ITEM 1A. RISK FACTORS.
This Annual Report on Form 10-K contains forward-looking information based on our current expectations. Because our business is subject to many risks and our actual results may differ materially from any forward-looking statements made by or on behalf of us, this section includes a discussion of important factors that could affect our business, operating results, financial condition and the trading price of Montauk common stock. You should carefully consider these risk factors, together with all of the other information included in this Annual Report on Form 10-K as well as our other publicly available filings with the SEC. Although the risks are organized by headings, and each risk is discussed separately, many are interrelated.
Operational Risks
Our renewable energy projects may not generate expected levels of output.
Landfills contain organic material whose decomposition causes the generation of gas consisting primarily of methane, which our RNG projects use to generate power or renewable natural gas, and carbon dioxide. The estimation of landfill gas production volume is an inexact process and dependent on many site-specific conditions, including the estimated annual waste volume, composition of waste, regional climate and the capacity and construction of the landfill. Production levels are subject to a number of additional risks, including a failure or wearing out of our or our landfill operators’, customers’ or utilities’ equipment; an inability to find suitable replacement equipment or parts; less than expected supply or quality of the project’s source of biogas and faster
than expected diminishment of such biogas supply; or volume disruption in our fuel supply collection system. Any extended interruption and/or volume disruption in the project’s operation, or failure of the project for any reason to generate the expected amount of output, could adversely affect our business and operating results. In addition, we have in the past, and may in the future, incur material asset impairment charges if any of our renewable energy projects incurs operational issues that indicate our expected future cash flows from the project are less than the project’s carrying value. Any such impairment charge could adversely affect our operating results in the period in which the charge is recorded.
In addition, in order to maximize collection of LFG, we will need to take various measures, such as drilling additional gas wells in the landfill to increase LFG collection, balancing the pressure on the gas field based on the data collected by the landfill operator from the gas wells to ensure optimum landfill gas utilization and ensuring that we match availability of engines and related equipment to availability of LFG. There can be no guarantee that we will be able to take all necessary measures to maximize collection. In addition, the LFG available to our projects is dependent in part on the actions of other persons, such as landfill operators. We may not be able to ensure the responsible management of the landfill site by owners and operators, which may result in less than optimal gas generation or increase the likelihood of “hot spots” occurring. Hot spots can temporarily reduce the volume of gas which may be collected from a landfill site, resulting in a lower gas yield. Other events that can result in a reduction in LFG output include: extreme hot or cold temperatures or excessive rainfall; liquid levels within a landfill increasing; oxidation within a landfill, which can kill the anaerobic microbes that produce landfill gas; and the buildup of sludge. The occurrence of these or any other changes within any of the landfills where our projects operate could lead to a reduction in the amount of LFG available to operate our projects, which could have a material adverse effect on our business, financial condition and results of operations.
The concentration in revenues from five of our projects and geographic concentration of our projects expose us to greater risks of production interruptions from severe weather or other interruptions of production or transmission.
A substantial portion of our revenues are generated from five project sites. For the years ended December 31, 2022 and 2021, excluding the effect of derivative instruments, approximately 72.4% and 76.3%, respectively, of operating revenues were derived from these locations. During 2022, RNG production at our McCarty, Rumpke, Atascocita and Apex facilities accounted for approximately 17.5%, 21.6%, 21.6%, and 10.2% of our RNG revenues, respectively, and 15.2%, 26.3%, 18.6%, and 9.5% of the RNG we produced during 2022,
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respectively. During 2022, Renewable Electricity production at our Bowerman Power LFG, LLC (“Bowerman”) facility accounted for approximately 90.5% of our Renewable Electricity Generation revenues and 82.3% of the Renewable Electricity we produced during 2022. A lengthy interruption of production or transmission of renewable energy from one or more of these projects, as a result of a severe weather event, failure or degradation of our or a landfill operator’s equipment or interconnection transmission problems could have a disproportionate effect on our revenues and cash flow as further described below.
Our Atascocita, McCarty, Galveston and Coastal Plains projects are located within 20 miles of each other near Houston, Texas and seven of our other RNG projects are located in relatively close proximity to each other in Pennsylvania and Ohio. Regional events, such as gas transmission interruptions, regional availability of replacement parts and service in the event of equipment failures and severe weather events in either of those geographic regions could adversely affect our RNG production and transmission more than if our projects were more geographically diversified. Historically cold weather impacted our Houston, Texas facilities during the winter of 2020-2021. Production at these facilities was temporarily idled from February 14, 2021 through February 20, 2021 while the facilities were without power. The index based pricing for the cost of utilities were adversely impacted during the month of February. Force majeure events were declared for the period February 12 through February 22, 2021 related to these weather events Operations at these facilities have subsequently resumed, but as a result of our utility provisions when we are not using utilities, providers are able to contribute the capacity back into the market and we receive credit against our future bills.
Additionally, California wildfires, which occurred in October of 2020, forced our Bowerman facility to temporarily shut down and caused limited damage to our facility and equipment. Production was reduced by approximately 38% at the Bowerman facility during the fourth quarter of 2020 as compared to the fourth quarter of 2019. While production resumed in November 2020, our first quarter of 2021 revenues related to the Bowerman facility were approximately 18.9% lower than the prior year period, related in part to these wildfires.
Our projects are not able to insure against all potential risks and may become subject to higher insurance premiums.
Our projects are exposed to the risks inherent in the construction and operation of renewable energy projects, such as breakdowns, manufacturing defects, extreme weather, natural disasters, terrorist attacks and sabotage. We are also exposed to environmental risks.
We have insurance policies covering certain risks associated with our business. Our insurance policies do not, however, cover all losses, including, in some situations, those as a result of force majeure, which is generally defined as events that are beyond the control of the parties. For example, we did not receive any insurance recovery from the shutdowns in Houston in February 2021 due to the extreme cold or from the Bowerman shutdown in October 2020 due to wildfires. Even if insurance policies for some of our projects cover losses as a result of certain types of force majeure events, such coverage is subject to important limitations. Furthermore, insurance liabilities are difficult to assess and quantify due to unknown factors, including the severity of an injury, the determination of our liability in proportion to other parties, the number of incidents not reported and the effectiveness of our safety program. Insurance coverage is not always available on commercially reasonable terms (if at all) and is often capped at predetermined limits. In addition, our insurance policies are subject to annual review by our insurers and may not be renewed on similar or favorable terms or at all. A serious uninsured loss or a loss significantly exceeding the limits of our insurance policies could adversely affect our business, financial condition and results of operations.
Competition Risks
We may face intense competition and may not be able to successfully compete.
There are a number of other companies operating in the renewable energy and waste-to-energy markets. These include other renewable energy companies and service or equipment providers, consultants, managers and strategic investors.
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We may not have the resources to compete with our existing competitors or with any new competitors, including in a competitive bidding process. Some of our competitors have significantly larger personnel, financial and managerial resources than we have, and we may fail to maintain or expand our business. Our competitors may also offer energy solutions at prices below cost, devote significant sales forces to competing with us or attempt to recruit our key personnel by increasing compensation, any of which could improve their competitive positions. Moreover, if the demand for renewable energy increases, new companies may enter the market, and the influx of added competition will pose an increased risk to us.
Further, certain of our strategic partners and other landfill or agricultural operators could decide to manage, recover and convert biogas from waste to renewable energy on their own which would further increase our competition, limit the number of commercially viable landfill sites available for our projects or require us to reduce our profit margins to maintain or acquire projects.
Our success depends, in part, on technological innovation to stay ahead of market competitors.
Our success will depend on our ability to create and maintain a competitive position in the renewable energy industry. Other than the patented technology acquired through the Montauk Ag Renewables Acquisition, we do not have any exclusive rights to any of the technologies that we utilize, and our competitors may currently use and may be planning to use identical, similar or superior technologies. While significant to the development associated with our emerging North Carolina Montauk Ag Renewables business, we do not currently consider the patented technology material to the total business. In addition, the technologies that we use may be rendered obsolete or uneconomical by technological advances, more efficient and cost-effective processes or entirely different approaches developed by one or more of our competitors or others.
We may also face competition based on technological developments that reduce demand for electricity, increase power supplies through existing infrastructure or that otherwise compete with our projects. We also encounter competition in the form of potential customers electing to develop solutions or perform services internally rather than engaging an outside provider such as us.
Our use and enjoyment of real property rights for our projects may be adversely affected by the rights of lienholders and leaseholders that are superior to those of the grantors of those real property rights to our projects.
Our projects generally are, and any of our future projects are likely to be, located on land occupied pursuant to long-term easements, leases and rights of way. The ownership interests in the land subject to these easements, leases and rights-of-way may be subject to mortgages securing loans or other liens (such as tax liens) and other easement, lease rights and rights-of-way of third parties (such as leases of oil or mineral rights) that were created prior to our projects’ easements, leases and rights-of-way. As a result, certain of our projects’ rights under these easements, leases or rights-of-way may be subject, and subordinate, to the rights of those third parties. We may not be able to protect our operating projects against all risks of loss of our rights to use the land on which our projects are located, and any such loss or curtailment of our rights to use the land on which our projects are located and any increase in rent due on such lands could adversely affect our business, financial condition and results of operations.
We may not be able to obtain long-term contracts for the sale of power produced by our projects on favorable terms and we may not meet certain milestones and other performance criteria under existing PPAs.
Obtaining long-term contracts for the sale of power produced by our projects at prices and on other terms favorable to us is essential for the long term success of our business. We must compete for PPAs against other developers of renewable energy projects. This intense competition for PPAs has resulted in downward pressure
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on PPA pricing for newly contracted projects. The inability to compete successfully against other power producers or otherwise enter into PPAs favorable to us would negatively affect our ability to develop and finance our projects and negatively affect our revenues. In addition, the availability of PPAs depends on utility and corporate energy procurement practices that could evolve and shift allocation of market risks over time. Further, PPA availability and terms are a function of a number of economic, regulatory, tax, and public policy factors, which are also subject to change.
Our PPAs typically require us to meet certain milestones and other performance criteria. Our failure to meet these milestones and other criteria, including minimum quantities, may result in price concessions, in which case we would lose any future cash flow from the relevant project and may be required to pay fees and penalties to our counterparty. We cannot assure you that we will be able to perform our obligations under such agreements or that we will have sufficient funds to pay any fees or penalties thereunder.
Business Strategy Risks
Our commercial success depends on our ability to identify, acquire, develop and operate individual renewable energy projects, as well as our ability to maintain and expand production at our current projects.
We aim to maintain and grow our position as a leading producer of RNG in the United States. Our specific focus on the renewable energy sector exposes us to risks related to the supply of and demand for energy commodities and Environmental Attributes, the cost of capital expenditures, government regulation, world and regional events and economic conditions, and the acceptance of alternative power sources. As a renewable energy producer, we may also be negatively affected by lower energy output resulting from variable inputs, mechanical breakdowns, faulty technology, competitive electricity markets or changes to the laws and regulations that mandate the use of renewable energy sources by refiners and importers of gasoline and diesel fuel and electric utilities.
In addition, several other factors related to the development and operation of individual renewable energy projects could adversely affect our business, including:
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Any of these factors could prevent us from completing or operating our projects, or otherwise adversely affect our business, financial condition and results of operations.
If there is not sufficient demand for renewable energy, or if renewable energy projects do not develop or take longer to develop than we anticipate, we may be unable to achieve our investment objectives.
If demand for renewable energy fails to grow sufficiently, we may be unable to achieve our business objectives. In addition, demand for renewable energy projects in the markets and geographic regions that we target may not develop or may develop more slowly than we anticipate. Many factors will influence the widespread adoption of renewable energy and demand for renewable energy projects, including:
• increases or decreases in the prices of oil, coal and natural gas;
• availability or effectiveness of government subsidies and incentives.
Acquisition, financing, construction and development of new projects and project expansions and conversions may not commence on anticipated timelines or at all.
Our strategy is to continue to expand in the future, including through the acquisition of additional projects. From time to time, we enter into nonbinding letters of intent for projects. However, until the negotiations are
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finalized and the parties have executed definitive documentation, we cannot assure you that we will be able to enter into any development or acquisition transactions, or any other similar arrangements, on the terms in the applicable letter of intent or at all.
The acquisition, financing, construction and development of new projects involves numerous risks, including:
• failure to obtain all necessary rights to land access and use;
• assumptions with respect to the cost and schedule for completing construction;
• the ability to obtain financing for a project on acceptable terms or at all;
• delays in deliveries or increases in the prices of equipment;
• increases in the cost of labor, labor disputes and work stoppages;
• failure to receive quality and timely performance of third-party services;
• unforeseen engineering and environmental problems;
• cost overruns;
• accidents involving personal injury or the loss of life; and
In addition, new projects have no operating history and may employ recently developed technology and equipment. A new project may be unable to fund principal and interest payments under its debt service obligations or may operate at a loss, which may adversely affect our business, financial condition or results of operations.
We may also experience delays and cost overruns in converting existing facilities from Renewable Electricity to RNG production. During the conversation projects, there is a gap in production and relating revenue while the electricity project is offline until it commences operation as an RNG facility, which adversely affects our financial condition and results of operations.
Our fuel supply agreements with site hosts have defined contractual periods, and we cannot assure you that we will be able to successfully extend these agreements.
Fuel supply rights are issued by the landfill owner to operators for a contractual period. As operators, we have already invested resources in the development of existing sites and the ability to extend these contracts on expiration would enable us to achieve operational efficiency in continuing to generate revenues from a site without significant additional capital investments. We cannot assure you that we will be able to extend existing fuel supply agreements when they expire.
Our agreements contain complex price adjustments, calculations and other terms based on gas price indices and other metrics, the interpretation of which could result in disputes with counterparties that could affect our results of operations and customer relationships.
Certain of our PPAs, fuel supply agreements, RNG off-take agreements and other agreements require us to make payments or adjust prices to counterparties based on past or current changes in gas price indices, project
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productivity or other metrics and involve complex calculations. Moreover, the underlying indices governing payments under these agreements are subject to change, may be discontinued or replaced. The interpretation of these price adjustments and calculations and the potential discontinuation or replacement of relevant indices or metrics could result in disputes with the counterparties with respect to these agreements. Any such disputes could adversely affect project revenues, expense margins, customer or supplier relationships, or lead to costly litigation, the outcome of which we would be unable to predict.
In order to secure contracts for new projects, we typically face a long and variable development cycle that requires significant resource commitments and a long lead time before we realize revenues.
The development, design and construction process for our renewable energy projects generally lasts from 18 to 36 months, on average. We frequently receive requests for proposals from potential site hosts as part of their consideration of alternatives for their proposed projects. Prior to responding to an RFP, we typically conduct a preliminary audit of the site host’s needs and assess whether the site is commercially viable based on our expected return on investment, investment payback period, and other operating metrics, as well as the necessary
permits to develop a project on that site. If we are awarded a project, we then perform a more detailed review of the site’s facilities, which serves as the basis for the final specifications of the project. Finally, we negotiate and execute a contract with the site host. This extended development process requires the dedication of significant time and resources from our sales and management personnel, with no certainty of success or recovery of our expenses. A potential site host may go through the entire sales process and not accept our proposal. Further, upon commencement of operations, it typically takes 12 months or longer for the project to ramp up to our expected production level. All of these factors, and in particular, increased spending that is not offset by increased revenues, can contribute to fluctuations in our quarterly financial performance and increase the likelihood that our operating results in a particular period will fall below investor expectations.
We plan to expand our business in part through developing RNG recovery projects at landfills and livestock farms, but we may not be able to identify suitable locations or complete development of new projects.
Historically, development of new RNG projects at landfills and livestock farms has been a significant part of our growth strategy. We plan to continue to develop new RNG projects at landfills and livestock farms to expand our project skillsets and capabilities, expand and complement our existing geographic markets, add experienced management and increase our product offerings. However, we may be unable to implement this growth strategy if we cannot identify suitable landfills and livestock farms on which to develop projects, reach agreements with landfill or livestock farm owners to develop RNG projects on acceptable terms or arrange required financing for new projects on acceptable terms. While the EPA has identified an additional 470 landfills as candidates for biogas projects, based on our industry experience and technical knowledge and analysis, after evaluating their currently available LFG collection systems and potential production capacities, we believe that approximately 38 of these sites produce sufficient quantities of LFG to support commercial-scale projects, with 25 of the approximately 38 sites being operated by Waste Management or Republic Waste, with whom we would need to negotiate with to secure sufficient LFG rights to support an RNG project. In the future, additional candidate landfills may become economically viable as their growth increases LFG production and requires installation of LFG collection systems. However, the time and effort involved in attempting to identify suitable sites and development of new projects may divert members of our management from our operations.
Our dairy farm project has, and any future digester project will have, different economic models and risk profiles than our landfill facilities, and we may not be able to achieve the operating results we expect from these projects.
Our dairy farm project produces significantly less RNG than our landfill facilities. As a result, we will be even more dependent on the LCFS credits and RINs produced at our dairy farm project than on the RINs produced at our landfill facilities for the project’s commercial viability. Since the number of LCFS credits for RNG generated on dairy farms is significantly greater than the number of LCFS credits for RNG generated at
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landfills, we are substantially more dependent upon the revenue from LCFS credits for the commercial viability of the dairy farm project. In the event that CARB worsens the CI score that it applies to waste conversion projects, such as dairy digesters, the number of LCFS credits for RNG generated at our dairy farm project will decline. Additionally, revenue from LCFS credits also depends on the price per LCFS credit, which is driven by various market forces, including the supply of and demand for LCFS credits, which in turn depends on the demand for traditional transportation fuel and the supply of renewable fuel from other renewable energy sources, and mandated CI targets, which determine the number of LCFS credits required to offset LCFS deficits, and which increase over time. Fluctuations in the price of LCFS credits or the number of LCFS credits assigned will have a significantly greater impact on the success of our dairy farm project than the value that RINs have on our landfill facilities. A significant decline in the value of LCFS credits could require us to incur an impairment charge on our dairy farm project and could adversely affect our business, financial condition and results of operations.
While we currently focus on converting methane into renewable energy, in the future we may decide to expand our strategy to include other types of projects. Any future energy projects may present unforeseen challenges and result in a competitive disadvantage relative to our more established competitors.
Our business is currently focused on converting methane into renewable energy. In the future, we may expand our strategy to include other types of projects. We cannot assure you that we will be able to identify attractive opportunities outside of our current area of focus or acquire or develop such projects at a price and on terms that are attractive or that, once acquired or developed, such projects will operate profitably. In addition, these projects could expose us to increased operating costs, unforeseen liabilities or risks, and regulatory and environmental concerns associated with entering into new sectors of the energy industry, including requiring a disproportionate amount of our management’s attention and resources, which could adversely affect our business, as well as place us at a competitive disadvantage relative to more established market participants. A failure to successfully integrate such new projects into our existing project portfolio as a result of unforeseen operational difficulties or otherwise, could adversely affect our business, financial condition and results of operations.
Any future acquisitions, investments or other strategic relationships that we make could disrupt our business, cause dilution to our stockholders or harm our business, financial condition or operating results.
We expect future acquisitions of companies, purchases of assets and other strategic relationships to be an important part of our growth strategy. We plan to use acquisitions to expand our capabilities, expand our geographic markets, add experienced management and add to our project portfolio. However, we may not be able to identify suitable acquisition or investment candidates, reach agreements with acquisition targets on acceptable terms or arrange for any required financing for an acquisition on acceptable terms, any of which would materially impact our present strategy. While we perform due diligence on prospective acquisitions, we may not be able to discover all potential operational deficiencies in such projects. Further, if we are successful in consummating acquisitions, those acquisitions could subject us to a number of risks, including:
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Any of these factors could adversely affect our business, financial condition and operating results.
Our renewable fuel projects may be exposed to the volatility of the price of RINs.
The price of RINs is driven by various market forces, including gasoline prices and the availability of renewable fuel from other renewable energy sources and conventional energy sources. Refiners are permitted to carry-over up to 20% RINs generated for one calendar year after the RINs are generated to satisfy their RVOs. As a result, we are only able to sell RINs on a forward basis for the year in which the RINs are generated and the following year. We may be unable to manage the risk of volatility in RIN pricing for all or a portion of our revenues from RINs, which would expose us to the volatility of commodity prices with respect to all or the portion of RINs that we are unable to sell through forward contracts, including risks resulting from changes in regulations, general economic conditions and changes in the level of renewable energy generation. We expect to have quarterly variations in the revenues from the projects in which we generate revenue from the sale of RINs that we are unable to sell through forward contracts.
Our revenues may be subject to the risk of fluctuations in commodity prices.
The operations and financial performance of projects in the renewable energy sectors may be affected by the prices of energy commodities, such as natural gas, wholesale electricity and other energy-related products. For example, the price of renewable energy resources changes in relation to the market prices of natural gas and electricity. The market price for natural gas is sensitive to cyclical demand and capacity supply, changes in weather patterns, natural gas storage levels, natural gas production levels, general economic and geopolitical conditions (including the current conflict in Ukraine) and the volume of natural gas imports and exports. The market price of electricity is sensitive to cyclical changes in demand and capacity supply, and in the economy and geopolitical conditions (including the current conflict in Ukraine), as well as to regulatory trends and developments impacting electricity market rules and pricing, transmission development and investment to power markets within the United States and in other jurisdictions through interconnects and other external factors outside of the control of renewable energy power-producing projects. Volatility of commodity prices also creates volatility in the prices of Environmental Attributes, which are inversely related to the wholesale price of unleaded gasoline. In addition, volatility of commodity prices, such as the market price of gas and electricity, may also make it more difficult for us to raise any additional capital for our renewable energy projects that may be necessary to operate, to the extent that market participants perceive that a project’s performance may be tied directly or indirectly to commodity prices. Accordingly, the potential revenues and cash flows of these projects may be volatile and adversely affect the value of our investments.
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Our off-take agreements for the sale of RNG are typically shorter in duration than our fuel supply agreements. Accordingly, if we are unable to renew or replace an off-take agreement for a project for which we continue to produce RNG, we would be subject to the risks associated with selling the RNG produced at that project at then-current market prices. We may be required to make such sales at a time when the market price for natural gas as a whole or in the region where that project is located, is depressed. If this were to occur, we would be subject to the volatility of gas prices and be unable to predict our revenues from such project, and the sales prices for such RNG may be lower than what we could sell the RNG for under an off-take agreement.
We are subject to volatility in prices of RINs and other Environmental Attributes.
Volatility of commodity prices creates volatility in the price of Environmental Attributes. The value of RINs is inversely proportionate to the wholesale price of unleaded gasoline. Further, the production of RINs significantly in excess of the RVOs set by the EPA for a calendar year could adversely affect the market price of RINs, particularly towards the end of the year, if refiners and other RFS obligated parties have satisfied their RVOs for the year. A significant decline in the price of RINs and price of LCFS credits for a prolonged period could adversely affect our business, financial condition and results of operations, and could require us to take an impairment charge relating to one or more of our projects.
We are exposed to the risk of failing to meet our contractual commitments to sell RINs from our production.
We may sell forward a portion of our RINs under contracts to fix the revenues from such attributes for financing purposes or to manage our risk against future declines in prices of such Environmental Attributes. If our RNG projects do not generate the amount of RINs sold under such forward contracts we may be required to make up the shortfall of RINs under such forward contracts through purchases on the open market or of the payment of liquidated damages. Forward selling our RINs could result in realized prices monetized in a year which do not correspond directly to index prices.
The failure of our hedge counterparties or significant customers to meet their obligations to us may adversely affect our financial results.
To the extent we hedge our RNG revenues, our hedging transactions expose us to the risk that a counterparty fails to perform under a derivative contract. Volatility in the market index to which we hedge our RNG revenues could expose us to variability in our commodity based revenues. Disruptions in the financial markets could lead to sudden decreases in a counterparty’s liquidity, which could make them unable to perform under the terms of the derivative contract and we may not be able to realize the benefit of the derivative contract. Any default by the counterparty to these derivative contracts could adversely affect our business, financial condition and results of operations.
We also face credit risk because we sell our RNG to a limited number of significant customers who do not post collateral. The inability or failure of our significant customers to meet their obligations to us or their insolvency or liquidation may adversely affect our financial results.
Regulatory Risks
The reduction or elimination of governmental economic incentives for renewable energy projects or other related policies could adversely affect our business, financial condition and results of operation.
We depend, in part, on Environmental Attributes, which are federal, state and local government incentives in the United States, provided in the form of RINs, RECs, LCFS credits, rebates, tax credits and other incentives to end users, distributors, system integrators and manufacturers of renewable energy projects, that promote the use of renewable energy. RINs are created through the RFS program administered by the EPA, which requires transportation fuel sold in the United States to contain a minimum volume of renewable fuel and has historically
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permitted refineries and importers of transportation fuel to satisfy their RVOs by purchasing either (i) D5 RINs and cellulosic waiver credits (“CWCs”) or (ii) D3 RINs. In a December 1, 2022 proposed rule, EPA proposed to not utilize its cellulosic waiver authority for the years 2023-2025. However, if actual production is lower than the RVO, the EPA will have discretion to utilize CWC. RECs are created through state law requirements for utilities to purchase a portion of their energy from renewable energy sources. 70% and 62% of our operating revenues for 2022 and 2021, respectively, were generated from the sale of Environmental Attributes. These government economic incentives could be reduced or eliminated altogether, or the categories of renewable energy qualifying for such government economic incentives could be changed. These renewable energy program incentives are subject to regulatory oversight and could be administratively or legislatively changed in a manner that could adversely affect our operations. Further, the generation of LCFS credits on our dairy farm project is expected to increase the percentage of our revenues generated from Environmental Attributes. Reductions in, changes to, or eliminations or expirations of governmental incentives could result in decreased demand for, and lower revenues from, our projects. Changes in the level or structure of the RPS of a state for electricity could also result in a decline in our revenues or decreased demand for, and lower revenues from, our electricity projects.
We may be unable to obtain, modify or maintain the regulatory permits, approvals and consents required to construct and operate our projects.
Our operations are subject to various federal, state and local EHS laws and regulations, including those relating to the release, emission or discharge of materials into the air, water and ground, the generation, storage,
handling, use, transportation and disposal of hazardous materials and wastes, the health and safety of our employees and other persons, and the generation of RINs and LCFS credits.
These laws and regulations impose numerous obligations applicable to our operations, including the acquisition of permits before construction and operation of our projects; the restriction of types, quantities and concentration of materials that can be released into the environment; the limitation or prohibition of our activities on certain lands lying within wilderness, wetlands and other protected areas; the application of specific health and safety criteria addressing worker protection; and the imposition of substantial liabilities for pollution resulting from the ownership or operation of our properties. These laws, regulations and permits can require expensive pollution control equipment or operational changes to limit actual or potential impacts to the environment.
Numerous governmental entities have the power to enforce difficult and costly compliance measures or corrective actions pursuant to these laws and regulations and the permits issued under them. We may be required to make significant capital and operating expenditures on an ongoing basis, or to perform remedial or other corrective actions at our properties, to comply with the requirements of these environmental laws and regulations or the terms or conditions of our permits. Failure to comply with these laws and regulations may result in the assessment of sanctions, including administrative, civil or criminal penalties, the imposition of investigatory or remedial obligations, and the issuance of orders limiting or prohibiting some or all of our operations. In addition, we may experience delays in obtaining or be unable to obtain required environmental regulatory permits or approvals, which may delay or interrupt our operations and limit our growth and revenue.
Our operations inherently risk incurring significant environmental costs and liabilities due to the need to manage waste from our processing facilities. Spills or other releases of regulated substances, including spills and releases that occur in the future, could expose us to material losses, expenditures and liabilities under applicable environmental laws, rules and regulations. Under certain of such laws and regulations, we could be held strictly liable for the removal or remediation of previously released materials or property contamination, regardless of whether we were responsible for the release or contamination and even if our operations met previous standards in the industry at the time they were conducted. In connection with certain acquisitions, we could acquire, or be required to provide indemnification against, environmental liabilities that could expose us to material losses. In addition, claims for damages to persons or property, including natural resources, may result from the EHS impacts of our operations. Our insurance may not cover all environmental risks and costs or may not provide sufficient coverage if an environmental claim is made against us.
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New laws, changes to existing laws, new interpretations of existing laws, increased governmental enforcement of environmental laws or other developments could require us to make significant additional expenditures. Continued government and public emphasis on environmental issues can be expected to result in increased future investments for environmental controls at our plants. Present and future environmental laws and regulations, and interpretations of those laws and regulations, applicable to our operations, more vigorous enforcement policies and discovery of currently unknown conditions may require substantial expenditures that could have a material adverse effect on our results of operations and financial condition. In January 2021, President Biden issued an executive order directing all federal agencies to review and take action to address any federal regulations, orders, guidance documents, policies, and any similar agency actions promulgated during the prior administration that may be inconsistent with the current administration’s policies and to address climate change. The federal agencies review of previous agency actions remain ongoing. In January 2021, President Biden also issued an executive order solely targeting climate change. Pursuant to these executive orders, on February 19, 2021 the United States formally rejoined the Paris Climate Agreement, an international treaty that provides for the cutting of carbon emissions every five years, beginning in 2023. In August 2022, President Biden signed into law the Inflation Reduction Act, which includes incentives for development and production of renewable energy. These incentives include grants, loan guaranties, development funding, investment tax credits, and production tax credits. At this time, we cannot predict the outcome of any of these executive actions on our operations.
Our ability to generate revenue from sales of RINs and LCFS credits depends on our strict compliance with these federal and state programs, which are complex and can involve a significant degree of judgment. If the agencies that administer and enforce these programs disagree with our judgments, otherwise determine that we
are not in compliance, conduct reviews of our activities or make changes to the programs, then our ability to generate or sell these credits could be temporarily restricted pending completion of reviews or as a penalty, permanently limited or lost entirely, and we could also be subject to fines or other sanctions. Moreover, the inability to sell RINs and LCFS credits could adversely affect our business.
In order to construct, modify and operate our projects, we will need to obtain or may need to modify numerous environmental and other regulatory permits, approvals and consents from federal, state and local governmental entities, including air permits, wastewater discharge permits, stormwater permits, permits or consents related to the management of municipal solid waste landfills and permits or consents related to the management and disposal of waste. A number of these permits, approvals and consents must be obtained prior to the start of development of a project. Other permits, approvals and consents are required to be obtained at, or prior to, the time of first commercial operation or within prescribed time frames following commencement of commercial operations. Any failure to successfully obtain or modify the necessary environmental and other regulatory permits, approvals and consents on a timely basis could delay the construction, modification or commencement of commercial operation of our projects. In addition, once a permit, approval or consent has been issued or acquired for a project, we must take steps to comply with the conditions of each permit, approval or consent conditions, including conditions requiring timely development and commencement of the project. Failure to comply with certain conditions within a permit, approval or consent could result in the revocation or suspension of such permit, approval or consent; the imposition of penalties; or other enforcement action by governmental entities. We also may need to modify permits, consents or approvals we have already obtained to reflect changes in project design or requirements, which could trigger a legal or regulatory review under a standard more stringent than the standard under which the permits, approvals or consents were originally issued.
Obtaining and modifying necessary permits, approvals and consents is a time-consuming and expensive process, and we may not be able to obtain or modify them on a timely or cost effective basis or at all. In the event that we fail to obtain or modify all necessary permits, approvals or consents, we may be forced to delay construction or operation of a project or abandon the project altogether, which could adversely affect our business, financial condition and results of operations. In addition, we may be required to make capital expenditures on an ongoing basis to comply with increasingly stringent federal, state, provincial and local EHS laws, regulations and permits.
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Negative attitudes toward renewable energy projects from the U.S. government, other lawmakers and regulators, and activists could adversely affect our business, financial condition and results of operations.
Parties with an interest in other energy sources, including lawmakers, regulators, policymakers, environmental and advocacy organizations or other activists may invest significant time and money in efforts to delay, repeal or otherwise negatively influence regulations and programs that promote renewable energy. Many of these parties have substantially greater resources and influence than we have. Further, changes in U.S. federal, state or local political, social or economic conditions, including a lack of legislative focus on these programs and regulations, could result in their modification, delayed adoption or repeal. Any failure to adopt, delay in implementing, expiration, repeal or modification of these programs and regulations, or the adoption of any programs or regulations that encourage the use of other energy sources over renewable energy, could adversely affect our business, financial condition and results of operations.
In addition, in June 2019, the EPA issued the final Affordable Clean Energy (“ACE”) rule and repealed the Clean Power Plan (the “CPP”), which had previously established standards to limit carbon dioxide emissions from existing fossil-fueled power generation facilities. Under the ACE rule, emissions from electric utility generation facilities would be regulated only through the use of various “inside the fence” or onsite efficiency improvements and emission control technologies. In contrast, the CPP allowed facility owners to reduce emissions with “outside the fence” measures, including those associated with renewable energy projects. On January 19, 2021, the United States Court of Appeals for the D.C. Circuit vacated the ACE rule and remanded the rule back to EPA for reconsideration of the “best system of emission reduction.” On February 22, 2021, the
D.C. Circuit subsequently issued an order allowing EPA to promulgate new standards in lieu of reviving the CPP. In June 2022, the U.S. Supreme Court reversed the D.C. Circuit’s decision on the Affordable Clean Energy rule and remanded the case back to the D.C. Circuit. The U.S. Supreme Court restricted the EPA’s authority to regulate GHG from existing power plants under Section 111(d). The U.S. Supreme Court concluded that Congress did not grant the EPA authority under the CAA to demand generation-shifting to achieve reduction of GHG emissions, but the court did not hold that the EPA is limited in future rulemakings to just the heat-rate improvements that made up the ACE rule. We are unable to predict the future course of the litigation on remand, nor the direction that the EPA may take in the future to regulate GHG emissions from existing fossil fuel-fired generation facilities. On August 16, 2022, President Biden signed into law the Inflation Reduction Act, which includes an amendment to the CAA defining GHGs as air pollutants. On September 8, 2022, the EPA announced the opening of a non-rulemaking docket for public comments on the EPA’s efforts to reduce GHG emissions from existing fossil-fuel fired electric generating units. Comments may be submitted to the EPA until March 27, 2023. The impact of the disposition of this litigation or a new rule regulating GHG emissions on our operations is unclear.
Revenue from any projects we complete may be adversely affected if there is a decline in public acceptance or support of renewable energy, or regulatory agencies, local communities, or other third parties delay, prevent, or increase the cost of constructing and operating our projects.
Certain persons, associations and groups could oppose renewable energy projects in general or our projects specifically, citing, for example, misuse of water resources, landscape degradation, land use, food scarcity or price increase and harm to the environment. Moreover, regulation may restrict the development of renewable energy plants in certain areas. In order to develop a renewable energy project, we are typically required to obtain, among other things, environmental impact permits or other authorizations and building permits, which in turn require environmental impact studies to be undertaken and public hearings and comment periods to be held during which any person, association or group may oppose a project. Any such opposition may be taken into account by government officials responsible for granting the relevant permits, which could result in the permits being delayed or not being granted or being granted solely on the condition that we carry out certain corrective measures to the proposed project. Opposition to our projects’ requests for permits or successful challenges or appeals to permits issued for our projects could adversely affect our operating plans.
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As a result, we cannot guarantee that the renewable energy plants we currently plan to develop or, to the extent applicable, are developing, will ultimately be authorized or accepted by the local authorities or the local population. For example, the local population could oppose the construction of a renewable energy plant or infrastructure at the local government level, which could in turn lead to the imposition of more restrictive requirements. This type of negative response may lead to legal, public relations or other challenges that could impede our ability to meet our construction targets, achieve commercial operations for a project on schedule, address the changing needs of our projects over time or generate revenues.
In certain jurisdictions, if a significant portion of the local population were to mobilize against a renewable energy plant, it may become difficult, or impossible, for us to obtain or retain the required building permits and authorizations. Moreover, such challenges could result in the cancellation of existing building permits or even, in extreme cases, the dismantling of, or the retroactive imposition of changes in the design of, existing renewable energy plants.
Authorization for the use, construction, and operation of systems and associated transmission facilities on federal, state, and local lands will also require the assessment and evaluation of mineral rights, private rights-of-way, and other easements; environmental, agricultural, cultural, recreational, and aesthetic impacts; and the likely mitigation of adverse effects to these and other resources and uses. The inability to obtain the required permits and other federal, state and local approvals, and any excessive delays in obtaining such permits and approvals due, for example, to litigation or third-party appeals, could potentially prevent us from successfully constructing and operating such projects in a timely manner and could result in the potential forfeiture of any deposit we have made with respect to a given project. Moreover, project approvals subject to project modifications and conditions, including mitigation requirements and costs, could affect the financial success of a given project. Changing regulatory requirements and the discovery of unknown site conditions could also adversely affect the financial success of a given project.
A decrease in acceptance of renewable energy plants by local populations, an increase in the number of legal challenges, or an unfavorable outcome of such legal challenges could adversely affect our business, financial condition and results of operations. We may also be subject to labor unavailability due to multiple
simultaneous projects in a geographic region. If we are unable to grow and manage the capacity that we expect from our projects in our anticipated timeframes, it could adversely affect our business, financial condition and results of operations.
Existing regulations and policies, and future changes to these regulations and policies, may present technical, regulatory and economic barriers to the generation, purchase and use of renewable energy, and may adversely affect the market for credits associated with the production of renewable energy.
The market for renewable energy is influenced by U.S. federal, state and local government regulations and policies concerning renewable energy. These regulations and policies are continuously being modified, which could result in a significant future reduction in the potential demand for renewable energy, including RINs, RECs and LCFS credits, renewable energy project development and investments. Renewable Fuel Standards for 2023 through 2025 remain subject to finalization. Any new government regulations applicable to our renewable energy projects or markets for renewable energy may result in significant additional expenses or related development costs and, as a result, could cause a significant reduction in demand for our renewable energy. For additional information on regulatory developments, see “Item 7A.—Management’s Discussion and Analysis of Financial Condition and Results of Operations —Key Trends—Regulatory, Environmental and Social Trends.”
In order to benefit from RINs and LCFS credits, our RNG projects are required to be registered and are subject to regulatory audit.
We are required to register an RNG project with the EPA and relevant state regulatory agencies. Further, we qualify our RINs through a voluntary Quality Assurance Plan, which typically takes from three to five months
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from first injection of RNG into the commercial pipeline system. Although no similar qualification process currently exists for LCFS credits, we expect such a process to be implemented and would expect to seek qualification on a state-by-state basis under such future programs. Changes to the LCFS program require annual verification of the CI score assigned to a project. Annual verification could significantly affect the profitability of a project, particularly in the case of a livestock farm project. Delays in obtaining registration, RIN qualification, and any future LCFS credit qualification, or CI rescoring through CARB annual audits, of a new project could delay future revenues from the project and could adversely affect our cash flow. Further, we typically make a large investment in the project prior to receiving the regulatory approval and RIN qualification. By registering each RNG project with the EPA’s voluntary Quality Assurance Plan, we are subject to quarterly third-party audits and semi-annual on-site visits of our projects to validate generated RINs and overall compliance with the RFS program. We are also subject to a separate third party’s annual attestation review. The Quality Assurance Plan provides a process for RIN owners to follow, for an affirmative defense to civil liability, if used or transferred Quality Assurance Plan verified RINs were invalidly generated. A project’s failure to comply could result in remedial action by the EPA, including penalties, fines, retirement of RINs, or termination of the project’s registration, any of which could adversely affect our business, financial condition and results of operations. For additional information on recent developments in this area, including the Pico facility’s CI score, see “Item 7A.—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Key Trends—Regulatory, Environmental and Social Trends.”
Our business is subject to the risk of extreme or changing weather patterns.
Extreme weather patterns related to climate change could cause changes in rainfall and storm patterns and intensities, water shortages and changing temperatures, which could result in significant volatility in the supply and prices of energy. In addition, legislation and increased regulation regarding climate change could impose significant costs on us and our suppliers, including costs related to capital equipment, environmental monitoring and reporting and other costs to comply with such regulations.
Furthermore, extreme weather events, such as lightning strikes, ice storms, tornados, extreme wind, hurricanes and other severe storms, wildfires and other unfavorable weather conditions or natural disasters, such as floods, fires, earthquakes, and rising sea-levels, could adversely affect the input and output commodities associated with the renewable energy sector. Such weather events or natural disasters could also require us to temporarily or permanently shut down the equipment associated with our renewable energy projects, such as our access to power and our power to biogas collection, separation and transmission systems, which would impede the ability of our projects to operate and decrease production levels and our revenue. Operational problems, such as degradation of our project’s equipment due to wear or weather or capacity limitations or outages on the electrical transmission network, could also affect the amount of energy that our projects are able to deliver. Any of these events, to the extent not fully covered by insurance, could adversely affect our business, financial condition and results of operations
These events could result in significant volatility in the supply and prices of energy. This volatility may create fluctuations in commodity or energy prices and earnings of companies in the renewable energy sectors. See “—Operational Risks—“The concentration in revenues from five of our projects and geographic concentration of our projects expose us to greater risks of production interruptions from severe weather or other interruptions of production or transmission” for additional information.
Our business is subject to risks arising out of climate change, which could result in increased operating costs.
Numerous proposals have been made and are likely to continue to be made at the international, national, regional and state levels of government to monitor and limit existing emissions of GHGs and eliminate future GHG emissions. Governmental and public concern arising from GHG emissions has resulted in increasing regulatory, political, financial and litigation risks in the United States and globally that target predominantly fossil fuel-related energy entities or their operations, which may have indirect effects on other companies or industries, including the renewable energy industry.
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In the United States, no comprehensive federal climate change legislation has been implemented. The EPA has adopted rules that, among other things, establish permit reviews for GHG emissions from certain large stationary sources, require the monitoring and annual reporting of GHG emissions from specified sources in the U.S., implement standards reducing emissions of methane, a form of GHG, from specified oil and gas sectors, and together with the U.S. Department of Transportation, implement GHG emissions limits on vehicles manufactured for operation in the United States. While these rules largely do not directly impact our operations, they do represent a concerted effort at the federal level to reduce emissions of GHGs in an effort to mitigate adverse effects associated with climate change, which could in turn result in increased demand for renewable energy.
Additionally, in August 2022 the Inflation Reduction Act of 2022 was signed into law, which appropriates significant federal funding for renewable energy initiatives and, for the first time ever, imposes a fee on GHG emissions from certain facilities in the oil and natural gas sector. The emissions fee and renewable and low carbon energy funding provisions of the law could accelerate the transition away from fossil fuels, which could in turn have an indirect adverse effect on our business and results of operations. Under the Biden Administration, it is anticipated that efforts by the EPA or other federal agencies to restrict GHG emissions will continue. Additionally, various states and groups of states have adopted or are considering adopting legislation, regulations or other regulatory initiatives that are focused on such areas as GHG cap and trade programs, carbon taxes, reporting and tracking programs, and restriction of emissions. As a result, there exists the possibility of executive orders being issued or federal legislation or regulatory initiatives being adopted that could result in further restrictions on fossil fuels and have a further indirect effect on the demand for renewable energy and our products.
Cybersecurity and Information Technology Risks
A failure of our IT and data security infrastructure could have a material adverse effect on our business and operations.
We rely upon the capacity, reliability and security of our IT and data security infrastructure and our ability to expand and continually update this infrastructure in response to the changing needs of our business. Our existing IT systems and any new IT systems may not perform as expected. We also face the challenge of supporting our older systems and implementing necessary upgrades. If we experience a problem with the functioning of an important IT system or a security breach of our IT systems, including during system upgrades or new system implementations, the resulting disruptions could have a material adverse effect on our business.
We and some of our third-party vendors receive and store personal information in connection with our human resources operations and other aspects of our business. Despite our implementation of reasonable security measures, our IT systems, like those of other companies, are vulnerable to damages from computer viruses, natural disasters, fire, power loss, telecommunications failures, personnel misconduct, human error, unauthorized access, physical or electronic security breaches, cyber-attacks (including malicious and destructive code, phishing attacks, ransomware, and denial of service attacks), and other similar disruptions. Such attacks or security breaches may be perpetrated by bad actors internally or externally (including computer hackers, persons involved with organized crime, or foreign state or foreign state-supported actors). Cybersecurity threat actors employ a wide variety of methods and techniques that are constantly evolving, increasingly sophisticated, and difficult to detect and successfully defend against. Cybersecurity incidents could expose us to claims, litigation, regulatory or other governmental investigations, administrative fines and potential liability. Any system failure, accident or security breach could result in disruptions to our operations. A material network breach in the security of our IT systems could include the theft of our trade secrets, customer information, human resources information or other confidential data, including but not limited to personally identifiable information, that could have a material adverse effect on our business, financial condition, or results of operations. To the extent that any material disruptions or security breaches result in a loss or damage to our data, or an inappropriate disclosure of
confidential, proprietary or customer information, it could materially cause damage to our reputation, affect our
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relationships with our customers and strategic partners, lead to claims against us from governments and private plaintiffs, and ultimately have a material adverse effect on our business. While we have been the previous target of cyberattacks and security breaches, none of these attacks or breaches to date have had a material adverse effect on the Company. We cannot guarantee that future cyberattacks, if successful, will not have a material effect on our business or financial results.
Many governments have enacted laws requiring companies to provide notice of cyber incidents involving certain types of data, including personal data. Any compromise of our security could result in a violation of applicable domestic and foreign security, privacy or data protection, consumer and other laws, regulatory or other governmental investigations, enforcement actions, and legal and financial exposure, including potential contractual liability that could have a material adverse effect on our business. In addition, we may be required to incur significant costs to protect against and remediate damage caused by these disruptions or security breaches in the future that could have a material adverse effect on our business.
We rely on the technology, infrastructure, and software applications of certain third parties in order to host or operate some of our business. Additionally, we rely on computer hardware purchased in order to operate our business. We do not have control over the operations of the facilities of the third parties that we use. If any of these third-party services experience errors, disruptions, security issues, or other performance deficiencies, if these services, software, or hardware fail or become unavailable due to extended outages, interruptions, defects, or otherwise, or if they are no longer available on commercially reasonable terms or prices (or at all), these issues could result in material errors or defects in our platforms (including causing our platforms to fail), our revenue and margins could materially decline, or our reputation and brand to be materially damaged. Additionally, we could be exposed to material legal or contractual liability, our expenses could materially increase, our ability to manage our operations could be materially interrupted, and our processes for servicing our customers could be materially impaired until equivalent services or technology, if available, are identified, procured, and implemented, all of which may take significant time and resources, increase our costs, and could materially and adversely affect our business. Many of these third-party providers that attempt to impose limitations on their liability for such errors, disruptions, defects, performance deficiencies, or failures, and if enforceable, we may have additional liability to our customers or third-party providers that could have a material adverse effect on our business. A failure to maintain our relationships with our third-party providers (or obtain adequate replacements), and to receive services from such providers that do not contain any material errors or defects, could adversely affect our ability to deliver effective products and solutions to our customers and adversely affect our business and results of operations.
Our business could be negatively affected by security threats, including cybersecurity threats and other disruptions.
As a renewable energy producer, we face various security threats, including among others, computer viruses, malware, telecommunication and electrical failures, cyber-attacks or cyber-intrusions over the internet, attachments to emails, persons with access to systems inside our organization, cybersecurity threats to gain unauthorized access to sensitive information or to expose, exfiltrate, alter, delete or render our data or systems unusable, threats to the security of our projects and infrastructure or third-party facilities and infrastructure, such as processing projects and pipelines, natural disasters, threats from terrorist acts and war.
We take various steps to identify and mitigate potential cybersecurity threats. As cyber incidents become more frequent and the sophistication of threat actors increases, our associated cybersecurity costs are expected to increase. Specifically, we expect to implement several incremental cybersecurity improvements over the next 18 to 36 months to enhance our defensive capabilities and resilience. Despite our ongoing and anticipated cybersecurity efforts, a successful cybersecurity incident could lead to additional material costs, including those related to the loss of sensitive information, repairs to infrastructure or capabilities essential to our operations, responding to litigation or regulatory investigations, and those related to a material and adverse impact on our reputation, financial position, results of operations, or cash flows.
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Our implementation of various procedures and controls to monitor and mitigate these security threats, and to increase security for our information projects and infrastructure, may result in materially increased capital and operating costs. Moreover, there can be no assurance that such procedures and controls will be sufficient to prevent security breaches from occurring. Cybersecurity attacks, in particular, are becoming more sophisticated and include, but are not limited to, malicious software, attempts to gain unauthorized access to data and systems and other electronic security breaches that could lead to disruptions in critical systems, unauthorized release of confidential or otherwise protected information, and corruption of data. These events could lead to financial losses from remedial actions, loss of business or potential liability which can have a material adverse effect on our business and results of operations.
Third-Party Partner Risks
Failure of third parties to manufacture quality products or provide reliable services in a timely manner could cause delays in developing and operating our projects, which could damage our reputation, adversely affect our partner relationships or adversely affect our growth.
Our success depends on our ability to develop and operate projects in a timely manner, which depends in part on the ability of third parties to provide us with timely and reliable products and services. In developing and operating our projects, we rely on products meeting our design specifications and components manufactured and supplied by third parties, and on services performed by subcontractors. We also rely on subcontractors to perform substantially all of the construction and installation work related to our projects, and we often need to engage subcontractors with whom we have no experience.
If any of our subcontractors are unable to provide services that meet or exceed our customers’ expectations or satisfy our contractual commitments, our reputation, business and operating results could be harmed. In addition, if we are unable to avail ourselves of warranties and other contractual protections with providers of products and services, we may incur liability to our customers or additional costs related to the affected products and services, which could adversely affect our business, financial condition and results of operations. Moreover, any delays, malfunctions, inefficiencies or interruptions in these products or services could adversely affect the quality and performance of our projects and require considerable expense to maintain and repair our projects. This could cause us to experience interruption in our production and distribution of renewable energy and generation of related Environmental Attributes, difficulty retaining current relationships and attracting new relationships, or harm our brand, reputation or growth.
Our projects rely on interconnections with and access to electric distribution and transmission facilities and gas transportation pipelines that are owned and operated by third parties, and as a result, are exposed to risks related to such facilities’ development and operational curtailment risks.
Our projects are interconnected with electric distribution and transmission facilities owned and operated by regulated utilities necessary to deliver the Renewable Electricity that we produce. Our RNG projects are similarly interconnected with gas distribution and interstate pipeline systems required to deliver RNG A failure or delay in the operation or development of these distribution or transmission facilities could result in a loss of revenues or breach of contract because such a failure or delay could limit the amount of RNG and Renewable Electricity that our operating projects deliver or delay the completion of our construction projects. In addition, certain of our operating projects’ generation may be curtailed without compensation due to distribution and transmission limitations, reducing our revenues and impairing our ability to capitalize fully on a particular project’s potential. Such a failure or curtailment at levels above our expectations could impact our ability to satisfy our supply agreements and adversely affect our business. Additionally, we experience work interruptions from time to time due to federally required maintenance shutdowns.
We may acquire projects with their own interconnections to available transmission and distribution networks. In some cases, these projects may cover significant distances. A failure in our operation of these
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projects that causes the projects to be temporarily out of service, or subject to reduced service, could result in lost revenues because it could limit the amount of Renewable Electricity and RNG our operating projects are able to deliver.
We are dependent upon our relationships with Waste Management and Republic Services for the operation and maintenance of landfills on which several of our RNG and Renewable Electricity projects operate.
We currently operate eight renewable energy projects (seven RNG projects and one Renewable Electricity project) on landfills operated by Waste Management and two RNG projects on landfills operated by Republic Services. Our projects located on Waste Management and Republic Services operated landfills represented a significant proportion of our revenue in 2022. We are dependent upon Waste Management and Republic Services to operate and maintain their landfill facilities and provide a continuous supply of waste for conversion to RNG and Renewable Electricity. Further, we consider our relationship with these landfill operators an important factor in our growth strategy for additional projects. In the event that we fall out of favor with either of these landfill operators due to a dispute, problems with our operations at one of their facilities or otherwise, the landfill operator may seek to terminate the related project and be less inclined to work with us on future projects.
Additionally, Waste Management and Republic Services could seek to develop their own waste-to-renewable energy conversion projects at other existing landfill locations in lieu of contracting with us for these projects. Failure to maintain these favorable relationships could adversely affect our business, growth strategy, financial condition and results of operations.
We have significant customer concentration, with a limited number of customers accounting for a substantial portion of our revenues.
For 2022, sales to ExxonMobil, Valero, and the City of Anaheim represented approximately 32.0%, 17.0%, and 7.6%, respectively of our operating revenues. For 2021, sales to Victory Renewables, LLC, Valero, and City of Anaheim represented approximately 13.1%, 12.4%, and 9.6%, respectively of our operating revenues. Five customers made up approximately 69% and 68% of our accounts receivable as of December 31, 2022 and 2021, respectively. Revenues from our largest customers may fluctuate from time to time based on our customers’ business needs, market conditions or other factors outside of our control. If any of our largest customers terminates its relationship with us, such termination could adversely affect our revenues and results of operations.
Capital and Credit Risks
Our senior credit facility may not be sufficient to meet our financial needs and contains financial and operating restrictions that may limit our business activities and our access to other forms of credit.
Our senior credit facility consists of an $80.0 million principal amount term loan, of which $72.0 remains outstanding as of December 31, 2022, and a $120.0 million revolving credit line, which is undrawn as of December 31, 2022. This facility may not be sufficient to meet our financial needs as our business grows. The senior credit facility matures in December 2026 and we may be unable to extend or replace it on acceptable terms, or at all. Furthermore, the credit agreement governing our facility (the “Amended Credit Agreement”) imposes business restrictions and contains other covenants that require us to meet specified financial ratios and financial tests. Under the Amended Credit Agreement, we are required to maintain:
• a fixed charge coverage ratio of at least 1.20 to 1.00; and
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The Amended Credit Agreement is subject to customary events of default, and contemplates that we would be in default if, for any fiscal quarter (x) the average monthly D3 RIN price is less than $0.80 per RIN and (y) the consolidated EBITDA for such quarter is less than $6.0 million. Additional information regarding the senior credit facility and the Amended Credit Agreement can be found in Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources.”
Our failure to comply with these covenants could result in the declaration of an event of default and cause us to be unable to borrow under the Amended Credit Agreement. In addition to preventing additional borrowings under the Amended Credit Agreement, an event of default, if not cured or waived, could result in the acceleration of the maturity of indebtedness outstanding under the facility, which would require us to immediately repay all amounts outstanding. If an event of default occurs, we may not be able to cure it within any applicable cure period, or at all. As of December 31, 2022, we were in compliance with all covenants.
Variable rate indebtedness under our Amended Credit Agreement may adversely affect our business, financial condition and results of operations.
Borrowings under our Amended Credit Agreement are at variable rates of interest, particularly the Bloomberg Short-Term Bank Yield Index Rate (“BSBY”), which will fluctuate with changing market conditions. If BSBY increases, our interest expense will mechanically increase, which could adversely affect our cash flow and our ability to service our indebtedness and fund our operations. Additionally, BSBY is one of a relatively new series of reference rates, and certain regulatory authorities have indicated that BSBY may suffer from the same or similar deficiencies that LIBOR suffered from. Therefore, based on its limited historical performance and other available information, the future performance of BSBY cannot be accurately predicted, which could result in increases in our interest expense that may adversely impact the amount of interest payments under the Amended Credit Agreement.
We may be required to write-off or impair capitalized costs or intangible assets in the future or we may incur restructuring costs or other charges, each of which would harm our earnings.
In accordance with GAAP, we capitalize certain expenditures and advances relating to our acquisitions, pending acquisitions, project development costs, interest costs related to project financing and certain energy assets. In addition, we have considerable unamortized assets. In 2022, we recorded impairment charges of $2.1 million related to our estimate of future cash flows no exceeding the carrying amount of an Renewable Electricity facility and discrete charges of $1.4 million and $1.1 million related to the ongoing development of the Montauk Ag Renewables and an asset component of an RNG facility. In 2021, we recorded impairment charges of $0.8 million related to the ongoing Renewable Electricity facility decommissioning and $0.4 million related to certain assets at one RNG facility. In 2020, we recorded impairment charges of $0.3 million related to our digester joint venture. In addition, from time to time in future periods, we may be required to incur a charge against earnings in an amount equal to any unamortized capitalized expenditures and advances, net of any portion thereof that we estimate will be recoverable, through sale or otherwise, relating to: (i) any operation or other asset that is being sold, permanently shut down, impaired or has not generated or is not expected to generate sufficient cash flow; (ii) any pending acquisition that is not consummated; (iii) any project that is not expected to be successfully completed; and (iv) any goodwill or other intangible assets that are determined to be impaired. A material write-off or impairment change could adversely affect our ability to comply with the financial covenants under the Amended Credit Agreement, and otherwise adversely affect our business, financial condition and results of operations.
Our ability to use our U.S. net operating loss carryforwards to offset future taxable income may be subject to certain limitations.
As of December 31, 2022, Montauk had U.S. federal net operating loss (“NOL”) carryforwards of approximately $12.1 million that were incurred in 2018 or later taxable years and, therefore, can generally be carried forward indefinitely to offset 80% of taxable income in a future year. Our ability to utilize our U.S. NOL carryforwards is dependent upon our ability to generate taxable income in future periods.
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On January 1, 2020, the minority investor of MEC, Johnstown LFG Holdings, Inc. (via assignment of shares from MEC on December 9, 2019), was bought out by MEH, converting MEC from a partnership to a disregarded entity for U.S. federal income tax purposes, which is currently wholly owned by MEH. This transaction allowed Monmouth Energy Inc., a subsidiary of MEC, to file as part of our consolidated federal tax group. Monmouth Energy, Inc. has NOLs of approximately $13.0 million that are limited for use under the separate return limitation year rules due to the fact that they were generated prior to Monmouth Energy Inc. joining our consolidated group.
In addition, our U.S. NOL carryforwards and certain other tax attributes may be limited if we have experienced or experience an “ownership change” under Section 382 of the Internal Revenue Code of 1986, as amended (the “Code”), which generally occurs if one or more stockholders or groups of stockholders who own at least 5% of our shares increase their ownership by more than 50 percentage points over their lowest ownership percentage within a rolling period that begins on the later of three years prior to the testing date and the date of the last ownership change. Similar rules may apply under state tax laws. Previous issuances and sales of MNK’s ordinary shares or of our common stock, and future issuances and sales of our common stock (including certain transactions involving our common stock that are outside of our control) could have caused or could cause an “ownership change.” If an “ownership change” either had occurred or were to occur, Section 382 of the Internal Revenue Code of 1986, as amended (the Code) would impose an annual limit on the amount of pre-ownership change NOL carryforwards and other tax attributes we could use to reduce our taxable income, potentially increasing and accelerating our liability for income taxes, and also potentially causing certain tax attributes to expire unused. It is possible that such an ownership change could materially reduce our ability to use our U.S. NOL carryforwards or other tax attributes to offset taxable income, which could adversely affect our profitability.
Emerging Growth Company Risks
For as long as we are an emerging growth company, we will not be required to comply with certain requirements that apply to other public companies.
We are an emerging growth company, as defined in the JOBS Act. For as long as we are an emerging growth company, which may be up to five full fiscal years following January 22, 2021, the completion of the IPO, unlike other public companies, we will not be required to, among other things: (i) provide an auditor’s attestation report on management’s assessment of the effectiveness of our system of internal control over financial reporting pursuant to Section 404(b) of the Sarbanes-Oxley Act; (ii) comply with any new requirements adopted by the PCAOB requiring mandatory audit firm rotation or a supplement to the auditor’s report in which the auditor would be required to provide additional information about the audit and the financial statements of the issuer; (iii) provide certain disclosures regarding executive compensation required of larger public companies; or (iv) hold nonbinding advisory votes on executive compensation and any golden-parachute payments not previously approved. In addition, the JOBS Act provides that an emerging growth company can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act of 1933, as amended (the “Securities Act”), for adopting new or revised financial accounting standards. We intend to take advantage of the longer phase-in periods for the adoption of new or revised financial accounting standards permitted under the JOBS Act until we are no longer an emerging growth company. If we were to subsequently elect instead to comply with these public company effective dates, such election would be irrevocable pursuant to the JOBS Act.
We will remain an emerging growth company for up to five years after January 22, 2021, the date of the IPO, although we will lose that status sooner if we have more than $1.07 billion of revenues in a fiscal year, have more than $700.0 million in market value of our common stock held by non-affiliates, or issue more than $1.0 billion of non-convertible debt over a three-year period.
For so long as we rely on any of the exemptions available to emerging growth companies, you will receive less information about our executive compensation and internal control over financial reporting than issuers that
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are not emerging growth companies. We cannot predict whether investors will find our common stock less attractive because we will rely on these exemptions. If some investors find our common stock to be less attractive as a result, there may be a less active trading market for our common stock and our stock price may be more volatile.
If we identify material weaknesses in the future or otherwise fail to maintain an effective system of internal controls, we may be unable to accurately or timely report our financial condition or results of operations, which may adversely affect our business.
We are required to comply with the SEC’s rules implementing Sections 302 and 404 of the Sarbanes-Oxley Act, which require management to certify financial and other information in our quarterly and annual reports and provide an annual management report on the effectiveness of controls over financial reporting. As an emerging growth company, our independent registered public accounting firm will not be required to formally attest to the effectiveness of our internal controls over financial reporting pursuant to Section 404 until the date we are no longer an emerging growth company. At such time, our independent registered public accounting firm may issue a report that is adverse in the event that it is not satisfied with the level at which our controls are documented, designed or operating.
To comply with the requirements of being a public company, we have undertaken various actions, including implementing additional internal controls and procedures and hiring additional accounting or internal audit staff, increasing the use of external specialists and may need to take additional actions in the future. Testing and maintaining internal controls can divert our management’s attention from other matters that are important to the operation of our business. If we identify material weaknesses in our internal controls over financial reporting or are unable to comply with the requirements of Section 404 or assert that our internal controls over financial reporting are effective, or if our independent registered public accounting firm is unable to express an opinion as to the effectiveness of our internal controls over financial reporting, investors may lose confidence in the accuracy and completeness of our financial reports and the market price of our common stock could be negatively affected. In addition, we could become subject to investigations by the SEC or other regulatory authorities, which could require additional financial and management resources.
Common Stock Risks
Our stock price may be volatile, and the value of our common stock may decline.
The market price of our common stock may be highly volatile and may fluctuate or decline substantially as a result of a variety of factors, some of which are beyond our control, including:
• success or failure of our business strategies;
• our ability to obtain financing as needed;
• the failure of securities analysts to cover our common stock;
• the operating and stock price performance of other comparable companies;
• investor perception of our company or our industry;
• overall market fluctuations;
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• results from any material litigation or government investigation;
• changes in senior management or key personnel;
• the trading volume of our common stock;
• changes in capital gains taxes and taxes on dividends affecting stockholders;
• changes in the anticipated future growth rate of our business.
Broad market and industry fluctuations, as well as general economic, political, regulatory and market conditions, may also adversely affect the market price of our common stock.
Our shares of common stock may trade on more than one market and this may result in price variations.
The Company’s common stock is traded on the Nasdaq Capital Market under the ticker symbol of “MNTK” and on the JSE under the ticker symbol of “MKR.” Trading in our common stock takes place in USD on the Nasdaq Capital Market and ZAR on the JSE, and at different times, resulting from different time zones, trading days and public holidays in the United States and South Africa. The trading prices of our common stock on these two markets may differ due to these and other factors. Any decrease in the price of our common stock on either exchange could cause a corresponding decrease in the trading price of the common stock on the other exchange.
Future sales of our common stock in the public market could cause the market price of our common stock to decline.
Sales of a substantial number of shares of our common stock in the public market, or the perception that these sales might occur, could depress the market price of our common stock and could impair our ability to raise
capital through the sale of additional equity securities. Many of our existing equity holders have substantial unrecognized gains on the value of the equity they hold based upon the price of the IPO, and therefore they may take steps to sell their shares or otherwise secure the unrecognized gains on those shares. Additionally, pursuant to the terms of the Second Amended Promissory Note (as amended), MNK is required to use the proceeds from any sale of the 800,000 shares of our common stock previously pledged as security for MNK’s loan obligations to repay the amounts due under the Second Amended Promissory Note (as amended). These sales may have a downward impact on the prevailing market price of our common stock. MNK is currently evaluating a number of options to complete the sale of these shares including but not limited to register sale or underwritten offering in the US, direct sale to a South African investor, or extending the term of the loan. We also have default provisions in the underlying note whereby MNK can satisfy the note by delivering the shares back to us as permitted by applicable law. We are unable to predict the timing of or the effect that such sales, by MNK or by other shareholders, may have on the prevailing market price of our common stock.
We are a “controlled company” within the meaning of the Nasdaq rules and, as a result, qualify for, and intend to rely on, exemptions and relief from certain governance requirements.
Certain stockholders, which are Messrs. Copelyn’s and Govender’s respective affiliates, have entered into a Consortium Agreement whereby the parties thereto agreed to act in concert with respect to voting our common stock in the election of directors, among other matters. The parties to the Consortium Agreement beneficially owned, in the aggregate, approximately 52.3% of our common stock as of February 28, 2023. As a result, we are a “controlled company” within the meaning of the Nasdaq corporate governance standards. Under these
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corporate governance standards, a company of which more than 50% of the voting power in the election of directors is held by an individual, group or another company is a “controlled company” and may elect not to comply with certain corporate governance requirements. For example, controlled companies are not required to have:
We may rely on any or all of these exemptions so long as we remain a controlled company.
The concentration of our capital stock ownership may limit our stockholders’ ability to influence corporate matters and may involve other risks.
As a result of the Consortium Agreement, certain of our stockholders control matters requiring stockholder approval, including the election of our directors and approval of significant corporate transactions. This
concentration of ownership may also have the effect of delaying or preventing a change in control of us that may be otherwise viewed as beneficial by stockholders other than management. Accordingly, other stockholders may not have any influence over significant corporate transactions and other corporate matters. There is also a risk that certain controlling stockholders may have interests which are different from other stockholders and that they will pursue an agenda which is beneficial to themselves at the expense of other stockholders.
Provisions of our Amended and Restated Certificate of Incorporation, Amended and Restated Bylaws, and Delaware law may prevent or delay an acquisition of us, which could decrease the trading price of our common stock.
Certain provisions of our Amended and Restated Certificate of Incorporation and Amended and Restated Bylaws, together with applicable Delaware law, may discourage, delay or prevent a merger or acquisition that our stockholders consider favorable. These provisions may discourage, delay or prevent certain types of transactions involving an actual or a threatened acquisition or change in control of us, including unsolicited takeover attempts, even though the transaction may offer our stockholders the opportunity to sell their common stock at a price above the prevailing market price.
Certain of our directors reside outside of the United States and it may be difficult to enforce judgments against them in the United States.
Two of our directors, all of our executive officers and all of our operating assets reside in the United States. Certain of our directors, including John A. Copelyn, Theventheran (Kevin) G. Govender, Mohamed H. Ahmed and Yunis Shaik are residents of South Africa. Another director, Michael A. Jacobson, is a resident of Australia. As a result, it may not be possible for you to effect service of legal process, within the United States or elsewhere, upon certain of our directors, including matters arising under U.S. federal securities laws. This may make it difficult or impossible to bring an action against these individuals in the United States in the event that a person believes that their rights have been violated under applicable law or otherwise. Even if an action of this type is successfully brought, the laws of the United States and of South Africa or Australia may render a judgment unenforceable.
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General Risk Factors
Our issuance of additional capital stock in connection with financings, acquisitions, investments, our equity incentive plans or otherwise will dilute stockholders.
We expect to issue additional capital stock in the future that will result in dilution to stockholders. We expect to grant equity awards to employees, directors and consultants under our equity incentive plans. We may also raise capital through equity financings in the future. As part of our business strategy, we may acquire or make investments in companies and issue equity securities to pay for any such acquisition or investment. Any such issuances of additional capital stock may cause stockholders to experience significant dilution of their ownership interests and the per share value of our common stock to decline.
Ifsecuritiesor industryanalystsdo not publishresearchor publishinaccurateor unfavorableresearchabout our business,our share priceand tradingvolumecould decline.
The trading market for our common stock will be influenced by the research and reports that securities or industry analysts publish about us. Securities and industry analysts do not currently, and may never, publish research focused on us. If no securities or industry analysts commence coverage of us, the price and trading volume of our common stock likely would be adversely affected. If securities or industry analysts initiate coverage and one or more of the analysts who cover us downgrade our common stock or publish inaccurate or unfavorable research about our company, our common stock share price would likely decline. If analysts publish target prices for our common stock that are below historical sales prices or the then-current public price of our common stock, it could cause our stock price to decline significantly. Further, if one or more of these analysts cease coverage of us or fail to publish reports on us regularly, demand for our common stock could decrease, which might cause our common stock price and trading volume to decline.
We are highly dependent on our senior management team and other highly skilled personnel, and if we are not successful in attracting or retaining highly qualified personnel, we may not be able to successfully implement our business strategy.
Our success depends, in significant part, on the continued services of our senior management team and on our ability to attract, motivate, develop and retain a sufficient number of other highly skilled personnel, including engineering, design, finance, marketing, sales and support personnel. Our senior management team has extensive experience in the renewable energy industry, and we believe that their depth of experience is instrumental to our continued success. The loss of any one or more members of our senior management team, for any reason, including resignation or retirement, could impair our ability to execute our business strategy and adversely affect our business, financial condition and results of operations.
Competition for qualified highly skilled personnel can be strong, and we cannot assure you that we will be successful in attracting or retaining such personnel now or in the future. Any inability to recruit, develop and retain qualified employees may result in high employee turnover and may force us to pay significantly higher wages, which may harm our profitability. Additionally, we do not carry key personnel insurance for any of our management executives, and the loss of any key employee or our inability to recruit, develop and retain these individuals as needed, could adversely affect our business, financial condition and results of operations.
Our ability to pay regular dividends on our common stock is subject to the discretion of our Board of Directors.
Our common stock will have no contractual or other legal right to dividends. The payment of future dividends on our common stock will be at the discretion of our Board of Directors and will depend on, among
other things, our earnings, financial condition, capital requirements, level of indebtedness, statutory and contractual restrictions applying to the payment of dividends and other considerations that our Board of Directors deems relevant. Accordingly, we may not make, or may have to reduce or eliminate, the payment of dividends on our common stock, which could adversely affect the market price of our common stock.
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ITEM 1B. UNRESOLVED STAFF COMMENTS.
None.
ITEM 2. PROPERTIES.
Our principal executive office is located in Pittsburgh, Pennsylvania. We lease an approximate 24,000 square foot office space at this site for approximately $43,000 per month pursuant to a lease which expires on April 30, 2033.
We also lease an 8,400 square foot regional office and warehouse to service our sites in Houston, Texas, pursuant to a lease which expires on December 31, 2026, for approximately $5,000 per month. We also have a month to month lease for nominal office space for Montauk Ag in Greensboro, North Carolina. We currently own and operate 15 projects, 12 of which are RNG projects and three of which are Renewable Electricity projects. See “Item 1. Business—Our Current Operating Portfolio” for further descriptions of our projects, which information is incorporated into this item by reference.
ITEM 3. LEGAL PROCEEDINGS.
From time to time we and our subsidiaries may be parties to legal proceedings arising in the normal course of our business. We and our subsidiaries are currently not a party, nor is our property subject, to any material pending legal proceedings. None of our directors, officers, affiliates, or any owner of record or beneficially of more than 5% of our common stock, is involved in a material proceeding adverse to us or our subsidiaries or has a material interest adverse to us or our subsidiaries.
ITEM 4. MINE SAFETY DISCLOSURES.
Not Applicable.
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PART II
Market Information
The Company’s common stock has traded on the Nasdaq Capital Market under the ticker symbol of “MNTK” and on the JSE under the ticker symbol of “MKR” since January 22, 2021. Prior to that time, there was no established public trading market for the Company’s common stock.
Holders of Montauk Common Stock
As of March 8, 2023, there were 11 holders of record of 141,633,417 shares of Montauk common stock outstanding as of such date. The number of holders of record of Montauk common stock does not reflect the number of beneficial holders whose shares are held by depositaries, brokers or other nominees.
Performance Graph
The following stock performance graph compares our total stock return with the total return for (a) NASDAQ Composite Index and (b) an industry peer group. Our 2022 peer group, which is comprised of companies that we believe have comparable characteristics and are in the same industry or line-of-business, consists of Aemetis Inc., Clean Energy Fuels Corp., and Gevo Inc. Our eleven month 2021 peer group also included Archaea Energy, Inc., and Renewable Energy Group Inc. but these entities were acquired and ceased trading during 2022 and, as such, a separate line showing the total returns for this group is not possible in the below performance graph through December 31, 2022. The graph assumes that on January 22, 2021, the date our common stock began trading on the Nasdaq Capital Market, $100 was invested in our common stock and in each index based on the closing market price on that day and that all dividends were reinvested. The returns shown are based on historical events and are not intended to suggest future performance.
The following performance graph and related information is being furnished and shall not be deemed “soliciting material” or “filed” with the SEC for purposes of Section 18 of the Exchange Act or otherwise subject to the liabilities under that section, nor shall such information be incorporated by reference into any future filing under the Securities Act or the Exchange Act, except to the extent we specifically incorporate it into reference into such filing.
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Dividend Policy
The Company did not pay any dividends in the fiscal year ended December 31, 2022 and currently intends to retain future earnings, if any, to finance the operations, growth and development of its business. Any future determination as to the declaration and payment of dividends, if any, will be at the discretion of our Board of Directors, subject to compliance with contractual restrictions and covenants in the agreements governing our current and future indebtedness and the DGCL. Any such determination will also depend upon our business prospects, results of operations, financial condition, cash requirements and availability, and other factors that our Board of Directors may deem relevant.
Securities Authorized for Issuance Under Equity Compensation Plans
The information required by Item 5 of Form 10-K regarding equity compensation plans is incorporated herein by reference to Item 12 of Part III of this Annual Report.
Issuer Repurchases of Equity Securities
None.
Use of Proceeds from Sale of Registered Securities
On January 21, 2021, our Registration Statement on Form S-1, as amended (File No. 333-251312) (the “Registration Statement”), was declared effective by the SEC in connection with the IPO. The underwriter for the IPO was Roth Capital Partners. A total of 3,399,515 shares of our common stock were sold pursuant to the Registration Statement, which was comprised of (1) 2,702,500 shares of new common stock issued by the Company and (2) 697,015 shares of the Company’s common stock held by MNK. The 3,399,515 shares were sold at an offering price of $8.50 per share and resulting in net proceeds to the Company of approximately $15.0 million, after deducting the underwriting discount of approximately $1.6 million and offering expenses payable by the Company of approximately $6.2 million.
The IPO closed on January 26, 2021. No payments for such expenses were made directly or indirectly to (i) any of our officers or directors or their associates, (ii) any persons owning 10% or more of any class of our equity securities or (iii) any of our affiliates.
From the closing of the IPO through December 31, 2022, approximately $14.8 million of the net proceeds from the IPO have been used by Montauk for the following: the Montauk Ag Asset Acquisition in May 2021, the purchase of the real-estate and property in October 2021 related to Montauk Ag, and subsequent development activities related to Montauk Ag Renewables. An immaterial amount has been used relating to other possible acquisitions and projects. As of December 31, 2022, the remaining net proceeds of approximately $0.2 million is held as cash. The remaining net proceeds have been used by the Company during 2023 in the continued development of Montauk Ag Renewables.
Recent Sales of Unregistered Securities
None.
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ITEM 6. RESERVED
The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our financial statements and the related notes to those statements included elsewhere in this Annual Report on Form 10-K. The historical consolidated financial data discussed below reflects the historical results of operations and financial position of Montauk USA, prior to the Equity Exchange on January 4, 2021. Following the Equity Exchange on January 4, 2021, the consolidated financial statements of Montauk USA became our historical financial statements for the periods prior to the Equity Exchange.
In addition to historical financial information, the following discussion and analysis contains forward-looking statements that involve risks, uncertainties, and assumptions. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of many factors, including those discussed under “Cautionary Note Regarding Forward-Looking Statements” and “Item 1A.–Risk Factors” and elsewhere in this report.
This section generally discusses our results of operations for the year ended December 31, 2022 compared to the year ended December 31, 2021. For discussion and analysis of our results for the year ended December 31, 2021 compared to the year ended December 31, 2020, refer to “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part II, Item 7 of our Annual Report on Form 10-K filed with the SEC on March 16, 2022.
Overview
Montauk is a renewable energy company specializing in the recovery and processing of biogas from landfills and other non-fossil fuel sources for beneficial use as a replacement to fossil fuels. We develop, own, and operate RNG projects, using proven technologies that supply RNG into the transportation industry and use RNG to produce Renewable Electricity. We are one of the largest U.S. producers of RNG, having participated in the industry for over 30 years. We established our operating portfolio of 12 RNG and three Renewable Electricity projects through self-development, partnerships, and acquisitions that span six states.
Biogas is produced by microbes as they break down organic matter in the absence of oxygen (during a process called anaerobic digestion). Our two current sources of commercial scale biogas are LFG and ADG, which is produced inside an airtight tank used to breakdown organic matter, such as livestock waste. We typically secure our biogas feedstock through long-term fuel supply agreements and property lease agreements with biogas site hosts. Once we secure long-term fuel supply rights, we design, build, own, and operate facilities that convert the biogas into RNG or use the processed biogas to produce Renewable Electricity. We sell the RNG and Renewable Electricity through a variety of short-, medium-, and long-term agreements. Because we are capturing waste methane and making use of a renewable source of energy, our RNG and Renewable Electricity generate valuable Environmental Attributes, which we are able to monetize under federal and state initiatives.
Recent Developments
RINs Generated but Unsold
Our profitability is highly dependent on the market price of Environmental Attributes, including the market price for RINs. As we self-market a significant portion of our RINs, a decision not to commit to transfer available RINs during a period will impact our revenue and operating profit. The industry experienced volatile D3 RIN index prices since the EPAs release of the 2023 RVO in December 2022. Though the average market price of D3 RINs since the 2023 RVO release was approximately $2.18, the market price declined as low as $1.88 in February 2023 from a D3 RIN index price of $2.43 on the day of the 2023 RVO release. We viewed this reduction in price as temporary and, accordingly, we determined not to transfer a significant amount of D3 RINs generated and available for transfer during the first quarter of 2023. As a result, we have approximately 3,890 RINs in inventory from 2022 gas production and have approximately 7,269 RINs in inventory from 2023 gas production as of the filing of this Report.
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We have not entered into commitments to transfer these RINs in inventory nor have we entered into agreements to transfer future RINs generated from forecasted future production. The average D3 RIN index price during the month of February 2023 was approximately $1.95.
Montauk Ag Asset Acquisition
In 2021, through a wholly-owned subsidiary Montauk Ag Renewables, we completed an asset purchase related to developing technology to recover residual natural resources from waste streams of modern agriculture and to refine and recycle such waste products through proprietary and other processes in order to produce high quality renewable natural gas, bio-oil and biochar (the “Montauk Ag Renewables Acquisition”). The assets acquired include real property, intellectual property, mobile equipment, and other equipment related to operating the business. The real property includes the purchase of an approximate 9.35 acre parcel in Duplin County, North Carolina. Also, in 2021, we closed on a transaction to acquire approximately 146 acres and an approximately 500,000 square foot existing structure in Turkey, North Carolina where we plan to use consolidate and expand the production processes purchased in the Montauk Ag Renewables Acquisition.
We continue to work with our engineer of record through the optimization of improvements to the now patented reactor technology. However, we have not completed our improvements, and we have not reached commercial operations at the Turkey, NC location. The improvements to the reactor technology are intended to be deployed at the Turkey, NC location. During the fourth quarter of 2022 we began to relocate the reactor in Magnolia, NC to the Turkey, NC location to centralize processing at one location. As part of the centralization and in connection with the optimization of the reactor, we assessed various assets of the Magnolia, NC reactor as no longer being applicable to the improved reactor process. As a result, we recorded an impairment charge of approximately $1,393 related to assets originally acquired in the May 2021 Montauk Ag Renewables Acquisition we determined were no longer usable.
While these project developments continue, we continue to engage with regulatory agencies in North Carolina related to the resulting power generation derived from swine waste to confirm its eligibility for Renewable Energy Credits under North Carolina’s Renewable Energy Portfolio Standards in anticipation of commercial production. Accordingly, we requested that our Turkey location be approved to participate in the Piedmont Natural Gas Renewable Gas Pilot Program which is a step towards obtaining the New Renewable Energy Facility (“NREF”) designation under the North Carolina Utilities Commission. Due to our consolidation of operations at the Turkey, NC location and based on our current expectations related to commercial operations, we have paused our registration process to obtain NREF status for the Turkey, NC location. Our Turkey, NC location has been accepted into the Piedmont Natural Gas Renewable Gas Pilot Program.
In the first quarter of 2023 we signed a receipt interconnection agreement with Piedmont Natural Gas for the Turkey, NC location. This agreement is structured to coincide with the development timeline at the Turkey, NC location. We are also in varying stages of discussions with potential power purchasers.
We are at the beginning stages of developing the opportunities associated with Montauk Ag Renewables and can give no assurances that our plans related to this acquisition will meet our expectations. We continue to design and plan for the development of the facility to be used for commercial production. Based on our current development timeline expectations, we do not expect to commence significant revenue generating activities until 2024. We intend to contract with additional farms to secure feedstock sources for future production processes.
Amendment to Pico Feedstock Agreement
During the second quarter of 2021, we completed an amendment to our Pico feedstock agreement (“Pico Feedstock Amendment”). The amendment will increase the amount of feedstock supplied to the facility for processing over a one to three-year period. We have paid $3,500 in cash under the terms of the Pico Feedstock Amendment.
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Under the Pico Feedstock Amendment the dairy began delivering the first and second increases in feedstock during the third quarter of 2022. The improved efficiencies of our existing digestion process and the water management improvements have enabled us to process the increased feedstock volumes which we currently expect to increase by five to ten percent once all increased feedstock deliveries have been received from the dairy. We completed the design of the digestion capacity project in the third quarter of 2022 and have begun incurring capital expenditures related to the construction of the project. We currently expect the construction project to be functionally completed during the third quarter of 2023. We currently expect the dairy to begin delivering the final increase in feedstock volumes during 2024.
In the first quarter of 2023, CARB finalized the engineering review of the Pico facility’s provisional CI application and released it for public comment. The public comment period ended March 14, 2023. We do not believe we received any significant public comments and expect to receive the certified provisional CI score before the end of the first quarter of 2023.
Second Apex RNG Facility
In August 2022, we announced the planned construction of a second RNG processing facility at the Apex landfill. This project is being driven by projections in biogas feedstock availability from the host landfill. We anticipate an approximate 40% increase in RNG processing capacity with the addition of the second facility. This expansion is expected to increase daily production approximately 2,100 MMBtu per day and expand the infrastructure for the conversion of LFG to RNG. We have begun to incur capital expenditures for this project and expect the project to be complete and become commercially operational in 2024.
Raeger Capital Improvement
In June 2022, our Board of Directors approved a capital improvement project to make upgrades to our Raeger facility that will increase production. This facility is currently being impacted by requirements to meet federal pipeline tariffs which limit the oxygen content of product gas. The pipeline tariffs have resulted in limitations in our ability to process all existing feedstock. During the second quarter of 2022, we completed our analysis of process facility improvements necessary to meet these more stringent tariff requirements. Construction on this capital project commenced during the third quarter of 2022 and we expect it will become commercially operational during the second half of 2023. Based on the current production of the Raeger facility, we anticipate an approximate increase of 50% of average daily production.
Key Trends
Market Trends Affecting the Renewable Fuel Market
We believe rising demand for RNG is attributable to a variety of factors, including growing public support for renewable energy, U.S. governmental actions to increase energy independence, environmental concerns increasing demand for natural gas-powered vehicles, job creation, and increasing investment in the renewable energy sector.
Key drivers for the long-term growth of RNG include the following factors:
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Factors Affecting Our Future Operating Results:
Conversion of Electricity Projects to RNG Projects:
We periodically evaluate opportunities to convert existing facilities from Renewable Electricity to RNG production. These opportunities tend to be most attractive for any merchant electricity facilities given the favorable economics for the sale of RNG plus RINs relative to the sale of market rate electricity plus RECs. This strategy has been an increasingly attractive avenue for growth since 2014 when RNG from landfills became eligible for D3 RINs. However, during the conversion of a project, there is a gap in production while the electricity project is offline until it commences operation as an RNG facility, which can adversely affect us. This timing effect may adversely affect our operating results as a result of our potential conversion of Renewable Electricity projects. Upon completion of a conversion, we expect that the increase in revenue upon commencement of RNG production will more than offset the loss of revenue from Renewable Electricity production. Historically, we have taken advantage of these opportunities on a gradual basis at our merchant electricity facilities, such as Atascocita and Coastal Plains.
Acquisition and Development Pipeline
The timing and extent of our development pipeline affects our operating results due to:
a multiple of those realized from landfill projects due to the significantly more attractive CI score of livestock farms.
Regulatory, Environmental and Social Trends
Regulatory, environmental and social factors are key drivers that incentivize the development of RNG and Renewable Electricity projects and influence the economics of these projects. We are subject to the possibility of legislative and regulatory changes to certain incentives, such as RINs, RECs and GHG initiatives. In accordance with the consent decree entered into between the EPA and Growth Energy approved by the U.S. District Court for the District of Columbia, the EPA issued the final Renewable Fuel Standards for 2020, 2021, and 2022 on June 3, 2022. Final volumes for cellulosic biofuel were set at 510, 560 and 630 million RINs for the three years 2020, 2021 and 2022, respectively. While final volumes set for all three years were lower than proposed, the EPA partially offset the lower volumes by issuing its final notice, also on June 3, 2022, to deny the remaining 69 petitions for RFS Small Refinery Exemptions. Per the settlement agreement with Growth Energy, the EPA was
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required to issue a proposed 2023 RVO no later than November 16, 2022 with final volume requirements established by June 11, 2023. On November 4, 2022, the EPA filed a notice with the U.S. District Court for the District of Columbia indicating that EPA and Growth Energy have agreed to extend the deadline for signing the proposed rule for the 2023 renewable fuel standards.
The EPA issued the proposed Renewable Fuel Standard for 2023, 2024, and 2025 on December 1, 2022. Comments on this proposed rule were due by February 10, 2023 with a final rule to be issued by June 14, 2023. The proposed volumes for cellulosic biofuel were set at 720, 1,420, and 2,130 million RINs for the three years 2023, 2024, and 2025, respectively. Included within these volumes are 0, 600, and 1,200 million volumes of eRINs generated from renewable electricity for 2023, 2024, and 2025, respectively.
Changes to the LCFS program require annual verification of the CI score assigned to a project. Annual verification could significantly affect the profitability of a project, particularly in the case of a livestock farm project. CARB finalized engineering review of the Pico facility’s provisional CI application and posted the application for public comment on February 28, 2023. The public comment period ended March, 14, 2023. We expect to receive the certified provisional CI score before the end of the first quarter of 2023.
Factors Affecting Revenue
Our total operating revenues include renewable energy and related sales of Environmental Attributes. Renewable energy sales primarily consist of the sale of biogas, including LFG and ADG, which is either sold or converted to Renewable Electricity. Environmental Attributes are generated and monetized from the renewable energy.
We report revenues from two operating segments: Renewable Natural Gas and Renewable Electricity Generation. Corporate relates to additional discrete financial information for the corporate function; primarily used as a shared service center for maintaining functions such as executive, accounting, treasury, legal, human
resources, tax, environmental, engineering, and other operations functions not otherwise allocated to a segment. As such, the corporate entity is not determined to be an operating segment but is discretely disclosed for purposes of reconciliation to the Company’s consolidated financial statements.
Our revenues are priced based on published index prices which can be influenced by factors outside our control, such as market impacts on commodity pricing and regulatory developments. With our royalty payments structured as a percentage of revenue, royalty payments fluctuate with changes in revenues. Due to these factors, we place a primary focus on managing production volumes and operating and maintenance expenses as these factors are more controllable by us.
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RNG Production
Our RNG production levels are subject to fluctuations based on numerous factors, including:
Disruptions to Production: Disruptions to waste placement operations at our active landfill sites, severe weather events, failure or degradation ofour or a landfill operator’s equipment or interconnection or transmission problems could result in a reduction of our RNG production. We strive to proactively address any issues that may arise through preventative maintenance, process improvement and flexible redeployment of equipment to maximize production and useful life.
Pricing
Our Renewable Natural Gas and Renewable Electricity Generation segments’ revenues are primarily driven by the prices under our off-take agreements and PPAs and the amount of RNG and Renewable Electricity that we
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produce. We sell the RNG produced from our projects under a variety of short-term and medium-term agreements to counterparties, with contract terms varying from three years to five years. Our contracts with counterparties are typically structured to be based on varying natural gas price indices for the RNG produced. All of the Renewable Electricity produced at our biogas-to-electricity projects is sold under long-term contracts to creditworthy counterparties, typically under a fixed price arrangement with escalators.
The pricing of Environmental Attributes, which accounts for a substantial portion of our revenues, is subject to volatility based on a variety of factors, including regulatory and administrative actions and commodity pricing.
Our dairy farm project is expected to be awarded a more attractive CI by CARB, thereby generating LCFS credits at a multiple of those generated by our landfill projects.
The sale of RINs, which is subject to market price fluctuations, accounts for a substantial portion of our revenues. We manage against the risk of these fluctuations through forward sales of RINs, although currently we only sell RINs in the calendar year they are generated in the following calendar year. We did not forward sell a significant portion of expected 2023 RIN generation. Realized prices for Environmental Attributes monetized in a year may not correspond directly to index prices due to the forward selling of commitments.
Factors Affecting Operating Expenses
Our operating expenses include royalties, transportation, gathering and production fuel expenses, project operating and maintenance expenses, general and administrative expenses, depreciation and amortization, net loss (gain) on sale of assets, impairment loss and transaction costs.
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Key Operating Metrics
Total operating revenues reflect both sales of renewable energy and sales of related Environmental Attributes. As a result, our revenues are primarily affected by unit production of RNG and Renewable Electricity, production of Environmental Attributes, and the prices at which we monetize such production. Set forth below is an overview of these key metrics:
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The following table summarizes the key operating metrics described above, which metrics we use to measure performance.
(in thousands, unless otherwise indicated) For the yearended December 31,
Revenues
RNG Metrics
Plus: Prior period RNG volumes dispensed in current period 372 353 19 5.4 %
Total RNG volumes available for RIN generation(1) 4,238 4,073 165 4.1 %
RIN Metrics
Plus: Prior period RINs carried into CY 140 110 30 27.3 %
RIN Inventory — — — —
RNG Inventory (volumes not dispensed for RINs)(4) 368 372 (4 ) (1.1 )%
Operating Expenses
Other Metrics
Renewable Electricity Generation Volumes Produced (MWh) 190 183 7 3.8 %
Average Realized Price $/MWh (actual) $ 90.37 $ 84.45 $ 5.92 7.0 %
(4) Represents gas production which has not been dispensed to generate RINs.
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Results of Operations
Comparison of Years Ended December 31, 2022 and 2021
The following table summarizes our revenues, expenses and net income for the periods set forth below:
(in thousands, except per share data) For the yearended December 31,
Operating Expenses:
Gain on insurance proceeds (313 ) (332 ) 19 (5.7 )%
Revenues for the Years Ended December 31, 2022 and 2021
Total revenues in 2022 were $205,559, an increase of $57,432 (38.8%) compared to $148,127 in 2021. The primary driver for this increase relates to an increase of 70.2% in realized RIN pricing during 2022 of $3.25 compared to $1.91 in 2021. Additionally, the natural gas index price increased approximately 72.9% in 2022 and was $6.64 compared to $3.84 in 2021. These increases were offset by lower counterparty sharing revenues of $13,176 in 2022 compared to 2021 due to these arrangements ending.
Renewable Natural Gas Revenues
We produced 5,522 MMBtu of RNG during 2022, a decrease of 166 MMBtu (2.9%) from the 5,688 MMBtus produced in 2021. Our Atascocita facility produced 160 fewer MMBtu in 2022 compared to 2021 due to a temporary process equipment failure. Our Rumpke facility produced 89 fewer MMBtu in 2022 compared to 2021 as a result of lower wellfield inlet flow associated with the landfill host operations. Our Apex facility produced 70 fewer MMBtu in 2022 compared to 2021 due to landfill filling pattern changes resulting in lower production. Offsetting the decrease are production volume increases at our Pico and Galveston facilities. Our Pico facility produced 108 MMBtu more in 2022 compared to 2021 as a result of improvements related to the existing digestion process and our water management practices. Our Galveston facility produced 52 MMBtu more in 2022 compared to 2021 as a result of higher inlet gas due to wellfield changes and plant efficiency optimization of process equipment.
Revenues from the Renewable Natural Gas segment in 2022 were $196,218, an increase of $64,415 (48.9%) compared to $131,803 in 2021. Average commodity pricing for natural gas for 2022 was 72.9% higher than the prior year. During 2022, we self-marketed 43,823 RINs, representing a 1,219 increase (2.9%) compared to 42,604 in 2021. The increase was primarily related to an offtake agreement change in 2021 providing more RNG volumes available to self-market. Average pricing realized on RIN sales during 2022 was $3.25 as compared to $1.91 in 2021, an increase of 70.2%. This compares to the average D3 RIN index price for 2022 of $2.98 being approximately 1.3% lower than the average D3 RIN index price in 2021 of $3.02. All our RIN sales in 2022 and
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2021 were priced generally on the D3 index with none based on CWC. At December 31, 2022, we had approximately 0.4 million MMBtus available for RIN generation and had approximately 0.7 million RINs generated and unsold. We had approximately 0.4 million MMBtus available for RIN generation and approximately 0.1 million RINs generated and unsold at December 31, 2021.
Renewable Electricity Generation Revenues
We produced 190 MWh in Renewable Electricity in 2022, an increase of approximately 7 MWh (3.8%) compared to 183 MWh in 2021. In 2022, our Security facility produced 10 MWh in 2022 compared to zero production in 2021 as a result of the prior period engine restoration project. Offsetting this increase, is a decrease at our Tulsa facility that produced 3 MWh less in 2022 compared to 2021 due to reduced feedstock availability at the landfill.
Revenues from Renewable Electricity facilities in 2022 were $17,170, an increase of $1,721 (11.1%) compared to $15,449 in 2021. Our Bowerman facility contributed to $1,244 of the increase, which was primarily driven by a temporary shutdown of the facility in the fourth quarter 2020 due to the California wildfires, resulting in $598 in reduced Environmental Attribute revenues in 2021 compared to 2022. Also contributing to the increase is our Security facility engine restoration project resulting in $668 in higher revenues for 2022 compared to zero in 2021.
Corporate Analysis
During 2022, our gas commodity hedge was priced at rates below actual index prices and we recorded losses of $7,829 related to our gas commodity hedge. Our gas commodity hedge expired in December 2022 and we did not have any gas commodity hedges during 2021. During 2021, we recorded revenues of $875 related to RINs purchased in 2021 and recorded an adjustment of $710, associated with our purchase of RINs, to reduce the carrying value of those RINs to net realizable value. This is included within our operating revenues in the Consolidated Statement of Operations for the 2021 period. We did not have market purchased RINs during 2022.
Expenses for the Years Ended December 31, 2022 and 2021
General and Administrative Expenses
Total general and administrative expenses of $34,139 in 2022, a decrease of $8,413 (19.8%) compared to $42,552 in 2021. Employee related costs, including stock-based compensation, decreased approximately $10,643 (35.4%) in 2022 compared to 2021. The decrease is primarily related to our accounting for the cancellation of MNK options and January 2021 grants of restricted stock, non-qualified stock options, and restricted stock units to the Company’s employees. Offsetting this decrease is an increase in general and administrative expenses of approximately $3,608 (337.5%) in 2022 as compared to 2021 associated with the Montauk Ag Renewables Acquisition. Our corporate insurance premiums increased approximately $377 (6.8%) during 2022 compared to 2021, primarily related to premium increases. Our board of directors approved payments of cash fees to non-employee directors resulting in increased fees of approximately $675 in 2022 as compared to 2021. Finally, excluding the Montauk Ag Renewables Acquisition, our professional fees increased approximately $799 (19.4%) in 2022 as compared to 2021 primarily related to increased legal fees.
Renewable Natural Gas Expenses
Operating and maintenance expenses for our RNG facilities in 2022 were $43,729, an increase of $5,615 (14.7%) compared to $38,114 in 2021. The increase is driven by increased RNG utilities of approximately $6,061 (61.2%) in 2022 compared to 2021. The increase was caused by a cold weather event in the first quarter of 2021 impacting our Houston based facilities being favorably impacted by lower utility rates.
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Royalties, transportation, gathering and production fuel expenses for the Company’s RNG facilities for 2022 were $42,339, an increase of $15,407 (57.2%) compared to $26,932 in 2021. Royalties, transportation, gathering and production fuel expenses increased as a percentage of RNG revenues to 21.6% for 2022 from 20.4% in 2021.
Renewable Electricity Expenses
Operating and maintenance expenses for our Renewable Electricity facilities in 2022 were $13,086, an increase of $2,660 (25.5%) compared to $10,426 in 2021. The increase is primarily driven by the timing of scheduled engine preventative maintenance intervals at our Bowerman facility, of approximately $1,645 higher in 2022 over 2021. Adding to the increase are operating expenses of approximately $434 related to Montauk Ag Renewables Acquisition.
Royalties, transportation, gathering and production fuel expenses for our Renewable Electricity facilities for 2022 were $1,824, an increase of $73 (4.2%) compared to $1,751 in 2021 and as a percentage of Renewable Electricity Generation segment, revenues decreased from 11.3% to 10.6%.
Royalty Payments
Royalties, transportation, gathering, and production fuel expenses in 2022 were $44,163, an increase of 15,480 (54.0%) compared to $28,683 in 2021. We make royalty payments to our fuel supply site partners on the commodities we produce and the associated Environmental Attributes. These royalty payments are typically structured as a percentage of revenue subject to a cap, with fixed minimum payments when Environmental Attribute prices fall below a defined threshold. To the extent commodity and Environmental Attributes’ prices fluctuate, our royalty payments may fluctuate upon renewal or extension of a fuel supply agreement or in connection with new projects. Our fuel supply agreements are typically structured as 20-year contracts, providing long-term visibility into the margin impact of future royalty payments.
Depreciation
Depreciation and amortization in 2022 were $20,700, a decrease of $2,169 (9.5%) compared to $22,869 in 2021. The decrease is associated with assets remaining in service being fully amortized.
Impairment loss
We calculated and recorded impairment losses of $4,852 for 2022, an increase of $3,661 (307.4%) compared to $1,191 for 2021. The primary driver of this increase relates to an impairment of $2,133 for a REG site wherein the forecast future cash flows did not exceed the carrying value of the site’s long lived assets. A second REG site was impaired for $1,393 due to discrete conclusion that certain assets acquired in the May 2021 Montauk Ag Renewables Acquisition would no longer be utilized. Also in 2022, we recorded an impairment at an RNG facility for approximately $1,108 due to the specific identification of certain assets no longer being capable of use as designed. The 2021 impairment loss of $1,191 was primarily related to the closure of two REG sites and the disposal of machinery at one RNG site.
Other Expenses (Income)
Other expenses in 2022 were $1,324, a decrease of $2,378 (64.2%) compared to $3,702 in 2021. Reduced interest expense of $1,136 is related to our favorable interest rate swap contract resulting in reduction of interest expense in 2022 as compared to 2021. Also impacting the decrease is $865 relating to asset disposal costs at our Galveston and Pico facilities in 2021.
Income Tax Expense
Prior to 2022, we generated NOLs, which can be carried forward indefinitely, however, some of the NOLs are under an 80% limitation. In 2022, we utilized all non-limited NOL carryforwards. Based upon our historical
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pre-tax book income and forecasts, we expect to utilize some remaining NOLs and thus have not recorded a valuation allowance against such NOLs.
Our effective income tax rate (“ETR”) for 2022 was an expense of 18.6% compared to 1,132.1% for the prior year period. The higher ETR in the prior year period was driven by the low pre-tax income compared to the tax expense of $4,161 for 2021, which was primarily driven by the Section 162(m) limitation.
The Inflation Reduction Act of 2022, enacted by the United States on August 16, 2022, did not have a material impact on our provision for income taxes for the year ended December 31, 2022. The American Rescue Plan Act of 2021, enacted on March 11, 2021 did not have a material impact on the provision for income taxes for the year ended December 31, 2021. The Company is continuing to analyze the ongoing impact of the Inflation Reduction Act legislation.
Operating Profit (Loss) for the Years Ended December 31, 2022 and 2021
Operating profit in 2022 was $44,566, an increase of $41,231 (1236.3%) compared to $3,335 in 2021. RNG operating profit for 2022 was $94,439, an increase of $44,089 (87.6%) compared to $50,350 in 2021. Renewable Electricity Generation operating loss for 2022 was $7,019, an increase of $3,929 (127.2%) compared to an operating loss of $3,090 in 2021.
Non-GAAP Financial Measures:
The following table presents EBITDA and Adjusted EBITDA, non-GAAP financial measures for each of the periods presented below. We present EBITDA and Adjusted EBITDA because we believe the measures assist investors in analyzing our performance across reporting periods on a consistent basis by excluding items that we do not believe are indicative of our core operating performance. In addition, EBITDA and Adjusted EBITDA are financial measurements of performance that management and the Board of Directors use in their financial and operational decision-making and in the determination of certain compensation programs. EBITDA and Adjusted EBITDA are supplemental performance measures that are not required by, or presented in accordance with GAAP. EBITDA and Adjusted EBITDA should not be considered alternatives to net income or any other performance measure derived in accordance with GAAP, or as an alternative to cash flows from operating activities or a measure of our liquidity or profitability.
The following table provides our EBITDA and Adjusted EBITDA for the periods presented, as well as a reconciliation to net income:
Year EndedDecember 31,
Net (gain) loss on sale of assets (233 ) 822
Loss on extinguishment of debt — 154
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Liquidity and Capital Resources
Sources of Liquidity
At December 31, 2022 and 2021, our cash and cash equivalents, net of restricted cash, was $105,177 and $53,266, respectively. We intend to fund development projects using cash flows from operations and borrowings under our revolving credit facility. We believe that we will have sufficient cash flows from operations and borrowing availability under our credit facility to meet our debt service obligations and anticipated required capital expenditures (including for projects under development) for the next 12 to 24 months. However, we are subject to business and operational risks that could adversely affect our cash flows and liquidity.
At December 31, 2022, we had debt before debt issuance costs of $72,000, compared to debt before debt issuance costs of $80,000 at December 31, 2021.
Our debt before issuance costs (in thousands) is as follows:
Revolving Credit Facility — —
Amended Credit Agreement
On December 21, 2021, the Company entered into the Fourth Amendment to the Second Amended and Restated Revolving Credit and Term Loan Agreement (the “Amended Credit Agreement”), with Comerica Bank (“Comerica”) and certain other financial institutions. The Amended Credit Agreement, which is secured by substantially all of our assets and assets of certain of our subsidiaries, provides for a five-year $80,000 term loan and a five-year $120,000 revolving credit facility.
As of December 31, 2022, $72,000 was outstanding under the term loan and we had no outstanding borrowings under the revolving credit facility. The term loan amortizes in quarterly installments of $2,000 through December 2024, quarterly installments of $3,000 from 2025 through the maturity, with a final payment of $32,000, of December 21, 2026 with an interest rate of 4.12% and 2.91% at December 31, 2022 and 2021, respectively. The revolving and term loans under the Amended Credit Agreement bear interest at the BSBY Margin or Base Rate Margin based on our Total Leverage Ratio (in each case, as those terms are defined in the Amended Credit Agreement).
The Amended Credit Agreement contains customary covenants applicable to us and certain of our subsidiaries, including financial covenants. The Amended Credit Agreement is subject to customary events of default, and contemplates that we would be in default if, for any fiscal quarter (x) the average monthly D3 RIN price (as determined in accordance with the Amended Credit Agreement) is less than $0.80 per RIN and (y) the consolidated EBITDA for such quarter is less than $6.0 million. Consolidated EBITDA is defined under the Amended Credit Agreement as net income plus (a) income tax expense, (b) interest expense, (c) depreciation, depletion, and amortization expense, (d) non-cash unrealized derivative expense, (e) any extraordinary, unusual, or non-recurring cash expenses and/or losses not exceeding $500,000 in the aggregate to the extent not included in the determination of operating income on MEH’s consolidated statements of profits and loss, (f) subject to
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Comerica’s approval, which may be granted or withheld in its reasonable credit judgment, any extraordinary, unusual, or non-recurring cash expenses or losses to the extent not included in the determination of operating income on MEH’s consolidated statements of profits and losses exceeding $500,000 in the aggregate, (g) any extraordinary, unusual, or non-recurringnon-cash expenses and/or losses not included in the determination of operating income on MEH’s consolidated statements of profits and loss, and (h) any extraordinary, unusual, or non-recurringnon-cash expenses and/or losses included in the determination of operating income on MEH’s consolidated statements of profits and loss, plus, to the extent not included in the calculation of net income, the
amount of dividends and distributions paid by the Excluded Entities (as defined in the Amended Credit Agreement) to MEH during such period minus the sum of (j) any non-cash unrealized derivative income during such period, (k) any extraordinary, unusual or non-recurring cash or non-cash income and/or gains not included in the determination of operating income on MEH’s consolidated statements of profits and loss, (l) any extraordinary, unusual, or non-recurringnon-cash income and/or gains included in the determination of operating income on MEH’s consolidated statements of profits and loss, all as determined on a consolidated basis for MEH and its subsidiaries (excluding the Excluded Entities except where an Excluded Entity is specifically included in the calculation) in accordance with GAAP.
Under the Amended Credit Agreement, we are required to maintain the following ratios:
As of December 31, 2022, we were in compliance with all financial covenants related to the Amended Credit Agreement.
The Amended Credit Agreement replaced our prior credit agreements with Comerica Bank and a portion of the proceeds of the term loan made under the Amended Credit Agreement were used by us to, among other things, fully satisfy an aggregate of $59,197 outstanding principal under such credit agreements. For additional information regarding the Amended Credit Agreement, see the sections entitled “Description of Indebtedness and Note 13—Debt to our audited consolidated financial statements.
Capital Expenditures
We have historically funded our growth and capital expenditures with our working capital, cash flow from operations and debt financing. We used the proceeds from our 2021 IPO to fund the Montauk Ag Renewables Asset Acquisition and the continued development of Montauk Ag Renewables. In 2023, we expect the development of Montauk Ag Renewables to be funded from our working capital, cash flow from operations and debt financing. We expect our non-development 2023 capital expenditures to range between $15,000 and $18,000. Our 2023 capital plans include annual preventative maintenance expenditures, annual wellfield expansion projects, critical spare expenditures, and other specific facility improvements. Additionally, we currently estimate that our existing 2023 development capital expenditures will range between $70,000 and $100,000. The majority of our 2023 development capital expenditures are related to our Pico digestion capacity increase, the ongoing development of Montauk Ag Renewables and the second Apex facility. Our Amended Credit Agreement provides us with an $120,000 revolving credit facility, with a $75,000 accordion option, providing us with access to additional capital to implement our acquisition and development strategy. We are currently in various stages of discussions regarding a variety of development and strategic growth opportunities. Development opportunities include: up to seven LFG RNG sites which we could contemplate generating renewable electricity to qualify for eRINs and up to two waste water treatment RNG opportunities. If we ultimately enter into definitive agreements for any of these opportunities, we expect to incur material capital expenditures related to either acquisitions costs or development costs, or both. As we continue to explore
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strategic growth opportunities and while we have entered into nonbinding letters of intent for certain of these opportunities, we provide no assurances that our plans related to any or all of these strategic opportunities will progress to definitive agreements. We believe that our existing cash and cash equivalents, cash generated from operations, and credit availability under our Amended Credit Agreement would allow us to pursue and close on our identified strategic growth opportunities.
Cash Flow
The following table presents information regarding our cash flows and cash equivalents for years ended December 31, 2022 and 2021:
Year EndedDecember 31,
Net cash flows provided by operating activities $ 81,066 $ 42,879
Net cash flows used in investing activities (20,794 ) (19,474 )