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, 2019 | |
o | Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934. | |
Commission file number 000-53202 | ||
HOMELAND ENERGY SOLUTIONS, LLC | |||
(Exact name of registrant as specified in its charter) | |||
Iowa | 20-3919356 | ||
(State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) | ||
2779 Highway 24, Lawler, Iowa | 52154 | ||
(Address of principal executive offices) | (Zip Code) | ||
(563) 238-5555 | |||
(Registrant's telephone number, including area code) | |||
Securities registered pursuant to Section 12(b) of the Act: None | |||
Title of each class | Trading Symbol(s) | Name of each exchange on which registered |
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 every Interactive Data File required to be submitted 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 such files). x Yes o No
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth 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) | Emerging Growth Company | o | ||
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. | o | |||
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, 2019, the aggregate market value of the membership units held by non-affiliates (computed by reference to the most recent offering price of membership units) was $56,777,000.
As of March 6, 2020, there were 90,420 membership units outstanding. On June 13, 2013, the registrant entered into an agreement with Steve Retterath, the registrant's largest equity holder, to repurchase and retire all of the units owned by Mr. Retterath. The registrant agreed to repurchase and retire 25,860 membership units owned by Mr. Retterath in exchange for $30 million. This transaction has been the subject of litigation since August 2013. In February 2020, the Iowa Supreme Court ruled that the unit purchase agreement was valid and enforceable. As of December 31, 2019, the registrant had recorded a $30 million short-term liability related to the amount the registrant agreed to pay Mr. Retterath to repurchase his membership units and correspondingly reduced members' equity on our balance sheet. The 90,420 membership units outstanding include the contested membership units the registrant agreed to repurchase from Mr. Retterath.
DOCUMENTS INCORPORATED BY REFERENCE
The registrant has incorporated by reference into Part III of this Annual Report on Form 10-K portions of its definitive proxy statement to be filed with the Securities and Exchange Commission within 120 days after the close of the fiscal year covered by this Annual Report.
INDEX
Page No. | |
2
CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING STATEMENTS
This annual report contains historical information, as well as forward-looking statements that involve known and unknown risks and relate to future events, our future financial performance, or our expected future operations and actions. In some cases, you can identify forward-looking statements by terminology such as "may," "will," "should," "expect," "plan," "anticipate," "believe," "estimate," "future," "intend," "could," "hope," "predict," "target," "potential," or "continue" or the negative of these terms or other similar expressions. These forward-looking statements are only our predictions based on current information and involve numerous assumptions, risks and uncertainties. Our actual results or actions may differ materially from these forward-looking statements for many reasons, including the reasons described in this report. While it is impossible to identify all such factors, factors that could cause actual results to differ materially from those estimated by us include:
• | Reductions in the corn-based ethanol use requirement in the Federal Renewable Fuels Standard; |
• | Lower oil and gasoline prices which result in lower ethanol prices; |
• | Negative operating margins which result from lower ethanol prices; |
• | Lower ethanol prices which result from the Chinese and Brazilian tariffs; |
• | Lower distillers grains prices which result from the Chinese anti-dumping and anti-subsidy duties; |
• | Changes in the availability and price volatility of corn and natural gas; |
• | Decreases in the market price of ethanol, distiller grains and corn oil; |
• | Changes in economic conditions or the occurrence of certain events causing an economic impact in the agriculture, oil or automobile industries; |
• | Our ability to continue to satisfy the financial covenants contained in our credit agreements with our lender; |
• | Changes in interest rates or the lack of credit availability; |
• | Our ability to generate sufficient liquidity to fund our operations, debt service requirements and capital expenditures; |
• | The results of our hedging transactions and other risk management strategies; |
• | Changes in plant production capacity or technical difficulties in operating the plant; |
• | Changes in environmental regulations or in our ability to comply with the environmental regulations that apply to our plant site and our operations; |
• | Changes in or elimination of federal and/or state laws having an impact on the ethanol industry; |
• | Overcapacity within the ethanol industry; |
• | Lack of transport, storage and blending infrastructure preventing our products from reaching high demand markets; |
• | Changes and advances in ethanol production technology that may make it more difficult for us to compete with other ethanol plants utilizing such technology; |
• | Our reliance on key management personnel; and |
• | Competition in the ethanol industry from alternative fuels. |
The cautionary statements referred to in this section also should be considered in connection with any subsequent written or oral forward-looking statements that may be issued by us or any persons acting on our behalf. We undertake no duty to update these forward-looking statements, even though our situation may change in the future. Furthermore, we cannot guarantee future results, events, levels of activity, performance, or achievements. We caution you not to put undue reliance on any forward-looking statements, which speak only as of the date of this report. You should read this report and the documents that we reference in this report and have filed as exhibits, completely and with the understanding that our actual future results may be materially different from what we currently expect. We qualify all of our forward-looking statements by these cautionary statements.
AVAILABLE INFORMATION
Information about us is also available on our website at www.homelandenergysolutions.com, under "Investor Relations - SEC Filings," which includes links to reports we have filed with the Securities and Exchange Commission. The contents of our website are not incorporated by reference in this Annual Report on Form 10-K.
3
PART I
ITEM 1. BUSINESS.
Business Development
Homeland Energy Solutions, LLC (referred to herein as "we," "us," the "Company," "Homeland" or "Homeland Energy Solutions") is an Iowa limited liability company. We were formed on December 7, 2005 to build and operate a 100 million gallon per year ethanol plant located near Lawler, Iowa. The primary products produced at the plant are ethanol, distiller grains and corn oil. We commenced production on April 4, 2009. The ethanol plant is currently operating at a rate in excess of its nameplate production capacity of 100 million gallons of ethanol per year.
On June 13, 2013, we entered into an agreement with Steve Retterath, our largest member, to repurchase and retire all of the units owned by Mr. Retterath. We agreed to repurchase and retire 25,860 membership units owned by Mr. Retterath in exchange for $30 million, to be paid in two equal installments, payable at closing and on July 1, 2014. The transaction failed to close by August 1, 2013 due to objections by Mr. Retterath. On August 14, 2013, the Company filed a lawsuit against Mr. Retterath in Iowa state court to enforce the terms of the repurchase agreement. The Company asked the Iowa state court to require Mr. Retterath to complete the repurchase agreement pursuant to its terms.
In January 2017, we went to trial with Mr. Retterath on the first part of the Iowa state court case regarding whether the repurchase agreement is valid and enforceable. On June 15, 2017, the Iowa state court issued its ruling finding the repurchase agreement valid and enforceable and ordering Mr. Retterath to perform his obligations under the repurchase agreement. Following the Iowa state court's decision, Mr. Retterath filed post-trial motions in which he asked the court to reconsider its decision and grant a new trial and requested the court stay its order until these motions are considered. The Iowa state court granted the stay pending resolution of the post-trial motions. These post-trial motions were denied and Mr. Retterath filed an appeal of the Iowa state court's ruling. In February 2020, the Iowa Supreme Court ruled that the repurchase agreement was valid and enforceable.
Details of the Company's lawsuit against Mr. Retterath are provided below in the section entitled "PART I - Item 3. Legal Proceedings."
On February 7, 2019 we executed a second amended and restated consulting agreement with Cornerstone Resources LLC (the "Cornerstone Agreement"). Pursuant to the Cornerstone Agreement, Cornerstone Resources provides the services of James Broghammer to serve as the President and CEO of the Company. Pursuant to the Cornerstone Agreement, the engagement of Cornerstone Resources will continue until December 31, 2021 unless it is earlier terminated. Thereafter, the Cornerstone Agreement will continue on a month-to-month basis. Cornerstone Resources will be compensated on a flat fee basis per day of services provided. Cornerstone Resources is entitled to reimbursement of certain out of pocket expenses incurred pursuant to the Cornerstone Agreement. Mr. Broghammer is entitled to a bonus based on our net income pursuant to the restrictions set forth in the Cornerstone Agreement.
During our 2019 fiscal year, we paid two distributions for a total distribution of $22,596,000, $75 per membership unit paid in June 2019 to holders of 64,560 membership units, and $275 per membership unit paid in December 2019 to holders of 64,560 membership units.
Financial Information
Please refer to "Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations" for information about our revenue, profit and loss measurements and total assets and liabilities and "Item 8 - Financial Statements and Supplementary Data" for our financial statements and supplementary data.
4
Principal Products
The principal products that we produce are ethanol, distiller grains and corn oil. The table below shows the approximate percentage of our total revenue which is attributed to each of our primary products for each of our last three fiscal years.
Product | Fiscal Year 2019 | Fiscal Year 2018 | Fiscal Year 2017 | ||||||
Ethanol | 78 | % | 76 | % | 81 | % | |||
Distiller Grains | 18 | % | 20 | % | 14 | % | |||
Corn Oil | 4 | % | 4 | % | 5 | % | |||
Ethanol
Ethanol is ethyl alcohol, a fuel component made primarily from corn and various other grains. Ethanol is primarily used as: (i) an octane enhancer in fuels; (ii) an oxygenated fuel additive for the purpose of reducing ozone and carbon monoxide vehicle emissions; and (iii) a non-petroleum-based gasoline substitute. Ethanol produced in the United States is primarily used for blending with unleaded gasoline and other fuel products. Ethanol blended fuel is typically designated in the marketplace according to the percentage of the fuel that is ethanol, with the most common fuel blend being E10, which includes 10% ethanol. The United States Environmental Protection Agency ("EPA") has approved the use of gasoline blends that contain 15% ethanol, or E15, for use in all vehicles manufactured in model year 2001 and later. In addition, flexible fuel vehicles can use gasoline blends that contain up to 85% ethanol called E85.
Our ethanol plant uses corn as the feedstock in the ethanol production process. A corn-based ethanol plant is essentially a fermentation plant. Ground corn and water are mixed with enzymes and yeast to produce a substance called "beer," which contains approximately 15% alcohol, 11% solids and 74% water. The beer is boiled to separate the water, resulting in ethyl alcohol, which is then dehydrated to increase the alcohol content. This product is then mixed with a certified denaturant, such as gasoline, to make the product unfit for human consumption which allows it to be sold commercially.
Distiller Grains
The principal co-product of the ethanol production process is distiller grains, a high protein, high-energy animal feed supplement primarily marketed to the dairy and beef industry. We produce two forms of distiller grains: Modified/Wet Distiller Grains ("MWDG") and Distiller Dried Grains with Solubles ("DDGS"). MWDG is processed corn mash that has been dried to approximately 50% moisture. MWDG has a shelf life of approximately seven days and is often sold to markets near our ethanol plant. DDGS is processed corn mash that has been dried to approximately 10% moisture. It has a longer shelf life and may be sold and shipped to any market, regardless of its vicinity to our ethanol plant. We market nearly all of our distiller grains as DDGS.
Corn Oil
In October 2011, we commenced operating our corn oil extraction equipment. The corn oil extraction equipment we installed allows us to remove some of the corn oil contained in our distiller grains and sell the corn oil separately. The corn oil that we are capable of producing is not food grade corn-oil and it cannot be used for human consumption. The primary uses of the corn oil that we produce are for animal feed, industrial uses and biodiesel production.
Principal Product Markets
Ethanol
The primary market for our ethanol is the domestic fuel blending market. Other than in 2019, over recent years the United States has experienced increased ethanol exports. This increase in ethanol exports followed a conscious effort by the United States ethanol industry to expand ethanol exports along with lower ethanol prices which encourage exports. During our 2019 fiscal year, exports of ethanol have decreased, but with the top export destinations being Canada, Brazil, India, China, South Korea, the Philippines and Peru. Ethanol export demand is more unpredictable than domestic demand and tends to fluctuate throughout the year as it is subject to monetary and political forces in other nations. An example of this, the recent imposition of a tariff on imported ethanol by Brazil and increased tariffs implemented by China have created uncertainty as to the viability of these markets for ethanol produced in the United States and may require United States producers to seek out other markets for their products. The trade actions taken by other countries are unpredictable and can have a significant impact on domestic demand and prices as excess ethanol supply can significantly reduce domestic ethanol prices. The industry continues to look for new export markets in order to diversify demand for ethanol.
5
Ethanol is generally blended with gasoline before it is sold to the end consumer. Therefore, the primary purchasers of ethanol are fuel blending companies who mix the ethanol we produce with gasoline. As discussed below in the section entitled "Distribution of Principal Products," we have a third party marketer that sells all of our ethanol. Our ethanol marketer makes substantially all decisions regarding where our ethanol is sold.
Distiller Grains
Distiller grains are primarily used as animal feed. Distiller grains are typically fed to animals instead of other traditional animal feeds such as corn and soybean meal. Distiller grains exports have increased in recent years as distiller grains have become a more accepted animal feed. During our 2019 fiscal year, the largest importers of United States distiller grains were Mexico, Turkey, South Korea, Thailand, China and Canada. Distiller grains demand has continued to be impacted by Chinese tariffs on distiller grains. Historically, China was the largest export market for United States distiller grains. However, due to continuing trade tensions between the United States and China, management does not believe China will significantly increase its demand for distiller grains in the near term which could impact profitability in the ethanol industry during 2020.
Corn Oil
The primary markets for corn oil are the industrial chemicals market, animal feeding market and the biodiesel production market. Corn oil demand was relatively stable during our 2019 fiscal year. However, additional corn oil supply has continued to enter the market as the production capacity of the United States ethanol industry has expanded which has negatively impacted corn oil prices. The market for corn oil is expected to continue to shift as changes in supply and demand of corn oil interact. Our corn oil is primarily marketed in the United States and we do not expect that significant exports of corn oil will occur in the near future.
Distribution of Principal Products
We have hired third party marketers which are responsible for the distribution of all of the products we produce. Below is a description of the arrangements we have with our ethanol, distiller grains and corn oil marketers.
Ethanol Distribution
We have an ethanol marketing agreement with Renewable Products Marketing Group, Inc. ("RPMG"), a professional third party marketer, which is the sole marketer of our ethanol. RPMG also markets all of our corn oil. We are an equity owner of RPMG, LLC ("RPMG, LLC"), the parent company of RPMG, which allows us to realize favorable marketing fees and transparency in the sale of our ethanol and corn oil. Our ethanol marketing agreement provides we can sell our ethanol either through an index arrangement or at a fixed price agreed to between us and RPMG. The term of the ethanol marketing agreement is perpetual, until it is terminated. The primary reasons the ethanol marketing agreement would terminate are if we cease to be an owner of RPMG, LLC, if there is a breach of the ethanol marketing agreement which is not cured, or if we give advance notice to RPMG that we wish to terminate the ethanol marketing agreement. Notwithstanding our right to terminate the ethanol marketing agreement, we may be obligated to continue to market our ethanol through RPMG for a period of time after termination. Further, following termination, we would accept an assignment of certain railcar leases which RPMG has secured to service our ethanol sales. If our ethanol marketing agreement is terminated, it would trigger a redemption by RPMG, LLC of our ownership interest in RPMG, LLC.
Distiller Grains Distribution
We have a Distiller Grains Marketing Agreement with CHS, Inc. ("CHS"), pursuant to which CHS agreed to purchase all of the distiller grains produced at our plant. The initial term of the distiller grains marketing agreement was one year, beginning with the start-up of operations and production at the plant. After the initial one-year term, the agreement automatically renews for successive one year terms unless either party gives 90 days written notice of termination before the current term expires.
CHS agreed to pay us 98% of the actual sale price received by CHS from its customers for DDGS sold and 96% of the actual sale price received by CHS for MWDG sold, subject to certain minimum and maximum fees per ton. CHS deducts the customary freight costs incurred by CHS in delivering the distiller grains to its customers from our portion of the distiller grains sale price.
6
Corn Oil Distribution
In July 2011, we entered into a Corn Oil Marketing Agreement with RPMG. We have an exclusive marketing arrangement with RPMG where it will market all of the corn oil that we produce. We agreed to pay RPMG a commission based on each pound of corn oil that RPMG sells on our behalf. We also agreed to pay certain costs associated with RPMG marketing our corn oil. The initial term of the corn oil marketing agreement is for one year and the agreement automatically renews for additional one year terms unless written notice is given, either by us or RPMG, at least ninety days prior to the expiration of the current term of the agreement.
New Products and Services
We did not introduce any new products or services during our 2019 fiscal year.
Competition
We are in direct competition with numerous ethanol producers in the sale of our products and with respect to raw material purchases related to those products. Many of the ethanol producers with which we compete have greater resources than we do. While management believes we are a lower cost producer of ethanol, larger ethanol producers may be able to take advantage of economies of scale due to their larger size and increased bargaining power with both ethanol, distiller grains and corn oil customers as well as raw material suppliers. As of December 3, 2019, the Renewable Fuels Association estimates that there are 212 ethanol production facilities in the United States with capacity to produce approximately 16.6 billion gallons of ethanol per year. According to RFA estimates, approximately 9% of the ethanol production capacity in the United States was not operating as of December 3, 2019. The largest ethanol producers include Archer Daniels Midland, Flint Hills Resources, Green Plains Renewable Energy, POET Biorefining, 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 800
million gallons per year (MMgy) or more
Company | Current Capacity (MMgy) | Percent of Market | ||
Archer Daniels Midland | 1,616 | 10% | ||
POET Biorefining | 1,711 | 10% | ||
Valero Renewable Fuels | 1,697 | 10% | ||
Green Plains Renewable Energy | 1,111 | 7% | ||
Flint Hills Resources | 840 | 5% | ||
Updated: December 3, 2019
The products that we produce are commodities. Since our products are commodities, there are typically no significant differences between the products we produce and the products of our competitors that would allow us to distinguish our products in the market. As a result, competition in the ethanol industry is primarily based on price and consistent quality.
We have experienced increased competition from oil companies that have purchased ethanol production facilities. These oil companies are required to blend a certain amount of ethanol each year. Therefore, the oil companies may be able to operate their ethanol production facilities at times when it is unprofitable for us to operate our ethanol plant. Further, some ethanol producers own multiple ethanol plants which may allow them to compete more effectively by providing them flexibility to run certain production facilities while they have other facilities shut down. Finally, some ethanol producers which own ethanol plants in different areas of the United States may spread the risk they encounter related to feedstock prices due to localized corn shortages or poor growing conditions.
We anticipate increased competition from renewable fuels that do not use corn as the feedstock. Many of the current ethanol production incentives are designed to encourage the production of renewable fuels using raw materials other than corn. One type of ethanol production feedstock that is being explored is cellulose. Cellulose is the main component of plant cell walls and is the most common organic compound on earth. Cellulose is found in wood chips, corn stalks, rice straw, amongst other
7
common plants. Cellulosic ethanol is ethanol produced from cellulose. There are several commercial scale cellulosic ethanol production facilities either in production or in the construction phase. If this technology can be profitably employed on a commercial scale, it could potentially lead to ethanol that is less expensive to produce than corn based ethanol, especially when corn prices are high. Cellulosic ethanol may also capture more government subsidies and assistance than corn based ethanol. This could decrease demand for our product or result in competitive disadvantages for our ethanol production process.
A number of automotive, industrial and power generation manufacturers are developing alternative clean power systems using fuel cells, plug-in hybrids, electric cars or clean burning gaseous fuels. Electric car technology has 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. These efforts have resulted in increased market share enjoyed by electric cars. Additional competition from these other sources of alternative energy, particularly in the automobile market, could reduce the demand for ethanol, which would negatively impact our profitability.
Competition among ethanol producers may continue to increase as gasoline demand decreases due to more fuel efficient vehicles being produced. If the concentration of ethanol used in most gasoline does not increase and gasoline demand is lower due to increased fuel efficiency by the vehicles operated in the United States, competition may increase among ethanol producers to supply the ethanol market.
Distiller Grains Competition
Our ethanol plant competes with other ethanol producers in the production and sales of distiller grains. Distiller grains are primarily used as an animal feed supplement which replaces corn and soybean meal. As a result, we believe that distiller grains prices are positively impacted by increases in corn and soybean prices. In addition, in recent years the United States ethanol industry has increased exports of distiller grains which management believes has positively impacted demand and prices for distillers grains in the United States. In the event these distiller grains exports decrease, including as a result of the Chinese tariffs which have significantly reduced export demand for distiller grains, it could lead to an oversupply of distiller grains in the United States. An oversupply of distiller grains could result in increased competition among ethanol producers for sales of distiller grains which could negatively impact market distiller grains prices in the United States.
Corn Oil Competition
We compete with many ethanol producers for the sale of corn oil. Many ethanol producers have installed the equipment necessary to separate corn oil from the distiller grains they produce which has increased competition for corn oil sales and has resulted in lower market corn oil prices. Many ethanol producers have increased corn oil production due to the relatively low value of distiller grains which has increased corn oil competition.
Sources and Availability of Raw Materials
Corn Supply
The major raw material required to produce ethanol, distiller grains and corn oil at our plant is corn. The ethanol plant is currently operating at a rate in excess of its nameplate capacity. We anticipate that we will require approximately 65 million bushels of corn per year to produce approximately 190 million gallons of ethanol per year. We buy as much corn as possible from local grain elevators and farmers. Our commodities manager is responsible for purchasing corn for our operations, scheduling corn deliveries and establishing hedging positions to protect the price we pay for corn.
Corn prices were higher during our 2019 fiscal year compared to previous years as a result of a decrease in the amount of corn harvested in the fall of 2019 in our local corn draw area. We have not had difficulty securing the corn we need to operate the ethanol plant, however, our cost to purchase the corn we require has been higher. There is less corn available in our local market due to the wet weather and flooding in the spring of 2019, which delayed planting, along with wet weather during harvest, which delayed the harvest, it may have decreased the amount of corn harvested in the fall of 2019. This may require us to purchase corn which is grown farther away from our plant which may increase our corn costs during our 2020 fiscal year. Since corn is the primary raw material we use to produce our products, the availability and cost of corn can have a significant impact on the profitability of our operations.
8
Commodities Account/Risk Management
In an attempt to minimize the effects of the volatility of corn costs on our profitability, we have two commodities trading accounts with ADM Investor Services, Inc. ("ADMIS"). In addition, we have a commodities manager who manages our corn procurement activities. ADMIS serves as our broker for the purchase and sale of commodity futures contracts for corn, and enters into transactions and exercises commodity options for our account in accordance with our instructions. We are required to maintain adequate margins in our accounts, and if we do not maintain adequate margins, ADMIS may close out any of our positions or transfer funds from our other accounts to cover the margin.
The effectiveness of our risk management strategy is dependent on the cost of corn and our ability to sell sufficient ethanol to use all of the corn for which we have futures contracts. Our risk management activities may not be successful in reducing the risk caused by price fluctuation, which may leave us vulnerable to high corn prices.
Utilities
We entered into an agreement with Northern Natural Gas in April 2008 for connection to its interstate pipeline and for transportation services for our natural gas supply. To access sufficient supplies of natural gas to operate the plant, a dedicated lateral pipeline from Northern Natural Gas's interstate pipeline has been constructed to service our plant. Construction of the natural gas lateral pipeline was completed prior to the commencement of our operations at the ethanol plant. We purchase our natural gas through various suppliers.
We entered into an Energy Management Services Agreement with U.S. Energy dated July 10, 2009. U.S. Energy is now known as Kinect. Pursuant to the agreement, Kinect assists us with electric energy and natural gas management and procurement. Kinect's responsibilities include administration of our gas supply contracts, nomination, scheduling and other logistical issues such as storage and transportation, negotiation and delivery. We work with Kinect to provide estimated usage volumes on a monthly basis. In exchange for these management services, we pay a monthly service fee, as well as pre-approved expenses in connection with the services. The agreement for these services continues on a month-to-month basis.
On March 6, 2009, we entered into an Electrical Services Agreement with Hawkeye Tri-County Electric Cooperative (Hawkeye), to supply all of the electricity necessary to operate the ethanol plant. Pursuant to the agreement, Hawkeye has installed the electrical facilities necessary to deliver all of the electric power and energy required to operate our ethanol plant. The agreement with Hawkeye remained in effect for ten years from the date we began processing ethanol at the plant (April 2009), and terminated on the tenth anniversary of that date (April 2019). We may continue to receive the service following expiration of the ten-year term for a minimum of two years. Either party will then have the right to terminate the agreement upon six months' written notice. Hawkeye recently completed a merger and is now called MiEnergy Cooperative.
During our 2016 fiscal year we installed a steam turbine which allows us to use excess steam produced by the ethanol plant to generate electricity that we use in our production process. Management believes that this project allows us to decrease our total utility costs and allows us to operate the ethanol plant more profitably.
Seasonality of Sales
We experience some seasonality of demand for our ethanol, distiller grains and corn oil. Since ethanol is predominantly blended with gasoline for use in automobiles, ethanol demand tends to shift in relation to gasoline demand. As a result, we experience some seasonality of demand for ethanol in the summer months related to increased driving and, as a result, increased gasoline demand. In addition, we experience some increased ethanol demand during holiday seasons related to increased gasoline demand. We also experience decreased distiller grains demand during the summer months due to natural depletion in the size of herds at cattle feed lots and when the animals are turned out to pasture or are slaughtered. Further, we expect some seasonality of demand for our corn oil since a major corn oil user is the biodiesel industry which typically reduces production during the winter months.
Working Capital
We primarily use our working capital for purchases of raw materials necessary to operate the ethanol plant, for payments on our credit facilities, for distributions to our members and for capital expenditures to maintain and upgrade the ethanol plant. Our primary sources of working capital are income from our operations as well as our revolving line of credit with our primary lender, Home Federal Savings Bank ("Home Federal"). Management believes that our current sources of working capital are sufficient to sustain our operations for our 2020 fiscal year and beyond.
9
Dependence on One or a Few Major Customers
As discussed previously, we have exclusive marketing agreements with RPMG for sales of our ethanol and corn oil and with CHS for sales of our distiller grains. As a result, we rely on RPMG and CHS for the sale and distribution of all of our products. Any loss of RPMG or CHS as the marketing agent for our products could have a significant negative impact on our revenues. While we anticipate that we could secure other ethanol, distiller grains and corn oil marketers if necessary, any loss of our marketers could significantly impact our ability to operate the ethanol plant profitably.
Patents, Trademarks, Licenses, Franchises and Concessions
We do not currently hold any patents, trademarks, franchises or concessions. We were granted a perpetual and royalty free license by ICM, Inc. ("ICM") to use certain ethanol production technology necessary to operate our ethanol plant. The cost of the license granted by ICM was included in the amount we paid to Fagen, Inc. to design and build our ethanol plant.
Federal Ethanol Supports and Governmental Regulation
Federal Ethanol Supports
The ethanol industry is dependent on the Federal Renewable Fuels Standard (the "RFS"). The RFS requires that in each year, a certain amount of renewable fuels must be used in the United States. The RFS is a national program that does not require that any renewable fuels be used in any particular area or state, allowing refiners to use renewable fuel blends in those areas where it is most cost-effective. The RFS statutory volume requirement increases incrementally each year until the United States is required to use 36 billion gallons of renewable fuels by 2022, including both corn-based and advanced ethanol. Starting in 2009, the RFS required that a portion of the RFS must be met by certain "advanced" renewable fuels. These advanced renewable fuels include ethanol that is not made from corn, such as cellulosic ethanol and biomass based biodiesel. The use of these advanced renewable fuels increases each year as a percentage of the total renewable fuels required to be used in the United States.
The United States Environmental Protection Agency (the "EPA") has the authority to waive the RFS statutory volume requirement, in whole or in part, provided one of the following two conditions have been met: (1) there is inadequate domestic renewable fuel supply; or (2) implementation of the requirement would severely harm the economy or environment of a state, region or the United States. Annually, the EPA is supposed to pass a rule that establishes the number of gallons of different types of renewable fuels that must be used in the United States which is called the renewable volume obligations. Recently, the EPA has been granting small refinery exemptions from the RFS while not using its authority to waive the RFS statutory volume requirements. These small refinery exemptions created unallocated gallons reducing the corn-based conventional biofuel RFS requirements by 2.25 billion gallons in 2018 and 2 billion gallons in 2019. These small refinery exemptions have had a significant negative impact on domestic demand for ethanol and have resulted in negative operating margins in the ethanol industry.
In recent years, the EPA has reduced the volume obligations for advanced renewable fuels under the RFS which has negatively impacted demand for ethanol. The RFS statutory Renewable Volume Obligation (RVO) and the EPA's RVO (in billion gallons) are as follows:
Year | Total Renewable Volume Obligation | Total Renewable Volume Obligation For Corn-based Ethanol | ||||
2017 | Statutory | 24.00 | 15.00 | |||
EPA Rule | 19.28 | 15.00 | ||||
2018 | Statutory | 26.00 | 15.00 | |||
EPA Rule | 19.29 | 15.00 | ||||
2019 | Statutory | 28.00 | 15.00 | |||
EPA Rule | 19.92 | 15.00 | ||||
2020 | Statutory | 30.00 | 15.00 | |||
EPA Rule | 20.09 | 15.00 | ||||
In February 2010, the EPA issued new regulations governing the RFS. These new regulations are called RFS2. The most controversial part of RFS2 involves what is commonly referred to as the lifecycle analysis of greenhouse gas emissions. Specifically, the EPA adopted rules to determine which renewable fuels provided sufficient reductions in greenhouse gases, compared to conventional gasoline, to qualify under the RFS program. RFS2 establishes a tiered approach, where regular renewable fuels are required to accomplish a 20% greenhouse gas reduction compared to gasoline, advanced biofuels and biomass-based biodiesel
10
must accomplish a 50% reduction in greenhouse gases, and cellulosic biofuels must accomplish a 60% reduction in greenhouse gases. Any fuels that fail to meet this standard cannot be used by fuel blenders to satisfy their obligations under the RFS program. The scientific method of calculating these greenhouse gas reductions has been a contentious issue. Many in the ethanol industry were concerned that corn-based ethanol would not meet the 20% greenhouse gas reduction requirement based on certain parts of the environmental impact model that many in the ethanol industry believed was scientifically suspect. However, RFS2 as adopted by the EPA provides that corn-based ethanol from modern ethanol production processes does meet the definition of a renewable fuel under the RFS program. Our ethanol plant was grandfathered into the RFS due to the fact that it was constructed prior to the effective date of the lifecycle greenhouse gas requirement and is not required to prove compliance with the lifecycle greenhouse gas reductions. Many in the ethanol industry are concerned that certain provisions of RFS2 as adopted may disproportionately benefit ethanol produced from sugarcane which could make sugarcane-based ethanol, which is primarily produced in Brazil, more competitive in the United States ethanol market. If this were to occur, it could reduce demand for the ethanol that we produce.
Most ethanol that is used in the United States is sold in a blend called E10. E10 is a blend of 10% ethanol and 90% gasoline. E10 is approved for use in all standard vehicles. Estimates indicate that gasoline demand in the United States is approximately 143 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 domestic demand for ethanol is 14.3 billion gallons per year. This is commonly referred to as the "blend wall," which represents a theoretical limit where more ethanol cannot be blended into the national gasoline pool. This is a theoretical limit because it is believed that it would not be possible to blend ethanol into every gallon of gasoline that is being used in the United States and it discounts the use of higher percentage blends such as E15 or E85. These higher percentage blends may lead to additional ethanol demand if they become more widely available and accepted by the market.
Many in the ethanol industry believe that it will be impossible to meet the RFS requirement in future years without an increase in the percentage of ethanol that can be blended with gasoline for use in standard (non-flex fuel) vehicles. The EPA has approved the use of E15, gasoline which is blended at a rate of 15% ethanol and 85% gasoline, in vehicles manufactured in the model year 2001 and later. However, there are still hurdles that need to be addressed in some states before E15 will become more widely available. Many states still have regulatory issues that prevent the sale of E15. Sales of E15 may be limited because it is not approved for use in all vehicles, the EPA requires a label that management believes may discourage consumers from using E15, and retailers may choose not to sell E15 due to concerns regarding liability. As a result, the approval of E15 by the EPA has not had an immediate impact on ethanol demand in the United States. In June 2019, the Trump Administration approved the use of E15 year-round which has somewhat expanded the use of E15, but has not been significant enough to offset demand losses which resulted from the small refinery waivers from the RFS.
Effect of Governmental Regulation
Plant operations are governed by the Occupational Safety and Health Administration ("OSHA"). OSHA regulations may change such that the costs of operating the ethanol plant may increase. Any of these regulatory factors may result in higher costs or other adverse conditions effecting our operations, cash flows and financial performance.
In late 2009, California passed a Low Carbon Fuels Standard ("LCFS"). The California LCFS requires that renewable fuels used in California must accomplish certain reductions in greenhouse gases which is measured using a lifecycle analysis, similar to the RFS. The LCFS could have a negative impact on demand for corn-based ethanol and result in decreased ethanol prices affecting our ability to operate profitably.
Costs and Effects of Compliance with Environmental Laws
We are subject to extensive air, water and other environmental regulations and we require a number of environmental permits to operate the plant. We have obtained all permits that are currently required for operation of the plant. In the fiscal year ended December 31, 2019, we incurred costs and expenses of approximately $195,000 complying with environmental laws, including the cost of obtaining permits. Although we have been successful in obtaining all of the permits currently required, any retroactive change in environmental regulations, either at the federal or state level, could require us to obtain additional or new permits or spend considerable resources in complying with such regulations. We anticipate incurring costs and expenses of approximately $200,000 for compliance with environmental laws for our fiscal year ended December 31, 2020.
Employees
As of December 31, 2019, we had 54 full-time employees. We do not anticipate a significant change in the number of full-time employees we have in the next 12 months.
11
ITEM 1A. RISK FACTORS.
You should carefully read and consider the risks and uncertainties below and the other information contained in this report. The risks and uncertainties described below are not the only ones we may face. The following risks, together with additional risks and uncertainties not currently known to us or that we currently deem immaterial could impair our financial condition and results of operation.
Risks Relating to Our Business
The spread between ethanol and corn prices can vary significantly which can negatively impact our financial condition. Our only source of revenue comes from sales of our ethanol, distiller grains and corn oil. The primary raw materials we use to produce our ethanol, distiller grains and corn oil are corn and natural gas. In order to operate the ethanol plant profitably, we must maintain a positive spread between the revenue we receive from sales of our products and our corn and natural gas costs. This spread between the market price of our products and our raw material costs has been volatile in the past. If we were to experience a period of time where this spread is negative, and the negative margins continue for an extended period of time, it may prevent us from profitably operating the ethanol plant which could decrease the value of our units.
Decreasing gasoline prices may lower ethanol prices which could negatively impact our ability to operate profitably. In recent years, the price of ethanol has been less than the price of gasoline which increased demand for ethanol from fuel blenders. However, at times the price of gasoline has decreased which has reduced the spread between the price of gasoline and the price of ethanol. This trend negatively impacted ethanol prices. If this trend were to return and continue for a significant period of time, it could hurt our ability to profitably operate the ethanol plant which could decrease the value of our units.
Distiller grains demand and prices has been negatively impacted by the Chinese anti-dumping and countervailing duty investigation. China was historically the world's largest importer of distiller grains produced in the United States. On January 12, 2016, the Chinese government announced that it would commence an anti-dumping and countervailing duty investigation related to distiller grains imported from the United States. On September 23, 2016, the Chinese instituted a preliminary anti-dumping duty of 33% in response to this investigation and an anti-subsidy duty on September 30, 2016 of approximately 10%. In January 2017, the Chinese finalized the anti-dumping and anti-subsidy duties at rates higher than the preliminary rates set in September 2016. The anti-dumping duties range from 42.2% to 53.7%, an increase from the preliminary duty of 33.8% issued in September 2016. The final anti-subsidy tariffs range from 11.2% to 12%, up from 10% to 10.7% issued in September 2016. Both during the investigation and after the announcement of the duties, distiller grains demand and prices have been negatively impacted. While we expect China to continue to import some distiller grains, we do not anticipate that the imports will be at the same level as previous years which could continue to negatively impact market distiller grains demand and prices. This potential reduction in demand along with lower domestic corn prices could negatively impact our ability to profitably operate the ethanol plant.
A reduction in ethanol exports to Brazil due to the imposition by the Brazilian government of a tariff on U.S. ethanol could have a negative impact on ethanol prices. Brazil has historically been a top destination for ethanol produced in the United States. However, in 2017, Brazil imposed a 20% tariff on ethanol which is produced in the United States and exported to Brazil. This tariff has resulted in a decline in demand for ethanol from Brazil and could negatively impact the market price of ethanol in the United States and our ability to profitably operate the ethanol plant.
We may be forced to reduce production or cease production altogether if we are unable to secure the corn we require at prices which allow us to profitably operate the ethanol plant. We require a significant amount of corn to operate the ethanol plant at capacity. In recent years, the supply of corn in the market has been higher and we have not had difficulty securing the corn we require at prices that allow us to operate profitably. However, during 2019 the United States experienced late corn planting and harvest due to wet weather conditions. These unfavorable weather conditions resulted in higher corn prices during 2019. Further, the late corn harvest may result in less corn being harvested and more quality issues with the corn which could impact our operations during our 2020 fiscal year. If we are unable to secure the corn we require to continue to operate the ethanol plant, or we are unable to secure corn at prices that allow us to operate profitably, we may have to reduce production or cease operating altogether which may negatively impact the value of our units.
We may violate the terms of our credit agreements and financial covenants which could result in our lender demanding immediate repayment of our loans. Our credit agreements with Home Federal require that we comply with various financial loan covenants. We are currently in compliance with all of our financial loan covenants. Current management projections indicate that we will be in compliance with our loan covenants for at least the next 12 months. However, unforeseen circumstances may develop which could result in us violating our loan covenants. If we violate the terms of our credit agreements, including our financial loan covenants, Home Federal could deem us to be in default of our loans and prevent us from drawing funds on our revolving line of credit and also require us to immediately repay any outstanding balance of our loans. If we do not have the funds
12
available to repay the loans or we cannot find another source of financing, we may fail which could decrease or eliminate the value of our units.
Our marketers may fail to sell all of the ethanol, distiller grains and corn oil we produce which could negatively impact our profitability. We rely on our ethanol, distiller grains and corn oil marketers to sell all of our products. Currently we have an agreement with RPMG which markets all of our ethanol and corn oil and we have an agreement with CHS to market all of our distiller grains. Our only source of revenue is from the sale of our ethanol, distiller grains and corn oil. If our marketers are unable to sell all of the ethanol, distiller grains or corn oil we produce, or if they are unable to sell them at prices that allow us to operate profitability, the value of our units may be negatively impacted. Further, RPMG or CHS could fail. While we anticipate that we will be able to secure alternative marketers should RPMG or CHS cease marketing our products for any reason, we may not be able to do so without incurring additional costs or without a reduction in our revenue. Any loss of our ethanol, distiller grains or corn oil marketers may negatively impact our profitability and could decrease the value of our units.
We engage in hedging transactions which involve risks that can harm our business. We are exposed to market risk from changes in commodity prices. Exposure to commodity price risk results from our dependence on corn and natural gas in the ethanol production process. We seek to minimize the risks from fluctuations in the prices of corn and natural gas through the use of hedging instruments. These hedging instruments can be risky and can negatively impact our liquidity. In times when commodity prices are volatile, we may be required to use significant amounts of cash to make margin calls as a result of our hedging positions. The effectiveness of our hedging strategies is dependent on the cost of corn and natural gas and our ability to sell sufficient products to use all of the corn and natural gas for which we have futures contracts. Our hedging activities may not successfully reduce the risk caused by price fluctuations which may leave us vulnerable to high corn and natural gas prices. Alternatively, we may choose not to engage in hedging transactions in the future. As a result, our future results of operations and financial condition may also be adversely affected during periods in which corn and/or natural gas prices increase. These hedging transactions could impact our ability to profitably operate the ethanol plant and negatively impact our liquidity.
Our business is not diversified. Our success depends almost entirely on our ability to profitably operate our ethanol plant. We do not have any other lines of business or other sources of revenue if we are unable to operate our ethanol plant and manufacture ethanol, distiller grains and corn oil. If economic or political factors adversely affect the market for ethanol, distiller grains and corn oil, we have no other line of business to fall back on. Our business would also be significantly harmed if the ethanol plant could not operate at full capacity for any extended period of time which could reduce the value of our units.
We depend on our management and key employees, and the loss of these relationships could negatively impact our ability to operate profitably. We are highly dependent on our management team to operate our ethanol plant. Our management employees may decide to end their employment with us. If one or more of our management employees terminate their employment, we may not be able to replace these individuals. While we seek to compensate our management and key employees in a manner that will encourage them to continue their employment with us, they may choose to seek other employment. Any loss of these managers or key employees may prevent us from operating the ethanol plant profitably and could decrease the value of our units.
We may incur casualty losses that are not covered by insurance which could negatively impact the value of our units. We have purchased insurance which we believe adequately covers our losses from foreseeable risks. However, there are risks that we may encounter for which there is no insurance or for which insurance is not available on terms that are acceptable to us. If we experience a loss which materially impairs our ability to operate the ethanol plant which is not covered by insurance, the value of our units could be reduced or eliminated.
Our operations may be negatively impacted by natural disasters, severe weather conditions, and other unforeseen plant shutdowns which can negatively impact our operations. Our operations may be negatively impacted by events outside of our control such as natural disasters, severe weather, strikes, train derailments and other unforeseen events which may negatively impact our operations. If we experience any of these unforeseen circumstances which negatively impact our operations, it may affect our cash flow and negatively impact the value of our business.
Changes and advances in ethanol production technology could require us to incur costs to update our plant or could otherwise hinder our ability to compete in the ethanol industry or operate profitably. Advances and changes in the technology of ethanol production are expected to occur. Such advances and changes may make the ethanol production technology installed in our plant less desirable or obsolete. These advances could also allow our competitors to produce ethanol at a lower cost than 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
13
be available or, once obtained, they may not continue to be available on commercially reasonable terms. These costs could negatively impact our financial performance by increasing our operating costs and reducing our net income.
Failures of our information technology infrastructure could negatively impact our operations. We utilize various software applications and other information technology that are critically important to our business operations. We rely on information technology networks and systems, including the Internet, to process, transmit and store electronic and financial information, to manage a variety of business processes and activities, including production, manufacturing, financial, logistics, sales, marketing and administrative functions. We depend on our information technology infrastructure to communicate internally and externally with employees, customers, suppliers and others. We also use information technology networks and systems to comply with regulatory, legal and tax requirements. These information technology systems, some of which are managed by third parties, may be susceptible to damage, disruptions or shutdowns due to failures during the process of upgrading or replacing software, databases or components thereof, power outages, hardware failures, computer viruses, attacks by computer hackers or other cybersecurity risks, telecommunication failures, user errors, natural disasters, terrorist attacks or other catastrophic events. If any of our significant information technology systems suffer severe damage, disruption or shutdown, and our disaster recovery and business continuity plans do not effectively resolve the issues in a timely manner, our product sales, financial condition and results of operations may be materially and adversely affected.
A cyber attack or other information security breach could negatively impact our operations and financial performance. We are regularly the target of attempted cyber and other security threats and must continuously monitor and develop our information technology networks and infrastructure to prevent, detect, address and mitigate the risk of unauthorized access, misuse, computer viruses and other events that could have a security impact. If we are unable to prevent cyber attacks and other information security breaches, we may encounter significant disruptions in our operations which could adversely impact our business, financial condition and results of operations or result in the unauthorized disclosure of confidential information. Such breaches may also harm our reputation, result in financial losses or subject us to litigation or other costs or penalties.
Risks Related to Ethanol Industry
Excess ethanol supply in the market could put negative pressure on the price of ethanol which could lead to tight operating margins and may impact our ability to operate profitably. In the past the ethanol industry has confronted market conditions where ethanol supply exceeded demand which led to unfavorable operating conditions. Most recently, in 2012, profitability in the ethanol industry was reduced due to increased ethanol imports from Brazil at a time when gasoline demand in the United States was lower and domestic ethanol supplies were higher. This disconnect between ethanol supply and demand resulted in lower ethanol prices at a time when corn prices were higher which led to unfavorable operating conditions. We may experience periods of time when ethanol supply exceeds demand which could negatively impact our profitability. The United States benefited from additional exports of ethanol in recent years. However, this did not continue to occur for our 2019 fiscal year, and may not continue to occur during our 2020 fiscal year. We may experience periods of ethanol supply and demand imbalance during our 2020 fiscal year. If we experience excess ethanol supply, either due to increased ethanol production or lower gasoline demand, it could negatively impact the price of ethanol which could hurt our ability to profitably operate the ethanol plant.
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 143 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 14.3 billion gallons. This is commonly referred to as the "blend wall," which represents a theoretical limit where more ethanol cannot be blended into the national gasoline pool. Many in the ethanol industry believe that the ethanol industry has reached this blend wall. 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. The EPA approved the use of E15 for standard (non-flex fuel) vehicles produced in the model year 2001 and later. 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, which could reduce or eliminate 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
14
cellulose-based biomass would create opportunities to produce ethanol in areas of the country which are unable to grow corn. The RFS requires that 16 billion gallons per year of advanced bio-fuels, such as cellulosic ethanol, must be consumed in the United States by 2022. Additionally, state and federal grants have been awarded to several companies which are seeking to develop commercial scale cellulosic ethanol plants. This has encouraged innovation and has led to several companies which have completed construction or are in the process of building commercial scale cellulosic ethanol plants. If an efficient method of producing ethanol from cellulose-based biomass is developed, we may not be able to compete effectively. If we are unable to produce ethanol as cost-effectively as cellulose-based producers, our ability to generate revenue and our financial condition will be negatively impacted.
Growth in the ethanol industry is dependent on growth in the fuel blending infrastructure to accommodate ethanol, which may be slow and could result in decreased ethanol demand. The ethanol industry depends on the fuel blending industry to blend the ethanol that is produced with gasoline so it may be sold to the end consumer. Substantial investments are required to expand this blending infrastructure and the fuel blending industry may choose not to expand the blending infrastructure to accommodate ethanol. Should the ability to blend ethanol not expand at the same rate as increases in ethanol supply, it may decrease the demand for ethanol which may lead to a decrease in the selling price of ethanol, which could impact our ability to operate profitably.
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 ethanol producers located outside of the United States. The largest ethanol producers include Archer Daniels Midland, Flint Hills Resources, Green Plains Renewable Energy, POET Biorefining, and Valero Renewable Fuels, each which is capable of producing significantly more ethanol than we produce. Further, many believe that there will be consolidation occurring in the ethanol industry which will likely lead to a few companies which control a significant portion of the United States ethanol production market. We may not be able to compete with these larger producers. These larger ethanol producers may be able to affect the ethanol market in ways that are not beneficial to us which could negatively impact our financial performance and the value of our units.
Competition from the advancement of alternative fuels and technologies may lessen demand for ethanol. Alternative fuels, gasoline oxygenates and ethanol production methods are continually under development. A number of automotive, industrial and power generation manufacturers are developing alternative clean power systems using fuel cells, plug-in hybrids, and electric cars or clean burning gaseous fuels. Like ethanol, these emerging technologies offer an option to address worldwide energy costs, the long-term availability of petroleum reserves and environmental concerns. If these alternative technologies continue to expand and gain broad acceptance and become readily available to consumers for motor vehicle use, we may not be able to compete effectively. This additional competition could reduce the demand for ethanol, resulting in lower ethanol prices that might adversely affect our results of operations and financial condition.
If exports of ethanol are reduced, ethanol prices may be negatively impacted. The United States ethanol industry was supported during our 2019 fiscal year with exports of ethanol. Management believes exports of ethanol were due to lower market ethanol prices in the United States and increased global demand for ethanol. However, these ethanol exports may continue to decrease. In 2017, China and Brazil both implemented import tariffs on United States ethanol and the European Union has maintained a tariff since 2012, which was only recently repealed in 2019. As a result of small refinery exemptions in 2018 and 2019, we are experiencing the impact of excess ethanol supplies in the market. Without exports of ethanol, excess ethanol supplies in the United States will continue which could continue to negatively impact prices. Any decrease in ethanol prices or demand may negatively impact our ability to profitably operate the ethanol plant.
Consumer resistance to the use of ethanol based on the belief that ethanol is expensive, adds to air pollution, harms engines and/or takes more energy to produce than it contributes or based on perceived issues related to the use of corn as the feedstock to produce ethanol may affect demand for ethanol. Certain individuals believe that the use of ethanol will have a negative impact on gasoline prices at the pump. Some also believe that ethanol adds to air pollution and harms car and truck engines. Still other consumers believe that the process of producing ethanol actually uses more fossil energy, such as oil and natural gas, than the amount of energy that is produced. Further, some consumers object to the fact that ethanol is produced using corn as the feedstock which these consumers perceive as negatively impacting food prices. These consumer beliefs could potentially be wide-spread and may be increasing as a result of recent efforts to increase the allowable percentage of ethanol that may be blended for use in vehicles. If consumers choose not to buy ethanol based on these beliefs, it would affect the demand for the ethanol we produce which could negatively affect our profitability and financial condition.
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.
15
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.
Many ethanol producers are expanding their production capacity which could lead to an oversupply of ethanol in the United States. Recently, many ethanol producers have commenced projects to expand their ethanol production capacities. These expansions could result in a significant increase in the supply of ethanol in the United States. Currently, ethanol prices are supported by ethanol exports which may not continue at their current levels. While many in the ethanol industry are working to increase the amount of ethanol that is used domestically, specifically in the form of E15, which contains 15% ethanol as compared to the 10% ethanol which is used in most current blends, adoption of E15 has not been as rapid as most ethanol producers would like. Also, the additional ethanol capacity which is being constructed may exceed current domestic and export demand. If an oversupply of ethanol were to occur, it could negatively impact domestic ethanol prices which could negatively impact our ability to profitably operate the ethanol plant.
Risks Related to Regulation and Governmental Action
Government incentives for ethanol production may be reduced or eliminated in the future, which could hinder our ability to operate at a profit. The ethanol industry is assisted by various federal and state ethanol incentives, the most important of which is the RFS set forth in the Energy Policy Act of 2005. The RFS helps support a market for ethanol that might disappear without this incentive. The EPA has the authority to waive the RFS statutory volume requirement, in whole or in part, provided certain conditions have been met. Annually, the EPA is supposed to pass a rule that establishes the number of gallons of different types of renewable fuels that must be used in the United States which is called the renewable volume obligations. In the past, the EPA has set the renewable volume obligations below the statutory volume requirements. On December 19, 2019, the EPA released its final rule and set the 2020 total volume obligation at 20.09 billion gallons of which 15.0 billion gallons could be met by corn-based ethanol. If the EPA were to significantly reduce the volume requirements under the RFS or if the RFS were to be otherwise reduced or eliminated by the exercise of the EPA waiver authority or by Congress in the future, the market price and demand for ethanol could decrease which will negatively impact our financial performance.
The EPA issued small refinery exemption waivers to the RFS requirement which has resulted in demand destruction and negatively impacted profitability in the ethanol industry. During 2019, the ethanol industry learned that the EPA has been issuing small refinery waivers to the ethanol use requirements in the RFS. In previous years, when the EPA issued small refinery exemption waivers, the EPA reallocated the waived gallons to other refiners. The EPA under the Trump Administration was granting significantly more waivers than in the past and was not reallocating the waived gallons to other refiners. These actions have resulted in demand destruction in 2018 and 2019 which led to reduced market ethanol prices and negative operating margins in the ethanol industry. This reduction in ethanol demand has negatively impacted the profitability of our operations. We believe that these small refinery exemptions will continue to be granted by the EPA and that it will continue to negatively impact profitability in the ethanol industry which could reduce or eliminate the value of our units despite efforts to include reallocated gallons.
Government policies and regulations, particularly those affecting the agricultural sector and related industries, could adversely affect our operations and profitability. Agricultural commodity production and trade flows are significantly affected by government policies and regulations. Governmental policies affecting the agricultural industry, such as taxes, trade tariffs, duties, subsidies, import and export restrictions on commodities and commodity products, can influence industry profitability, the planting of certain crops, the location and size of crop production, whether unprocessed or processed commodity products are traded, and the volume and types of imports and exports. In addition, international trade disputes can adversely affect trade flows by limiting or disrupting trade between countries or regions. Future governmental policies, regulations or actions affecting our industry may adversely affect the supply of, demand for and prices of our products, restrict our ability to do business and cause our financial results to suffer. We may experience negative impacts of higher ethanol tariffs and other disruptions to international agricultural trade related to current trade actions announced by the Trump administration and responsive actions announced by trading partners, including by China. The Chinese government increased the tariff on U.S. ethanol imports into China to 70%. We cannot estimate the exact effect this tariff increase will have on the overall domestic ethanol market. However, the increased tariff is expected to reduce overall U.S. ethanol export demand, which could have a negative effect on U.S. domestic ethanol prices.
The California Low Carbon Fuel Standard may decrease demand for corn-based ethanol which could negatively impact our profitability. California passed a Low Carbon Fuels Standard ("LCFS") which requires that renewable fuels used in California must accomplish certain reductions in greenhouse gases which reductions are measured using a lifecycle analysis. Management believes that these regulations could preclude corn-based ethanol produced in the Midwest from being used in California. California represents a significant ethanol demand market. If the ethanol industry is unable to supply corn-based ethanol
16
to California, it could significantly reduce demand for the ethanol we produce. This could result in a reduction of our revenues and negatively impact our ability to profitably operate the ethanol plant.
Changes in environmental regulations or violations of these regulations could be expensive and reduce our profitability. We are subject to extensive air, water and other environmental laws and regulations. In addition, some of these laws require our plant to operate under a number of environmental permits. These laws, regulations and permits can often require expensive pollution control equipment or operational changes to limit actual or potential impacts to the environment. A violation of these laws and regulations or permit conditions can result in substantial fines, damages, criminal sanctions, permit revocations and/or plant shutdowns. In the future, we may be subject to legal actions brought by environmental advocacy groups and other parties for actual or alleged violations of environmental laws or our permits. Additionally, any changes in environmental laws and regulations, both at the federal and state level, could require us to spend considerable resources in order to comply with future environmental regulations. The expense of compliance could be significant enough to reduce our profitability and negatively affect our financial condition.
Carbon dioxide may be regulated in the future by the EPA as an air pollutant requiring us to obtain additional permits and install additional environmental mitigation equipment, which could adversely affect our financial performance. In 2007, the Supreme Court decided a case in which it ruled that carbon dioxide is an air pollutant under the Clean Air Act for motor vehicle emissions. Our plant produces a significant amount of carbon dioxide. While there are currently no regulations restricting carbon dioxide emissions, if the EPA or the State of Iowa were to regulate carbon dioxide emissions by plants such as ours, we may have to apply for additional permits or we may be required to install carbon dioxide mitigation equipment or take other as yet unknown steps to comply with these potential regulations. Compliance with any future regulation of carbon dioxide, if it occurs, could be costly and may prevent us from operating the ethanol plant profitably which could decrease or eliminate the value of our units.
ITEM 2. PROPERTIES.
Our plant is located on an approximately 350 acre site in Chickasaw County, Iowa. The plant's address is 2779 Highway 24, Lawler, Iowa 52154. Construction of our plant was completed in April 2009. All of our operations are located at this site.
We selected our plant site because of its close proximity to rail service and access to natural gas supplies capable of meeting plant consumption needs. The plant is located on Iowa Highway 24, which runs east/west, and is about 10 miles east of Iowa Highway 63, which runs north/south, and about 40 miles north of Iowa Highway 20, which runs east/west. Our proximity to these highways provides us with easy access to Interstate 35 and Interstate 80. In addition, the plant is located on the Canadian Pacific railroad line which provides us access to many markets for our products.
All of our tangible and intangible property, real and personal, serves as the collateral for our debt financing with Home Federal, which is described below under "Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations - Short-Term and Long-Term Debt Sources."
ITEM 3. LEGAL PROCEEDINGS.
Retterath Lawsuit
On August 14, 2013, the Company filed a lawsuit against Steve Retterath in the Iowa state court located in Polk County, Iowa. The purpose of the lawsuit is to enforce the terms of the repurchase agreement the Company executed with Mr. Retterath on June 13, 2013. The Company asked the Iowa state court to require Mr. Retterath to perform his obligations under the repurchase agreement pursuant to its terms. Mr. Retterath removed the case to federal court in the Federal District Court for the Southern District of Iowa in December 2013. The Company believed that this removal was improper and as a result the Company moved to remand the case back to the Iowa state court in Polk County which was granted. Mr. Retterath answered the lawsuit in August 2014, denying the validity of the repurchase agreement. In addition, the Iowa state court permitted Jason Retterath and Annie Retterath, the son and daughter-in-law of Steve Retterath, to be added as parties to the Iowa state lawsuit. In February 2015, the Company filed a motion for summary judgment asking the Iowa state court to enforce the repurchase agreement. The Retteraths also filed motions for summary judgment asking the Iowa state court to find the repurchase agreement invalid. On October 16, 2015, the Iowa state court entered a ruling granting Homeland's motion for summary judgment and determined no membership vote was required as Mr. Retterath has contended. The Iowa state court also denied the summary judgment motions filed by Mr. Retterath and his son and daughter-in-law.
Mr. Retterath and his son and daughter-in-law filed a motion to add a significant number of additional parties to the Iowa lawsuit along with additional claims against the Company. We filed a resistance to Mr. Retterath's attempts to expand the scope of the Iowa lawsuit. In November 2016, the Iowa Court ruled that our original claims against Mr. Retterath would proceed to trial
17
in January 2017 as scheduled and that any other issues that remain following that trial would be litigated after a ruling is issued in the January 2017 trial. The trial was held in January 2017. On June 15, 2017, the Iowa Court ruled in favor of Homeland that the repurchase agreement was valid and directed Mr. Retterath to perform his obligations under the repurchase agreement by August 1, 2017. Mr. Retterath subsequently filed motions with the Iowa Court to reconsider its ruling or alternatively award Mr. Retterath a new trial. Mr. Retterath also asked the Iowa Court to stay his obligation to perform the repurchase agreement until these motion are ruled on by the Iowa Court. The Iowa Court granted Mr. Retterath's stay while the court considered his post-trial motions. On May 7, 2018, the Iowa Court denied Mr. Retterath's motions for a new trial and to reconsider the Iowa Court's prior ruling. Mr. Retterath filed an appeal of the Iowa Court's decision. In February 2020, the Iowa Supreme Court ruled that the repurchase agreement is valid and enforceable.
GS Cleantech Patent Litigation
On August 9, 2013, GS Cleantech Corporation ("GS Cleantech"), a subsidiary of Greenshift Corporation, filed a complaint in the United States District for the Northern District of Iowa against the Company. The Company is one of more than twenty ethanol manufacturers that were sued by GS Cleantech. The complaint alleges that the Company's operation of a corn oil extraction process infringes patent rights claimed by GS Cleantech. GS Cleantech seeks royalties, damages and potentially triple damages associated with the alleged infringement, as well as attorney's fees. The complaint was transferred to the United States District Court for the Southern District of Indiana due to a finding that the action involves questions of fact common to several other lawsuits which were joined in a multi-district litigation ("MDL"). The MDL Court developed two tracks of defendants in this litigation. The first track includes defendants which were originally sued by GS Cleantech in 2010 and a second track of defendants sued in 2013 which includes the Company. On October 23, 2014, the MDL Court granted summary judgment in favor of the first track defendants and found that the GS Cleantech patents which the Company is alleged to have infringed are invalid. Further, in a January 16, 2015 decision, the MDL ruled in favor of a stipulated motion for partial summary judgment finding that all of the GS Cleantech patents in the suit were invalid and, therefore, not infringed. GS Cleantech appealed these decisions. The federal appeals court recently rejected GS Cleantech's appeal.
ITEM 4. MINE SAFETY DISCLOSURES
None.
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES.
Outstanding Equity
As of March 6, 2020, we had 90,420 units outstanding and approximately 1,278 total members. On June 13, 2013, the Company entered into an agreement with Steve Retterath, the Company's largest equity holder, to repurchase and retire all of the units owned by Mr. Retterath. The Company agreed to repurchase and retire 25,860 membership units owned by Mr. Retterath in exchange for $30 million. Following the end of our 2019 fiscal year, in February 2020, the Iowa Supreme Court ruled that the repurchase agreement is valid and enforceable. The 90,420 membership units outstanding include the contested membership units the Company agreed to repurchase from Mr. Retterath.
Unit Trading
There is no established public trading market for our units. However, on February 5, 2008, we established the Unit Trading Bulletin Board, which is a private online matching service, in order to facilitate trading among our members. The Unit Trading Bulletin Board consists of an electronic bulletin board on our website that provides a list of interested buyers and a list of interested sellers, along with their non-firm price quotes. The Unit Trading Bulletin Board does not automatically effect matches between potential sellers and buyers and it is the sole responsibility of sellers and buyers to contact each other to negotiate an agreement to transfer units. We do not become involved in any purchase or sale negotiations arising from our Unit Trading Bulletin Board and have no role in effecting transactions beyond approval, as required under our operating agreement, and the issuance of new certificates. We do not give advice regarding the merits or shortcomings of any particular transaction. We do not receive, transfer or hold funds or securities as an incident of operating the Unit Trading Bulletin Board. We do not receive any compensation for creating or maintaining the Unit Trading Bulletin Board. In advertising our Unit Trading Bulletin Board, we do not characterize Homeland Energy Solutions as being a broker or dealer or an exchange. We do not use the Unit Trading Bulletin Board to offer to buy or sell securities other than in compliance with the securities laws, including any applicable registration requirements.
18
There are detailed time lines that must be followed under the Unit Trading Bulletin Board rules and procedures with respect to offers and sales of membership units, with which all transactions must comply. In addition, all transactions must comply with our operating agreement, and are subject to approval by our board of directors.
The following table contains historical information by quarter for the past two years regarding the actual unit transactions that were completed by our unit-holders during the periods specified. Some of these transfers were made without consideration and as such no price information is included. We believe this most accurately represents the current trading value of our units. The information was compiled by reviewing the completed unit transfers that occurred on the Unit Trading Bulletin Board or through private transfers during the quarters indicated.
Quarter | Low Price | High Price | Average Price | Number of Units Traded | ||||||||||
First Quarter 2018 | $ | 2,400 | $ | 2,800 | $ | 2,764 | 55 | |||||||
Second Quarter 2018 | $ | 2,500 | $ | 2,700 | $ | 2,671 | 97 | |||||||
Third Quarter 2018 | $ | 2,500 | $ | 2,950 | $ | 2,676 | 78 | |||||||
Fourth Quarter 2018 | $ | 3,000 | $ | 3,000 | $ | 3,000 | 25 | |||||||
First Quarter 2019 | $ | 2,750 | $ | 3,000 | $ | 3,000 | 10 | |||||||
Second Quarter 2019 | $ | 2,750 | $ | 2,800 | $ | 2,773 | 54 | |||||||
Third Quarter 2019 | $ | 2,500 | $ | 2,800 | $ | 2,571 | 35 | |||||||
Fourth Quarter 2019 | $ | — | $ | — | $ | — | — | |||||||
The following tables contain the bid and asked prices that were posted on the Unit Trading Bulletin Board and includes some transactions that were not completed. We believe the table above more accurately describes the trading value of our units as the bid and asked prices below include some offers that never resulted in completed transactions. The information was compiled by reviewing postings that were made on the Unit Trading Bulletin Board.
Sellers' Quarter | Low Price | High Price | Average Price | Number of Units Listed | ||||||||||
First Quarter 2018 | $ | — | $ | — | $ | — | — | |||||||
Second Quarter 2018 | $ | — | $ | — | $ | — | — | |||||||
Third Quarter 2018 | $ | 3,200 | $ | 3,200 | $ | 3,200 | 25 | |||||||
Fourth Quarter 2018 | $ | 3,000 | $ | 3,000 | $ | 3,000 | 35 | |||||||
First Quarter 2019 | $ | 2,750 | $ | 3,000 | $ | 2,857 | 70 | |||||||
Second Quarter 2019 | $ | 2,750 | $ | 2,850 | $ | 2,783 | 30 | |||||||
Third Quarter 2019 | $ | 2,650 | $ | 2,750 | $ | 2,716 | 107 | |||||||
Fourth Quarter 2019 | $ | — | $ | — | $ | — | — | |||||||
Buyers' Quarter | Low Price | High Price | Average Price | Number of Units Listed | ||||||||||
First Quarter 2018 | $ | 2,450 | $ | 2,500 | $ | 2,480 | 50 | |||||||
Second Quarter 2018 | $ | 2,500 | $ | 2,500 | $ | 2,500 | 30 | |||||||
Third Quarter 2018 | $ | 2,500 | $ | 2,600 | $ | 2,527 | 55 | |||||||
Fourth Quarter 2018 | $ | 2,750 | $ | 2,900 | $ | 2,806 | 40 | |||||||
First Quarter 2019 | $ | — | $ | — | $ | — | — | |||||||
Second Quarter 2019 | $ | 2,000 | $ | 2,000 | $ | 2,000 | 50 | |||||||
Third Quarter 2019 | $ | — | $ | — | $ | — | — | |||||||
Fourth Quarter 2019 | $ | 2,200 | $ | 2,200 | $ | 2,200 | 10 | |||||||
As a limited liability company, we are required to restrict the transfers of our membership units in order to preserve our partnership tax status. Our membership units may not be traded on any established securities market or readily traded on a secondary market (or the substantial equivalent thereof). All transfers are subject to a determination that the transfer will not cause us to be deemed a publicly traded partnership.
19
Distributions
Our board of directors has discretion over the timing and amount of distributions to our unit holders subject to certain financial covenants required by our senior credit facility and restrictions under Iowa law. Our expectations with respect to our ability to make future distributions are discussed in greater detail in "Item 7 - Management's Discussion And Analysis Of Financial Condition And Results Of Operations."
Performance Graph
The following graph shows a comparison of cumulative total member return since December 31, 2014, calculated on a dividend reinvested basis, for the Company, the NASDAQ Composite Index (the "NASDAQ Market Index") and an index of other companies that have the same SIC code as the Company (the "SIC Code Index"). The graph assumes $100 was invested in each of our units, the NASDAQ Market Index, and the SIC Code Index on December 31, 2014. Data points on the graph are quarterly. Note that historic unit price performance is not necessarily indicative of future unit price performance. The data for this performance graph was compiled for us by Zacks Investment Research, Inc.
Pursuant to the rules and regulations of the Securities and Exchange Commission, the performance graph and the information set forth therein shall not be deemed to be filed for purposes of Section 18 of the Securities Exchange Act of 1934, and shall not be deemed to be incorporated by reference in any filing under the Securities Act of 1933, as amended, or the Exchange Act, except as shall be expressly set forth by specific reference in such a filing.
20
ITEM 6. SELECTED FINANCIAL DATA
The following table presents selected financial and operating data as of the dates and for the periods indicated. The selected balance sheet financial data as of December 31, 2017, 2016 and 2015 and the selected income statement data and other financial data for the years ended December 31, 2016 and 2015 have been derived from our audited financial statements that are not included in this Form 10-K. The selected balance sheet financial data as of December 31, 2019 and 2018 and the selected income statement data and other financial data for each of the years in the three year period ended December 31, 2019 have been derived from the audited financial statements included elsewhere in this Form 10-K. You should read the following table in conjunction with "Item 7. Management Discussion and Analysis of Financial Condition and Results of Operations" and the financial statements and the accompanying notes included elsewhere in this Form 10-K. Among other things, those financial statements include more detailed information regarding the basis of presentation for the following financial data.
2019 | 2018 | 2017 | 2016 | 2015 | ||||||||||||||||
Total Revenue | $ | 329,774,685 | $ | 307,400,097 | $ | 256,525,281 | $ | 272,938,079 | $ | 269,970,953 | ||||||||||
Net Income | 19,476,753 | 19,766,205 | 16,832,350 | 34,484,463 | 24,511,283 | |||||||||||||||
Net Income Per Unit | 301.68 | 306.09 | 260.62 | 533.94 | 379.52 | |||||||||||||||
Distributions Declared Per Unit | 350.00 | 220.00 | 255.00 | 499.00 | 362.00 | |||||||||||||||
Total Assets | 222,959,992 | 225,593,652 | 225,298,068 | 198,784,899 | 186,992,229 | |||||||||||||||
Long-term Liabilities | 15,081,767 | 17,950,754 | 23,936,683 | 123,190 | 350,059 | |||||||||||||||
Members' Equity | 153,975,555 | 157,094,802 | 151,600,547 | 151,237,372 | 148,980,824 | |||||||||||||||
21
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Results of Operations
Comparison of Fiscal Years Ended December 31, 2019 and 2018
2019 | 2018 | |||||||||||||
Income Statement Data | Amount | % | Amount | % | ||||||||||
Revenue | $ | 329,774,685 | 100.0 | $ | 307,400,097 | 100.0 | ||||||||
Cost of goods sold | 307,650,836 | 93.3 | 283,549,201 | 92.2 | ||||||||||
Gross profit | 22,123,849 | 6.7 | 23,850,896 | 7.8 | ||||||||||
Selling, general and administrative expenses | 3,885,532 | 1.2 | 3,658,156 | 1.2 | ||||||||||
Operating income | 18,238,317 | 5.5 | 20,192,740 | 6.6 | ||||||||||
Other income (expense) | 1,238,436 | 0.4 | (426,535 | ) | (0.1 | ) | ||||||||
Net income | $ | 19,476,753 | 5.9 | $ | 19,766,205 | 6.4 | ||||||||
Revenue
Our total revenue for our 2019 fiscal year was approximately 7% greater than our total revenue for our 2018 fiscal year. Management attributes this increase in revenue primarily with increased total production at the ethanol plant which resulted in increased sales during our 2019 fiscal year, partially offset by decreased average distiller grains prices. Our revenue is presented in our financial statements net of the shipping costs that are incurred in transporting our products to the end customer. These shipping charges are deducted by our marketers from the amounts realized on the sale of our ethanol, distiller grains and corn oil.
For our 2019 fiscal year, our total ethanol revenue increased by approximately 10% compared to our 2018 fiscal year due to increased production due to increased efficiency operating our expanded ethanol plant along with a slight increase in the average price we received for the ethanol we sold during our 2019 fiscal year. The gallons of ethanol we sold during our 2019 fiscal year increased by approximately 5% compared to our 2018 fiscal year. This increase in ethanol sales resulted from increased ethanol production at the ethanol plant. The average price we received for our ethanol during our 2019 fiscal year was approximately 4% greater than during our 2018 fiscal year. Management attributes this increase in ethanol prices to increased corn prices along with a decreased market supply of ethanol due to unfavorable operating conditions in the ethanol industry which resulted in some ethanol producers decreasing production or ceasing operation altogether. Ethanol demand was significantly impacted by EPA's small refinery exemption waivers from the ethanol blending requirements in the Renewable Fuels Standard. Management anticipates continued lower ethanol prices during our 2020 fiscal year as we expect that domestic ethanol demand will continue to be impacted by EPA's small refinery exemptions, however, we expect them to be less than in prior years. In addition, trade disputes, particularly with China, may continue to negatively impact export demand for ethanol which may result in continued oversupply in the market and unfavorable operating margins. While we believe that we are an efficient producer of ethanol which may allow us to operate at times when our competition must shut down, we expect that poor market conditions will continue to impact our profitability.
Our total distiller grains revenue was approximately 4% less during our 2019 fiscal year compared to the same period of 2018 primarily due to decreased average distiller grains prices, partially offset by increased distiller grains production during our 2019 fiscal year. We sold approximately 3% more tons of distiller grains during our 2019 fiscal year compared to the same period of 2018 due to our increased overall production. The average prices we received for our distiller grains was less during our 2019 fiscal year compared to the same period of 2018 due primarily to decreased distiller grains demand. We primarily sell our distiller grains in the dried form based on market conditions which favor this product, however we still sell a small portion of our distillers grains in the modified form. The average price we received per ton of dried distiller grains sold decreased by approximately 6% during our 2019 fiscal year compared to the same period of 2018. The average price we received per ton of modified distiller grains sold decreased by approximately 31% during our 2019 fiscal year compared to the same period of 2018. Since distiller grains are primarily used as an animal feed substitute for corn and soybean meal, the price of distiller grains is impacted by these competing products. Management anticipates relatively stable distiller grains prices during our 2020 fiscal year unless corn and soybean production is lower or export demand for these products increases, especially if export issues between China and the
22
United States are resolved. If China reenters the market for United States agricultural products, it could quickly result in higher corn, soybean and distiller grains prices.
Our revenue from corn oil sales was approximately 12% greater during our 2019 fiscal year compared to the same period of 2018, due to increased corn oil production and prices for the corn oil we sold during our 2019 fiscal year. The average price we received for our corn oil during our 2019 fiscal year was approximately 4% greater than the average price we received during the same period of 2018. Management attributes this increase in corn oil prices with decreased corn oil supply during 2019. Recently the biodiesel blenders' tax credit was renewed for prior years and until December 31, 2022. Management expects that added certainty in the biodiesel blenders' credit will result in higher corn oil prices.
We sold approximately 7% more pounds of corn oil during our 2019 fiscal year compared to the same period of 2018. Management attributes this increase in corn oil sales with increased production by the ethanol plant, generally. Management expects corn oil production to be comparable during our 2020 fiscal year compared to our 2019 fiscal year.
Cost of Goods Sold
Our two primary costs of producing ethanol, distiller grains and corn oil are corn costs and natural gas costs. Our total cost of goods sold was higher during our 2019 fiscal year compared to our 2018 fiscal year due to increased consumption of corn and natural gas, along with higher average corn costs per bushel during our 2019 fiscal year compared to our 2018 fiscal year.
The average price we paid per bushel of corn was approximately 5% greater during our 2019 fiscal year compared to our 2018 fiscal year. Management attributes this increase in the average price we paid per bushel of corn with late planting and a late harvest in 2019 which led to uncertainty about the size and quality of the 2019 corn crop. In addition, the amount of corn harvested in the fall of 2019 was less than in previous years which impacted corn prices later in the year. Management anticipates that corn prices will remain at current levels during our 2020 fiscal year, unless Chinese export demand increases significantly which could result in higher corn prices and demand. During our 2019 fiscal year we have realized and unrealized gains on our corn and natural gas risk management positions of approximately $4.5 million, which decreased our cost of goods sold during our 2019 fiscal year. During our 2018 fiscal year, we experienced a combined realized and unrealized gain on our risk management positions of approximately $2.9 million which reduced our cost of goods sold during our 2018 fiscal year.
We purchased approximately 7% more bushels of corn during our 2019 fiscal year compared to our 2018 fiscal year. Management attributes this increase in corn consumption with increased production during our 2019 fiscal year due to improved operation of the ethanol plant during our 2019 fiscal year. Management anticipates that our corn consumption will be comparable during our 2020 fiscal year compared to our 2019 fiscal year because we currently anticipate comparable production during the 2020 fiscal year.
During our 2019 fiscal year, the average price we paid per MMBtu of natural gas was approximately 9% less compared to our 2018 fiscal year. Management attributes this decrease in natural gas prices to lower market prices of natural gas due additional natural gas supply in the market. In addition, we entered into natural gas price lock agreements for most of 2019 which helped avoid natural gas price spikes. Management expects relatively stable natural gas prices during our 2020 fiscal year because we anticipate securing price lock agreements for a percentage of our 2020 anticipated usage. We consumed approximately 5% more natural gas during our 2019 fiscal year compared to the same period of 2018, primarily due to increased production at the ethanol plant along with our steam turbine which converts steam to electricity. We expect our natural gas consumption to be comparable during our 2020 fiscal year as we anticipate comparable production at the ethanol plant during our 2020 fiscal year.
Selling, General and Administrative Expenses
Our selling, general and administrative expenses were greater during our 2019 fiscal year compared to our 2018 fiscal year due primarily to increased insurance expense, increased property taxes and additional employee related expenses partially offset by lower business promotion and legal expenses.
Other Income (Expense)
We had less interest expense during our 2019 fiscal year compared to our 2018 fiscal year due to decreasing principal amounts outstanding on our loans as scheduled principal payments are paid. We had more interest income during our 2019 fiscal year compared to the same period of 2018 due to having more cash on hand during the 2019 period. We had more other income during our 2019 fiscal year compared to the same period of 2018 primarily due to having more net earnings on trading securities.
23
Comparison of Fiscal Years Ended December 31, 2018 and 2017
2018 | 2017 | |||||||||||||
Income Statement Data | Amount | % | Amount | % | ||||||||||
Revenue | $ | 307,400,097 | 100.0 | $ | 256,525,281 | 100.0 | ||||||||
Cost of goods sold | 283,549,201 | 92.2 | 236,834,163 | 92.3 | ||||||||||
Gross profit | 23,850,896 | 7.8 | 19,691,118 | 7.7 | ||||||||||
Selling, general and administrative expenses | 3,658,156 | 1.2 | 3,525,736 | 1.4 | ||||||||||
Operating income | 20,192,740 | 6.6 | 16,165,382 | 6.3 | ||||||||||
Other income (expense) | (426,535 | ) | (0.1 | ) | 666,968 | 0.3 | ||||||||
Net income | $ | 19,766,205 | 6.4 | $ | 16,832,350 | 6.6 | ||||||||
Revenue
Our total revenue for our 2018 fiscal year was approximately 20% more than our total revenue for our 2017 fiscal year. Management attributes this increase in revenue primarily with increased total production at the ethanol plant which resulted in increased sales during our 2018 fiscal year, partially offset by decreased ethanol and corn oil prices. Our revenue is presented in our financial statements net of the shipping costs that are incurred in transporting our products to the end customer. These shipping charges are deducted by our marketers from the amounts realized on the sale of our ethanol, distiller grains and corn oil.
For our 2018 fiscal year, our total ethanol revenue increased by approximately 13% compared to our 2017 fiscal year due to increased production due to our plant expansion, partially offset by lower average ethanol sales prices during our 2018 fiscal year. The average price we received for our ethanol during our 2018 fiscal year was approximately 5% less than during our 2017 fiscal year. Management attributes this decrease in ethanol prices to an increase in the market supply of ethanol due to plant expansions in the ethanol industry which became operational during 2018 along with significantly lower domestic demand for ethanol due to the EPA's small refinery exemptions from the ethanol blending requirements in the Renewable Fuels Standard. Management believes that these small refinery exemptions removed more than 2 billion gallons of domestic ethanol demand during our 2018 fiscal year. While export demand was strong during 2018, the loss of this domestic ethanol demand was larger than increased demand from export markets.
We sold 19% more gallons of ethanol during our 2018 fiscal year compared to the same period of 2017. Management attributes this increase in ethanol sales resulted from increased ethanol production at the ethanol plant due to our plant expansion
project which became operational in the last month of our 2017 fiscal year.
Our total distiller grains revenue was approximately 68% greater during our 2018 fiscal year compared to the same period of 2017 primarily due to increased distiller grains production due to our plant expansion project along with higher average sales prices for our distiller grains during our 2018 fiscal year. We sold approximately 20% more tons of distiller grains during our 2018 fiscal year compared to the same period of 2017 due to our increased overall production. The average prices we received for our distiller grains was also higher during our 2018 fiscal year compared to the same period of 2017 due primarily to increased domestic and export demand for distiller grains along with higher market corn and soybean prices which typically impact prices of distiller grains. We primarily sell our distiller grains in the dried form based on market conditions which favor this product, however we still sell a small portion of our distillers grains in the modified form. The average price we received per ton of dried distiller grains sold increased by approximately 40% during our 2018 fiscal year compared to the same period of 2017. The average price we received per ton of modified distiller grains sold increased by approximately 50% during our 2018 fiscal year compared to the same period of 2017. Since distiller grains are primarily used as an animal feed substitute for corn and soybean meal, the price of distiller grains is impacted by these competing products.
Our revenue from corn oil sales was approximately 5% less during our 2018 fiscal year compared to the same period of 2017, due to lower market corn oil prices partially offset by an increase in the total pounds of corn oil we sold during our 2018 fiscal year. The average price we received for our corn oil during our 2018 fiscal year was approximately 13% less than the average price we received during the same period of 2017. Management attributes this decrease in corn oil prices with decreased corn oil demand from the biodiesel industry during 2018.
24
We sold approximately 8% more pounds of corn oil during our 2018 fiscal year compared to the same period of 2017. Management attributes this increase in corn oil sales with increased production by the ethanol plant, generally. However, we experienced production issues with our corn oil extraction equipment during our 2018 fiscal year so the increase in overall production at the ethanol plant due to our plant expansion project was greater than the increase we experienced in our corn oil production.
Cost of Goods Sold
Our two primary costs of producing ethanol, distiller grains and corn oil are corn costs and natural gas costs. Our total cost of goods sold were higher during our 2018 fiscal year compared to our 2017 fiscal year due to our plant expansion project which required us to use significantly more raw materials during our 2018 fiscal year. In addition, our average cost per bushel of corn was higher during our 2018 fiscal year compared to our 2017 fiscal year, which resulted in increased cost of goods sold.
The average price we paid per bushel of corn was approximately 4% greater during our 2018 fiscal year compared to our 2017 fiscal year. Management attributes this increase in the average price we paid per bushel of corn with increased demand for corn due to our expansion project along with weather conditions during our 2018 fiscal year which impacted local prices for corn during our 2018 fiscal year. In addition to the higher corn prices, our cost of goods sold was higher during our 2018 fiscal year due primarily to increased production during 2018 fiscal year as well as less realized and unrealized gains on our corn risk management positions as compared to 2017. During our 2017 fiscal year, we experienced a combined realized and unrealized gain on our risk management positions of approximately $3.8 million which reduced our cost of goods sold during our 2017 fiscal year as compared to $2.9 million realized and unrealized gains during our 2018 fiscal year.
We purchased approximately 15% more bushels of corn during our 2018 fiscal year compared to our 2017 fiscal year. Management attributes this increase in corn consumption with increased production during our 2018 fiscal year due to our plant expansion project.
During our 2018 fiscal year, the average price we paid per MMBtu of natural gas was approximately 13% less compared to our 2017 fiscal year. Management attributes this decrease in natural gas prices to unusually high natural gas prices during the end of our 2017 fiscal year which resulted in higher averages prices. This spike in natural gas prices did not occur during our 2018 fiscal year which resulted in lower average natural gas prices during our 2018 fiscal year. In addition, we entered into natural gas price lock agreements for most of 2018 which helped avoid natural gas price spikes. We consumed approximately 18% more natural gas during our 2018 fiscal year compared to the same period of 2017, primarily due to increased production at the ethanol plant along with our steam turbine which converts steam to electricity.
Selling, General and Administrative Expenses
Our selling, general and administrative expenses were greater during our 2018 fiscal year compared to our 2017 fiscal year due primarily to increased accounting fees related to a cost segregation study, research and development analysis and a sales tax study as well as increased employee bonuses that are partially calculated on net income.
Other Income (Expense)
We had more interest expense during our 2018 fiscal year compared to our 2017 fiscal year due to having borrowing related to our plant expansion project for all of the 2018 fiscal year as compared to only a portion of 2017. We had less interest income during our 2018 fiscal year compared to the same period of 2017 due to having less cash on hand during the 2018 period. We had less other income during our 2018 fiscal year compared to the same period of 2017 primarily due to having less net earnings on trading securities along with decreased investment income from our investment in RPMG, our ethanol and corn oil marketer.
25
Changes in Financial Condition for the Fiscal Years Ended December 31, 2019 and 2018
Balance Sheet Data | December 31, 2019 | December 31, 2018 | ||||||
Total current assets | $ | 87,173,152 | $ | 85,563,079 | ||||
Total property and equipment | 126,554,986 | 135,195,924 | ||||||
Total other assets | 9,231,854 | 4,834,649 | ||||||
Total Assets | $ | 222,959,992 | $ | 225,593,652 | ||||
Total current liabilities | $ | 53,902,670 | $ | 50,548,096 | ||||
Total long-term liabilities | 15,081,767 | 17,950,754 | ||||||
Total members' equity | 153,975,555 | 157,094,802 | ||||||
Total Liabilities and Members' Equity | $ | 222,959,992 | $ | 225,593,652 | ||||
We had less cash on hand at December 31, 2019 compared to December 31, 2018 due to cash we were holding in our trading securities account. We had approximately $42.5 million in marketable trading securities at December 31, 2019 compared to approximately $30.6 million at December 31, 2018. A portion of our marketable trading securities during each period is being held to complete the Retterath unit repurchase. The value of our accounts receivable was less at December 31, 2019 compared to December 31, 2018 due to the timing of our product shipments compared to the end of our fiscal year as we were awaiting payment for less of our finished products at the end of our 2019 fiscal year compared to the end of our 2018 fiscal year. The value of our inventory was higher at December 31, 2019 compared to December 31, 2018 due primarily to increased corn inventory at December 31, 2019 compared to December 31, 2018 partially offset by decreased finished goods inventory at the end of our 2019 fiscal year. We had more prepaid and other assets at December 31, 2019 compared to December 31, 2018 due to increases in spare parts held on hand and an increase in prepaid insurance.
The value of our plant equipment and buildings was less at December 31, 2019 compared to December 31, 2018 primarily due to regular depreciation of our assets, partially offset by capital projects which were completed or in progress during our 2019 fiscal year. We had approximately $723,0000 in construction in progress at December 31, 2019 primarily related to capital projects involving heat recovery.
Our other assets were higher because of the right of use asset related to the new lease pronouncement which requires leases be recognized on the balance sheet. This increase was partially offset by a decrease in undistributed income from our investment in RPMG, LLC, an affiliate of our ethanol and corn oil marketer. In addition, we continue to amortize certain utility rights associated with construction of the ethanol plant.
Current liabilities increased due to increased accounts payables at December 31, 2019 compared to December 31, 2018 and the addition of the current portion of operating lease liability in 2019. We had a $30 million liability as of December 31, 2019 and 2018 related to the membership unit repurchase agreement. Our accrued expenses, primarily related to year-end bonus accruals, were comparable at December 31, 2019 and December 31, 2018.
We had less long-term liabilities at December 31, 2019 compared to December 31, 2018 due to payments we made on the term debt we incurred related to our expansion project partially offset by the addition of operating lease liability in 2019.
Liquidity and Capital Resources
Our primary sources of liquidity are cash from our operations and our $30 million long-term revolving loan. Our credit facilities are described in greater detail below under "Short-Term and Long-Term Debt Sources." As of December 31, 2019, we had $30 million available pursuant to our revolving loan and approximately $17.3 million in cash. Based on financial forecasts performed by our management, we anticipate that we will have sufficient cash from our revolving loans and cash from our operations to continue to operate the ethanol plant at capacity for the next 12 months and beyond. We do not anticipate seeking additional equity or debt financing in the next 12 months to continue our operations. However, should we experience unfavorable operating conditions in the future, we may have to secure additional debt or equity financing for working capital or other purposes.
26
Comparison of Cash Flows for fiscal years ended December 31, 2019 and 2018.
The following table shows cash flows for the fiscal years ended December 31, 2019 and 2018:
2019 | 2018 | |||||||
Net cash provided by operating activities | $ | 35,290,146 | $ | 30,742,309 | ||||
Net cash (used in) investing activities | (18,171,437 | ) | (11,286,592 | ) | ||||
Net cash (used in) financing activities | (28,596,000 | ) | (20,271,950 | ) | ||||
Cash at beginning of period | 28,751,994 | 29,568,227 | ||||||
Cash at end of period | $ | 17,274,703 | $ | 28,751,994 | ||||
Cash Flow From Operations
Our operations generated more cash during our 2019 fiscal year compared to the same period of 2018 primarily due to changes in our accounts payable and accrued expenses during the 2019 fiscal year which resulted in additional cash during the 2019 period.
Cash Flow From Investing Activities
We used less cash for capital expenditures during our 2019 fiscal year compared to our 2018 fiscal year . Our primary capital projects during our 2019 fiscal year were a yeast propagation project, a stack heat recovery project and some other operating upgrades. We used more cash during our 2019 fiscal year compared to our 2018 fiscal year for purchases of trading securities.
Cash Flow From Financing Activities
We used more cash for distributions to our members during our 2019 fiscal year compared to our 2018 fiscal year.
Comparison of Cash Flows for fiscal years ended December 31, 2018 and 2017.
The following table shows cash flows for the fiscal years ended December 31, 2018 and 2017:
2018 | 2017 | |||||||
Net cash provided by operating activities | $ | 30,742,309 | $ | 31,611,491 | ||||
Net cash (used in) investing activities | (11,286,592 | ) | (29,672,565 | ) | ||||
Net cash provided by (used in) financing activities | (20,271,950 | ) | 13,460,658 | |||||
Cash at beginning of period | 29,568,227 | 14,168,643 | ||||||
Cash at end of period | $ | 28,751,994 | $ | 29,568,227 | ||||
Cash Flow From Operations
Our operations generated less cash during our 2018 fiscal year compared to the same period of 2017 primarily due to changes in our accounts receivable during the 2018 fiscal year partially offset by increased inventory and depreciation as well as net income.
Cash Flow From Investing Activities
We used less cash for capital expenditures during our 2018 fiscal year compared to our 2017 fiscal year due to less capital projects during our 2018 fiscal year. We were completing our plant expansion project during our 2017 fiscal year.
Cash Flow From Financing Activities
Our financing activities used cash during our 2018 fiscal year due to payments on our long-term debt and distributions to our members compared to our 2017 fiscal year when our financing activities provided cash due to $30 million in loan proceeds we received during our 2017 fiscal year offset by 2017 distributions to our members.
27
Short-Term and Long-Term Debt Sources
Master Loan Agreement with Home Federal Savings Bank
On November 30, 2007, we entered into a Master Loan Agreement with Home Federal Savings Bank ("Home Federal") establishing a senior credit facility with Home Federal. In return, we executed a mortgage and a security agreement in favor of Home Federal creating a senior lien on substantially all of our assets.
On June 29, 2017, we entered into a new $30 million term loan (the "Term Loan") and increased and extended our existing revolving loan (the "Revolving Loan") with Home Federal. Each loan is described below.
Term Loan
We have a $30 million term loan with a fixed interest rate of 4.79%. We will pay interest on the Term Loan monthly with semi-annual principal payments of $3 million commencing on June 30, 2018. The maturity date of the Term Loan is December 31, 2022. We have the ability to prepay principal on the Term Loan without penalty by giving Home Federal thirty days advance notice. If we choose to refinance the Term Loan within the first thirty-six months following the closing, we will be required to pay Home Federal a prepayment fee. In the event we default on the Term Loan, Home Federal can charge a default interest rate 2% in excess of the current interest rate. As of December 31, 2019, we had $18 million outstanding on the Term Loan.
Term Revolving Loan
We have a $30 million term revolving loan which has a maturity date of December 31, 2022. Interest on the Revolving Loan accrues at 310 basis points in excess of the 30-day London Interbank Offered Rate (LIBOR), 4.80% as of December 31, 2019. We are required to make monthly payments of interest until the maturity date on December 31, 2022, on which date the unpaid principal balance of the Revolving Loan becomes due. We agreed to pay a fee of 30 basis points on a per annum basis on the unused portion of the Revolving Loan payable on a quarterly basis. As of December 31, 2019, we had $0 outstanding on our term revolving loan and $30,000,000 available to be drawn.
Covenants
In connection with the Master Loan Agreement, we are required to comply with certain debt covenants and financial ratios. We agreed to a debt service coverage ratio of 1:15 to 1:00 and minimum working capital covenant of $30 million. We are permitted to pay distributions to our members up to 100% of our net income for the year in which the distributions are paid provided that immediately prior to the distribution and after giving effect to the distribution, no default exists and we are in compliance with all of our loan covenants including compliance with the financial covenants. Further, during 2018 our maximum capital expenditure covenant was increased from $10 million to $12 million for 2018 and $15 million per year going forward. As of December 31, 2019, we were in compliance with all of our debt covenants and financial ratios.
Management anticipates that we will be in compliance with all of our debt covenants and financial ratios for at least the next 12 months.
Should we default on any of our obligations pursuant to the Home Federal loan, Home Federal may terminate its commitment to provide us funds and declare the entire unpaid principal balance of the loan, plus accrued interest, immediately due and payable. Events of default include the failure to make payments when due, our insolvency, any material adverse change in our financial condition or the breach of any of the covenants, representations or warranties we have made in the loan agreements.
28
Contractual Cash Obligations
In addition to our long-term debt obligations, we have certain other contractual cash obligations and commitments. The following table provides information regarding our contractual obligations and approximate commitments as of December 31, 2019:
Payment Due By Period | ||||||||||||||||||||
Contractual Cash Obligations | Total | Less than One Year | One to Three Years | Three to Five Years | After Five Years | |||||||||||||||
Debt Obligations | $ | 18,000,000 | $ | 6,000,000 | $ | 12,000,000 | $ | — | $ | — | ||||||||||
Operating Lease Obligations | 5,049,000 | 1,752,000 | 2,798,000 | 409,000 | 90,000 | |||||||||||||||
Purchase Obligations | 27,438,000 | 27,438,000 | — | — | — | |||||||||||||||
Total Contractual Cash Obligations | $ | 50,487,000 | $ | 35,190,000 | $ | 14,798,000 | $ | 409,000 | $ | 90,000 | ||||||||||
Application of Critical Accounting Policies
Management uses estimates and assumptions in preparing our financial statements in accordance with generally accepted accounting principles. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities, and the reported revenues and expenses. Of the significant accounting policies described in the notes to our financial statements, we believe that the following are the most critical:
Revenue recognition
In the first quarter of 2018, the Company adopted Accounting Standards Update (ASU) 2014-9, Revenue from Contracts with Customers (Topic 606). Under the ASU, revenue from the sale of the Company's products is recognized at the time control transfers to the customers. This generally occurs upon shipment, loading of the goods or when the customer picks up the goods. The Company believes for its contracts with customers, control is transferred at a point in time, typically upon delivery to the customers. When the Company performs shipping and handling activities after the transfer of control to the customers (e.g. when control transfers prior to delivery), they are considered as fulfillment activities, and accordingly, the costs are accrued for when the related revenue is recognized. Interest income is recognized as earned. Shipping costs incurred by the Company in the sale of ethanol, distiller grains and corn oil are not specifically identifiable and as a result, revenue from the sale of ethanol, distiller grains and corn oil is recorded based on the net selling price reported to the Company from the marketer.
Derivative Instruments
The Company evaluates its contracts to determine whether the contracts are derivative instruments. Certain contracts that literally meet the definition of a derivative may be exempted from derivative accounting as normal purchases or normal sales. Normal purchases and normal sales are contracts that provide for the purchase or sale of something other than a financial instrument or derivative instrument that will be delivered in quantities expected to be used or sold over a reasonable period in the normal course of business. Contracts that meet the requirements of normal purchases or sales are documented as normal and exempted from the accounting and reporting requirements of derivative accounting.
The Company enters into short-term cash, option and futures contracts as a means of securing purchases of corn, natural gas and sales of ethanol for the plant and managing exposure to changes in commodity and energy prices. All of the Company's derivatives are designated as non-hedge derivatives for accounting purposes, with changes in fair value recognized in net income. Although the contracts are economic hedges of specified risks, they are not designated as and accounted for as hedging instruments.
As part of its trading activity, the Company uses futures and option contracts through regulated commodity exchanges to manage its risk related to pricing of inventories. To reduce that risk, the Company generally takes positions using cash and futures contracts and options.
Realized and unrealized gains and losses related to derivative contracts related to corn and natural gas are included as a component of cost of goods sold and derivative contracts related to ethanol are included as a component of revenues in the accompanying financial statements. The fair values of contracts entered through commodity exchanges are presented on the accompanying balance sheet as derivative instruments.
29
Off-Balance Sheet Arrangements
We do not have any off-balance sheet arrangements.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
We are exposed to the impact of market fluctuations associated with commodity prices as discussed below. We have no exposure to foreign currency risk as all of our business is conducted in U.S. Dollars and we had no amounts outstanding on variable interest debt as of December 31, 2019. We use derivative financial instruments as part of an overall strategy to manage market risk. We use cash, futures and option contracts to hedge changes to the commodity prices of corn, natural gas and ethanol. We do not enter into these derivative financial instruments for trading or speculative purposes, nor do we designate these contracts as hedges for accounting purposes.
Commodity Price Risk
We seek to minimize the risks from fluctuations in the prices of raw material inputs, such as corn and natural gas, and finished products, such as ethanol and distiller grains, through the use of hedging instruments. In practice, as markets move, we actively manage our risk and adjust hedging strategies as appropriate. Although we believe our hedge positions accomplish an economic hedge against our future purchases and sales, management has chosen not to use hedge accounting, which would match the gain or loss on our hedge positions to the specific commodity purchase being hedged. We are using fair value accounting for our hedge positions, which means as the current market price of our hedge positions changes, the realized or unrealized gains and losses are immediately recognized in our cost of goods sold or as an offset to revenues. The immediate recognition of hedging gains and losses under fair value accounting can cause net income to be volatile from quarter to quarter due to the timing of the change in value of the derivative instruments relative to the cost and use of the commodity being hedged.
As of December 31, 2019, we had price protection in place for approximately 6% of our anticipated corn needs, 78% of our natural gas needs and 15% of our ethanol sales for the next 12 months. A sensitivity analysis has been prepared to estimate our exposure to ethanol, corn and natural gas price risk. Market risk related to these factors is estimated as the potential change in income resulting from a hypothetical 10% adverse change in the average cost of our corn and natural gas prices and average ethanol price as of December 31, 2019, 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, 2019. The results of this analysis, which may differ from actual results, are as follows:
Estimated Volume Requirements for the next 12 months (net of forward and futures contracts) | Unit of Measure | Hypothetical Adverse Change in Price | Approximate Adverse Change to Income | ||||||||
Natural Gas | 1,121,000 | MMBTU | 10% | $ | 246,620 | ||||||
Ethanol | 192,235,000 | Gallons | 10% | 26,912,900 | |||||||
Corn | 60,759,000 | Bushels | 10% | 24,303,600 | |||||||
For comparison purposes, our sensitivity analysis for our 2018 fiscal year is set forth below.
Estimated Volume Requirements for the next 12 months (net of forward and futures contracts) | Unit of Measure | Hypothetical Adverse Change in Price | Approximate Adverse Change to Income | ||||||||
Natural Gas | 983,500 | MMBTU | 10% | $ | 344,225 | ||||||
Ethanol | 200,000,000 | Gallons | 10% | 24,000,000 | |||||||
Corn | 61,700,000 | Bushels | 10% | 22,212,000 | |||||||
Liability Risk
We participate, along with other plants in the industry, in a group captive insurance company (Captive). The Captive insures losses related to workman's compensation, commercial property and general liability. The Captive reinsures catastrophic losses for all participants, including the Company, in excess of predetermined amounts. Our premiums are accrued by a charge to income for the period to which the premium relates and is remitted by our insurer to the captive reinsurer. These premiums are structured such that we have made a prepaid collateral deposit estimated for losses related to the above coverage. The Captive
30
insurer has estimated and collected an amount in excess of the estimated losses but less than the catastrophic loss limit insured by the Captive. We cannot be assessed over the amount in the collateral fund.
31
ITEM 8. FINANCIAL STATEMENTS
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Members and the Board of Directors of Homeland Energy Solutions, LLC
Opinion on the Financial Statements
We have audited the accompanying balance sheets of Homeland Energy Solutions, LLC (the Company) as of December 31, 2019 and 2018, the related statements of operations, members’ equity and cash flows for each of the three years in the period ended December 31, 2019, and the related notes to the financial statements (collectively, the financial statements). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2019 and 2018, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2019, in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting 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.
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
/s/ RSM US LLP
We have served as the Company's auditor since 2010.
Des Moines, Iowa
March 6, 2020
32
33
Homeland Energy Solutions, LLC
Balance Sheets
December 31, 2019 | December 31, 2018 | ||||||
ASSETS | |||||||
CURRENT ASSETS | |||||||
Cash and cash equivalents | $ | 17,274,703 | $ | 28,751,994 | |||
Trading securities | 42,508,451 | 30,553,821 | |||||
Accounts receivable | 7,159,632 | 7,231,721 | |||||
Derivative instruments | 799,484 | 929,383 | |||||
Inventory | 15,311,396 | 14,750,199 | |||||
Prepaid and other | 4,119,486 | 3,345,961 | |||||
Total current assets | 87,173,152 | 85,563,079 | |||||
PROPERTY AND EQUIPMENT | |||||||
Land and improvements | 23,181,342 | 23,169,342 | |||||
Buildings | 8,777,302 | 8,718,139 | |||||
Equipment | 222,979,738 | 212,760,113 | |||||
Construction in progress | 722,507 | 4,131,692 | |||||
255,660,889 | 248,779,286 | ||||||
Less accumulated depreciation | 129,105,903 | 113,583,362 | |||||
Total property and equipment | 126,554,986 | 135,195,924 | |||||
OTHER ASSETS | |||||||
Right of use asset operating leases | 4,678,365 | — | |||||
Utility rights, net of accumulated amortization of $1,728,386 and $1,591,994 | 579,643 | 716,035 | |||||
Other assets | 3,973,846 | 4,118,614 | |||||
Total other assets | 9,231,854 | 4,834,649 | |||||
TOTAL ASSETS | $ | 222,959,992 | $ | 225,593,652 | |||
See Notes to Financial Statements.
34
Homeland Energy Solutions, LLC
Balance Sheets (continued)
December 31, 2019 | December 31, 2018 | ||||||
LIABILITIES AND MEMBERS' EQUITY | |||||||
CURRENT LIABILITIES | |||||||
Accounts payable | $ | 14,834,053 | $ | 13,177,598 | |||
Due to former member | 30,000,000 | 30,000,000 | |||||
Accrued expenses | 1,507,195 | 1,370,498 | |||||
Current maturities of long term debt | 6,000,000 | 6,000,000 | |||||
Current portion operating lease liability | 1,561,422 | — | |||||
Total current liabilities | 53,902,670 | 50,548,096 | |||||
COMMITMENTS AND CONTINGENCIES (Note 5) | |||||||
LONG-TERM LIABILITIES | |||||||
Term revolving loan, total long-term liabilities | 11,964,824 | 17,950,754 | |||||
Operating lease liability | 3,116,943 | — | |||||
Total long-term liabilities | 15,081,767 | 17,950,754 | |||||
MEMBERS' EQUITY (64,560 units issued and outstanding) | 153,975,555 | 157,094,802 | |||||
TOTAL LIABILITIES AND MEMBERS' EQUITY | $ | 222,959,992 | $ | 225,593,652 | |||
See Notes to Financial Statements.
35
Homeland Energy Solutions, LLC
Statements of Operations
For the Years Ended December 31, 2019, 2018, and 2017
2019 | 2018 | 2017 | |||||||||
Revenue | $ | 329,774,685 | $ | 307,400,097 | $ | 256,525,281 | |||||
Costs of goods sold | 307,650,836 | 283,549,201 | 236,834,163 | ||||||||
Gross profit | 22,123,849 | 23,850,896 | 19,691,118 | ||||||||
Selling, general and administrative expenses | 3,885,532 | 3,658,156 | 3,525,736 | ||||||||
Operating income | 18,238,317 | 20,192,740 | 16,165,382 | ||||||||
Other income (expense) | |||||||||||
Interest expense | (902,101 | ) | (1,314,324 | ) | (318,288 | ) | |||||
Interest income | 53,375 | 14,516 | 88,558 | ||||||||
Other income | 2,087,162 | 873,273 | 896,698 | ||||||||
Total other income (expense) | 1,238,436 | (426,535 | ) | 666,968 | |||||||
Net Income | $ | 19,476,753 | $ | 19,766,205 | $ | 16,832,350 | |||||
Basic & diluted net income per capital unit | $ | 302 | $ | 306 | $ | 261 | |||||
Distribution per capital unit | $ | 350 | $ | 220 | $ | 255 | |||||
Weighted average number of units outstanding for the calculation of basic & diluted net income per capital unit | 64,560 | 64,576 | 64,585 | ||||||||
See Notes to Financial Statements.
36
Homeland Energy Solutions, LLC
Statement of Members' Equity
For the Years ended December 31, 2019, 2018 and 2017
Members' | ||||
Equity | ||||
Balance, December 31, 2016 | $ | 151,237,372 | ||
Distributions | (16,469,175 | ) | ||
Net Income | 16,832,350 | |||
Balance, December 31, 2017 | 151,600,547 | |||
Redemption of 25 Membership Units | (65,000 | ) | ||
Distributions | (14,206,950 | ) | ||
Net Income | 19,766,205 | |||
Balance, December 31, 2018 | 157,094,802 | |||
Distributions | (22,596,000 | ) | ||
Net Income | 19,476,753 | |||
Balance, December 31, 2019 | $ | 153,975,555 | ||
See Notes to Financial Statements.
37
Homeland Energy Solutions, LLC
Statements of Cash Flows
For the Years Ended December 31, 2019, 2018, and 2017
2019 | 2018 | 2017 | |||||||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||||||||
Net income | $ | 19,476,753 | $ | 19,766,205 | $ | 16,832,350 | |||||
Adjustments to reconcile net income to net cash provided by operating activities: | |||||||||||
Depreciation and amortization | 15,693,009 | 15,169,546 | 12,707,225 | ||||||||
Unrealized loss (gain) on risk management activities | 129,900 | (174,163 | ) | (226,035 | ) | ||||||
Realized and unrealized (gain) on trading securities | (1,954,630 | ) | (351,156 | ) | (631,352 | ) | |||||
(Gain) loss on disposal of property and equipment | (550 | ) | — | 4,082 | |||||||
Change in working capital components: | |||||||||||
Accounts receivable | 72,089 | (5,971,285 | ) | 4,998,067 | |||||||
Inventory | (561,197 | ) | 1,233,735 | (4,364,370 | ) | ||||||
Prepaid expenses and other | (965,629 | ) | (470,208 | ) | (167,724 | ) | |||||
Accounts payable, accrued expenses | 3,400,401 | 1,539,635 | 2,459,248 | ||||||||
Net cash provided by operating activities | 35,290,146 | 30,742,309 | 31,611,491 | ||||||||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||||||||
Purchase of trading securities | (30,000,000 | ) | — | — | |||||||
Sale of trading securities | 20,000,000 | — | 11,979,838 | ||||||||
Payments for equipment and construction in progress | (8,508,858 | ) | (10,524,217 | ) | (41,450,674 | ) | |||||
Proceeds from sale of equipment | 550 | — | — | ||||||||
Decrease (increase) in other assets | 336,871 | (762,375 | ) | (201,729 | ) | ||||||
Net cash (used in) investing activities | (18,171,437 | ) | (11,286,592 | ) | (29,672,565 | ) | |||||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||||||||
Distribution to members | (22,596,000 | ) | (14,206,950 | ) | (16,469,175 | ) | |||||
Payments for debt issuance costs | — | — | (70,167 | ) | |||||||
Proceeds from long-term borrowings | — | — | 30,000,000 | ||||||||
Redemption of member units | — | (65,000 | ) | — | |||||||
Payments on long-term borrowings | (6,000,000 | ) | (6,000,000 | ) | — | ||||||
Net cash provided by (used in) financing activities | (28,596,000 | ) | (20,271,950 | ) | 13,460,658 | ||||||
Net increase (decrease) in cash and cash equivalents | (11,477,291 | ) | (816,233 | ) | 15,399,584 | ||||||
Cash and Cash Equivalents - Beginning | 28,751,994 | 29,568,227 | 14,168,643 | ||||||||
Cash and Cash Equivalents - Ending | $ | 17,274,703 | $ | 28,751,994 | $ | 29,568,227 | |||||
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION | |||||||||||
Cash paid for interest, net of capitalized interest of 2019 $203,690 and 2018 $74,077 and 2017 $427,079 | $ | 888,031 | $ | 1,423,995 | $ | 187,696 | |||||
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES | |||||||||||
Establishment of lease liability and right-of-use asset | $ | 6,320,411 | $ | — | $ | — | |||||
Accounts payable related to property and equipment | $ | 188,830 | $ | 1,796,079 | $ | 2,548,456 | |||||
See Notes to Financial Statements.
38
1.Nature of Business and Significant Accounting Policies
Nature of Business
Homeland Energy Solutions, LLC (an Iowa Limited Liability Company) is located near Lawler, Iowa and was organized to pool investors for a 100 million gallon ethanol plant with distribution throughout the United States. The Company has capacity to produce in excess of 190 million gallons annually and sells distillers dried grains and corn oil as byproducts of ethanol production.
Organization
Homeland Energy Solutions, LLC is organized as an Iowa limited liability company. The members' liability is limited as specified in Homeland Energy Solutions' operating agreement and pursuant to the Iowa Revised Uniform Limited Liability Company Act.
Significant Accounting Policies:
Accounting Estimates
Management uses estimates and assumptions in preparing these financial statements in accordance with United States Generally Accepted Accounting Principles. Those estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities, and the reported revenues and expenses. Actual results could differ from those estimates.
Cash and Cash Equivalents
The Company maintains its accounts primarily at one financial institution. At various times, the Company's cash balances may exceed amounts insured by the Federal Deposit Insurance Corporation. The Company has not experienced any losses in such accounts. Also included in cash and equivalents are highly liquid investments that are readily convertible into known amounts of cash, which are subject to an insignificant risk of change in value due to interest rate, quoted price or penalty on withdrawal and have a maturity of three months or less.
Trading Securities
Investments bought and held principally for the purpose of selling them in the near term are classified as trading securities. Trading securities are measured at fair value using prices obtained from pricing services. Any interest, dividends, and unrealized or realized gains and losses on the trading securities are recorded as part of other income (expense).
At December 31, 2019, trading securities consisted of short term bond mutual funds with an approximate cost of $42,370,000 and fair value of $42,508,000. At December 31, 2018, trading securities consisted of corporate bonds and short term bond mutual funds with an approximate cost of $31,292,000 and fair value of $30,554,000. For the fiscal years ended December 31, 2019, 2018, and 2017 the Company recorded interest, dividends and realized and unrealized gains and losses from these investments of approximately $1,955,000, $351,000, and $553,000 respectively.
The Board of Directors voted to set aside up to $30 million in trading securities that will be used by the Company for the repurchase of 25,860 membership units held by Steve Retterath per the terms of an agreement with Mr. Retterath entered into on June 13, 2013 by the Company.
Receivables
Credit sales are made primarily to two customers and no collateral is required. The Company carries these accounts receivable at face amount with no allowance for doubtful accounts due to the historical collection rates on these accounts.
Investments
The Company has a less than 20% investment interest in Renewable Products Marketing Group, LLC (RPMG). This investment is being accounted for under the equity method of accounting under which the Company's share of net income is recognized as income in the Company's income statement and added to the investment account. The investment balance is included in other assets and the income recognized as other income. The investment is evaluated for indications of impairment on a regular basis, a loss would be recognized when the fair value is determined to be less than the carrying value.
39
Inventories
Inventories are generally valued at the lower of cost (first-in, first-out) or net realizable value. In the valuation of inventories and purchase commitments, net realizable value is defined as estimated selling price in the ordinary course of business less reasonably predictable costs of completion, disposal, and transportation.
Property and Equipment
Property and equipment are stated at cost. Significant additions and betterments are capitalized, while expenditures for maintenance and repairs are charged to operations when incurred. The Company uses the straight-line method of computing depreciation over the estimated useful lives as follows.
Estimated Useful Life in Years | |||
Minimum | Maximum | ||
Land Improvements | 20 | 40 | |
Buildings | 10 | 40 | |
Equipment | 7 | 40 | |
The Company reviews its property and equipment for impairment whenever events indicate that the carrying amount of the asset group may not be recoverable. If circumstances require a long-lived asset group be tested for possible impairment, the Company first compares undiscounted cash flows expected to be generated by an asset group to the carrying value of the asset group. If the carrying value of the long-lived asset group in not recoverable on an undiscounted cash flow basis, an impairment is recognized to the extent that the carrying value exceeds its fair value. Fair value is determined through various valuation techniques including discounted cash flow models, quoted market values, and third-party independent appraisals, as considered necessary. The Company has concluded that no impairment is necessary as of December 31, 2019 and 2018.
Derivative Instruments
The Company evaluates its contracts to determine whether the contracts are derivative instruments. Certain contracts that literally meet the definition of a derivative may be exempted from derivative accounting as normal purchases or normal sales. Normal purchases and normal sales are contracts that provide for the purchase or sale of something other than a financial instrument or derivative instrument that will be delivered in quantities expected to be used or sold over a reasonable period in the normal course of business. Contracts that meet the requirements of normal purchases or sales are documented as normal and exempted from the accounting and reporting requirements of derivative accounting.
The Company enters into short-term cash, option and futures contracts as a means of securing purchases of corn, natural gas and sales of ethanol for the plant and managing exposure to changes in commodity and energy prices. All of the Company's derivatives are designated as non-hedge derivatives for accounting purposes, with changes in fair value recognized in net income. Although the contracts are economic hedges of specified risks, they are not designated or accounted for as hedging instruments.
As part of its trading activity, the Company uses futures and option contracts through regulated commodity exchanges to manage its risk related to pricing of inventories. To reduce that risk, the Company generally takes positions using cash and futures contracts and options.
Realized and unrealized gains and losses related to derivative contracts related to corn and natural gas are included as a component of cost of goods sold and derivative contracts related to ethanol are included as a component of revenues in the accompanying financial statements. The fair values of all contracts with the same counter party are presented net on the accompanying balance sheet as derivative instruments net of cash due from/to broker.
Utility Rights
Utility rights consist of payments to electric and natural gas companies for construction in aid of electric and gas lines to the facility but the Company retains no ownership rights to the assets. The utility rights are amortized on a straight-line basis over 15 years based on the estimate normal usage of such infrastructure.
40
At December 31, 2019, the Company anticipates the following amortization of utility rights for the years ended December 31:
2020 | $ | 136,000 | ||
2021 | 136,000 | |||
2022 | 136,000 | |||
2023 | 136,000 | |||
2024 | 36,000 | |||
Total amortization | $ | 580,000 | ||
Revenue and Cost Recognition
In the first quarter of 2018, the Company adopted Accounting Standards Update (ASU) 2014-9, Revenue from Contracts with Customers (Topic 606). Under the ASU, revenue is recognized when a customer obtains control of promised goods or services in an amount that reflects the consideration the entity expects to receive in exchange for those goods or services. In addition, the standard requires disclosure of the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The Company applied the five-step method outlined in the ASU to all contracts with customers and elected the modified retrospective implementation method. The Company generally has a single performance obligation in its arrangements with customers. The Company believes for its contracts with customers, control is transferred at a point in time, typically upon delivery to the customers. When the Company performs shipping and handling activities after the transfer of control to the customers (e.g., when control transfers prior to delivery), they are considered as fulfillment activities, and accordingly, the costs are accrued for when the related revenue is recognized. The Company generally expenses sales commissions when incurred because the amortization period would have been less than one year. The implementation of the new standard does not have any material impact on the measurement or recognition of revenue of prior periods, however additional disclosures have been added in accordance with the ASU.
The following is a description of principal activities from which we generate revenue. Revenues from contracts with customers are recognized when control of the promised goods or services are transferred to our customers, in an amount that reflects the consideration that we expect to receive in exchange for those goods or services.
• | sales of ethanol; |
• | sales of distiller grains; and |
• | sales of corn oil; |
All revenue recognized in the income statement is considered to be revenue from contracts with customers. The disaggregation of revenue according to product line, along with accounts receivable from contracts with customers, is as disclosed in Note 5.
Shipping costs incurred by the Company in the sale of ethanol and distiller grains are not specifically identifiable and as a result, revenue from the sale of ethanol and distiller grains is recorded based on the net selling price reported to the Company from the marketer. Rail car lease costs incurred by the Company in the sale and shipment of distiller grain products are included in the cost of goods sold.
Income Taxes
The Company was formed under sections of the federal and state income tax laws which provide that, in lieu of corporate income taxes, the members separately account for their share of the Company's items of income, deductions, losses and credits. As a result of this election, no income taxes have been recognized in the accompanying financial statements.
Management has evaluated the Company's tax positions under the Financial Accounting Standards Board issued guidance on accounting for uncertainty in income taxes and concluded that the Company had taken no uncertain tax positions that require adjustment to the financial statements to comply with the provisions of this guidance.
41
Committed Shares to be Redeemed
On June 13, 2013, the Company entered into an agreement with Steve Retterath, the Company's largest member, to repurchase and retire all of the membership units owned by Mr. Retterath. The Company agreed to close on this repurchase on, or before, August 1, 2013. The Company agreed to repurchase and retire 25,860 membership units owned by Mr. Retterath in exchange for $30 million, to be paid in two equal installments, payable at closing and on July 1, 2014. The transaction failed to close by the scheduled date due to objections by Mr. Retterath. Due to all conditions of the agreement being met prior to, or on, August 1, 2013, the Company believes that it has a binding agreement with Mr. Retterath; as such the commitment to repurchase and retire the membership units is reflected in the financial statements as a liability as these shares became mandatorily redeemable on June 13, 2013. No distributions have been paid to Mr. Retterath since the time of the original expected closing date of August 1, 2013.
Net Income per Unit
Basic and diluted net income per unit is computed by dividing net income by the weighted average number of members' units and members' unit equivalents outstanding during the period. There were no member unit equivalents outstanding during the periods presented; accordingly, the Company's basic and diluted net income per unit are the same.
Prior to, or on, August 1, 2013, the Company believes it has a binding agreement with Steve Retterath to repurchase and retire all 25,860 membership units owned by Mr. Retterath. These membership units have thus been excluded in the determination of net income per unit as presented in the Statement of Operations. The Company is currently involved in litigation with Mr. Retterath. There is potential that Mr. Retterath will continue as a unit holder upon conclusion of the litigation and said membership units would not be redeemed under the repurchase agreement. If the units are not redeemed, basic and diluted net income per unit, including the 25,860 units, for the twelve months ended December 31, 2019, 2018 and 2017 would be approximately $215, $219, and $186, respectively.
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.
Environmental Liabilities
The Company's operations are subject to environmental laws and regulations adopted by various governmental authorities in the jurisdiction in which it operates. These laws require the Company to investigate and remediate the effects of the release or disposal of materials at its locations. Accordingly, the Company has adopted policies, practices and procedures in the areas of pollution control, occupational health and the production, handling, storage and use of hazardous materials to prevent material environmental or other damage, and to limit the financial liability which could result from such events. Environmental liabilities are recorded when the Company's liability is probable and the costs can be reasonably estimated. No expense or liability, including asset retirement obligations, for environmental liabilities has been recorded for the years ended December 31, 2019, 2018, or 2017.
Fair Value
Financial instruments include cash and equivalents, trading securities, accounts receivable, derivative instruments, accounts payable, accrued expenses and long-term debt. The fair value of trading securities and derivative financial instruments is based on quoted market prices (see Note 9). The fair value of other current financial instruments is estimated to approximate carrying value due to the short-term nature of these instruments (Level 3). The fair value of long-term debt is estimated to approximate carrying value due to the short period of time held and the fixed rate approximating available market rates as of year-end (Level 3).
Risks and Uncertainties
The Company has certain risks and uncertainties that it will experience during volatile market conditions, which can have a severe impact on operations. The Company's revenues are derived from the sale and distribution of ethanol, distiller grains and corn oil to customers primarily located in the United States. Corn for the production process is supplied to the plant primarily from local agricultural producers and from purchases on the open market. For the year ended December 31, 2019, ethanol sales averaged approximately 78% of total revenues, while approximately 18% of revenues were generated from the sale of distiller grains and 4% of revenues were generated from the sale of corn oil. For the year ended December 31, 2019, corn costs averaged approximately
42
79% of cost of goods sold.
The Company's operating and financial performance is largely driven by the prices at which it sells ethanol and the net expense of corn. The price of ethanol is influenced by factors such as supply and demand, weather, government policies and programs, and unleaded gasoline and the petroleum markets. Excess ethanol supply in the market, in particular, puts downward pressure on the price of ethanol. The Company's largest cost of production is corn. The cost of corn is generally impacted by factors such as supply and demand, weather, and government policies and programs. The Company's risk management program is used to protect against the price volatility of these commodities.
Recent & Pending Accounting Pronouncements
In February 2016, FASB issued ASU No. 2016-02 "Leases" ("ASU 2016-02"). ASU 2016-02 requires the recognition of lease
assets and lease liabilities by lessees for all leases greater than one year in duration and classified as operating leases under previous GAAP. ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, and for interim periods within that fiscal year. Under the new guidance, lessees will be required to recognize the following for all leases (with the exception of short-term leases): (1) a lease liability, which is a lessee's obligation to make lease payments arising from a lease, measured on a discounted cash flow basis; and (2) a "right of use" asset, which is an asset that represents the lessee's right to use the specified asset for the lease term. The Company adopted this accounting standard effective January 1, 2019. Upon adoption, the Company elected a practical expedient which allows existing leases to retain their classification as operating leases. The Company has elected to account for lease and related nonlease components as a single lease component. See Note 6 for more detailed information regarding leases.
In August 2018, FASB issued ASU No. 2018-13 "Fair Value Measurement (Topic 820): Disclosure Framework - Changes to the Disclosure Requirements for Fair Value Measurement" ("ASU 2018-13"). ASU 2018-13 changes some of the disclosure requirements related to fair value measurements related to the Level 1, 2 and 3 investments. ASU 2018-13 is effective for fiscal years beginning after December 15, 2019, and for interim periods within that fiscal year. The Company is currently evaluating the impact of its pending adoption of the new standard on the financial statements.
2. INVENTORY
Inventory consisted of the following as of December 31, 2019 and 2018.
2019 | 2018 | |||||||
Raw Materials | $ | 10,757,505 | $ | 8,983,124 | ||||
Work in Process | 2,617,916 | 2,295,715 | ||||||
Finished Goods | 1,935,975 | 3,471,360 | ||||||
Totals | $ | 15,311,396 | $ | 14,750,199 | ||||
3. DEBT
Master Loan Agreement with Home Federal Savings Bank
On June 29, 2017, the Company amended and restated the Master Loan Agreement with Home Federal Savings Bank ("Home Federal"), amending the term revolving loan to provide funding to operate the plant and establishing a term loan to help fund the Company's $42 million expansion project. In return, the Company entered into agreements providing Home Federal a security interest in substantially all personal property located on Company property. The Company currently has two loans with Home Federal, a term revolving loan and a term loan.
Term Revolving Loan
Under the terms of the Second Supplement to the Master Loan Agreement, dated June 29, 2017, the Company has a $30 million term revolving loan which has a maturity date of December 31, 2022. Interest on the term revolving loan is due monthly and accrues at a rate equal to the one month LIBOR plus 310 basis points, 4.8% on December 31, 2019. There was no balance outstanding on the term revolving loan and $30 million available to be drawn as of December 31, 2019.
Term Loan
43
Under the terms of the Fourth Supplement to the Master Loan Agreement, dated June 29, 2017, the Company has a $30 million term loan which has a maturity date of December 31, 2022. The Company currently has $18 million outstanding on the term loan. Interest on the term loan is at a fixed rate of 4.79%. The Company is required to make monthly interest payments beginning July 1, 2017 and bi-annual principal payments of $3 million beginning on June 30, 2018. The long-term portion of the outstanding debt is presented net of unamortized debt issuance costs of $35,176 and $49,246 as of December 31, 2019 and 2018.
At December 31, 2019, the Company had the following debt maturities on the term loan for the twelve month periods ended December 31:
2020 | $ | 6,000,000 | ||
2021 | 6,000,000 | |||
2022 | 6,000,000 | |||
Total principal payments | $ | 18,000,000 | ||
Covenants
During the term of the loans, the Company is subject to certain financial covenants at various times calculated monthly, quarterly or annually, including restriction of the payment of dividends and capital expenditures and maintenance of certain financial ratios including minimum working capital and a fixed charge ratio as defined by the Master Loan Agreement. Failure to comply with the protective loan covenants or maintain the required financial ratios may cause acceleration of the outstanding principal balances on the loans and/or the imposition of fees, charges or penalties. The Company is in compliance with all debt covenants as of December 31, 2019.
4. RELATED PARTY TRANSACTIONS AND SUBSEQUENT EVENT
Due to Former Member
On June 13, 2013, the Company entered into an agreement with Steve Retterath, the Company's largest member, to repurchase and retire all of the units owned by Mr. Retterath. The Company agreed to close on this repurchase on or before August 1, 2013. The Company agreed to repurchase and retire 25,860 memberships units owned by Mr. Retterath in exchange for $30 million, to be paid in two equal installments payable at closing and on July 1, 2014. The transaction failed to close by the scheduled date due to objections by Mr. Retterath. The Company believes that it has a binding agreement with Mr. Retterath. On August 14, 2013, the Company filed a lawsuit against Mr. Retterath in Iowa state court to enforce the terms of the repurchase agreements. The Company is asking the Iowa court to require Mr. Retterath to complete the repurchase agreement pursuant to its terms. In February 2020, the Iowa Supreme Court ruled that the repurchase agreement was valid and enforceable and ordered Mr. Retterath to close on the unit repurchase.
Mr. Retterath contends that he is not bound by the agreement. The Company's position is as of the closing date, Mr. Retterath is no longer the equitable owner of any membership units in the Company. As a result, the Company has recorded a $30 million current liability related to the amount the Company agreed to pay Mr. Retterath to repurchase his membership units and has correspondingly reduced members' equity on its balance sheet.
Other Matters
The Company purchases corn and materials from members of its Board of Directors who own or manage elevators or are local producers of corn. Purchases during the years ended December 31, 2019, and 2018 from these companies and individuals totaled approximately $3,113,000, and $3,641,000, respectively. Amounts due to those members was $3,540 and $0, as of December 31, 2019 and 2018, respectively.
5. COMMITMENTS, CONTINGENCIES AND AGREEMENTS
Ethanol, corn oil, and distiller grains marketing agreements and major customers
The Company has entered into a marketing agreement with RPMG, a related party, to sell all ethanol produced at the plant at a mutually agreed on price, less commission and transportation charges. As of December 31, 2019, the Company had commitments to sell 2.8 million of its produced gallons of ethanol at fixed prices.
44
The Company has also entered into a marketing agreement with RPMG to sell all corn oil produced at the plant at a mutually agreed on price, less marketing fees and transportation charges. As of December 31, 2019, the Company had commitments to sell approximately 8.6 million pounds of corn oil at various fixed and basis price levels indexed against exchanges for delivery throughout the first quarter of 2020.
The Company also has an investment in RPMG, LLC, included in other assets, totaling approximately $2,422,000 and $2,522,000 as of December 31, 2019 and 2018.
The Company has entered into a marketing agreement to sell all distiller grains produced at the plant to CHS, an unrelated party, at a mutually agreed on price, less commission and transportation charges. The agreement calls for automatic renewal for successive one-year terms unless 90-day prior written notice is given before the current term expires in April, 2020; no such written notice has been given. As of December 31, 2019, the Company had approximately 49,000 tons of distiller grains commitments for delivery through February 2020 at various fixed prices.
All above sales commitments are accounted for as normal sales, and accordingly, have not been marked to market.
Sales and marketing fees related to the agreements in place for the years ended December 31, 2019, 2018 and 2017 were as follows:
2019 | 2018 | 2017 | ||||||||||
Sales ethanol - RPMG | $ | 257,312,000 | $ | 234,222,000 | $ | 207,344,000 | ||||||
Sales distiller grains | 58,555,000 | 61,034,000 | 36,393,000 | |||||||||
Sales corn oil - RPMG | 13,607,000 | 12,103,000 | 12,789,000 | |||||||||
Marketing fees ethanol - RPMG | $ | 243,000 | $ | 254,000 | $ | 250,000 | ||||||
Marketing fees distiller grains | 879,000 | 852,000 | 663,000 | |||||||||
Marketing fees corn oil - RPMG | 104,000 | 76,000 | 52,000 | |||||||||
2019 | 2018 | |||||||||||
Amount due from RPMG | $ | 4,712,000 | $ | 4,927,000 | ||||||||
Amount due from CHS | 2,388,000 | 2,170,000 | ||||||||||
At December 31, 2019, the Company had approximately $11,557,000 in outstanding corn purchase commitments for bushels at various prices and approximately 1,283,000 bushels of unpriced corn purchase commitments through April 2021. Additionally, the Company had locked in place approximately 3,920,000 decatherms of natural gas at fixed prices through December 31, 2020. These contracts are accounted for under the normal purchase exclusion.
As of December 31, 2019, the Company had approximately 1,017,000 bushels with approximate market value of $3,821,000 of deferred corn. As of December 31, 2018, the Company had approximately 1,053,000 bushels with approximate market value of $3,756,000 of deferred corn.
The Company has commitments for minimum purchases of various utilities such as natural gas and electricity through December, 2020, accounted for under the normal purchase exclusion, which approximated $12,125,000.
6. LEASE OBLIGATIONS
Effective January 1, 2019, the Company adopted ASU 2016-02, Leases (Topic 842). The Company elected the option to apply the transition provisions at the adoption date instead of the earliest comparative period presented in the financial statements. By making this election, the Company has not applied retrospective reporting for 2018. The Company elected the short-term lease exception provided for in the standard and therefore only recognized right-of-use assets and lease liabilities for leases with a term greater than one year. The Company elected the package of practical expedients to not re-evaluate existing contracts as containing
45
a lease or the lease classification unless it was not previously assessed against the lease criteria. In addition, the Company did not reassess initial direct costs for any existing leases.
A lease exists when a contract conveys to a party the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. The Company recognized a lease liability at the lease commencement date, as the present value of future lease payments, using an estimated rate of interest that the Company would pay to borrow equivalent funds on a collateralized basis. A lease asset is recognized based on the lease liability value and adjusted for any prepaid lease payments, initial direct costs, or lease incentive amounts. The lease term at the commencement date includes any renewal options or termination options when it is reasonably certain that the Company will exercise or not exercise those options, respectively.
The Company leases rail cars and rail moving equipment with original terms up to seven years. The Company is obligated to pay costs of insurance, taxes, repairs and maintenance pursuant to terms of the leases. Rent expense incurred for the operating leases during the years ended December 31, 2019, 2018 and 2017 was approximately $1,734,000, $1,676,000 and $1,577,000. The lease agreements have maturity dates ranging from March 2022 to October 2025. The weighted average remaining life of the lease term for these leases was 2.89 years as of December 31, 2019.
The discount rate used in determining the lease liability for each individual lease was the Company's estimated incremental borrowing rate of 4.79%. The right-of-use asset operating lease, included in other assets, and operating lease liability, included in current and long term liabilities was $4,678,365 as of December 31, 2019.
At December 31, 2019, the Company had the following approximate minimum rental commitments under non-cancelable operating leases for the years ended December 31:
2020 | $ | 1,752,000 | ||
2021 | 1,752,000 | |||
2022 | 1,046,000 | |||
2023 | 300,000 | |||
2024 | 109,000 | |||
2025 | 90,000 | |||
Total lease commitments | $ | 5,049,000 | ||
A reconciliation of the undiscounted future payments in the schedule above and the lease liability recognized in the consolidated balance sheet as of December 31, 2019, is shown below.
Undiscounted future payments | $ | 5,049,000 | ||
Discount effect | (370,635 | ) | ||
$ | 4,678,365 | |||
7. EMPLOYEE BENEFIT PLANS
On January 1, 2016, the Company adopted a 401k retirement plan which provides retirement savings options for all eligible employees. Previously, the Company utilized a Simple IRA Adoption Agreement to provide retirement savings options for all eligible employees. Employees meeting certain eligibility requirements can participate in the plan. The Company makes a matching contribution based on the participants' eligible wages. For the years ended December 31, 2019, 2018 and 2017, the Company made matching contributions of approximately $185,000, $174,000 and $274,000, respectively.
8. DERIVATIVE INSTRUMENTS
The Company's activities expose it to a variety of market risks, including the effects of changes in commodity prices. These financial exposures are monitored and managed by the Company as an integral part of its overall risk-management program. The Company's risk management program focuses on the unpredictability of financial and commodities markets and seeks to reduce the potentially adverse effects that the volatility of these markets may have on its operating results.
46
To reduce price risk caused by market fluctuations, the Company generally follows a policy of using exchange traded futures and options contracts to reduce its net position of merchandisable agricultural commodity inventories and forward cash purchase and sales contracts and uses exchange traded futures and options contracts to reduce price risk. Exchange-traded futures contracts are valued at market price. Changes in market price of exchange traded futures and options contracts related to corn and natural gas are recorded in costs of goods sold and changes in market prices of contracts related to the sale of ethanol, if applicable, are recorded in revenues.
The Company uses futures or options contracts to fix the purchase price of anticipated volumes of corn to be purchased and processed in a future month. The Company's plant will grind approximately 65 million bushels of corn per year. During the previous period and over the next 12 months, the Company has hedged and anticipates hedging between 5% and 60% of its anticipated monthly grind. At December 31, 2019, the Company has hedged portions of its anticipated monthly purchases for corn averaging approximately 6% of its anticipated monthly grind over the next twelve months.
Unrealized gains and losses on non-exchange traded forward contracts are deemed "normal purchases or sales" under authoritative accounting guidance, as amended and, therefore, are not marked to market in the Company's financial statements. The following table represents the approximate amount of realized and unrealized gains (losses) and changes in fair value recognized in earnings on commodity contracts for years ended December 31, 2019, 2018, and 2017 and the fair value of derivatives as of December 31, 2019 and 2018:
Income Statement Classification | Realized Gain (Loss) | Change In Unrealized Gain (Loss) | Total Gain (Loss) | ||||||||||
Derivatives not designated as hedging instruments: Commodity contracts for the year ended December 31, 2019. | |||||||||||||
Cost of Goods Sold | $ | 3,530,000 | $ | 927,000 | $ | 4,457,000 | |||||||
Total | $ | 3,530,000 | $ | 927,000 | $ | 4,457,000 | |||||||
Derivatives not designated as hedging instruments: Commodity contracts for the year ended December 31, 2018. | |||||||||||||
Cost of Goods Sold | $ | 2,957,000 | $ | (48,000 | ) | $ | 2,909,000 | ||||||
Total | $ | 2,957,000 | $ | (48,000 | ) | $ | 2,909,000 | ||||||
Derivatives not designated as hedging instruments: Commodity contracts for the year ended December 31, 2017. | |||||||||||||
Cost of Goods Sold | $ | 3,467,000 | $ | 317,000 | $ | 3,784,000 | |||||||
Total | $ | 3,467,000 | $ | 317,000 | $ | 3,784,000 | |||||||
Balance Sheet Classification | December 31, 2019 | December 31, 2018 | |||||||
Futures and option contracts | |||||||||
In gain position | $ | 1,126,000 | $ | 271,000 | |||||
In loss position | (37,000 | ) | (19,000 | ) | |||||
Cash held by (due to) broker | (290,000 | ) | 677,000 | ||||||
Current Asset | $ | 799,000 | $ | 929,000 | |||||
47
9. FAIR VALUE MEASUREMENTS
Financial assets and liabilities carried at fair value will be classified and disclosed in one of the following three categories:
Level 1: Valuations for assets and liabilities traded in active markets from readily available pricing sources for market transactions involving identical assets or liabilities.
Level 2: Valuations for assets and liabilities traded in less active dealer or broker markets. Valuations are obtained from third-party pricing services for identical or similar assets or liabilities.
Level 3: Valuations incorporate certain assumptions and projections in determining the fair value assigned to such assets or liabilities.
A description of the valuation methodologies used for instruments measured at fair value, including the general classification of such instruments pursuant to the valuation hierarchy, is set forth below:
Trading securities: Trading securities consisting of corporate bonds and short term bond mutual funds are reported at fair value utilizing Level 1 inputs. Trading securities are measured at fair value using prices obtained from pricing services.
Derivative financial instruments: Commodity futures and exchange-traded commodity options contracts are reported at fair value utilizing Level 1 inputs. For these contracts, the Company obtains fair value measurements from an independent pricing service. The fair value measurements consider observable data that may include dealer quotes and live trading levels from the CBOT and NYMEX markets.
The following table summarizes financial assets and financial liabilities measured at fair value on a recurring basis as of December 31, 2019 and December 31, 2018, segregated by the level of the valuation inputs within the fair value hierarchy utilized to measure fair value:
Total | Level 1 | Level 2 | Level 3 | ||||||||||||
Trading Securities | |||||||||||||||
December 31, 2019 | |||||||||||||||
Assets | $ | 42,508,000 | $ | 42,508,000 | $ | — | $ | — | |||||||
December 31, 2018 | |||||||||||||||
Assets | $ | 30,554,000 | $ | 30,554,000 | — | — | |||||||||
Derivative financial instruments | |||||||||||||||
December 31, 2019 | |||||||||||||||
Assets | $ | 1,126,000 | $ | 1,126,000 | $ | — | $ | — | |||||||
Liabilities | (37,000 | ) | (37,000 | ) | — | — | |||||||||
December 31, 2018 | |||||||||||||||
Assets | $ | 271,000 | $ | 271,000 | $ | — | $ | — | |||||||
Liabilities | (19,000 | ) | (19,000 | ) | — | — | |||||||||
10. LITIGATION MATTERS
Retterath
In relation to the repurchase agreement discussed in Note 4, on August 1, 2013 Mr. Retterath filed a lawsuit against the Company along with several directors, the Company's former CEO, CFO, COO, a former director and the Company's outside legal counsel in Florida state court. In August 2016, this lawsuit was voluntarily dismissed without prejudice by the Retteraths. On August 14, 2013, the Company filed a lawsuit in Iowa state court to enforce the repurchase agreement the Company entered into with Mr. Retterath. No distributions have been paid to Mr. Retterath since the time of the original expected closing date of August 1, 2013. On June 15, 2017, the Iowa Court ruled in favor of Homeland that the repurchase agreement was valid and directed Mr. Retterath to perform his obligations under the repurchase agreement by August 1, 2017. Mr. Retterath subsequently filed various motions
48
with the Iowa Court and was granted a stay regarding his obligation to perform the repurchase agreement while the court considered his post trial motions. The Iowa Court overruled Mr. Retterath's post trial motions and Mr. Retterath filed an appeal. In February 2020, the Iowa Supreme Court ruled that the repurchase agreement was valid and enforceable.
GS Cleantech Corporation
On August 9, 2013, GS Cleantech Corporation (GS Cleantech), a subsidiary of Greenshift Corporation, filed a complaint against the Company alleging that the Company's operation of a corn oil extraction process licensed by the Company infringes patent rights claimed by GS Cleantech. GS Cleantech seeks royalties, damages and potentially triple damages associated with the alleged infringement, as well as attorney's fees from the Company. The Company filed a motion for summary judgment which was granted by the Court. GS Cleantech has appealed this decision. The Company has filed an answer and counterclaims claiming invalidity of the patents, noninfringement, and inequitable conduct. Recently the federal appeals court rejected GS Cleantech's appeal. It is unclear if GS Cleantech intends to seek additional appeals. The Company is not currently able to predict the outcome of the litigation with any degree of certainty.
11. QUARTERLY FINANCIAL DATA (UNAUDITED)
Summary quarterly results for the years ended December 31, 2019, 2018 and 2017 are as follows:
2019 | First Quarter | Second Quarter | Third Quarter | Fourth Quarter | ||||||||||||
Total Revenues | $ | 82,074,397 | $ | 84,860,557 | $ | 76,896,475 | $ | 85,628,405 | ||||||||
Gross Profit | 5,567,871 | 4,600,109 | 4,527,443 | 7,428,426 | ||||||||||||
Operating Income | 4,402,367 | 3,621,216 | 3,801,180 | 6,413,554 | ||||||||||||
Net Income | 4,719,055 | 4,259,845 | 3,990,592 | 6,507,261 | ||||||||||||
Basic & diluted earnings per unit | $ | 73 | $ | 66 | $ | 62 | $ | 101 | ||||||||
2018 | First Quarter | Second Quarter | Third Quarter | Fourth Quarter | ||||||||||||
Total Revenues | $ | 76,622,447 | $ | 84,188,461 | $ | 77,391,884 | $ | 69,156,641 | ||||||||
Gross Profit | 5,926,327 | 12,090,427 | 7,436,293 | (1,602,151 | ) | |||||||||||
Operating Income (Loss) | 5,181,254 | 10,987,670 | 6,540,911 | (2,517,095 | ) | |||||||||||
Net Income (Loss) | 5,072,754 | 10,700,036 | 6,404,067 | (2,410,652 | ) | |||||||||||
Basic & diluted earnings (loss) per unit | $ | 79 | $ | 166 | $ | 99 | $ | (38 | ) | |||||||
2017 | First Quarter | Second Quarter | Third Quarter | Fourth Quarter | ||||||||||||
Total Revenues | $ | 63,156,498 | $ | 71,505,612 | $ | 59,680,650 | $ | 62,182,521 | ||||||||
Gross Profit | 5,135,045 | 6,741,476 | 7,528,111 | 286,486 | ||||||||||||
Operating Income (Loss) | 3,840,725 | 6,008,641 | 6,721,339 | (405,323 | ) | |||||||||||
Net Income (Loss) | 4,154,127 | 6,227,065 | 6,797,340 | (346,182 | ) | |||||||||||
Basic & diluted earnings (loss) per unit | $ | 64 | $ | 96 | $ | 105 | $ | (5 | ) | |||||||
12. GROUP INSURANCE
The Company participates, along with other plants in the industry, in a group captive insurance company (Captive). The Captive insures losses related to workman's compensation, commercial property and general liability. The Captive reinsures catastrophic losses for all participants, including the Company, in excess of predetermined amounts. The Company's premiums are accrued by a charge to income for the period to which the premium relates and is remitted by the Company's insurer to the captive reinsurer. These premiums are structured such that the Company has made a prepaid collateral deposit estimated for losses related to the above coverage. The Captive insurer has estimated and collected an amount in excess of the estimated losses but less than the catastrophic loss limit insured by the Captive. The Company cannot be assessed over the amount in the collateral fund.
49
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.
None.
ITEM 9A. CONTROLS AND PROCEDURES.
Disclosure Controls and Procedures
Management of Homeland Energy is responsible for maintaining disclosure controls and procedures that are designed to ensure that information required to be disclosed in the reports that we file or submit under the Securities Exchange Act of 1934 (the "Exchange Act") are recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission's rules and forms. In addition, the disclosure controls and procedures must ensure that such information is accumulated and communicated to the Company's management, including its Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required financial and other required disclosures.
As of the end of the period covered by this report, an evaluation of the effectiveness of our disclosure controls and procedures (as defined in Rules 13(a)-15(e) and 15(d)-15(e) of the Exchange Act) was carried out under the supervision and with the participation of our Chief Executive Officer (the principal executive officer), James Broghammer, and our Chief Financial Officer (the principal financial and accounting officer), Beth Eiler. Based on their evaluation of our disclosure controls and procedures, they have concluded that such disclosure controls and procedures were effective as of December 31, 2019 to ensure that information required to be disclosed in the reports that we file or submit under the Exchange Act are recorded, processed, summarized and reported within the time periods required by the forms and rules of the Securities and Exchange Commission; and to ensure that the information required to be disclosed by an issuer in the reports that it files or submits under the Exchange Act is accumulated and communicated to our management including our principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.
Internal Control Over Financial Reporting
Inherent Limitations Over Internal Controls
Our internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. Our internal control over financial reporting includes those policies and procedures that:
(i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets;
(ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that our receipts and expenditures are being made only in accordance with authorizations of our management and directors; and
(iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of our assets that could have a material effect on the financial statements.
Management, including our Chief Executive Officer and Chief Financial Officer, does not expect that our internal controls will prevent or detect all errors and all fraud. The effectiveness of controls in future periods is subject to the risk that those internal controls may become inadequate because of changes in business conditions, or that the degree of compliance with the policies or procedures may deteriorate.
Management's Annual Report on Internal Control over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934, as amended). Management conducted an evaluation of the effectiveness of our internal control over financial reporting based on the criteria set forth in the 2013 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, 2019.
50
This annual report does not include an attestation report of our registered public accounting firm regarding internal control over financial reporting. As we are a non-accelerated filer, management's report is not subject to attestation by our registered public accounting firm.
This report shall not be deemed to be filed for purposes of Section 18 of the Securities Exchange Act of 1934, or otherwise subject to the liabilities of that section , and is not incorporated by reference into any filing of the Company, whether made before or after the date hereof, regardless of any general incorporation language in such filing.
Changes in Internal Controls
There were no changes in our internal control over financial reporting during the fourth quarter of our 2019 fiscal year, which were identified in connection with management's evaluation required by paragraph (d) of rules 13a-15 and 15d-15 under the Exchange Act, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
ITEM 9B. OTHER INFORMATION.
None.
PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
The information required by this Item is incorporated by reference in the definitive proxy statement from our 2020 annual meeting of members to be filed with the Securities and Exchange Commission within 120 days after our 2019 fiscal year end on December 31, 2019. This proxy statement is referred to in this report as the 2020 Proxy Statement.
ITEM 11. EXECUTIVE COMPENSATION.
The information required by this Item is incorporated by reference to the 2020 Proxy Statement.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS.
The information required by this Item is incorporated by reference to the 2020 Proxy Statement.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE.
The information required by this Item is incorporated by reference to the 2020 Proxy Statement.
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES.
The information required by this Item is incorporated by reference to the 2020 Proxy Statement.
PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES.
Exhibits Filed as Part of this Report and Exhibits Incorporated by Reference.
The following exhibits and financial statements are filed as part of, or are incorporated by reference into, this report:
(1) | Financial Statements |
The financial statements appear beginning at page 31 of this report.
(2) | Financial Statement Schedules |
51
All supplemental schedules are omitted as the required information is inapplicable or the information is presented in the financial statements or related notes.
(3) | Exhibits |
Exhibit No. | Exhibit | Filed Herewith | Incorporated by Reference | ||
3.1 | Exhibit 3.1 to the registrant's registration statement on Form SB-2 (Commission File 333-135967). | ||||
3.2 | Exhibit 3.2 to the registrant's registration statement on Form SB-2 (Commission File 333-135967). | ||||
3.3 | Exhibit 3.3 to the registrant's registration statement on Form SB-2 (Commission File 333-135967). | ||||
3.4 | Exhibit 3.4 to Pre-Effective Amendment No. 3 to the registrant's registration statement on Form SB-2 (Commission File 333-135967). | ||||
3.5 | Exhibit 3.1 to the registrant's Form 10-Q filed with the Commission on May 15, 2013. | ||||
3.6 | Exhibit 3.6 to the registrant's Form 10-K filed with the Commission on February 27, 2014. | ||||
3.7 | Exhibit 3.1 to the Registrant's Form 10-Q filed with the Commission on May 16, 2018. | ||||
4.1 | Exhibit 4.2 to the registrant's registration statement on Form SB-2 (Commission File 333-135967). | ||||
10.1 | Exhibit 10.26 to the registrant's Form 10-QSB filed with the Commission on August 11, 2007. | ||||
10.2 | Exhibit 10.30 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008. | ||||
10.3 | Exhibit 10.31 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008. | ||||
10.4 | Exhibit 10.32 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008. | ||||
10.5 | Exhibit 10.33 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008. | ||||
10.6 | Exhibit 10.34 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008. | ||||
10.7 | Exhibit 10.35 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008. | ||||
10.8 | Exhibit 10.36 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008. | ||||
52
10.9 | Exhibit 10.37 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008. | ||||
10.10 | Exhibit 10.38 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008. | ||||
10.11 | Exhibit 10.39 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008. | ||||
10.12 | Exhibit 10.40 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008. | ||||
10.13 | Exhibit 10.42 to the registrant's Form 10-KSB/A filed with the Commission on May 15, 2008. | ||||
10.14 | Exhibit 10.44 to the registrant's Form 10-KSB/A filed with the Commission on May 15, 2008. | ||||
10.15 | Exhibit 10.45 to the registrant's Form 10-KSB/A filed with the Commission on May 15, 2008. | ||||
10.16 | Exhibit 10.46 to the registrant's Form 10-KSB/A filed with the Commission on May 15, 2008. | ||||
10.17 | Exhibit 10.2 to the registrant's Form 10-Q filed with the Commission on August 14, 2008. | ||||
10.18 | Exhibit 10.3 to the registrant's Form 10-Q filed with the Commission on August 14, 2008. | ||||
10.19 | Exhibit 10.4 to the registrant's Form 10-Q filed with the Commission on August 14, 2008. | ||||
10.20 | Exhibit 10.1 to the registrant's Form 10-K filed with the Commission on February 26, 2009. | ||||
10.21 | Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on May 15, 2009. | ||||
10.22 | Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on August 14, 2009. | ||||
10.23 | Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on November 12, 2010. | ||||
10.24 | Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on May 16, 2011. | ||||
10.25 | Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on August 12, 2011. | ||||
53
10.26 | Exhibit 10.26 to the registrant's Form 10-K filed with the Commission on February 21, 2012. | ||||
10.27 | Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on November 9, 2012. | ||||
10.28 | Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on May 15, 2013. | ||||
10.29 | Exhibit 10.2 to the registrant's Form 10-Q filed with the Commission on May 15, 2013. | ||||
10.30 | Exhibit 10.3 to the registrant's Form 10-Q filed with the Commission on May 15, 2013. | ||||
10.31 | Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on August 14, 2013. | ||||
10.32 | Exhibit 10.32 to the registrant's Form 10-K filed with the Commission on February 27, 2014. | ||||
10.33 | Exhibit 10.33 to the registrant's Form 10-K filed with the Commission on February 27, 2014. | ||||
10.34 | Exhibit 10.34 to the registrant's Form 10-K filed with the Commission on February 27, 2014. | ||||
10.35 | Exhibit 10.35 to the registrant's Form 10-K filed with the Commission on February 27, 2014. | ||||
10.36 | Exhibit 10.36 to the registrant's Form 10-K filed with the Commission on February 27, 2014. | ||||
10.37 | Exhibit 99.1 to the registrant's Form 8-K filed with the Commission on May 16, 2014 | ||||
10.38 | Exhibit 10.1 to the registrant's Form 10-K filed with the Commission on August 12, 2014 | ||||
10.39 | Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on May 15, 2015 | ||||
10.40 | Exhibit 10.40 to the registrant's Form 10-K filed with the Commission on February 25, 2016. | ||||
10.41 | Exhibit 10.41 to the registrant's Form 10-K filed with the Commission on February 25, 2016. | ||||
10.42 | Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on November 14, 2016. | ||||
10.43 | Exhibit 10.43 to the registrant's Form 10-K filed with the Commission on March 3, 2017. | ||||
54
10.44 | Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on August 14, 2017. | ||||
10.45 | Exhibit 10.2 to the registrant's Form 10-Q filed with the Commission on August 14, 2017. | ||||
10.46 | Exhibit 10.3 to the registrant's Form 10-Q filed with the Commission on August 14, 2017. | ||||
10.47 | Exhibit 10.4 to the registrant's Form 10-Q filed with the Commission on August 14, 2017. | ||||
10.48 | Exhibit 10.5 to the Registrant's Form 10-Q filed with the Commission on August 14, 2017. | ||||
10.49 | Exhibit 10.49 to the Registrant's Form 10-K filed with the Commission on March 2, 2018. | ||||
10.50 | Exhibit 10.50 to the Registrant's Form 10-K filed with the Commission on February 22, 2019. | ||||
14.1 | Exhibit 14.1 to the registrant's Form 10-K filed with the Commission on February 26, 2009. | ||||
31.1 | X | ||||
31.2 | X | ||||
32.1 | X | ||||
32.2 | X | ||||
101 | The following financial information from Homeland Energy Solutions, LLC's Annual Report on Form 10-K for the fiscal year ended December 31, 2019, formatted in XBRL (eXtensible Business Reporting Language): (i) Balance Sheets as of December 31, 2019 and 2018, (ii) Statements of Operations for the fiscal years ended December 31, 2019, 2018 and 2017, (iii) Statements of Cash Flows for the fiscal years ended December 31, 2019, 2018 and 2017, (iv) Statement of Changes in Members' Equity, and (v) the Notes to Financial Statements.** | ||||
________________________________
(+) Confidential Treatment Requested.
(**) Furnished herewith.
ITEM 16. FORM 10-K SUMMARY
None.
55
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
HOMELAND ENERGY SOLUTIONS, LLC | |||
Date: | March 6, 2020 | /s/ James Broghammer | |
James Broghammer | |||
President and Chief Executive Officer (Principal Executive Officer) | |||
Date: | March 6, 2020 | /s/ Beth Eiler | |
Beth Eiler | |||
Chief Financial Officer (Principal Financial Officer) | |||
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
Date: | March 6, 2020 | /s/ Nick Bowdish | |
Nick Bowdish, Director | |||
Date: | March 6, 2020 | /s/ Patrick Boyle | |
Patrick Boyle, Vice Chairman and Director | |||
Date: | March 6, 2020 | /s/ Randy Bruess | |
Randy Bruess, Director | |||
Date: | March 6, 2020 | /s/ Steven Core | |
Steven Core, Chairman and Director | |||
Date: | March 6, 2020 | /s/ Mathew Driscoll | |
Mathew Driscoll, Secretary and Director | |||
Date: | March 6, 2020 | /s/ Leslie Hansen | |
Leslie Hansen, Director | |||
Date: | March 6, 2020 | /s/ Maurice Hyde | |
Maurice Hyde, Director | |||
Date: | March 6, 2020 | /s/ Chad Kuhlers | |
Chad Kuhlers, Director | |||
Date: | March 6, 2020 | /s/ Christine Marchand | |
Christine Marchand, Director | |||
56