EDGAR 10-K Filing

Company CIK: 1730346
Filing Year: 2022
Filename: 1730346_10-K_2022_0001730346-22-000002.json

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ITEM 1. BUSINESS
Item 1. Business
Our Company
Charah Solutions, Inc. (together with its subsidiaries, “Charah Solutions,” the “Company,” “we,” “us,” or “our”) is a leading national service provider of mission-critical environmental services and byproduct recycling to the power generation industry. We offer a suite of remediation and compliance services, byproduct services, raw material sales and Environmental Risk Transfer ("ERT") services. We also design and implement solutions for complex environmental projects (such as coal ash pond closures) and facilitate coal ash recycling through byproduct marketing and other beneficial use services. We believe we are a partner of choice for the power generation industry due to our quality, safety, domain experience and compliance record, all of which are key criteria for our customers. In 2021, we performed work at more than 40 coal-fired generation sites nationwide.
Charah Solutions, Inc. was incorporated in Delaware in 2018 in connection with our initial public offering in June 2018 and, together with its predecessors, has been in business since 1987. Since our founding, we have continuously worked to anticipate our customers’ evolving environmental needs, increasing the number of services we provide through our embedded presence at their power generation facilities. Our multi-service platform allows customers to efficiently source multiple required offerings from a single, trusted partner compared to service providers with a more limited scope.
On November 19, 2020, the Company sold its Allied Power Holdings LLC (“Allied”) subsidiary engaged in maintenance, modification and repair services to the nuclear and fossil power generation industry to an affiliate of Bernhard Capital Partners Management, LP (“BCP”), the Company’s majority shareholder, in an all-cash deal for $40 million (the “Allied Transaction”) subject to customary adjustments for working capital and other adjustments as set forth in the Purchase Agreement. As described in further detail in Part II, Item 8. Financial Statements and Supplementary Data, the Company has presented Allied as discontinued operations in the accompanying consolidated financial statements and related notes.
We operate as a single operating segment, reflecting the suite of end-to-end services we offer our utility partners and how our chief operating decision maker reviews consolidated financial information to evaluate results of operations, assess performance and allocate resources for these services. We provide the following services through our one segment: remediation and compliance services, byproduct services, raw material sales and ERT services. Remediation and compliance services are associated with our customers’ need for multi-year environmental improvement and sustainability initiatives, whether driven by regulatory requirements, power generation customer initiatives or consumer expectations and standards. Byproduct services consist of recurring and mission-critical coal ash management and operations for coal-fired power generation facilities while also supporting both our power generation customers’ desire to recycle their recurring and legacy volumes of coal combustion residuals (“CCRs”), commonly known as coal ash, and our ultimate end customers’ need for high-quality, cost-effective supplemental cementitious materials (“SCMs”) that provide a sustainable, environmentally-friendly substitute for Portland cement in concrete. Our raw materials sales provide customers with the raw materials that are essential to their business while also providing the sourcing, logistics, and management needed to facilitate these raw materials transactions around the globe. ERT services represent an innovative solution designed to meet utility customers' evolving and increasingly complex plant closure and environmental remediation needs. These customers need to retire and decommission older or underutilized assets while maximizing the asset's value and improving the environment. Our ERT services manage the sites' environmental remediation requirements, benefiting the communities and lowering the utility customers' costs.
As a result of our comprehensive offerings, the embedded nature of our on-site presence, our domain experience, and our track record of successful execution, we have built long-term relationships with leading U.S. regulated utilities and independent power producers, including Dominion Energy, Inc., Duke Energy Corporation, Dynegy Inc., PPL Corporation, The Southern Company, and Consumers Energy, among others. These relationships have spanned more than 20 years in some cases. Our operational footprint's national scale is also a key competitive differentiator, as many competitors are localized, focusing on a single geographic area (sometimes isolated to a single plant). We operate in more than 20 states, resulting in an overall footprint and density in key markets that we believe are difficult to replicate. We believe our national reach enables us to successfully pursue new business within our existing customer base and attract new customers while providing consistent quality, safety, and compliance standards.
Our services platform is led by a senior executive team with deep industry experience and is supported by a highly skilled labor force. The nature of our work requires employees to have specialized skills, training, and certifications for them to be allowed on-site at our customers’ facilities. Collectively, our focus on human capital management enables us to maintain and develop a labor force of highly qualified, well-trained personnel capable of handling our customers’ needs.
Market Opportunity
The U.S. power generation industry is composed of critical infrastructure providing essential electric power to communities nationwide. According to the U.S. Energy Information Administration (the “EIA”), as of 2019, there were approximately 500 large-scale facilities in the United States with generation capabilities of at least 250 megawatts, including more than 150 coal-fired power plants. With near-constant demand from consumers and industry, these facilities' continuous operation is critical given potentially high economic and reputational costs of downtime. These complex facilities have specialized and recurring environmental and compliance service needs to maintain continuous operations throughout their lifecycles. These service needs are particularly significant for coal-fired plants due to the increasing demands of environmental regulation, the aging nature of the installed base, and the feedstock characteristics required to power such facilities. Due to the breadth and scope of these service needs, power plant operators typically do not possess the necessary capabilities internally and instead outsource these mission-critical and often regulatory-driven requirements to a fragmented set of service providers. Many significant dynamics support the continuing need for these specialized services.
Coal-Fired Power Plants Have Significant and Recurring Environmental Management Needs Associated with Their Waste Byproducts
Coal-fired power plants consistently generate various waste byproducts throughout the power generation process. The primary type of these waste byproducts is CCRs. CCRs come in multiple forms, including fly ash, bottom ash, and boiler slag, and are collected throughout the coal burning process. Although not considered a hazardous waste under the Resource Conservation and Recovery Act, as amended (the “RCRA”), utilities have significant regulatory and reputational risks associated with the handling and disposal of coal ash. According to the American Coal Ash Association, approximately 70 million tons of coal ash were produced in 2020, the latest year for which data is available. Coal ash management is mission-critical to coal-fired power plants' daily operations as they generally have on-site storage capacity for only three to four days of CCR waste accumulation. This limited coal ash storage capacity requires continuous daily monitoring, handling, transportation, and disposal to enable ongoing power plant operation. The U.S. Environmental Protection Agency (the “EPA”) has estimated that coal-fired utilities spend approximately $2.9 billion per year on coal ash management. Power plant operators typically engage specialized service providers to conduct this critical recurring activity on-site alongside their plant personnel.
Large Installed Base of Legacy Coal Ash Disposal Ponds That Require Remediation
Collected coal ash is disposed of or beneficially used (recycled) in a range of applications. According to the American Coal Ash Association, utilities disposed of approximately 41% of coal ash produced in the United States during 2020. According to EPA data published, of the CCRs generated that were not beneficially used, approximately 80% were disposed in on-site disposals units, with the balance transported and disposed of off-site at third-party landfills. For many years, coal-fired power plants relied on ash ponds as the primary disposal locations for CCRs. The vast majority of these older inactive and older existing ash ponds were constructed without the design standards now mandated by regulation to prevent harm to the environment, and those ponds will require remediation or closure in the future. The EPA estimated that there are more than 1,000 active and inactive on-site landfill and surface impoundments, substantially all of which will require remediation or closure. These sites will require significant capital expenditures from their owners and specialized environmental expertise to monitor them on an ongoing basis, remediate and relocate the waste, or completely close.
Power Plant Operators Are Increasingly Focused on Environmental Stewardship and Regulatory Compliance
Power plant operators face increasing pressure from regulators, advocacy groups, and their communities to manage the environmental risks associated with their operations. Therefore, the industry is increasingly focused on environmental stewardship. Due to the potentially considerable consequences of environmental liabilities, spending on environmental liability management has increased over time and is expected to increase in the future.
Additionally, power plants are highly regulated by environmental authorities at the federal, state, and local government levels, which have recently added compliance requirements. A recent example is the Disposal of Coal Combustion Residuals From Electric Utilities; Final Rule (the “CCR Rule”). The EPA enacted the CCR Rule in April 2015 in response to two significant coal ash spills in Kingston, Tennessee and Eden, North Carolina, that caused widespread environmental damage. The CCR Rule regulates the disposal of coal ash as a solid waste. It established new requirements for the closure and remediation of existing coal ash ponds and restrictions on the location of new ash ponds. The CCR Rule will result in significant incremental environmental management costs for many industry participants. Also, the power generation industry is proactively implementing environmental best practices across their assets, even when not yet required by law.
Recycling Waste Byproducts Is a Critical Component of the Coal Ash Value Chain
Coal ash can be recycled to produce positive environmental, economic, and performance benefits, such as lower greenhouse gas (“GHG”) emissions, reduced use of other natural resources and improved strength and durability of materials.
According to the American Coal Ash Association, approximately 41 million tons, or 59%, of coal ash produced in the United States was beneficially used in 2020. The leading beneficial use of coal ash is as a direct and more economical substitute for cement during the production of concrete (approximately 11 million tons of CCRs production and use in 2020). There are many good reasons to view coal combustion residuals as a resource rather than a waste. Recycling them conserves natural resources and saves energy.
In many cases, products made with CCRs perform better than products made without them. For instance, coal fly ash makes concrete stronger and more durable. It also reduces the need to manufacture Portland cement, resulting in approximately 12 million tons of greenhouse gas emissions reductions each year. An economic analysis by the American Road and Transportation Builders Association estimates that coal fly ash used in roads and bridges saves approximately $5.2 billion per year in U.S. construction costs. Additionally, technologies currently available, including our EnviroSourceTM multi-process ash beneficiation technology, improve the characteristics of certain types of coal ash, making them more viable for recycling purposes and ultimately increasing the addressable market of recyclable coal ash.
Coal Power Generation Remains an Important Energy Source
According to the EIA, while renewable energy and natural gas sources are expected to provide an increasing share of U.S. domestic energy production, coal-fired power generation is expected to remain a key baseload energy source for decades, providing at least 0.9 trillion kilowatt-hours of energy production annually through 2050. In 2020, coal power generation accounted for approximately 20% of domestic U.S. energy generation. Coal power generation is projected to increase to 23% between 2021 and 2022, following a decline during 2020 from lower demand due to the coronavirus (“COVID-19”) pandemic and increasing demand for competing fuels used for power generation. Despite short-term improvements, coal-fired capacity will continue to shrink. Based on current plans, the EIA projects the removal of about 2.7 gigawatts (“GW”) of coal power generation capacity in 2021, following the loss of about 9.4 GW in 2020. From 2021 to 2025, the EIA forecast that about 25.2 GW of coal-fired capacity will be removed. Although other energy generation sources, such as natural gas and renewables, are expected to make moderate gains on a percentage contribution basis, we believe the aggregate demand for coal power generation will remain consistent as the installed base of coal plants is deeply entrenched throughout the U.S. national power grid.
The Power Generation Industry Increasingly Requires Larger Scale Environmental Service Providers
The mounting burden of environmental compliance, the constant need to maintain aging facilities, and the focus on continuous and safe plant operations have the power generation industry, particularly the coal-fired energy producers, increasingly seeking to partner with outsourced service providers having a larger and broader scale that can provide a range of services on their behalf. Most prospective service providers either have narrow service offerings or a highly localized geographic focus (sometimes limited to a single plant). Few service providers can offer broad service capabilities with a track record of quality service, exceptional safety, exacting environmental standards, and a reliable labor force like Charah Solutions.
According to the EIA, after substantial retirements of U.S. coal-fired electric generating capacity from 2015 to 2020 that averaged 11.0 GW a year, coal capacity retirement slowed to less than 5.0 GW in 2021. However, we expect the retirement of coal-fired generators to increase again this year; 12.6 GW of coal capacity is scheduled to retire in 2022, or 6% of the coal-fired generating capacity.
U.S. coal plants are retiring as the coal fleet ages and as coal-fired generators face increasing competition from natural gas and renewables. According to the EIA, power plant owners and operators have reported that they plan to retire 28%, or approximately 59.0 GW, of the coal-fired capacity currently operating in the United States by 2035. Since 2002, around 100 GW of coal capacity has retired in the United States, and the capacity-weighted average age at retirement was 50 years. As of September 2021, 212 GW of utility-scale coal-fired electric-generating capacity was operating in the United States, most of which was built in the 1970s and 1980s.
After a coal-fired plant is retired, the site will undergo a multi-year decommissioning, remediation and closure process. Remediation of CCRs is the main focus of coal plant decommissioning. Depending on the facility, CCRs are disposed of in on-site landfills or coal ash ponds or are beneficially reused in other products.
Many utilities are experiencing an increased need to retire and decommission older or less economically viable generating assets while minimizing costs and maximizing the asset's value and improving the environment. Our ERT services allow these partners to remove the environmental risk and insurance obligations and place control and oversight with a company specializing in these complex remediation and reclamation projects. We believe our broad set of service capabilities, track record of quality service and safety, exacting environmental standards, and a dependable and experienced labor force is a significant competitive advantage. Our work, mission and culture are directly aligned with meeting environmental, sustainability, and governance (“ESG”) standards and providing innovative services to solve our utility customers’ most
complex environmental challenges. We believe that we are an industry leader in quality, safety, and compliance, and we are committed to reducing greenhouse gas emissions and preserving our environment for a cleaner energy future.
Our Strengths
We believe our company has become a leader in providing mission-critical environmental services to the power generation industry. Our strengths that support our leading position include:
Industry-Leading Quality, Safety, and Compliance
We believe we are a partner of choice for our customers due to our reputation as a leader in quality, safety, and compliance. Utilities and independent power producers are generally risk-averse and focus on environmental and safety considerations as crucial factors for awarding on-site service provider contracts. We believe our reputation for and dedication to quality, industry-leading safety record, and adherence to environmental compliance standards provide a distinct competitive advantage and differentiate us from many of our competitors. We believe we have developed trusted relationships and credibility with regulatory agencies supported by our team of in-house compliance experts. We pride ourselves on being a reliable partner to our customers, consistently delivering high-quality, efficient, and on-time service.
These attributes are vital contributors to our leading market share positions. Our leading capabilities position us well for potential new business as customers recognize the value of engaging a proven service partner.
Broad Platform of Mission-Critical Environmental Services
Our broad platform of essential environmental services has enabled us to become a leading service provider to our power generation customers. In our end markets, we are a leading national service provider offering a suite of remediation and compliance services, byproduct services, raw material sales and ERT services. Our multi-service platform allows customers to gain efficiencies from sourcing multiple required offerings from a single, trusted partner compared to service providers with a more limited scope.
The national scale of our operational footprint is also a key differentiator, as many of our competitors are localized, focusing on a single geographic area (sometimes isolated to a single plant). We operate in more than 20 states across the country, resulting in an overall footprint and density in key markets that we believe are difficult to replicate. Our national reach enables us to successfully pursue new business within our existing customer base and attract new customers while providing consistent quality, safety, and compliance standards.
Long-Term Partnerships with Leading Power Generators
Our customers are some of the largest power generation companies in the United States, including Dominion Energy, Inc., Duke Energy Corporation, Dynegy Inc., PPL Corporation, The Southern Company and Consumers Energy. Given our services' essential nature, our on-site personnel becomes integrated into each facility's daily procedures, seamlessly working with utility employees to provide uninterrupted continuous operations. Our co-location and integration into our customers’ daily operations result in direct relationships with key decision-makers at every level of our customers’ organizations. We believe this embedded partnership deepens customer connectivity and drives longer customer tenure. In some cases, these relationships have spanned more than 20 years. For example, LG&E and KU Energy LLC, which PPL Corporation currently owns, have been customers for more than 20 years. We have also demonstrated the ability to grow our service offerings with a single customer. We first provided Duke Energy Corporation with byproduct services in 2001 at two plants, and we now provide all of our coal-related services across nine of their plants. We believe these long-term relationships are critical for renewing existing contracts, winning incremental business from existing customers at new sites, and adding new customers.
Innovative Solutions to Our Customers’ Environmental Challenges
Our customers regularly face complex, large-scale environmental challenges that require bespoke, technical solutions. We believe we have a proactive and differentiated approach to solving these challenges. Our internal technical and engineering experts have developed in-depth domain knowledge and capabilities in environmental remediation and the beneficial use of coal ash due to our long-term and significant experience in the sector. We believe this credibility, combined with an entrepreneurial mindset, enables us to source market opportunities not readily available to our competitors.
For example, we demonstrated this innovative approach for a major reclamation project at the Asheville Regional Airport in North Carolina. In the course of remediating an on-site ash pond at a nearby coal power plant, we had the vision to beneficially use that ash as structural fill to support a newly constructed taxiway at the airport. Our engineers designed a state-of-the-art, highly engineered structural fill system to capture the ash in an environmentally sound way. Asheville Regional Airport saved approximately $12 million by using coal ash instead of traditional materials, and approximately 4 million cubic yards of coal ash from an ash pond were beneficially used. We believe this innovative approach, coupled with new technologies and processes, generates additional value for our customers and stockholders.
Furthermore, our ERT turnkey project for Consumers Energy in Michigan is another example of our creative solutions to a complex problem. Remediating the existing ash ponds at the B.C. Cobb facility was part of the site's post-closure regulation requirements and sustainability objectives. Additionally, the utility and the community wished to further advance the wetlands along the eastern shore of Lake Michigan. We provided Consumers with a cost-effective proposal to meet these goals, provide remediation of the ponds and repurpose the site to natural wetlands.
We further demonstrated our innovative approach to customer’s environmental challenges through our turnkey ERT services in acquiring the Texas Municipal Power Agency's Gibbons Creek Steam Electric Station and Reservoir in Grimes County, Texas. As part of the asset purchase agreement, the Company, through one of its subsidiaries, acquired the 6,166-acre area that included the closed power station and adjacent property, the 3,500-acre reservoir, dam and spillway and assumed responsibility for the shutdown and decommissioning of the coal power plant as well as the performance of all environmental remediation work for the site landfills and ash ponds. As a sustainability leader in utility services, the Company is redeveloping the property in an environmentally conscious manner designed to expand economic activity and benefit the surrounding communities through job creation, promotion of industry, support of the tax base, as well as restoring the property to a state that will enable it to be put to its best potential use.
Entrepreneurial Management Team Supported by Highly Skilled Labor Force
We are led by an experienced management team with an entrepreneurial mindset and a keen focus on safety and customer service. Our senior executive team consists of industry veterans with deep industry experience, helping us provide high-quality operational execution and solidify long-term customer relationships. In addition to a commitment to developing internal talent, we have made key strategic external hires to deepen our expertise further. Our entrepreneurial mindset drives us to continually search for new ways to maximize customer relevance and develop innovative solutions.
Our customers have unique certification and training requirements for the service providers they allow on-site. Our ability to hire, develop, and retain a highly-skilled labor force with specialized skills, training, and certifications is a critical differentiator in the sector. We also have a dedicated team of in-house professionals that focus exclusively on training, certification, and mentorship. As part of our commitment to safety and compliance, each of our on-site employees must complete a unique, rigorous training program. We train our managers to lead from the front line and share, involve, and support their teams. Our ability to staff large-scale projects rapidly is also critical. Collectively, our human capital management allows us to maintain and develop a labor force of highly qualified, well-trained personnel capable of handling our customers’ needs.
Our Growth Strategy
Expand Market Share by Capitalizing on the Significant Needs of Power Generation Customers
We have a substantial growth opportunity in the near term as U.S. coal-fired power generation facilities continue to remediate and close coal ash ponds and landfills. These projects are triggered as coal power plant operators preemptively manage environmental liabilities, comply with regulatory requirements (at the local, state, and federal levels), and work to meet consumer standards for environmental sustainability. We believe there are $75 billion in coal ash remediation opportunities in the United States, driving a need for creative remediation solutions, including the beneficiation of ash. We estimate there are more than 1,000 active and inactive landfills and surface impoundments, substantially all of which will require remediation or closure. We expect that customer spending for our core services, including ash pond and landfill remediation, will increase significantly over the next three to five years in response to these remediation requirements. We believe spending on coal ash management will increase due to our customers’ increased focus on environmental stewardship.
Continue to Grow On-Site Services Revenue by Expanding Our Offerings
We believe our broad platform of services is a competitive differentiator and, therefore, continuing to enhance the breadth of services offered to our existing customers is a key growth opportunity. We are a trusted partner and our team is embedded with the customer on-site to handle its most critical operational needs. As a result, we are well-positioned to identify relevant, attractive service offerings to add to our portfolio. We believe significant opportunities exist in remediation and compliance services and byproduct services across our platform. We have earned our reputation as the premier one-stop solution to the power generation industry for ash pond remediation and compliance, environmentally friendly ash recycling and daily ash operations. We believe our customers will continue to find value in a full-service platform and source incremental services from us as an existing, on-site, trusted partner.
Leverage New and Existing Customer Relationships to Maximize Fleet-Wide Opportunities
The trend among our customers is to consolidate service providers. Given the breadth of our service offerings and our access to our customers’ senior decision-makers, we believe we are well-positioned to deepen our relationship with current customers by providing our services to other coal-fired power plants within their fleets. We see an opportunity to increase this percentage meaningfully. We will also seek to generate business with new utility customers and compete fleet-wide across their power plant footprints. We see similar opportunities in international geographies.
Invest in Innovative Technologies, Processes, and Solutions
We believe investments in new technology and processes present opportunities to provide higher-margin offerings while improving the environment. Our operations' embedded nature gives us a superior understanding of unique customer problems allowing us to deploy innovative solutions. We believe there are opportunities for technological innovation in environmental compliance and stewardship. For example, our EnviroSourceTM ash beneficiation technology provides an innovative new proprietary thermal process for fly ash beneficiation. This technology converts previously unusable coal ash into consistent, high-quality fly ash that meets industry specifications, increasing marketable fly ash supply to concrete producers nationwide. We expect these innovative technologies will allow us to optimize our traditional fly ash sales and distribution, enter new markets for our products, and provide cleaner, environmentally friendly solutions to our customers. We intend to continue to invest in new technologies and other processes that expand our portfolio of solutions and further establish us as an innovator in our industry.
Our Services
We deliver services and solutions to the power generation industry through one reportable segment. We have over 30 years of experience constructing, operating, and managing structural fill projects for coal-fired utilities and assisting coal-fired utilities in beneficially using waste byproducts. We offer a suite of end-to-end services providing remediation and compliance services, byproduct services, raw material sales and ERT services. Our remediation and compliance services primarily include environmental management of landfills for coal-fired power generation facilities and new and existing active pond management, including closure by removal, cap-in-place, and design and construction of new ponds. Additional service offerings include all aspects of landfill development, construction, and management. Our remediation and compliance services teams can also provide site evaluation and characterization; preliminary design and cost estimates with life-cycle analysis; hydrogeological assessments; groundwater and containment modeling; permit application and processing for expansions and greenfield sites; design engineering; construction of landfills and cap and cover systems; conversion of impoundments to landfill sites; quality assurance and quality control and documentation; engineered fills (off-site) and other related services.
Our byproduct services offerings include recycling recurring and contracted volumes of coal-fired power generation waste byproducts, such as bottom ash, fly ash, and gypsum byproducts, as sustainable and environmentally-friendly construction materials. These byproducts can be used for various industrial purposes, including producing concrete products as a replacement for Portland cement. Our dedicated sales and marketing team has a national presence, and it works with many of the nation’s largest power generators to identify opportunities to improve each customer’s long-term position in the market while providing concrete producers with the consistent fly ash sourcing they need. With various coal sources being utilized across the power generation industry, we evaluate, process, and market the different bottom ash products to achieve the highest value for a given market area. Our byproduct services offerings also include coal ash management, which is mission-critical to the daily operations of power plants as they generally only have on-site storage capacity for three to four days of CCR waste accumulation. These services offerings focus on recurring and daily onsite management operations for coal-fired power generation facilities to fulfill our customers' environmental service needs in handling their waste byproducts. These services include silo management, on-site ash transportation and capture and disposal of ash byproducts from coal power operations. Our operations cover the management of a wide variety of combustion byproducts, including bottom ash, flue gas desulfurization ("FGD") gypsum disposal, Pozatec/fixated scrubber sludge disposal, and fluidized bed combustion fly ash disposal. We coordinate all aspects of the ash management operation, from processing and screening for sales to facilitating economical disposal.
Our raw materials sales provide customers with the raw materials that are essential to their business while also providing the sourcing, logistics, and management needed to facilitate these raw materials transactions around the globe.
Our ERT services represent an innovative solution designed to meet the utility customers' evolving and increasingly complex plant closure and environmental remediation needs. These customers need to retire and decommission older or underutilized assets while maximizing the asset's value and improving the environment. Our ERT services manage the sites' environmental remediation requirements benefiting the communities and lowering utility customers' costs. We provide a custom, environmentally-friendly approach to these large-scale projects that removes the liability from the utility through the acquisition of the property. We then provide environmental remediation of the ash ponds and landfills to meet all local, state and federal regulations. We will then redevelop the property upon project completion for public use, which typically includes natural habitat restoration for marine and other wildlife.
Safety Record
Utilities and independent power producers are focused on environmental and safety considerations as crucial factors for awarding on-site service provider contracts. We believe our strong safety record provides a distinct competitive advantage. We believe we have developed trusted relationships and credibility with regulatory agencies and utilities over the past 30 years
due to our long-standing safety record supported by an experienced team of in-house safety and regulatory compliance professionals.
Safety is integral to our culture and our results, and it is one of our core values. We believe we operate under the strictest safety standards, and we are committed to maintaining a safe working environment. Our dedicated in-house team of safety professionals develops and trains our employees and subcontractors to perform their jobs safely and proactively contribute to a safe workplace. This expert team includes highly trained professionals who are accredited Occupational Safety and Health Administration trainers, along with full-time transportation specialists in both over-the-road and rail operations.
We recognize the unique safety issues related to working with our utility industry partners. Our Engineering, Environmental, and Quality Group has the expertise and experience to ensure our operations are compliant with local, state, and federal regulations and exceed our industry's customary safety standards.
Sales and Marketing
Our MultiSource® materials network is a unique distribution system of nearly 40 locations serving the United States, Mexico, and Canada with sourcing, transportation modes, and distribution options that ensure a steady and reliable supply of supplementary cementitious materials (“SCMs”). The MultiSource® materials network provides SCMs to markets where they are needed and sufficient storage to level out seasonal supply and demand fluctuations. Logistics support must include an established network of transportation options, including truck, rail, and barge, as well as sufficient storage and supply capabilities to meet the on-time delivery requirements of customers. By combining the strengths of our EnviroSourceTM ash beneficiation technology, the proven MultiSource® network, and strategic investment in logistics infrastructure, we can meet demand in regions not previously attainable while maintaining a competitive price, consistent quality and supply for concrete producers.
Our dedicated sales and marketing team has built successful and long-term relationships with the nation’s largest power generators. We think we can leverage the deep connections and strong operational track record we have built to broaden our on-site presence and deepen client partnerships. We also seek to grow our business with new power generation customers and compete enterprise-wide across their power plant footprints. Through close connections with utility management and personal relationships developed daily by our network of embedded field teams of regional managers and site managers, we believe we understand our customers’ needs and that we can quickly respond to their project requirements and provide creative solutions. Our team includes professional engineers, experienced site managers, and seasoned estimators who strive to be detailed, accurate, and upfront, enabling us to minimize contract modifications after the work begins. We employ what we refer to as a “zippered” organizational approach to customer service and marketing, leveraging relationships up and down the organization. By structuring our organization around our customers’ needs through this unique network of regional field operations managers, we ensure that projects are completed on time and within budget. Additionally, we can quickly recognize opportunities to cross-sell and market our services.
Customers
We have developed our long-term, committed relationships to become a preferred provider to many of the largest power generation companies in the United States. In 2021, we performed work at more than 40 plants for more than 20 “blue-chip” entities, including Ameren Corporation, Big Rivers Electric Corporation, Consumers Energy, Dominion Energy, Inc., Duke Energy Corporation, Hoosier Energy Rural Electric Cooperative, Inc., NRG Energy, Inc., PPL Corporation, The Southern Company and Vistra Corp. The majority of our power generation clients have investment-grade credit ratings. During the year ended December 31, 2021, three customers accounted for 36% of total consolidated revenue. As of December 31, 2021, these three customers accounted for 18% of total consolidated trade accounts receivable, net. If a major customer decided to stop purchasing our services, revenue could decline, and our operating results and financial condition could be adversely affected.
Award Status
In 2021, we won approximately $840 million in contracted new awards, the largest in the Company's history, as compared to $715 million and $430 million in 2020 and 2019, respectively. Though the timing of future awards is difficult to determine, we believe we are well-positioned to capture a significant portion of a large and growing addressable market.
Joint Ventures and Contractual Arrangements
A portion of our byproduct services was provided through the following two joint ventures:
Ash Venture Joint Venture
In December 2013, we formed Ash Venture LLC, a North Carolina limited liability company (“Ash Venture”), which provides ash management and marketing services to the utility industry. Ash Venture is a joint venture between Charah, LLC, a Kentucky limited liability company and our wholly-owned subsidiary (“Charah”), and Titan America, LLC, an unrelated third
party. Charah owns 67% of Ash Venture, and the third party owns 33%. During the year ended December 31, 2021, the agreement to provide ash management and marketing services with the third-party utility partner came to its conclusion, and the joint venture began settling its remaining current assets and liabilities through the normal course of business.
Equity Method Investment
In January 2016, we formed CV Ash, a joint venture with VHSC Holdings, LLC, an unrelated third party, which markets and sells fly ash to the ready-mix concrete market. We account for the joint venture under the equity method. Charah and the third party each own 50% of the joint venture. During the first quarter of 2021, the CV Ash joint venture relationship ended, and the joint venture began settling its remaining current assets and liabilities through the normal course of business.
Competition
The power and environmental services industries are highly fragmented across regional competitors. A limited subset of competitors provides a national presence, few of which offer the same spectrum of services we provide. Our competitors consist of a mix of large environmental and waste management businesses that do not specialize in ash management services and hundreds of regional and local companies with limited-service areas, typically servicing only one to three sites each. The highly fragmented and regional nature of our industry has produced a limited number of competitors with a national scope.
We are a leading national service provider offering a suite of coal ash management and recycling services to the power generation industry. While some competitors are significantly engaged in one of the core areas in the power or environmental services value chain, many have limited or no engagement in most of our core areas.
Seasonality
Based on historical trends, we expect our operating results to vary seasonally due to demand within our industry as well as weather conditions. For additional information on the effects of seasonality on our operating results, see “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations-Key Factors Affecting Our Business and Financial Statements-Seasonality of Business.”
Risk Management and Insurance
The nature of our business exposes us to liabilities arising out of our operations, including possible damages to the environment. Such potential liabilities could involve, for example, claims for remediation costs, personal injury, property damage, and damage to the environment, including natural resources, claims of employees, customers, or third parties for personal injury or property damage occurring in the course of our operations, or claims alleging negligence or other wrongdoing in the planning or performance of work. We could also be subject to fines, civil and criminal penalties and other sanctions in connection with alleged violations of regulatory requirements that could be significant. We maintain general liability, contractor’s pollution liability policies (as well as additional pollution and remediation policies as needed), vehicle liability, employment practices liability, fiduciary liability, directors’ and officers’ liability, workers’ compensation, property, and employer’s liability coverages. We also maintain umbrella liability policies to provide excess coverage over the underlying limits contained in these primary policies.
Regulation
Our coal-based generation utility customers are subject to various federal, state, and local environmental laws and regulations. Our operations and services for these utility customers are subject to many of the same environmental laws and regulations that govern the host utility site. These environmental laws and regulations, among other things, impose limits on the discharge of pollutants into the air and water, and they establish requirements for the treatment, storage, and disposal of solid and hazardous materials, remediation of releases of hazardous substances, and reclamation of land. Compliance with applicable environmental laws and regulations adds to the cost of doing business. Moreover, to establish and operate power plants and collect, transport, and manage CCRs, our customers and we have obtained various federal, state, and local environmental permits. We must comply with these permits or processes and procedures approved by regulatory authorities. Any failure to comply with these laws or regulations, permits, or processes and procedures could result in the issuance of substantial fines and penalties or other sanctions and may cause us (or our customers) to incur environmental or reclamation liabilities or subject us (or our customers) to third-party claims.
We generally perform our remediation and compliance and byproduct service offerings on-site at the host utility power plant. As such, the utility holds permits for our operational activities performed on-site. We secure any necessary permits at facilities that we own or lease.
Despite the safeguards we follow, our operations entail risks of regulatory noncompliance or releases of hazardous substances that could create an environmental liability.
Regulations Affecting the Company
Our service offerings are subject to environmental laws and regulations that can increase operating costs and give rise to increased risk of regulatory noncompliance and environmental liabilities.
• Resource Conservation and Recovery Act. RCRA Subtitle C regulates the handling, transporting, and disposing of hazardous waste. RCRA Subtitle D regulates non-hazardous wastes and delegates authority to states to develop solid waste programs. In 1991, the EPA issued final regulations under RCRA Subtitle D, which set forth minimum federal performance and design criteria for municipal solid waste garbage landfills. In 2015, the EPA published regulations under RCRA Subtitle D for CCRs generated by the electric utility industry. Subtitle D municipal solid waste regulations are implemented by the states, although states can impose more stringent requirements than the Subtitle D standards. The CCR Rule regulates the disposal of CCRs under RCRA Subtitle D as non-hazardous wastes, as discussed below.
• EPA CCRs Rule. As a CCR, coal ash had previously mainly been exempted from regulation under the RCRA by the “Bevill amendment” and, therefore, was subject to state-level solid waste regulations. However, after a major spill at a Tennessee Valley Authority site in Tennessee in 2008, the EPA began a rulemaking process to regulate CCRs. That process ended with the publication in April 2015 of the CCR Rule to regulate the disposal of CCRs, including fly ash, bottom ash, and flue gas desulfurization products generated at coal-fired power plants. The CCR Rule, among other things, regulates CCRs as non-hazardous waste and imposes new standards for location, groundwater monitoring, and dam stability on surface impoundments and requires long-term monitoring of existing and new surface impoundments and landfill facilities. The CCR Rule also preserves an exemption for CCRs when used for beneficial purposes. In March 2018, the EPA issued proposed Phase-1 1-Part rules to reconsider certain sections of the CCR Rule. In July 2018, the EPA issued a final Phase-1 1-Part rule to modify the CCR Rule to establish the program to grant states authorization with approved CCR permit programs under the Water Infrastructure Improvements for the Nation Act (the “WIIN Act”). The Phase-1 1-Part rule also allows CCRs to be used during certain closure situations and addresses certain matters remanded to the EPA by the D.C. Circuit Court of Appeals in June 2016. The EPA intends to reconsider and propose additional regulations to address litigation decisions by courts related to CCRs.
• WIIN Act. In December 2016, Congress passed the WIIN Act, which, among other things, establishes state primacy for enforcement of the CCR Rule. The WIIN Act directed the EPA to provide guidance to states on issuing state regulations to manage the CCR program. The EPA published the Coal Combustion Residuals State Permit Program Guidance Document (Interim Final) in August 2017. States may now submit their regulatory programs for CCRs and receive EPA approval provided they are equivalent to or more stringent than federal guidelines. As noted above, the rule finalized by the EPA in July 2018 further implements the WINN Act's objectives by allowing states or the EPA to incorporate flexibilities into their coal ash permit programs.
•Groundwater Protection. On January 11, 2022, the EPA took action to enforce the CCR Rule to expand and strengthen the regulation for coal ash and groundwater management of regulatory mandated surface impoundments and landfills for CCRs. The announced plans re-state the EPA’s consistently held position that surface impoundments or landfills cannot be closed with coal ash in contact with groundwater and provide for enforcement mechanisms for the regulation. The EPA rule provided remediation and closure criteria for leaking ash ponds, criteria for the location of new ash ponds, and water regulations on power plant discharges, resulting in approximately 1,000 regulatory mandated surface impoundments that needed to be remediated or closed. In addition, the EPA announced proposed decisions on requests for extensions to the current deadline for initiating closure of unlined CCR surface impoundments and accelerating plans to close coal ash ponds at plants in four states. This new rule will continue the increase in environmental management costs for many industry participants.
The CCR Rule affirms that beneficial uses of CCRs remain exempt from federal waste regulation under the RCRA’s “Bevill amendment.” The regulation defines beneficial use as where CCRs provide a functional benefit, substitute for the use of virgin material, meet the product specifications, follow established specifications for use, and are environmentally equivalent to the material that they substitute for or are below all thresholds for safety and environmental impact. In February 2014, the EPA released a report determining that the use of fly ash in concrete constitutes a beneficial use, and the CCR Rule notes explicitly that the incorporation of fly ash in concrete, as a replacement for Portland cement, is one of “the most widely recognized beneficial applications” of CCRs. The CCR Rule indicates that the use of CCRs in applications such as road base generally would qualify as beneficial use, so long as relevant regulations and guidelines are followed.
Both industry and environmental organizations have challenged the CCR Rule. The D.C. Circuit Court of Appeals has ruled on several cases involving CCRs. The D.C. Circuit Court remanded certain provisions of the CCR Rule back to the EPA
to address through modification of the rules. The D.C. Circuit decision has indicated that CCR disposal or storage units that have only clay liners are not protective, and the EPA must now address the impacts of this decision on the CCR rules.
In September 2016, the U.S. Commission on Civil Rights (the “Civil Rights Commission”) issued a report which determined that CCR disposal facilities can negatively impact environmental justice communities. While the Civil Rights Commission cannot require changes to EPA regulations, environmental organizations may seek to use the Civil Rights Commission’s report to spur the EPA to make regulatory changes.
In July 2018, the EPA issued a final rule extending the deadline for the closure of certain impoundments and adopting other substantive changes. In August 2018, the D.C. Circuit Court of Appeals vacated and remanded portions of the CCR Rule. In December 2019, the EPA addressed the deficiencies identified by the court and proposed amendments to change the closure deadline to August 31, 2020, but allow certain extensions. The EPA extended the comment period on this legacy CCR surface impoundment advance notice of proposed rulemaking through February 23, 2022 on three proposals and until March 25, 2022 on a fourth proposal.
Regulations Affecting the Coal Industry
The services offerings are dependent upon managing CCRs produced by our customers, typically coal-fired power plants. Coal-fired power plants and the coal industry are generally highly regulated under federal and state law. Regulation affecting this industry is ever-evolving, including the following:
• Clean Air Act. The federal Clean Air Act of 1970 and subsequent amendments, particularly the Clean Air Act Amendments of 1990 (as amended, the "CAA"), and corresponding state laws and EPA regulations (discussed below), regulate the emission of air pollutants such as SOx, NOx, particulate matter (“PM”), and ozone. The EPA finalized more stringent ambient air quality standards for fine PM in January 2013 and ozone in October 2015 and issued a final policy assessment for NOx in April 2017 and a draft policy assessment for SOx in August 2017. The EPA concluded that the current primary NOx standard is adequate, but has not taken additional steps concerning the SOx standards. Utilities have been required to make changes, such as changing fuel sources, installing expensive pollution control equipment, and, in some cases, shutting down plants to meet EPA emissions limits. On January 20, 2021, the current administration 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 administration’s policies. As a result, the degree to which certain recent regulatory developments may be modified or rescinded is unclear. The executive order also established an Interagency Working Group on the Social Cost of Greenhouse Gases (“Working Group”), which is called on to, among other things, develop methodologies for calculating the “social cost of carbon,” “social cost of nitrous oxide” and “social cost of methane.” The Working Group filed its final recommendations on January 25, 2022. with the public comment period ending on February 15, 2022. The recommendations are currently undergoing external scientific peer review managed by a contractor of the EPA. Further regulation of air emissions and uncertainty regarding the future course of regulation could eventually reduce the coal demand.
•National Ambient Air Quality Standards. The CAA requires the EPA to set National Ambient Air Quality Standards (“NAAQS”) for six pollutants considered harmful to public health and the environment (“criteria pollutants”). Areas that are not in compliance with these standards are considered “non-attainment areas.” In recent years, the EPA has adopted more stringent NAAQS for these criteria pollutants that could directly or indirectly impact coal plants by designing new non-attainment areas. This could prompt local changes to permitting or emissions control requirements, as prescribed by federally mandated state implementation plans that require emission source identification and emission reduction plans. Final rules may require significant investment in emissions control technologies by our customers in the electric power generation industry and could affect coal demand. For example, in 2015, the EPA finalized the NAAQS for ozone pollution and reduced the limit to 70 parts per billion (ppb) from the previous 75 ppb standard. The final rule was challenged in the D.C. Circuit. On April 7, 2017, the EPA advised the D.C. Circuit that it intended to reconsider the final rule, and the Court subsequently stayed the litigation pending further action by the EPA. In August 2018, the EPA ultimately decided not to revisit the rule. As a result, the D.C. Circuit lifted its stay of the 2015 ozone NAAQS rule imposing the 70 ppb ambient air quality standard while the EPA reviews the standards under an expedited review process. On October 31, 2019, the EPA published a draft policy assessment recommending that the 70 ppb ozone NAAQS be retained. In December 2020, the EPA retained without changes these current NAAQS standards. However, as noted above, on January 20, 2021, the current administration issued an executive order directing federal agencies to review and take action to address any federal regulations or similar agency actions promulgated during the prior administration that may be inconsistent with the current administration’s stated priorities. On October 29, 2020,
the EPA determined that California, Connecticut, New York, Pennsylvania, and Texas did not submit a State Implementation Plan (SIP) revision which satisfied the CAA’s reasonably available control technology (RACT) requirements with regard to ozone standards. The EPA’s findings trigger a 24-month deadline for the EPA approve the respective SIP or finalize a Federal Implementation plan which addresses the deficiencies.
• Cross-State Air Pollution Rule. In July 2011, the EPA adopted the Cross-State Air Pollution Rule (the “CSAPR”), a cap-and-trade type program requiring utilities to make substantial reductions in SO2 and NOx and emissions that contribute to ozone and in fine PM emissions to reduce interstate transport of such pollution. The CSAPR was challenged and vacated by the D.C. Circuit Court of Appeals in August 2012, but the U.S. Supreme Court reversed that decision in April 2014. The D.C. Circuit has since lifted its stay on the CSAPR and ruled in favor of the EPA on the remaining significant issues. In January 2016, the EPA filed a brief with the D.C. Circuit addressing the remaining legal challenges left undecided by the U.S. Supreme Court’s 2014 decision. Conforming with a court-ordered schedule, the EPA implemented the first phase of the CSAPR in 2015 and 2016 and the second phase in 2017. In November 2014 and January 2015, the EPA issued notices of data availability outlining emission allowance allocations for existing generating units that began operating before and after 2010. In September 2016, the EPA finalized a rule updating the CSAPR to maintain 2008 ozone emission limitations in downwind states by addressing summertime (May-September) transport of ozone pollution (the "CSAPR Update"). The CSAPR Update, which commenced in May 2017, sets stricter NOx ozone season emission budgets in 22 states and could affect up to 886 coal-fired facilities. For both NOx and SO2, these emission control requirements can impact the quantity and quality of CCRs produced at a power plant, add to the costs of operating a power plant, and make coal a less attractive fuel alternative in the planning and building of utility power plants. On December 6, 2018, the EPA issued the CSAPR “Close-Out” Rule, a final determination that the CSAPR achieves concerning the 2008 ground-level ozone NAAQS in 20 states. Accordingly, those states will not be required to impose requirements for further reduction in transported ozone pollution. The covered states do not need to submit state implementation plans to establish additional requirements beyond the existing CSAPR Update. Several states and other entities challenged the CSAPR Close-Out Rule in the D.C. Circuit. In a September 13, 2019 ruling, the D.C. Circuit remanded the CSAPR Update to the EPA, finding that rule is inconsistent with the CAA. In a subsequent October 1, 2019 ruling, the CSAPR Close-Out Rule was vacated. On March 15, 2021, the EPA finalized its Revised CSAPR Update Rule to address 21 states’ outstanding interstate pollution transport obligations for the 2008 NAAQS. Starting in the 2021 ozone season, the rule requires additional emissions reductions of NOx from power plants in 12 states. The CSAPR Update Rule will affect the demand for coal.
• Comprehensive Environmental Response, Compensation and Liability Act. Certain environmental laws, including the Comprehensive Environmental Response, Compensation and Liability Act (the “CERCLA”) and similar state laws, impose strict, joint and several liability on responsible parties for the investigation and remediation of regulated materials at contaminated sites, including our sites, customer sites, and sites to which we sent wastes, including CCRs. CCRs may contain materials such as metals that are regulated materials under these laws. Management of CCRs can give rise to liability under the CERCLA and similar laws.
• Mercury and Air Toxics Standards for Power Plants. In February 2012, under its Mercury and Air Toxics Standards for Power Plants rule, the EPA promulgated final limits on mercury and other toxic chemicals from new and modified power plants. In June 2015, the U.S. Supreme Court ordered the EPA to undertake a cost-benefit analysis when promulgating mercury and air toxics standards. In April 2016, the EPA published a supplemental finding pursuant to the U.S. Supreme Court’s directive, currently being challenged in the D.C. Circuit. In April 2017, the D.C. Circuit granted the EPA’s motion to stay the litigation while the EPA reconsiders its finding that the rule is “appropriate and necessary” as required under the Clean Air Act. If upheld, requirements to control mercury emissions could result in the implementation of additional technologies at power plants that could negatively affect fly ash quality.
• GHG Emissions. Some states and regions have adopted legislation and regulatory programs to reduce GHG emissions, either directly or through mechanisms such as renewable portfolio standards for electric utilities. These programs require electric utilities to increase their use of renewable energy, such as solar and wind power. Federal GHG legislation appears unlikely in the near term. The EPA has initiated a review of rules finalized in August 2015 for GHG emissions from new and existing fossil fuel-fired electric power plants and for carbon emissions from existing sources in the power sector (the latter being known as the “Clean Power Plan”). The Clean Power Plan establishes state-specific, rate-based reduction goals for carbon emissions and calls on the power sector to reduce carbon emissions to 32% below 2005 levels by 2030.
On June 19, 2019, the EPA finalized the Affordable Clean Energy ("ACE") rule to replace the Clean Power Plan. The ACE rule establishes emission guidelines for states to develop plans to address greenhouse gas emissions from existing coal-fired power plants. The ACE rule has several components: a determination of the best system of emission reduction for greenhouse gas emissions from coal-fired power plants, a list of “candidate technologies” states can use when developing their plans, a new preliminary applicability test for determining whether a physical or operational change made to a power plant may be a “major modification” triggering New Source Review, and new implementing regulations for emission guidelines under Clean Air Act section 111(d). On February 19, 2021, the current administration rejoined the Paris Agreement. Regardless of the extent to which the United States ultimately participates in these reductions, participation in the Paris Agreement framework could reduce the overall demand for coal over the long term.
In December 2015, 195 nations (including the United States) signed the Paris Agreement, a long-term, international framework convention designed to address climate change over the next several decades. This agreement entered into force in November 2016 after more than 70 countries, including the United States, ratified or otherwise agreed to be bound by the agreement. The United States was among the countries that submitted its declaration of intended greenhouse gas reductions in early 2015, stating its intention to reduce U.S. greenhouse gas emissions by 26-28% by 2025 compared to 2005 levels. Whether and to what extent the United States meets its stated intention likely depends on several factors, including whether the ACE rule is implemented. In June 2017, the Trump administration announced the United States' intention to withdraw from the Paris Agreement. In November 2019, the Trump administration formally initiated the withdrawal process and formally exited the Agreement on November 4, 2020. In January 2021, the current administration issued an executive order commencing the process to reenter the Paris Agreement, although the emissions pledges connected with that effort have not yet been updated. Regardless of the extent to which the United States ultimately participates in these reductions, participation in the Paris Agreement framework could reduce the overall demand for coal over the long term.
Several U.S. states have enacted legislation establishing greenhouse gas emissions reduction goals or requirements or joined regional greenhouse gas reduction initiatives. Some states have also enacted legislation or regulations requiring electricity suppliers to use renewable energy sources to generate a certain percentage of power or that provide financial incentives to electricity suppliers to use renewable energy sources. For example, eleven northeastern states are current members of the Regional Greenhouse Gas Initiative, a mandatory cap-and-trade program established in 2005 to cap regional carbon dioxide emissions from power plants. Six Midwestern states and one Canadian province entered into the Midwestern Regional Greenhouse Gas Reduction Accord to establish voluntary regional greenhouse gas reduction targets and develop a voluntary multi-sector cap-and-trade system to help meet the targets. However, it has been reported that the members no longer are actively pursuing the group’s activities. Lastly, California and Quebec remain members of the Western Climate Initiative, formed in 2008 to establish a voluntary regional greenhouse gas reduction goal and develop market-based strategies to achieve emissions reductions. Those two jurisdictions have adopted their own greenhouse gas cap-and-trade regulations. Several states and provinces that initially were members of these organizations and some current members have joined the new North America 2050 initiative, which seeks to reduce greenhouse gas emissions and create economic opportunities aside from cap-and-trade programs. Any particular state, or any of these or other regional groups, may have or adopt future rules or policies that cause some coal users to switch from coal to a lower carbon fuel. There can be no assurance at this time that a carbon dioxide cap-and-trade-program, a carbon tax or other regulatory or policy regime, if implemented by any one or more states or regions in which our customers operate or at the federal level, will not affect the future market for coal in those states or regions and lower the overall demand for coal.
• EPA Water Quality Regulations. The EPA is addressing water quality impacts from coal-fired power plants and coal mining operations. To obtain a permit for certain coal mining activities, including the construction of coal refuse areas and slurry impoundments that may result in impacts to waters of the United States, an operator may need to obtain a permit for the discharge of fill material from the Army Corps of Engineers (“ACOE”) under Section 404, as well as a corresponding permit from the state regulatory authority under Section 401 of the CWA. All permits associated with the placement of dredged or fill material subject to minimum thresholds require appropriate mitigation. Permit holders must receive explicit authorization from the ACOE before proceeding with mining activities. In September 2015, the EPA finalized new effluent limitations (the "Clean Water Rule") under the Clean Water Act for steam electric power generating facilities. The final rule requires coal plant operators with a generating capacity of over 50 megawatts to store fly ash and bottom ash in dry landfills rather than containment ponds. Approximately 12% of coal plants will be affected, and some marginal operations may shut down rather than face the expense of complying with the Clean Water Rule. Multiple challenges to the Clean Water Rule were
consolidated and are pending before the Court of Appeals for the Fifth Circuit. On February 28, 2017, President Trump issued an executive order prompting the EPA and ACOE to consider replacing the blocked Clean Water Rule. On December 11, 2018, the EPA and the ACOE proposed a new regulation to determine which waterbodies are subject to federal jurisdiction. A final rule repealing the 2015 definition of “Waters of the United States” ("WOTUS") became effective on December 23, 2019.
In December 2018, the EPA and ACOE also formally proposed a new rule revising the definition of WOTUS. The new rule -- the Navigable Waters Protection Rule -- became effective on June 22, 2020, and substantially reduces the scope of waters that fall within the Clean Water Act’s jurisdiction, in part by excluding ephemeral streams, which potentially qualified as “Waters of the United States” under the 2015 WOTUS rule. The repeal of the 2015 WOTUS rule and the implementation of the pre-2015 rule have been challenged in federal courts, as has the Navigable Waters Protection Rule, which is currently subject to a challenge in at least twelve federal district courts. A federal district court issued a preliminary injunction preventing the Navigable Waters Protection Rule from taking effect in Colorado, but the rule is otherwise effective in every other state. In addition, in April 2020, the U.S. Supreme Court issued a decision finding that point source discharges to navigable waters through groundwater are subject to regulation under the Clean Water Act. The U.S. Supreme Court specifically held that the Clean Water Act requires a permit if the addition of the pollutants through groundwater is the “functional equivalent” of a direct discharge from the point source into navigable waters. As a result of such recent developments, substantial uncertainty exists regarding the scope of waters protected under the Clean Water Act and the discharges to such waters that are subject to permit requirements. Should the State of Colorado’s challenge to the new definition of “Waters of the United States” be unsuccessful, or should the new Biden administration further modify the definition, operators could incur increased costs or delays with respect to obtaining permits for such activities as dredge and fill operations. These more stringent regulations of coal-fired power plants and coal mining operations could increase the costs for utilities and, thus, indirectly impact the availability and cost of fly ash for our CCR activities.
Increasingly strict requirements, such as those described above, will generally increase the cost of doing business and may make burning coal less attractive for utilities. Faced with the prospect of more stringent regulations, litigation by environmental groups, and the relatively low cost of natural gas, an increasing number of electric utilities are reducing their portfolio of coal-fired power plants. For example, in recent years, multiple companies have closed coal-fired power plant units or plants or dropped plans to open new coal-fired plants, citing the cost of compliance with pending or new environmental regulations and the relatively low cost of natural gas. The potential negative impact on job prospects in the utility and mining industries has prompted considerable concern in Congress, leading to calls to restrict the EPA’s regulatory authority and prompting the EPA to reconsider the same. The outcome of these developments cannot be predicted. If the rate of coal-fired power plant closures increases, our business, financial condition and results of operations may be adversely affected. Nevertheless, we believe that reliance on coal for a substantial amount of power generation in the United States is likely to continue for the foreseeable future.
Motor Carrier Operations
Through the services we provide, we operate as a motor carrier and are subject to regulation by the U.S. Department of Transportation (the “DOT”) and various state agencies. These regulatory authorities exercise broad powers governing activities, such as the authorization to engage in motor carrier operations; regulatory safety; hazardous materials labeling, placarding, and marking; financial reporting; and certain mergers, consolidations, and acquisitions. Additional regulations specifically relate to the trucking industry, including testing and specification of equipment and product handling requirements. The trucking industry is subject to possible regulatory and legislative changes that may affect the industry's economics by requiring changes in operating practices or by changing the demand for common or contract carrier services or the cost of providing truckload services. Some of these possible changes include increasingly stringent environmental regulations, changes in the hours of service regulations that govern the amount of time a driver may drive in any specific period, and requiring onboard black box recorder devices or limits on vehicle weight and size.
Interstate motor carrier operations are subject to safety requirements prescribed by the DOT. Intrastate motor carrier operations are subject to safety requirements that often mirror federal regulations. Such matters as weight and dimension of equipment are also subject to federal and state regulations. DOT regulations also mandate drug testing of drivers. From time to time, various legislative proposals are introduced, including proposals to increase federal, state, or local taxes, including taxes on motor fuels, which may increase our costs or adversely impact the recruitment of drivers. We cannot predict whether, or in what form, any increase in such taxes applicable to us will be enacted.
Human Capital Resources
As of December 31, 2021, we had approximately 693 employees. Approximately 90 of our employees were covered by collective bargaining agreements. We believe we have good relations with our employees. We have 56 employees (more than 8.0% of all employees) with ten or more years of seniority working at the Company.
The Company is an Equal Opportunity Employer. We will consider all qualified applicants for employment without regard to race, color, religion, sex, sexual orientation, gender identity, national origin, or protected veteran status, and we will not discriminate against any qualified candidate based on disability.
Each eligible employee receives a comprehensive benefits package that includes full healthcare coverage, 100% paid preventive care, dental, vision, life insurance, short- and long-term disability, paid time off, and 401(k) with company contribution. We understand the importance of keeping our employees safe and healthy.
Health and Safety
Safety is one of our core values. We are dedicated to maintaining a safe working environment and training our employees and subcontractors to perform their jobs safely and proactively contribute to a safe workplace.
A vital principle of the Charah Way involves actively caring for those around us and working together as one team. Caring for our coworkers and acting as a team is a crucial part of working safely. It requires us to coach and be coached when unsafe behaviors are identified or observed. Safety is not one person’s responsibility; we believe safety is everyone’s responsibility as well as being there for one another in times of crisis.
Charah Solutions recently passed a one-year safety milestone with 1.25 million person-hours of work without an Occupational Safety and Health Administration (“OSHA”) recordable incident. Another significant milestone is that Charah has worked without a lost-time event since April 17, 2019 and logged more than 3 million person-hours. These significant achievements are a result of the commitment of all personnel to put safety first.
Our record in safety excellence also includes the following achievements:
•We accomplished a 0.32 Recordable Incident Rate in 2021 with no lost time or restricted time injuries in comparison to the most recent industry Recordable Incident Rate industry average of 3.1;
•An impressive three-year average Experience Modification Rate (“EMR”) of less than 0.7;
•A Charah Solutions employee is 8.8 times less likely to suffer a recordable injury versus the industry average.
Our Managers and Safety Specialists team utilize an advanced predictive analytics tool to document, monitor, and track behaviors and conditions. This tool utilizes observations, incidents, and historical event data to provide valuable information that we thoroughly assess. We provide our site, regional, and executive leadership "dashboards" that detail incident and observation data from the previous week, month, and year and identify particular trends in that data. We use this information to customize plans to mitigate hazards and reverse any negative trends aggressively. We also use this data, along with other analytical data at the project level to compare statistical data across regions and job sites. Over the last five years, our team has completed over 40,000 inspections and 1.9 million observations, with more than 23,000 opportunities for improvement identified.
Recent award recognition for our focus on Safety Leadership includes:
•AGC Willis Towers Watson Construction Safety Excellence Award for the fifth straight year, including being named the winner of the award in 2022
•Seven Employee Gold-Level Certificates of Safety Achievement from the North Carolina Department of Labor
•Construction Safety Leader Award from Coalition for Construction Safety for our proprietary Basin Excavation Strategies Training (“BEST”) program
•Event-Free Safety Award from Duke Energy for the Crystal River Energy Complex in Citrus County, Florida
Training and development
We strive to educate, advance and promote our talent internally. Career training such as our “Leading from the Frontline” program combines management education and leadership training so that all of our employees understand the importance and impact of leadership in our organization, and we pride ourselves in providing reimbursement for continuing education.
We provide career skills education to support our construction trade employees in mastering current skill areas and future areas of development. These programs include direct sessions with team leaders in safety protocol, specified skills, hands-on training sessions, equipment know-how, heavy equipment training and certification, and sessions on emerging trends impacting and changing the construction skill sets of the future. We offer construction trade professionals an attractive pathway for career advancement, with the potential to work on different projects and locations.
Exchange Act Reports
We make available free of charge through our website, www.charah.com, our Annual Report on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, proxy statement and all amendments to these reports. These reports are available on the investor relations portion of our website, ir.charah.com, as soon as reasonably practicable after such materials are electronically filed with, or furnished to, the Securities and Exchange Commission (the “SEC”). We use the investor relations portion of our website to distribute company information, including as a means of disclosing material, non-public information and for complying with our disclosure obligations under Regulation FD. We routinely post and make accessible financial and other information regarding the Company on our website's investor relations area. Accordingly, investors should monitor the investor relations portion of our website and follow our press releases, SEC filings, public conference calls and webcasts. The information provided on our website is not part of this Annual Report and is not incorporated herein by reference.
The SEC also maintains a website, www.sec.gov, which contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC.

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ITEM 1A. RISK FACTORS
Item 1A. Risk Factors
Risks Related to Our Business
A decline in the production of CCRs by our coal-fired utility industry customers due to environmental regulations or otherwise could negatively impact our profitability and hinder our growth.
Many of our services are dependent upon the production of CCRs by our coal-fired utility industry customers. The coal-fired utility industry faces several new and pending initiatives by regulatory authorities seeking to address air and water pollution, GHG emissions, and the management and disposal of CCRs. In recent years, federal and state environmental regulations have imposed more stringent requirements regarding the emission of air pollutants and other toxic chemicals, reduction of GHG emissions, and water quality impacts from coal operations. Adoption of more stringent regulations governing coal combustion, water discharges, or air emissions may decrease the amount of CCRs produced by our customers and, as a result, the demand for our services. Faced with the prospect of more stringent regulations, litigation by environmental groups, and the relatively low cost of natural gas, an increasing number of electric utilities are reducing their portfolio of coal-fired power plants. The pace of the reduction may increase due to changes in the U.S. executive administration, Congressional leadership and regulatory agency leadership. This reduction could cause states to substitute electricity generation from higher-emitting coal plants with low-emitting coal and natural gas plants and zero-emitting renewable sources. See “Item 1. Business-Regulation.”
Increasingly strict requirements generally will increase the cost of doing business and may make burning coal less attractive for utilities. In recent years, multiple companies have announced plans to close coal-fired power plant units or plants or dropped plans to open new plants, citing the cost of compliance with pending or new environmental regulations and the relatively low cost of natural gas. A reduction in coal use as fuel would cause a decline in the production and availability of CCRs, which would adversely affect our byproduct services offerings and result in reduced revenue. The outcome of these developments cannot be predicted but could have a material adverse effect on our business, results of operation, financial condition, and cash flows.
The COVID-19 pandemic and any future major public health crisis could disrupt the Company's operations and adversely impact its business, results of operations and financial conditions.
The COVID-19 pandemic, including new and emerging strains and variants, continues to have adverse effects on the U.S. and global economies. This outbreak has adversely affected workforces, customers, economies, supply chains, and global transportation and financial markets. While the Company has not incurred significant disruptions thus far from the COVID-19 pandemic, the pandemic and any future major public health crisis could impact our business, consolidated results of operations and financial condition in the future. For example, our business and results of operations could be materially adversely affected if significant portions of our workforce are unable to work effectively, whether it is due to illness, quarantines, government actions or other restrictions in connection with the COVID-19 pandemic or any future major public health crisis. However, the significance of the impact on our operations going forward is not yet certain and depends on numerous evolving factors that the Company may not be able to accurately predict or effectively respond to, including, without limitation: the COVID-19 pandemic or any future major public health crisis, actions taken by governments, businesses and individuals in response, the effect on economic activity and actions taken in response, the effect on customers and their demand for the Company’s products and services and the timing of such demand, the ability of our subcontractors to perform under their contracts due to their own financial or operational difficulties, the availability of subcontractors and other talent, the speed and effectiveness of responses to combat the COVID-19 virus or any future major public health crisis, including vaccine efficacy, distribution and widespread public acceptance, and the Company’s ability to continue operations, including without limitation as a result of supply chain challenges, facility closures, social distancing, restrictions on travel, fear or anxiety by the populace and shelter-in-place orders.
Our business, financial condition and results of operations depend on the award of new contracts and the timing of the performance of these contracts.
We derive our revenue from the performance of customer contracts which itself is dependent on new contract awards. Reductions in the number and amounts of new awards, delays in the timing of the awards, or potential cancellations of such awards resulting from economic conditions, material and equipment pricing, and availability or other factors could adversely impact our business, financial condition and results of operations. It is particularly difficult to predict whether or when we will be awarded large-scale projects as these contracts frequently involve a lengthy and complex bidding and selection process that is affected by market conditions as well as regulatory requirements. We have experienced difficulty in the timely award of new projects and may again in the future. Because we generate our revenue from such projects, our results of operations and cash flows can fluctuate significantly from quarter to quarter depending on the timing of our contract awards and the commencement and progress of work under awarded contracts. Also, many of these contracts are subject to financing contingencies. As a result, we are subject to the risk that the customer will not be able to secure the necessary financing for a project to proceed. If we are
unable to secure the awards of new contracts, our business, financial condition and results of operations will be adversely affected.
We may lose existing contracts through competitive bidding or early termination.
Many of our contracts are for a specified term and are subject to competitive rebidding after the term for such contract expires. Although we intend to bid to extend expiring contracts, we may not always be successful. Also, some or all of our customers may terminate their contracts with us before their scheduled expiration dates. If we are not able to replace lost revenue resulting from unsuccessful competitive bidding, early termination, or the renegotiation of existing contracts with other revenue within a reasonable period, our business, financial condition and results of operations could be adversely affected.
We could be precluded from entering into or maintaining permits or certain contracts if we are unable to obtain sufficient third-party financial assurance or adequate insurance coverage.
Our operations sometimes require us to obtain performance or surety bonds, letters of credit, or other means of financial assurance to secure our contractual performance. We currently obtain performance and surety bonds from multiple financial institutions; however, if we are unable to obtain financial assurance in the future in sufficient amounts from appropriately rated sureties or on acceptable terms, we could be precluded from entering into certain additional contracts or from obtaining or retaining landfill management or other contracts or operating permits. Any future difficulty in obtaining insurance could also impair our ability to secure future contracts conditioned upon having adequate insurance coverage.
Unsatisfactory service and safety performance may negatively affect our customer relationships and, to the extent we fail to retain existing customers or attract new customers, adversely impact our revenue.
Our ability to retain existing customers and attract new business is dependent on many factors, including our ability to demonstrate that we can reliably and safely operate our business in a manner that is consistent with our customers’ standards of service as well as applicable laws, rules, and permits, which are subject to change. Existing and potential customers consider the safety and service record of their third-party service providers to be of high importance in their decision to engage such providers. The power generation industry generally emphasizes safety and service over cost due to economic and reputational risk associated with operations at their facilities.
We may experience multiple or particularly severe accidents in the future, causing our safety record to deteriorate. This possibility may be more likely as we continue to grow, if we experience high employee turnover or a labor shortage or hire inexperienced personnel to support our staffing needs. If one or more accidents were to occur while we are providing services to our customers, or if we were unable to maintain the level of safety and service our customers require, the affected customer may seek to terminate our services and may be less likely to use our services in the future, which could adversely affect our business, financial condition and results of operations. Furthermore, our ability to attract new customers may be impaired if they view our safety or service record as unacceptable.
Our ERT services will require us to acquire significant real property and assume liabilities that could adversely impact our future results.
As part of our ERT services, we will purchase real and personal property and assume environmental liabilities. We will plan to sell these acquired assets to third parties. However, the timing of these future dispositions is difficult to predict, and we may not be able to realize the gains on sales as anticipated. If we cannot sell these assets, the assets may be written down to their fair value, with the impairment loss recognized as a non-cash charge in the consolidated statement of operations. Furthermore, these services will require us to assume environmental liabilities with long-term monitoring requirements. If actual costs exceed our cost estimates, we may incur future additional liabilities, which could adversely impact our results of operations.
The loss of a large customer may adversely affect our revenue and operating results.
We will likely continue to derive a significant portion of our revenue from a relatively small number of customers in the future. If a major customer fails to pay us promptly or at all, our revenue would be negatively impacted, and our operating results, financial condition and cash flows could be materially adversely affected. Additionally, if we were to lose any material customer, such loss would have a material adverse effect on our business and results of operations.
We and our customers operate in industries subject to significant environmental regulation, and compliance with changes in, or liabilities under, such regulations could add significantly to the costs of conducting business.
Our operations and the operations of our customers are subject to federal, state, and local environmental laws and regulations that, among other matters, impose limitations on the discharge of pollutants into the air and water and establish standards for the treatment, storage, and disposal of solid, hazardous, and radioactive waste materials, the remediation of releases of hazardous substances, and the reclamation of land. We and our customers have obtained various federal, state, and
local environmental permits to conduct our operations, and we must comply with these permits and processes and procedures regulatory authorities have approved. Any failure to comply with these environmental requirements could give rise to sanctions, including, but not limited to: i) the cessation of all or part of our operations, ii) substantial fines and penalties, iii) environmental or reclamation liabilities, which liabilities may be strict and joint and several and iv) damages, including natural resource damages in connection with our sites, customer sites, or sites to which we sent wastes, including CCRs, and third-party claims. Moreover, changes in environmental laws and regulations occur frequently, and any changes that result in more stringent or costly environmental requirements could require our customers or us to make significant expenditures to attain and maintain compliance. New regulations, failure to comply with existing regulations, or environmental liabilities arising thereunder could have a material adverse effect on our business, results of operation, financial condition, and cash flows.
Success by environmental groups in convincing the EPA to restrict beneficial uses of CCRs, or to regulate CCRs as hazardous waste, may have an adverse effect on our business.
In April 2015, the EPA published the CCR Rule to regulate the disposal of CCRs, including fly ash and bottom ash generated at coal-fired power plants, as non-hazardous waste under Subtitle D of the RCRA and to distinguish the beneficial use of CCRs from disposal, which became effective in October 2015. The CCR Rule establishes national minimum criteria for CCR landfills and impoundments consisting of location restrictions, design and operating criteria, groundwater monitoring and corrective action, closure requirements, post-closure care, recordkeeping and reporting and other requirements, and requires closure of facilities unable to comply with these criteria within five to seven years. The CCR Rule has increased the complexity and cost of managing and disposing of CCRs and remediating existing ash ponds and landfills. Also, Congress passed the WIIN Act in December 2016, which, among other things, authorizes state permit programs to manage CCRs in place of the CCR Rule. The WIIN Act also gives the EPA the authority to regulate coal ash in states that choose not to implement state permitting programs and in states whose permitting programs are determined to be inadequate by the EPA. In July 2018, the EPA issued a final rule that would take further steps under the WIIN Act by granting states with approved CCR permit programs (or the EPA where it is the permitting authority) the ability to set specific alternative performance standards. The rule would also allow CCRs to be used during certain closure situations. Finally, it addresses certain matters remanded to the EPA by the D.C. Circuit Court of Appeals in June 2016, including clarifying corrective action triggers and requirements, adding boron to the list of constituents triggering corrective action, determining the proper height of woody and grassy vegetation for slope protection, and modifying alternative closure procedures. In August 2018, the D.C. Circuit Court of Appeals vacated and remanded portions of the CCR Rule. In December 2019, the EPA addressed the deficiencies identified by the court and proposed amendments to change the closure deadline to August 31, 2020, but to allow certain extensions. The EPA extended the comment period on this legacy CCR surface impoundment advance notice of proposed rulemaking through February 23, 2022 on three proposals and until March 25, 2022 on a fourth proposal.
Some environmental groups continue to urge the EPA to restrict certain beneficial uses of CCRs, such as in concrete, road base, and soil stabilization, alleging contaminants may leach into the environment. The CCR Rule created a definition of “beneficial use” that includes uses in concrete and road base, but changes in the definition could reduce the demand for fly ash and other CCRs, which would have an adverse effect on our revenue. Moreover, if the EPA were to regulate CCRs as hazardous waste, we, together with CCR generators, could be subject to environmental cleanup, personal injury, and other possible claims and liabilities that could result in significant additional costs. Any such changes in or new regulations or indemnity obligations could have a material adverse effect on our business, results of operation, financial condition, and cash flows.
We may be adversely affected by uncertainty in the global financial markets and the deterioration of our customers' financial condition. If any of our customers suffer financial difficulties affecting their credit risk, our operating results could be negatively impacted.
Our future results of operations may be affected by the uncertainty caused by an economic downturn, natural disaster, pandemic, volatility or deterioration in the capital markets or credit markets, inflation, deflation, or other adverse economic conditions that may negatively affect us or parties with whom we do business, resulting in a reduction in our customers’ spending and their nonpayment or inability to perform obligations owed to us, such as the failure of customers to honor their commitments. Additionally, downturns in U.S. construction could lower the demand for our byproduct services and raw material sales offerings.
We also provide service to power generators. To the extent these entities suffer significant financial difficulties, they could be unable to pay amounts owed to us or to renew contracts with us on attractive terms. Our customers' inability, particularly larger customers, to pay us promptly or to pay increased rates could negatively affect our business, financial condition and results of operations. In addition, in the course of our business, we hold accounts receivable from our customers. In the event of the customer's financial distress or bankruptcy, we could lose all or a portion of such outstanding accounts
receivable associated with that customer. Further, if a customer was to enter bankruptcy, it could result in the cancellation of all or a portion of our service contracts with that customer at significant expense or loss of expected revenue.
If we are unable to accurately estimate the overall risks, revenues or costs on our projects, we may incur contract losses or achieve lower profits than anticipated.
Pricing on fixed unit price contracts is based on approved quantities irrespective of our actual costs, and contracts with a fixed total price require that the work be performed for an agreed-upon price irrespective of our actual costs. We only generate profits on fixed unit price and fixed total price contracts when our revenues exceed our actual costs, which requires us to estimate our costs accurately, control our actual costs and avoid cost overruns. If our cost estimates are too low or we do not perform the contract within our cost estimates, then cost overruns may cause us to incur a loss or cause the contract not to be as profitable as we expected. As a result, these types of contracts could negatively affect our cash flow, earnings and financial position.
The costs incurred and profit realized, if any, on our contracts can vary, sometimes substantially, from our original projections due to a variety of factors, including, but not limited to:
•onsite conditions that differ from those assumed in the original bid or contract;
•failure to include required materials or work in a bid, or the failure to estimate properly the quantities or costs needed to complete a lump sum contract;
•delays caused by weather conditions or otherwise failing to meet scheduled acceptance dates;
•contract or project modifications creating unanticipated costs not covered by change orders or contract price adjustments;
•changes in availability, proximity and costs of materials, including steel, concrete, aggregates and other construction materials (such as stone, gravel, sand and oil for asphalt paving), as well as fuel and lubricants for our equipment;
•higher than anticipated costs to lease, acquire and maintain equipment;
•availability and skill level of workers in the geographic location of a project;
•rapidly increasing labor costs;
•the failure of our suppliers, subcontractors, designers, engineers or customers to perform their obligations;
•fraud, theft or other improper activities by our suppliers, subcontractors, designers, engineers, customers or our personnel;
•mechanical problems with our machinery or equipment;
•citations issued by a government authority, including OSHA;
•difficulties in obtaining required government permits or approvals;
•changes in applicable laws and regulations;
•uninsured claims or demands from third parties for alleged damages arising from the design, construction or use and operation of a project of which our work is part; and
•delays in quickly identifying and taking measures to address issues that arise during the execution of a project.
Increases in labor costs or our ability to find, employ and deploy technically skilled labor could impact our financial results.
Our continued success will depend on our ability to attract and retain qualified personnel. We compete with other businesses in our markets for qualified employees. From time to time, the labor supply is tight in some of our markets. Labor is a primary component of operating our business. A number of factors may adversely affect the labor force available to us or increase labor costs from time to time, including high employment levels, federal unemployment subsidies, including unemployment benefits offered in response to the COVID-19 pandemic, and other government regulations.
Although we have not experienced any material disruptions due to labor shortages to date, we have observed an overall tightening and increasingly competitive labor market. A sustained labor shortage or increased turnover rates within our employee base, whether caused by COVID-19 or as a result of general macroeconomic factors, could lead to increased costs, such as increased overtime to meet demand and increased wage rates to attract and retain employees, and could negatively
affect our ability to complete our construction projects according to the required schedule or otherwise efficiently operate our business. If we are unable to hire and retain employees capable of performing at a high level, or if mitigation measures we may take to respond to a decrease in labor availability, such as overtime and third-party outsourcing, have unintended negative effects, our business could be adversely affected. In addition, we dispose of CCRs and distribute our raw material sales offerings to customers primarily by truck. Reduced availability of trucking capacity due to shortages of drivers, primarily as a result of the COVID-19 pandemic, has caused an increase in the cost of transportation for us and our suppliers. An overall labor shortage, lack of skilled labor, increased turnover or labor inflation, caused by COVID-19 or as a result of general macroeconomic factors, could have a material adverse impact on our operations, results of operations, liquidity or cash flows.
Dependence on third-party subcontractors and equipment manufacturers could adversely affect our profits.
We rely on third-party subcontractors and equipment manufacturers to complete many of our projects. We could experience losses to the extent that we cannot engage subcontractors or acquire equipment or materials or if the amount we are required to pay for these goods or services exceeds the amount we have estimated in bidding for fixed-price contracts in the performance of these contracts. Also, if a subcontractor or a manufacturer is unable to deliver its services, equipment or materials according to the negotiated terms for any reason including, but not limited to, the deterioration of its financial condition, we may be required to purchase the services, equipment or materials from another source at a higher price. This may reduce the expected profit or result in a loss on a project, negatively impacting our business, financial condition and results of operations.
We service a significant portion of our contracts with our own construction equipment rather than leased or rented equipment. To the extent that we are unable to buy construction equipment necessary for our needs, either due to a lack of available funding or equipment shortages in the marketplace, we may be forced to rent equipment on a short-term basis, which could increase the costs of performing our contracts.
The property, plants and equipment needed to produce our products and provide our services can be very expensive. We must spend a substantial amount of capital to purchase and maintain such assets. Although we believe our current cash balance, along with our projected internal cash flows and available financing sources, will provide sufficient cash to support our currently anticipated operating and capital needs, if we are unable to generate sufficient cash to purchase and maintain the property, plants and equipment necessary to operate our business, or if the timing of payments on our receivables is delayed, we may be required to reduce or delay planned capital expenditures or to incur additional indebtedness. In addition, due to the level of fixed and semi-fixed costs associated with our business, volume decreases could have a material adverse effect on our financial condition, results of operations or liquidity.
Supply chain issues, including shortages of equipment, vehicles and construction supplies, could increase our costs or cause delays in our ability to complete our projects, which could have an adverse impact on our business and our relationships with customers.
We rely on our supply chain for equipment, vehicles and construction supplies in order to complete our projects. A reduction or interruption in supply, including disruptions due to the COVID-19 pandemic, a significant natural disaster, shortages in global freight capacity, significant increases in the price of critical components, a failure to appropriately forecast or adjust our requirements based on our business needs, or volatility in demand for our products and services could materially adversely affect our business, operating results, and financial condition and could materially damage customer relationships. Our vendors and subcontractors also may be unable to meet our demand, significantly increase lead times for deliveries or impose significant price increases that we are unable to offset through alternate sources of supply, price increases to our customers or increased productivity in our operations. In some cases, we procure certain inputs and services from single or limited suppliers or subcontractors. In the event of supply disruptions from these suppliers or subcontractors, we may not be able to diversify our resources for such materials or services in a timely manner or may experience quality issues with alternate sources. Our growth and ability to meet customer demand depend in large part on our ability to obtain timely deliveries of equipment and vehicles from our suppliers, and significant disruptions in their supply could materially adversely affect our business, operating results, and financial condition and could materially damage customer relationships.
Our employees perform services that involve certain risks, including risks of accident, and a failure to maintain a safe work site could result in significant losses.
Safety is a primary focus of our business and is critical to our reputation. Our services can place our employees and others in challenging environments near large equipment, dangerous processes and highly toxic or caustic materials. Our operations involve risks, such as truck accidents, equipment defects, malfunctions and failures, and natural disasters, which could potentially result in releases of CCR materials, injury or death of employees and others, or a need to shut down or reduce the operation of our customers’ facilities while we undertake remedial actions. We are responsible for safety on the sites where we work, and these risks expose us to potential liability for pollution and other environmental damages, personal injury, loss of
life, business interruption, and property damage or destruction. Unsafe work conditions also can increase employee turnover, increase costs and raise our operating costs. If we fail to implement appropriate safety procedures and/or our procedures fail, our employees or others may suffer injuries.
Although we maintain functional groups whose primary purpose is to implement effective health, safety, and environmental procedures throughout our company, the failure to comply with such procedures, client contracts, or applicable regulations could subject us to losses and liability and the potential loss of customers. If we were to incur substantial liabilities above any applicable insurance, our business, results of operations, and financial condition could be adversely affected.
Our financial results may fluctuate from quarter to quarter due to seasonal weather patterns and other factors, making it difficult to predict our future performance.
Consumption of energy is seasonal, and any variation from normal weather patterns, including due to unseasonably cooler or warmer weather, can have a significant impact on energy demand. Additionally, adverse weather conditions, such as hurricanes, tropical storms, and severe cold weather, may interrupt or curtail our operations or our customers’ operations and result in a loss of revenue and damage to our equipment and facilities, which may or may not be insured.
Our byproduct services and raw material sales offerings are also subject to quarterly fluctuations from time to time. For these reasons, comparing our financial results on a period-to-period basis may not be meaningful, and our past results should not be relied on as an indication of our future performance. Our future quarterly and annual expenses as a percentage of our revenue may be significantly different from those we have recorded in the past or which we expect for the future. Our financial results in some quarters may fall below expectations. Changes in cost estimates relating to our services, which under the cost-to-cost input method of accounting principles could lead to significant fluctuations in revenue or changes in the timing of our recognition of revenue from such services, could cause our stock price to fall.
We operate in a highly competitive industry and may not be able to compete effectively with larger and better-capitalized companies.
While no specific company provides the range of services that we offer, the industries in which we operate are highly competitive and require substantial labor and capital resources. Some of the markets in which we compete or plan to compete are served by one or more large national companies and regional and local companies of varying sizes and resources, some of which may have accumulated a substantial reputation in their markets. Some of our competitors may also be better capitalized than we are, have greater name recognition than we do, or provide or be willing to bid their services at a lower price than we may be willing to offer. Our inability to compete effectively could hinder our growth or adversely impact our business, financial condition and results of operations.
We rely on technology in our business, and any technology disruption or delay in implementing new technology could adversely affect our business, financial condition, results of operation and cash flows.
We invest in new technology and processes to provide higher-margin offerings for our customers while limiting and managing our environmental risk. We also depend on digital technologies to process and record financial and operating data, and we rely on sophisticated information technology systems and infrastructure to support our business, including process control technology. The failure of our technology initiatives and systems to perform as we anticipate or a delay in implementing new technology could adversely affect our business, financial condition, results of operations and cash flows. For example, the roll-out of our technology initiatives, including our EnviroSourceTM ash beneficiation technology, has been slower than previously anticipated, resulting in lower than expected contribution to operating results.
Additionally, if competitors implement new technologies before we do, allowing such competitors to provide lower-priced or enhanced services of superior quality compared to those we provide, this could have an adverse effect on our financial condition, results of operations and cash flows.
If we are unable to protect the confidentiality of our trade secrets fully, or if competitors are able to replicate our technology or services, we may suffer a loss in our competitive advantage or market share.
Though we do not have patents or patent applications relating to many of our key processes and technology, if we cannot maintain our trade secrets' confidentiality, or if our competitors replicate our technology or services, our competitive advantage would be diminished. Further, our competitors may develop or employ comparable technologies or processes.
In addition, third parties, from time to time, may initiate litigation against us by asserting that the conduct of our business infringes, misappropriates, or otherwise violates intellectual property rights. If we are sued for infringement and lose, we could be required to pay substantial damages and/or be enjoined from using or selling the infringing products or technology. Any legal proceeding concerning intellectual property could be protracted and costly regardless of the merits of any claim, is inherently unpredictable, and could have a material adverse effect on our financial condition, irrespective of its outcome.
Additionally, we currently license certain third-party intellectual property in connection with our business, and the loss of any such license could adversely impact our financial condition and results of operations.
We may be unable to make attractive acquisitions, integrate acquired businesses successfully or successfully complete divestitures, and any inability to do so may disrupt our business and hinder our growth.
From time to time, we may consider opportunities to acquire or make investments in other businesses and business lines that could enhance our technical capabilities, complement our current services, or expand the breadth of our markets. Any completed acquisition's success will depend on our ability to integrate the acquired business into our existing operations effectively. The process of integrating acquired businesses or dispositions may involve unforeseen difficulties or liabilities and may require a disproportionate amount of our managerial and financial resources. Also, possible future acquisitions may be larger and for purchase prices significantly higher than those paid for earlier acquisitions. No assurance can be given that we will be able to identify suitable acquisition opportunities, negotiate acceptable terms, obtain financing for acquisitions on acceptable terms, or successfully acquire identified targets. Our failure to achieve consolidation savings, integrate the acquired businesses and assets into our existing operations successfully or minimize any unforeseen operational difficulties or liabilities could have a material adverse effect on our business, financial condition and results of operations.
We are vulnerable to significant fluctuations in our liquidity or capital requirements that may vary substantially over time.
Our operations could require us to utilize large sums of working capital, sometimes on short notice and sometimes without assurance of recovery of the expenditures. Environmental liabilities could result in significant cash outflows, including those arising from various customer contracts and acquisition agreements that require us to indemnify for certain environmental liabilities, litigation risks, unexpected costs or losses resulting from acquisitions, contract initiation or completion delays, political conditions, client payment problems and professional liability claims.
We may be unable to obtain or maintain sufficient bonding capacity, which could preclude us from bidding on certain projects.
A significant number of our contracts require performance and payment bonds. Sureties typically issue or continue bonds on a project-by-project basis, and they can decline to do so at any time or require the posting of additional collateral as a condition thereto. Our ability to obtain performance and payment bonds primarily depends on our capitalization, working capital, past performance, management expertise, reputation and certain external factors, including the overall capacity of the surety market. Events that adversely affect the insurance and bonding markets generally may result in bonding becoming more difficult or costly to obtain in the future. If we are unable to obtain or renew a sufficient level of bonding, or if bonding costs were to increase, we may be precluded from bidding on certain projects or successfully contracting with certain customers, which could limit the aggregate dollar amount of contracts that we are able to pursue. In addition, even if we are able to successfully renew or obtain performance or payment bonds, we may be required to post letters of credit in connection with such bonds, which could negatively affect our liquidity and results of operations.
Our substantial indebtedness could adversely affect our financial condition and prevent us from fulfilling our obligations.
Our debt consists primarily of our borrowings under the Company’s 8.50% Senior Notes due 2026 (the “Notes”) and for equipment financing through notes payables and capital lease obligations. As of December 31, 2021, the Company had total indebtedness of $199.7 million, excluding debt issuance costs of $11.4 million. A significant portion of our cash flow is required to pay interest and principal on our outstanding indebtedness, and we may be unable to generate sufficient cash flow from operations or have future borrowings available to enable us to repay our indebtedness or to fund other liquidity needs.
Our indebtedness could have significant consequences, including the following:
•require us to use a significant percentage of our cash flow from operations for debt service and the satisfaction of repayment obligations, and not for other purposes;
•limit our ability to borrow money or issue equity to fund our working capital, capital expenditures, acquisitions and debt service requirements;
• limit our flexibility in planning for, and reacting to, changes in our business;
• place us at a competitive disadvantage if we are more leveraged than our competitors;
• limit our ability to deduct our interest expense;
• make us more vulnerable to adverse economic and industry conditions; and
• limit our ability to exploit business opportunities.
To the extent that we incur new debt in addition to our current debt levels, the leverage risks described above would increase.
Our variable rate indebtedness related to borrowings under our Asset-Based Lending Credit Agreement subjects us to interest rate risk, and the transition away from the London Interbank Offered Rate (“LIBOR”) could have an adverse impact on us.
On November 30, 2020, the Federal Reserve announced that LIBOR would be phased out and eventually replaced by June 2023. In the same announcement, banks were instructed to stop writing contracts using LIBOR by the end of 2021, and all contracts using LIBOR should wrap up by June 30, 2023. We expect that the Secured Overnight Financing Rate (or “SOFR”), published by the Federal Reserve Bank of New York will replace U.S. Dollar LIBOR as the principal reference rate for U.S. Dollar-denominated floating rate instruments. However, the manner and timing of this shift are currently unknown. SOFR is an overnight rate instead of a term rate, making SOFR an inexact replacement for LIBOR.
Borrowings under our Asset-Based Lending Credit Agreement (the “Credit Agreement”) are at variable rates of interest and expose us to interest rate risk. As interest rates increase, our debt service obligations on the variable rate indebtedness will increase even if the amount borrowed remains the same, and our results of operations and cash flows, including cash available for servicing our indebtedness, will correspondingly decrease. Our Credit Agreement contains LIBOR benchmark replacement provisions and has identified the SOFR as its preferred alternative rate for the U.S. LIBOR. However, at this time, there can be no assurance as to whether this alternative benchmark or resulting interest rates may be more or less favorable than LIBOR or any other unforeseen impacts of the discontinuation of LIBOR. As a result, the proposals or consequences related to this transition could have a material adverse effect on our debt service obligations, financing costs, liquidity, financial condition, results of operations or cash flows and could impair our access to the capital markets.
We are subject to cyber security risks and interruptions or failures in our information technology systems. A cyber incident could occur and result in information theft, data corruption, operational disruption, and/or financial loss.
We depend on digital technologies to process and record financial and operating data, and we rely on sophisticated information technology systems and infrastructure to support our business, including process control technology. At the same time, cyber incidents, including deliberate attacks, have increased. The U.S. government has issued public warnings that indicate that energy assets might be specific targets of cyber-security threats. Our technologies, systems, and networks and those of our vendors, suppliers and other business partners may become the target of cyber-attacks or information security breaches that could result in the unauthorized release, gathering, monitoring, misuse, loss, or destruction of proprietary and other information, or other disruption of business operations. In addition, certain cyber incidents, such as surveillance, may remain undetected for an extended period. Despite our considerable expenditures and efforts to secure our systems, our systems for protecting against cyber security risks may not be sufficient. As the sophistication of cyber incidents continues to evolve, we will likely be required to expend additional resources to continue modifying or enhancing our protective measures or investigate and remediate any vulnerability to cyber incidents. Additionally, these systems may be susceptible to outages due to fire, floods, power loss, telecommunications failures, usage errors by employees, computer viruses, cyber-attacks, or other security breaches or similar events. The failure of any of our information technology systems may cause disruptions in our operations, which could adversely affect our revenue and profitability.
In the normal course of business, we may be subject to judicial, administrative, or other third-party proceedings that could materially and adversely affect our reputation, business, financial condition, results of operations, and liquidity.
We have in the past been, and may in the future be, named as a defendant in lawsuits, claims, and other legal proceedings during the ordinary course of our business. In the future, individuals, citizen groups, trade associations, community groups, or environmental activists may bring actions against us in connection with our operations that could interrupt or limit the scope of our business. Many of these proceedings could raise difficult and complicated factual and legal issues and are subject to uncertainties and complexities. These proceedings may seek, among other things, compensation for alleged personal injury, workers’ compensation, employment discrimination, breach of contract, property damage, punitive damages, civil penalties, or other losses, consequential damages, or injunctive or declaratory relief. Also, under our service agreements, we generally indemnify our customers for claims related to our conduct and the services we provide thereunder.
With respect to all such proceedings, we have and will, when warranted in the future, accrue expenses in accordance with accounting principles generally accepted in the United States (“GAAP”). If such actions or indemnities are ultimately resolved unfavorably at amounts exceeding our accrued expenses or at material amounts, the outcome could materially and
adversely affect our reputation, business, financial condition, and results of operations. In addition, payments of significant amounts, even if reserved, could adversely affect our liquidity position.
We recognize revenue from construction contracts using the cost-to-cost input method; therefore, variations of actual results from our assumptions may reduce our profitability.
We recognize revenue from construction contracts using the cost-to-cost input method permitted under GAAP, under which we measure the percentage of revenue to be recognized in a given period by the percentage of costs incurred to date on the contract to the total estimated costs for the contract. The cost-to-cost input method, therefore, relies on estimates of total expected contract costs. Contract revenue and total cost estimates are reviewed and revised on an ongoing basis as the work progresses. Adjustments arising from changes in the estimates of contracts revenue or costs are reflected in the fiscal period in which such estimates are revised. Estimates are based on management’s reasonable assumptions, judgment and experience but are subject to the risks inherent in estimates, including unanticipated delays or technical complications. Variances in actual results from related estimates on a large project or on several smaller projects could be material to our results of operations. The full amount of an estimated loss on a contract is recognized in the period such a loss is identified. Such adjustments and accrued losses could reduce profitability, which could negatively impact our financial condition and results of operations.
Our balance sheet includes a significant amount of goodwill and intangible assets which have been subject to impairment. A decline in our reporting unit's estimated fair value or trade name intangible asset could result in additional asset impairment charges, which would be recorded as a non-cash expense in our consolidated statement of operations.
Goodwill and our trade name and customer relationship intangible assets must be tested for impairment no less than annually. The fair value of the goodwill assigned to our reporting unit could decline if projected revenue or cash flows were to be lower in the future due to the timing of new awards or other causes. If the carrying value of intangible assets or goodwill exceeded its fair value, the asset would be written down to its fair value, with the impairment loss recognized as a non-cash charge in the consolidated statement of operations.
As of December 31, 2021, we had approximately $62.2 million of goodwill and $53.5 million of our trade name and customer relationship intangibles on our balance sheet, which together represent 34% of our total assets. No impairment charges to our goodwill and intangible assets were identified during the year ended December 31, 2021. However, changes in our operations' future outlook could result in impairment charges, which could have a material adverse effect on our results of operations and financial condition.
Risks Related to Our Common Stock
Our stock's market price may be influenced by many factors, some of which are beyond our control.
These factors include the various risks described in this section as well as the following:
•the failure of securities analysts to continue to cover our common stock or changes in financial estimates or recommendations by analysts;
•announcements by us or our competitors of significant contracts, acquisitions, or capital commitments;
•changes in market valuation or earnings of our competitors;
•variations in quarterly operating results;
•internal control failures;
•changes in management;
•availability of capital;
•general economic conditions;
•terrorist acts;
•natural disasters and pandemics;
•legislation;
•future sales of our common stock; and
•investor perception of us and the power generation industry.
Additional factors that do not specifically relate to our company or the electric utility industry may also materially reduce our common stock market price, regardless of our operating performance.
The concentration of our capital stock will limit other stockholders’ ability to influence corporate matters.
Bernhard Capital Partners Management, LP and its affiliates (“BCP”) beneficially own approximately 45% of the total voting power of our outstanding shares of common stock and all of the outstanding Series A Preferred Stock (“Preferred Stock”). The Preferred Stock is convertible at BCP's option at any time into shares of common stock. As a result, BCP can exert substantial influence or actual control over our management and affairs and most matters requiring our stockholders' actions. The interests of BCP may not coincide with the interests of the other holders of our common stock. This concentration of ownership may also affect delaying or preventing a change in control otherwise favored by our other stockholders, which could depress our common stock's market price.
BCP and its respective affiliates are not limited in their ability to compete with us, and the corporate opportunity provisions in our amended and restated certificate of incorporation could enable BCP to benefit from corporate opportunities that might otherwise be available to us.
Our governing documents provide that BCP and its respective affiliates (including portfolio investments of BCP and its affiliates) are not restricted from owning assets or engaging in businesses that compete directly or indirectly with us. In particular, subject to the limitations of applicable law, our amended and restated certificate of incorporation, among other things:
• permits BCP and its respective affiliates to conduct business that competes with us and to make investments in any kind of property in which we may make investments; and
• provides that if BCP or its respective affiliates, or any employee, partner, member, manager, officer or director of BCP or its respective affiliates, which is also one of our directors or officers, becomes aware of a potential business opportunity, transaction, or other matter, they will have no duty to communicate or offer that opportunity to us.
BCP or its respective affiliates may become aware, from time to time, of certain business opportunities (such as acquisition opportunities) and may direct such opportunities to other businesses in which they have invested, in which case we may not become aware of or otherwise have the ability to pursue such opportunity. Furthermore, such businesses may choose to compete with us for these opportunities, possibly causing these opportunities to not be available to us or causing them to be more expensive for us to pursue. In addition, BCP and its respective affiliates may dispose of properties or other assets in the future without any obligation to offer us the opportunity to purchase any of those assets. As a result, our business or prospects may be negatively affected if such parties procure attractive business opportunities for their benefit rather than for ours.
We have engaged in transactions with our affiliates, and we may do so in the future. The terms of such transactions and the resolution of any conflicts that may arise may not always be in our or our stockholders’ best interests.
We have engaged in transactions with affiliated companies in the past and may do so in the future. The terms of such transactions and the resolution of any conflicts that may arise may not always be as favorable as may be obtained with a third party.
Our amended and restated certificate of incorporation and amended and restated bylaws, as well as Delaware law, contain provisions that could discourage acquisition bids or merger proposals, which may adversely affect the market price of our common stock.
Our amended and restated certificate of incorporation authorizes our board of directors to issue preferred stock without stockholder approval. If our board of directors elects to issue preferred stock, it could be more difficult for a third party to acquire us. Also, some provisions of our amended and restated certificate of incorporation and amended and restated bylaws could make it more difficult for a third party to acquire control of us, even if the change of control would be beneficial to our stockholders, including:
• after BCP and its affiliates no longer collectively hold more than 35% of the voting power of our common stock, providing that all vacancies, including newly created directorships, may, except as otherwise required by law or, if applicable, the rights of holders of a series of preferred stock, only be filled by the affirmative vote of a majority of directors then in office, even if less than a quorum (before such time, vacancies may also be filled by stockholders holding a majority of the outstanding shares entitled to vote);
• after BCP and its affiliates no longer collectively hold more than 35% of the voting power of our common stock, permitting any action by stockholders to be taken only at an annual meeting or special meeting rather than by written consent of the stockholders, subject to the rights of any series of preferred stock concerning such rights;
• after BCP and its affiliates no longer collectively hold more than 35% of the voting power of our common stock, permitting our amended and restated certificate of incorporation and amended and restated bylaws to be amended by the affirmative vote of the holders of at least two-thirds of our then outstanding shares of stock entitled to vote thereon;
• after BCP and its affiliates no longer collectively hold more than 35% of the voting power of our common stock, permitting special meetings of our stockholders to be called only by our board of directors pursuant to a resolution adopted by the affirmative vote of a majority of the total number of authorized directors whether or not there exist any vacancies in previously authorized directorships (before such time, a special meeting may also be called at the request of stockholders holding a majority of the outstanding shares entitled to vote);
• after BCP and its affiliates no longer collectively hold more than 35% of the voting power of our common stock, requiring the affirmative vote of the holders of at least 75% in voting power of all then outstanding common stock entitled to vote generally in the election of directors, voting together as a single class, to remove any or all of the directors from office at any time, and directors will be removable only for “cause”;
• dividing our board of directors into three classes of directors, with each class serving staggered three-year terms;
• prohibiting cumulative voting in the election of directors;
• establishing advance notice provisions for stockholder proposals and nominations for elections to the board of directors to be acted upon at meetings of stockholders; and
• providing that the board of directors is expressly authorized to adopt or alter or repeal our amended and restated bylaws.
Our amended and restated certificate of incorporation designates the Court of Chancery of the State of Delaware as the sole and exclusive forum for certain types of actions and proceedings that our stockholders may initiate, which could limit our stockholders’ ability to obtain a favorable judicial forum for disputes with us or our directors, officers, employees, or agents.
Our amended and restated certificate of incorporation provides that, unless we consent in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware will, to the fullest extent permitted by applicable law, be the sole and exclusive forum for (i) any derivative action or proceeding brought on our behalf, (ii) any action asserting a claim of breach of a fiduciary duty owed by any of our directors, officers, employees, agents, or stockholders to us or our stockholders, (iii) any action asserting a claim against us or any director, officer, employee, or agent of ours arising under any provision of the Delaware General Corporation Law (the “DGCL”), our amended and restated certificate of incorporation or our amended and restated bylaws, or (iv) any action asserting a claim that is governed by the internal affairs doctrine. Any person or entity purchasing or otherwise acquiring any interest in shares of our capital stock will be deemed to have notice of, and consented to, the provisions of our amended and restated certificate of incorporation described in the preceding sentence. This choice of forum provision may limit a stockholder’s ability to bring a claim in a judicial forum that it finds favorable for disputes with us or our directors, officers, employees, or agents, which may discourage such lawsuits against us and such persons. Alternatively, if a court were to find these provisions of our amended and restated certificate of incorporation inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings, we may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect our business, financial condition, or results of operations.
We do not intend to pay cash dividends on shares of our common stock. Consequently, your only opportunity to achieve a return on your investment is if our common stock price appreciates.
We do not plan to declare cash dividends on shares of our common stock in the foreseeable future. Additionally, our debt agreements place certain restrictions on our ability to pay cash dividends on common stock. Consequently, your only opportunity to achieve a return on your investment in us will be if you sell your common stock at a price higher than you paid for it. There is no guarantee that our common stock price will prevail in the market will ever exceed the price you paid for it.
Shares eligible for future sale may cause our common stock's market price to drop significantly, even if our business is doing well.
Our common stock market price could decline due to sales of a large number of shares of our common stock in the market or the perception that these sales could occur. These sales, or the possibility that these sales may occur, also might make it more difficult for us to sell equity securities in the future at a time and at a price that we deem appropriate.
On March 16, 2020, we issued $26.0 million in Preferred Stock to BCP, the terms of which could adversely affect the voting power or value of our common stock.
We currently have 26,000 shares of Preferred Stock outstanding, which is convertible at BCP's option at any time following the three-month anniversary of the issuance date into shares of common stock with an initial conversion price of $2.77 per share. Dividends will be payable quarterly at a rate of 13% per annum, provided that we pay dividends in-kind through the issuance of additional shares to BCP. Our Preferred Stock gives BCP a superior right to our assets upon liquidation compared to our common stock and could adversely impact the voting power or value of our common stock. For example, our preferred stock provides BCP the right to nominate one member of the Company's board of directors and the right to veto specified transactions. Similarly, the repurchase or redemption rights or liquidation preferences assigned to BCP could affect the common stock's residual value.
Taking advantage of the reduced disclosure requirements applicable to “emerging growth companies” may make our common stock less attractive to investors.
We qualify as an “emerging growth company” as defined in the Jumpstart Our Business Startups Act (the “JOBS Act”). An emerging growth company may take advantage of certain reduced reporting and other generally applicable public company requirements. Under these reduced disclosure requirements, emerging growth companies are not required to, among other things, comply with the auditor attestation requirements of Section 404 of the Sarbanes-Oxley Act of 2002, provide certain disclosures regarding executive compensation, hold stockholder advisory votes on executive compensation, or obtain stockholder approval of any golden parachute payments not previously approved. In addition, emerging growth companies have extended phase-in periods to adopt new or revised financial accounting standards.
We intend to take advantage of all of the reduced reporting requirements and exemptions, including the extended phase-in periods for adopting new or revised financial accounting standards under Section 107 of the JOBS Act, until we are no longer an emerging growth company. Under the JOBS Act, emerging growth companies can delay adopting new or revised accounting standards until those standards apply to private companies. If we were to subsequently elect instead to comply with these public company effective dates, such an election would be irrevocable under Section 107 of the JOBS Act.
Our election to use the longer phase-in periods permitted by this election may make it difficult to compare our financial statements to those of non-emerging growth companies and other emerging growth companies that have opted out of the extended phase-in periods under Section 107 of the JOBS Act and who will comply with new or revised financial accounting standards. We cannot predict if investors will find our common stock less attractive because we will rely on these exemptions. If some investors find our common stock less attractive as a result, there may be a less active trading market for our common stock, and our common stock price may be more volatile.
If securities or industry analysts do not publish research or reports about our business, if they adversely change their recommendations regarding our common stock, or our operating results do not meet their expectations, our stock price could decline.
Our common stock's trading market is influenced by the research and reports that industry or securities analysts publish about us or our business. If one or more of these analysts cease coverage of our company or fail to publish reports on us regularly, we could lose visibility in the financial markets, which in turn could cause our stock price or trading volume to decline. Moreover, if one or more of the analysts who cover our company adversely changes their recommendation concerning our common stock or if our operating results do not meet their expectations, our stock price could decline.
We have identified a material weakness in our internal control over financial reporting. If we fail to remediate the material weakness, or if we experience additional material weaknesses in the future or otherwise fail to maintain an effective system of internal controls, we may not be able to accurately or timely report our financial condition or results of operations, which may adversely affect investor confidence in us and, as a result, the value of our common stock.
Effective internal control over financial reporting is necessary for us to provide reliable financial reports and, together with adequate disclosure controls and procedures, is designed to prevent fraud. Any failure to implement required new or improved controls, or difficulties encountered in the implementation, could cause us to fail to meet our reporting obligations. In addition, any testing by us, as and when required, our independent registered public accounting firm may reveal deficiencies in our internal control over financial reporting that are deemed to be material weaknesses or that may require prospective or retroactive changes to our financial statements or identify other areas for further attention or improvement. Inferior internal controls could also cause investors to lose confidence in our reported financial information, which could have a negative effect on the trading price of our common stock.
Management identified a material weakness in our internal control over financial reporting in connection with our assessment as of and for the year ended December 31, 2021. A material weakness is a deficiency, or combination of
deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis. Specifically, these control deficiencies constitute a material weakness, in the aggregate, relating to: (i) the lack of a sufficient number of trained resources with assigned responsibilities and accountability for the design and operation of internal controls over financial reporting; (ii) the lack of formal and effective controls over certain financial statement account balances, (iii) the lack of user profiles to ensure adequate restriction of users to perform only transactions that are consistent with their function; and (iv) the lack of appropriate segregation of duties within the accounting and finance functions, including order to cash, process to pay and payroll business processes.
Although we have begun to implement measures to address the material weakness, the implementation of these measures may not fully address the material weakness and deficiencies in our internal control over financial reporting, and we cannot conclude that these matters have been fully remedied. As we continue to evaluate, and work to improve, our internal control over financial reporting, management may determine that additional or different measures to address control deficiencies or modifications to the remediation plan are necessary. Further, in the future, we may determine that we have additional material weaknesses. Our failure to remediate the material weakness or failure to identify and address any other material weaknesses or control deficiencies could result in inaccuracies in our financial statements and could also impair our ability to comply with applicable financial reporting requirements and related regulatory filings on a timely basis, which could cause investors to lose confidence in our reported financial information, which may result in volatility in and a decline in the market price of our common stock.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
Item 1B. Unresolved Staff Comments
None.

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ITEM 2. PROPERTIES
Item 2. Properties
While many of our employees are embedded directly at our customers’ power generation facilities, we lease our corporate headquarters in Louisville, Kentucky and own and lease other facilities throughout the United States where we conduct business. Our facilities are utilized for operations in our reportable segment and include offices, equipment yards, mines, storage, and manufacturing facilities. As of December 31, 2021, we owned two of our facilities and leased the remainder. We believe that our existing facilities are sufficient for our current needs.

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ITEM 3. LEGAL PROCEEDINGS
Item 3. Legal Proceedings
We are from time-to-time party to various lawsuits, claims and other legal proceedings that arise in the ordinary course of our business. With respect to all such lawsuits, claims and proceedings, we record reserves when it is probable a liability has been incurred, and the amount of loss can be reasonably estimated. Although it is difficult to predict the ultimate outcome of these lawsuits, claims and proceedings, we do not believe that the ultimate disposition of any of these matters, individually or in the aggregate, would have a material adverse effect on our results of operations, financial position or cash flows. We maintain liability insurance for certain risks that is subject to certain self-insurance limits.

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ITEM 4. MINE SAFETY DISCLOSURE
Item 4. Mine Safety Disclosures
Not applicable.
Information About Our Executive Officers
The following information is provided for each of the Company's executive officers as of March 31, 2022.
Name
Age
Positions with Charah Solutions
Scott A. Sewell
42 President, Chief Executive Officer and Director
Roger D. Shannon
57 Chief Financial Officer and Treasurer
Scott A. Sewell-President, Chief Executive Officer and Director. Mr. Sewell has served as President and Chief Executive Officer of Charah Solutions and a member of our board of directors since January 2019. Before that, Mr. Sewell held several other leadership positions with Charah Solutions, including Chief Operating Officer from 2013 to January 2019, Senior Vice President of Operations from 2012 to 2013, Vice President of Operations from 2010 to 2012, and Operations Manager from 2008 to 2010. Before joining Charah Solutions, he worked for Bechtel Corporation from 2002 to 2007. He is a Six Sigma Yellow Belt and holds professional affiliations as a member of the Project Management Institute, the Association of Equipment Management Professionals and the International Erosion Control Association. Mr. Sewell holds a bachelor’s degree in international business from the College of Charleston in South Carolina.
Roger D. Shannon-Chief Financial Officer and Treasurer. Mr. Shannon has served as Chief Financial Officer and Treasurer of Charah Solutions since June 2019. Mr. Shannon previously served in various roles, including CFO, Senior Vice President of Finance, Treasurer and Head of Corporate Development at ADTRAN, a publicly-traded provider of next-generation networking solutions. Mr. Shannon also served as CFO and Treasurer for Steel Technologies, plus various senior finance roles at the Brown-Forman Corporation, British American Tobacco, and accounting positions at Vulcan Materials Company, Lexmark International and KPMG. Roger is a CPA and CFA and has a bachelor’s of science degree in accounting from Auburn University and an MBA from the University of Georgia.
PART II

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Our common stock shares and our Notes trade on the New York Stock Exchange under the symbols “CHRA” and "CHRB," respectively.
As of March 21, 2022, there were 2,523 stockholders of record of our common stock. We have not paid dividends on our common stock to date and do not intend to pay dividends in the foreseeable future. Our debt agreements place certain restrictions on our ability to pay cash dividends on common stock and limit our ability to pay cash dividends on preferred equity. We intend to retain earnings to finance the development and expansion of our business. Payment of common and/or stock dividends in the future will depend upon our debt covenants, our ability to generate earnings, our need for capital, our investment opportunities and our overall financial condition, among other things.
Unregistered Sales of Equity Securities and Use of Proceeds
There were no repurchases of our common stock during the three months ended December 31, 2021.

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ITEM 6. SELECTED FINANCIAL DATA
Item 6. [Reserved]

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion and analysis should be read in conjunction with the historical financial statements and the related notes included in Part II Item 8. Financial Statements and Supplementary Data. The following Management's Discussion and Analysis of Financial Condition and Results of Operations included in this report provides an analysis of our financial condition and results of operations and reasons for material changes therein for the year ended December 31, 2021 as compared to the year ended December 31, 2020 and 2019 ("2020 and 2019"). This discussion contains “forward-looking statements” reflecting our current expectations, estimates, and assumptions concerning events and financial trends that may affect our future operating results or financial position. Actual results and the timing of events may differ materially from those contained in these forward-looking statements due to several factors. Factors that could cause or contribute to such differences include, but are not limited to, capital expenditures, economic and competitive conditions, regulatory changes, and other uncertainties, as well as those factors discussed below and elsewhere herein. Please read Cautionary Note Regarding Forward-Looking Statements. Please read the risk factors and other cautionary statements described under “Item 1A. Risk Factors” included elsewhere herein. Except as required by applicable law, we assume no obligation to update any of these forward-looking statements.
Charah Solutions, Inc.
Charah Solutions, Inc. (together with its subsidiaries, “Charah Solutions,” the “Company,” “we,” “us” or “our”) was incorporated in Delaware in 2018 in connection with our initial public offering in June 2018 and, together with its predecessors, has been in business since 1987. Since our founding, we have continuously worked to anticipate our customers’ evolving environmental needs, increasing the number of services we provide through our embedded presence at their power generation facilities. Our multi-service platform allows customers to gain efficiencies from sourcing multiple required offerings from a single, trusted partner compared to service providers with a more limited scope.
Overview
We are a leading national service provider of mission-critical environmental services and byproduct recycling to the power generation industry. We offer a suite of remediation and compliance services, byproduct services, raw material sales and Environmental Risk Transfer (“ERT”) services. We also design and implement solutions for complex environmental projects (such as coal ash pond closures) and facilitate coal ash recycling through byproduct marketing and other beneficial use services. We believe we are a partner of choice for the power generation industry due to our quality, safety, domain experience, and compliance record, all of which are key criteria for our customers. In 2021, we performed work at more than 40 coal-fired generation sites nationwide.
On November 19, 2020, the Company sold its Allied Power Holdings LLC (“Allied”) subsidiary engaged in maintenance, modification and repair services to the nuclear and fossil power generation industry to an affiliate of Bernhard Capital Partners Management, LP (“BCP”), the Company’s majority shareholder, in an all-cash deal for $40 million (the “Allied Transaction”) subject to customary adjustments for working capital and other adjustments as set forth in the Purchase Agreement. As described in further detail in Part II, Item 8. Financial Statements and Supplementary Data, the company has presented Allied as discontinued operations in the accompanying consolidated financial statements and related notes.
We operate as a single operating segment, reflecting the suite of end-to-end services we offer our utility partners and how our chief operating decision maker reviews consolidated financial information to evaluate results of operations, assess performance and allocate resources for these services. We provide the following services through our one segment: remediation and compliance services, byproduct services, raw material sales and ERT services. Remediation and compliance services are associated with our customers’ need for multi-year environmental improvement and sustainability initiatives, whether driven by regulatory requirements, power generation customer initiatives or consumer expectations and standards. Byproduct services consist of recurring and mission-critical coal ash management and operations for coal-fired power generation facilities while also supporting both our power generation customers’ desire to recycle their recurring and legacy volumes of coal combustion residuals (“CCRs”), commonly known as coal ash, and our ultimate end customers’ need for high-quality, cost-effective supplemental cementitious materials (“SCMs”) that provide a sustainable, environmentally-friendly substitute for Portland cement in concrete. Our raw materials sales provide customers with the raw materials that are essential to their business while also providing the sourcing, logistics, and management needed to facilitate these raw materials transactions around the globe. ERT services represent an innovative solution designed to meet utility customers' evolving and increasingly complex plant closure and environmental remediation needs. These customers need to retire and decommission older or underutilized assets while maximizing the asset's value and improving the environment. Our ERT services manage the sites' environmental remediation requirements, benefiting the communities and lowering the utility customers' costs
COVID-19 Update
The pandemic caused by a novel coronavirus (“COVID-19”) has impacted many aspects of our operations, directly and indirectly, including our employees, the services we provide at our customers’ power generation facilities, our suppliers and the overall market. We, along with our utility partners, have implemented the precautionary health and safety measures recommended by the Centers for Disease Control and Prevention (the “CDC”) in response to the COVID-19 pandemic, including, but not limited to: an employee health status questionnaire, taking daily temperatures, enhanced sanitation practices and cleaning surfaces throughout each shift, and increasing the number of hand sanitizing stations. We have also implemented social distancing measures such as staggering shift start and stop times and break times with additional break spaces to support social distancing as well as holding safety meetings outside of the site trailer. Furthermore, we have implemented work-from-home measures for the majority of office employees. Understanding that the COVID-19 challenge is evolving, based on new information and feedback, we continue to monitor the situation and update our proactive measures in coordination with our customers. We continue to work closely with our utility partners and concrete producer customers to meet their needs and monitor any potential slowdowns of byproduct recycling and marketing services if there is decreased demand for construction materials.
The COVID-19 pandemic presents potential new risks to the Company’s business, including logistical, supply chain and other challenges that may continue to affect demand for services, which are driven by construction activity, and the timing of our remediation and compliance services projects, due to delays in new contract awards and increasing costs and declining availability for certain machinery and equipment.
How We Evaluate Our Operations
We use a variety of financial and operational metrics to assess the performance of our operations, including:
•Revenue;
•Gross Profit;
•Operating Income;
•Adjusted EBITDA; and
•Adjusted EBITDA Margin.
Revenue
We analyze our revenue by comparing actual revenue to our internal projections for a given period and to prior periods to assess our performance. We believe that revenue is a meaningful indicator of the demand and pricing for our services.
Gross Profit
We analyze our gross profit, which we define as revenue less cost of sales, to measure our financial performance. We believe gross profit is a meaningful metric because it provides insight into our revenue streams' financial performance without consideration of Company overhead. When analyzing gross profit, we compare actual gross profit to our internal projections for a given period and prior periods to assess our performance.
Operating Income
We analyze our operating income, which we define as revenue less cost of sales, general and administrative expenses, gain on change in contingent payment liability and impairment expense to measure our financial performance. We believe operating income is a meaningful metric because it provides insight into profitability and operating performance based on our assets' cost basis. We also compare operating income to our internal projections for a given period and to prior periods.
Adjusted EBITDA and Adjusted EBITDA Margin
We view Adjusted EBITDA and Adjusted EBITDA Margin, which are non-GAAP financial measures, as important indicators of performance because they allow for an effective evaluation of our operating performance compared to our peers, without regard to our financing methods or capital structure.
We define Adjusted EBITDA as net loss attributable to Charah Solutions, Inc. before income from discontinued operations, net of tax, interest expense, net, loss on extinguishment of debt, impairment expense, gain on change in contingent payment liability, income taxes, depreciation and amortization, equity-based compensation, the Brickhaven contract deemed termination revenue reversal and transaction-related expenses and other items. Adjusted EBITDA margin represents the ratio of Adjusted EBITDA to total revenue. See “-Non-GAAP Financial Measures” below for more information and a reconciliation of Adjusted EBITDA to net loss, the most directly comparable financial measure calculated and presented in accordance with GAAP.
Key Factors Affecting Our Business and Financial Statements
Ability to Capture New Contracts and Opportunities
Our ability to grow revenue and earnings is dependent on maintaining and increasing our market share, renewing existing contracts, and obtaining additional contracts from proactive bidding on contracts with new and existing customers. We proactively work with existing customers ahead of contract end dates to attempt to secure contract renewals. We also leverage the embedded long-term nature of our customer relationships to obtain insight and capture new business opportunities across our platform.
Seasonality of Business
Based on historical trends, we expect our operating results to vary seasonally. Variations in normal weather patterns can also cause changes in energy consumption which may influence the demand and timing of associated services for our byproduct services offerings. Our byproduct services and raw material sales are also negatively affected during winter months when the use of cement and cement products is generally lower. Inclement weather can impact construction-related activities associated with pond and landfill remediation, which affects the timing of revenue generation for our remediation and compliance services.
Project-Based Nature of Environmental Remediation Mandates
We believe there is a significant pipeline of coal ash ponds and landfills that will require remediation and/or closure in the future. Due to their scale and complexity, these environmental remediation projects are typically completed over longer periods. As a result, our revenue from these projects can fluctuate over time. Some of our revenue from projects is recognized over time using the cost-to-cost input method of accounting for GAAP purposes, based primarily on contract costs incurred to date compared to total estimated contract costs. This method is the most accurate measure of our contract performance because it depicts the company’s performance in transferring control of goods or services promised to customers according to a reasonable measure of progress toward complete satisfaction of the performance obligation. The timing of revenue recorded for financial reporting purposes may differ from actual billings to customers, sometimes resulting in costs and billing in excess of actual revenue. Because of the risks in estimating gross profit margins for long-term jobs, actual results may differ from these estimates.
Byproduct Recycling Market Dynamics
There is a growing demand for recycled coal ash across various applications driven by market forces and governmental regulations, creating the need to dispose of coal ash in an environmentally sensitive manner. Pricing of byproduct services and raw material sales are driven by supply and demand market dynamics as well as the chemical and physical properties of the ash. As demand increases for the end-products that use CCRs’ (i.e., concrete for construction and infrastructure projects), the demand for recycled coal ash also typically rises. These fluctuations affect the relative demand for our services. In recessionary periods, construction and infrastructure spending and the corresponding need for concrete may decline. However, this unfavorable effect may be partially offset by an increase in the demand for recycled coal ash during recessionary periods, given that coal ash is more cost-effective than other alternatives.
Power Generation Industry Spend on Environmental Liability Management and Regulatory Requirements
The power generation industry has increased annual spending on environmental liability management. We believe this results from regulatory requirements and consumer pressure, and the industry’s increasing focus on environmental stewardship. Continued increases in spending on environmental liability management by our customers should result in increased demand for services across our platform.
Many power generation entities are experiencing an increased need to retire and decommission older or less economically viable generating assets while minimizing costs and maximizing the value of the assets and improving the environment. Our ERT services allow these partners to remove the environmental risk and insurance obligations and place control and oversight with a company specializing in these complex remediation and reclamation projects. We believe our broad set of service capabilities, track record of quality service and safety, exacting environmental standards, and a dependable and experienced labor force is a significant competitive advantage. Our work, mission and culture are directly aligned with meeting environmental, sustainability, and governance (“ESG”) standards and providing innovative services to solve our utility customers’ most complex environmental challenges. We believe that we are an industry leader in quality, safety, and compliance, and we are committed to reducing greenhouse gas emissions and preserving our environment for a cleaner energy future.
Cost Management and Capital Investment Efficiency
Our principal operating costs consist of labor, material and equipment costs and equipment maintenance. We focus on cost management and efficiency, including monitoring labor costs, both in terms of wage rates and headcount, along with other costs such as materials and equipment. We believe we maintain a disciplined approach to capital expenditure decisions, typically associated with specific contract requirements. Furthermore, we strive to extend our equipment's useful life by applying a well-planned routine maintenance program.
How We Generate Revenue
Our remediation and compliance services primarily consist of designing, constructing, managing, remediating and closing ash ponds and landfills on customer-owned sites.
Our byproduct services include recycling recurring and contracted volumes of coal-fired power generation waste byproducts, such as fly ash, bottom ash, IGCC slag and gypsum byproducts, each of which can be used for various industrial purposes. Byproduct services also include the management of coal ash which is mission-critical to power plants’ daily operations including silo management, on-site ash transportation and capture, and disposal of combustion byproducts from coal-power operations. More than 90% of our services work is time and materials based, cost reimbursable or unit price contracts, which significantly reduces the risk of loss on contracts and provides gross margin visibility. Revenue from management contracts is recognized when the ash is hauled to the landfill or the management services are provided. Revenue from the sale of ash is recognized when it is delivered to the customer. Revenue from construction contracts is recognized using the cost-to-cost input method.
Our raw materials sales provide customers with the raw materials that are essential to their business while also providing the sourcing, logistics, and management needed to facilitate these raw materials transactions around the globe.
Revenue from construction contracts is recognized using the cost-to-cost input method. Revenue from management contracts is recognized when the ash is hauled to the landfill or the management services are provided. Revenue from the sale of ash is recognized when it is delivered to the customer. This combination of one-stop related services deepens customer connectivity and drives long-term relationships, which we believe are critical for renewing existing contracts, winning incremental business from existing customers at new sites and adding new customers.
Overview of Financial Results
In 2021, we won approximately $840 million in contracted new business awards compared to $715 million in 2020 and $430 million in 2019. The 2021 awards span all of our lines of business and included two ERT projects, two large and several mid-size and smaller remediation and compliance projects, several ash marketing agreements, and multiple renewals of existing contracts. Revenue contributions from these new awards will be recognized beginning in 2021 and 2022 and, for some awards, continue beyond 2022. We believe that our unique ability to provide a single-source solution for large-scale and complex environmental challenges continues to position us well to capture a significant portion of a large and growing addressable market, although the timing of future awards is uncertain. We believe that regulatory developments in several states as well as at the federal level will positively impact our business opportunities over time as state legislatures and the EPA become more prescriptive in their requirements to remediate ash ponds. In addition, customer interest in our ERT services and our EnviroSourceTM ash beneficiation technology remains strong. We made significant progress on a major ERT project in
2021 and announced two additional ERT projects in 2021 and early 2022, with the acquisitions of both expected to close in the second quarter of 2022. We also have contracts for EnviroSourceTM under discussion with potential utility customers.
During the year ended December 31, 2021, we completed a significant refinancing, issuing $135.0 million of unsecured senior notes and approximately 2.9 million shares of common stock for $13.0 million. Proceeds from the refinancing were used to repay all loans and borrowings outstanding under our Credit Facility, which totaled $126.5 million. We terminated the Credit Facility and replaced it with a new asset-based lending facility in November 2021, as discussed below in “-Liquidity and Capital Resources-Our Debt Agreements.” These transactions improved our financial flexibility, extended our debt maturity profile and reduced our debt service requirements. We believe they enhance our ability to grow our business.
Our primary ongoing sources of liquidity and capital resources are cash on the balance sheet, cash flows generated by operating activities and availability under our asset-based lending facility. In part due to longer sales cycles, driven by the increase in the size, scope and complexity of remediation and compliance projects that we are bidding on, we have experienced contract initiation delays and project completion delays that have adversely affected our revenue and overall liquidity. Our lengthy and complex projects require us to expend large sums of working capital, and delays in payment receipts, project commencement or project completion can adversely affect our financial position and the cash flows that typically fund our expenditures. See “-Liquidity and Capital Resources-Our Debt Agreements-Existing Credit Facility” below for more information about the Credit Facility.
Results of Operations
A discussion of results of operations changes between the years ended December 31, 2021 and 2020 is included below. A discussion of changes between the years ended December 31, 2020 and 2019 can be found in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations of our Annual Report on Form 10-K for the year ended December 31, 2020, which was filed with the SEC on March 24, 2021.
Year Ended December 31, 2021 Compared to Year Ended December 31, 2020
The table below sets forth our selected operating data for the years ended December 31, 2021 and 2020.
Year Ended December 31, Change
2021 2020 $ %
(in thousands)
Revenue $ 293,219 $ 232,377 60,842 26.2 %
Cost of sales (267,321) (209,570) (57,751) 27.6 %
Gross profit 25,898 22,807 3,091 13.6 %
General and administrative expenses (42,189) (34,064) (8,125) 23.9 %
Gain on sales-type lease 5,568 - 5,568 (100.0) %
Gains on sales of real estate, property and equipment, net 23,543 - 23,543 100.0 %
Gain on ARO settlement 3,623 - 3,623 100.0 %
Other operating expenses from ERT services (5,078) - (5,078) (100.0) %
Gain on change in contingent payment liability - 9,702 (9,702) (100.0) %
Impairment expense (827) (38,014) 37,187 (97.8) %
Operating income (loss) 10,538 (39,569) 50,107 126.6 %
Interest expense, net (15,227) (13,774) (1,453) 10.5 %
Loss on extinguishment of debt (638) (8,603) 7,965 92.6 %
Income (loss) from equity method investment 191 (2,516) 2,707 (107.6) %
Loss from continuing operations before income taxes (5,136) (64,462) 59,326 92.0 %
Income tax (expense) benefit (661) 914 (1,575) (172.3) %
Loss from continuing operations, net of tax (5,797) (63,548) 60,901 (95.8) %
Income from discontinued operations, net of tax - 8,883 (8,883) (100.0) %
Net loss (5,797) (54,665) 48,868 (89.4) %
Less income attributable to non-controlling interest 17 1,198 (1,181) (98.6) %
Net loss attributable to Charah Solutions, Inc. $ (5,814) $ (55,863) $ 50,049 (89.6) %
Revenue. Revenue increased $60.8 million, or 26.2%, to $293.2 million for the year ended December 31, 2021, as compared to $232.4 million for the year ended December 31, 2020, primarily driven by an increase in remediation and compliance services revenue of $79.8 million from the commencement of new project work. This increase was partially offset by (i) lower raw materials sales of $13.6 million resulting from reduced supply from international sources due to supply chain constraints resulting from significantly higher ocean cargo rates that have led to a decrease in profitable imported fly ash sales opportunities and (ii) lower byproduct services revenue of $5.3 million primarily due to the dissolution of our Ash Ventures LLC joint venture in the second quarter of 2021.
Gross Profit. Gross profit increased $3.1 million, or 13.6%, to $25.9 million for the year ended December 31, 2021 as compared to $22.8 million for the year ended December 31, 2020. As a percentage of revenue, gross profit was 8.8% and 9.8% for the years ended December 31, 2021 and 2020, respectively. The increase in gross profit was primarily driven by an increase in revenue as discussed above, partially offset by a lower gross profit margin percentage. The decline in gross profit margin was primarily driven by issues at certain remediation and compliance projects, most of which are nearing completion, resulting from construction delays and supply chain issues, mostly affecting the fourth quarter of 2021.
General and Administrative Expenses. General and administrative expenses increased $8.1 million, or 23.9%, to $42.2 million for the year ended December 31, 2021, as compared to $34.1 million for the year ended December 31, 2020. The increase was primarily attributable to the absence of a $7.1 million reduction in expense from the expiration of our purchase option liability on our structural fill sites.
Gain on sales-type lease. Gain on sales-type lease increased $5.6 million for the year ended December 31, 2021 due to the recognition of a parcel transferred under a sales-type lease at an ERT project as discussed in Note 6, Balance Sheet Items, to the accompanying consolidated financial statements.
Gains on sales of real estate, property and equipment, net. Gains on sales of real estate, property and equipment, net increased $23.5 million for the year ended December 31, 2021 due to the commencement of operations on the Gibbons Creek ERT project in 2021 that led to sales of certain parcels of land acquired and increased scrap sales from the demolition of the power plant, as well as due to the sale of certain grinding-related assets.
Gain on ARO settlement. Gain on ARO settlement increased $3.6 million for the year ended December 31, 2021 due to differences between the estimated costs used in the measurement of the fair value of the Company's AROs and the actual costs incurred for specific remediation tasks recognized on a proportionate basis.
Other operating expenses from ERT services. Other operating expenses from ERT services increased $5.1 million for the year ended December 31, 2021 due to expenses associated with the commencement of operations on the Gibbons Creek ERT project in 2021.
Gain on Change in Contingent Payment Liability. A gain on the change in contingent payment liability resulted in a $9.7 million benefit for the year ended December 31, 2020 and did not recur in 2021. We reduced the associated liability because we determined that certain performance sales levels using the grinding technology mentioned below would not be achieved.
Impairment Expense. Impairment expense decreased $37.2 million to $0.8 million for the year ended December 31, 2021, as compared to $38.0 million for the year ended December 31, 2020 primarily driven by (i) the non-recurrence of a $21.0 million impairment of the Charah Solutions trade name indefinite-lived intangible asset, (ii) a decrease of $9.8 million of impairments of certain grinding technology equipment and construction in progress assets and intangible asset, and (iii) the non-recurrence of a $6.4 million impairment related to our structural fill site asset resulting from the expiration of the purchase option liability.
Interest Expense, Net. Interest expense, net increased $1.5 million, or 10.5%, to $15.2 million for the year ended December 31, 2021, as compared to $13.8 million for the year ended December 31, 2020. The increase was primarily attributable to higher debt balances, a higher weighted-average cost of capital associated with equipment financing and an increase in amortization of debt issuance costs.
Loss on Extinguishment of Debt. Loss on extinguishment of debt decreased $8.0 million during the year ended December 31, 2020 due to the absence of the Company’s Amendment No. 3 to Credit Agreement (the “Third Amendment”) of our previous Credit Facility. The Company expensed $5.2 million in amendment fees and wrote off $3.4 million in previously capitalized debt issuance costs during the year ended December 31, 2020.
Income (Loss) from Equity Method Investment. Income (loss) from equity method investment increased $2.7 million to $0.2 million for the year ended December 31, 2021, as compared to a loss from equity investment of $2.5 million for the year ended December 31, 2020. The increase period-over-period was primarily attributable to the absence of a $3.8 million impairment of our investment in the joint venture that resulted from the fair value of our investment being less than its carrying value at December 31, 2020, partially offset by a decrease in operating income from our equity method investment due to the joint venture arrangement ending during the year ended December 31, 2021.
Income Tax (Expense) Benefit. Income tax (expense) benefit decreased by $1.6 million to a $0.7 million expense for the year ended December 31, 2021, as compared to a $0.9 million benefit during the year ended December 31, 2020. The change in balance was primarily driven by an increase in the valuation allowance recorded during the year ended December 31, 2021 as compared to the year ended December 31, 2020 as we were not able to conclude it was more likely than not certain deferred tax assets will be realized. Furthermore, during the year ended December 31, 2021 the income tax expense was attributed to the impact of accelerated tax depreciation and amortization of tax goodwill on the valuation allowance.
Income from Discontinued Operations, Net of Tax. Income from discontinued operations, net of tax, decreased $2.7 million for the year ended December 31, 2021 due to the sale of our subsidiary through the Allied Transaction during the year ended December 31, 2020.
Net Loss. Net loss decreased $48.9 million, or 89.4%, to $5.8 million for the year ended December 31, 2021, as compared to $54.7 million for the year ended December 31, 2020.
Consolidated Balance Sheet
The following table is a summary of our overall financial position:
As of December 31, Change
2021 2020 $
(in thousands)
Total assets $ 344,107 $ 280,960 $ 63,147
Total liabilities 287,778 233,221 54,557
Mezzanine equity 35,532 27,423 $ 8,109
Total equity 20,797 20,316 481
Assets
Total assets increased $63.1 million, driven primarily by:
▪$37.7 million in property and equipment additions, net of disposals, resulting from the Gibbons Creek Transaction and new capital leases entered into during the year ended December 31, 2021;
▪$30.0 million in cash and restricted cash due to $10.2 million in cash used in operating activities, $56.4 million in cash provided by investing activities and $16.3 million in cash used in financing activities;
▪$8.5 million in increases to contract assets resulting from the commencement of new remediation and compliance services project work that has led to additional costs and estimated earnings in excess of billings and retainage;
▪$6.0 million in increases to other assets resulting from a lease receivable recognized during the year ended December 31, 2021 from the sales-type lease discussed in Note 6, Balance Sheet Items, to the accompanying consolidated financial statements; and
▪$2.7 million in increases to trade accounts receivable, net from the commencement of new remediation and compliance services and the timing of receipts of outstanding payments from customers.
These increases were partially offset by:
▪$16.7 million in property and equipment depreciation expense during the year ended December 31, 2021; and
▪$7.9 million in intangible asset amortization expense during the year ended December 31, 2021.
Liabilities
Total liabilities increased $54.6 million, primarily driven by:
•$156.3 million in proceeds from long-term debt;
•$37.3 million in increases to current and non-current asset retirement obligations (“AROs”) resulting from the AROs acquired in Gibbons Creek Transaction and partially offset by ARO liabilities settled and gain on ARO settlement during the year ended December 31, 2021;
•$24.5 million in new capital lease obligations entered into during the year ended December 31, 2021; and
•$17.0 million in increases to accounts payables and accrued expenses from the commencement of new remediation and compliance services and the timing of payments to vendors.
These increases were partially offset by:
•$154.8 million in principal payments of long-term debt;
•$13.4 million in new debt issuance costs from our Notes offering and asset-based lending credit agreement;
•$12.0 million in net payments on our line of credit under our previous Credit Facility;
•$7.4 million in payments of the working capital adjustment and other items for the Allied Transaction; and
•$4.8 million in principal payments on capital lease obligations.
Mezzanine Equity
Total mezzanine equity increased $8.1 million primarily driven by paid-in-kind dividends and accretion associated with our Preferred Stock.
Total Equity
Total equity increased $0.5 million, driven primarily by $13.0 million from the issuance of common stock and $2.7 million in share-based compensation, partially offset by $8.7 million in paid in-kind and deemed dividends associated with our Preferred Stock, a $5.8 million net loss and $0.5 million in taxes paid related to the net settlement of shares.
Liquidity and Capital Resources
Our primary ongoing sources of liquidity and capital resources are cash on the balance sheet, cash flows generated by operating activities, borrowings under the Notes, proceeds from the issuance of common stock and availability under our asset-based lending credit agreement. Due to longer sales cycles, driven by the increase in the size, scope and complexity of remediation and compliance projects that we are bidding on, we have experienced contract initiation delays and project completion delays that have adversely affected our revenue and overall liquidity. Our long and complex projects require us to
expend large sums of working capital, and delays in payment receipts, project commencement or project completion can adversely affect our financial position and the cash flows that typically fund our expenditures.
As of December 31, 2021, we had cash of $24.3 million and borrowing capacity under our Asset Based Lending Credit Agreement of $13.2 million, for total liquidity of $37.5 million. We believe our cash on hand and cash generated from operations will be sufficient to cover our working capital requirements and debt obligations for the next 12 months.
Cash Flows
The following table is a summary of our cash flows for the years ended December 31, 2021 and 2020:
Year Ended December 31, Change
2021 2020 $
(in thousands)
Net cash and restricted cash (used in) provided by operating activities $ (10,166) $ 12,522 $ (22,688)
Cash and restricted cash provided by investing activities $ 56,432 $ 42,073 14,359
Cash and restricted cash used in financing activities $ (16,303) $ (31,512) 15,209
Year Ended December 31, 2021 Compared to Year Ended December 31, 2020
Operating Activities
Net cash and restricted cash (used in) provided by operating activities decreased $22.7 million to $10.2 million of net cash used in operating activities for the year ended December 31, 2021 as compared to $12.5 million of net cash provided by operating activities. The change in cash flows provided by operating activities was primarily attributable to:
▪a decrease in net loss of $48.9 million.
▪a decrease in non-working capital adjustments to net loss of $71.3 million, primarily due to a decrease of $39.9 million in impairment expense, an increase of $24.1 million in (gain) loss on sale of property and equipment, a decrease of $8.0 million in loss on extinguishment of debt, $5.6 million in gain on a sales-type lease, $3.6 million in gain on ARO settlements, an increase of $2.7 million in (income) loss from equity method investment and a decrease of $1.6 million in paid-in-kind interest on long-term debt. These changes were partially offset by the absence of $9.7 million in gain on change in contingent payment liability and an increase of $4.7 million in depreciation and amortization during the year ended December 31, 2021.
▪a decrease of $0.3 million from all other operating activities.
Investing Activities
Net cash and restricted cash provided by investing activities increased $14.4 million to $56.4 million for the year ended December 31, 2021, as compared to $42.1 million for the year ended December 31, 2020. The change in cash flows provided by investing activities was primarily attributable to a $37.2 increase in proceeds from the sales of real estate, property and equipment, primarily from real estate and scrap sales associated with the Gibbons Creek Transaction, $34.9 million in cash and restricted cash received from the Gibbons Creek Transaction, and $1.0 million of distributions received from our equity method investment. These increases were partially offset by the absence of $34.9 million of proceeds from the sale of a subsidiary, net of subsidiary cash, $7.0 million in proceeds received from a sales-leaseback transaction, payments of $7.4 million of the working capital adjustment and other items resulting from the Allied Transaction and an increase in capital and land improvement expenditures of $4.2 million.
Financing Activities
Net cash and restricted cash used in financing activities decreased $15.2 million for the year ended December 31, 2021, to $16.3 million as compared to $31.5 million for the year ended December 31, 2020. The change in cash flows used in financing activities was primarily attributable to a $156.3 million increase in proceeds received from long-term debt, $13.0 million of proceeds received from the issuance of common stock and a decrease of $1.4 million in distributions to our non-controlling interest. These changes were partially offset by an $159.5 million increase in principal payments on long-term debt and capital lease obligations, the absence of $24.3 million of proceeds received from Preferred Stock issuance, an $11.8 million increase in payments of debt issuance costs and the change in net activity of $5.0 million on the line of credit.
Working Capital
Our working capital, which we define as total current assets less total current liabilities, totaled $31.5 million at December 31, 2021 as compared to $21.5 million as of December 31, 2020. This increase in net working capital for the year ended December 31, 2021 was primarily due to:
•increases in restricted cash associated with the Gibbons Creek Transaction and the cash collateral deposits for our letters of credit;
•increases in contract assets and trade accounts receivable primarily due to an increase in the number of remediation and compliance projects and changes in the timing of the related billings and collections associated with these projects; and
•decreases in current maturities of capital lease obligations and notes payable due to the refinance of our previous Credit Facility into the Notes and our use of the proceeds from the Notes, along with cash from the sale of equity to B. Riley, to fully repay and terminate the Credit Facility as it became due and payable.
These changes were partially offset by:
•increases in the current portion of our asset retirement obligations primarily driven by the AROs acquired in the Gibbon Creek Transaction and the estimated timing of such remediation activities; and
•increases in accounts payable and accrued liabilities, primarily driven by an increase in the number of remediation and compliance projects and changes in the timing of the related payments to vendors associated with these projects.
Our Debt Agreements
Senior Notes
On August 25, 2021, the Company completed an offering of $135.0 million, in the aggregate, of the Company’s Notes, which amount includes the exercise by the underwriters of their option to purchase an additional $5.0 million aggregate principal amount of Notes.
The Notes were sold pursuant to the Company’s Registration Statement on Form S-1, as amended (File No. 333-258650), which was declared effective by the Securities and Exchange Commission on August 20, 2021. The Notes were issued pursuant to the First Supplemental Indenture (the “First Supplemental Indenture”), dated as of August 25, 2021, between the Company and Wilmington Savings Fund Society, FSB, as trustee (the “Trustee”). The First Supplemental Indenture supplements the Indenture entered into by and between the Company and the Trustee, dated as of August 25, 2021 (the “Base Indenture” and, together with the First Supplemental Indenture, the “Indenture”).
The public offering price of the Notes was 100.0% of the principal amount. The Company received proceeds before payment of expenses and other fees of $135.0 million. The Company used the proceeds, along with cash from the issuance of $13.0 million of common stock, to fully repay and terminate the Company’s Credit Facility, as defined below.
The Notes bear interest at the rate of 8.50% per annum. Interest on the Notes is payable quarterly in arrears on January 31, April 30, July 31 and October 31 of each year, commencing October 31, 2021. The Notes will mature on August 31, 2026.
The Company may redeem the Notes for cash in whole or in part at any time (i) on or after August 31, 2023 and prior to August 31, 2024, at a price equal to 103% of their principal amount, plus accrued and unpaid interest to, but excluding, the date of redemption, (ii) on or after August 31, 2024 and prior to August 31, 2025, at a price equal to 102% of their principal amount, plus accrued and unpaid interest to, but excluding, the date of redemption, and (iii) on or after August 31, 2025 and prior to maturity, at a price equal to 100% of their principal amount, plus accrued and unpaid interest to, but excluding, the date of redemption. On and after any redemption date, interest will cease to accrue on the redeemed Notes. If the Company is redeeming less than all of the Notes, the Trustee will select the Notes to be redeemed by such method as the Trustee deems fair and appropriate in accordance with methods generally used at the time of selection by fiduciaries in similar circumstances.
The Indenture also contains customary event of default and cure provisions. If an uncured default occurs and is continuing, the Trustee or the holders of not less than 25% in aggregate principal amount of the Notes may declare the Notes to be immediately due and payable.
The Notes are senior unsecured obligations of the Company and rank equal in right of payment with the Company’s existing and future senior unsecured indebtedness.
As a result of the issuance of the Notes, $12,116 of third-party fees were capitalized as debt issuance costs that will be amortized through interest expense, net in the accompanying consolidated statements of operations using the effective interest method through the maturity date of the Notes.
Asset-Based Lending Credit Agreement
On November 9, 2021, the Company entered into a new Credit Agreement with JPMorgan Chase Bank, N.A. (“JPMorgan”), as administrative agent, the lenders party thereto and certain subsidiary guarantors named therein. The Credit
Agreement provides for a four-year senior secured revolving credit facility with initial aggregate commitments from the lenders of $30.0 million, which includes $5.0 million available for swingline loans, plus an additional $5.0 million of capacity available for the issuance of letters of credit if supported by cash collateral provided by the Company (with a right to increase such amount by up to an additional $5.0 million) (“Aggregate Revolving Commitments”). Availability under the Credit Agreement is subject to a borrowing base calculated based on the value of certain eligible accounts receivable, inventory, and equipment of the Company and subject to redeterminations made in good faith and in the exercise of permitted discretion of JPMorgan. Proceeds of the Credit Agreements may be used for working capital and general corporate purposes.
The Credit Agreement provides for borrowings of either base rate loans or Eurodollar loans. Principal amounts borrowed are payable on the maturity date with such borrowings bearing interest that is payable (i) with respect to base rate loans, monthly and (ii) with respect to Eurodollar loans, the last day of each Interest Period (as defined below); provided that if any Interest Period for a Eurodollar loan exceeds three months, interest will be payable on the respective dates that fall every three months after the beginning of such Interest Period. Eurodollar Loans bear interest at a rate per annum equal to the Adjusted LIBOR for one, three or six months (the “Interest Period”), plus an applicable margin of 2.25%. Base rate loans bear interest at a rate per annum equal to the greatest of (i) the agent bank’s reference rate, (ii) the federal funds effective rate plus 50 basis points and (iii) the rate for one month Adjusted LIBOR loans plus 100 basis points, plus an applicable rate of 125 basis points. The Credit Agreement contains a provision for sustainability adjustments annually that will impact the applicable margin by between positive 0.05% and negative 0.05% based on the achievement, or lack thereof, of certain metrics agreed upon between JPMorgan and the Company and publicly reported through the Company’s annual non-financial sustainability report.
The Credit Agreement is guaranteed by certain of the Company’s subsidiaries and is secured by substantially all of the Company’s and such subsidiaries’ assets. The Credit Agreement contains customary restrictive covenants for asset-based loans that may limit the Company’s ability to, among other things: incur additional indebtedness, sell assets, make loans to others, make investments, pay cash dividends to common stockholders, limit or restrict payments of cash dividends on preferred equity, enter into mergers, make certain restricted payments, incur liens, and engage in certain other transactions without the prior consent of the lenders.
A covenant testing period (“Covenant Testing Period”) is a period in which excess availability (which is defined in the Credit Agreement as the sum of availability and an amount up to $1.0 million) is less than the greater of (a) 12.5% of the lesser of the aggregate revolving commitments and the borrowing base, (b) the lesser of $7.5 million and the PP&E Component as defined in the Credit Agreement, and (c) $3.5 million, for three consecutive business days. During a Covenant Testing Period, the Credit Agreement requires the Company to maintain a fixed charge coverage ratio as defined in the Credit Agreement, determined for any period of twelve (12) consecutive months ending on the last day of each fiscal quarter, of at least 1.00 to 1.00.
As of December 31, 2021, the Company has not drawn on the Credit Agreement. Outstanding letters of credit under this Credit Agreement were $19,027 as of December 31, 2021. As of December 31, 2021, the Company had $13.4 million of outstanding letters of credit with JPMorgan and $5.6 million with Bank of America, N.A.
As a result of entering into the Credit Agreement, $1,366 of third-party fees were capitalized as debt issuance costs that will be amortized through interest expense, net in the accompanying consolidated statements of operations using the effective interest method through the maturity date of the Credit Agreement.
Letter of Credit Cash Collateralization Promissory Note
On August 25, 2021, Charah, LLC issued a Secured Promissory Note (the “Promissory Note”), as the borrower, in favor of B. Riley Commercial Capital, LLC, as the noteholder (the “Noteholder”), evidencing a loan in aggregate principal amount of $17.9 million made by the Noteholder to Charah, LLC. The loan outstanding under the Promissory Note bore interest at a rate of eight percent (8%) per annum and was set to mature on the thirteen-month anniversary of the effective date of the Promissory Note. The proceeds of the Promissory Note were used by the Company and its subsidiaries to collateralize the Company's existing letters of credit issued through Bank of America, N.A. The loan was repaid in full during the year ended December 31, 2021.
Previous Credit Facility
On September 21, 2018, we entered into a credit agreement (the “Credit Facility”) by and among us, the lenders party thereto from time to time and Bank of America, N.A., as administrative agent (the “Administrative Agent”). The Credit Facility included:
•A revolving loan not to exceed $50.0 million (the “Revolving Loan”);
•A term loan of $205.0 million (the “Closing Date Term Loan”); and
•A commitment to loan up to a further $25.0 million in term loans, which expired in March 2020 (the “Delayed Draw Commitment” and the term loans funded under such Delayed Draw Commitment, the “Delayed Draw Term Loan,” together with the Closing Date Term Loan, the “Term Loan”).
Pursuant to the terms of the Credit Facility and its related amendments, all amounts associated with the Revolving Loan and the Term Loan under the Credit Facility were set to mature in July 2022. The interest rates per annum applicable to the loans under the Credit Facility were based on a fluctuating rate of interest measured by reference to, at our election, either (i) the Eurodollar rate, currently LIBOR, or (ii) an alternative base rate. Various margins were added to the interest rate based on our consolidated net leverage ratio (as defined in the Credit Facility). Customary fees were payable regarding the Credit Facility and included (i) commitment fees for the unused portions of the Credit Facility and (ii) fees on outstanding letters of credit. Amounts borrowed under the Credit Facility were secured by substantially all of the assets of the Company.
The Credit Facility contained various customary representations, warranties, restrictive covenants, certain affirmative covenants, including reporting requirements, and customary events of default.
Outstanding letters of credit under the previous Credit Facility were $11.1 million as of December 31, 2020.
During the year ended December 31, 2021, using the proceeds from the Notes, along with cash from the sale of equity to B. Riley, to fully repay and terminate the Credit Facility, the Company paid $114.1 million of outstanding principal on the Closing Date Loan and $12.3 million of outstanding loans on the Revolver. Further, the Company paid $2.0 million of previously accrued fees required as consideration for Amendment No. 3 to Credit Agreement that was otherwise due and payable on the maturity date. During the year ended December 31, 2021, the Company wrote off unamortized debt issuance costs of $0.6 million as a result of this refinancing, which is included in loss on extinguishment of debt in the accompanying consolidated statements of operations.
Equipment Financing Facilities and Capital Lease Equipment Financing
We have entered into various equipment financing arrangements to finance the acquisition of certain equipment (the “Equipment Financing Facilities”). As of December 31, 2021, we had $17.2 million of equipment notes outstanding. Each of the Equipment Financing Facilities includes non-financial covenants, and, as of December 31, 2021, we complied with all such covenants.
We have entered into various equipment capital lease financing arrangements to finance the acquisition of certain equipment. As of December 31, 2021, we had $30.4 million of future minimum lease payments related to this equipment.
Series A Preferred Stock
As a condition to the Third Amendment, the Company entered into an agreement with an investment fund affiliated with Bernhard Capital Partners Management, LP (“BCP”) to sell 26,000 shares of Series A Preferred Stock, par value $0.01 per share (the “Preferred Stock”), for net proceeds of approximately $25.2 million in a private placement (the “Preferred Stock Offering”). The Preferred Stock has an initial liquidation preference of $1,000 per share and pays a dividend at the rate of 10% per annum in cash, or 13% if the Company elects to pay dividends in-kind by adding such amount to the liquidation preference. Upon meeting certain “specified payment conditions,” the Company has the ability under the Asset-Based Lending Credit Agreement to pay cash dividends on the Series A Preferred Stock. However, the Company intends to pay dividends-in-kind for the foreseeable future. We used proceeds from the Preferred Stock Offering for liquidity and general corporate purposes.
For more information related to the Series A Preferred Stock, see Note 12 “Mezzanine Equity" to the notes to consolidated financial statements included in Part II, Item 8. Financial Statements and Supplementary Data of this Annual Report on Form 10-K.
Common Stock Issuances
In August 2021, the Company executed a stock purchase agreement with a previously unrelated third party, B. Riley, and issued 2.9 million shares of common stock at $4.50 per share in a private placement for total proceeds of $13.0 million. Pursuant to the terms of the stock purchase agreement, B. Riley entered into an Investor Rights Agreement and appointed one director to the Company's board of directors.
Material Cash Requirements
The following table sets forth our material cash requirements from contractual obligations as of December 31, 2021.
Total 2022 2023 2024 2025 2026 Thereafter
(in thousands)
Senior Notes $ 135,000 $ - $ - $ - $ - $ 135,000 $ -
Equipment Financing Facilities 17,205 7,100 5,545 3,226 1,122 212 -
Commercial insurance financing agreement 467 467 - - - - -
Interest on Outstanding Loans 54,932 12,243 11,893 11,640 11,512 7,644 -
Capital Lease Obligations 30,427 8,680 8,429 6,231 4,794 2,293 -
Interest on Capital Lease Obligations 3,802 1,631 1,147 685 273 66 -
Operating Lease Obligations(1)
29,106 10,216 9,271 5,646 2,151 1,003 819
Minimum Royalty and purchase obligations 49,620 14,101 13,644 15,914 5,961 - -
Total(2)
$ 320,559 $ 54,438 $ 49,929 $ 43,342 $ 25,813 $ 146,218 $ 819
(1)We lease equipment and office facilities under non-cancellable operating leases.
(2)Contingent payments for acquisitions and the asset retirement obligation are not included in the table above because such payments' timing is uncertain. There are no uncertain tax positions.
Non-GAAP Financial Measures
Adjusted EBITDA
Adjusted EBITDA and Adjusted EBITDA margin are not financial measures determined in accordance with GAAP.
We define Adjusted EBITDA as net loss attributable to Charah Solutions, Inc. before income from discontinued operations, net of tax, interest expense, net, loss on extinguishment of debt, impairment expense, gain on change in contingent payment liability, income taxes, depreciation and amortization, equity-based compensation, the Brickhaven contract deemed termination revenue reversal and transaction-related expenses and other items. Adjusted EBITDA margin represents the ratio of Adjusted EBITDA to total revenue.
We believe Adjusted EBITDA and Adjusted EBITDA margin are useful performance measures because they allow for an effective evaluation of our operating performance compared to our peers, without regard to our financing methods or capital structure. We exclude the items listed above from net loss attributable to Charah Solutions, Inc. in arriving at Adjusted EBITDA because these amounts are either non-recurring or can vary substantially within our industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Adjusted EBITDA should not be considered as an alternative to, or more meaningful than, net loss attributable to Charah Solutions, Inc. determined according to GAAP. Certain items excluded from Adjusted EBITDA are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are reflected in Adjusted EBITDA. Our Adjusted EBITDA presentation should not be construed as an indication that our results will be unaffected by the items excluded from Adjusted EBITDA. Our computations of Adjusted EBITDA may not be identical to other similarly titled measures of other companies. We use Adjusted EBITDA margin to measure our business's success in managing our cost base and improving profitability. The following table presents a reconciliation of Adjusted EBITDA to net loss attributable to Charah Solutions Inc., our most directly comparable financial measure calculated and presented in accordance with GAAP, along with our Adjusted EBITDA margin.
The table below represents the consolidated financial information of Charah Solutions for the years ended December 31, 2021, 2020 and 2019.
Year Ended December 31,
2021 2020 2019
(in thousands)
Net loss attributable to Charah Solutions, Inc. $ (5,814) $ (55,863) $ (42,058)
Income from discontinued operations, net of tax - (8,883) (7,105)
Interest expense, net(1)
15,227 13,774 14,624
Loss on extinguishment of debt(1)
638 8,603 -
Impairment expense(1)
827 44,572 -
Gain on change in contingent payment liability(1)
- (9,702) -
Income tax expense (benefit)(1)
661 (914) 4,190
Depreciation and amortization(1)
24,612 19,131 22,846
Equity-based compensation(1)
2,702 2,394 2,414
Brickhaven contract deemed termination revenue reversal(1)
- - 10,000
Transaction-related expenses and other items(1)(2)
1,219 1,130 3,458
Adjusted EBITDA $ 40,072 $ 14,242 $ 8,369
Adjusted EBITDA margin(3)
13.7 % 6.1 % 7.4 %
(1)Represents amounts for continuing operations only.
(2)Represents expenses associated with the Amendment to the Credit Facility, non-recurring legal costs and expenses and other miscellaneous items.
(3)Adjusted EBITDA margin is a non-GAAP financial measure that represents the ratio of Adjusted EBITDA to total revenue. We use Adjusted EBITDA margin to measure the success of our businesses in managing our cost base and improving profitability.
Critical Accounting Policies and Estimates
Our financial statements are prepared in accordance with GAAP. In connection with preparing our financial statements, we are required to make assumptions and estimates about future events and apply judgments that affect the reported amounts of assets, liabilities, revenue, expense, and related disclosures. We base our assumptions, estimates, and judgments on historical experience, current trends and other factors that management believes to be relevant when preparing our consolidated financial statements. Regularly, management reviews the accounting policies, assumptions, estimates, and judgments to ensure that our consolidated financial statements are presented fairly and in accordance with GAAP. However, because future events and their effects cannot be determined with certainty, actual results could differ materially from our assumptions and estimates.
Our significant accounting policies are described in Note 2 to our consolidated financial statements included herein. Our critical accounting policies are described below to provide a better understanding of our estimates and assumptions about future events that affect the amounts reported in the consolidated financial statements and accompanying notes. Significant accounting estimates are important to the representation of our financial position and results of operations and involve our most difficult, subjective or complex judgments. We base our estimates on historical experience and various other assumptions we believe to be reasonable according to the current facts and circumstances through the date of the issuance of our financial statements.
Revenue
To determine revenue recognition for contracts, we evaluate whether two or more contracts should be combined and accounted for as one single contract and whether the combined or single contract should be accounted for as more than one performance obligation. This evaluation requires significant judgment, and the decision to combine a group of contracts or separate a combined or single contract into multiple performance obligations could change the amount of revenue and profit recorded in a given period. Contracts are considered to have a single performance obligation if the promise to transfer the individual goods or services is not separately identifiable from other promises in the contracts primarily because we provide a service that involves multiple inter-related and integrated tasks to achieve the completion of a specific, single project. We allocate the transaction price to each performance obligation for contracts with multiple performance obligations using our best estimate of the stand-alone selling price of each distinct good or service in the contract.
For sales and service contracts where we have the right to consideration from the customer in an amount that corresponds directly with the value received by the customer based on our performance to date, revenue is recognized at a point in time when services are performed and contractually billable. Certain service contracts contain provisions dictating fluctuating rates per unit for the certain services in which the rates are not directly related to changes in the Company’s effort to perform under the contract. We recognize revenue based on the stand-alone selling price per unit for such contracts, calculated as the average rate per unit over the term of those contractual rates. This creates a contract asset or liability for the difference between the revenue recognized and the amount billed to the customer.
Under the typical payment terms of our services contracts, amounts are billed as work progresses in accordance with agreed-upon contractual terms, at periodic intervals (e.g., weekly, biweekly or monthly).
We recognize revenue over time, as performance obligations are satisfied, for substantially all of our construction contracts due to the continuous transfer of control to the customer. For most of our construction contracts, the customer contracts with us to provide a service that involves multiple inter-related and integrated tasks to complete a specific, single project and is therefore accounted for as a single performance obligation. We recognize revenue using the cost-to-cost input method, based primarily on contract costs incurred to date compared to total estimated contract costs. This method is the most accurate measure of our contract performance because it depicts the company’s performance in transferring control of goods or services promised to customers according to a reasonable measure of progress toward complete satisfaction of the performance obligation.
Contract costs include all direct material, labor and subcontractor costs and indirect costs related to contract performance. The costs incurred that do not relate directly to transferring a service to the customer are excluded from the input method used to recognize revenue. Project mobilization costs are generally charged to the project as incurred when they are an integrated part of the performance obligation being transferred to the client. Pre-contract costs are expensed as incurred unless they are expected to be recovered from the client.
It is common for our contracts to contain contract provisions that give rise to variable consideration such as unpriced change orders or volume discounts that may either increase or decrease the transaction price. We estimate the amount of variable consideration at the expected value or most likely amount, depending on which is determined to be more predictive of the amount to which the Company will be entitled. Variable consideration is included in the transaction price when it is probable that a significant reversal of cumulative revenue recognized will not occur or when the uncertainty associated with the variable consideration is resolved. Our estimates of variable consideration and determination of whether to include such amounts in the transaction price are based largely on our assessment of legal enforceability, anticipated performance, industry business practices, and any other information (historical, current or forecasted) that is reasonably available to us. Variable consideration associated with unapproved change orders is included in the transaction price only to the extent of costs incurred.
We provide limited warranties to customers for work performed under our contracts. Such warranties are not sold separately, assure that the services comply with the agreed-upon specifications and legal requirements and do not provide customers with a service in addition to assurance of compliance with agreed-upon specifications. Accordingly, these types of warranties are not considered to be separate performance obligations. Historically, warranty claims have not resulted in material costs incurred by the Company.
Due to the nature of the work required to be performed on many of our performance obligations, the estimation of total revenue and cost at completion is complex, subject to many variables and requires significant judgment. As a significant change in one or more of these estimates could affect the profitability of our contracts, we routinely review and update our contract-related estimates through a disciplined project review process in which management reviews the progress and execution of our performance obligations and the estimated costs at completion. As part of this process, management reviews information including, but not limited to, outstanding contract matters, progress towards completion, program schedule and the associated changes in estimates of revenue and costs. Management must make assumptions and estimates regarding the availability and productivity of labor, the complexity of the work to be performed, the availability and cost of materials, the performance of subcontractors, and the availability and timing of funding from the customer, along with other risks inherent in performing services under all contracts where we recognize revenue over-time using the cost-to-cost method.
We recognize changes in contract estimates on a cumulative catch-up basis in the period in which the changes are identified. Such changes in contract estimates can result in recognition of revenue in a current period for performance obligations that were satisfied or partially satisfied in prior periods. Changes in contract estimates may also result in the reversal of previously recognized revenue if the current estimate differs from the previous estimate. If at any time the estimate of contract profitability indicates an anticipated loss on the contract, we recognize the total loss in the period it is identified.
Contracts are often modified to account for changes in contract specifications and requirements. Most of our contract modifications are for goods or services that are not distinct from existing contracts due to the significant integration provided in
the context of the contract and are accounted for as if they were part of the original contract. The effect of a contract modification on the transaction price and our measure of progress for the performance obligation to which it relates is recognized as an adjustment to revenue (either as an increase in or a reduction of revenue) on a cumulative catch-up basis. We account for contract modifications when the modification results in the promise to deliver additional goods or services that are distinct and the increase in the price of the contract is for the same amount as the stand-alone selling price of the additional goods or services included in the modification.
Goodwill
Goodwill represents the cost of an acquisition purchase price over the fair value of acquired net assets, and such amounts are reported separately as goodwill on our Consolidated Balance Sheets. Our total goodwill resulted from applying “push-down” accounting associated with BCP’s January 2017 acquisition of a controlling equity position in Charah Management and the acquisition of certain assets and liabilities of SCB.
Goodwill is not amortized, but instead is tested for impairment at least annually, at October 1st of each year, or more often if events or circumstances indicate that goodwill might be impaired. We test goodwill of the Company as a whole since we concluded the Company was a single reporting unit. We may elect to perform a qualitative assessment of our reporting units to determine whether it is more likely than not that the reporting units' fair value is greater than their carrying value. If a qualitative assessment is not performed, or if as a result of a qualitative assessment it is not more likely than not that the fair value of a reporting unit exceeds its carrying value, then the reporting unit’s fair value is compared to its carrying value. We performed a quantitative assessment of the Company using a market approach whereby the market capitalization of the Company was compared to its carrying value. The market capitalization was derived from the Company's publicly traded stock price.
Indefinite-Lived Intangible Assets
We assess our trade name indefinite-lived intangible asset at least annually as of October 1 for impairment, or more frequently if certain events occur or circumstances change that would more likely than not reduce the fair value of an indefinite-lived intangible asset below its carrying value. The Charah Solutions trade name fair value is based upon the income approach, primarily utilizing the relief from royalty methodology. This methodology assumes that a third party would be willing to pay a royalty to obtain the rights to use the comparable asset in place of ownership. An impairment loss is recognized when the intangible asset's estimated fair value is less than the carrying value. Fair value calculation requires significant judgments in determining both the assets’ estimated cash flows and the appropriate discount and royalty rates applied to those cash flows to determine fair value. Variations in economic conditions or a change in general consumer demands, operating results estimates or the application of alternative assumptions could produce significantly different results.
During the year ended December 31, 2021, we performed a quantitative assessment of our trade name indefinite-lived intangible asset and determined there was no impairment. For the period between the impairment testing date and year-end, there were no indicators of impairment. If actual future results are not consistent with our assumptions and estimates, we may be required to record impairment charges in the future. During the year ended December 31, 2020, we recorded an impairment of our Charah Solutions trade name intangible asset of $21.0 million. As part of the October 1, 2020 annual impairment test, we identified a decrease in the royalty rate used in the valuation primarily attributable to the Company's recent performance.
Some of the inherent estimates and assumptions used in determining the fair value of the indefinite-lived intangible asset are outside management control, including interest rates, cost of capital, tax rates and credit ratings. As for the indefinite-lived intangible asset, the most significant assumptions used are the revenue growth rate, the royalty rate, and the discount rate. A decrease in the revenue growth rate, a decrease in the royalty rate, or an increase in the discount rate could result in a future impairment. We will continue to monitor our Charah Solutions trade name for any triggering events or other signs of impairment. We may be required to perform additional impairment testing based on changes in the economic environment, disruptions to our business, significant declines in our operating results and other factors that could result in impairment charges in the future. Although management cannot predict when improvements in macroeconomic conditions will occur, if contract awards decline significantly in the future or if operational activity deteriorates significantly from current levels, it is reasonably likely the Company will be required to record impairment charges in the future.
Deferred Taxes, Valuation Allowance
As discussed in Note 21, Income Taxes, to our consolidated financial statements, deferred tax assets and liabilities are recognized for the expected future tax consequences of events that have been recognized in our consolidated financial statements or tax returns. We record a valuation allowance to reduce certain deferred tax assets to amounts that are more-likely-than-not to be realized. We evaluate the realizability of our deferred tax assets by assessing the valuation allowance and adjusting the amount of such allowance, if necessary. The factors used to assess the likelihood of realization include our forecast of future taxable income exclusive of reversing temporary differences and carryforwards, future reversals of existing
taxable temporary differences and available tax planning strategies that could be implemented to realize the net deferred tax assets.
Based on the available evidence as of December 31, 2021 and 2020, we could not conclude it is more likely than not certain deferred tax assets will be realized. Therefore, a valuation allowance of $19.9 million and $17.2 million, respectively, was recorded against our deferred tax assets. We will continue to evaluate the need for a valuation allowance on our deferred tax assets in future periods.
Asset Retirement Obligations
The Company has land and structural fill assets with corresponding obligations to restore such assets at the end of their operation. Estimating the future closure and post-closure costs is difficult and requires management to make estimates and judgments because these obligations are over many years in the future. Asset retirement obligations (“ARO”) associated with retiring long-lived assets are recognized as a liability in the period in which a legal obligation is incurred and becomes determinable. The ARO liability reflects the estimated present value of the closure and post-closure activities associated with the Company’s land and structural fill assets. The Company utilizes current retirement costs to estimate the expected cash outflows for retirement obligations.
Inherent in the present value calculation are numerous assumptions and judgments, including the ultimate settlement amounts, inflation factors, credit-adjusted discount rates, timing of settlement, and changes in the legal, regulatory, environmental and political environments. To the extent future revisions to these assumptions impact the present value of the existing ARO liability, a corresponding adjustment is made to the land and/or structural fill balance. Accretion expense is recognized over time as the discounted liability is accreted to its expected settlement value. Gains and losses on ARO settlement are recognized as specific remediation tasks are performed. These gains and losses are determined based on the differences between the estimated costs used in the measurement of the fair value of the Company's AROs and the actual costs incurred for specific remediation tasks recognized on a proportionate basis.
Recent Accounting Pronouncements
Please see Note 2, “Summary of Significant Accounting Policies-Recently Adopted Accounting Pronouncements” and “Summary of Significant Accounting Policies-Recently Issued Accounting Pronouncements” to our historical consolidated financial statements as of and for the years ended December 31, 2021 and 2020, included elsewhere herein, for a discussion of recent accounting pronouncements.
Under the JOBS Act, we meet the definition of an “emerging growth company,” which allows us to have an extended transition period for complying with new or revised accounting standards under Section 107(b) of the JOBS Act. We intend to take advantage of all of the reduced reporting requirements and exemptions, including the longer phase-in periods for adopting new or revised financial accounting standards under Section 107(b) of the JOBS Act until we are no longer an emerging growth company.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Item 7A. Quantitative and Qualitative Disclosure About Market Risks
Market risk is the risk of loss arising from adverse changes in market rates and prices. Currently, our market risks relate to potential changes in the fair value of our long-term debt due to fluctuations in applicable market interest rates. We expect that in the future, our market risk exposure generally will be limited to those risks that arise in the normal course of business, as we do not engage in speculative, non-operating transactions, nor do we utilize financial instruments or derivative instruments for trading purposes.
Interest Rate Risk
Our cash consists of cash in readily available checking accounts. Outstanding borrowing under our Credit Agreement bear interest at a variable rate; however, there were no outstanding borrowing on our Credit Agreement as of December 31, 2021. As a result, the fair value of our long-term debt is relatively insensitive to interest rate changes.
Credit Risk
While we are exposed to credit risk in the event of non-performance by counter parties, the majority of our customers are investment-grade companies, and we do not anticipate non-performance. We mitigate the associated credit risk by performing credit evaluations and monitoring the payment patterns of our customers.
Off-Balance Sheet Arrangements
We currently have no material off-balance sheet arrangements except for operating leases as referenced in “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations-Liquidity and Capital Resources.”

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Item 8. Financial Statements and Supplementary Data
Our consolidated financial statements and the related notes begin on page herein.

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure
None.

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ITEM 9A. CONTROLS AND PROCEDURES
Item 9A. Controls and Procedures
Evaluation of Disclosure Controls and Procedures
The Company maintains disclosure controls and procedures (as defined in Rule 13a-15(e) or Rule 15d-15(e) under the Exchange Act) that are designed to ensure that information required to be disclosed in the Company’s reports under the Exchange Act is processed, recorded, summarized, and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to management, including the Chief Executive Officer and Chief Financial Officer, as appropriate, to allow for timely decisions regarding required disclosure.
As required by SEC Rule 13a-15(b), the Company carried out an evaluation, under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the disclosure controls and procedures. Based on the foregoing, the Company’s Chief Executive Officer and Chief Financial Officer concluded, as of that time, the disclosure controls and procedures were not effective due to the material weakness in internal control over financial reporting described below.
Notwithstanding the identified material weakness, management, including our Chief Executive Officer and Chief Financial Officer, believes the consolidated financial statements included in this Annual Report fairly represent, in all material respects, our financial condition, results of operations and cash flows as of and for the periods presented in accordance with U.S. Generally Accepted Accounting Principles.
Management’s Annual Report on Internal Control Over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act). The Company’s internal control over financial reporting is a process designed under the supervision of its Chief Executive Officer (Principal Executive Officer) and Chief Financial Officer and Treasurer (Principal Financial Officer) and effected by the Company’s Board of Directors, management and other personnel, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of its financial statements for external reporting purposes in accordance with GAAP.
The Company’s internal control over financial reporting includes policies and procedures that pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect transactions and dispositions of the Company’s assets; provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with GAAP, and that receipts and expenditures of the Company are being made only following authorizations of management and the directors; and provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Company’s assets that could have a material effect on its financial statements.
Management evaluated the effectiveness of the Company’s internal control over financial reporting as of December 31, 2021 based on the framework established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation, management, with the participation of the Chief Executive Officer and Chief Financial Officer, concluded that, as of December 31, 2021, the Company’s internal control over financial reporting was not effective due to the material weakness described below.
This annual report does not include an attestation report of the Company’s registered public accounting firm due to an exemption for emerging growth companies under the JOBS Act.
Material Weakness in Internal Control over Financial Reporting
Management identified a material weakness in our internal control over financial reporting in connection with our assessment as of and for the year ended December 31, 2021. A material weakness is a deficiency, or combination of deficiencies, in internal control over financial reporting such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis.
We identified the following control deficiencies which aggregate to a material weakness: (i) lack of a sufficient number of trained resources with assigned responsibilities and accountability for the design and operation of internal controls over financial reporting; (ii) lack of formal and effective controls over certain financial statement account balances; (iii) lack of user profiles to ensure adequate restriction of users to perform only transactions that are consistent with their function; and (iv)
lack of appropriate segregation of duties within the accounting and finance functions, including order to cash, process to pay and payroll business processes.
Management's Remediation Plan
We have identified and implemented, and continue to implement, certain remediation efforts to improve the effectiveness of our internal control over financial reporting and disclosure controls and procedures. These remediation efforts are ongoing. The following remedial actions have been identified and initiated as of December 31, 2021:
▪We have hired an external consultant to assist us in an evaluation of design and implementation of certain internal controls to address the identified deficiencies.
▪We are in the process of hiring additional accounting resources with appropriate levels of experience and reallocating responsibilities across the finance organization. This measure will provide for appropriate segregation of duties and will ensure that the appropriate level of knowledge and experience will be applied based on the risk and complexity of transactions and tasks under review.
▪We are revising user profiles within our accounting systems to ensure appropriate segregation of duties are in place.
In designing and evaluating the disclosure controls and procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives, and management is required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. In addition, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions or that the degree of compliance with the policies or procedures may deteriorate. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. As we continue to evaluate and take actions to improve our internal control over financial reporting, we will further refine our remediation plan and take additional actions to address control deficiencies or modify certain of the remediation measures described above.
While progress has been made to enhance our internal control over financial reporting, we are still in the process of designing, implementing, documenting, and testing the effectiveness of these processes, procedures and controls. Additional time is required to complete the implementation and to assess and ensure the sustainability of these procedures. We will continue to devote time and attention to these remedial efforts. However, the material weakness cannot be considered remediated until the applicable remedial controls are fully implemented, have operated for a sufficient period of time and management has concluded that these controls are operating effectively through testing.
Changes in Internal Control Over Financial Reporting
Aside from the identification of the material weakness described above and the actions taken as described in Management's Remediation Plan above to improve the Company’s internal control over financial reporting, there were no changes in our internal control over financial reporting identified in connection with the evaluation required by Rules 13a-15(d) and 15d-15(d) of the Exchange Act that occurred during the quarter ended December 31, 2021 that have materially affected or are reasonably likely to materially affect, our internal control over financial reporting.

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ITEM 9B. OTHER INFORMATION
Item 9B. Other Information
None.

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Item 10. Directors, Executive Officers and Corporate Governance
Charah Solutions will file with the SEC a definitive proxy statement for its 2022 Annual Meeting of Stockholders (the “Proxy Statement”) no later than 120 days after the close of its fiscal year ended December 31, 2021. The information required by this item for our executive officers appears in Part I of this Annual Report under the heading “Information About Our Executive Officers.” The other information required by this item is furnished by incorporation by reference to the information under the headings “Election of Directors,” “Corporate Governance,” and “Delinquent Section 16(a) Reports” in the Proxy Statement.
We have adopted a Financial Code of Ethics (the “Code of Ethics”), which is intended to qualify as a “code of ethics” within the meaning of Item 406 of Regulation S-K of the Exchange Act. The Code of Ethics applies to our principal executive officer, principal financial officer, principal accounting officer or controller, and persons performing similar functions. The Code of Ethics is available on our website at www.charah.com.
We will disclose information about any amendment to, or waiver from, the provisions of the Code of Ethics that apply to our principal executive officer, principal financial officer, principal accounting officer or controller, or persons performing similar functions and that relate to any element of the Code of Ethics enumerated in the SEC rules and regulations by posting this information on our website, www.charah.com. The information contained on our website or available by hyperlink from our website is not a part of this Annual Report and is not incorporated into this Annual Report or any other documents we file with or furnish to, the SEC.

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ITEM 11. EXECUTIVE COMPENSATION
Item 11. Executive Compensation
The information required by this item is furnished by incorporation by reference to the information under the headings “Director Compensation,” “Executive Compensation,” “Compensation Committee Interlocks and Insider Participation,” and “Compensation Committee Report” in the Proxy Statement.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
The information required by this item is furnished by incorporation by reference to the information under the headings “Security Ownership of Certain Beneficial Owners and Management” and “Equity Compensation Plan Information” in the Proxy Statement.

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Item 13. Certain Relationships and Related Transactions, and Director Independence
The information required by this item is furnished by incorporation by reference to the information under the headings “Corporate Governance-Director Independence,” “Corporate Governance-Policy for Review of Related Party Transactions,” and “Corporate Governance-Related Party Transactions” in the Proxy Statement.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Item 14. Principal Accountant Fees and Services
The information required by this item is furnished by incorporation by reference to the information under the heading “Ratification of the Appointment of Independent Registered Public Accounting Firm” in the Proxy Statement.
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
Item 15. Exhibits and Financial Statement Schedules
1. Financial Statements
Description Page Number
Report of Independent Registered Public Accounting Firm PCAOB ID No. 34
Consolidated Balance Sheets as of December 31, 2021 and December 31, 2020
Consolidated Statements of Operations for the years ended December 31, 2021, 2020 and, 2019
Consolidated Statements of Stockholders’ Equity for the years ended December 31, 2021, 2020 and 2019
Consolidated Statements of Cash Flows for the years ended December 31, 2021, 2020 and 2019
Notes to Consolidated Financial Statements
2. Financial Statement Schedules
Schedule II-Schedule of Valuation and Qualifying Accounts
3. Listing of Exhibits
INDEX TO EXHIBITS
Exhibit
Number Description
2.1††
Master Reorganization Agreement, dated June 13, 2018, by and among Charah Solutions, Inc. and the other parties named therein (incorporated by reference to Exhibit 2.1 to the Current Report on Form 8-K filed on June 19, 2018 (File No. 001-38523)).
2.2††
Unit Purchase Agreement dated November 19, 2020, by and among Allied Group Intermediate Holdings LLC, Charah Solutions, Inc, Allied Power Holdings, LLC and the other parties named therein (incorporated by reference to Exhibit 2.1 to the Current Report on Form 8-K filed on November 20, 2020 (File No. 001-38523)).
3.1
Amended and Restated Certificate of Incorporation of Charah Solutions, Inc. (incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K filed June 22, 2018 (File No. 001-38523)).
3.2
Certificate of Designation of Series A Preferred Stock, dated March 16, 2020 (incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K filed on March 18, 2020 (File No. 001-38523)).
3.3
Amended and Restated Bylaws of Charah Solutions, Inc. (incorporated by reference to Exhibit 3.2 to the Current Report on Form 8-K filed June 22, 2018 (File No. 001-38523)).
4.1*
Description of Common Stock of Charah Solutions, Inc. (incorporated by reference to Exhibit 4.1 to the Annual Report on Form 10-K for the year ended December 31, 2019, filed March 27, 2020 (File No. 001-38523)).
4.2
Registration Rights Agreement (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K filed June 22, 2018 (File No. 001-38523)).
4.3
Amendment No.1 to Registration Rights Agreement (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K filed on March 18, 2020 (File No. 001-38523))
4.4
Stockholders’ Agreement (incorporated by reference to Exhibit 4.2 to the Current Report on Form 8-K filed June 22, 2018 (File No. 001-38523)).
4.5
Waiver of Rights Under Stockholders' Agreement (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K filed July 15, 2020 (File No. 001-38523)).
4.6
Investor Rights Agreement, dated as of August 6, 2021, by and among Charah Solutions, Inc., B. Riley Securities, Inc. and B. Riley Financial, Inc. (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K filed on August 9, 2021 (File No. 001-38523)).
Exhibit
Number Description
4.7
Indenture dated as of August 25, 2021, between Charah Solutions, Inc. and Wilmington Savings Fund Society, FSB, as trustee (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K filed on August 26, 2021 (File No. 001-38523)).
4.8
First Supplemental Indenture dated as of August 25, 2021, between Charah Solutions, Inc. and Wilmington Savings Fund Society, FSB, as trustee (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K filed on August 26, 2021 (File No. 001-38523)).
4.8.1
Form of 8.50% Senior Note due 2026 (included as Exhibit A to 4.7 above).
10.1
Series A Preferred Stock Purchase Agreement between Charah Solutions, Inc. and Charah Preferred Stock Aggregator, LP, as purchaser, dated March 5, 2020 (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed March 6, 2020 (File No. 001-38523)).
10.2
Information Rights Agreement, dated October 9, 2018, by and between Charah Solutions, Inc. and Bernhard Capital Partners Management, LP (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed October 10, 2018 (File No. 001-38523)).
10.3
Mutual Release Agreement, effective as of December 13, 2018, by and between Charah Solutions, Inc. and Bernhard Capital Partners Management, LP (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed December 18, 2018 (File No.001-38523)).
10.4†
Form of Restricted Stock Agreement under the Charah Solutions, Inc. 2018 Omnibus Incentive Plan (Time Based) (incorporated by reference to Exhibit 4.5 to the Registration Statement on Form S-8 filed June 19, 2018 (File No. 333-225717)).
10.5†
Form of Restricted Stock Agreement under the Charah Solutions, Inc. 2018 Omnibus Incentive Plan (Time and Performance Based) (incorporated by reference to Exhibit 4.6 to the Registration Statement on Form S-8 filed June 19, 2018 (File No. 333-225717)).
10.6†
Form of Restricted Stock Unit Agreement under the Charah Solutions, Inc. 2018 Omnibus Plan (incorporated by reference to Exhibit 10.12 to the Annual Report on Form 10-K for the year ended December 31, 2018 (File No. 001-38523)).
10.7†
Form of Performance Share Unit Grant Notice (Form for grantee with employment agreement) (incorporated by reference to Exhibit 10.1 to the Quarterly Report on Form 10-Q for the quarter ended June 30, 2019 (File No. 001-38523)).
10.8†
Form of Performance Share Unit Grant Notice (Form for grantee without employment agreement) (incorporated by reference to Exhibit 10.2 to the Quarterly Report on Form 10-Q for the quarter ended June 30, 2019 (File No. 001-38523)).
10.9†
Form of Restricted Stock Unit Grant Notice (Form for grantee with employment agreement) (incorporated by reference to Exhibit 10.3 to the Quarterly Report on Form 10-Q for the quarter ended June 30, 2019 (File No. 001-38523)).
10.10†
Form of Restricted Stock Unit Grant Notice (Form for grantee without employment agreement) (incorporated by reference to Exhibit 10.4 to the Quarterly Report on Form 10-Q for the quarter ended June 30, 2019 (File No. 001-38523)).
10.11†
Letter Agreement between Charah Solutions, Inc. and Scott Sewell, dated January 23, 2019 (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed January 24, 2019 (File No.001-38523)).
10.12†
Amended and Restated Employment Agreement between Charah, LLC, Charah Solutions, Inc. and Scott A. Sewell, dated June 10, 2019 (incorporated by reference to Exhibit 10.2 to the Current Report on Form 8-K, filed June 14, 2019 (File No. 001-38523)).
10.13†
Amended and Restated Employment Agreement with Dorsey “Ron” McCall, dated July 12, 2017 (incorporated by reference to Exhibit 10.10 to the Registration Statement on Form S-1 filed May 18, 2018 (File No. 333-225051)).
10.14†
First Amendment to Employment Agreement with Dorsey "Ron" McCall, dated June 5, 2018 (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed June 19, 2018 (File No. 001-38523)).
10.15†
Employment Agreement between Charah, LLC, Charah Solutions, Inc. and Roger D. Shannon, dated June 17, 2019 (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K, filed June 14, 2019 (File No. 001-38523)).
10.16†
Form of Indemnification Agreement (incorporated by reference to Exhibit 10.2 to the Registration Statement on Form S-1 filed May 18, 2018 (File No. 333-225051)).
10.17
Confidential Settlement Agreement and Release, dated August 30, 2019, by and between Duke Energy Business Services LLC, as agent for and on behalf of Duke Energy Carolinas, LLC and Duke Energy Progress, LLC, and Charah, LLC (incorporated by reference to the Company’s Current Report on Form 8-K filed on August 30, 2019 (File No. 001-38523)).
Exhibit
Number Description
10.18†
Form of Performance Share Unit Grant Notice (form for grantee with employment agreement) 2018 Omnibus Incentive Plan. (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on April 29, 2021 (File No. 001-38523)).
10.19
Charah Solutions, Inc. 2018 Omnibus Incentive Plan, as amended by First Amendment approved by stockholders June 9, 2021 (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed June 16, 2021 (File No. 001-38523)).
10.20
Credit Agreement dated as of November 9, 2021 among (i) Charah Solutions, Inc., Charah, LLC, SCB International Holdings, LLC, (ii) The Lenders Party thereto and JPMorgan Chase Bank, N.A., as Administrative Agent (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on November 10, 2021 (File No. 001-38523)).
10.21
Promissory Note, dated as of August 25, 2021, between Charah, LLC and B. Riley Commercial Capital, LLC (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on August 26, 2021 (File No. 001-38523)).
21.1*
List of Subsidiaries of Charah Solutions, Inc.
23.1*
Consent of Deloitte & Touche LLP, Independent Registered Public Accounting Firm.
31.1*
Certification of Principal Executive Officer pursuant to Rule 13a-14(a)/15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*
Certification of Principal Financial Officer pursuant to Rule 13a-14(a)/15d-14(a) as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1**
Certification of Principal Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2**
Certification of Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.CAL* Inline XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF* Inline XBRL Taxonomy Extension Definition Linkbase Document.
101.INS* Inline XBRL Instance Document.
101.LAB* Inline XBRL Taxonomy Extension Labels Linkbase Document.
101.PRE* Inline XBRL Taxonomy Extension Presentation Linkbase Document.
101.SCH* Inline XBRL Taxonomy Extension Schema Document
104* Cover page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
* Filed herewith.
** Furnished herewith.
† Indicates a management contract or compensatory plan or arrangement.
†† Schedules and similar attachments have been omitted pursuant to Item 601(a)(5) of Regulation S-K. The registrant will furnish a supplemental copy of any omitted schedule or similar attachment to the SEC upon request.