United States
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
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x | ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
☒ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 20192021
or
☐TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
Commission File Number: 001-37822
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¨ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
Commission File Number: 001-37822
Advanced Emissions Solutions, Inc.
(Name of registrant as specified in its charter)
| | 27-5472457 | | | | | | |
| Delaware | | 27-5472457 |
| (State of incorporation) | | (IRS Employer
Identification No.)
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640 Plaza Drive,8051 E. Maplewood Ave, Suite 270, Highlands Ranch,210, Greenwood Village, CO, 8012980111
(Address of principal executive offices) (Zip Code)
(Registrant’s telephone number, including area code): (720)(720) 598-3500
Securities registered under Section 12(b) of the Act:
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| Class | | Trading Symbol | | Name of each exchange on which registered |
| Common stock, par value $0.001 per share | | ADES | | NASDAQNasdaq Global Market |
Securities registered under Section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. ¨ Yes x No
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Act. ¨ Yes x No
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. x Yes ¨ No
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). x Yes ¨ No
Indicate by check mark if disclosure of delinquent filers in response to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See definition of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act.
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| Large accelerated filer | ¨ | Accelerated filer | x¨ |
| Non-accelerated filer | ¨x | Smaller Reporting Company | x☒ |
| | Emerging growth company | ¨☐ |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act.) ¨☐ Yes x No
The aggregate market value of the voting stock held by non-affiliates of the registrant was approximately $182.9$122.6 million based on the last reported bid price of the Common Stock on the NASDAQNasdaq Global Market on June 30, 2019.2021. The number of shares outstanding of the registrant’s Common Stock, par value $0.001 per share, as of March 6, 2020February 25, 2022 was 18,341,113.18,841,000.
Documents Incorporated By Reference
Portions of Part III of this Form 10-K are incorporated by reference from the Registrant's definitive proxy statement to be filed with the Securities and Exchange Commission no later than 120 days after the end of the Registrant's fiscal year.
ADVANCED EMISSIONS SOLUTIONS, INC.
ANNUAL REPORT ON FORM 10-K
FOR THE FISCAL YEAR ENDED DECEMBER 31, 20192021
TABLE OF CONTENTS
PART I
Item 1. Business
General
ADA-ES, Inc. (“ADA”("ADA"), a Colorado corporation, was incorporated in 1997. Pursuant to an Agreement and Plan of Merger, effective July 1, 2013, Advanced Emissions Solutions, Inc. (“ADES”("ADES"), a Delaware company incorporated in 2011, succeeded ADA as the publicly-held corporation and ADA became a wholly-owned subsidiary of ADES. In 2018, we acquired ADA Carbon Solutions, LLC ("Carbon Solutions") as a means to enter into the broader activated carbon ("AC") market and to expand our product offerings in the mercury control industry and other applicable activated carbon markets. This Annual Report on Form 10-K is referred to as the "Form 10-K" or the "Report." As used in this Report, the terms the "Company," "we," "us" and "our" means ADES and its consolidated subsidiaries.
We provide environmental solutionssell consumable products that utilize AC and chemical-based technologies to a broad range of customers, inincluding coal-fired power generation, municipalutilities, industrials, water treatment plants and other industries primarily through air and water purification control technologies of our subsidiaries and joint ventures.diverse markets. Our proprietary technologies and associated product offerings provide multi-pollutant control and purification solutions to enable coal-fired power generators, municipal waterour customers to reduce certain contaminants and industrialspollutants to meet compliance requirements for applicablethe challenges of existing and potential future regulations.
As of December 31, 20192021 and 2018,2020, we held equity interests of 42.5% and 50.0% in Tinuum Group, LLC ("Tinuum Group") and Tinuum Services, LLC ("Tinuum Services"), respectively, which are both unconsolidated entities, and each of their operationshistorically have both contributed significantly impactedto our financial position and results of operations for the years ended December 31, 2019 and 2018.operations. We account for Tinuum Group and Tinuum Services under the equity method of accounting.
We operate two segments: Refined Coal (“RC”) and Power Generation and Industrials (“PGI”). The segments are discussed in more detail later under this Item 1. Our products are primarily used for the removal of mercury and other air pollutants at coal-fired power plants and other industrial companies. Our products are also used for the purification of water and our operating results from water products are included in All Other and Corporate for segment reporting purposes.
Carbon Solutions Acquisition
On December 7, 2018 (the "Acquisition Date"), the Company purchased 100% As a result of the membership interestsexpiration of ADA Carbon Solutions, LLCInternal Revenue Code ("Carbon Solutions"IRC") for a total purchase priceSection 45 - Production Tax Credit ("Section 45") refined coal tax credit program effective December 31, 2021, both Tinuum Group and Tinuum Services have substantially ceased operations as of $75.0 million (the "Carbon Solutions Acquisition") plus transaction fees of $4.5 million. The fair value of the purchase consideration was $66.5 millionDecember 31, 2021, and consisted of cash consideration of $65.8 million and an additional purchase adjustment amount payable to Carbon Solutions' secured lender of $0.7 million. The Company acquired Carbon Solutions to enter into the broader activated carbon market and to expand the Company's product offeringsTinuum Group is in the mercury control industry and other complementary activated carbon markets. Carbon Solutions owns and operates an activated carbon manufacturing and processing facility and owns an associated lignite mine (“Five Forks Mine”), which supplies the primary raw material for the activated carbon plant.
The Company primarily funded the cash consideration in the Carbon Solutions Acquisition from a $70.0 million senior term loan facility, less original issue discountprocess of $2.1 million (the "Senior Term Loan"), which iscompleting reclamation activities. See further discusseddiscussion below in Item 7under "Segments - Management's Discussion and AnalysisRC" of Financial Condition and Results of Operations ("Item 7").this item.
Markets
Activated carbon ("AC")AC is a specialized sorbent material that is used widely in a host of industrial and consumer applications to remove impurities, contaminants orand pollutants from gas, water and other product or waste streams. ACs areAC is produced by activating carbonaceous raw materials, including wood, coal, nut shells, resins and petroleum pitch. Properties such as surface area, pore volume, surface chemical functionalities and particle size can be specifically engineered to selectively target various contaminants to meet end-use application requirements. AC can come in several different forms that are important for the end-use application, including powdered activated carbon ("PAC"), granular activated carbon ("GAC"), pellets, honeycombs, blocks or cloths, which can be important for the end-use application.cloths.
Key markets include removal of heavy metal pollutants from coal-fired electrical generation and other industrial processes, treatment of drinking and waste waters, industrial acid gas and odor removal, automotive gasoline emission control, soil and ground water remediation and food and beverage process and product purifications.purification.
TheDemand for AC marketproducts has been, and is expected to continue to be, driven by increasing environmental regulations principallypertaining to water and air purification, especially in the maturedeveloped and more industrialized areas of the world. Additionally, we believe environmental issues will continue to be the predominant forcedrive demand for AC in the AC markets of rapidly developing countries.
Power GenerationWe see opportunities and Industrials
Currently, in the PGI segment, approximately 90%are continuing to pursue diverse markets for our purification products outside of our revenue is generated from coal-fired power. According to the most recent data from the U.S. Energy Information Administration ("EIA"), coal-fired power generation, was down year-over-year by approximately 15% even thoughincluding industrial applications, water treatment plants and other end markets. In addition, we see significant opportunities emerging in the soil, sediment and groundwater treatment markets. Increased environmental attention has been drawn to the monitoring and treatment of heavy metals, organic and inorganic compounds in groundwater to improve overall power generation was flat. Consistent with 2018, 2019 U.S.drinking water quality across North America. Activated carbon, in various forms, has and will continue to play a key role in these remediation efforts.
Segments
Advanced Purification Technologies
In our Advanced Purification Technologies ("APT") segment, our AC and chemical products are used to purify contaminated liquid and gas streams from a variety of industrial sources including coal-fired power generation has been significantly affected by pricesplants and waste-water treatment plants, among others. Most of competingthe North American coal-fired power generation sourcesgenerators installed equipment to control air pollutants, such as natural gas andmercury, prior to or since the accelerationinception of new renewable energy available to the electricity grid. Low natural gas prices make gas generation a competitive alternative to coal-fired power generation and therefore, coal consumption has been reduced, which in turn has reduced the demand for our products in both the RC and PGI segments. Both lower prices of competing power generation sources and lower electricity demand in the U.S. may continue to negatively impact our revenues, sales volumes, earnings and cash flows in the near term as well as in future years. However, we believe that coal-fired power generation will remain a significant component of the U.S. power generation mix for many years, given coal's abundance, affordability, reliability and availability as a domestic fuel source.
The primary drivers for many of our products and services are environmental laws and regulations impacting the electric power generation industry and other coal users. These regulations include the Mercury and Air Toxics Standards ("MATS"),. However, many power generators need consumable products to complement the operation of installed equipment on a U.S. federal regulation requiring all existingrecurring basis to chemically and any new coal-fired electricity generating unitsphysically capture mercury and other contaminants. AC has been adopted as the most widely-used technology to capture mercury due to product efficiency and effectiveness and currently accounts for the majority of the mercury control mercury emissions, acid gases,consumables in the North American market. We offer AC and particulate matter, as well as various state regulations and permitting requirements for coal-fired electricity generating units. In addition to the federal MATS rule, many states have implemented their own mercury rules that are similar to, or in many cases more stringent than, MATS, and many coal-fired electricity generating units around the country have agreed to consent decrees, which require pollution controls that, in some cases, are more restrictive than the existing regulations. We continue to believe the MATS regulation as well as certain state regulations creates a market for our RC and PGI products. An additional regulation impacting ourother chemical products and services iswork with customers as they develop and implement a compliance control strategy that utilizes the Industrial Boiler Maximum Achievable Control Technology ("MACT") rule that established air toxin standards for industrial boilers, including mercury, particulate matter, and acid gas emission limits.
While the long-term future for coal as a fuel source for electricity generation is uncertain, and as coal assets continue to age, we expect a continued purchasing trend towards variable cost products and integrated solutions with low capital expenditure requirements and a move away from large capital equipment and other fixed costconsumables solutions that are less likely to have costs recovered.fit with their unique operating and pollution control configuration.
We believe it is likely that many U.S. coal mines, coal-fired electricity generating units, coal-centric large equipment providers and other coal-related businesses will have difficulty adapting to industry changes expected inFor the coming years. However, we see opportunities for companies that can offer their customers creative and cost-effective solutions that help U.S. coal-related businesses meet regulatory compliance, improve efficiency, lower costs and maintain reliability.
Water
purification of water, AC has been used in the treatment of drinking water, wastewater, contaminated soil and groundwater to absorbadsorb compounds causing unpleasant taste and odor and other contaminants. Both industrial and municipal wastewater treatment plants have deployed the use of AC in their treatment processes.
Groundwater contamination has become a matter of increasing concern to federal and state governments as well as to the public, especially in the last 10over recent years. The U.S. AC market may see significant growth from water purification markets, especially if future regulations are passed controlling certain chemicals in drinking water. At present, individual states are primarily responsible for the protection of groundwater. Worldwide, waterThe existing technologies for treatment, accounts for 41%including removal of the total consumptionsoil for external treatment or landfill, pumping the groundwater above surface for treatment and/or installing treatment trenches or barriers, are expensive and may have complicated life-cycle management requirements. An emerging technology generating increasing interest by site engineering firms and owners is injecting highly engineered ACs into the subsoil, also described as "in situ" treatment, to intercept the contamination plume or to treat the groundwater. In response to this market opportunity, in late 2021, we developed a new Colloidal Carbon Product ("CCP") platform, FluxSorb ISTM, that is currently in the process of ACor planning stages of in-field testing at multiple contaminated soil and continuesgroundwater remediation treatment sites.
Coal-fired power plants continue to be a significant, though declining, source of electricity in the largest global market segmentUnited States. Demand for AC.
our AC products related to coal-fired electricity generation is dependent on the availability and cost of alternative energy sources, such as natural gas, solar and wind energy. We see opportunities in the water marketto continue pursuing diverse markets for our purification products that will provide cost-effective solutions to help industrial and municipal wastewater treatment plants meet water purification standards.
Segments
Refined Coal
Tinuum Group, an unconsolidated entity, provides reduction of mercury and nitrogen oxide ("NOX") emissions at select coal-fired power generators through the production and sale of RC that qualifies for tax credits under the Internal Revenue Code ("IRC") Section 45 - Production Tax Credit ("Section 45 tax credits"). We benefit from Tinuum Group's production and sale of RC, which historically has generated substantial tax credits to us, as well as our equity earnings earned from Tinuum Group's sales or leases of RC facilities to tax equity investors. See the separately filed financial statements of Tinuum Group included in Item 15 - "Exhibits, Financial Statement Schedules" ("Item 15") of this Report.
Products
Our patented CyCleanTM technology, a pre-combustion coal treatment process provides electric power generators the ability to enhance combustion and reduce emissions of nitrogen oxides ("NOX") and mercury from coals burned in cyclone boilers.
Our patented M-45TM and M-45-PCTM technologies (collectively, the "M-45 Technology") are proprietary pre-combustion coal treatment technologies used to control emissions from circulating fluidized bed boilers and pulverized coal boilers, respectively.
Sales and Customers
Our RC segment derives its revenues from license royalties earned from Tinuum Group on the M-45 Technology ("M-45 Royalties") and other revenues related to reduced emissions of both NOX and mercury from coal are treated with our proprietary chemicals and burned at coal-fired electricity generating units. For the year ended December 31, 2019, M-45 Royalties comprised 24% of our total consolidated revenues. We also derive substantial earnings from our equity method investments in the RC segment, which include Tinuum Group, Tinuum Services and GWN Manager, LLC. RC segment earnings are primarily provided by equity earnings from Tinuum Group and Tinuum Services. The loss of equity earnings and M-45 Royalties will have a material adverse effect on our financial condition and consolidated operating results. Additional information related to major customers is disclosed in Note 16 of the Consolidated Financial Statements included in Item 8 of this Report.
Coal-fired electricity generating units use RC as one of a portfolio of tools to help comply with MATS and other environmental regulations. These RC facilities produce and sell RC that qualifies for Section 45 tax credits, including meeting the "placed in service" requirements (referred to as "placed in service"). The IRS has issued guidance regarding emissions reductions in the production of electricity by coal-fired electric generating units, including measurement and certification criteria necessary to qualify for the Section 45 tax credits. The ability to produce and sell RC, which generates Section 45 tax credits, expires 10 years after each RC facility was placed in service, but not later than December 31, 2021. Two of Tinuum Group's RC facilities were placed in service in 2009 and related Section 45 tax credits for these facilities expired in December 2019. As of December 31, 2019, Tinuum Group had built and placed into service a total of 26 RC facilities designed to produce RC for sale to coal-fired electricity generating units that were still eligible to produce RC qualifying for Section 45 tax credits. The ability to generate Section 45 tax credits related to the remaining 26 RC facilities expires in 2021.
Once an RC facility is in operation, Tinuum Group may lease or sell it to a tax equity investor, which we refer to as an "invested" RC facility. The tax equity investor subsequently operates the RC facility to produce and sell RC to a utility. It is financially advantageous for Tinuum Group to lease or sell an RC facility as the tax equity investor assumes the operating expenses for the RC facility and remits to Tinuum Group either payments to purchase or lease payments to lease the RC facility. We benefit from equity income and cash distributions through our investment in Tinuum Group. Tax equity investors may benefit from their investment in RC facilities through the realization of tax assets and credits from the production and sale of RC.
RC facilities that are producing and selling RC and have not been leased or sold, are referred to as "retained" RC facilities, whereby the RC is produced and sold by Tinuum Group and, as an owner in Tinuum Group, we benefit from the related Section 45 tax benefits. As of December 31, 2019 and 2018, respectively, the Section 45 tax credits were $7.173 and $7.031 per ton of RC produced and sold to a utility. The value of the Section 45 tax credits is adjusted annually based on inflation adjustment factors published in the Federal Register. As of December 31, 2019, we have earned, but have not been able to fully utilize, substantial tax credits and benefits from certain retained RC facilities that previously produced and sold RC for the benefit of Tinuum Group. See Note 14 to our Consolidated Financial Statements included in Item 8 - "Financial Statements and Supplementary Data" ("Item 8") of this Report for additional information regarding our net operating losses, tax credits and other deferred tax assets.
As of December 31, 2019, Tinuum Group had 20 invested RC facilities producing RC at utility sites. The remaining 6 RC facilities, although placed in service, were either installed but not operating, awaiting site selection or in various other stages of contract negotiation or permanent installation. As of December 31, 2019, Tinuum Group had eight facilities that are leased to affiliates of The Goldman Sachs Group (the "GS Affiliates"), and one of these GS Affiliates is also an owner of Tinuum Group. A majority of Tinuum Group's leases are periodically renewed and the loss of these customers or material modification to the lease terms of these facilities by these customers would have a significant adverse impact on Tinuum Group's financial position, results of operations and cash flows, which in turn would have material adverse impact on our financial position, results of operations and cash flows.
During the third quarter of 2019, Tinuum Group restructured contracted RC facility leases with the GS Affiliates, which resulted in a decrease of lease payments for 2019 through 2021. Further, two coal-fired utilities in which Tinuum Group had invested RC facilities announced closures in the fourth quarter of 2019, and the associated leases of those RC facilities terminated during this period. As a result of reduced lease payments with the GS Affiliates, the termination of the RC facility leases at the closed coal-fired utilities and higher depreciation on all Tinuum Group RC facilities as a result of a reduction in their estimated useful lives as determined by Tinuum Group during the three months ended September 30, 2019, we expect our pro-rata share of Tinuum Group’s earnings and distributions to be lower in future periods.
Tinuum Services operates and maintains RC facilities under operating and maintenance agreements with Tinuum Group and owners or lessees of RC facilities. Tinuum Group or the owners or lessees of the RC facilities pay Tinuum Services, subject to certain limitations, the costs of operating and maintaining the RC facilities plus various fees. Tinuum Services also arranges for the purchase and delivery of certain chemical additives under chemical agency agreements, which include the chemicals required for our CyCleanTM, and M-45 Technologies that are necessary for the production of RC. The term of each chemical agency agreement runs concurrently with the respective RC facility's operating and maintenance agreement.
We also earn royalty revenues from the licensing of our M-45 Technology ("M-45 License") to Tinuum Group. License royalties are recognized based upon a percentage of the per-ton, pre-tax margin as defined in the M-45 License.
The following table provides summary information related to the Company's investment in Tinuum Group and the related RC facilities as of December 31, 2019 and tons of RC produced and sold for the year ended December 31, 2019:
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| | | | | | | | | | | | |
| | | | | | | Operating |
| | | # of RC Facilities | | Not Operating | | Invested | | Retained |
| RC Facilities | | 26 |
| | 6 |
| | 20 |
| (1) | — |
|
| RC tons produced and sold (000's) | | | | | | 66,481 |
| | 1,505 |
|
The following tables provide summary information related to the Company's investment in Tinuum Group and the related RC facilities as of December 31, 2018 and tons of RC produced and sold for the year ended December 31, 2018:
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| | | | | | | | | | | | |
| | | | | | | Operating |
| | | # of RC Facilities | | Not Operating | | Invested | | Retained |
| Facilities | | 28 |
| | 9 |
| | 19 |
| (1) | — |
|
| RC tons produced and sold (000's) | | | | | | 59,737 |
| | 2,302 |
|
(1) One RC facility is approximately 50% invested with an independent third party. The remaining approximate 50% is retained by Tinuum Group, the Company and another member of Tinuum Group.
Competition
We believe Chem-Mod, LLC and licensees of Chem-Mod's technology are Tinuum Group's principal competitors. Competition in the RC market is based primarily on price, the number of tons of coal burned at the coal-fired electric generating units where the RC facilities are operating and the tax compliance facts associated with each RC facility. Additionally, competition for tax equity investors extends into other investment opportunities, including opportunities related to potential tax incentive transactions.
Raw Materials
The principal raw materials used in our RC products are comprised of non-bromine based halogens.
Operations
Tinuum RC facilities are located at coal-fired power plants in the U.S. As of December 31, 2019, Tinuum Group and Tinuum Services had operations in 15 states.
Power Generation and Industrials
Products
Our products provide mercury control and other air contaminants control to coal-fired power generators and other industrial companies. Most of the North American coal-fired power generators have installed equipment to control air pollutants, like mercury, prior to or since the inception of the MATS rule. However, many power generators need consumable products on a recurring basis to chemically and physically capture mercury and other contaminants. There are three primary consumable products that work in conjunction with the installed equipment, to control mercury: PAC, coal halogen additives and scrubber additives. In many cases these three consumable products can be used together or in many circumstances substituted for each other. However, PAC has widely been adopted as the best available technology to capture mercury due to product efficiency and effectiveness and currently accounts for over 50% of the mercury control consumables North American market. Additionally, we offer coal additives through both our RC and PGI segments. Regardless of the offering, we work with customers to develop and implement a compliance control strategy that utilizes the consumables solutions that fit with their unique operating and pollutions control configuration.
Power generators must stay in compliance with the various regulatory emissions requirements. As such, we believe power generators’ top priority is to identify and work with a vendor that can consistently and reliably provide a consumables solution. However, as the market has matured since 2016 and coal-fired power continues to be under economic pressure from natural gas and renewable energy sources, cost of compliance has become increasingly important. Our current products and services provide cost competitive solutions across the entire spectrumoutside of coal-fired power generators' needs.generation, including industrial applications, water treatment plants and other markets. We believe the Supply Agreement with Cabot, as discussed below, will drive adoption of our AC products by customers in some of those diverse end-markets.
Sales and Customers
Sales of consumables are primarily made by the Company’s employees and through distributors and sales representatives to a range of end customers, including coal-fired utilities, industrial companies, water treatment plants and industrials. Some of ourother customers. Our AC sales of AC are generally made under annual requirements-based contracts or longer-term agreements.ranging from one to five years. Our chemical product sales are generally made on a purchase order by purchase order basis. Revenues from our top three customers comprised approximately 37% of our total consolidated consumables revenues duringfor the year ended December 31, 2019,2021, and the loss of any of these customers would have a material adverse effect on the PGIour operating results.
Cabot Supply Agreement and Related Agreements
On September 30, 2020, we and Cabot Norit Americas, Inc., ("Cabot") entered into a supply agreement (the "Supply Agreement") pursuant to which we agreed to sell and deliver to Cabot, and Cabot agreed to purchase and accept from us, certain lignite-based activated carbon products ("Furnace Products"). The term of the Supply Agreement is for 15 years with 10-year renewal terms that are automatic unless either party provides three years prior notice of intention not to renew before the end of any term.
We believe the Supply Agreement will continue to provide material incremental sales volume and lower fixed operating costs on a per unit basis for our manufacturing plant located in Louisiana (the "Red River Plant"). Further, the Supply Agreement has expanded distribution of our AC products to additional markets outside of those we have traditionally served.
As a condition to entering into the Supply Agreement, on September 30, 2020, we entered into an agreement to purchase (the "Mine Purchase Agreement") from Cabot 100% of the membership interests in Marshall Mine, LLC (the "Marshall Mine Acquisition"), which owns a lignite mine located outside of Marshall, Texas (the "Marshall Mine"), for a nominal cash purchase price. Immediately after completion of the Mine Purchase Agreement, we independently determined to commence activities to shutter the Marshall Mine, and we will incur the associated reclamation costs as further described below.
In conjunction with the execution of the Supply Agreement and the Mine Purchase Agreement, on September 30, 2020, we entered into a reclamation contract (the "Reclamation Contract") with a third party that provides a capped cost, subject to certain contingencies, in the initial amount of approximately $19.7 million plus an obligation to pay certain direct costs of approximately $3.6 million (collectively, the "Reclamation Costs") over the estimated reclamation period of 10 years. Under the terms of the Supply Agreement, Cabot is obligated to reimburse us for approximately $10.2 million of the Reclamation Costs (the "Reclamation Reimbursements"), which are payable semi-annually over 13 years and inclusive of interest.
As the owner of the Marshall Mine, we were required to post a surety bond to ensure performance of our reclamation activities under the Surety Bond Indemnification Agreement (the "Surety Agreement"). As of December 31, 2021, we posted a surety bond of $16.6 million.
On February 1, 2021, we and a subsidiary of Cabot Corporation, Cabot Norit Nederland B.V. ("Cabot Corporation") entered into a five-year supply agreement ("EMEA Supply Agreement") to supply Cabot Corporation with lignite activated carbon products and other proprietary products used for mercury removal in utility and industrial coal-fired power plants in the EMEA market (as defined below). Cabot Corporation will be the exclusive and sole reseller of these products within Europe, Turkey, the Middle East and Africa ("EMEA"), and we will have a first right to provide the products to Cabot for sale in the EMEA market.
Competition
Our primary competitors for consumable sorbent products include Cabot Norit America, Inc., a division of Cabot Corporation (CBT), Calgon Carbon, a subsidiary of Tokyo Stock Exchange listed Kuraray Co., Ltd., Donau Carbon Company, Midwest Energy Emissions Corp. (MEEC) and Nalco Holding Company, a subsidiary of Ecolab Inc. (ECL) and Midwest Energy Emissions Corp (MEEC).
Raw Materials
The principal raw material we use in the manufacturing of AC is lignite coal, which is in general, readily available and we believe we have an adequateavailable. We supply 100% of the lignite coal through our ownership of the Five Forks Mine which("Five Forks") to fulfill customer orders. Five Forks is operated for us by Demery Resources Company, LLC ("Demery"), a subsidiary of the North American Coal Company ("Demery").Company. We may also periodically purchase various ACs to supplement our inventory levels or to produce various products to serve AC certain markets.
We purchase various additives utilized in the production of AC. The manufacturing of AC is dependent upon these various additives that are subject to price fluctuations and supply constraints. In addition, the number of suppliers who provide the necessary additives needed to manufacture our ACs is limited. We purchase these additives through supply agreements or spot purchases with the producers. Supply agreements with these producers are generally renewed on an annual basis.
We also purchase additives that are included in certain chemical products for resale to our customers through contracts with suppliers. The manufacturing of our consumablesthese consumable products is dependent upon certain discrete additives that are subject to price fluctuations and supply constraints. In addition, the number of suppliers who provide the necessary additives needed to manufacture our chemical products are limited. Supply agreements with these producers are generally renewed on an annual basis.
Operations
We own and operate an ACthe Red River plant thatwhich is located in Louisiana. We also lease land in which operate a manufacturing and distribution facility located in Louisiana. Additionally, we have sales, product development and administrative operations located in Colorado.
Refined Coal ("RC")
RevenueThrough December 31, 2021, Tinuum Group provided reduction of mercury and nitrogen oxide ("NOX") emissions at select coal-fired power generators through the production and sale of RC that qualified for Section 45 tax credits. We benefited from Tinuum Group's production and sale of RC from our share of earnings from Tinuum Group's sales or leases of RC facilities to tax equity investors. As noted above, the Section 45 tax credit period expired on December 31, 2021 and both Tinuum Group and Tinuum Services substantially ceased operations as of that date. Tinuum Group is performing reclamation at its RC facilities and, along with Tinuum Services. As such, our earnings and distributions from our RC segment substantially ceased as of December 31, 2021, and this will have a material adverse effect on our results of operations and financial position beginning in 2022. See the separately filed financial statements of Tinuum Group included in Item 15 - "Exhibits, Financial Statement Schedules" ("Item 15") of this Report.
Products
Our patented M-45TM and M-45-PCTM technologies (collectively, the "M-45 Technology") are proprietary pre-combustion coal treatment technologies used to control emissions of nitrogen oxides ("NOX") and mercury from coals burned in circulating fluidizer bed boilers and pulverized coal boilers, respectively.
Our patented CyCleanTM technology, a pre-combustion coal treatment process provides electric power generators the ability to enhance combustion and reduce emissions of NOX and mercury from coals burned in cyclone boilers.
Our patents related to the RC segment are not expected to have significant commercial application beyond December 31, 2021 primarily due to the wind down of Tinuum Group and Tinuum Services as a result of the expiration of the Section 45 tax credit period.
Sales and Customers
Through December 31, 2021 we earned royalties ("M-45 Royalties") under a licensing arrangement with Tinuum Group for those RC facilities that utilized the M-45 Technology to treat coal for the reduction of emissions of both NOX and mercury. With the closure of all of the RC facilities as of December 31, 2021, we will no longer earn M-45 Royalties and the loss of this revenue stream will have a material adverse effect on our results of operations and financial position beginning in 2022. For the year ended December 31, 2021, M-45 Royalties comprised 14% of our total consolidated revenues and approximately 296% of our total consolidated operating income. M-45 Royalties are recognized based upon a percentage of the per-ton, pre-tax margin as defined in the M-45 License.
For 2021 and 2020, we also derived substantial earnings in the RC segment from our equity method investments in Tinuum Group and Tinuum Services. Additional information related to major customers is disclosed in Note 21 of the Consolidated Financial Statements included in Item 8 of this Report.
Historically, we generated substantial earnings and cash distributions from our ownership in Tinuum Group, which constructed RC facilities that were either leased or sold to tax equity investors who earned Section 45 tax credits for the production and sale of RC to utilities at their respective RC facilities. We referred to these RC facilities as "invested RC facilities."
RC facilities that produced and sold RC and were not leased or sold, but wholly or partially owned by Typeus or Tinuum Group, were referred to as "retained" RC facilities. Through our direct ownership in retained RC facilities or indirect ownership through Tinuum Group, we earned Section 45 tax credits at retained RC facilities for the RC that was produced and sold to utilities. For the years ended December 31, 2021 and 2020, we earned $0.4 million and $0.4 million of Section 45 tax credits, respectively. As of December 31, 2021, we have cumulatively earned substantial tax credits from certain retained RC facilities, but have not been able to fully utilize them. See Note 18 to our Consolidated Financial Statements included in Item 8 - "Financial Statements and Supplementary Data" ("Item 8") of this Report for additional information regarding our tax credits and other deferred tax assets.
Through December 31, 2021, Tinuum Services operated and maintained RC facilities under operating and maintenance agreements with owners or lessees of these RC facilities.
The following table
showsprovides summary information related to the
amountCompany's investment in Tinuum Group and the related RC facilities as of
total revenue by type:December 31, 2021 and tons of RC produced and sold for the year ended December 31, 2021: |
| | | | | | | | |
| | | Years Ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Revenues: | | | | |
| Consumables | | $ | 53,187 |
| | $ | 8,733 |
|
| License royalties, related party | | 16,899 |
| | 15,140 |
|
| Other | | — |
| | 72 |
|
| Total revenues | | $ | 70,086 |
| | $ | 23,945 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | Operating |
| | # of RC Facilities | | Not Operating | | | | | | | | Invested | | Retained |
| RC Facilities | | 26 | | | 26 | | | | | | | | | — | | | — | |
| RC tons produced and sold (000's) | | | | | | | | | | | | 64,455 | | | 144 | |
The following table provides summary information related to the Company's investment in Tinuum Group and the related RC facilities as of December 31, 2020 and tons of RC produced and sold for the year ended December 31, 2020:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | Operating |
| | # of RC Facilities | | Not Operating | | | | | | | | Invested | | Retained |
| Facilities | | 26 | | | 3 | | | | | | | | | 23 | | | — | |
| RC tons produced and sold (000's) | | | | | | | | | | | | 64,982 | | | 693 | |
Raw Materials
The principal raw materials used in our RC products were comprised of non-bromine based halogens.
Operations
Tinuum RC facilities were located at coal-fired power plants in the U.S.
Research and Development Activities
We have conducted research and development directed towards product development related to the Supply Agreement and other markets. During the years ended December 31, 2021 and 2020, we incurred expenses of $0.4 million and $1.0 million, respectively.
Legislation and Environmental Regulations
Our products and services, as well as Tinuum Group’s production and sale of RC, are used for the reduction of pollutants and other contaminants in the coal-burning electrical generation and water treatment processes. To the extent that legislationcontaminants. Legislation and regulation limit the amount of pollutants and other contaminants permitted and may increase the need for our products increases.product. Below is a summary of the primary legislation and regulation that affects the market for our products.
U.S. Federal Mercury and Air Toxic Standards (“MATS”("MATS") Affecting Electric Utility Steam Generating Units
On December 16, 2011, theThe U.S. Environmental Protection Agency ("EPA") issued the final "MATS Rule" that went into effect in April 2012. The EPA structured the MATS Rule as a MACT-basedMaximum Achievable Control Technology-based ("MACT-based") hazardous pollutant regulation applicable to coal and oil-fired Electric Utility Steam Generating Units (“EGU”("EGU"), which generate electricity through steam turbines and have a capacity of 25 megawatts or greater, and provide for, among other provisions, control of mercury, and particulate matter and control of acid gases such as hydrochloric acid ("HCl"), sulfuric acid ("H2SO4") and other Hazardous Air Pollutants ("HAPs"). Approximately 1,260 units in the U.S. were coal-fired EGUs when the rule was enacted. According to our estimates, the MATS Rule sets a limit that we believe requires the capture of up to 80-90% plus of the mercury in the coal burned in electric power generation boilers as measured at the exhaust stack outlet for most plants. The MACT standards are also known as National Emission Standards for Hazardous Air Pollutants ("NESHAP"). Plants generally had four years to comply with the MATS Rule, and we estimate that, based on data reported to the EPA and conversations with plant operators, most plants were required to comply by April 2016 and implementation of the MATS Rule is now largely complete.completed. We estimate that 42%52% of the coal-fired EGUsunits that were operating in December 20112012 when the MATS ruleRule was finalized have been permanently shut down, leaving approximately 527 EGUs518 units in operation in the U.S. at the end of 2019.2021.
In April 2017, a review by the U.S. Court of Appeals for the D.C. Circuit (the "D.C. Circuit") of a 2016 “supplemental finding”'supplemental finding' associated with the cost benefit analysis of the MATS Rule conducted by the EPA was stayed at the request of the currentTrump Administration. The court case continues to be stayed indefinitely. In February 2019,May 2020, the EPA published a reconsideration ofreconsidered and withdrew its 2016 "supplemental finding" associated with the cost benefit analysis of the MATS Rule. This reconsideration proposesIn this action, EPA found that it iswas not “appropriate or necessary”"appropriate and necessary" to regulate HAPs emissions from coal- and oil-filedoil-fired EGUs. However, the EPA expressly statesstated that the reconsideration is not removingneither removed coal- and oil-fired EGUs from the list of sources that must comply with the MATS rule, but does,nor rescinded the MATS Rule, which has remained continuously in effect. ADES joined a number of parties in seeking review of this EPA action before the reconsideration, solicit public comments on whetherD.C. Circuit. President Biden identified EPA’s withdrawal of the supplemental finding as one of the actions to be reviewed for conformity with Biden Administration policy, and in February 2021, the Biden Administration moved that the pending judicial review of the supplemental finding withdrawal be held in abeyance. On February 9, 2022, the EPA haspublished a new proposed rule revoking the authorityMay 2020 withdrawal of the 2016 supplemental finding and affirming that it is "appropriate and necessary" to removeregulate HAP emissions from coal- and oil-fired EGUs, fromwhich is currently pending. The D.C. Circuit granted the list of sources that must comply with theBiden Administration’s motion, and this appeal also is now in abeyance. The MATS Rule or whether it can rescind the MATS Rule. The timing and content of the final reconsideration rule are unknown.remains in effect.
State Mercury and Air Toxics Regulations Affecting EGUs
In addition, certain states have their own mercury rules that are similar to or more stringent than the MATS Rule, and coal-firedRule. Coal-fired electricity generating units in the U.S are subject to consent decrees that require the control of acid gases and particulate matter, in addition to mercury emissions.
U.S. Federal Industrial Boiler MACT
In January 2013, the U.S. EPA issued the final set of adjustments to the MACT-based air toxics standards for industrial boilers, including mercury, particulate matter and acid gas emission limits. Existing boilers typically had until January 31, 2017 to comply with the rule. On December 1, 2014, the EPA announced the reconsideration of the industrial boiler MACT ("IBMACT") and proposed amendments to the version published January 31, 2013, representing technical corrections and clarifications. The proposed amendments do not affect the applicability of the final rule.
The EPA estimated that approximately 600 coal-fired boilers will be affected by IBMACT, in industries such as pulp and paper. Our estimates, based on conversations with plant operators, suggest that most of the affected plants have or will either shut down or switchswitched fuels to natural gas to comply with the regulation.
Effluent Limitation Guidelines
On September 30,In 2015, the EPA set the first federal limits known as effluent limitation guidelines (“ELGs”("ELGs") on the levels of toxic metals in wastewater that can be discharged from power plants. The final rule requires, among other things, zero discharge for fly ash and bottom ash transport water, and limits on mercury, arsenic, selenium, and nitrate from flue gas desulfurization ("FGD") wastewater. In September 2017, the EPA finalized a rule that delayed the original compliance deadlines for certain wastewater streams from November 2018 to November 2020, with the possibility that plants would not need to comply until December 2023 with state approval. In April 2019, the U.S. Court of Appeals for the Fifth Circuit struck down the EPA’s ELGs that apply to leachate wastewater and “legacy"legacy wastewater,”" and directed the EPA to revise the limits on the levels of toxic metals in those wastewater streams. In November 2019, the EPA proposed to revise the ELGs for bottom ash and FGD wastewater. The final rule, published in the Federal Register on October 13, 2020 and effective on December 14, 2020, does not directly regulate halogens. It does, however, propose to establish a voluntary incentives program for the removal of certain halides. In none of the proposed effluent guidelines that the EPA is considering are halogens directly regulated. Though under several (thoughmany
(though not all) of the proposed treatment options that the EPA is considering, selenium in FGD wastewater would be regulated, and. someregulated. Some halogens may impact the effectiveness of biological wastewater treatment systems that are often used for the removal of selenium. On August 3, 2021, the EPA initiated a supplemental rule-making initiative to strengthen certain discharge limits and intends to issue a proposed rule for public comment in Fall of 2022.
Additional U.S. Legislation and Regulations
On August 3,In 2015, the EPA finalized rules to reduce greenhouse gases ("GHGs") in the form of the Clean Power Plan ("CPP"), which established guidelines for states to follow in developing plans to reduce GHG emissions from fossil fuel-fired power plants. Under the CPP, states were required to prepare "State Plans" to meet state targets based on emission reductions from affected sources. The CPP was challenged by multiple states in the U.S. Court of Appeals for the District of Columbia Circuit ("DC Circuit").D.C. Circuit. The CPP was stayed by the U.S. Supreme Court. The DCD.C. Circuit held the CPP litigation in abeyance until April 28, 2017, and dismissed the case once the EPA replacedrepealed the CPP.CPP in July 2019.
In July 2019, theThe EPA repealed the CPP and replaced it with the Affordable Clean Energy (“ACE”("ACE") rule, which established guidelines for states to follow in developing plans to reduce GHG emissions from fossil fuel-fired power plants. ACE also requires states to prepare State Plans and prescribes that they must be based on heat rate improvements at affected plants. Numerous states, power companies and non-governmental organizations challenged the ACE rule in the D.C. Circuit.Circuit, which vacated the ACE rule on January 19, 2021. On February 12, 2021, EPA stated that neither the ACE or CPP regulations were in place with respect to GHGs for fossil fuel-fired power plants.
International Regulations
There are various international regulations related to mercury control. In Canada, the Canada-Wide Standard ("CWS") was initially implemented in 2010, with increasingly stringent limits through 2020 and with varying mercury emissions caps for each province. China and Germany both have limits for mercury emissions that are less stringent than U.S. limits and are typically met using co-benefits from other installed air pollution control equipment designed to control other pollutants. In May 2017, the EU ratified the Minimata Convention on Mercury, triggering mercury control regulations with implementation starting in 2021. Specific emissions limits for dust, nitrogen oxides (NOx), sulfur dioxide (SO2), mercury and particulate matter (PM) are currently being developed guided by the best available technologies reference ("BREF") document for limiting stack emissions and liquid effluents from industrial processes. The BREF conclusions for large coal-fired electricity generating units were adopted by the European Commission in July 2017.
Based uponon the existing and potential regulations, we believe the international market for mercury control products may expand in the coming years, and we areyears. We believe the EMEA Supply Agreement with Cabot will help facilitate positioning our patent portfolio and existing commercial products accordingly to be prepared if an international market for our products develops.
in the EMEA region.
Mining Environmental and Reclamation Matters
Federal, state and local authorities regulate the U.S. coal mining industry with respect to matters such as employee health and safety and the environment, including the protection of air quality, water quality, wetlands, special status species of plants and animals, land uses, cultural and historic properties and other environmental resources identified during the permitting process. Reclamation is required during production and after mining has been completed. Materials used and generated by mining operations must also be managed according to applicable regulations and law.
The Surface Mining Control and Reclamation Act of 1977 ("SMCRA"), establishes mining, environmental protection, reclamation and closure standards for all aspects of surface mining. Mining operators must obtain SMCRA permits and permit renewals from the Office of Surface Mining (the "OSM"), or from the applicable state agency if the state agency has obtained regulatory primacy. A state agency may achieve primacy if the state regulatory agency develops a mining regulatory program that is no less stringent than the federal mining regulatory program under SMCRA. OurThe Five Forks Mine operates in Louisiana, which has achieved primacy and issues permits in lieu of the OSM. The Marshall Mine operates in Texas, which has also achieved primacy and issues permits in lieu of the OSM.
Mine operators are often required by federal and/or state laws, including SMCRA, to assure, usually through the use of surety bonds, payment of certain long‑term obligations including mine closure or reclamation costs, federal and state workers’ compensation costs, coal leases and other miscellaneous obligations. Although surety bonds are usually noncancelable during their term, many of these bonds are renewable on an annual basis and collateral requirements may change. As of December 31, 2019,
2021, we posted a surety bond of approximately $5.9$7.5 million for reclamation of the Five Forks Mine and $16.6 million for the reclamation of Marshall Mine.
Patents
As of December 31, 2019,2021, we held 5783 U.S. patents and seven12 international patents that were issued or allowed, 2715 additional U.S. provisional patents or applications that were pending, and seventwo international patent applications that were either pending or filed relating to different aspects of our technology. Our existing patents generally have terms of 20 years from the effective date of filing, with our next patents expiring beginning in 2021. We consider many of our patents and pending patents to be critical to the ongoing conduct of our business.2022.
Seasonality of Activities
The sale of our consumable products and RC facility operation levels dependdepends on the operations of the coal-fired electricity generatingpower generation units toand industrial facilities in which the applicable consumables are provided and the location of the RC facilities, respectively.provided. Power generation is weather dependent, with electricity and steam production varying in response to heating and cooling needs. Additionally, coal-fired electricitypower generating units routinely schedule maintenance outages in the spring and/or fall depending uponon the operation of the boilers. During the period in which an outage may occur, which may range from one week to over a month, no consumables are used, and no RC is produced or sold, and our revenues and Tinuum's revenuessales may be correspondingly reduced.
The sale of our AC products for water purification depends on demand from municipal water treatment facilities where these products are utilized. Depending on weather conditions and other environmental factors, the summer months historically have the highest demand for PAC, as one of the major uses for PAC is for the treatment of taste and odor problemsepisodes caused by increased degradation of organic contaminants and natural materials in water during the summer.
Safety, Health and Environment
Our operations are subject to numerous federal, state, and local laws, regulations, rules and ordinances relating to safety, health, and environmental matters (“("SH&E Regulations”Regulations"). These SH&E Regulations include requirements to maintain and comply with various environmental permits related to the operation of many of our facilities, including mine health and safety laws required for continued operation of the Five Forks Mine.
Employees
As of December 31, 2019,2021, we employed 133139 personnel, 27 in Colorado and 112 in Louisiana, all of which were full-time employees; 36 employees were employed at our offices in Colorado and 97 employees were employed at our facilities in Louisiana.
full-time.
Available Information
Our periodic and current reports are filed with the Securities and Exchange Commission ("SEC') pursuant to Section 13(a) of the Securities Exchange Act of 1934, as amended (the "Exchange Act") and are available free of charge within 24 hours after they are filed with, or furnished to, the SEC at the Company’s website at www.advancedemissionssolutions.com.www.advancedemissionssolutions.com. The filings are also available through the SEC at the SEC's Public Reference Room at 100 F Street, N.E., Washington, D.C. 20549 or by calling 1-800-SEC-0330. Alternatively, these reports can be accessed at the SEC’s website at www.sec.gov. The information contained on our website shall not be deemed incorporated by reference in any filing under the Securities Act of 1933, as amended (the "Securities Act") or the Exchange Act.
Copies of Corporate Governance Documents
The following Company corporate governance documents are available free of charge at our website at www.advancedemissionssolutions.com and such information is available in print to any stockholder who requests it by contacting the Secretary of the Company at 640 Plaza Drive, Suite 270, Highlands Ranch CO, 80129.
Certificate of Incorporation
Bylaws
Code of Ethics and Business Conduct
Insider Trading Policy
Whistleblower Protection Policy
Board of Directors Responsibilities
Audit Committee Charter
Compensation Committee Charter
Nominating and Governance Committee Charter
Forward-Looking Statements Found in this Report
This Report contains forward-looking statements within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act that involve risks and uncertainties. In particular such forward-looking statements are found in this Part I and under the heading in Part II, Item 7 below. Words or phrases such as "anticipates," "believes," "expects," "intends," "plans," "estimates," "predicts," the negative expressions of such words, or similar expressions are used in this Report to identify forward-looking statements, and such forward-looking statements include, but are not limited to, statements or expectations regarding:
| |
(a) | the scope and impact of mercury and other regulations or pollution control requirements, including the impact of the final MATS; |
| |
(b) | the production and sale of RC by RC facilities that will qualify for Section 45 tax credits; |
| |
(c) | expected growth or contraction in and potential size of our target markets; |
| |
(d) | expected supply and demand for our products and services; |
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(e) | increasing competition in the PGI market; |
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(f) | future level of research and development activities; |
| |
(g) | the effectiveness of our technologies and the benefits they provide; |
| |
(h) | Tinuum Group’s ability to profitably sell and/or lease additional RC facilities and/or RC facilities that may be returned to Tinuum Group, or to recognize the tax benefits from production and sale of RC on retained RC facilities and the effect of these factors on Tinuum Group's future earnings and distributions; |
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(i) | probability of any loss occurring with respect to certain guarantees made by Tinuum Group ("Party Guarantees"); |
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(j) | the timing of awards of, and work and related testing under, our contracts and agreements and their value; |
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(k) | the timing and amounts of or changes in future revenues, royalties earned, backlog, funding for our business and projects, gross margins, expenses, earnings, tax rates, valuation allowance on our deferred tax assets, cash flows, license royalties, working capital, liquidity and other financial and accounting measures; |
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(l) | the outcome of current legal proceedings; |
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(m) | awards of patents designed to protect our proprietary technologies both in the U.S. and other countries; and |
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(n) | whether any legal challenges or EPA actions will have a material impact on the implementation of the MATS or other regulations and on our ongoing business. |
(a)expected growth or contraction in and potential size of our target APT markets, including the water purification, food and beverage and pharmaceuticals markets;
(b)the anticipated effects from the increase in pricing of our APT products;
(c)expected supply and demand for our APT products and services;
(d)increasing competition in the APT market;
(e)the timing and effects of our review of strategic alternatives;
(f)future level of research and development activities;
(g)the effectiveness of our technologies and the benefits they provide;
(h)probability of any loss occurring with respect to certain guarantees made by Tinuum Group;
(i)the timing of awards of, and work and related testing under, our contracts and agreements and their value;
(j)the timing and amounts of or changes in future revenues, royalties earned, backlog, funding for our business and projects, margins, expenses, earnings, tax rates, cash flows, royalty payment obligations, working capital, liquidity and other financial and accounting measures;
(k)the amount of future capital expenditures needed for our business;
(l)awards of patents designed to protect our proprietary technologies both in the U.S. and other countries;
(m)the adoption and scope of regulations to control certain chemicals in drinking water; and
(n)opportunities to effectively provide solutions to U.S. coal-related businesses to comply with regulations, improve efficiency, lower costs and maintain reliability.
Our expectations are based on certain assumptions, including without limitation, that:
| |
(a) | coal will continue to be a significant source of fuel for electrical generation in the U.S.; |
| |
(b) | the IRS will allow the production and sale of RC to qualify for Section 45 tax credits through December 31, 2021; |
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(c) | we will continue as a key supplier of consumables to the coal-fired power generation industry as it seeks to implement reduction of mercury emissions; |
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(d) | current environmental laws and regulations requiring reduction of mercury from coal-fired boiler flue gases will not be materially weakened or repealed by courts or legislation in the future; |
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(e) | we will be able to obtain adequate capital and personnel resources to meet our operating needs and to fund anticipated growth and our indemnity obligations; |
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(f) | we will be able to establish and retain key business relationships with current and other companies; |
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(g) | orders we anticipate receiving will be received; |
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(h) | we will be able to formulate new consumables that will be useful to, and accepted by, the PGI markets; |
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(i) | we will be able to effectively compete against others; |
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(j) | we will be able to meet any technical requirements of projects we undertake; |
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(k) | Tinuum Group will be able to sell or lease additional RC facilities, including RC facilities that may be returned to Tinuum Group, to third party investors; and |
| |
(l) | we will be able to utilize the Section 45 tax credits earned from the production and sale of RC from retained facilities. |
(a)coal will continue to be a significant source of fuel for electrical generation in the U.S.;
(b)we will continue as a key supplier of consumables to the coal-fired power generation industry as it seeks to implement reduction of mercury emissions;
(c)we will be able to obtain adequate capital and personnel resources to meet our operating needs and to fund anticipated growth and our indemnity obligations;
(d)Cabot will continue to purchase Furnace Products from us under the Supply Agreement in the quantities specified;
(e)we will be able to establish and retain key business relationships with current and other companies;
(f)orders we anticipate receiving will be received;
(g)we will be able to formulate new consumables that will be useful to, and accepted by, the APT markets;
(h)we will be able to effectively compete against others; and
(i)we will be able to meet any technical requirements of projects we undertake.
The forward-looking statements included in this Report involve risks and uncertainties. Actual events or results could differ materially from those discussed in the forward-looking statements as a result of various factors including, but not limited to, timing of new and pending regulations and any legal challenges to or extensions of compliance dates of them; the U.S. government’s failure to promulgate regulations or appropriate funds that benefit our business; changes in laws and regulations, accounting rules, prices, economic conditions and market demand; impact of competition; availability, cost of and demand for alternative energy sources and other technologies; technical, start up and operational difficulties; failure of the RC facilities to produce RC; termination of or amendments to the contracts for sale or lease of RC facilities or such facilities to qualify for Section 45 tax credits; decreases in the production of RC; our inability to commercialize our APT technologies on favorable terms; our inability to ramp up our operations to effectively address recent and expected growth in our APT business; loss of key personnel; potential claims from any terminated employees, customers or vendors; availability of materials and equipment for our businesses; intellectual property infringement claims from third parties; pending litigation; as well as other factors relating to our business, as described in our filings with the SEC, with particular emphasis on the risk factor disclosures contained in those filings and in Item 1A - "Risk Factors" of this Report. You are cautioned not to place undue reliance on the forward-looking statements made in this Report and to consult filings we have made and will make with the SEC for additional discussion concerning risks and uncertainties that may apply to our business and the ownership of our securities. The forward-looking statements contained in this Report are presented as of the date hereof, and we disclaim any duty to update such statements unless required by law to do so.
Item 1A. Risk Factors
The following risks relate to us as of the date this Report is filed with the SEC. This list of risks is not intended to be exhaustive, but reflects what we believe are the material risks inherent in our business and the ownership of our securities as of the specified dates. A statement to the effect that the occurrence of a specified event may have a negative impact on our business, results of operations, profitability, financial condition, or the like, is intended to reflect the fact that such an event, if it occurs, would be likely to have a negative impact on your investment in ADES, but should not imply the likelihood of the occurrence of such specified event. The order in which the following risk factors are presented is not intended as an indication of the relative seriousness of any given risk.
Risks relatingrelated to our business
As of December 31, 2021, earnings in our RC segment have substantially ended and beginning in 2022, we will be solely dependent on earnings from our APT segment to fund our operations. We will need to grow the earnings from our APT segment substantially to make up for the loss of earnings of our RC segment.
The Section 45 tax credit period expired on December 31, 2021. As a result, both Tinuum Group and Tinuum Services have substantially ceased operations and we expect to receive limited, final distributions from each during the first half of 2022. Substantially all of our earnings and cash flows in 2021 and 2020 were comprised of equity method earnings from Tinuum Group and M-45 Royalties generated from certain of Tinuum Group’s invested RC facilities. For the year ended December 31, 2021, our RC segment generated segment operating income of $82.6 million.
From an earnings standpoint, our APT segment must grow substantially, either organically or through acquisition, in order to replace earnings from our RC segment. There can be no assurance that we will be able to increase our APT segment earnings during 2022 or beyond to cover our current operating expenses or to provide a return to shareholders that is comparable to the return that we previously provided while our RC segment was operating. We do not expect our overall selling, general and administrative portions of our operating expenses to materially decrease in 2022 as a result of the wind down of our RC segment. If we are not able to cover operating expenses, we could be forced to raise additional capital, significantly reduce our operating expenses or take other alternative actions.
The financial effects of Tinuum Group providing indemnification under performance guarantees of its RC facilities are largely unknown and could adversely affect our financial condition.
Tinuum Group indemnifies certain utilities and lessees of RC facilities for particular risks associated with the operations and tax treatment of those facilities. We have provided limited, joint and several guarantees of Tinuum Group’s obligations under those leases. Any substantial payments made under such guarantees could have a material adverse effect on our financial condition, results of operations and cash flows.
We are reviewing strategic alternatives and there can be no assurance that we will be successful in identifying or completing any strategic transaction, that any such strategic transaction will result in additional value for our stockholders or that the process will not have an adverse impact on our business.
We have announced that our board of directors has initiated a strategic review to assess a range of strategic alternatives to maximize shareholder value. No timetable has been set for completion of this process, and there can be no assurance that the review of strategic alternatives will result in the identification or consummation of any transaction. The process of reviewing strategic alternatives may be time consuming and disruptive to our business operations and, if we are unable to effectively manage the process, our business, financial condition and results of operations could be adversely affected. We have and will continue to incur substantial expenses associated with identifying, evaluating and negotiating potential strategic alternatives. There can be no assurance that any potential transaction or other strategic alternative, if consummated, will provide greater value to our stockholders than that reflected in the current price of our common stock. Until the review process is concluded, perceived uncertainties related to our future may result in the loss of potential business opportunities and volatility in the market price of our common stock and may make it more difficult for us to attract and retain qualified personnel and business partners.
Our inability to meet customer supply requirements due to damage to or insufficient production capacity of our Red River manufacturing facility may have a material adverse effect on our business, results of operations and financial condition.
We own and operate a single activation-based manufacturing plant, which is our sole manufacturing plant for producing and selling products to our customers. Our ability to meet customer expectations, manage inventory, complete sales and achieve our
objectives for operating efficiencies depends on the full-time operation of the Red River Plant. We cannot replicate our manufacturing methods at another plant due to the limited availability of similar manufacturing plants, the additional costs incurred in supplying raw materials such as lignite to another plant, and the risk of revealing our confidential and proprietary technologies and manufacturing processes.
If the Red River Plant was destroyed or damaged in a significant manner, we would suffer a loss of inventory to supply customers, likely incur additional costs to deliver products to our customers, and disrupt the ordinary course of our business. In addition, if contractual demand exceeds manufacturing capacity, we would jeopardize our ability to fulfill obligations under our contracts, which could, in turn, result in reduced sales, profitability, contract penalties or terminations and damage to our customer relationships and could have a material adverse effect on our business. While we have insured the Red River Plant against damage or destruction as well as for losses from business interruptions, there can be no assurance that any insurance coverage will be sufficient to cover any such losses.
Further, a prolonged disruption in our operations due to Red River Plant downtime or having to meet customer requirements that exceed its maximum manufacturing capacity would require us to seek alternative customer supply arrangements, which may not be on attractive terms to us or could lead to delays in distribution of products to our customers, either of which could have a material adverse effect on our business, results of operations and financial condition.
Governmental regulations requiring mandatory COVID-19 vaccination of employees could have a material adverse impact on our business and results of operations
On September 9, 2021, President Biden issued Executive Order 14042 (the "Executive Order") requiring all employers with U.S. Government contracts to ensure that their U.S.-based employees, contractors, and subcontractors that work on or in support of U.S. Government contracts are fully vaccinated by December 8, 2021. The executive order includes on-site and remote U.S.-based employees, contractors and subcontractors and it only permits limited exemptions for medical and religious reasons. The Executive Order is facing legal challenges and currently is enjoined nationwide.
Removal of the injunction of the Executive Order or additional vaccine mandates may be announced in jurisdictions in which our business operates. Our implementation of these required policies may result in employee attrition, including attrition of critically skilled labor, and difficulty securing future labor needs, which could have a material adverse effect on our business, financial condition and results of operations.
The COVID-19 pandemic is expected to continue to affect and pose risks to our business and other epidemics or outbreaks of infectious diseases may have a similar impact.
The COVID-19 pandemic has resulted in significant volatility in the general economy. International, federal, state and local public health and governmental authorities have taken extraordinary actions to contain and combat the outbreak and spread of COVID-19, including travel bans, quarantines, "stay-at-home" orders and similar mandates that caused many individuals to substantially restrict their daily activities and many businesses to curtail or cease normal operations. While certain governments eased restrictions during the balance of 2020 and 2021, the pandemic remains disruptive to our business operations.
We may not be able to operate at optimal levels of efficiency given new work rules and procedures that were or will be implemented to protect our employees, as well as potential increased absenteeism as a result of community spread of COVID-19. Any suspension of production at our manufacturing facility, or difficulties or inefficiencies in resuming or increasing production, is likely to adversely impact our future results of operations, financial condition and liquidity, and that impact may be material. Furthermore, COVID-19 and related supply chain disruptions have impacted and may further impact our ability to efficiently operate and may lead to production delays or increased costs of production.
While we are unable to accurately predict the full impact that COVID-19 will have on our results of operations, financial condition, liquidity and cash flows due to continued uncertainties, including the duration and severity of the pandemic and containment measures, our compliance with these measures has impacted our day-to-day operations and could continue to affect our business and operations, as well as that of our key customers, suppliers and other counterparties, for an indefinite period of time. The disruptions to our operations caused by COVID-19 have resulted and are expected to continue to result in inefficiencies, delays and additional costs in our manufacturing, sales, marketing, and customer service efforts that we cannot fully mitigate through remote or other alternative work arrangements.
The situation surrounding the COVID-19 pandemic remains fluid. The ultimate impact of the COVID-19 pandemic on our results of operations, financial condition and liquidity will depend on future developments, some of which are beyond our knowledge or control. These include the duration and scope of the pandemic, travel restrictions, government mandated
restrictions and regulations, business and workforce disruptions, the impact on demand for our products, the effectiveness of actions taken to contain and treat the disease, including the efficacy of and ability to widely distribute vaccinations and therapeutics, and whether the pandemic leads to recessionary conditions in any of our key markets. We will continue to evaluate the nature and extent of the impact of COVID-19 to our business.
Demand for our products and services depends significantly on environmental laws and regulations. Uncertainty as to the future of such laws and regulations, as well as changes to such laws and regulations or granting of extensions of compliance deadlines has had, and will likely continue to have, a material effect on our business.
A significant market driver for our existing products and services and those planned in the future are present and expected environmental laws and regulations, particularly those addressing the reduction of mercury and other emissions from coal-fired electricity generating units. If such laws and regulations are delayed, or are not enacted or are repealed or amended to be less strict, or include prolonged phase-in periods, or are not enforced, our business would be adversely affected by declining demand for such products and services. For example:
a.The implementation of environmental regulations regarding certain pollution control and permitting requirements has been delayed from time to time due to various lawsuits. The uncertainty created by litigation and reconsiderations of rule-making by the EPA has negatively impacted our business, results of operations and financial condition and will likely continue to do so.
b.To the extent federal, state and local legislation mandating that electric power generating companies serving a state or region purchase a minimum amount of power from renewable energy sources such as wind, hydroelectric, solar and geothermal, and such amount lessens demand for electricity from coal-fired plants, the demand for our products and services would likely decrease.
Federal, state and international laws or regulations addressing emissions from coal-fired electricity generating units, climate change or other actions to limit emissions, including public opposition to new coal-fired electricity generating units, has caused and could continue to cause electricity generators to transition from coal to other fuel and power sources, such as natural gas, nuclear, wind, hydroelectric and solar. The potential financial impact on us of future laws or regulations or public pressure will depend upon the degree to which electricity generators diminish their reliance on coal as a fuel source. That, in turn, will depend on a number of factors, including the specific requirements imposed by any such laws or regulations, the periods over which those laws or regulations are or will be phased in, the amount of public opposition and the state and cost of commercial development of related technologies and processes. In addition, Public Utility Commissions ("PUCs") may not allow utilities to charge consumers for, and pass on the cost of, emissions control technologies without federal or state mandate.mandates. We cannot reasonably predict the impact that any such future laws or regulations or public opposition may have on our results of operations, financial condition or cash flows.
Action by the EPA related to MATS that decreases demand for our mercury removal products could have a material adverse effect on our PGIAPT segment.
Performance in our PGIAPT segment depends onis largely dependent upon demand for mercury removal relatedremoval-related product, which is largely dependent onaffected by the amount of coal-based power generation used in the U.S. and the continued regulation of utilities under MATS. In August 2018,May 2020, the EPA announced that it intends to reconsider the MATS rulereconsidered and in September 2018 submitted its proposal to the White House Office of Management and Budget. In February 2019, the EPA published a reconsideration ofwithdrew its 2016 "supplemental finding" associated with the cost benefit analysis of the MATS Rule. This reconsideration proposesIn this action, the EPA found that it iswas not 'appropriate or necessary'"appropriate and necessary" to regulate HAPsHAP emissions from coal- and oil-filedoil-fired EGUs. However, the EPA expressly statesstated that the reconsideration is not removingneither removed coal- and oil-fired EGUs from the list of sources that must comply with the MATS rule, but does,nor rescinded the MATS Rule, which has remained continuously in the reconsideration, solicit comments on whethereffect.On February 9, 2022, the EPA haspublished a new proposed rule revoking the authorityMay 2020 withdrawal of the 2016 supplemental finding and affirming that it is "appropriate and necessary" to removeregulate HAP emissions from coal- and oil-fired EGUs from the list of sources that must comply with the MATS Rule or whether it can rescind the MATS Rule.EGUs. Any final action taken by
the EPA related to MATS that decreases demand for our products for mercury removal will have a negative effect on the financial results of our PGIAPT segment. The timing and content of the final reconsideration rule are unknown.
Uncertain geopolitical conditions could adversely affect our business.
Uncertain geopolitical conditions, including the invasion of Ukraine, sanctions against Russia and other potential impacts on this region's economic environment and currencies may cause disruptions in our business. These include logistics delays or shortages in producing and shipping certain of our raw materials, increases in energy prices that could increase costs of certain
of our raw materials, increases in transportation costs from overall higher gasoline prices and cyber-attacks targeted at U.S. power infrastructure that could impact demand for our products.
The failure of tariffs placed on U.S. imports of Chinese activated carbon to adequately address the impact of low-priced imports from China could have a material adverse effect on the competitiveness and financial performance of our PGIAPT segment.
Our PGIAPT segment faces competition in the U.S. from low-priced imports of activated carbon products. If the amountsvolumes of these low-priced imports increase, especially if they are sold at less than fair value, our sales of competing products could decline, which could have an adverse effect on the earnings of our PGIAPT segment. In addition, sales of these low-priced imports may negatively impact our pricing. To limit these activities, regulators in the U.S. have enacted an anti-dumping duty order on steam activated carbon products from China. In 2018, the order was extended for an additional five years. The amount of anti-dumping duties collected on imports of steam activated carbon from China is reviewed annually by the U.S. Department of Commerce. To the extent the anti-dumping margins do not adequately address the degree to which imports are unfairly traded, the anti-dumping order may be less effective in reducing the volume of these low-priced activated carbon imports in the U.S., which could negatively affect demand and/or pricing for our AC products.
The market for consumables and other products that provide pollutant reduction is highly competitive and some of our competitors are significantly larger and more established than we are, which could adversely impede our growth opportunities and financial results.
We operate in a highly competitive marketplace. Our ability to compete successfully depends in part upon our ability to maintain a production cost advantage, competitive technological capabilities and to continue to identify, develop and commercialize new and innovative products for existing and future customers. We may face increased competition from existing or newly developed products offered by industry competitors or other companies whose products offer a similar functionality as our products and could be substituted for our products, which may negatively affect demand for our products. In addition, market competition could negatively impact our ability to maintain or raise prices or maintain or grow our market position.
We compete against certain significantly larger and/or more established companies in the market for consumables and other products that provide mercury emissions reduction, water treatment and water treatment.air purification.
Reduction of coal consumption by North American electricity power generators could result in less demand for our products and services. If utilities significantly reduce the number of coal-fired electricity generating units or the amount of coal burned without a corresponding increase in the services required at the remaining units, this could reduce our revenues and materially and adversely affect our business, financial condition and results of operations.
The amount of coal consumed for North American electricity power generation is affected by, among other things, (1) the location, availability, quality and price of alternative energy sources for power generation, such as natural gas, fuel oil, nuclear, hydroelectric, wind, biomass and solar power; and (2) technological developments, including those related to competing alternative energy sources.
Natural gas-fueled generation and renewable energy generation has been displacing and may continue to displace coal-fueled generation, particularly from older, less efficient coal-powered generators. We expect that a significant amount of the new power generation necessary to meet increasing demand for electricity generation will be fueled by these sources. The price of natural gas has remained at historically low levelsrelatively competitive for power generation and the use of natural gas is perceived as having a lower environmental impact than burning coal. Natural gas-fired plants are cheaper to construct, and permits to construct these plants are easier to obtain, and ongoing costs of natural gas-fired plants associated with meeting environmental compliance are lower. Possible advances in technologies and incentives, such as tax credits, that enhance the economics of renewable energy sources could make those sources more competitive than coal. Any reduction in the amount of coal consumed by domestic electricity power generators, whether as a result of new power plants utilizing alternative energy sources or as a result of technological advances, could reduce the demand for our current products and services, thereby reducing our revenues and materially and adversely affecting our business and results of operations.
Additionally, long-term changes in environmental regulation that threaten or preclude the use of coal or other fossil fuels as a primary fuel source for electricity production may result in the reduction or closure of a significant number of coal-fired electric generating units, and may adversely affect our business, financial condition and results of operations.
The loss of, or significant reduction in, purchases by our largest customers could adversely affect our business, financial condition or results of operations.
During the year ended December 31, 2019,2021, we derived approximately 65%50% of our total consumable revenues from our tenfive largest customers. ManyOur top three customers accounted for approximately 37% of these customers purchase our products to comply with emissions regulations, and if coal-fired generation decreases, it may have a negative impact on the amount oftotal consumable products purchased.revenue for our last fiscal year. If any of our tenfive largest customers were to significantly reduce the quantities of consumables they purchase from us, it may adversely affect our business, financial condition and results of operations.
Volatility in price and availability of raw materials can significantly impact our results of operations.
The manufacturing and processing of our consumable products requires significant amounts of raw materials. The price and availability of those raw materials can be impacted by factors beyond our control. Our consumable products, exclusive of lignite coal, use a variety of additives. Significant movements or volatility in the costs of additives could have an adverse effect on our working capital or results of operations. Additionally, we obtain certain raw materials from selected key suppliers. While we have inventory of such raw materials, if any of these suppliers are unable to meet their obligations with us on a timely basis or at an acceptable price, we may be forced to incur higher costs to obtain the necessary raw materials or be unable to obtain the materials.
We may attempt to offset the increase in raw material costs or challenges in the supply of raw materials with price increases allowed in our contractual relationships or through cost reduction efforts. If we are unable to fully offset the increased cost of raw materials through price increases, it could significantly impact our business, financial condition and results of operations.
We face operational risks inherent in mining operations and our mining operations have the potential to cause safety issues, including those that could result in significant personal injury.
We own the Five Forks Mine, a lignite coal mine located in Louisiana, thatwhich is operated for us by a third party. Mining operations by their nature involve a high level of uncertainty and are often affected by risks and hazards outside of our control. At the Five Forks Mine, the risks are primarily operational risks associated with the maintenance and operation of the heavy equipment required to dig and haul the lignite and risks relating to producing lower than expected lignite quality or recovery rates. The failure to adequately manage these risks could result in significant personal injury, loss of life, damage to mineral properties, production facilities or mining equipment, damage to the environment, delays in or reduced production and potential legal liabilities.
We also own the Marshall Mine, a former lignite coal mine located in Texas, which ceased mining operations in the third quarter of 2020 and is currently being reclaimed. Reclamation operations by their nature involve a high level of uncertainty and are often affected by risks and hazards outside of our control. At the Marshall Mine, the current risks are primarily operational risks associated with the maintenance and operation of the heavy equipment. The failure to adequately manage these risks could result in significant personal injury, loss of life, equipment, damage to the environment, delays in reclamation and potential legal liabilities.
Our operations and products are subject to extensive safety, health and environmental requirements that could increase our costs and/or impair our ability to manufacture and sell certain products.
Our ongoing operations are subject to extensive federal, state and local laws, regulations, rules and ordinances relating to safety, health and environmental matters, many of which provide for substantial monetary fines and potential criminal sanctions for violations. These include requirements to obtain and comply with various environmental-related permits for constructing any new facilities (or modifications to existing facilities) and operating all of our existing facilities. In addition, our AC manufacturing facilityRed River Plant may become subject to greenhouse gas emission trading schemesrequirements under which we may be required to purchase emission credits if our emission levels exceed our allocations. Greenhouse gas regulatory programs that have been adopted, such as cap-and-trade programs, have not had a significant impact on our business to date. Costs of complying with regulations could increase, as concerns related to greenhouse gases and climate change continue to emerge. The enactment of new environmental laws and regulations and/or the more aggressive interpretation of existing requirements could require us to incur significant costs for compliance or capital improvements or limit our current or planned operations, any of which could have a material adverse effect on our earnings or cash flow. We may attempt to offset the effects of these compliance costs through price increases, productivity improvements and cost reduction efforts, and our success in offsetting any such increased regulatory costs is largely influenced by competitive and economic conditions and could vary significantly depending on the market segment served. Such increases may not be accepted by our customers, may not be sufficient to compensate for increased regulatory costs or may decrease demand for our products and our volume of sales.
We may not be successful in achieving our growth expectations related to new products in our existing or new markets.
We may not be successful in achieving our growth expectations from developing new products for our existing or new markets. Further, we cannot ensure costs incurred to develop new products will result in an increase in revenues. Additionally, our ability to bring new products to the market will depend on various factors, including, but not limited to, solving potential technical or manufacturing difficulties, competition and market acceptance, which may hinder the timeliness and cost to bring such products to production. These factors or delays could affect our future operating results.
We may make futurenot be successful in realizing the benefits associated with our acquisitions, or formdispositions and strategic partnerships, and joint ventures thatour business could be adversely affected.
We have and may involve numerous risks that could impact our financial condition, results of operations and cash flows.
Our strategy may include expandingin the future expand the our scope of products, services, and services organically ortechnologies through selective acquisitions, investments or creating partnerships and joint ventures. We have acquired, and may selectively acquire, other businesses, product or service lines,also dispose of assets or technologiesportions of our business that are complementary tono longer complement our business. We may be unable to find or consummate future acquisitions at acceptable prices and terms, or we may be unable to integrate existing or future acquisitions effectively and efficiently and may need to divest those acquisitions.long-term strategic objectives. We continually evaluate potential acquisition, disposition, and strategic partnership opportunities in the ordinary course of business. Acquisitions, dispositions, and strategic partnerships involve numerous risks, including among others:
our evaluation•inability to negotiate favorable prices and terms;
•incorrect evaluations of the synergies and/or long-term benefits of an acquired business;the acquisition, disposition, and strategic partnership;
•integration difficulties, including challenges and costs associated with implementing systems, processes and controls to comply with the requirements of a publicly-traded company;
•diverting management’s attention;
•litigation arising from acquisition and disposition activity;
•potential increased debt leverage;
•potential issuance of dilutive equity securities;
•entering markets in which we have no or limited direct prior experience and where competitors in such markets have stronger market positions;
•unanticipated costs and exposure to undisclosed or unforeseen liabilities or operating challenges;
•potential goodwill or other intangible asset impairments;
•potential requirements to provide transition services in connection with a disposition, which may result in the diversion of resources and focus of management and employees;
•potential loss of key employees and customers of the acquired businesses, product or service lines, assets or technologies;
•our ability to properly establish and maintain effective internal controls over an acquired company; and
•increasing demands on our operational and IT systems.
The success of acquisitions of businesses, new technologies and products,an acquisition, disposition or arrangements with third partiesstrategic partnership is not always predictable, and we may not be successful in realizing our objectives as anticipated. The Senior Term Loananticipated, and our line of credit facility contain certain covenants that limit, or thatbusiness may have the effect of limiting, among other things, the payment of dividends, acquisitions, capital expenditures, the sale of assets and the incurrence of additional indebtedness.be adversely affected as a result.
Natural disasters could affect our operations and financial results.
We operate facilities, including the Red River Plant and Five Forks Mine, that are exposed to natural hazards, such as floods, windstorms and hurricanes. Extreme weather events present physical risks that may become more frequent as a result of factors related to climate change. Such events could disrupt our supply of raw materials or otherwise affect production, transportation and delivery of our products or affect demand for our products.
Additionally, weIn addition, extreme and unusually cold or hot temperatures throughout the U.S. could experienceresult in abnormally high loads on geographic electrical grids that could result in the failure of coal-fired power plants to produce electricity. If these plants were off-line for a prolonged disruption, interruption or other losssignificant period of operations attime, the demand for our manufacturing facility and headquarters as well as reduced travel and interactions with customers for any number of reasons, including the occurrence of a contagious disease or illness, such as the novel coronavirus (“COVID-19”). Due to the evolving and highly uncertain nature of this event, it is currently not possible to estimate the direct or indirect impacts this outbreak may have onproducts could be less, which would impact our business. However, if the COVID-19 were to develop into a global pandemic that disrupts the manufacturing of our product, commerce
and related activity, it could materially and adversely affect our results of operations and financial condition dueresults. Conversely, abnormally high loads on geographic electrical grids, resulting in increased demand of coal-fired power plants to theseproduce electricity, could impact our ability to meet customer contracts and other potential consequences of a pandemic.demands.
Information technology vulnerabilities and cyberattacks on our networks could have a material adverse impact on our business.
We rely uponon information technology ("IT") to manage and conduct business, both internally and externally, with our customers, suppliers and other third parties. Internet transactions involve the transmission and storage of data including, in certain instances, customer and supplier business information. Therefore, maintaining the security of computers and other electronic devices, computer networks and data storage resources is a critical issue for us and our customers and suppliers because security breaches could result in reduced or lost ability to carry on our business and loss of and/or unauthorized access to confidential information.
We have limited personnel and other resources to address information technology reliability and security of our computer networks and to respond to known security incidents to minimize potential adverse impact. Experienced hackers, cybercriminals and perpetrators of threats may be able to penetrate our network security and misappropriate or compromise our confidential information or that of third parties, create system disruptions or cause shutdowns. These perpetrators of cyberattacks also may be able to develop and deploy viruses, worms, malware and other malicious software programs that attack our information and networks or otherwise exploit any security vulnerabilities of our information and networks.
Techniques used to obtain unauthorized access to or sabotage systems change frequently and often are not recognized until long after beingthey are launched against a target, and we may be unable to anticipate these techniques or to implement adequate preventative measures. A breach of our IT systems and security measures as a result of third party action, malware, employee error, malfeasance or otherwise could materially adversely impact our business and results of operations and expose us to customer, supplier and other third party liabilities.
Risks relating to Refined Coal
The ability of Tinuum Group to continue to generate revenues from the sale or lease of RC facilities to tax equity investors is not assured, and the inability to sell, lease or operate RC facilities to produce and sell RC and generate Section 45 production tax credits could adversely affect our future growth and profitability.
Tinuum Group has successfully sold and leased RC facilities to third party investors and is continuing its efforts to sell or lease new RC facilities in the near term. The inability of Tinuum Group to successfully lease or sell additional RC facilities to third party tax equity investors who qualify to receive the benefit of the Section 45 tax credits that are expected to be generated from those RC facilities, as well as the termination or cancellation of existing RC facility leases in the near term, would likely have an adverse effect on our future growth and profitability.
Furthermore, if, in the near term, electricity power generators decide to limit coal-fired generation for economic reasons such as cheaper alternative power sources or are forced to limit coal-fired generation under environmental regulations or other legal statutes, this could also lessen the production and use of RC. This in turn would likely negatively impact Tinuum Group's ability to attract additional investors in RC facilities over the currently anticipated term of the Section 45 tax credit program, which in turn would negatively impact its business, financial condition and results of operations.
The ability to generate Section 45 tax credits from existing operating RC facilities ends in 2021, which could eliminate the desire for investors to lease further RC facilities beyond this date. This would effectively eliminate Tinuum Group’s and Tinuum Services' operations and significantly impact our financial condition and results of operations beyond 2021.
Substantially all of our earnings and cash flows in 2019 and 2018 are comprised of equity method earnings from Tinuum Group and license royalties generated from certain of Tinuum Group’s invested RC facilities. For the year ended December 31, 2019, our RC segment generated segment operating income of $83.5 million. As of December 31, 2019, Tinuum Group has 20 invested facilities and zero retained facilities. Absent a modification to the Section 45 tax credit program, the 20 invested facilities will no longer generate Section 45 tax credits beyond 2021. As a result, we believe that substantially all of the invested RC facilities will be returned to Tinuum Group upon the expiration of the Section 45 tax credit program. If Tinuum Group continues to operate these RC facilities, if any, its earnings will be significantly reduced and accordingly, our pro rata share will also be substantially reduced.
Additionally, our RC segment is the larger of our two segments, and the remainder of our business must grow substantially, either organically or acquisitively, in order to replace earnings from Tinuum Group that will substantially end during the 2021. There can be no assurance that we will be able to increase our PGI segment earnings during this period to cover our current operating expenses or to provide a return to shareholders that is comparable to the return currently provided by our RC segment. If we are not able to cover operating expenses, we could be forced to raise additional capital, significantly reduce our operating expenses or take other alternative actions.
The 2017 Tax Act introduced changes in income tax rates and other specific provisions that may make Section 45 production tax credits less attractive, which, in turn, could adversely affect our results of operations or financial condition.
On December 22, 2017, the Tax Cuts and Jobs Act of 2017 (the "2017 Tax Act") became law. The 2017 Tax Act, among other things, lowered the federal income tax rate on corporations from 35% to 21%, effective for the year beginning January 1, 2018 and created certain new tax provisions, including the Base Erosion and Anti-Abuse tax ("BEAT"). In December 2019, the U.S. Treasury Department and the Internal Revenue Service issued final and proposed regulations on BEAT under Internal Revenue Code Section 59A (the "final BEAT regulations") and the "2019 proposed regulations," respectively). The final BEAT regulations are generally consistent with the proposed BEAT regulations released on December 13, 2018 but adopted several changes. Most notably, the final BEAT regulations generally exclude from the base erosion payment definition amounts transferred to a foreign-related party in certain specified nonrecognition transactions. The 2019 proposed regulations would also allow taxpayers to elect to forego a deduction so that it is not taken into account as a base erosion tax benefit so long as the deduction is waived for all US income tax purposes. In general, the final BEAT regulations apply to tax years ending on or after December 17, 2018, and the 2019 proposed regulations generally would apply to tax years beginning on or after the date that regulations finalizing those rules are published. However, taxpayers may rely on the 2019 proposed regulations in their entirety for tax years beginning after December 31, 2017 and before the regulations are finalized. The changes to previously higher tax rates and provisions such as BEAT could negatively impact tax capacity of current or potential tax equity investors and result in Section 45 production tax credits being less attractive.
Presently, the GS Affiliates account for a substantial portion of earnings for Tinuum Group and any further lease renegotiation or termination by the GS Affiliates or any failure to continue to produce and sell RC at the GS Affiliates' RC facilities would have a material adverse effect on our business.
As of December 31, 2019, eightof Tinuum Group’s 26 RC facilities are leased to the GS Affiliates. Significant components of our total cash flows come from Tinuum Group's distributions relating to payments received under these leases. These leases have an initial fixed period and then automatically renew, unless terminated at the option of the lessee, for successive one-year terms through 2021. In September 2019, Tinuum Group restructured all of the existing leases with the GS Affiliates, which resulted in a decrease in net lease payments for the balance of 2019 and will result in lower net lease payments for 2020 and 2021. If the GS Affiliates further renegotiate or terminate their leases, or if the utilities where the RC facilities are installed materially reduce their use of RC, these events would have a material adverse effect on our business, results of operations or financial condition.
Our RC businesses are joint ventures and managed under operating agreements where we do not have sole control of the decision-making process, and we cannot mandate decisions or ensure outcomes.
We oversee our joint ventures under the terms of their respective operating agreements by participating in the following activities: (1) representation on the respective governing boards of directors, (2) regular oversight of financial and operational performance and controls and establishing audit and reporting requirements, (3) hiring of management personnel, (4) technical support of RC facilities, and (5) other regular and routine involvement with our joint venture partners. Notwithstanding this regular participation and oversight, our joint venture partners also participate in the management of these businesses and they may have business or economic interests that divert their attention from the joint venture, or they may prefer to operate the business, make decisions or invest resources in a manner that is contrary to our preferences. Since material business decisions must be made jointly with our joint venture partners, we cannot mandate decisions or ensure outcomes.
The financial effects of Tinuum Group providing indemnification under performance guarantees of its RC facilities are largely unknown and could adversely affect our financial condition.
Tinuum Group indemnifies certain utilities and lessees of RC facilities for particular risks associated with the operations of those facilities. We have provided limited, joint and several guarantees of Tinuum Group’s obligations under those leases. Any substantial payments made under such guarantees could have a material adverse effect on our financial condition, results of operations and cash flows.
Risks related to intellectual property
Failure to protect our intellectual property or infringement of our intellectual property by a third party could have an adverse impact on our financial condition.
We rely on a combination of patent, copyright and trademark laws, trade secrets, confidentiality procedures and contractual provisions to protect our proprietary rights. Such means of protecting our proprietary rights may not be adequate because they provide only limited protection or such protection may be prohibitively expensive to enforce. We also enter into confidentiality and non-disclosure agreements with our employees, consultants and many of our customers and vendors, and generally control access to and distribution of our proprietary information. Notwithstanding these measures, a third party could copy or otherwise obtain and use our proprietary information without authorization. We cannot provide assurance that the steps we have taken will prevent misappropriation of our technology and intellectual property, which could negatively impact our business and
financial condition. In addition, such actions by third parties could divert the attention of our management from the operation of our business.
We may be subject to intellectual property infringement claims from third parties that are costly to defend and that may limit our ability to use the disputed technologies.
If our technologies are alleged to infringe the intellectual property rights of others, we may be forced to mount a defense to such claims, which may be expensive and time consuming. During the pendency of litigation, we could be prevented from marketing and selling existing products or services and from pursuing research, development or commercialization of new or complimentary products or services. Further, we may be required to obtain licenses to third party intellectual property or be forced to develop or obtain alternative technologies. Our failure to obtain a license to a technology that we may require, or the need to develop or obtain alternative technologies, could significantly and negatively affect our business.
Indemnification of third partythird-party licensees of our technologies against intellectual property infringement claims concerning our licensed technology and our products could be financially significant to us.
We have agreed to indemnify licensees of our technologies (including Tinuum Group) and purchasers of our products, and we may enter into additional agreements with others under which we agree to indemnify and hold them harmless from losses they may incur as a result of the alleged infringement of third partythird-party rights caused by the use of our technologies and products. Infringement claims, which are expensive and time-consuming to defend, could have a material adverse effect on our business, operating results and financial condition, even if we are successful in defending ourselves (and the indemnified parties) against them.
Our future success depends in part on our ongoing identification and development of intellectual property and our ability to invest in and deploy new products, services and technologies into the marketplace efficiently and cost effectively.
The process of identifying customer needs and developing and enhancing products, services and solutions for our business segments is complex, costly and uncertain. Any failure by us to identify and anticipate changing needs, emerging trends and new regulations could significantly harm our future market share and results of operations.
Risk related to tax matters
An “ownership change”"ownership change" could limit our ability to utilize tax loss and credit carryforwards to offset future taxable income.
We have certain general business credit tax credits ("Tax Credits"). As of December 31, 2019,2021, we had $98.5$86.1 million of Tax Credits, equaling 92%87% of our total gross deferred tax assets. Our ability to use these Tax Credits to offset future taxable income may be significantly limited if we experience an "ownership change" as discussed below. Under the Internal Revenue Code ("IRC') and regulations promulgated by the U.S. Treasury Department, we may carry forward or otherwise utilize the Tax Credits in certain circumstances to offset any current and future taxable income, and thus reduce our federal income tax liability, subject to certain requirements and restrictions. To the extent that the Tax Credits do not otherwise become limited, we believe that we will have available a significant amount of Tax Credits in future years, and therefore the Tax Credits could be a substantial asset to us. However, if we experience an "ownership change," as defined in SectionSections 382 and 383 of the IRC, our ability to use the Tax Credits may be substantially limited, and the timing of the usage of the Tax Credits could be substantially delayed, which could therefore significantly impair the value of that asset.
In general, an "ownership change" under SectionSections 382 and 383 occurs if the percentage of stock owned by an entity’s 5% stockholders (as defined for tax purposes) increases by more than 50 percentage points over a rolling three-year period. An entity that experiences an ownership change generally will be subject to an annual limitation on its pre-ownership change tax loss and credit carryforwards equal to the equity value of the entity immediately before the ownership change, multiplied by the long-term, tax-exempt rate posted monthly by the IRS (subject to certain adjustments). The annual limitation would be increased each year to the extent that there is an unused limitation in a prior year. The limitation on our ability to utilize the Tax Credits arising from an ownership change under SectionSections 382 and 383 of the IRC would depend on the value of our equity at the time of any ownership change. If we were to experience an "ownership change," it is possible that a significant portion of our tax credit carryforwards could expire before we would be able to use them to offset future taxable income.
On May 5, 2017, our Board of Directors (the "Board") approved the Tax Asset Protection Plan (the "Protection Plan""TAPP") and declared a dividend of one preferred share purchase right (each, a "Right") for each outstanding share of our common stock. The Protection Plan TAPP
was adopted in an effort to protect stockholder value by attempting to diminish the risk that our ability to use the Tax Credits to reduce potential future federal income tax obligations may become substantially limited.
On April 9, 2021, the Board approved the Fourth Amendment to the TAPP ("Fourth Amendment") that amends the TAPP, as previously amended by the First, Second and Third Amendments that were approved the Board on April 6, 2018, April 5, 2019 and April 9, 2020, respectively. The Fourth Amendment amends the Board approved amendingdefinition of "Final Expiration Date" under the Protection Plan as previously amendedTAPP to extend the duration of the Protection PlanTAPP and makes associated changes in connection therewith. At the Company's 20192021 annual meeting of stockholders, the Company's stockholders approved that amendment;the Fourth Amendment, thus the final expiration dateFinal Expiration Date will be the close of business on December 31, 2020.2022.
The Protection Plan,TAPP, as amended, is intended to act as a deterrent to any person acquiring beneficial ownership of 4.99% or more of our outstanding common stock without the approval of the Board. Stockholders who beneficially owned 4.99% or more of our outstanding common stock upon execution of the Protection Plan will not trigger the Protection Plan so long as they do not acquire beneficial ownership of additional shares of our common stock. The Board may, in its sole discretion, also exempt any person from triggering the Protection Plan.
Risks relatingrelated to our common stock
Our stock price is subject to volatility.
The market price of our common stock has experienced substantial price volatility in the past and may continue to do so. The market price of our common stock may continue to be affected by numerous factors, including:
a.actual or anticipated fluctuations in our operating results and financial condition;
b.changes in laws or regulations and court rulings and trends in our industry;
Tinuum Group’s ability to lease or sell RC facilities;
c.announcements of sales awards;
d.changes in supply and demand of components and materials;
e.adoption of new tax regulations or accounting standards affecting our industry;
f.changes in financial estimates by securities analysts;
g.perceptions of the value of corporate transactions;
h.trends in social responsibility and investment guidelines;
our ability to continue to bei.whether we are able and elect to pay cash dividends;
j.the numbercontinuation of repurchasing shares of common stock repurchased under stock repurchase programs; and
k.the degree of trading liquidity in our common stock and general market conditions.
From January 1, 20182020 to December 31, 2019,2021, the closing price of our common stock ranged from $7.69$3.76 to $14.84$12.49 per share. In June 2017, we commenced a quarterly cash dividend program and have paid out cash dividends in each succeeding quarter through DecemberMarch 31, 2019.2020. In 2018, and 2019, we implemented stock repurchase programs, and repurchased a total of 2,883,76720,613 shares of our common stock during these twofor the fiscal years 2021 and 2020 for cash of $31.1$0.2 million.
Stock price volatility over a given period may cause the average price at which we repurchase shares of our common stock to exceed the stock’s price at a given point in time. We believe our stock price should reflect expectations of future growth and profitability. Future dividends are subject to declaration by the Board, and under our current stock repurchase program, we are not obligated to acquire any specific number of shares. If we fail to meet expectations related to future growth, profitability, dividends, stock repurchases or other market expectations, our stock price may decline significantly, which could have a material adverse impact on our ability to obtain additional capital and erode investor confidence, and employee retention, andwhich could further reduce the liquidity of our common stock. We do not expect to repurchase additional shares of our common stock in the near term.
There can be no assurance that we will continueWe are unlikely to declareresume our quarterly cash dividends at all or in any particular amounts.dividend program.
The Board first approved a $0.25 per share of common stock quarterly dividend in June 2017. During 2018 and 2019,We last paid a cash dividend on March 10, 2020.
With the ceasing of our cash-generating RC segment, it is unlikely, for the foreseeable future, that we declaredwill resume declaring quarterly dividends in the aggregate amount of $38.8 million. We intend to continue to pay quarterly dividends subject to capital availability, compliance with debt covenants and periodic determinations by the Board that cash dividends are in the best interest of our stockholders and are in compliance with all laws and agreements applicable to the declaration and payment of cash dividends by us.
under a dividend program. The payment of future dividends may alsowill be affected by, among other factors, compliance with debt covenants;factors: (1) our views on potential future capital requirements for investments in acquisitions; (2) legal risks; (3) stock repurchase programs; (4) changes in federal and state income tax laws or corporate laws; (5) changes to our business model; and our increased interest and principal payments required by the Senior Term Loan and(6) any additional indebtedness that we may incur in the future.
Under covenants in the Senior Term Loan, annual collective dividends and repurchases of our common stock in the aggregate may not exceed $30 million, and shall be permitted so long as (a) no default or event of default exists under the Senior Term Loan and (b) expected future net cash flows from the refined coal business as of the end of the most recent fiscal quarter exceed $100 million. Based on our current forecasts, we anticipate that future net cash flows from the refined coal business will be below the $100 million minimum requirement as of the third fiscal quarter of 2020, which would preclude us from paying dividends or repurchasing our common stock at that time, absent a modification to the Senior Term Loan.
Our dividend payments may change from time to time, and we cannot provide assurance that we will continue to declare dividends at all or in any particular amounts. A reduction in our dividend payments could have a negative effect on our stock price.
Our certificate of incorporation and bylaws contain provisions that may delay or prevent an otherwise beneficial takeover attempt of us.
Certain provisions of our certificate of incorporation and bylaws could make it more difficult for a third party to acquire us, even if doing so would be beneficial to our stockholders. These include provisions that:
a.Limit the business at special meetings of stockholders to the purpose stated in thea notice of the meeting;
b.Authorize the issuance of "blank check" preferred stock, which is preferred stock with voting or other rights or preferences that could impede a takeover attempt and that the Board can create and issue without prior stockholder approval;
c.Establish advance notice requirements for submitting nominations for election to the Board and for proposing matters that can be acted upon by stockholders at a meeting; and
d.Require the affirmative vote of the "disinterested" holders of a majority of our common stock to approve certain business combinations involving an "interested stockholder" or its affiliates, unless either minimum price criteria or procedural requirements are met, or the transaction is approved by a majority of our "continuing directors" (known as "fair price provisions").
These provisions, alone or in combination with each other, may discourage transactions involving actual or potential changes of control, including transactions that otherwise could involve payment of a premium over prevailing market prices to holders of our common stock, or could limit the ability of our stockholders to approve transactions that they may deem to be in their best interest.
An increased focus on environmental, social and governance factors by institutional investors may negatively impact our access to capital and the liquidity of our stock price.
Some institutional investors including our largest shareholder, have recently adopted Environmental, Social and Governance ("ESG") investing guidelines that may prevent them from increasing or taking new stakes with companies with exposure to fossil fuels. Additional institutional investors may adopt similar ESG investment guidelines. This could limit both the demand for owning our common stock and/or our access to capital. If such capital is desired, we cannot assure you that we will be able to obtain any additional equity or debt financing on terms that are acceptable to us. Given these emerging trends, liquidity in our common stock and our stock price may be negatively impacted.
We may require additional funding for our growth plans, and such funding may require us to issue additional shares of our common stock, resulting in a dilution of your investment.
We estimate our funding requirements in order to implement our growth plans. If the actual funding required to implement growth plansinitiatives should exceed thesefunding estimates significantly, or if we come across opportunities to grow through expansion plans which cannot be predicted at this time, and our funds generated from our operations from such growth initiatives prove insufficient for such purposes, we may need to raise additional funds to meet these funding requirements.
These additional funds may be raised by issuing equity or debt securities or by borrowing from banks or other resources. We cannot assure you that we will be able to obtain any additional financing on terms that are acceptable to us, or at all. If we fail to obtain additional financing on terms that are acceptable to us, we willmay not be able to implement such plans fully. Such financing, even if obtained, may be accompanied by conditions that limit our ability to pay dividends or require us to seek lenders’ consent for payment of dividends, or restrict our freedomability to operate our business by requiring lender’s consent for certain corporate actions. Further, if we raise additional funds through the issuance of new shares of our common stock, any shareholders who are unable or unwilling to participate in such an additional round of fund raising may suffer dilution of their investment.
Item 1B. Unresolved Staff Comments
None.
Item 2. Properties
OfficesOffice and Facilities
We lease approximately 24,000 square feet of office space in Highlands Ranch,Greenwood Village, Colorado for our corporate headquarters. Also, in Colorado, we lease additional office, warehouse and laboratory space. Total combined leased space for these facilities is approximately 32,000 square feet. We also lease or own manufacturing, storage and distribution facilities in Louisiana. Our manufacturing plant sits on
approximately 59 acres and the remaining facilities are comprised of a total of approximately 310,000 square feet. All of the facilities located in Louisiana are included in our PGI segment and Corporate and other.
In August 2019, we entered into a new lease for our corporate headquarters and primary laboratory (approximately 21,000 square feetresearch and development laboratory.
We own our manufacturing plant, which is located on approximately 59 acres in Greenwood Village, Colorado).Coushatta, Louisiana. We expect to occupy this new facility beginningalso lease 6.9 acres in March 2020, at which pointNatchitoches Parish, Louisiana where we will no longer occupy the previously leased space in Coloradooperate a manufacturing and distribution facility.
The APT segment of approximately 32,000 square feet.our business utilizes all of our office and facilities space.
Mining
The APT segment of our business utilizes all of our mining and mining-related properties.
As of December 31, 2019,2021, we owned or controlled primarily through long-term leases approximately 2,2794,425 acres of coal land for surface miningmining. Of those acres, approximately 1,975 acres are located in the Gulf Coast Lignite Region, in Natchitoches Parish, Louisiana ("Five Forks"). The majority of the Five Forks land is leased for mineral rights and right-of-use purposes that expire at varying dates over the next 30 years and contain options to renew. The remaining land is owned by us.
Under our current mining plans, substantially all leased reserves will be mined out within the period of existing leases or within the time period of assured lease renewals. Royalties are paid to lessors either as a fixed price per ton or as a percentage of the gross sales price of the mined coal. The majority of the significant leases are on a percentage royalty basis. In some cases, a payment is required either at the time of execution of the lease or in annual installments. In most cases, the prepaid royalty amount is applied to reduce future production royalties.
On October 31, 2018, the SEC issued new rulesThe remaining 2,450 acres (of 4,425 acres of coal land for disclosures under this Item for mining registrants. These rules amend Item 102 of Regulation S-K under the Securities Act and the Exchange Act and rescind Industry Guide 7 to direct mining registrants, and create a new subpart of Regulation S-K, which contains all of the requirements for property disclosures by mining registrants from and after January 1, 2021 (the "Mining Disclosures"). The Mining Disclosures became effective on February 25, 2019 and allow mining registrants a transition period through January 1, 2021 to comply. We elected to adopt the Mining Disclosures effective February 25, 2019 and were subjectsurface mining) pertain to the requirements effective withMarshall Mine, which is located in Harrison and Panola Counties, Texas. Mining operations on this land ceased in the filingthird quarter of our Annual Report on Form 10-K for the fiscal year ended December 31, 2019. 2020.
Based on the materiality and the vertically-integrated company guidelines contained in Regulation S-K of the Mining Disclosures,Securities Act and the Exchange Act, we have concluded that no additional disclosures related to our mining operations are required under this Item.
Item 3. Legal Proceedings
From time to time, we are involved in various litigation matters arising in the ordinary course of our business. Information with respect to this item may be found in Note 914 "Commitments and Contingencies" to the consolidated financial statementsConsolidated Financial Statements included in Item 8 of this Report.
Item 4. Mine Safety Disclosures
The statement concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K is included in Exhibit 95 to this Report.
PART II
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Market for Our Common Stock
As of December 31, 2019,2021, our common stock was quoted on the NASDAQNasdaq Global Market under the symbol "ADES." The trading volume for our common stock is relatively limited. There is no assurance that an active trading market will provide adequate liquidity for our existing stockholders or for persons who may acquire our common stock in the future.
Dividends
In June 2017, we commenced a quarterly cash dividend program of $0.25 per common share.share and made our most recent payment in March 2020. Currently, we do not plan to recommence a quarterly cash dividend program in the near term.
WeIn the future, we may continue to declare and pay a cash dividend on shares of our common stock on a quarterly basis.stock. Whether we do, however, and the timing and amounts of dividends will be subject to approval and declaration by the Board and will depend on a variety of factors including, but not limited to, our financial results, cash requirements, financial condition compliance with loan covenants and other contractual restrictions and other factors considered relevant by the Board, and will be subject to limitations imposed under Delaware law.
Holders
The number of holders of record of our common stock as of March 6, 2020February 25, 2022 was approximately 800.900. The approximate number of beneficial stockholders is estimated at 7,800.
Purchases of Equity Securities by the Company and Affiliated Purchasers
In November 2018,We had no repurchases of our common stock for the Board authorizedthree months ended December 31, 2021.
We maintain a program for us to repurchase up to $20.0 million of shares of our common stock under a stock repurchase program (the "Stock Repurchase Program") through open market transactions at prevailing market prices. As of September 30, 2019, the Company had $2.9 million remaining under this program. In November 2019, theThe Board subsequently approved an amendment to The Stock Repurchase Program in which it authorized an incremental $7.1 million, resulting in a total of $10.0 million of shares of our common stock allowable to thisrepurchase. As of December 31, 2021, $7.0 million of shares of our common stock remained outstanding for repurchase program and provided thatunder the programStock Repurchase Program, which will remain in effect until all amounts are utilized or the programit is otherwise modified by the Board. The following table summarizes the common stock repurchase activity for the three months ended December 31, 2019:
|
| | | | | | | | | | | | | | |
| Period | | (a) Total number of shares (or units) purchased | | (b) Average price paid per share (or unit) | | (c) Total number of shares (or units) purchased as part of publicly announced programs | | (d) Maximum number (or approximate dollar value) of shares (or units) that may yet be purchased under the plans or programs (in thousands) |
| October 1 to 31, 2019 | | — |
| | $ | — |
| | — |
| | $ | — |
|
| November 1 to 30, 2019 | | 144,615 |
| | 10.36 |
| | 144,615 |
| | — |
|
| December 1 to 31, 2019 | | 131,987 |
| | 10.37 |
| | 131,987 |
| | 7,134 |
|
| Total | | 276,602 |
| | | | 276,602 |
| | $ | 7,134 |
|
Item 6. Selected Financial DataReserved
The information under this Item is not required to be provided by smaller reporting companies.
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations
Overview
This Form 10-K for the year endedThrough December 31, 20192021, we operated two segments: RC and APT. Our RC segment is filed by Advanced Emissionscomprised of our equity ownership in Tinuum Group and Tinuum Services, both of which are unconsolidated entities from which we generated substantial earnings. Tinuum Group provides reduction of mercury and NOx emissions at select coal-fired power generators through the production and sale of RC that qualifies for Section 45 tax credits under IRC Section 45. We benefited from Tinuum Group's production and sale of RC, which generated Section 45 tax credits, as well as its revenue from selling or leasing RC facilities to tax equity investors. We also earned royalties for technologies that we licensed to Tinuum Group, which were used at certain RC facilities to enhance combustion and reduce emissions of NOx and mercury from coal burned to generate electrical power. Tinuum Services operated and maintained the RC facilities under operating and maintenance agreements with Tinuum Group and owners or lessees of the RC facilities. Effective December 31, 2021, the Section 45 tax credit period expired and as a result both Tinuum Group and Tinuum Services have substantially ceased their operations. As such, our earnings and distributions from our RC segment substantially ceased as of December 31, 2021. We expect to receive limited, additional cash distributions from Tinuum Group and Tinuum Services during the first half of 2022.
Our APT segment is primarily comprised of operations of our wholly-owned subsidiary, Carbon Solutions, Inc. together with its consolidated subsidiaries (collectively, "ADES," the "Company," "we," "us," or "our" unless the context indicates otherwise).
which we acquired on December 7, 2018. We are a leader in emissions reductions technologies through consumablessell consumable products that utilize powdered activated carbon (“PAC”)AC and chemical based technologies primarily serving theto a broad range of customers, including coal-fired power generationutilities, industrials, water treatment plants and industrial boiler industries.other diverse markets. Our primary products are comprised of AC, which is produced from lignite coal. Our AC products include PAC and GAC. Our proprietary environmental technologies and specialty chemicalsassociated product offerings provide purification solutions to enable our customers to reduce emissions of mercurycertain contaminants and other pollutants maximize utilization levels and improve operating efficiencies to meet the challenges of existing and potential emissions control regulations. Additionally, we own an associated lignite mine which supplies the primary raw material for manufacturing our products.
See further discussion of our business included in Item 1 -"Business" ("Item 1") of this Report. Discussion regarding segment information is included in the discussion of our consolidated results under this Item 7. Additionally, discussion related to our reportable segments is included in Item 1 and Note 1519 of the Consolidated Financial Statements, which is included in Item 8 of this Report.
On December 7, 2018 (the “Acquisition Date”),We believe there are opportunities and are continuing to pursue diverse markets for our purification products outside of coal-fired power generation, including industrial applications and water. The Supply Agreement with Cabot, as discussed below, continues to expand sales of our AC products to those diverse end-markets and drive the Company’s post-Refined Coal future.
Review of Strategic Alternatives
In May 2021, we acquired allannounced that we had retained Ducera Partners, LLC as our financial advisor to assist in a strategic review process to assess a range of strategic alternatives to enhance value for our stockholders. We cannot provide any assurance that the exploration of strategic alternatives will result in the identification or consummation of any transaction. Similarly, any strategic decision will involve risks and uncertainties, and we cannot provide any assurance that any strategic alternative, if identified, evaluated and consummated, will provide the anticipated benefits or otherwise enhance stockholder value. The process is ongoing and our board of directors has not set a timetable for completion of the outstanding equity interests (the "Carbon Solutions Acquisition”) of ADA Carbon Solutions, LLC (“CS” or “Carbon Solutions”). Carbon Solutions is an activated carbon company and the North American leader in mercury capture using PAC for the coal-fired power plant, industrial and water treatment markets. Carbon Solutions owns and operates an activated carbon ("AC") manufacturing and processing facility. It also owns an associated lignite mine ("Five Forks Mine") that supplies the raw material for the powdered activated carbon plant. Our operating results for 2018 include the operating results of Carbon Solutions for the period from the Acquisition Date to December 31, 2018.
On December 7, 2018, ADES and ADA-ES, Inc. ("ADA"), a wholly-owned subsidiary, and certain other subsidiaries of the Company as guarantors, The Bank of New York Mellon as administrative agent, and Apollo Credit Strategies Master Fund Ltd. and Apollo A-N Credit Fund (Delaware) L.P. (collectively "Apollo"), affiliates of a beneficial owner of greater than five percent of the Company's common stock and related parties, entered into the Term Loan and Security Agreement (the "Senior Term Loan") in the principal amount of $70.0 million, less original issue discount of $2.1 million. Proceeds from the Senior Term Loan were used to fund the Carbon Solutions Acquisition.evaluation.
Drivers of Demand and Key Factors Affecting Profitability
Drivers of demand and key factors affecting our profitability differ by segment. InHistorically, we derived substantial earnings and cash distributions from the Refined Coal ("RC')RC segment demand is driven primarily bythrough our equity ownership in Tinuum Group and Tinuum Services as well as the Internal Revenue Code ("IRC") Section 45 - Production Tax Credit ("royalties earned from a licensing arrangement with Tinuum Group for use of our M-45 Technology. With the expiration of the Section 45 tax credits"), which is expectedcredit period, we will no longer generate earnings from either Tinuum Group or Tinuum Services. Additionally, we do not expect our overall selling, general and administrative portions of our operating expenses to expire no later than December 31, 2021. Operating resultsmaterially decrease in 2022 as a result of the wind down of our RC have been influenced by: (1)segment.
Demand in the ability to sell, lease or operate RC facilities; (2) lease renegotiation or termination; and (3) changes in tonnage of RC due to changing coal-fired dispatch and electricity power generation sources.
In the Power Generation and Industrials ("PGI")APT segment demand is driven primarily by consumables-based solutions for coal-fired power generation, municipal water treatment and other industrials.industrial customers; and since the fourth quarter of 2020, demand from Cabot's customers through the Supply Agreement discussed below. Operating results in PGI hasthe APT segment have been influenced by: (1) changes in our sales volumes; (2) changes in price and product mix; (3) changes related to non-integrated supply chain inputs and (3)(4) changes in coal-fired dispatch and electricity power generation sources. For the year ended December 31, 2021, we observed significant
increases in demand for our AC product. As such, we continue to purchase inventory to meet our customer demands to supplement products manufactured at our Red River Plant.
Customer Supply Agreement
On September 30, 2020, we and Cabot entered into the Supply Agreement, pursuant to which we agreed to sell and deliver to Cabot, and Cabot agreed to purchase and accept from us, Furnace Products. The term of the Supply Agreement is for 15 years with 10-year renewal terms that are automatic unless either party provides three years prior notice of intention not to renew before the end of any term.
The Supply Agreement has provided material incremental volume and allowed us to capture operating cost efficiencies at our Red River manufacturing plant. The incremental volumes from the Supply Agreement have improved fixed cost absorption and resulted in increased gross margins. Further, the Supply Agreement has expanded our AC products to diverse end markets that are outside of markets we historically served.
Acquisition of Marshall Mine
Concurrently with the execution of the Supply Agreement, on September 30, 2020, we entered into the Mine Purchase Agreement from Cabot for 100% of the membership interests in Marshall Mine, LLC (the "Marshall Mine Acquisition") for a nominal purchase price. Marshall Mine, LLC owns a lignite mine located outside of Marshall, Texas (the "Marshall Mine"). We independently determined to immediately commence activities to shutter the Marshall Mine and to incur the associated reclamation costs.
In conjunction with the execution of the Supply Agreement and the Mine Purchase Agreement, on September 30, 2020, we entered into the Reclamation Contract with a third party that provides a capped cost, subject to certain contingencies, in the amount of approximately $19.7 million plus an obligation to pay certain direct costs of approximately $3.6 million (collectively, the "Reclamation Costs") over the estimated reclamation period of 10 years. Under the terms of the Supply Agreement, Cabot is obligated to reimburse us for approximately $10.2 million of Reclamation Costs (the "Reclamation Reimbursement"), which are payable semi-annually over 13 years and inclusive of interest.
On February 25, 2022, we received $10.6 million in cash from Cabot (the "Cabot Payment") as a result of a change in control provision in the Supply Agreement (the "Change in Control"), which occurred as a result of the sale of Cabot by its parent, Cabot Corporation. Under the Change in Control, we received from Cabot full payment of all amounts outstanding under the Reclamation Reimbursement, payment of all unbilled amounts related to certain capital expenditures incurred by us through February 28, 2022 for specific use in manufacturing Furnace Products and payment of additional Reclamation Costs (the "Cabot Reclamation Costs"). Under the Reclamation Contract, we are obligated to remit payment for the Cabot Reclamation Costs to the third party operator of Marshall Mine within a specified timeframe. We will account for the Cabot Payment in its March 31, 2022 quarter and we do not anticipate any impacts to the Supply Agreement except as described above.
As the owner of the Marshall Mine, we were required to post a surety bond to ensure performance of our reclamation activities. As of December 31, 2021, the amount outstanding under this surety bond was $16.6 million. For the obligations due under the Reclamation Contract, we were required to post collateral of $10.0 million.
As of June 30, 2021 and December 31, 2021, we revised our estimate of future obligations owed for reclamation of the Marshall Mine primarily based on scope reductions related to future reclamation requirements. As a result, we reduced the Marshall Mine ARO by $1.9 million and $0.8 million as of June 30, 2021 and December 31, 2021, respectively, and recorded a corresponding gain on change in estimate in the aggregate of $2.7 million in the Consolidated Statements of Operations for the year ended December 31, 2021.
Settlement with Former Customer
On December 29, 2020, we and a former customer (the "Parties") reached a settlement (the "Settlement") on various litigation matters (the "Litigation Matters") that resulted in the former customer (the "Former Customer") agreeing to pay to us cash of $2.5 million (the "Settlement Amount"), which was received on January 27, 2021. This payment was in exchange for full dissolution of all claims and counterclaims that the two Parties have asserted or could have asserted against each other in the Litigation Matters, or which have arisen or may arise against each other but are presently unknown, arising out of or related to the Litigation Matters and related to any other of the Parties’ business dealings, conduct and/or transactions through the date of the Settlement, including all claims for damages, fees, costs, sanctions, or any other amounts due or to become due in connection with the foregoing. We applied the Settlement Amount cash proceeds to both an outstanding trade account
receivable and a note receivable due from the Former Customer and recognized the excess cash received as a gain from the Settlement of $1.1 million, which is included as a reduction of operating expenses for the year ended December 31, 2020, See further discussion under "Results of Operations" under this Item 7.
Impact of COVID-19
In March 2020, the World Heath Organization declared COVID-19 a global pandemic. We follow the COVID-19 guidelines from the Centers for Disease Control concerning the health and safety of our personnel, including remote working for those that have the ability to do so, sequestered employees at our plant and other heath safety measures. Additionally, we have taken proactive and precautionary steps to ensure the safety of our employees, customers and suppliers, including frequent cleaning and disinfection of workspaces, property, plant and equipment, instituting social distancing measures and mandating remote working environments, where possible, for all employees.
In response to the COVID-19 outbreak, in March 2020, the federal government passed the Coronavirus Aid, Relief, and Economic Security Act (the "CARES Act"). The CARES Act provided, among other things, the deferral of payroll tax payments for all payroll taxes incurred through December 31, 2020 and created the Paycheck Protection Program ("PPP"), which was sponsored and administered by the Small Business Administration ("SBA"). In June 2020, the Paycheck Protection Program Flexibility Act of 2020 (the "PPPFA") was signed into law and established the payment dates in the event that amounts borrowed under the PPP are not forgiven. See further discussion below of the loan made to us under the PPP under the section "PPP Loan" under this Item.
We elected to defer payments of payroll taxes of $0.4 million for the periods allowed under the CARES Act, which allowed for a deferral of 50% of the total amount to December 31, 2021 and 50% of the total amount to December 31, 2022. As of December 31, 2021, we had repaid $0.2 million and will repay the outstanding balance by December 31, 2022.
For 2020, we incurred costs of $0.4 million related to sequestration of certain of our employees at our Red River plant. These costs included hazard pay, lodging and meal expenses for 30 days. For 2021, we did not incur similar costs.
Our customers may also be impacted by COVID-19 pandemic as we believe the utilization of energy has changed. We cannot predict the long-term impact on our customers and the subsequent impact on our business.
Components of Revenue, Expenses and Equity Method Investees
The following briefly describes the components of revenues and expenses as presented in the Consolidated Statements of Operations. Descriptions of the revenue recognition policies are included in Note 1 to the Consolidated Financial Statements included in Item 8 of this Report.
Revenues and costscost of revenuerevenues
Consumables
We sell PACAC and proprietary chemical blendsproducts and other chemical-based technology products to a broad range of customers, including coal-fired utilities, industrials, water treatment plants and other diverse markets. Currently, our products mostly serve coal-fired utilities and other industrial boilers that allow the respective utilities to comply with the regulatory air emissions standards. Additionally, we also sell PAC tostandards and water treatment plants to remove contaminants from the water. Revenue is generally recorded upon delivery of our product.Additionally, we sell AC to Cabot and its customers through the Supply Agreement.
License royalties, related party
We recognize license royalties under a licensing arrangement (the "M-45 License") ofthe M-45 License with Tinuum Group. License royalties from our M-45TM and M-45-PCTM emission control technologies (the "M-45 Technology") to Tinuum Group, LLC ("Tinuum Group"). License royalties Technology are based on a percentage of the per-ton, pre-tax margin, inclusive of impacts related to depreciation expense and other allocable expenses, as defined in the M-45 License. Because Section 45 tax credits from the production and sale of RC are not available to be generated after 2021 and both Tinuum Group and Tinuum Services significantly wound down their operations by the end of 2021, we do not expect to earn license royalties after 2021.
Other Operating Expenses
Payroll and benefits
Payroll and benefits costs include personnel related fringe benefits, sales and administrative staff labor costs and stock compensation expenses. Payroll and benefits costs exclude direct labor included in Cost of revenue.revenues.
Legal and professional fees
Legal and professional costs include external legal, audit and consulting expenses.
General and administrative
General and administrative costs include director fees and expenses, bad debt expense, research and development expense and other general costs of conducting business. Research and development costs, net of reimbursements from cost-sharing arrangements, are charged to expense in the period incurred and are reported in the General and administrative line item in the Consolidated Statements of Operations.
Depreciation, amortization, depletion and accretion
Depreciation and amortization expense consists of depreciation expense related to property, plant and equipment and the amortization of long-lived intangible assets. Depletion and accretion expense consists of depletion expense related to the depletion of mine development costs and the accretion of a mine reclamation liability.liabilities.
Other Income (Expense), net
Earnings from equity method investments
Earnings from equity method investments relates torepresent our share of earnings (losses) related to our equity method investments.
Our equity method earnings in Tinuum Group, a related party in which weWe own a 42.5% equity interest and a 50% voting interest in Tinuum Group. Our equity method earnings in Tinuum Group are positively impacted when Tinuum Group obtains an investor in a RC facility and receives cash payments under either a lease arrangement or sales arrangement of the RC facility. If Tinuum Group operates a retained RC facility, the Company's equity method earnings will beare negatively impacted as operating retained RC facilities generate operating losses. However, we benefit on an after-tax basis if we are able to utilize tax credits associated with the production and sale of RC from operation of retained RC facilities by Tinuum Group. These benefits, if utilized, will increase our consolidated net income as a result of a reduction in income tax expense.
Tinuum Services, LLC ("Tinuum Services"), a related party in which weWe own both a 50% equity and voting interest in Tinuum Services, which operates and maintains RC facilities under operating and maintenance agreements. Tinuum Group or theThe lessee/owner of thean RC facilitiesfacility pays Tinuum Services, subject to certain limitations, the costs of operating and maintaining the RC facilities plus certain fees. Tinuum Services also arranges for the purchase and delivery of certain chemical additives under chemical agency agreements necessary for the production of RC. Tinuum Services consolidates certain RC facilities leased or owned by tax equity investors that are deemed to be variable interest entities ("VIE's). All net income (loss) associated with these VIE's is allocated to the noncontrolling equity holders of Tinuum Services and therefore does not impact our equity earnings (loss) from Tinuum Services.
Other income (expense)
The remaining components of other income (expense) include interest income, interest expense and other miscellaneous items.
Results of Operations
Presentation of Financial Results
For the year ended December 31, 2020, we have restated our "Revenues - Consumables" and "Cost of revenues, excluding depreciation and amortization" line items in our Consolidated Statement of Operations for the impact of previously reporting shipping and handling costs billed to our customers as a reduction to cost of revenue rather than as a component of consumables revenue. This restatement was a result of a reassessment of our accounting and presentation of shipping and handling costs billed to our customers under accounting principles generally accepted in the United States ("GAAP") in our Consolidated Statement of Operations for the year ended December 31, 2021. Historically, we have accounted for and presented shipping and handling costs billed to customers as a reduction of consumables cost of revenue rather than as a component of consumables revenue as required under Accounting Standards Codification 606 - Revenue from Contracts with Customers. Accordingly, we have restated both consumables revenues and consumable cost of revenues for the year ended December 31, 2020 by increasing the previously reported amounts by $5.8 million, respectively.
For the year ended December 31, 2020, there was no impact of the restatement to previously reported amounts for gross margin, operating loss, loss before income taxes, net loss or loss per share. Further there was no impact of this error to the previously reported Consolidated Balance Sheet as of December 31, 2020 or the Consolidated Statement of Stockholders' Equity or Consolidated Statement of Cash Flows for the year ended December 31, 2020. See further discussion of this restatement in Note 2 to the Consolidated Financial Statements under Item 8 of this Report.
For comparison purposes, the following tables set forth our results of operations for the years presented in the Consolidated Financial Statements included in Item 8 of this Report. The operating results for the year ended December 31, 2018 include the operations of Carbon Solutions from the Acquisition Date through December 31, 2018. The year-to-year comparison of financial results is not necessarily indicative of financial results that may be achieved in future years. Our Annual Report on Form 10-K for the year ended December 31, 2020 includes a discussion and analysis of our financial condition and results of operations for the year ended December 31, 2019 in Item 7 of Part II, “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”
Year ended December 31, 20192021 Compared to Year ended December 31, 20182020
Total RevenueRevenues and Cost of RevenueRevenues
A summary of the components of revenues and cost of revenue for the years ended December 31, 20192021 and 20182020 is as follows:
| | | | | Years Ended December 31, | | Change | | Years Ended December 31, | | Change |
(Amounts in thousands except percentages) | | 2019 | | 2018 | | ($) | | (%) | (Amounts in thousands except percentages) | | 2021 | | 2020 | | ($) | | (%) |
| Revenues: | | | | | | | | | Revenues: | | | | | | | | |
| Consumables | | $ | 53,187 |
| | $ | 8,733 |
| | $ | 44,454 |
| | 509 | % | Consumables | | $ | 85,882 | | | $ | 53,908 | | | $ | 31,974 | | | 59 | % |
| License royalties, related party | | 16,899 |
| | 15,140 |
| | 1,759 |
| | 12 | % | License royalties, related party | | 14,368 | | | 13,440 | | | 928 | | | 7 | % |
| Other | | — |
| | 72 |
| | (72 | ) | | (100 | )% | Other | | 44 | | | 15 | | | 29 | | | 193 | % |
| | Total revenues | | $ | 70,086 |
| | $ | 23,945 |
| | $ | 46,141 |
| | 193 | % | Total revenues | | $ | 100,294 | | | $ | 67,363 | | | $ | 32,931 | | | 49 | % |
| | | | | | | | | | | | | | | | |
| Consumables cost of revenue, exclusive of depreciation and amortization | | $ | 49,443 |
| | $ | 6,606 |
| | $ | 42,837 |
| | 648 | % | |
| Other cost of revenue, exclusive of depreciation and amortization | | $ | — |
| | $ | (353 | ) | | $ | 353 |
| | (100 | )% | |
| Consumables cost of revenues, exclusive of depreciation and amortization | | Consumables cost of revenues, exclusive of depreciation and amortization | | $ | 65,576 | | | $ | 50,962 | | | $ | 14,614 | | | 29 | % |
| Other cost of revenues, exclusive of depreciation and amortization | | Other cost of revenues, exclusive of depreciation and amortization | | — | | | (563) | | | 563 | | | (100) | % |
|
Consumables revenuerevenues and consumables cost of revenuerevenues
For the years ended December 31, 20192021 and 2018,2020, consumables revenue increased year over year primarily due to the additionhigher product volumes, which comprised approximately $25.0 million of Carbon Solutions' operations. These operations increased the total pounds of ourchange in consumables sold year over year.
Consumables cost of revenue was also increased year-over-yearrevenues. Product volumes were higher in power generation primarily due to higher natural gas prices compared to the Carbon Solutions' operations. Additional increaseprior year, which contributed to costincreased utilization of revenue wascoal-fired generation and increased demand for our products. In addition, product sales increased under the Supply Agreement from the prior year as we began product shipments under this agreement beginning in the fourth quarter of 2020. Total revenues also increased due to a $5.0favorable price impact of our products by approximately $1.0 million adjustmentas well as favorable product mix impact on consumables revenue of approximately $4.1 million. Consumables revenue for 2021 also increased $0.9 million related to the step-upan increase in basisshipping and handling costs billed to our customers, driven by increases in volumes and costs to ship our products.
Our gross margin, exclusive of inventory acquired related to the Carbon Solutions Acquisition.
Duringdepreciation and amortization, increased for the year ended December 31, 2019, Consumables revenue and margins were2021 compared to 2020 primarily due to the higher product volumes, which resulted in lower fixed costs per pound of product sold. Additionally, gross margin was positively impacted by product price increases. Offsetting these improvements for the year ended December 31, 2021, gross margin was negatively impacted by low coal-fired power dispatchhaving to supplement the Red River production of our AC product, due to higher customer demand related to requirements-based contracts, with AC product purchases from third party suppliers at higher costs per pound. We expect to continue to purchase inventory from third party suppliers in 2022 due to ongoing increased demand for our products and Red River Plant capacity impacted by customer and product mix.
Consumables revenue is affected by electricity demand, driven by seasonal weather and related power generation from sources other than coalneeds, as well as mild weather conditions.competitor prices related to alternative power generation sources such as natural gas. According to data provided by the most recent U.S. Energy Information Administration, ("EIA") data,for the year ended December 31, 2021, power generation from coal-fired power generationdispatch was down year over year byup approximately 15%, even though overall18.0% compared to the corresponding period in 2020. Additionally, there was an increase in total power generation was flat.from all sources of approximately 3.1% in 2021 compared to the corresponding period in 2020.
BasedFor 2022, and based on current market estimates and the expected benefits from the Supply Agreement, we believe that both consumables salesrevenue and volumes will increase compared to 2021. We expect that consumables revenues and revenuesgross margin will be negativelypositively impacted by price increases announced in 2020 due2021 and our efforts to continued generation of powerimprove product mix to higher margin products through changes in our customer base. We anticipate that the product price increases will also help offset the increase
in operating costs from sources other than coal. The most significant driverspurchasing inventory from third party suppliers, as well as expected increases in pricing related to this expected impact are natural gas prices and the expansion of energy generation sources related to natural gas and renewables.certain additives necessary for our manufacturing operations.
License royalties, related party
License royalties increased in 20192021 compared to 20182020 primarily due to obtaining additional third party investors for two RC facilities during 2018 and four new RC facilities during 2019, all of which use our M-45 License. The addition of new invested RC facilities in 2018 and 2019 resulted in an increase in both cash payments to Tinuum Group and the relatedroyalty rate per ton. This increase was primarily a result of an increase year over year in rent revenues generated from RC facilities even though the tonnage produced remained relatively flat. The tons subject to the M-45 License. For the years ended December 31, 2019 and 2018, there were 47.3 million and 37.3 million tons, respectively, of RC produced from RC produced using the M-45 Technology. OffsettingTechnology under the net increase in license royaltiesM-45 License were 49.3 million and 49.4 million for 2019 from additional facilitiesthe year ends December 31, 2021 and related tonnage was a lower royalty per ton rate. This lower rate was attributable to higher depreciation recognized of approximately $1.0 million on all royalty bearing RC facilities during the second half of 2019 as a result of a reduction in their estimated useful lives as determined by Tinuum Group. Further offsetting the net increase in license royalties was a decrease in net lease payments of approximately $0.1 million as a result of Tinuum Group restructuring RC facility contracted leases with its largest customer. 2020, respectively.
As a result of higher depreciationthe Section 45 tax credit period ending as of December 31, 2021, both Tinuum Group and lower lease payments,Tinuum Services ceased operations and, as such, we do not expect that the lower royalty rate per ton will continue in 2020 andto earn M-45 License royalties after December 31, 2021.
Other cost of revenues
For the year ended December 31, 2020, we recognized a credit of $0.6 million to Other cost of revenues related to the Settlement with the Former Customer. See further discussion below of the reversal of an allowance on a note receivable due from the Former Customer in this section under the caption "General and administrative."
Additional information related to revenue concentrations and contributions by class and reportable segment is included in the segment discussion below"Business Segments" section of this Item and in Note 813 and Note 1619 to the Consolidated Financial Statements included in Item 8 of this Report.
Other Operating Expenses
A summary of the components of our operating expenses, exclusive of cost of revenuerevenues items (presented above), for the years ended December 31, 20192021 and 20182020 is as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Years Ended December 31, | | Change |
| (in thousands, except percentages) | | 2021 | | 2020 | | ($) | | (%) |
| Operating expenses: | | | | | | | | |
| Payroll and benefits | | $ | 11,315 | | | $ | 10,621 | | | $ | 694 | | | 7 | % |
| Legal and professional fees | | 6,260 | | | 5,585 | | | 675 | | | 12 | % |
| General and administrative | | 7,060 | | | 8,228 | | | (1,168) | | | (14) | % |
| Depreciation, amortization, depletion and accretion | | 7,933 | | | 8,537 | | | (604) | | | (7) | % |
| Gain on change in estimate, asset retirement obligation | | (2,702) | | | — | | | (2,702) | | | * |
| Impairment of long-lived assets | | — | | | 26,103 | | | (26,103) | | | (100) | % |
| Gain on settlement | | — | | | (1,129) | | | 1,129 | | | (100) | % |
| | | | | | | | |
| | $ | 29,866 | | | $ | 57,945 | | | $ | (28,079) | | | (48) | % |
|
| | | | | | | | | | | | | | | |
| | | Years Ended December 31, | | Change |
| (in thousands, except percentages) | | 2019 | | 2018 | | ($) | | (%) |
| Operating expenses: | | | | | | | | |
| Payroll and benefits | | $ | 10,094 |
| | $ | 10,639 |
| | $ | (545 | ) | | (5 | )% |
| Legal and professional fees | | 9,948 |
| | 8,552 |
| | 1,396 |
| | 16 | % |
| General and administrative | | 8,123 |
| | 4,178 |
| | 3,945 |
| | 94 | % |
| Depreciation, amortization, depletion and accretion | | 7,371 |
| | 723 |
| | 6,648 |
| | 920 | % |
| | | $ | 35,536 |
| | $ | 24,092 |
| | $ | 11,444 |
| | 48 | % |
Payroll and benefits
Payroll and benefits expenses decreased in 2019 compared to 2018increased year over year primarily due to restructuring expenses in connectionof $1.1 million related to the agreements with the departure of certainour executive officers and management's alignment of the business with strategic objectives during 2018,certain other key employees executed in June 2021 ("Retention Agreements") as well as the elimination of certain duplicative positions in connection with the Carbon Solutions Acquisition. There was a decrease in restructuring charges of $3.0$1.3 million year over year. Offsetting this decrease wasrelated to an increase in payroll-related expenses due to a fullincentive expense for the year of increased headcount as a result of the Carbon Solutions Acquisition.
Legal and professional fees
Legal and professional fees expenses increased in 2019ended December 31, 2021 compared to 2018 as a result of costs incurred related to professional fees, primarily outsourced IT cost specific to the integration of Carbon Solutions of $2.9 million, consulting fees of $1.8 million, legal fees related to ongoing business matters of $1.0 million and shared service costs, including audit fees, of $0.5 million.2020. These costsincreases were partially offset by a decrease in costs related to transaction fees incurred related to the Carbon Solutions Acquisitionexpenses taken during the year ended December 31, 20182020 of $1.4 million associated with the resignation of a former executive officer. Additionally, payroll expense decreased by approximately $4.5 million.$0.5 million due to a decrease in headcount.
Legal and professional fees
GeneralLegal and administrative
General and administrative expensesprofessional fees increased in 2019 compared to 2018year over year primarily due to an increase in legal and consulting fees of $0.9 million and $1.2 million, respectively, related to our continuing evaluation of strategic alternatives. Offsetting these increases was $0.9 million related to a reduction in outsourced shared service costs, which included legal and general operatingconsulting contractors, and $0.5 million in outsourced IT costs specific to the completion of the integration of Carbon Solutions in 2020.
General and administrative
General and administrative expenses including an increasedecreased year over year primarily due to decreases in product development expenses of approximately $1.3$0.6 million related to the Supply Agreement, costs incurred due to the sequestration of certain of our employees at the Red River Plant in 2020 of approximately $0.4 million, rent and occupancy expense from additional leased officerelated expenses of $0.3 million and warehouse space resulting from the Carbon Solutions Acquisition. Remaining increases of approximately $1.9 million period over period related to other general and administrative expenses, including recruiting, travel and licenses and fees of approximately $0.7 million.
Offsetting the net decrease in general and administrative expenses year over year was the offset to general and administrative expenses in 2020 from the reversal of an allowance on a note receivable from the Former Customer of $0.4 million. See further discussion below in this section under the caption "Gain on settlement." Further increases year over year included an increase in insurance and recruiting expenses.premiums of approximately $0.4 million.
Depreciation, amortization, depletion and accretion
Depreciation and amortization expense increaseddecreased year over year primarily due to lower absorption from the drawdown of inventory, partially offset by increase in 2019sales volumes for 2021, resulting in a decrease of depreciation expense of $0.2 million. Further, depreciation and amortization expense decreased by approximately $1.1 million related to a lower depreciable base for 2021 compared to 20182020 as a result of an impairment charge recorded in the second quarter of 2020 which reduced the carrying value of our property, plant and equipment. Offsetting these decreases was an increase in accretion expense of $0.6 million related to the Marshall Mine ARO and an increase in depletion expense of $0.2 million due to increased production volume at the additionFive Forks Mine.
Gain on change in estimate, asset retirement obligation
As previously discussed under this Item, for the year ended December 31, 2021, we recorded a gain on change in estimate of $2.7 million related to a reduction in scope of our estimated future reclamation efforts of the Marshall Mine.
Impairment of long-lived assets
As of June 30, 2020, we recorded an impairment charge of $26.1 million, which is included in the Statement of Operations for the year ended December 31, 2020 and was solely attributable to our APT segment. This impairment charge was necessitated by an analysis of the carrying values of our APT segment's long-lived assets and intangiblecertain other long-lived assets acquired as part(the "Asset Group"), which are comprised of our manufacturing plant and related assets and our lignite mine assets, to their respective fair values.
Gain on settlement
In connection with the Settlement discussed above, the Former Customer paid us the cash Settlement Amount of $2.5 million on January 27, 2021 in exchange for a full release of claims in the Litigation Matters. As a result of the Carbon Solutions Acquisition, which contributed approximately $6.7Settlement, we recognized a gain of $1.1 million of depreciation and amortization for 2019.the year ended December 31, 2020.
Other Income (Expense), net
A summary of the components of our other income (expense), net for the years ended December 31, 20192021 and 20182020 is as follows: | | | | | Years Ended December 31, | | Change | | Years Ended December 31, | | Change |
| (Amounts in thousands, except percentages) | | 2019 | | 2018 | | ($) | | (%) | (Amounts in thousands, except percentages) | | 2021 | | 2020 | | ($) | | (%) |
| Other income (expense): | | | | | | | | | Other income (expense): | | | | | | | | |
| Earnings from equity method investments | | $ | 69,176 |
| | $ | 54,208 |
| | $ | 14,968 |
| | 28 | % | Earnings from equity method investments | | $ | 68,726 | | | $ | 30,978 | | | $ | 37,748 | | | 122 | % |
| Gain on extinguishment of debt | | Gain on extinguishment of debt | | 3,345 | | | — | | | 3,345 | | | * |
| | Interest expense | | (7,174 | ) | | (2,151 | ) | | (5,023 | ) | | 234 | % | Interest expense | | (1,490) | | | (3,920) | | | 2,430 | | | (62) | % |
| | Other | | 427 |
| | 220 |
| | 207 |
| | 94 | % | Other | | 640 | | | 132 | | | 508 | | | 385 | % |
| Total other income | | $ | 62,429 |
| | $ | 52,277 |
| | $ | 10,152 |
| | 19 | % | Total other income | | $ | 71,221 | | | $ | 27,190 | | | $ | 44,031 | | | 162 | % |
* Calculation not meaningful
Earnings infrom equity method investments
The following table presents the equity method earnings by investee for the years ended December 31, 20192021 and 2018:2020: | | | | | Years Ended December 31, | | Change | | Years Ended December 31, | | | Change | |
| (in thousands) | | 2019 | | 2018 | | ($) | | (%) | (in thousands) | | 2021 | | 2020 | | | ($) | | (%) | |
| Earnings from Tinuum Group | | $ | 60,286 |
| | $ | 47,175 |
| | $ | 13,111 |
| | 28 | % | Earnings from Tinuum Group | | $ | 61,837 | | | $ | 24,396 | | | | $ | 37,441 | | | 153 | % | |
| Earnings from Tinuum Services | | 8,896 |
| | 7,033 |
| | 1,863 |
| | 26 | % | Earnings from Tinuum Services | | 6,952 | | | 6,582 | | | | 370 | | | 6 | % | |
| Loss from other | | (6 | ) | | — |
| | (6 | ) | | * |
| Loss from other | | (63) | | | — | | | | (63) | | | * | |
| | Earnings from equity method investments | | $ | 69,176 |
| | $ | 54,208 |
| | $ | 14,968 |
| | 28 | % | Earnings from equity method investments | | $ | 68,726 | | | $ | 30,978 | | | | $ | 37,748 | | | 122 | % | |
* Calculation not meaningful
Earnings from equity method investments, and changes related thereto, are impacted by our significant equity method investees: Tinuum Group and Tinuum Services.
For the year ended December 31, 2019,2021, we recognized $60.3$61.8 million in equity earnings from Tinuum Group compared to our proportionate share of Tinuum Group's net income of $62.0$40.1 million for the year. The difference represents the cumulative earnings short-fall balance as of December 31, 2018. For the year ended December 31, 2018, we recognized $47.2 million in equity earnings from Tinuum Group compared tobetween our proportionatepro-rata share of Tinuum Group's net income and our earnings from Tinuum Group equity method investment as reported on the Consolidated Statements of $57.7 million for the year. This difference wasOperations is the result of cumulative distributions received from Tinuum Group being in excess of the carrying value of the investment, and therefore we recognizedrecognize such excess distributions as equity method earnings in the yearperiod the distributions occurred.occur.
For the year ended December 31, 2019,2020, we recognized $24.4 million in equity earnings from Tinuum Group, were positively impacted by the addition during the year of four new invested RC facilities. Further, revenues from two of these facilities were recognized immediately in 2019 as a result of Tinuum Group's adoption of ASC Topic 606 - Revenue from Contracts with Customers ("ASC 606"). However, equity earnings from Tinuum Group were negatively impacted by approximately $4.9 million from higher depreciation on all Tinuum Group RC facilities as a result of a reduction in their estimated useful lives as determined by Tinuum Group during the three months ended September 30, 2019. In addition and during the three months ended September 30, 2019, Tinuum Group restructured RC facility leases with its largest customer, which decreased lease payments and equity earnings beginning in the three months ended September 30, 2019 and will also negatively impact equity earnings in the future. For the year ended December 31, 2018, cash distributions and related equity earnings from Tinuum Group were negatively impacted as a result of $17.6 million of capital expenditures incurred by Tinuum Group related to the engineering and installation of RC facilities. See the discussion below regarding the accounting of earnings from Tinuum Group.
We expect our earnings in Tinuum to decrease in future periods due to higher depreciation and revised lease payments as discussed above. Future earnings will also be negatively impacted due to the expiration of Section 45 tax credits in 2021. However, although earnings recognized under accounting principles generally accepted in the U.S. ("GAAP") are expected to decrease in future years compared to 2019, cash distributions are expected to significantly exceed GAAP earnings, consistent with our current expectations of future RC cash distributions.
On January 1, 2019, Tinuum Group adopted ASC 606 and ASU 2016-02 (Topic 842), Leases (“ASU 2016-02”). As a result of Tinuum Group’s adoption, on January 1, 2019, we recorded a cumulative adjustment increase to Retained earnings of $27.4 million relatedwas equal to our portion of Tinuum Group's cumulative effect adjustment. As a result, we recognized equity earnings based on our pro-rataproportionate share of Tinuum Group's net income as, on a go-forward basis,for the year.
As of December 31, 2021, we concluded the carrying amount of our cumulative pro-rata share ofinvestment in Tinuum Group's net incomeServices was equalnot fully recoverable due to or exceeded cumulativethe remaining expected future cash distributions to be received as Tinuum Services shutters its operations in 2022 as a result of the expiration of the Section 45 tax credit period as of December 31, 2021. As a result, we wrote-down our investment in the amount of $0.7 million, which is included in the "Earnings from Tinuum Group.equity method investments" line item in the Consolidated Statement of Operations for the year ended December 31, 2021.
See further discussion of year over year changes in Earnings from Equity Investments in "Business Segments" under this Item. Additional information related to equity method investments is included in Note 8 to the Consolidated Financial Statements included in Item 8 of this Report.
Tinuum Group's audited consolidated financial statements as of December 31, 20192021 and 20182020 and for the years then ended are included in Item 15 - "Exhibits and Financial Statement Schedules" ("Item 15") of this Report.
Equity earnings
Gain on extinguishment of debt
On July 27, 2021, we received formal notification in the form of a letter dated July 19, 2021 from Bank of Oklahoma ("BOK") that the SBA approved our interestPPP Loan forgiveness application for the PPP Loan in Tinuum Services increased by $1.9the amount of $3.3 million (including accrued interest). For the year ended December 31, 2021, we recorded a gain on extinguishment of the PPP Loan in the amount of $3.3 million in 2019 compared to 2018. Asthe Consolidated Statement of December 31, 2019 and 2018, Tinuum Services provided operating and maintenance services to 19 and 18 RC facilities, respectively. Tinuum Services derives earnings from both fixed-fee arrangements as well as fees that are tied to actual RC production, depending upon the specific RC facility operating and maintenance agreement.
Additional information related to equity method investmentsOperations, which is included in Note 5 to the Consolidated Financial Statements included in Item 8as a component of this Report."Other income (expense)."
Tax Credits and Obligations
Historically, we have earned Section 45 tax credits that may be available for future benefit related to the production of RC from the operation of RC facilities under Section 45 tax credits (or "GBC's) in which we have held both direct ownership and indirect ownership through Tinuum's direct ownership. We refer to these RC facilities as "retained facilities." We currently hold a directThe Section 45 tax credit period ended December 31, 2021 and indirect ownership through Tinuum Group in the GWN REF RC facility ("GWN REF") and during 2018 we earned substantially all of ourwill not earn Section 45 tax credits from GWN REF. However, under an agreement effective January 1, 2019 between Tinuum Group and its largest customer, who also has an ownership interest in Tinuum Group, substantially all of the tax credits earned from GWN REF were allocated prospectively tobeyond this customer. As a result, our earned Section 45 tax credits for the year ended December 31, 2019 were $0.3 million compared to $7.0 million for the year ended December 31, 2018. Future earned Section 45 tax credits for the years 2020-2021 are expected to be consistent with 2019.date. As of December 31, 2019,2021, we had approximately $98.5$86.1 million in GBCSection 45 tax carryforwards.
In the hypothetical event of an ownership change, as defined by IRC Section 382, utilization of GBC'sgeneral business credits ("GBC's") generated prior to the change would be subject to an annual limitation imposed by IRC Section 383 for GBC's. The results of a recent analysis indicated that we had not experienced an ownership change as of December 31, 2019,2021, as defined by IRC Section 382. Such analysis for the period from January 1, 20202022 through the date of this Report has not been completed. Therefore, it is possible that we experienced an ownership change between January 1, 20202022 and the date of the filing of this filing,Report, thus subjecting our GBC carryforwards to limitation.
Interest expense
Interest expense increased $5.0decreased year over year by $2.4 million in 2019 compared to 2018 primarily due to principal payments made in 2021 on a senior term loan (the "Senior Term Loan") that resulted in lower coupon interest expense of $5.3 million$1.5 million. Interest expense for debt discount and debt issuance costs related to the Senior Term Loan entered into on December 7, 2018also decreased by $0.5 million pursuant to fund the Carbon Solutions Acquisition. This increase was comprised of stated interest ondecrease in the Senior Term Loan principal. On June 1, 2021 and prior to the Senior Term Loan's maturity date, we paid the remaining principal balance of $3.7 million and interest expense related to debt discount and debt issuance costs associated with the Senior Term Loan of $1.6 million. Offsettingand all remaining accrued interest through this increase was adate.
The remaining decrease in interest expense year over year related to lower interest expense ("Section 453A interest") related to IRS section 453A ("Section 453A") interest expense of $0.5, which decreased by $0.3 million in 2019 comparedprimarily due to 2018. This reduction was driven by a decrease in Tinuum Group's the tax liability year over year associated with RC facilities in which Tinuum Group recognized as installment sales for tax purposes.
The following table shows the balance of the tax liability that has been deferred and the applicable interest rate used to calculate the 453A interest:interest liability:
| | | | | | | | | | | | |
| | | | As of December 31, | | |
| (in thousands) | | | | 2020 | | |
Tax liability deferred on installment sales (1) | | | | $ | 10,653 | | | |
| Interest rate | | | | 3.00 | % | | |
|
| | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2019 | | 2018 |
| Tax liability deferred on installment sales (1) | | $ | 20,783 |
| | $ | 35,703 |
|
| Interest rate | | 5.00 | % | | 5.00 | % |
(1) Represents the approximate tax effected liability utilizing the federal tax rate in effect for the applicable yearsyear ended related to the deferred gain on installment sales, (approximately $112 millionwhich was approximately zero as of December 31, 2019).2021.
Based on the interest rate in effect as of the date of this filing, the 453A interest rate for the year ended December 31, 2020 is expected to be 5%.
Income tax expense
For the year ended December 31, 2019,2021, our reported income tax expense was $15.7 million and was based on an effective rate of $12.0 million differed from income tax expense computed by applying21%. While the U.S. statutory federal income tax rate (the "Federal Rate") of $10.0 millionwas also 21%, our effective tax rate was primarily due toincreased for state income tax expense, net of federal benefit, of $1.6 million.and decreased from a reduction in the valuation allowance on our deferred tax assets.
For the year ended December 31, 2018,2020, our reported income tax expense of $10.4$6.5 million and was based on an inverse effective rate of 47%, which differed from income tax expense computed using the Federal Rate of $9.6 million primarily21% due to an increase in income tax expense from state income tax expense, net of federal benefit of $3.6 million andprimarily an increase in the valuation allowance from on our deferred tax assets of $4.5 million, offset by a decreaseassets. This increase in the valuation allowance resulted in income tax expense fromrather than expected income tax credits realized of $7.0 million.benefit based on the pretax loss.
Accounting for income taxes requires that companies assess whether a valuation allowance should be recorded against their deferred tax asset based on an assessment of the amount of the deferred tax asset that is “more likely than not” to be realized.
Valuation allowances are established, when necessary, to reduce deferred tax assets to the amount that is more likely than not to be realized.
We assess thea valuation allowance recorded against deferred tax assets at each reporting date. The determination of whether a valuation allowance for deferred tax assets is appropriate requires the evaluation of positive and negative evidence that can be objectively verified. Consideration must be given to all sources of taxable income available to realize the deferred tax asset, including, as applicable, the future reversal of existing temporary differences, future taxable income forecasts exclusive of the reversal of temporary differences and carryforwards, taxable income in carryback years and tax planning strategies. In estimating taxes, we assess the relative merits and risks of the appropriate tax treatment of transactions taking into account statutory, judicial, and regulatory guidance.
As of December 31, 2019,2021, we concluded it is more likely than not we will not generate sufficient taxable income within the applicable net operating loss and tax creditallowable carryforward periods to realize $14.1 millionany of our net deferred tax assets, which resulted in a decrease in the valuation allowance fromand fully reserved for such assets as of December 31, 2018 of $0.3 million.2021. In reaching this conclusion, we primarily considered: (1) the future reversal of existing temporary differences; and (2)considered forecasts of continued future taxable income.losses. As of December 31, 20192021 and 2018,2020, we had a valuation allowance of $79.6$87.5 million and $79.9$88.8 million, respectively, againston our deferred tax assets.
The ability to recognize the remaining deferred tax assets that continue to be subject to a valuation allowance is evaluated on a quarterly basis to determine if there are any significant events that would affect the ability to utilize those deferred tax assets.
Our estimate of future taxable income or losses is based on internal projections that consider historical performance, multiple internal scenariosassumptions on future performance and assumptions, as well as external data that we believe is reasonable.data. If events are identified that affect our ability to utilize our deferred tax assets, or if additional deferred tax assets are generated, thewe update our analysis will be updated to determine if any adjustmentsan increase to thea valuation allowance areis required. If actual results differ negatively from the current estimates of future taxable income, even if caused by adverse macro-economic conditions, the remaining valuation allowance may need to be increased. Such an increase could have a material adverse effect on our financial condition and results of operations. Conversely, better than expected results and continued positive results and trends could result in further releasesa decrease to the deferred taxa valuation allowance, and any such decreases could have a material positive effect on our financial condition and results of operations.
See additional discussion in Note 1418 of the Consolidated Financial Statements included in Item 8 of this Report.
Non-GAAP Financial Measures
To supplement our financial information presented in accordance with GAAP, we are providing non-GAAP measures of certain financial performance. These non-GAAP measures include Consolidated EBITDA, Consolidated Adjusted EBITDA, RC Segment EBITDA, RC Segment Adjusted EBITDA, APT Segment EBITDA and APT Segment Adjusted EBITDA. We have included non-GAAP measures because management believes that they help to facilitate comparisonperiod to period comparisons of our operating results between periods.results. We believe the non-GAAP measures provide useful information to both management and users of the financial statements by excluding certain expenses, gains and losses that may not be indicative of core operating results and business outlook. Management uses these non-GAAP measures in evaluating the performance of our business.
These non-GAAP measures are not in accordance with, or an alternative to, measures prepared in accordance with GAAP and may be different from non-GAAP measures used by other companies. In addition, these non-GAAP measures are not based on any comprehensive set of accounting rules or principles. These measures should only be used to evaluate our results of operations in conjunction with the corresponding GAAP measures.
We define Consolidated EBITDA as net income adjusted for the impact of the following items that are either non-cash or that we do not consider representative of our ongoing operating performance: depreciation, amortization, depletion, and accretion, amortization of upfront customer consideration that was recorded as a component of the Marshall Mine Acquisition ("Upfront Customer Consideration"), interest expense, net and income tax expense. We define Consolidated Adjusted EBITDA as Consolidated EBITDA, reduced by the non-cash impacts of equity earnings from equity method investments, gain on change in estimate of asset retirement obligations, gain on extinguishment of debt and gain on customer settlement, and increased by cash distributions from equity method investments and impairment of long-lived assets. Because Consolidated Adjusted EBITDA omits certain non-cash items, we believe that the measure is less susceptible to variances that affect our operating performance.
We define APT Segment EBITDA is calculated(loss) as APT Segment operating income (loss)loss adjusted for the impact of the following items that are either non-cash or that we do not consider representative of our ongoing operating performance: depreciation, amortization, depletion, and accretion, amortization of Upfront Customer Consideration and interest expense, net. We define APT Segment Adjusted EBITDA (loss) as APT Segment EBITDA (loss), reduced by gain on customer settlement, gain on change in estimate of asset retirement obligation, gain on extinguishment of debt and gain on customer settlement, and increased by impairment of long-lived assets.
We define RC Segment EBITDA as RC Segment operating income adjusted for the impact of the following items that are either non-cash or that we do not consider representative of our ongoing operating performance: depreciation, amortization, depletion, accretion and interest expense. We define RC Segment Adjusted EBITDA as RC Segment EBITDA, reduced by the non-cash impact of equity earnings from equity method investments and gain on extinguishment of debt, and increased by cash distributions from equity method investments.
When used in conjunction with GAAP financial measures, Segment EBITDA is awe believe these non-GAAP measures are supplemental measuremeasures of operating performance that management believes is a useful measureexplain our operating performance for our PGI segment performance relativeperiod to the performance ofperiod comparisons and against our competitors as well as performance period over period. Additionally,competitors' performance. Generally, we believe the measure isthese non-GAAP measures are less susceptible to variances that affect our operating performance results.
We present Consolidated EBITDAWith the exception of extinguishment of debt, gain on change in estimate, asset retirement obligation, impairment on long-lived assets and Segment EBITDA because we believe they are useful as supplemental measures in evaluating our operating performance and provide greater transparency intogain on settlement, the results of operations. Management uses Consolidated EBITDA and Segment EBITDA as factors in evaluating the performance of our business.
The adjustments to Consolidated Adjusted EBITDA and APT Segment Adjusted EBITDA in future periods are generally expected to be similar. Consolidated EBITDA and Segment EBITDAThese non-GAAP measures have limitations as analytical tools and these measures should not be considered in isolation or as a substitute for analyzing our results as reported under GAAP.
Consolidated EBITDA
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| | | Year ended December 31, |
| | | 2019 | | 2018 |
| Net income (1) | | $ | 35,537 |
| | $ | 35,454 |
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| Depreciation, amortization, depletion and accretion | | 7,371 |
| | 723 |
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| Interest expense, net | | 6,913 |
| | 1,912 |
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| Income tax expense | | 11,999 |
| | 10,423 |
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| Consolidated EBITDA | | $ | 61,820 |
| | $ | 48,512 |
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(1)Reconciliation of Net income for(loss) to Consolidated EBITDA (Loss) and Consolidated Adjusted EBITDA
The following table reconciles net income (loss), our most directly comparable as-reported financial measure calculated in accordance with GAAP, to Consolidated EBITDA (Loss) and Consolidated Adjusted EBITDA. A reconciliation of RC Segment EBITDA, RC Segment Adjusted EBITDA, APT Segment EBITDA and APT Segment Adjusted EBITDA to our most directly comparable as-reported financial measure calculated in accordance with GAAP is included below following the year ended December 31, 2019 was inclusivediscussion of a $5.0 million adjustment, which increased costthe results of revenue due to a step-up in basis of inventory acquired related to the Carbon Solutions Acquisition.each respective segment.
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| | | | Year ended December 31, |
| | | | | | 2021 | | 2020 |
| Net income (loss) | | | | | | $ | 60,401 | | | $ | (20,302) | |
| Depreciation, amortization, depletion and accretion | | | | | | 7,933 | | | 8,537 | |
| Amortization of Upfront Customer Consideration | | | | | | 508 | | | 158 | |
| Interest expense, net | | | | | | 1,164 | | | 3,793 | |
| Income tax expense | | | | | | 15,672 | | | 6,511 | |
| Consolidated EBITDA (loss) | | | | | | 85,678 | | | (1,303) | |
| Cash distributions from equity method investees | | | | | | 74,026 | | | 62,441 | |
| Equity earnings | | | | | | (68,726) | | | (30,978) | |
| Gain on extinguishment of debt | | | | | | (3,345) | | | — | |
| Gain on change in estimate, asset retirement obligation | | | | | | (2,702) | | | — | |
| Impairment | | | | | | — | | | 26,103 | |
| Gain on settlement | | | | | | — | | | (1,129) | |
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| Consolidated Adjusted EBITDA | | | | | | $ | 84,931 | | | $ | 55,134 | |
Business Segments
As of December 31, 2019,2021, we have two reportable segments: (1) Refined Coal ("RC");segments, RC and (2) Power Generation and Industrials ("PGI").APT.
The business segment measurements provided to and evaluated by our chief operating decision maker are computed in accordance with the principles listed below:
•The accounting policies of the operating segments are the same as those described in the summary of significant accounting policies except as described below.
•Segment revenues include equity method earnings and losses from our equity method investments.
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�� | Segment operating income (loss) includes segment revenues, gains related to sales of equity method investments and allocation of certain "Corporate general and administrative expenses," which include Payroll and benefits, Rent and occupancy, Legal and professional fees, and General and administrative. |
•Segment operating income (loss) includes segment revenues, gains related to sales of equity method investments and allocation of certain "Corporate general and administrative expenses," which include Payroll and benefits, Legal and professional fees, General and administrative, and Depreciation, amortization, depletion and accretion.
•RC segment operating income includes interest expense directly attributable to the RC segment.
The principal products and services of our segments are:
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1. | RC - Our RC segment derives its earnings from equity method investments as well as royalty payment streams and other revenues related to enhanced combustion of and reduced emissions of both NOX and mercury from the burning of RC. Our equity method investments related to the RC segment include Tinuum Group, Tinuum Services and one insignificant investee. Segment revenues include equity method earnings (losses) from our equity method investments and royalty earnings from Tinuum Group. These earnings are included in the Earnings from equity method investments and License royalties, related party line items in the Consolidated Statements of Operations included in Item 8are described in Item 1 of this Report. Key drivers to RC segment performance are the produced and sold RC from both operating and retained RC facilities, royalty-bearing tonnage, and the number of operating (leased or sold) and retained RC facilities. These key drivers impact our earnings and cash distributions from equity method investments.
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2. | PGI - Our PGI segment includes revenues and related expenses from the sale of consumable products that utilize PAC and chemical technologies. These options provide coal-powered utilities and industrial boilers with mercury control solutions working in conjunction with pollution control equipment systems, generally without the requirement for significant ongoing capital outlays. These amounts are included in the respective revenue and cost of revenue line items in the Consolidated Statements of Operations included in Item 8 of this Report. |
The following table presents our operating segment results for the years ended December 31, 20192021 and 2018:2020:
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| | | Years Ended December 31, | | | | Change |
| (in thousands) | | 2021 | | 2020 | | | | ($) | | |
| Revenues: | | | | | | | | | | |
| Refined Coal: | | | | | | | | | | |
| Earnings in equity method investments | | $ | 68,726 | | | $ | 30,978 | | | | | $ | 37,748 | | | |
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| License royalties, related party | | 14,368 | | | 13,440 | | | | | 928 | | | |
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| | 83,094 | | | 44,418 | | | | | 38,676 | | | |
| Advanced Purification Technologies: | | | | | | | | | | |
Consumables (1) | | 85,882 | | | 53,908 | | | | | 31,974 | | | |
| Other | | 44 | | | 15 | | | | | 29 | | | |
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| | 85,926 | | | 53,923 | | | | | 32,003 | | | |
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| Total segment reporting revenues | | 169,020 | | | 98,341 | | | | | 70,679 | | | |
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| Adjustments to reconcile to reported revenues: | | | | | | | | | | |
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| Earnings in equity method investments | | (68,726) | | | (30,978) | | | | | (37,748) | | | |
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| Total reported revenues | | $ | 100,294 | | | $ | 67,363 | | | | | $ | 32,931 | | | |
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| Segment operating income (loss) | | | | | | | | | | |
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| Refined Coal | | $ | 82,634 | | | $ | 42,689 | | | | | $ | 39,945 | | | |
Advanced Purification Technologies (2) | | 5,649 | | | (39,958) | | | | | 45,607 | | | |
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| Total segment operating income | | $ | 88,283 | | | $ | 2,731 | | | | | $ | 85,552 | | | |
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| | | Years Ended December 31, | | Change |
| (in thousands) | | 2019 | | 2018 | | ($) |
| Revenues: | | | | | | |
| Refined Coal: | | | | | | |
| Earnings in equity method investments | | $ | 69,176 |
| | $ | 54,208 |
| | $ | 14,968 |
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| License royalties, related party | | 16,899 |
| | 15,140 |
| | 1,759 |
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| | | 86,075 |
| | 69,348 |
| | 16,727 |
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| Power Generation and Industrials: | | | | | | |
| Consumables | | 50,458 |
| | 8,628 |
| | 41,830 |
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| Other | | — |
| | 72 |
| | (72 | ) |
| | | 50,458 |
| | 8,700 |
| | 41,758 |
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| Total segment reporting revenues | | 136,533 |
| | 78,048 |
| | 58,485 |
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| Adjustments to reconcile to reported revenues: | | | | | | |
| Earnings in equity method investments | | (69,176 | ) | | (54,208 | ) | | (14,968 | ) |
| Corporate and other | | 2,729 |
| | 105 |
| | 2,624 |
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| Total reported revenues | | $ | 70,086 |
| | $ | 23,945 |
| | $ | 46,141 |
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| Segment operating income (loss) | | | | | | |
| Refined Coal (1) | | $ | 83,471 |
| | $ | 64,854 |
| | $ | 18,617 |
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| Power Generation and Industrials (2) | | (11,606 | ) | | (2,621 | ) | | (8,985 | ) |
| Total segment operating income | | $ | 71,865 |
| | $ | 62,233 |
| | $ | 9,632 |
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(1) IncludedIncluded in the RCAPT segment operating income (loss) for the years ended December 31, 20192021 and 2018 is 453A interest expense of $1.02020 was $7.4 million and $1.6$7.9 million, respectively. Alsorespectively, of depreciation, amortization, depletion and accretion expenses on mine- and plant-related long-lived assets and liabilities. Further included in the RCAPT segment operating income (loss) for the year ended December 31, 20182021 was $0.4$2.7 million of severance expense.
(2)related to the gain on change in estimate, asset retirement obligation. Included in the PGIAPT segment operating incomeloss for the year ended December 31, 2019 and 20182020 was approximately $4.7an impairment charge of $26.1 million and $1.0 million, respectively,offset by gain on settlement with the Former Customer of cost of revenue expense related to a step up in basis of the fair value of inventory. Also included in the PGI segment operating income for the year ended December 31, 2019 and 2018 was $6.7 million and $0.5 million, respectively, of depreciation, amortization and depletion expense on mine- and plant-related long-lived assets.$1.1 million.
A reconciliation of segment operating income to consolidated net income is included in Note 1519 of the Consolidated Financial Statements included in Item 8 of this Report.
Refined Coal
The following table detailsprovides the segment revenues of our respective equity method investments for the years ended December 31, 20192021 and 2018:2020:
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| | Year ended December 31, | | |
| (in thousands) | | 2021 | | 2020 | | |
| Earnings from Tinuum Group | | $ | 61,837 | | | $ | 24,396 | | | |
| Earnings from Tinuum Services | | 6,952 | | | 6,582 | | | |
| Loss from other | | (63) | | | — | | | |
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| Earnings from equity method investments | | $ | 68,726 | | | $ | 30,978 | | | |
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| | | Year ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Earnings from Tinuum Group | | $ | 60,286 |
| | $ | 47,175 |
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| Earnings from Tinuum Services | | 8,896 |
| | 7,033 |
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| Loss from other | | (6 | ) | | — |
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| Earnings from equity method investments | | $ | 69,176 |
| | $ | 54,208 |
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RC earnings increased primarily due to increasedFor 2021, equity earnings from Tinuum Group duringwere positively impacted by an increase in overall coal-fired power generation demand and higher production volume from coal-fired sources, which was driven by higher prices related to alternative power generation sources such as natural gas. Also, this increase was driven by higher RC facility count for the majority of 2021 compared to 2020. Further, for the year ended December 31, 2019 compared to the year ended December 31, 2018, as presented above. For the year ended December 31, 2019,2020, we
recognized $60.3 million in equity earnings from Tinuum Group comparedequal to
our proportionate share of Tinuum Group's net income for the period, which was less than cash distributions received for the same period.
In the fourth quarter of $62.02020, Tinuum Group recorded an impairment charge of $3.0 million on certain of its assets located at RC facilities and a retention accrual related to the wind down of its operations upon the expected expiration of Section 45 on December 31, 2021.
RC earnings related to M-45 license royalties increased from 2021 to 2020 as a result of an increase in the royalty rate per ton year over year offset by a reduction in RC facilities subject to the M-45 License due to the expected expiration of Section 45 on December 31, 2021.
Equity earnings from Tinuum Services increased by $0.4 million in 2021 compared to 2020 primarily as a result of recording an impairment charge of $2.9 million for year ended December 31, 2020 as well as an increase in tonnage for the year. The difference representsRC facilities that Tinuum Services operated in 2021 compared to 2020. As of December 31, 2021 and 2020, Tinuum Services provided operating and maintenance services to zero and 22 RC facilities, respectively. Tinuum Services derived earnings from both fixed-fee arrangements as well as fees that are tied to actual RC production, as determined by the cumulative earnings short-fall balancespecific RC facility operating and maintenance agreement.
As discussed above, as of December 31, 2018. For2021, the year ended December 31, 2018, we recognized $47.2Company reduced its investment in Tinuum Services in the amount of $0.7 million, which is included in equity earningsthe "Earnings from Tinuum Group compared to our proportionate share of Tinuum Group's net income of $57.7 million for the year. This difference was the result of cumulative distributions received from Tinuum Group being in excess of the carrying value of the investment, and therefore we recognized such excess distributions as equity method earningsinvestments" line item in the year the distributions occurred.
For the year ended December 31, 2019, equity earnings from our interest in Tinuum Group were positively impacted by the additionConsolidated Statement of four new RC facilities during the year ended December 31, 2019. Further, revenues from two of these facilities were recognized immediately in 2019 as a result of Tinuum Group’s adoption of ASC 606 and ASC 842 as of January 1, 2019. However, our earnings were negatively impacted from higher depreciation recognizedOperations for the year ended December 31, 2019 on all Tinuum Group RC facilities as a result of a reduction in their estimated useful lives as determined by Tinuum Group during the three months ended September 30, 2019, as described above. 2021.
Outlook
As a result of a reduction in coal consumption, as noted above, during the three months ended September 30, 2019, Tinuum Group restructured RC facility contracted leases with its largest customer, which decreased lease payments beginning for the remainder of 2019 and will also negatively impact our pro-rata share of Tinuum Group's earnings in the future.
Earnings from Tinuum Services for 2019 increased compared to 2018 primarily due to an increase in the number of operating RC facilities from 18 to 19 in which Tinuum Services provides operating and maintenance services.
RC earnings were positively impacted during the year ended December 31, 2019 by an increase in royalties related to Tinuum Group's use of our M-45 License. The addition of new invested RC facilities in 2018 and 2019 resulted in an increase in both cash payments to Tinuum Group and the related tons subject to the M-45 License. For the years ended December 31, 2019 and 2018, there were 47.3 million and 37.3 million tons, respectively, of RC produced using the M-45 Technology. Offsetting the net increase in license royalties for the year ended December 31, 2019 from additional facilities and related tonnage was a lower royalty per ton rate. This lower rate is attributable to higher depreciation recognized of approximately $1.0 million on all royalty bearing RC facilities during the second half of 2019 as a result of a reduction in their estimated useful lives as determined by Tinuum Group. Further offsetting the net increase in license royalties was a decrease in lease payments of approximately $0.1 million as a result of Tinuum Group restructuring RC facility contracted leases with its largest customer.
Outlook
Future earnings and growth in the RC segment will continue to be impacted by coal-fired dispatch and invested facilities with leases subject to periodic renewals being terminated, repriced, or otherwise subject to renegotiated terms. Further, we expect our earnings in Tinuum to decrease in future periods due to higher depreciation and revised lease payments as discussed above. Future earnings will also be negatively impacted due to the expiration of the ability to generate Section 45 tax credits after December 31, 2021, both Tinuum Group and Tinuum Services ceased operations and are in 2021 earned from RC production. However, although GAAPreclamation of their respective businesses. The loss of equity earnings, are expected to decreasedistributions and M-45 Royalties beginning in future years2022 will have a material adverse effect on our financial condition and consolidated operating results compared to 2019, cash distributions are expectedhistorical periods.
Reconciliation of RC Segment operating income to significantly exceedRC Segment EBITDA and RC Segment Adjusted EBITDA
The following table reconciles RC Segment operating income, our most directly comparable as-reported financial measure calculated in accordance with GAAP, earnings, consistent with our current expectations of futureto RC distributions.Segment EBITDA and RC Adjusted EBITDA.
Power Generation and Industrials | | | | | | | | | | | | | | |
| | Year ended December 31, |
| (in thousands) | | 2021 | | 2020 |
| RC Segment operating income | | $ | 82,634 | | | $ | 42,689 | |
| Depreciation, amortization, depletion and accretion | | 40 | | | 116 | |
| Interest expense | | 12 | | | 331 | |
| RC Segment EBITDA | | 82,686 | | | 43,136 | |
| Cash distributions from equity method investees | | 74,026 | | | 62,441 | |
| Equity earnings | | (68,726) | | | (30,978) | |
| Gain on extinguishment of debt | | (97) | | | — | |
| RC Segment Adjusted EBITDA | | $ | 87,889 | | | $ | 74,599 | |
PGIAdvanced Purification Technologies
APT segment operating lossincome increased during the year ended December 31, 20192021 compared to 20182020 primarily due to the Impairment Charge of $26.1 million recorded for the year end December 31, 2020. Further, for the year ended December 31, 2021, consumable revenues and associated gross margin increased, driven by an increase in the operating loss of Carbon Solutions. This increase included $4.7 million of cost of revenue expense recognized in 2019volume year over year, specifically related to a step-upthe Supply Agreement, as well as an increase in basis of acquired finished goods inventorydemand for our products by our current customer base and $6.7 million of depreciation, amortization and depletion expense related to Carbon Solutions Acquisition. from new customers.
During the year ended December 31, 2019, Consumables revenue2020, we incurred costs of $0.4 million related to sequestration of certain of our employees at our Red River plant. These costs included hazardous pay, lodging expense and margins were negatively impacted by low coal-fired power dispatch driven by power generation from sources other than coal as well as mild weather. According to the most recent EIA data, coal-fired power generation was down year over year by approximately 15% even though overall power generation was flat.related costs for 60 days.
Outlook
Based on current market estimates, we believe that the PGIAPT segment will continuedcontinue to be affected, both positively and negatively, impacted, asby power generation from coal-fired power plants declines and the market focuses onpricing of other sources, including natural gas and renewable energy. Futureenergy, as well as weather throughout the U.S. In 2022, we expect demand will alsofrom our current customers to be impacted by pricesconsistent with 2021 based on current market trends. Further, we see opportunities and are continuing to pursue diverse markets for our purification products outside of competing energy sources, such as natural gas. Low prices of alternative energy sources and decreasingcoal-fire power generation, from coal-fired utilities reduce demand for our products.including industrial application, water treatment plants and other end markets.
PGI Segment EBITDA
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| | | Year ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Segment operating loss (1) | | $ | (11,606 | ) | | $ | (2,621 | ) |
| Depreciation, amortization, depletion and accretion | | 6,682 |
| | 520 |
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| Interest expense, net | | 351 |
| | 45 |
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| Segment EBITDA loss | | $ | (4,573 | ) | | $ | (2,056 | ) |
(1)Reconciliation of APT Segment operating loss forincome (loss) to APT Segment EBITDA (loss) and APT Segment Adjusted EBITDA (loss)
The following table reconciles APT Segment income (loss), our most directly comparable as-reported financial measure calculated in accordance with GAAP, to APT Segment EBITDA (loss) and Adjusted EBITDA (loss).
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| | Year ended December 31, |
| (in thousands) | | 2021 | | 2020 |
| APT Segment operating income (loss) | | $ | 5,649 | | | $ | (39,958) | |
| Depreciation, amortization, depletion and accretion | | 7,388 | | | 7,870 | |
| Amortization of Upfront Customer Consideration | | 508 | | | 158 | |
| Interest expense, net | | 297 | | | 402 | |
| APT Segment EBITDA (loss) | | 13,842 | | | (31,528) | |
| Gain on extinguishment of debt | | (2,562) | | | — | |
| Gain on change in estimate, asset retirement obligation | | (2,702) | | | — | |
| Impairment | | — | | | 26,103 | |
| Gain on settlement | | — | | | (1,129) | |
| APT Segment Adjusted EBITDA (loss) | | $ | 8,578 | | | $ | (6,554) | |
Liquidity and Capital Resources
Current Resources and Factors Affecting Our Liquidity
As of December 31, 2021, our principal future sources of liquidity include:
•$88.8 million of cash, cash equivalents and restricted cash; and
•operations of the APT segment
For the year ended December 31, 20192021, our principal uses of liquidity included:
•our business operating expenses, including capital expenditures, reclamation costs, federal and 2018 was inclusivestate tax payments and cash severance payments; and
•payment of adjustments of $4.7 milliondebt principal and $1.0 million, respectively, which increased cost of revenue due to a step-up in basis of inventory acquired related to the Carbon Solutions Acquisition.interest.
Liquidity and Capital Resources
Overview of Factors Affecting Our Liquidity
During 2019,2021, our liquidity position was positively affected primarily due tofrom cash distributions from Tinuum Group and Tinuum Services, royalty payments from Tinuum Group and borrowing availability under our bank ("Lender") line of credit (the "Linewith a bank ("Line of Credit").
Our principal sources Due to the expiration of liquidity currently include:
cashthe Section 45 tax period as of December 31, 2021 and cash equivalents on hand;
the resultant wind down of Tinuum Group's and Tinuum Services' operations at the end of 2021, distributions from Tinuum Group and Tinuum Services;
royalty payments from Tinuum Group;
operations of the PGI segment; and
the Line of Credit.
Our principal useswill no longer be a material source of liquidity during the year endedafter 2021. Our line of credit expired on December 31, 2019 included:
repurchases of shares of common stock;
payment of dividends;
payment of debt principal and interest; and
our business operating expenses, including capital expenditures, federal and state tax payments and cash severance payments.2021.
Our ability to continue to generate sufficient cash flow required to meet ongoing operational needs and obligations, and make potential future dividend payments and share repurchases depends upon several factors, includingfactors. These include: (1) executing on our contracts and initiatives,initiatives; (2) increasing our share of the market for APT consumables, including expanding our overall AC business into additional adjacent markets and improving our customer and product mix; and (3) receiving final, expected M-45 License royalty payments from Tinuum Group and distributions from Tinuum Group and Tinuum Services in 2022.
For 2022 and increasingbeyond, our shareprimary sources of liquidity are expected to be from cash on hand and through the ongoing operations of our APT segment. We believe our existing operations and related contract volumes will continue to provide operating cost efficiencies of the market for PGI consumables, including expanding our overall AC business intoRed River Plant, providing additional adjacent markets. Increasing distributions from Tinuum Group will likely be dependentsources of operating cash flows in the future. Full and partial reimbursements on both preserving existing contractual relationships and securing additional tax equity investors for those Tinuum Group facilities that are currently not operating.
Due to the Carbon Solutions Acquisition, we spent significantly more in capital expenditures from Cabot will offset our uses of investing cash flows. As discussed above, on February 25, 2022, we received the Cabot Payment in 2019,the amount of $10.6 million, which included expendituresprovides a source of cash for a plant turnaround of our AC manufacturing facility that occurs on average about every 18 - 24 months. We believe that capital expenditures for 2020 may be slightly lower compared to 2019. Carbon Solutions has historically incurred costs for capital expenditures related to the PAC manufacturing facility under normal operations and planned outages and for mine development at the Five Forks Mine. us in 2022.
Tinuum Group and Tinuum Services Distributions
The following table summarizes the cash distributions from our equity method investments, which most significantly affected our consolidated cash flow results, for the years ended December 31, 20192021 and 2018:2020:
| | | | | | | | | | | | | | | | |
| | Year ended December 31, | | |
| (in thousands) | | 2021 | | 2020 | | |
| | | | | | |
| Tinuum Group | | $ | 65,224 | | | $ | 53,289 | | | |
| Tinuum Services | | 8,802 | | | 9,152 | | | |
| | | | | | |
| Distributions from equity method investees | | $ | 74,026 | | | $ | 62,441 | | | |
|
| | | | | | | | |
| | | Year ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| | | | |
| Tinuum Group | | $ | 65,238 |
| | $ | 47,175 |
|
| Tinuum Services | | 8,650 |
| | 5,500 |
|
| Distributions from equity method investees | | $ | 73,888 |
| | $ | 52,675 |
|
Future cash flowsCash distributions from Tinuum throughGroup for 2021 are expectedincreased by $11.9 million compared to range from $1502020 primarily due to $175 million,higher production volume driven by high competitor prices related to alternative power generation sources such as natural gas. Also, this increase was driven by higher average RC facility count for the year ended December 31, 2021 compared to 2020.
Both Tinuum Group and key drivers in achieving these future cash flows are based on the following:
20 invested facilitiesTinuum Services ceased their operations as of December 31, 2019 and inclusive2021 due to the expiration of all net Tinuum cash flows (distributions and license royalties), offset by estimated federal and state incomethe Section 45 tax payments and 453A interest payments.
Expected future cash flows from Tinuum Group are based on the following key assumptions:
Tinuum Group continues to not operate retained facilities;
Tinuum Group does not have material unexpected capital expenditures or unusual operating expenses;
Tax equity lease renewals on invested facilities are not terminated or repriced; and
Coal-fired power generation remains consistent with existing contractual expectations.
During the fourth quarter of 2019, two coal-fired utilities where Tinuum Group had invested RC facilities operating closed. The shuttering of these two facilities has negatively impacted our expectations related to future cash flows if Tinuum is unable to move these two RC facilities to new utilities. As previously noted under this Item, Tinuum Group and its largest customer agreed to certain reductions in overall net lease payments for thecredit period from October 2019 to December 2021, and these reductions will negatively impact future cash flows. All of these factors, combined with the addition of new invested facilities during 2019, are included in the expected cash flows as of December 31, 2019.2021. As such, our distributions from our RC segment will substantially cease as of December 31, 2021.
During the first half of 2022, we expect to receive final cash distributions from Tinuum Group and Tinuum Services in the range of $4.0 to $5.0 million.
PPP Loan
On April 20, 2020, we entered into the PPP Loan under the PPP, evidenced by a promissory note, with BOK providing for $3.3 million in proceeds, which was funded on April 21, 2020. The PPP Loan had a maturity date of April 21, 2022. The PPP Loan
principal was eligible for forgiveness subject to the terms of the PPP and approval by the SBA. The interest rate on the PPP Loan was 1.00%. The PPP Loan was unsecured and contains customary events of default relating to, among other things, payment defaults, making materially false and misleading representations to the SBA or BOK, or breaching the terms of the PPP Loan. The occurrence of an event of default could result in the repayment of all amounts outstanding, collection of all amounts owing from us, or filing suit and obtaining judgment against us.
On July 27, 2021, we received formal notification in the form of a letter dated July 19, 2021 from BOK that the SBA approved the forgiveness of our PPP Loan forgiveness application for the PPP Loan in the amount of $3.3 million (including accrued interest). For the year ended December 31, 2021, the Company recorded a gain on extinguishment of the PPP Loan in the amount of $3.3 million in the Consolidated Statements of Operations, which is included as a component of "Other income (expense)."
Restricted Cash
As of December 31, 2021, we had long-term restricted cash of $10.0 million as required under the Surety Agreement related to the Reclamation Contract.
Senior Term Loan
On December 7, 2018, we executedand ADA-ES, Inc. ("ADA"), a wholly-owned subsidiary, and certain other subsidiaries of the Company as guarantors, The Bank of New York Mellon as administrative agent, and Apollo Credit Strategies Master Fund Ltd and Apollo A-N Credit Fund (Delaware) L.P., affiliates of a beneficial owner of greater than five percent of our common stock and a related party, entered into the Senior Term Loan with Apollo in the principal amount of $70.0 million, less original issue discount of $2.1 million. Proceeds from the Senior Term Loan were used to fund the acquisition of Carbon Solutions. We also paid debt issuance costs of $2.0 million related to the Senior Term Loan. The Senior Term Loan has a term of 36 months and bearsbore interest at a rate equal to 3-month LIBOR (subject to a 1.5% floor) + 4.75% per annum, which iswas adjusted quarterly to the current 3-month LIBOR rate, and interest iswas payable quarterly in arrears. Quarterly principal payments of $6.0 million were required beginning in March 2019, and we may prepay the Senior Term Loan at any time without penalty. The Senior Term Loan iswas secured by substantially all the assets of our assets,the Company, including the cash flows from the Tinuum Group and Tinuum Services,Entities, but excluding our equity interests in thosethe Tinuum entities.
The Senior Term Loan includes, among others, the following covenants: (1) Beginning December 31, 2018On June 1, 2021 and as of the end of each fiscal quarter thereafter, we must maintain a minimum cash balance of $5.0 million and shall not permit "expected future net cash flows from the refined coal business" (as defined inprior to the Senior Term Loan) to be less than 1.75 timesLoan's maturity date, we paid the remaining principal outstanding principal amount of the Senior Term Loan; (2) Beginning in January 2019, annual collective dividends and buybacks of shares of our common stock in an aggregate amount, not to exceed $30.0 million, are permitted so long as (a) no default or event of default exists underon the Senior Term Loan and (b) expected future net cash flows fromall remaining accrued interest through this date. We did not incur any prepayment fees associated with the refined coal business as of the end of the most recent fiscal quarter exceed $100.0 million. See "Risk Factors-Risks relating to our common stock - There can be no assurance that we will continue to declare cash dividends at all or in any particular amounts."early pay-off.
Stock Repurchases and Dividends
In November 2018, our Board of Directors (the "Board") authorized us to purchase up to $20.0 million of our outstanding common stock. As of November 2019, $2.9 million remained outstanding under this program. In November 2019, the Board authorized an incremental $7.1 million to this stock repurchase program and provided that the program will remain in effect until all amounts are utilized or the program is otherwise modified by the Board. For the year ended December 31, 2019, under these two stock repurchase programs, we purchased 533,345 shares of our common stock for cash of $5.8 million, inclusive of commissions and fees.
Previously, in December 2017, the Board had authorized us to purchase up to $20.0 million of our outstanding common stock under a separatestock repurchase program that(the "Stock Repurchase Program"), which was to remain in effect until JulyDecember 31, 2018. For2019 unless otherwise modified by the Board. As of November 2019, $2.9 million remained outstanding related to Stock Repurchase Program. In November 2019, the Board authorized an incremental $7.1 million to the Stock Repurchase Program and provided that it will remain in effect until all amounts are utilized or it is otherwise modified by the Board. We did not make any stock repurchases during the year ended December 31, 2018, under this program and the program implemented in November 2018, we purchased 2,350,422 shares of our common stock for cash of $25.3 million, inclusive of commissions and fees.2021.
During the year ended December 31, 2019,2021, we paiddid not pay quarterly cash dividends to stockholdersstockholders. We paid our most recent dividend in March 2020 of $18.3 million, which were paid on March 7, 2019, June 7, 2019, September 6, 2019 and December 13, 2019.$0.25 per share.
Line of Credit
As of December 31, 2019, there were no outstanding borrowings under the Line of Credit.
OnIn September 30, 2018,2013, ADA, as borrower, ADES, as guarantor, and the Lender entered into an amendment (the "Twelfth Amendment") to the Line of Credit. The Twelfth Amendment decreased the Line of Credit with a bank for an aggregate principal amount of $10.0 million that was secured by certain amounts due to us from certain Tinuum Group RC leases. The Line of Credit was amended 16 times from the period from December 2, 2013 through March 23, 2021, which included a reduction in the principal amount to $5.0 million due to decreased collateral requirements, extended the maturity date of thein September 2018. The Line of Credit to September 30, 2020 and permitted the Line of Credit to be used as collateral (in place of restricted cash) for letters of credit ("LC's") up to $5.0 million related to equipment projects and certain other agreements. Under the Twelfth Amendment, there was no minimum cash balance requirement basedexpired on us meeting certain conditions and maintaining minimum trailing twelve-month EBITDA (earnings before interest, taxes, depreciation and amortization), as previously defined in the "Eleventh Amendment" to the Line of Credit, of $24.0 million.December 31, 2021.
Cash Flows
On December 7, 2018, ADA, as borrower, ADES as guarantor, and the Lender entered into an amendment to the Line of Credit, which provided, among other things, for ADA to be able to enter into the Senior Term Loan as a guarantor so long as the principal amount of the Senior Term Loan does not exceed $70 million. Additionally, the financial covenants in the Line of Credit were amended and restated to be consistent with the aforementioned Senior Term Loan covenants, including maintaining a minimum cash balance of $5.0 million.
Sources and Uses of Cash
Cash, cash equivalents and restricted cash decreasedincreased from $23.8$35.9 million as of December 31, 20182020 to $17.1$88.8 million as of December 31, 2019, a decrease2021, an increase of $6.7$52.8 million. The following table summarizes our cash flows for the years ended December 31, 20192021 and 2018,2020, respectively: | | | | | Years Ended December 31, | | | | Years Ended December 31, | | | | |
| (in thousands) | | 2019 | | 2018 | | Change | (in thousands) | | 2021 | | 2020 | | | Change | |
| Cash provided by (used in): | | | | | | | Cash provided by (used in): | | | | | | | | |
| | Operating activities | | $ | 62,262 |
| | $ | (9,889 | ) | | $ | 72,151 |
| Operating activities | | $ | 25,999 | | | $ | 54,048 | | | | $ | (28,049) | | |
| | Investing activities | | (13,238 | ) | | (16,543 | ) | | 3,305 |
| Investing activities | | 44,378 | | | (7,466) | | | | 51,844 | | |
| | Financing activities | | (55,716 | ) | | 19,511 |
| | (75,227 | ) | Financing activities | | (17,529) | | | (27,730) | | | | 10,201 | | |
| Net change in Cash and Cash Equivalents and Restricted Cash | | $ | (6,692 | ) | | $ | (6,921 | ) | | $ | 229 |
| Net change in Cash and Cash Equivalents and Restricted Cash | | $ | 52,848 | | | $ | 18,852 | | | | $ | 33,996 | | |
|
Cash flows from operating activities
Cash flows provided by operating activities for the year ended December 31, 2019 increased2021 decreased by $72.2$28.0 million compared to the year ended December 31, 20182020 and were positively impactedthe net decrease was primarily bydue to the following: (1) an increasea decrease in Distributions from equity method investees, return on investment of $68.4 million;$39.5 million year over year; (2) an increase in depreciation, amortization, depletion and accretion of $6.6 million; (3) an increase of $3.4 million in deferred income tax expense; and (4) a net decrease in working capital of $6.9 million, primarily due to a decrease in accrued payroll and related liabilities. Offsetting these increases to operating cash flows was primarily an increase in earningsEarnings from equity method investments of $15.0 million.$37.7 million year over year; (3)Impairment of long-lived assets of $26.1 million recorded in 2020; and (4) Gain on extinguishment of debt of $3.3 million recorded in 2021. Offsetting the net decrease in cash flows provided by operating activities year over year was a net change in net income of $80.7 million year over year as a result of net loss recognized for the year ended December 31, 2020.
Cash flows from investing activities
Cash flows used inprovided by investing activities for the year ended December 31, 2019 decreased by $3.32021 were $44.4 million compared to the year ended December 31, 2018 primarily from the net cash consideration paid in 2018 of $62.5 million for the Carbon Solutions Acquisition. Offsetting this net decrease in cash flows used in investing activities were increasesof $7.5 million for the year ended December 31, 2020. This net increase in cash flows used inprovided by investing activities for acquisition of property, plant, equipment and intangibles of $7.4 million and mine development costs of $4.7 million. In addition, cash flows from investing activities were negatively impacted by a decreasewas primarily due to increases in cash distributions from equity method investees, returnearnings in excess of cumulative earnings of $47.2$51.1 million year over year as all distributions receivedwell as proceeds from Tinuum Groupthe sale of property and equipment in 2019 represent a return on investment and are classified under operating activities.2021.
Cash flows from financing activities
Cash flows used in financing activities for the year ended December 31, 2019 were $55.72021 decreased by $10.2 million compared to cash flows provided by financing activities of $19.5 million for the year ended December 31, 2018. This net increase in cash flows used in financing activities was2020 primarily due to the net borrowings, net of debt issuance costs paid, of $65.9 millionlower principal payments on the Senior Term Loan incurredof $8.0 million. Also contributing to the decrease was a decrease year over year in 2018dividends paid and principal payments made in 2019 on the Senior Term Loan and finance lease obligationsshares repurchased of $30.0$4.9 million and $1.4$0.2 million, respectively. Offsetting this net increase in cash flows used in financing activities were decreasesrespectively, and a reduction in repurchases of common shares of $19.6our common stock to satisfy tax withholdings of $0.3 million. Offsetting the net decrease year over year was $3.3 million of cash proceeds received in 2021 from the forgiveness of the PPP Loan.
Material Cash Requirements
For 2022, we expect to spend $13.0 million in capital expenditures compared to $7.6 million incurred in 2021. This increase is primarily the result of forecasted improvements to the plant, which are estimated to be $7.0 million, product specific capital expenditures related to the Supply Agreement, which are estimated to be $1.0 million and dividends paidroutine, scheduled maintenance improvements.
As of $1.9June 30, 2021, we entered into the Retention Agreements for the purpose of retaining officers and key employees in order to maintain our current business operations, while we pursue and execute on our strategic initiatives. The total amount due at time of payment pursuant to the Retention Agreements is $2.0 million, which we expect to pay in 2022.
We intend to fund the remaining portion of the Reclamation Costs from cash on hand as well as cash generated from the Supply Agreement. We believe that as reclamation activities proceed and the related bonded amounts required under the Surety Agreement are able to be reduced, there may be an opportunity to further reduce the collateral requirement. On a normalized basis, our annual capital expenditures, exclusive of any capital specifically procured for Cabot under the Supply Agreement or capital for major improvements to the plant, are expected to average approximately $5.0 million.
We expect that our cash on hand as of December 31, 2021 will provide sufficient liquidity to fund operations for the next 12 months.
Our contractual
Contractual obligations as of December 31, 20192021 are as follows: | | | | Payment Due by Period |
| (in thousands) | | (in thousands) | | Total | | Less than 1 year | | 1-3 years | | 4-5 years | | After 5 years |
| | | | | Payment Due by Period | |
| (in thousands) | | Total | | Less than 1 year | | 1-3 years | | 4-5 years | | After 5 years | |
| Senior Term Note (1) | | $ | 40,000 |
| | $ | 24,000 |
| | $ | 16,000 |
| | $ | — |
| | $ | — |
| |
| | Finance lease obligations | | 7,908 |
| | 1,707 |
| | 2,753 |
| | 2,880 |
| | 568 |
| Finance lease obligations | | 4,486 | | | 1,008 | | | 2,909 | | | 569 | | | — | |
| Operating lease obligations | | 5,759 |
| | 2,710 |
| | 2,690 |
| | 359 |
| | — |
| Operating lease obligations | | 7,249 | | | 2,502 | | | 2,744 | | | 1,132 | | | 871 | |
| Purchase obligations (2) | | 1,927 |
| | 1,927 |
| | — |
| | — |
| | — |
| |
| | | $ | 55,594 |
| | $ | 30,344 |
| | $ | 21,443 |
| | $ | 3,239 |
| | $ | 568 |
| |
Reclamation liability, Marshall Mine (1) | | Reclamation liability, Marshall Mine (1) | | 7,631 | | | 2,104 | | | 2,885 | | | 1,231 | | | 1,411 | |
| | | | $ | 19,366 | | | $ | 5,614 | | | $ | 8,538 | | | $ | 2,932 | | | $ | 2,282 | |
(1) Includes outstanding principal amountspayments due under a capped fee contract with a third-party mining operator for reclamation of the Marshall Mine (the "Marshall Mine ARO"). Payments on this contract are due through the maturity date.
(2) Represents non-cancellable obligationsapproximately 2031. Reclamation costs related to constructionthe Marshall Mine ARO are based on a stated fee by month structure based on the initial estimate of the total costs of reclamation, which provides for certain contingencies that could increase or decrease the reclamation fee over time. The timing and furnishings for our new corporate officeamount of future payments may change from original estimates, and laboratory facilities that we expect to occupy during the first quarter of 2020.
The table above excludes obligations related to 453A interest payments due to uncertainty of amounts payable in future periods relating to matters impacting future obligations such as our portion of Tinuum Group's deferred tax liability balance under the installment method at each future balance sheet date andCompany assesses changes in interest rates. If no additional RC facilities become invested in theestimated future Tinuum Group's deferred tax liability balance would decrease and interest payments, assuming no changes in the applicable tax and interest rates, would also decrease throughout the periods in the table above.amounts on a quarterly basis.
The table above also excludes our asset retirement obligation ("ARO") related to reclamation of the Five Forks Mine.Mine (the "Five Forks ARO"). As of December 31, 2019,2021, our consolidated balance sheet reflects a liability of $2.7$3.6 million for mine reclamation. Asset retirement obligations arethe Five Forks ARO. The Five Forks Mine ARO was recorded at fair value when incurredvalue. The timing and accretion expense is recognized through the expected date of settlement. Determining the fair value of our asset retirement obligation involves a number of estimates, as discussed in the section entitled “Critical Accounting Policies” below, including the timingamount of payments to satisfy the obligation. The timing of payments to satisfy asset retirement obligations isFive Forks ARO are uncertain and are based on numerous factors including, but not limited to, the Five Forks Mine expected closure date.
We had no outstanding letters of credit as of December 31, 2019.2021. We expect that our cash on hand as of December 31, 2021 will provide sufficient liquidity to fund operations for the next 12 months.
Off-Balance Sheet ArrangementsAs of December 31, 2021, we had outstanding surety bonds of $24.1 million related to performance requirements under reclamation contracts associated with both the Five Forks Mine and the Marshall Mine. As of December 31, 2021, we had restricted cash of $10.0 million securing the Surety Agreement. We expect that the obligations secured by these surety bonds will be performed in the ordinary course of business and in accordance with the applicable contractual terms. To the extent that the obligations are performed, the related surety bonds should be released, and we should not have any continuing obligations. However, in the event any surety bond is called, our indemnity obligations could require us to reimburse the issuer of the surety bond.
During 2019 and 2018, we did not engage in any off-balance sheet financing.
Critical Accounting Policies and Estimates
Our significant accounting policies are discussed in Note 1 to the Consolidated Financial Statements included in Item 8 of this Report. In presenting our financial statements in conformity with GAAP, we are required to make estimates and assumptions that affect the amounts reported therein. Several of the estimates and assumptions we are required to make relate to matters that are inherently uncertain as they pertain to future events. Our estimates are based on historical experience and other assumptions believed to be reasonable under the circumstances, and we evaluate these estimates on an ongoing basis. Actual results may differ from these estimates under different assumptions or conditions.
We believe that the accounting estimates discussed below are critical to understanding our historical and future performance, as these estimates relate to the more significant areas involving management’s judgments and estimates.
Business Combinations, including asset acquisitions
We apply the acquisition method to acquisitions of both businesses and assets and allocate the purchase price of acquired companies to the tangible and intangible assets acquired and liabilities assumed based on their estimated fair values at the Acquisition Date.acquisition date. The purchase price allocation process requires us to make significant estimates and assumptions with respect to property, plantassets acquired and equipment, intangible assets and certain obligations. Although weliabilities assumed. We believe the assumptions and estimates we have mademake are reasonable, they are based in part on historical experience, market conditions and information obtained from management of the acquired companiescompany or group of assets and are inherently uncertain.
Examples of critical estimates in valuing certain of thelong-lived assets, including intangible assets, we have acquired or may acquire in the future include but are not limited to:
•future expected cash flows from revenues;
•historical and expected customer attrition rates and anticipated growth in revenues from acquired customers;
•the acquired company’s developed technology as well as assumptions about the period of time the acquired developed technology will continue to be used in the combined company's product portfolio;
•the expected use and useful lives of the acquired assets; and
•valuation methods and discount rates used in estimating the values of the assets acquired and liabilities assumed.
In regard to the Marshall Mine Acquisition, which we accounted for as an asset acquisition, we recorded the fair value of assumed assets, which included property, plant and equipment and spare parts and assumed liabilities. In addition, we recorded other assets, including Upfront Customer Consideration and the Cabot Receivable, and a liability for the Marshall Mine ARO.
Carrying value of long-lived assets and intangibles;intangibles
We review and evaluate our long-lived assets and intangibles for impairment at least annually, or more frequently when events or changes in circumstances indicate that the related carrying amounts may not be recoverable. An impairment loss is measured and recorded for long-lived assets and intangibles based on the excess of their carrying amounts over their estimated fair value of the long-lived assets or intangibles being tested for impairment and their carrying amounts.values. Fair value is typically determined through the use of an income approach utilizing estimates of discounted pre-taxpretax future cash flows or a market approach utilizing recent transaction activity for comparable properties.assets.
Asset Retirement Obligation
Reclamation costs are related to the Five Forks Mine and are allocated to expense over the life of the related mine assets, and are periodically adjusted to reflect changes in the estimated present value resulting from the passage of time and revisions to the estimates of either the timing or amount of the reclamation costs. Reclamation obligations are based on when the spending for an existing environmental disturbance will occur. We review, on at least an annual basis, the reclamation obligation for the Five Forks Mine.
Remediation costs for the Five Forks Mine are accrued based on management’s best estimate at the end of each period of the costs expected to be incurred. Such cost estimates may include ongoing care, maintenance and monitoring costs.Obligations
Accounting for reclamation and remediation obligationsAROs requires managementus to make estimates of future costs unique to thea specific mining operation of the future coststhat we will incur to complete the reclamation and remediation work required to comply with existing laws and regulations. Any such changes in future costs, the timing of reclamation activities, scope or the exclusion of certain costs not considered reclamation and remediation costs could materially impact the amounts charged to earnings for reclamation and remediation. Additionally, future changes to environmental laws and regulations could increase the extentscope of reclamation and remediation work required.
Five Forks Mine ARO - Reclamation costs related to the Five Forks Mine ARO are allocated to expense over the life of the related mine assets and are periodically adjusted to reflect changes in the estimated present value resulting from the passage of time and revisions to the estimates of either the timing or amount of the reclamation costs. Remediation costs for the Five Forks Mine are accrued based on management’s best estimate of the costs expected to be incurred. Such cost estimates may include ongoing care, maintenance and monitoring costs. Reclamation obligations are based on the timing of estimated spending for an existing environmental disturbance. We review, on at least an annual basis, the future expected costs and the timing of such costs for the Five Forks Mine ARO.
Marshall Mine ARO - Reclamation costs related to the Marshall Mine are based on a capped fee structure for a significant portion of the ARO liability based on the initial estimate of the total costs of reclamation, which provides for certain contingencies that could increase or decrease the reclamation fee based on the reclamation agreement executed between us and the Marshall Mine operator. The timing of payments may vary, and in valuing the the Marshall Mine ARO, we account for these timing differences, as well as changes in actual reclamation costs, on a quarterly basis.
Income Taxes
We account for income taxes as required by GAAP, under the asset and liability method, which managementrequires judgment is required in determining income tax expense and the related balance sheet amounts. This judgment includes estimating and analyzing historical and projected future operating results, the reversal of taxable temporary differences, tax planning strategies, and the ultimate outcome of uncertain income tax positions. Actual income taxes paid may vary from estimates depending uponon changes in income tax laws, actual results of operations, state apportionment and, theif applicable, final auditaudits of tax returns by taxing authorities. Tax assessments may arise several years after tax returns have been filed. Changes in the estimates and assumptions used for calculating income tax expense and potential differences in actual results from estimates could have a material impact on our results of operations and financial condition.
We recognize deferred tax assets to the extent that we believe these assets are more likely than not to be realized. In making such a determination, we consider all available positive and negative evidence, including future reversals of existing taxable temporary differences, projected future taxable income, tax-planning strategies and results of recent operations.
We establish a valuation allowance against our deferred tax assets when, based upon the weight of all available evidence, we believe it is more likely than not that some portion or all of the deferred tax assets will not be realized. As of December 31, 2019 and 2018, we have established valuation allowances for our deferred tax assets that, in our judgment, will not be realized. In making this determination, we have consideredconsider the relative impact of all of the available positive and negative evidence regarding future sources of taxable income and tax planning strategies. However, there could be a material impact to our effective tax rate if there is a
significant change in our estimates of future taxable income and tax planning strategies.income. If and when our estimates change, or there is a change in the gross balancevalue of deferred tax assets or liabilities causingwarranting the need to reassess the realizability of deferred tax assets, we adjust thea valuation allowance through the provision for income taxes in the period in which this determination is made. Refer to Note 1418 of our Consolidated Financial Statements included in Item 8 of this Report for additional information regarding our net deferred tax assets and liabilities and related deferred income tax expense (benefit).
Recently Issued Accounting Standards
Refer to Note 1 of the Consolidated Financial Statements included in Item 8 of this Report for information regarding recently issued accounting standards.
Item 7A. Quantitative and Qualitative Disclosures About Market Risk
The information under this Item is not required to be provided by smaller reporting companies.
Item 8. Financial Statements and Supplementary Data
Advanced Emissions Solutions, Inc.
Index to Financial Statements
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| Advanced Emissions Solutions, Inc. | |
| Consolidated Financial Statements: | |
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Report of Independent Registered Public Accounting Firm
To the StockholdersShareholders and the Board of Directors of
Advanced Emissions Solutions, Inc. and Subsidiaries
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Advanced Emissions Solutions, Inc. and subsidiaries (the “Company”"Company") as of December 31, 20192021 and 2018,2020, the related consolidated statements of operations, changes in stockholders’ equity and cash flows for the years then ended, and the related notes (collectively referred to as the “consolidatedconsolidated financial statements”)statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the consolidated financial position of the Company as of December 31, 20192021 and 2018,2020, and the consolidated results of its operations and its cash flows for the years then ended, in conformity with accounting principles generally accepted in the United States of America.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”), the Company’s internal control over financial reporting as of December 31, 2019, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report dated March 16, 2020 expressed an unqualified opinion on the Company’s internal control over financial reporting.
Change in Accounting Principle
As discussed in Note 1 to the consolidated financial statements, in 2019 the Company changed its method of accounting for leases due to the adoption of Accounting Standards Codification (ASC) 842.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm registered with the PCAOBPublic Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the consolidatedfinancial statements, whether due to error or fraud, and performing procedures to respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidatedfinancial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits providea reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that are material to the consolidated financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Income Taxes – Realizability of Deferred Tax Assets
As described in Notes 1 and 18 to the consolidated financial statements, the Company recognizes deferred income taxes for the effects of temporary differences between the tax basis of an asset or liability and their reported amounts in the accompanying consolidated balance sheet. These temporary differences result in taxable or deductible amounts in future years. Valuation allowances are established, when necessary, to reduce deferred tax assets to the amount that is more likely than not to be realized. As of December 31, 2021, the Company concluded it is more likely than not that the Company will not generate sufficient taxable income within the applicable net operating loss and tax credit carry-forward periods to realize any of its net deferred tax assets, which resulted in a valuation allowance of $87.5 million.
We identified the realizability of deferred tax assets as a critical audit matter due to the Company’s tax structure and the significant judgments and estimates made by management to determine that sufficient taxable income will not be generated to realize a portion of deferred tax assets prior to expiration. This required a high degree of auditor judgment and an increased extent of effort when performing audit procedures to evaluate management’s estimates of taxable income prior to expiration.
The primary procedures we performed to address this critical audit matter included:
•Recalculating the mathematical accuracy of management’s accounting for the previously described taxes, which included supporting calculations, schedules, and reconciliations.
•Reading and evaluating management’s documentation of the accounting for income taxes, including their analysis of the valuation allowance. This includes relevant significant accounting policies, and information obtained by management from third party tax specialists which details management’s basis for the accounting and impact to the consolidated financial statements, inclusive of relevant positive and negative evidence available and utilized in performing the analysis.
•Obtaining and evaluating the supporting tax analyses and documentation prepared by management as a framework and initial support for audit procedures. This includes gaining an understanding of the Company’s estimation process, the Company’s deferred tax calculations, which also integrates management’s analysis of valuation allowances, current tax expenses (benefits), and IRC Section 45 credits.
•Consulting with internal tax specialists in evaluating management’s calculation of its provision for income taxes and that the significant judgments used were applied consistently with the tax code.
•Evaluating whether significant estimates and judgments used were consistent with past performance related to said estimates, the consistency of future forecasts and projections based on current operating and market conditions and future expectations, and that all were consistent with evidence obtained in procedures performed in other areas of the audit.
•Evaluating the adequacy of the Company’s disclosure in Notes 1 and 18 in relation to the income taxes.
/s/ Moss Adams LLP
Denver, Colorado
March 16, 20208, 2022
We have served as the Company’s auditor since 2017.
Advanced Emissions Solutions, Inc. and Subsidiaries
Consolidated Balance Sheets | | | | | As of December 31, | | As of December 31, |
| (in thousands, except share data) | | 2019 | | 2018 | (in thousands, except share data) | | 2021 | | 2020 |
| ASSETS | | | | | ASSETS | | | | |
| Current assets: | | | | | Current assets: | |
| Cash, cash equivalents and restricted cash | | $ | 12,080 |
| | $ | 18,577 |
| |
| Cash, cash equivalents and restricted cast | | Cash, cash equivalents and restricted cast | | $ | 78,753 | | | $ | 30,932 | |
| | Receivables, net | | 7,430 |
| | 9,554 |
| Receivables, net | | 12,622 | | | 13,125 | |
| Receivables, related party | | 4,246 |
| | 4,284 |
| Receivables, related party | | 2,481 | | | 3,453 | |
| | Inventories, net | | 15,460 |
| | 21,791 |
| Inventories, net | | 7,850 | | | 9,882 | |
| Prepaid expenses and other assets | | 7,832 |
| | 5,570 |
| |
| | Prepaid expenses and other current assets | | Prepaid expenses and other current assets | | 6,661 | | | 4,597 | |
| Total current assets | | 47,048 |
| | 59,776 |
| Total current assets | | 108,367 | | | 61,989 | |
| Restricted cash, long-term | | 5,000 |
| | 5,195 |
| Restricted cash, long-term | | 10,027 | | | 5,000 | |
| Property, plant and equipment, net of accumulated depreciation of $7,444 and $1,499, respectively | | 44,001 |
| | 42,697 |
| |
| Property, plant and equipment, net of accumulated depreciation of $7,684 and $3,340, respectively | | Property, plant and equipment, net of accumulated depreciation of $7,684 and $3,340, respectively | | 30,171 | | | 29,433 | |
| Intangible assets, net | | 4,169 |
| | 4,830 |
| Intangible assets, net | | 1,237 | | | 1,964 | |
| | Equity method investments | | 39,155 |
| | 6,634 |
| Equity method investments | | 2,391 | | | 7,692 | |
| Deferred tax assets, net | | 14,095 |
| | 32,539 |
| Deferred tax assets, net | | — | | | 10,604 | |
| Other long-term assets, net | | 20,331 |
| | 7,993 |
| Other long-term assets, net | | 33,243 | | | 29,989 | |
| Total Assets | | $ | 173,799 |
| | $ | 159,664 |
| Total Assets | | $ | 185,436 | | | $ | 146,671 | |
| LIABILITIES AND STOCKHOLDERS’ EQUITY | | | | | LIABILITIES AND STOCKHOLDERS’ EQUITY | | | | |
| Current liabilities: | | | | | Current liabilities: | |
| Accounts payable | | $ | 8,046 |
| | $ | 6,235 |
| Accounts payable | | $ | 10,009 | | | $ | 7,849 | |
| Accrued payroll and related liabilities | | 3,024 |
| | 8,279 |
| Accrued payroll and related liabilities | | 6,477 | | | 3,257 | |
| Current portion of long-term debt | | 23,932 |
| | 24,067 |
| Current portion of long-term debt | | 1,011 | | | 18,441 | |
| | Other current liabilities | | 4,311 |
| | 2,138 |
| Other current liabilities | | 5,124 | | | 12,996 | |
| Total current liabilities | | 39,313 |
| | 40,719 |
| Total current liabilities | | 22,621 | | | 42,543 | |
| Long-term debt, net of current portion | | 20,434 |
| | 50,058 |
| Long-term debt, net of current portion | | 3,152 | | | 5,445 | |
| | Other long-term liabilities | | 5,760 |
| | 940 |
| Other long-term liabilities | | 12,362 | | | 13,473 | |
| Total Liabilities | | 65,507 |
| | 91,717 |
| Total Liabilities | | 38,135 | | | 61,461 | |
| Commitments and contingencies (Notes 6 and 9) | |
| |
| |
| Commitments and contingencies (Note 14) | | Commitments and contingencies (Note 14) | | 0 | | 0 |
| Stockholders’ equity: | | | | | Stockholders’ equity: | |
| Preferred stock: par value of $.001 per share, 50,000,000 shares authorized, none outstanding | | — |
| | — |
| Preferred stock: par value of $.001 per share, 50,000,000 shares authorized, none outstanding | | — | | | — | |
| Common stock: par value of $.001 per share, 100,000,000 shares authorized, 22,960,157 and 22,640,677 shares issued and 18,362,624 and 18,576,489 shares outstanding at December 31, 2019 and 2018, respectively | | 23 |
| | 23 |
| |
| Treasury stock, at cost: 4,597,533 and 4,064,188 shares as of December 31, 2019 and 2018, respectively | | (47,533 | ) | | (41,740 | ) | |
| Common stock: par value of $.001 per share, 100,000,000 shares authorized, 23,460,212 and 23,141,284 shares issued and 18,842,066 and 18,523,138 shares outstanding at December 31, 2021 and 2020, respectively | | Common stock: par value of $.001 per share, 100,000,000 shares authorized, 23,460,212 and 23,141,284 shares issued and 18,842,066 and 18,523,138 shares outstanding at December 31, 2021 and 2020, respectively | | 23 | | | 23 | |
| Treasury stock, at cost: 4,618,146 and 4,618,146 shares as of December 31, 2021 and 2020, respectively | | Treasury stock, at cost: 4,618,146 and 4,618,146 shares as of December 31, 2021 and 2020, respectively | | (47,692) | | | (47,692) | |
| Additional paid-in capital | | 98,466 |
| | 96,750 |
| Additional paid-in capital | | 102,106 | | | 100,425 | |
| Retained earnings | | 57,336 |
| | 12,914 |
| Retained earnings | | 92,864 | | | 32,454 | |
| | Total stockholders’ equity | | 108,292 |
| | 67,947 |
| Total stockholders’ equity | | 147,301 | | | 85,210 | |
| Total Liabilities and Stockholders’ equity | | $ | 173,799 |
| | $ | 159,664 |
| Total Liabilities and Stockholders’ equity | | $ | 185,436 | | | $ | 146,671 | |
See Notes to the Consolidated Financial Statements.
Advanced Emissions Solutions, Inc. and Subsidiaries
Consolidated Statements of Operations
| | | | | Years Ended December 31, | | Years Ended December 31, | |
| (in thousands, except per share data) | | 2019 | | 2018 | (in thousands, except per share data) | | 2021 | | 2020 | |
| Revenues: | | | | | Revenues: | | | | | |
| Consumables | | $ | 53,187 |
| | $ | 8,733 |
| Consumables | | $ | 85,882 | | | $ | 53,908 | | |
| License royalties, related party | | 16,899 |
| | 15,140 |
| License royalties, related party | | 14,368 | | | 13,440 | | |
| Other | | — |
| | 72 |
| Other | | 44 | | | 15 | | |
| | Total revenues | | 70,086 |
| | 23,945 |
| Total revenues | | 100,294 | | | 67,363 | | |
| Operating expenses: | | | | | Operating expenses: | | | | | |
| Consumables cost of revenue, exclusive of depreciation and amortization | | 49,443 |
| | 6,606 |
| |
| Other cost of revenue, exclusive of depreciation and amortization | | — |
| | (353 | ) | |
| Consumables cost of revenues, exclusive of depreciation and amortization | | Consumables cost of revenues, exclusive of depreciation and amortization | | 65,576 | | | 50,962 | | |
| Other cost of revenues, exclusive of depreciation and amortization | | Other cost of revenues, exclusive of depreciation and amortization | | — | | | (563) | | |
| | Payroll and benefits | | 10,094 |
| | 10,639 |
| Payroll and benefits | | 11,315 | | | 10,621 | | |
| Legal and professional fees | | 9,948 |
| | 8,552 |
| Legal and professional fees | | 6,260 | | | 5,585 | | |
| General and administrative | | 8,123 |
| | 4,178 |
| General and administrative | | 7,060 | | | 8,228 | | |
| Depreciation, amortization, depletion and accretion | | 7,371 |
| | 723 |
| Depreciation, amortization, depletion and accretion | | 7,933 | | | 8,537 | | |
| Gain on change in estimate, asset retirement obligation | | Gain on change in estimate, asset retirement obligation | | (2,702) | | | — | | |
| Impairment of long-lived assets | | Impairment of long-lived assets | | — | | | 26,103 | | |
| Gain on settlement | | Gain on settlement | | — | | | (1,129) | | |
| | Total operating expenses | | 84,979 |
| | 30,345 |
| Total operating expenses | | 95,442 | | | 108,344 | | |
| Operating loss | | (14,893 | ) | | (6,400 | ) | |
| Operating income (loss) | | Operating income (loss) | | 4,852 | | | (40,981) | | |
| Other income (expense): | | | | | Other income (expense): | | | | | |
| Earnings from equity method investments | | 69,176 |
| | 54,208 |
| Earnings from equity method investments | | 68,726 | | | 30,978 | | |
| Gain on extinguishment of debt | | Gain on extinguishment of debt | | 3,345 | | | — | | |
| | Interest expense | | (7,174 | ) | | (2,151 | ) | Interest expense | | (1,490) | | | (3,920) | | |
| | Other | | 427 |
| | 220 |
| Other | | 640 | | | 132 | | |
| Total other income | | 62,429 |
| | 52,277 |
| Total other income | | 71,221 | | | 27,190 | | |
| Income before income tax expense | | 47,536 |
| | 45,877 |
| |
| Income (loss) before income tax expense | | Income (loss) before income tax expense | | 76,073 | | | (13,791) | | |
| Income tax expense | | 11,999 |
| | 10,423 |
| Income tax expense | | 15,672 | | | 6,511 | | |
| Net income | | $ | 35,537 |
| | $ | 35,454 |
| |
| Earnings per common share (Note 1): | | | | | |
| Net income (loss) | | Net income (loss) | | $ | 60,401 | | | $ | (20,302) | | |
| Earnings (loss) per common share (Note 1): | | Earnings (loss) per common share (Note 1): | | | | | |
| Basic | | $ | 1.96 |
| | $ | 1.78 |
| Basic | | $ | 3.31 | | | $ | (1.12) | | |
| Diluted | | $ | 1.93 |
| | $ | 1.76 |
| Diluted | | $ | 3.27 | | | $ | (1.12) | | |
| Weighted-average number of common shares outstanding: | | | | | Weighted-average number of common shares outstanding: | | |
| Basic | | 18,154 |
| | 19,901 |
| Basic | | 18,258 | | | 18,044 | | |
| Diluted | | 18,372 |
| | 20,033 |
| Diluted | | 18,461 | | | 18,044 | | |
|
See Notes to the Consolidated Financial Statements.
Advanced Emissions Solutions, Inc. and Subsidiaries
Consolidated Statements of Changes in Stockholders’ Equity
| | | | Common Stock | | Treasury Stock | | | |
| (in thousands, except share data) | | (in thousands, except share data) | | Shares | | Amount | | Shares | | Amount | | Additional Paid-in Capital | | Retained Earnings/(Accumulated Deficit) | | | Total Stockholders’
Equity |
| | | | | Common Stock | | Treasury Stock | | | | | | | |
| (in thousands, except share data) | | Shares | | Amount | | Shares | | Amount | | Additional Paid-in Capital | | Retained Earnings/(Accumulated Deficit) | | Total Stockholders’
Equity | |
| Balances, January 1, 2018 | | 22,465,821 |
| | $ | 22 |
| | (1,713,766 | ) | | $ | (16,397 | ) | | $ | 105,308 |
| | $ | (15,478 | ) | | $ | 73,455 |
| |
| Cumulative effect of change in accounting principle (Note 8) | | — |
| | — |
| | — |
| | — |
| | — |
| | 2,950 |
| | 2,950 |
| |
| | Balances, January 1, 2020 | | Balances, January 1, 2020 | | 22,960,157 | | | $ | 23 | | | (4,597,533) | | | $ | (47,533) | | | $ | 98,466 | | | $ | 57,336 | | | | $ | 108,292 | |
| | Stock-based compensation | | 217,174 |
| | 1 |
| | — |
| | — |
| | 2,489 |
| | — |
| | 2,490 |
| Stock-based compensation | | 278,910 | | | — | | | — | | | — | | | 2,496 | | | — | | | | 2,496 | |
| Issuance of stock upon exercise of options, net | | 18,667 |
| | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| |
| | Repurchase of common shares to satisfy tax withholdings | | (60,985 | ) | | — |
| | — |
| | — |
| | (769 | ) | | — |
| | (769 | ) | Repurchase of common shares to satisfy tax withholdings | | (97,783) | | | — | | | — | | | — | | | (537) | | | — | | | | (537) | |
| | Cash dividends declared on common stock | | — |
| | — |
| | — |
| | — |
| | (10,278 | ) | | (10,012 | ) | | (20,290 | ) | Cash dividends declared on common stock | | — | | | — | | | — | | | — | | | — | | | (4,580) | | | | (4,580) | |
| Repurchase of common shares | | — |
| | — |
| | (2,350,422 | ) | | (25,343 | ) | | — |
| | — |
| | (25,343 | ) | Repurchase of common shares | | — | | | — | | | (20,613) | | | (159) | | | — | | | — | | | | (159) | |
| | Net loss | | Net loss | | — | | | — | | | — | | | — | | | — | | | (20,302) | | | | (20,302) | |
| Balances, December 31, 2020 | | Balances, December 31, 2020 | | 23,141,284 | | | $ | 23 | | | (4,618,146) | | | $ | (47,692) | | | $ | 100,425 | | | $ | 32,454 | | | | $ | 85,210 | |
| | Stock-based compensation | | Stock-based compensation | | 364,657 | | | — | | | — | | | — | | | 1,927 | | | — | | | | 1,927 | |
| | Repurchase of common shares to satisfy tax withholdings | | Repurchase of common shares to satisfy tax withholdings | | (45,729) | | | — | | | — | | | — | | | (246) | | | — | | | | (246) | |
| | Accrued dividends cancelled on common stock | | Accrued dividends cancelled on common stock | | — | | | — | | | — | | | — | | | — | | | 9 | | | | 9 | |
| | Net income | | — |
| | — |
| | — |
| | — |
| | — |
| | 35,454 |
| | 35,454 |
| Net income | | — | | | — | | | — | | | — | | | — | | | 60,401 | | | | 60,401 | |
| Balances, December 31, 2018 | | 22,640,677 |
| | $ | 23 |
| | (4,064,188 | ) | | $ | (41,740 | ) | | $ | 96,750 |
| | $ | 12,914 |
| | $ | 67,947 |
| |
| Cumulative effect of change in accounting principle (Note 5) | | — |
| | — |
| | — |
| | — |
| | — |
| | 27,442 |
| | 27,442 |
| |
| Stock-based compensation | | 298,573 |
| | — |
| | — |
| | — |
| | 2,011 |
| | — |
| | 2,011 |
| |
| Issuance of stock upon exercise of options, net | | 50,268 |
| | — |
| | — |
| | — |
| | 156 |
| | — |
| | 156 |
| |
| Repurchase of common shares to satisfy tax withholdings | | (29,361 | ) | | — |
| | — |
| | — |
| | (451 | ) | | — |
| | (451 | ) | |
| Cash dividends declared on common stock | | — |
| | — |
| | — |
| | — |
| | — |
| | (18,557 | ) | | (18,557 | ) | |
| Repurchase of common shares | | — |
| | — |
| | (533,345 | ) | | (5,793 | ) | | — |
| | — |
| | (5,793 | ) | |
| Net income | | — |
| | — |
| | — |
| | — |
| | — |
| | 35,537 |
| | 35,537 |
| |
| Balances, December 31, 2019 | | 22,960,157 |
| | $ | 23 |
| | (4,597,533 | ) | | $ | (47,533 | ) | | $ | 98,466 |
| | $ | 57,336 |
| | $ | 108,292 |
| |
| Balances, December 31, 2021 | | Balances, December 31, 2021 | | 23,460,212 | | | $ | 23 | | | (4,618,146) | | | $ | (47,692) | | | $ | 102,106 | | | $ | 92,864 | | | | $ | 147,301 | |
See Notes to the Consolidated Financial Statements.
Advanced Emissions Solutions, Inc. and Subsidiaries
Consolidated Statements of Cash Flows
| | | | | | | | | | | | | | | | |
| | Years Ended December 31, | | |
| (in thousands) | | 2021 | | 2020 | | |
| Cash flows from operating activities | | | | | | |
| Net income (loss) | | $ | 60,401 | | | $ | (20,302) | | | |
| Adjustments to reconcile net income (loss) to net cash provided by operating activities: | | | | | | |
| Deferred income tax expense | | 10,604 | | | 3,491 | | | |
| Depreciation, amortization, depletion and accretion | | 7,933 | | | 8,537 | | | |
| Amortization of debt discount and debt issuance costs | | 945 | | | 1,418 | | | |
| Operating lease expense | | 2,038 | | | 3,559 | | | |
| Gain on extinguishment of debt | | (3,345) | | | — | | | |
| Gain on change in estimate, asset retirement obligation | | (2,702) | | | — | | | |
| Impairment of long-lived assets | | — | | | 26,103 | | | |
| Gain on settlement | | — | | | (1,129) | | | |
| Recovery of accounts receivable and other receivables | | (36) | | | (990) | | | |
| | | | | | |
| | | | | | |
| Stock-based compensation expense | | 1,927 | | | 2,496 | | | |
| | | | | | |
| Earnings from equity method investments | | (68,726) | | | (30,978) | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Other non-cash items, net | | (173) | | | 192 | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Changes in operating assets and liabilities, net of effects of acquired businesses: | | | | | | |
| Receivables, net | | 540 | | | (2,541) | | | |
| Related party receivables | | 972 | | | 794 | | | |
| Prepaid expenses and other current assets | | (2,064) | | | 3,234 | | | |
| | | | | | |
| Inventories, net | | 1,394 | | | 4,748 | | | |
| | | | | | |
| Other long-term assets, net | | 1,838 | | | (1,005) | | | |
| Accounts payable | | 1,977 | | | (196) | | | |
| Accrued payroll and related liabilities | | 3,220 | | | 233 | | | |
| Other current liabilities | | (8,279) | | | (520) | | | |
| | | | | | |
| Operating lease liabilities | | (2,764) | | | (2,200) | | | |
| Other long-term liabilities | | (2,645) | | | (3,337) | | | |
| | | | | | |
| Distributions from equity method investees, return on investment | | 22,944 | | | 62,441 | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Net cash provided by operating activities | | 25,999 | | | 54,048 | | | |
|
| | | | | | | | |
| | | Years Ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Cash flows from operating activities | | | | |
| Net income | | $ | 35,537 |
| | $ | 35,454 |
|
| Adjustments to reconcile net income to net cash used in operating activities: | | | | |
| Deferred income tax expense | | 8,655 |
| | 5,233 |
|
| Depreciation, amortization, depletion and accretion | | 7,371 |
| | 723 |
|
| Amortization of debt discount and debt issuance costs | | 1,678 |
| | 94 |
|
| Operating lease expense | | 3,192 |
| | — |
|
| Stock-based compensation expense, net | | 2,011 |
| | 2,490 |
|
| Earnings from equity method investments | | (69,176 | ) | | (54,208 | ) |
| Other non-cash items, net | | 638 |
| | 289 |
|
| Changes in operating assets and liabilities, net of effects of acquired businesses: | | | | |
| Receivables, net | | 2,124 |
| | (1,847 | ) |
| Related party receivables | | 37 |
| | (1,037 | ) |
| Prepaid expenses and other assets | | (2,200 | ) | | (757 | ) |
| Costs incurred on uncompleted contracts | | — |
| | 15,945 |
|
| Inventories, net | | 5,505 |
| | 237 |
|
| Other long-term assets, net | | (262 | ) | | (753 | ) |
| Accounts payable | | 2,218 |
| | (197 | ) |
| Accrued payroll and related liabilities | | (5,255 | ) | | (59 | ) |
| Other current liabilities | | (261 | ) | | (869 | ) |
| Billings on uncompleted contracts | | — |
| | (15,945 | ) |
| Operating lease liabilities | | (3,180 | ) | | — |
|
| Other long-term liabilities | | (258 | ) | | (182 | ) |
| Distributions from equity method investees, return on investment | | 73,888 |
| | 5,500 |
|
| Net cash provided by (used in) operating activities | | 62,262 |
| | (9,889 | ) |
| | | | | Years Ended December 31, | | Years Ended December 31, | |
| (in thousands) | | 2019 | | 2018 | (in thousands) | | 2021 | | 2020 | |
| Cash flows from investing activities | | | | | Cash flows from investing activities | | | | | |
| Distributions from equity method investees in excess of cumulative earnings | | $ | — |
| | $ | 47,175 |
| Distributions from equity method investees in excess of cumulative earnings | | $ | 51,082 | | | $ | — | | |
| Acquisition of business, net of cash acquired | | (661 | ) | | (62,501 | ) | |
| Acquisition of property, plant, equipment, and intangible assets, net | | (7,851 | ) | | (467 | ) | |
| Acquisition of property, equipment and intangible assets, net | | Acquisition of property, equipment and intangible assets, net | | (6,201) | | | (6,685) | | |
| Mine development costs | | (4,726 | ) | | — |
| Mine development costs | | (1,398) | | | (781) | | |
| Contributions to equity method investee | | — |
| | (750 | ) | |
| Net cash used in investing activities | | (13,238 | ) | | (16,543 | ) | |
| | Proceeds from sale of property and equipment | | Proceeds from sale of property and equipment | | 895 | | | — | | |
| | Net cash provided by (used in) investing activities | | Net cash provided by (used in) investing activities | | 44,378 | | | (7,466) | | |
| Cash flows from financing activities | | | | | Cash flows from financing activities | | | | | |
| Principal payments on term loan | | (30,000 | ) | | — |
| Principal payments on term loan | | (16,000) | | | (24,000) | | |
| Principal payments on finance lease obligations | | (1,354 | ) | | — |
| Principal payments on finance lease obligations | | (1,190) | | | (1,360) | | |
| Borrowings, net of debt discount - related party | | — |
| | 67,900 |
| |
| Debt issuance costs paid | | — |
| | (2,036 | ) | |
| | Dividends paid | | (18,274 | ) | | (20,165 | ) | Dividends paid | | (93) | | | (4,979) | | |
| Borrowings from Paycheck Protection Program Loan | | Borrowings from Paycheck Protection Program Loan | | — | | | 3,305 | | |
| Repurchase of shares to satisfy tax withholdings | | Repurchase of shares to satisfy tax withholdings | | (246) | | | (537) | | |
| Repurchase of common shares | | (5,793 | ) | | (25,343 | ) | Repurchase of common shares | | — | | | (159) | | |
| Repurchase of shares to satisfy tax withholdings | | (451 | ) | | (769 | ) | |
| Other | | 156 |
| | (76 | ) | |
| Net cash (used in) provided by financing activities | | (55,716 | ) | | 19,511 |
| |
| Decrease in Cash, Cash Equivalents and Restricted Cash | | (6,692 | ) | | (6,921 | ) | |
| | Net cash used in financing activities | | Net cash used in financing activities | | (17,529) | | | (27,730) | | |
| Increase in Cash, Cash Equivalents and Restricted Cash | | Increase in Cash, Cash Equivalents and Restricted Cash | | 52,848 | | | 18,852 | | |
| Cash, Cash Equivalents and Restricted Cash, beginning of year | | 23,772 |
| | 30,693 |
| Cash, Cash Equivalents and Restricted Cash, beginning of year | | 35,932 | | | 17,080 | | |
| Cash, Cash Equivalents and Restricted Cash, end of year | | $ | 17,080 |
| | $ | 23,772 |
| Cash, Cash Equivalents and Restricted Cash, end of year | | $ | 88,780 | | | $ | 35,932 | | |
| Supplemental disclosure of cash flow information: | | | | | Supplemental disclosure of cash flow information: | | | | | |
| Cash paid for interest | | $ | 5,650 |
| | $ | 1,400 |
| Cash paid for interest | | $ | 524 | | | $ | 2,489 | | |
| Cash paid for income taxes, net of refunds received | | $ | 4,308 |
| | $ | 7,460 |
| |
| Cash paid (received) for income taxes | | Cash paid (received) for income taxes | | $ | 8,882 | | | $ | (84) | | |
| Supplemental disclosure of non-cash investing and financing activities: | | | | | Supplemental disclosure of non-cash investing and financing activities: | | |
| Acquisition consideration payable | | $ | — |
| | $ | 661 |
| |
| Change in accrued purchases for property and equipment | | Change in accrued purchases for property and equipment | | $ | 183 | | | $ | — | | |
| Change in asset retirement obligation | | Change in asset retirement obligation | | $ | 121 | | | $ | 421 | | |
| Acquisition of property and equipment under finance lease | | Acquisition of property and equipment under finance lease | | $ | — | | | $ | 158 | | |
| | Dividends payable | | $ | 284 |
| | $ | 125 |
| Dividends payable | | $ | — | | | $ | 32 | | |
See Notes to the Consolidated Financial Statements.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Note 1 - Summary of Operations and Significant Accounting Policies
Nature of Operations
Advanced Emissions Solutions, Inc. ("ADES" or the "Company") is a Delaware corporation with its principal office located in Highlands Ranch,Greenwood Village, Colorado and operations located in Louisiana. The Company is principally engaged in the sale of consumable mercury controlair and water treatment options including powdered activated carbon ("PAC"AC") and chemical technologies. The Company's proprietary environmental technologies in the power generation and industrialadvanced purification technologies ("PGI"APT") market enable customers to reduce emissions ofair and water contaminants, including mercury and other pollutants, to maximize utilization levels and to improve operating efficiencies to meet the challenges of existing and pending emission control regulations. The Company generates substantial earnings and tax credits under Section 45 ("Section 45 tax credits") of the Internal Revenue Code ("IRC") fromThrough its equity investments in certain entities and earns royalties for technologies that are licensed to Tinuum Group, LLC, a Colorado limited liability company ("Tinuum Group"). Such technologies allow Tinuum Group to provide their customers with various solutions to enhance combustion and reduced emissions of nitrogen oxide ("NOx") and mercury from coal burned to generate electrical power. The Company’s sales occur principally throughout the United States. See Note 15 for additional information regarding the Company's operating segments.
On December 7, 2018 (the "Acquisition Date"), the Company acquired (the "Carbon Solutions Acquisition") 100% of the equity interests ofwholly-owned subsidiary, ADA Carbon Solutions, LLC (“("Carbon Solutions”Solutions"). Carbon Solutions is a manufacturer, the Company manufactures and seller of activated carbon ("AC")sells AC used to capture and the North American leader in mercury capture using PACremove contaminants for the coal-fired power plant,plants, industrial and water treatment markets. Carbon Solutions also owns an associated lignite mine (the "Five("Five Forks Mine") that supplies the primary raw material for manufacturing AC.
Through its equity ownership in Tinuum Group, LLC ("Tinuum Group") and Tinuum Services, LLC ("Tinuum Services"), both of which are unconsolidated entities, the activated carbon plant. Carbon Solutions was formed in 2008Company generates substantial earnings. Tinuum Group provides reduction of mercury and nitrogen oxide ("NOx") emissions at select coal-fired power generators through the production and sale of refined coal ("RC") that qualifies for tax credits ("Section 45 tax credits") under the Internal Revenue Code ("IRC") Section 45 - Production Tax Credit (the "Section 45 tax credit program"). The Company also earns royalties for technologies that are licensed to Tinuum Group and used at certain RC facilities to enhance combustion and reduced emissions of NOx and mercury from coal burned to generate electrical power. Tinuum Services operates and maintains the RC facilities under operating and maintenance agreements with Tinuum Group and owners or lessees of the RC facilities.
Effective December 31, 2021, the Section 45 tax credit program expired and, as a 50/50 joint venture by the Companyresult, both Tinuum Group and Energy Capital Partners LLC. The Company relinquished its ownershipTinuum Services ceased operations and are winding down their respective businesses. Beginning in 20112022, our equity earnings generated from both Tinuum Group and Tinuum Services are expected to be minimal. In addition, license royalties earned from Tinuum Group ceased as part of a legal settlement agreement as described in the Company's Annual Report on Form 10-K for the fiscal year ended December 31, 2017. The Company acquired Carbon Solutions primarily to expand the Company's product offerings in the mercury control industry and other complementary AC markets.2021.
Principles of Consolidation
The Consolidated Financial Statements include accounts of wholly-owned subsidiaries.subsidiaries and variable interest entities ("VIEs") in which the Company is the primary beneficiary. All significant intercompany balances and transactions have been eliminated in consolidation.
All investments in partially owned entities for which the Company has greater than 20% ownership are accounted for using the equity method based on the legal form of the Company's ownership percentage and the applicable ownership percentage of the entity and are included in the Equity method investments line item in the Consolidated Balance Sheet.Sheets. As of December 31, 2019,2021, the Company holds equity interests of 42.5% and 50.0% in Tinuum Group and Tinuum Services, LLC ("Tinuum Services"), respectively. Tinuum Group is deemed to be variable interest entity ("VIE") under the VIE model of consolidation, but the Company does not consolidate Tinuum Group as it is not deemed to be its primary beneficiary.
Cash, cash equivalents and restricted cash
Cash and cash equivalents include bank deposits and other highly liquid investments purchased with an original maturity of three months or less.
Restricted cash primarily consists of a surety bond indemnification agreement (the "Surety Agreement") associated with reclamation of a mine. As of December 31, 2020, restricted cash also consisted of minimum cash balance requirements under the Term Loan and Security Agreementa line of credit agreement (the "Senior Term Loan""Line of Credit") andwith a bank (the "Lender"). Restricted cash is classified according toconsistent with the period at which it will no longer be restricted.underlying obligation.
Receivables, net
Receivables, net are recorded at net realizable value. This carrying value, which includes an appropriate allowance for estimated uncollectible amounts to reflect any loss anticipated on the receivables balances. Increases and decreases in the allowance for doubtful accounts are established based upon changes in the credit quality of receivables and are included as a component of the General and administrative line item in the Consolidated Statements of Operations. The allowance for doubtful accounts is based on historical experience, general economic conditions and the credit quality of specific accounts.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Inventories, net
Inventories, net are stated at the lower of average cost or net realizable value and consist principally of raw materials and finished goods related to the Company's PACAC and chemical product offerings. The cost of inventory is determined using the average cost method.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Inventories are periodically reviewed for both potential obsolescence and potential declines in anticipated selling prices. In this review, the Company makes assumptions about the future demand for and market value of the inventory and based on these assumptions estimates the amount of any obsolete, unmarketable, slow moving or overvalued inventory. TheIf applicable, the Company will write down the value of inventories by an amount equal to the difference between the cost of the inventory and its estimated net realizable value.
Additional details regarding Inventory balances are included in Note 3.9.
Intangible Assets
Intangible assets consist of patents, licensed technology, customer relationships, developed technologies and trade names.
The Company has developed technologies resulting in patents being granted by the U.S. Patent and Trademark Office.Office or other regulatory offices. Legal costs associated with securing the patent are capitalized and amortized over the legal or useful life beginning on the patent filing date. The remaining intangible assets were recorded at fair value in connection with the Carbon Solutions Acquisition.
The following table details the components of the Company's intangible assets:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | As of December 31, |
| | | | 2021 | | 2020 |
| (in thousands, except years) | | Weighted Average Useful Life (in years) | | Cost | | Net of Accumulated Amortization | | Cost(1) | | Net of Accumulated Amortization |
| Customer relationships | | 5 | | $ | 835 | | | $ | 470 | | | $ | 835 | | | $ | 713 | |
| Patents | | 15 | | 1,454 | | | 426 | | | 1,306 | | | 733 | |
| Developed technology | | 5 | | 607 | | | 341 | | | 607 | | | 518 | |
| | | | | | | | | | |
| | | | | | | | | | |
| Total | | | | $ | 2,896 | | | $ | 1,237 | | | $ | 2,748 | | | $ | 1,964 | |
|
| | | | | | | | | | | | | | | | | | |
| | | | | As of December 31, |
| | | | | 2019 | | 2018 |
| (in thousands, except years) | | Weighted average amortization (in years) | | Initial Cost | | Net of Accumulated Amortization | | Initial Cost | | Net of Accumulated Amortization |
| Customer relationships | | 5 | | $ | 2,200 |
| | $ | 1,731 |
| | $ | 2,100 |
| | $ | 2,071 |
|
| Patents | | 16 | | 1,489 |
| | 1,039 |
| | 1,244 |
| | 891 |
|
| Developed technology | | 5 | | 1,600 |
| | 1,259 |
| | 1,600 |
| | 1,578 |
|
| Trade name | | 2 | | 300 |
| | 140 |
| | 300 |
| | 290 |
|
| Total | | | | $ | 5,589 |
| | $ | 4,169 |
| | $ | 5,244 |
| | $ | 4,830 |
|
Included in the Consolidated Statements of Operations is amortization expense related to intangible assets of $1.0$0.9 million and $0.2$1.0 million for the years ended December 31, 20192021 and 2018,2020, respectively. The estimated future amortization expense for existing intangible assets as of December 31, 20192021 is expected to be $0.8$0.2 million for each of the five succeeding fiscal years.
Investments
The investments in entities in which the Company does not have a controlling interest (financial or operating), but where it has the ability to exercise significant influence over operating and financial policies, are accounted for using the equity method of accounting. Whether or not the Company exercises significant influence with respect to an investee depends on an evaluation of several factors including, among others, representation on the investee company’s board of directors and the Company's ownership level. Under the equity method of accounting, an investee company’s accountsfinancial statements are not reflectedconsolidated in the Company’s Consolidated Balance Sheets and Consolidated Statements of Operations; however, the Company’s share of the earnings or losses of the investee company is reported in the Earnings"Earnings from equity method investmentsinvestments" line item in the Consolidated Statements of Operations, and the Company’s carrying value in an equity method investee company is reported in the Equity"Equity method investments investments"line in the Consolidated Balance Sheet.Sheets.
When the Company receives distributions in excess of the carrying value of the investment and has not guaranteed any obligations of the investee and/or is not required to provide additional funding to the investee, the Company recognizes such excess distributions as equity method earnings in the period the distributions occur. When the investee subsequently reports income, the Company does not record its share of such income until it equals the amount of distributions in excess of carrying value that were previously recognized in income. During the years ended December 31, 20192021 and 2018,2020, the Company had no guarantees or requirements to provide additional funding to investees.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Additionally, when the Company's carrying value in an equity method investment is zero, and the Company has not guaranteed any obligations of the investee and/or is not required to provide additional funding to the investee, the Company will not recognize its share of any reported losses by the investee until future earnings are generated to offset previously unrecognized losses. As a result, equity income or loss reported onin the Company's Consolidated Statements of Operations for certain equity method investees may differ from a mathematical calculation of net income or loss attributable to its equity interest based on
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
the percentage ownership of the Company's equity interest and the net income or loss attributable to equity owners as shown onin the investee company's statements of operations. Likewise, distributions from equity method investees are reported onin the Consolidated Statements of Cash Flows as “return"return on investment”investment" in Operating cash flows until such time as the carrying value in an equity method investee company is reduced to zero; thereafter, such distributions are reported as “distributions"distributions in excess of cumulative earnings”earnings" in Investing cash flows. See Note 58 for additional information regarding the Company's equity method investments.
Investments in partially-owned subsidiaries for which the Company has less-than-20% ownership are accounted for in accordance with accounting principles generally accepted in the United States ("U.S. GAAP")guidance applicable to equity investments that do not qualify for the equity method of accounting. The Company evaluates these types of investments for changes in fair value and, if there is change, recognizes the change in the Consolidated Statement of Operations. If no such events or changes in circumstances have occurred related to these types of investments, the fair value is estimated only if practicable to do so.
Property, Plant and Equipment
Property, plant and equipment isare stated at cost less accumulated depreciation and includes leasehold improvements. Depreciation on assets is computed using the straight-line method over the lesser of the estimated useful lives of the related assets or the lease term (ranging from 12 to 31 years). Maintenance and repairs that do not extend the useful life of the respective asset are charged to Operating expenses as incurred. When assets are retired, or otherwise disposed of, the property accounts are relieved of costs and accumulated depreciation and any resulting gain or loss is credited or charged to income. The Company performs an evaluation of the recoverability of the carrying value of its property, plant and equipment to determine if facts and circumstances indicate that their carrying valuevalues may be impaired and if any adjustment is warranted.impaired. Impairment charges are recorded to "Operating expenses" in the Consolidated Statements of Operations. Amortization of finance leased assets is included in depreciation expense and is calculated using the straight-line method over the term of the lease.
Leases
The Company records a right of use ("ROU") asset and related liability under a contract or part of a contract when it conveys the right to control the use of an identified asset for a period of time in exchange for consideration. Control over the use of an identified asset occurs when an entity has both the right to obtain substantially all of the economic benefits from the use of an identified asset and the right to direct the use of that identified asset. The determination of whether a contract contains a lease may require significant assumptions and judgments.
For all classes of underlying assets, the Company does not separate nonlease components from lease components and accounts for each separate lease component and the nonlease components associated with that lease component as a single lease component. The Company records lease liabilities and related ROU assets for all leases that have a term of greater than one year. For short-term leases (leases with terms of less than one year), the Company expenses lease payments on a straight-line basis over the lease term.
Variable lease payments represent payments made by a lessee for the right to use an underlying asset that vary because of changes in facts or circumstances occurring after the commencement date of a lease other than the passage of time. Variable lease payments that are based on an index or rate, calculated by using the index or rate that exists on the lease commencement date, are included in the measurement of a lease liability. Certain of the Company’s operating leases for office facilities contain variable lease components that are not based on an index or rate, and the Company recognizes these payments as lease expense in the period in which the obligation for those payments is incurred.
The Company calculates lease liabilities based on the present value of lease payments discounted by the rate implicit in the lease or, if not readily determinable, the Company’s incremental borrowing rate.
Finance lease liabilities are subsequently measured by increasing the carrying amount to reflect interest expense on the finance lease liability and reducing the carrying amount of the lease liability to reflect lease payments made during the period. Interest on finance lease liabilities is determined in each period during the lease term as the amount that produces a constant periodic discount rate on the remaining balance of the lease liability. ROU assets under finance leases are amortized over the remaining
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
lease term on a straight-line basis. Interest expense related to finance lease liabilities and amortization of ROU assets under finance leases are included in the "Interest expense" and "Depreciation, amortization, depletion and accretion" line item, respectively, in the Consolidated Statements of Operations.
Operating lease liabilities are subsequently measured at the present value of the lease payments not yet paid, discounted using the discount rate for the lease established at the inception date of the lease. ROU assets under operating leases are subsequently measured at the amounts of the related operating lease liability, adjusted for, as applicable, prepaid or accrued lease payments, the remaining balance of any lease incentives received, unamortized initial direct costs and impairment. Lease expense from operating leases is recognized as a single lease cost over the remaining lease term on a straight-line basis. Variable lease payments not included in operating lease liabilities are recognized as expense in the period in which the obligation for those payments is incurred. Lease expense from operating leases is included in the "General and administrative" and "Consumables Cost of revenues, excluding depreciation and amortization" line items in the Consolidated Statements of Operations.
Other Assets
Mine Development Costs
Mine development costs which are related to the Five Forks Mine and are stated at cost less accumulated depletion and include acquisition costs, the cost of other development work and mitigation costs. Costs are amortized over the estimated life of the related mine reserves, which as of December 31, 2021 is 21estimated to be 13 years. The Company performs an evaluation of the recoverability of the carrying value of mine development costs to determine if facts and circumstances indicate that their carrying value may be impaired and if any adjustment is warranted. Mine development costs are reported in the "Other long-term assets, net" line item onin the Consolidated Balance Sheet.Sheets.
Spare Parts
Spare parts include critical spares required to support plant operations. Parts and supply costs are determined using the lower of cost or estimated replacement cost. Parts are recorded as maintenance expenses in the period in which they are consumed. Spare parts are reported in the "Other long-term assets, net" line item onin the Consolidated Balance Sheet.Sheets.
Revenue Recognition
On January 1, 2018, the Company adopted ASC 606 - Revenue from Contracts with Customers ("ASC 606") using the modified retrospective method applied to those contracts that were not completed as of January 1, 2018. The Company recognized the cumulative effect of initially applying ASC 606 to the opening balance of the Accumulated deficit. See further discussion of the impact of the adoption of ASC 606 in Note 8.
Effective with the Acquisition Date, Carbon Solutions adopted ASC 606 using the modified retrospective method applied to those contracts that were not completed as of December 7, 2018. There was no impact to the consolidated financial statements of the Company upon Carbon Solutions’ adoption of ASC 606, except for a reclassification from revenues to cost of revenue for Carbon Solutions for freight costs billed to its customers in conjunction with product sales, which historically were recorded as revenues. This reclassification of freight costs billed to customers to cost of revenue results in an offset to Carbon Solutions' actual freight costs recorded in cost of revenue and has no impact to Carbon Solutions' operating results. This presentation is consistent with ADES' policy of reporting freight costs, net of freight costs billed to customers, under cost of revenue. ADES adopted this policy effective with its adoption of ASC 606 on January 1, 2018.
The Company recognizes revenue from a contract with a customer when a performance obligation under the terms of a contract with a customer is satisfied, which is when the customer controls the promised goods or services that are transferred in satisfaction of the performance obligation. Revenue is measured as the amount of consideration that is expected to be received
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
in exchange for transferring goods or providing services, and the transaction price is generally fixed and generally does not contain variable or noncash consideration. In addition, the Company’s contracts with customers generally do not contain customer refund or return provisions or other similar obligations. Transfer of control and satisfaction of performance obligations are further discussed in each of the revenue components listed below.
The Company uses estimates and judgments in determining the nature and timing of satisfaction of performance obligations, the standalone selling price ("SSP") of performance obligations and the allocation of the transaction price to multiple performance obligations.obligations, if any.
The Company’s principal revenue components are Consumables sales and License royalties.
Consumables
Consumables are comprised ofThe Company is principally engaged in the sale of consumable products that utilize AC and chemicals for mercury capturechemical based technologies to a broad range of customers, including coal-fired utilities, water treatment plants, and other diverse markets. Our proprietary technologies and associated product offerings provide purification solutions to enable our customers to reduce certain contaminants and pollutants and thus maximize utilization levels and improve operating efficiencies to meet the challenges of existing and potential regulations.
The sale of consumable products is comprised of a single performance obligation and is recognized at the point in time when control transfers and our obligation has been fulfilled, which is when the product is shipped or delivered to a customer. Performance obligations for the coal-fired power plant, industrial and water treatment markets. Customer contracts for consumables are short duration and performance obligations generallysale of consumable products do not extend beyond one year. Certain customer contracts for consumables are comprised of evaluation tests of the Company's consumables' effectiveness and efficiency in reducing emissions. These contracts entail the delivery of consumables to the customer and the Company's evaluation of results of emissions reduction over the term of the contract. Under these types of arrangements, which are generally for durations that are short term, the Company has determined that the customer is simultaneously receiving benefits of emissions reduction from the consumption of the consumables over the testing period and this represents a single performance obligation that is satisfied over time. This determination may require significant judgment.
The Company recognizes revenue over time using an input model that is generally based on the cost of consumables used by the customer during the testing period. The use of an input modelperforms shipping and handling activities through the use of total costs as the measurethird-party shippers and such activities occur prior to a customer obtaining control of progress in the satisfaction of the performance obligations may require significant judgment. In addition, under these types of contracts,goods. As such, the Company has determined that the services performedaccounts for these these activities as fulfillment activities and relatednot as separate performance obligations. Shipping and handling costs incurred by the Company duringin delivering products to
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
customers are billed to customers and are included in the testing period represent costs to fulfill a contract.transaction price and included in the "Revenues - Consumables" line item in the Consolidated Statements of Operations. Costs for shipping and handling activities incurred by the Company are included in the "Consumables Cost of revenues, excluding depreciation and amortization" line item in the Consolidated Statements of Operations.
License royalties, related party
The Company generates revenues from royalties ("M-45 Royalties") earned under a licensing arrangement ("M-45 License") of its M-45TM and M-45-PCTM emissions control technologies ("M-45 Technology") between the Company and Tinuum Group. The Company recognizes M-45 Royalties at a point in time based on the use of the M-45 Technology at certain RC facilities or through Tinuum Group’s use of licensed technology for rates in excess of amounts allowed for RC application. The amount of M-45 Royalties recognized is generally based on a percentage of pre-tax margins (as defined in the M-45 License) of the RC facilities using the M-45 Technology.
Practical Expedients and Exemptions
The Company does not disclose the value of unsatisfied performance obligations for contracts with an original expected length of one year or less.
Sales and other taxes that are collected concurrently with revenue-producing activities are excluded from revenue.
The Company has elected to account for freight costs as activities to fulfill the promise to transfer the goods, and therefore these activities are also not assessed as a separate service to customers.
The Company accounts for all shipping and handling activities that occur after control of the related good transfers as fulfillment activities. These activities are included in Cost of Revenue line items of the Consolidated Statement of Operations.
The Company generally expenses sales commissions when incurred because the amortization period of the asset that the Company would have recognized is one year or less. These costs are recorded in sales and marketing expenses in the General"General and administrativeadministrative" line item ofin the Consolidated StatementStatements of Operations.
Cost of RevenueRevenues
Cost of revenuerevenues includes all labor, fringe benefits, subcontract labor, additive and coal costs, materials, equipment, supplies, travel costs and any other costs and expenses directly related to the Company’s production of revenues. The Company records estimated contract losses, if any, in the period they are determined.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Payroll and Benefits
Payroll and benefits costs include direct payroll, personnel related fringe benefits, sales and administrative staff labor costs and stock compensation expense. Payroll and benefits costs exclude direct labor included in Cost of revenue.revenues.
Legal and Professional
Legal and professional costs include external legal, audit and consulting expenses.
General and Administrative
General and administrative costs include director fees and expenses, rent, insurance and occupancy-related expenses, bad debt expense, impairments and other general costs of conducting business.
Research and development costs are charged to expense in the period incurred and are reported in the General"General and administrativeadministrative" line item in the Consolidated Statements of Operations. For the years ended December 31, 2021 and 2020, the Company recorded research and development costs of $0.4 million and $1.0 million, respectively.
Asset Retirement Obligations
ReclamationAsset retirement obligations which("ARO") are comprised of mine reclamation activities required under operating agreements related to the Five Forks Mine and the Marshall Mine (as defined in Note 4) and are recognized when incurred and recorded as liabilities at fair value. The liabilityAn ARO is accreted over time through periodic charges to earnings. In addition,Accounting for reclamation and remediation obligations requires the Company to make estimates of future costs unique to a corresponding asset retirement cost is capitalized as part ofspecific mining operation that the asset’s carrying valueCompany expects to incur to complete the reclamation and amortized over the life of the related asset. Reclamation costsremediation work required to comply with existing laws and regulations. AROs are periodically adjusted to reflect changes in the estimated present value resulting from the passage of time and revisions to the estimates of either the timing or amount of the reclamation costs. The
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Five Forks Mine
For the Five Forks Mine ARO, a corresponding ARO asset is depreciated over its estimated life. Reclamation costs related to the Five Forks Mine are allocated to expense over the life of the related mine assets, and are periodically adjusted to reflect changes in the estimated present value resulting from the passage of time and revisions to the estimates of either the timing or amount of the reclamation obligation iscosts. Remediation costs for the Five Forks Mine are accrued based on whenmanagement’s best estimate at the end of each period of the costs expected to be incurred. Such cost estimates may include ongoing care, maintenance and monitoring costs. Reclamation obligations are based on the timing of estimated spending for an existing disturbance is expected to occur. The Company reviews, onenvironmental disturbance. On an annual basis, unless otherwise deemed necessary, the reclamation obligation forCompany reviews its estimates and assumptions of the Five Forks Mine.Mine ARO.
The Company’s mining activities at the Five Forks Mine are subject to various domestic laws and regulations governing the protection of the environment. The Company conducts its mining activities to protect public health and the environment and believes its operations are in compliance with applicable laws and regulations in all material respects. The Company has made, and expects to make in the future, expenditures to comply with such laws and regulations, but cannot predict the full amount of such future expenditures. Estimated future reclamation costs are based principally on current legal and regulatory requirements.
Marshall Mine (refer to Note 4)
Reclamation costs related to the Marshall Mine are largely based on a capped fee structure based on the initial estimate of the total costs of reclamation, which provides for certain contingencies that could increase or decrease the reclamation fee based on the reclamation agreement executed between the Company and the Marshall Mine operator. The timing of payments and actual reclamation costs may change and the Company accounts for these changes on a quarterly basis.
Income Taxes
The Company accounts for income taxes under the asset and liability method, which requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements. Under this method, deferred tax assets and liabilitiesincome taxes are determined on the basis of theprovided for temporary differences between the financial statementsreporting basis and tax basis of the Company's assets and liabilities and are tax-effected using enacted tax rates in effect for the year in which the temporary differences are expected to reverse. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in operations in the period that includes the enactment date.
The Company recognizes deferred tax assets and liabilities and maintains valuation allowances where it is more likely than not that all or a portion of deferred tax assets will not be realized. In making such a determination, the Company considers all available positive and negative evidence, including future reversals of existing taxable temporary differences, projected future taxable income, tax-planning strategies, and results of recent operations.
The Company records uncertain tax positions on the basis of a two-step process whereby (1) the Company determines whether it is more-likely-than-not that the tax positions will be sustained on the basis of the technical merits of the position and (2) for those tax positions that meet the more-likely-than-not recognition threshold, the Company recognizes the amount of tax benefit that is more than 50 percent likely to be realized upon ultimate settlement with the related tax authority.
TheBased on its ownership in Tinuum Group, the Company records its pro-rata share for interest expense due toresulting from the Company's sharesale of, Tinuum Group's equity method earnings for Refined Coal ("RC") facilities, in which the relatedor lease income or salegenerated from, RC facilities that are treated as installment sales for federal income tax purposes.purposes, pursuant to IRS section 453A ("Section 453A"). Section 453A requires taxpayers using the installment method to pay an interest charge ("453A interest") on the portion of the tax liability that is deferred under the installment method. The Company recognizes IRS section 453A interest ("453A interest") and other interest and penalties related to unrecognized tax benefits in the Interest expense"Interest expense" line item in the Consolidated Statements of Operations.
Stock-Based Compensation
Stock-based compensation expense is measured at the grant date based on the estimated fair value of the stock-based award and is generally expensed on a straight-line basis over the requisite service period and/or performance period of the award. Forfeitures are recognized when incurred. Stock-based compensation expense related to manufacturing employees and administrative employees is included in the Consumables,"Consumables Cost of revenues, exclusive of depreciation and Payrollamortization" and benefits"Payroll and benefits" line items, respectively, in the Consolidated Statements of Operations. Stock-based compensation expense related to non-employee directors and consultants is included in the General"General and administrativeadministrative" line item in the Consolidated Statements of Operations.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Dividends
When a sufficient amount of available earnings exists at the time of a dividend declaration, dividends are charged as a reduction to Retained earnings in the Consolidated Balance Sheet when declared. If a sufficient Retainedamount of available earnings is not available, dividends declared are charged as a reduction to Additional paid-in capital in the Consolidated Balance Sheet.capital.
Earnings (Loss) Per Share
Basic earnings (loss) per share is computed using the two-class method, which is an earnings allocation formula that determines earnings (loss) per share forweighted-average number of shares of common stock and any participating securities according to dividend and participating rights in undistributed earnings. The Company's restricted stock awards ("RSA's") granted prior to December 31, 2016 contain non-forfeitable rights to dividends or dividend equivalents and are deemed to be participating securities. RSA's granted subsequent to December 31, 2016 do not contain non-forfeitable rights to dividends and are not deemed to be participating securities.
Under the two-class method, net income (loss) for the period is allocated between common stockholders and the holders of the participating securities based on the weighted-average of common shares outstanding during the period, excluding participating, unvested RSA's ("common shares"), and the weighted-average number of participating, unvested RSA's outstanding during the period, respectively. The allocated, undistributed income for the period is then divided by the weighted-average number of common shares and participating, unvested RSA's outstanding during the period to determine basic earnings per common share and participating security for the period, respectively. Pursuant to U.S. GAAP, the Company has elected not to separately present basic or diluted earnings per share attributable to participating securities in the Consolidated Statements of Operations.
reporting period. Diluted earnings per share is computed in a manner consistent with that of basic earnings per share, while considering other potentially dilutive securities. The treasury stock method is used to determine the dilutive effect of potentially dilutive securities.
Potentially dilutive securities consist of both unvested, participating and non-participating RSA's,restricted stock awards ("RSA's"), as well as outstanding options to purchase common stock ("Stock Options") and contingent performance stock units ("PSU's") (collectively, "Potential dilutive shares"). The dilutive effect, if any, for non-participating RSA's, Stock Options and PSU's is determined using the greater of dilution as calculated under the treasury stock method or the two-class method. Potential dilutive shares are excluded from diluted earnings (loss) per share when their effect is anti-dilutive. When there is a net loss for a period, all Potential dilutive shares are anti-dilutive and are excluded from the calculation of diluted loss per share for that period.
Each PSU represents a contingent right to receive shares of the Company’s common stock, and the number of shares may range from zero to two times the number of PSU's granted on the award date depending upon the price performance of the Company's common stock as measured against a general index and a specific peer group index over requisite performance periods. The number of Potential dilutive shares related to PSU's is based on the number of shares of the Company's common stock, if any, that would be issuable at the end of the respective reporting period, assuming that the end of the reporting period is the end of the contingency period applicable to such PSU's. See Note 1116 for additional information related to PSU's.
The following table sets forth the calculations of basic and diluted earnings per common share: |
| | | | | | | | |
| | | Years Ended December 31, |
| (in thousands, except per share amounts) | | 2019 | | 2018 |
| Net income | | $ | 35,537 |
| | $ | 35,454 |
|
| Less: Dividends and undistributed income allocated to participating securities | | 44 |
| | 112 |
|
| Income attributable to common stockholders | | $ | 35,493 |
| | $ | 35,342 |
|
| |
|
| |
|
|
| Basic weighted-average number of common shares outstanding | | 18,154 |
| | 19,901 |
|
| Add: dilutive effect of equity instruments | | 218 |
| | 132 |
|
| Diluted weighted-average shares outstanding | | 18,372 |
| | 20,033 |
|
| Earnings per share - basic | | $ | 1.96 |
| | $ | 1.78 |
|
| Earnings per share - diluted | | $ | 1.93 |
| | $ | 1.76 |
|
| | | | | | | | | | | | | | | | |
| | | Years Ended December 31, | | |
| (in thousands, except per share amounts) | | 2021 | | 2020 | | |
| Net income (loss) | | $ | 60,401 | | | $ | (20,302) | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Basic weighted-average number of common shares outstanding | | 18,258 | | | 18,044 | | | |
| Add: dilutive effect of equity instruments | | 203 | | | — | | | |
| | | | | | |
| | | | | | |
| Diluted weighted-average shares outstanding | | 18,461 | | | 18,044 | | | |
| Earnings (loss) per share - basic | | $ | 3.31 | | | $ | (1.12) | | | |
| Earnings (loss) per share - diluted | | $ | 3.27 | | | $ | (1.12) | | | |
For the years ended December 31, 20192021 and 2018, options to purchase 0.32020, 0 and 0.6 million and 0.3 million shares of common stock for each of the years presentedweighted-average equity instruments, respectively, were outstanding but were not included in the computation of diluted net incomeearnings per share because the exercise price exceeded the average price of the underlying shares and thetheir effect would have been anti-dilutive.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Use of Estimates
The preparation of the Company’s consolidated financial statements in conformity with U.S. GAAPaccounting principles generally accepted in the United States ("GAAP") requires the Company’s management to make estimates and assumptions that affect the amounts reported in these financial statements and accompanying notes. Actual results could differ from those estimates. TheSignificant financial statement components in which the Company makes assumptions on the following significant financial statement components including:include
•business combinations;combinations, including asset acquisitions;
•the carrying value of its long-lived assets;
the carrying value of its intangible assets;•AROs; and
asset retirement obligation; and
•income taxes, including the valuation allowance for deferred tax assets and assessment of uncertain tax positions.
Due to the coronavirus ("COVID-19") pandemic, there has been uncertainty and disruption in the global economy and financial markets. Additionally, due to COVID-19, overall power generation and coal-fired power demand may change, which could also
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
have a material adverse effect on the Company. The Company is not aware of any specific event or circumstance due to COVID-19 that would require an update to its estimates or judgments or a revision of the carrying values of its assets or liabilities through the date of this Report. These estimates may change as new events occur and additional information is obtained. Actual results could differ materially from these estimates under different assumptions or conditions
Risks and Uncertainties
The Company’s earnings are significantly affected by equity earnings it receives from Tinuum Group. As of December 31, 2019,2021, all RC facilities had ceased operations and Tinuum is expected to complete reclamation activities, as required, during 2022. The loss of earnings from both Tinuum Group has 20 invested RC facilities of which 8 are leased to a single customer. A majority of these leases are periodically renewed and the loss of this customer by Tinuum Group wouldServices will have a significant adverse impact on itsour financial position, results of operations and cash flows whichbeginning in turn would have material adverse impact on the Company’s financial position, results of operations2022 and cash flows.beyond.
Reclassifications
Certain balances have been reclassified from prior years to conform to the current year presentation. Such reclassifications had no effect on the Company’s results of operations or financial position in any of the periods presented.
New Accounting Guidance
Recently Adopted
In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) ("ASU 2016-02"), which created ASC Topic 842 - Leases ("ASC 842"), requiring lessees to recognize a right of use asset and related lease liability for those leases classified as operating leases at the commencement date and have lease terms of more than 12 months. ASC 842 retains the distinction between finance leases (formerly defined as capital leases) and operating leases. On January 1, 2019, the Company adopted ASC 842 retrospectively beginning with the date of adoption. Under this adoption method, the application date is the beginning of the reporting period in which the Company first applies the provisions of ASC 842. Accordingly, the Company’s reporting for the comparative periods presented in the financial statements and related disclosures continues in accordance with legacy U.S. GAAP under ASC Topic 840 - Leases ("ASC 840"). The adoption of ASC 842 had no impact to the opening balance of Retained earnings.
As of the adoption date, the Company recorded $7.0 million and $7.0 million of "right of use" ("ROU") assets and incremental lease liabilities, respectively. The cumulative effect of the change from the adoption of ASC 842 to the Consolidated Balance Sheet as of January 1, 2019 is shown in the table that follows:
|
| | | | | | | | | | | | |
| | | Balance as of | | Impact of | | Balance as of |
| (in thousands) | | December 31, 2018 | | Adoption | | January 1, 2019 |
| Balance Sheet | | | | | | |
| Other long-term assets | | $ | 7,993 |
| | $ | 6,956 |
| | $ | 14,949 |
|
| Other liabilities | | $ | 50,058 |
| | $ | 3,085 |
| | $ | 53,143 |
|
| Other long-term liabilities | | $ | 940 |
| | $ | 3,871 |
| | $ | 4,811 |
|
See Note 7 for additional disclosures required under ASC 842 in the year of adoption.
As of January 1, 2019, Tinuum Group adopted ASC 606 and ASC 842. As a result of Tinuum Group’s adoption of these pronouncements, the Company recorded a cumulative effect increase of $27.4 million to Retained earnings as of January 1, 2019, based on the Company's ownership percentage of Tinuum Group's cumulative effect adjustment, and increased its investment balance in Tinuum Group in the amount of $37.2 million and established a deferred tax liability of $9.8 million. As
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
a result of the increase in the investment balance in Tinuum Group, for the year ended December 31, 2019, the Company recognized equity earnings in Tinuum Group based on its pro-rata share of Tinuum Group’s net income rather than based on cash distributions received as had been required in prior periods as a result of the cumulative cash distributions exceeding the cumulative pro-rata share of Tinuum Group's net income.
Not yet Adopted
In June 2016, the FASB issued ASU 2016-13, Financial Instruments - Credit Losses (Topic 326) Measurement of Credit Losses on Financial Instruments ("ASU 2016-13"). The main objective of ASU 2016-13 is to provide financial statement users with more decision-useful information about the expected credit losses on financial instruments and other commitments to extend credit held by a reporting entity at each reporting date. To achieve this objective, the amendments in ASU 2016-13 replace the incurred loss impairment methodology in current U.S. GAAP with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. ASU 2016-13 is effective for "smaller reporting companies" (as defined by the Securities and Exchange Commission) for fiscal years beginning after December 15, 2022, including interim periods within those years, and must be adopted under a modified retrospective method approach. Entities may adopt ASU 2016-13 earlier as of the fiscal years beginning after December 15, 2018, including interim periods within those years. The Company intends to adopt ASU 2016-13 effective January 1, 2023 and is currently evaluating the provisions of this guidancestandard and assessing its impact on the Company's financial statements and disclosures anddisclosures. The Company does not believe this standard will have a material impact on the Company's financial statements and disclosures.
In August 2018, the FASB issued ASU 2018-13, Fair Value Measurement (Topic 820) Disclosure Framework - Changes to the Disclosure Requirements for Fair Value Measurement ("ASU 2018-13"). The amendments in ASU 2018-13 improve the effectiveness of fair value measurement disclosures and modify the disclosure requirements on fair value measurements in Topic 820, Fair Value Measurement ("Topic 820"), based on the concepts in FASB Concepts Statement, Conceptual Framework for Financial Reporting - Chapter 8: Notes to Financial Statements, including the consideration of costs and benefits. ASU 2018-13 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019. The amendments on changes in unrealized gains and losses, the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements, and the narrative description of measurement uncertainty should be applied prospectively for only the most recent interim or annual period presented in the initial fiscal year of adoption. All other amendments should be applied retrospectively to all periods presented upon their effective date. Early adoption is permitted upon issuance of this Update. An entity is permitted to early adopt any removed or modified disclosures upon issuance of this Update and delay adoption of the additional disclosures until their effective date. The Company has completed its evaluation of ASU 2018-13 and does not believe this standard will have a material impact on the Company's financial statement disclosures.
In December 2019, the FASB issued ASU2019-12, Income Taxes (Topic 740) Simplifying the Accounting for Income Taxes ("ASU 2019-12"). The amendments in ASU 2019-12 simplify various aspects related to accounting for income taxes by removing certain exceptions contained in Topic 740 and also clarifies and amends existing guidance in Topic 740 to improve consistent application. ASU 2019-12 is effective for public business entities beginning after December 15, 2020, including interim periods within those years, and early adoption is permitted. The Company is currently evaluating the provisions of this guidance and assessing its impact on the Company's financial statements and disclosures and does not believe this standard will have a material impact on the Company's financial statements and disclosures.
Note 2 - AcquisitionRestatement
As described in Note 1, onSubsequent to the Acquisition Date,filing of its Quarterly Report for the quarterly period ended September 30, 2021, the Company completed the Carbon Solutions Acquisitionreassessed its presentation of shipping and handling costs billed to its customers in its Consolidated Statement of Operations for a total purchase price of $75.0 million (the "Purchase Price"). The results of Carbon Solutions have been included in the Company’s consolidated financial statements since the Acquisition Date. The fair value of the purchase consideration totaled $66.5 million and consisted of cash of $65.8 million and an additional purchase adjustment amount payable to Carbon Solutions' secured lender of $0.7 million, which was paid in March 2019. The Purchase Price was adjusted by assumed debt and contractual commitments of $11.8 million, and less cash acquired of $3.3 million. The Company also paid $4.5 million in acquisition-related costs (or transaction costs) during the year ended December 31, 2018. 2021. Historically, the Company has accounted for shipping and handling costs billed to customers as a reduction of consumables cost of revenues, as presented in the Consumables cost of revenues, exclusive of depreciation and amortization line item in the Consolidated Statements of Operations. Under Accounting Standards Codification 606 - Revenue from Contracts with Customers, shipping and handling costs billed to customers are considered a component of the total transaction price in a contract with a customer and should be presented as revenues.
The Company fundedconcluded that its historical presentation of shipping and handling costs billed to customers as a component of cost of revenues rather than as a component of revenues was incorrect and that the cash consideration from cash on handCompany's presentation of both the "Revenues - Consumables" and "Consumables cost of revenues, exclusive of depreciation and amortization" line items for the proceeds fromyear ended December 31, 2020 should be restated. The impact of this error resulted in an understatement of both the Senior Term Loan"Revenues - Consumables" and "Consumables cost of revenues, exclusive of depreciation and amortization" line items in the principal amountConsolidated Statements of $70.0 million,Operations for the year ended December 31, 2020, but had no impact to operating income (loss), income (loss) before income taxes, net income (loss) or earnings (loss) per share for these years. Further, there was no impact of this error to the Consolidated Balance Sheets, Consolidated Statements of Stockholders' Equity or Consolidated Statements of Cash Flow as more fully described in Note 6.of and for the year ended December 31, 2020.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The following table summarizes the final Purchase Price allocation. Subsequent to December 31, 2018, the Company completed additional analysis and adjustments were made to the preliminary Purchase Price allocations as noted in the table below:
|
| | | | | | | | | | | | |
| Fair value of assets acquired: | | As Originally Reported | | Adjustments | | As Adjusted |
| Cash | | $ | 3,284 |
| | $ | — |
| | $ | 3,284 |
|
| Receivables | | 6,409 |
| | — |
| | 6,409 |
|
| Inventories | | 22,100 |
| | (356 | ) | | 21,744 |
|
| Prepaid expenses and other current assets | | 2,992 |
| | 61 |
| | 3,053 |
|
| Spare parts | | 3,359 |
| | — |
| | 3,359 |
|
| Property, plant and equipment | | 43,033 |
| | (377 | ) | | 42,656 |
|
| Mine leases and development | | 2,500 |
| | 200 |
| | 2,700 |
|
| Mine reclamation asset | | — |
| | 2,402 |
| | 2,402 |
|
| Intangible assets | | 4,000 |
| | 100 |
| | 4,100 |
|
| Other assets | | 168 |
| | — |
| | 168 |
|
| Amount attributable to assets acquired | | 87,845 |
| | 2,030 |
| | 89,875 |
|
| | | | | | | |
| Fair value of liabilities assumed: | | | | | | |
| Accounts payable | | 4,771 |
| | — |
| | 4,771 |
|
| Accrued liabilities | | 7,354 |
| | 254 |
| | 7,608 |
|
| Equipment lease liabilities | | 8,211 |
| | — |
| | 8,211 |
|
| Mine reclamation liability | | 626 |
| | 1,776 |
| | 2,402 |
|
| Other liabilities | | 437 |
| | — |
| | 437 |
|
| Amount attributable to liabilities assumed | | 21,399 |
| | 2,030 |
| | 23,429 |
|
| | | | | | | |
| Net assets acquired | | $ | 66,446 |
| | $ | — |
| | $ | 66,446 |
|
Adjustments to the preliminary Purchase Price allocation primarily relate to changes in fair values assigned to property, plant and equipment, intangible assets, mine reclamation liability and the related mine reclamation asset as a resultA summary of the final valuation report from the Company's third-party valuation firm issued in May 2019. During the year ended December 31, 2019 based on new informationimpact of facts and circumstances that existed as of the Acquisition Date, the Company revised its estimates used as of the Acquisition Date related to the net realizable value of certain finished goods inventory items as well as values assigned to certain prepaid and accrued expense items.
The adjustments were recorded as of June 30, 2019 and were included in the Consolidated Balance Sheet as of that date and the resultant impact to the Statement of Operations was reflectedthis restatement for the year ended December 31, 2019.
The following2020 is included in the table represents the intangible assets identified as partbelow. A summary of the Carbon Solutions Acquisition:impact of this restatement for the quarterly periods ended March 31, 2021 and 2020: June 30, 2021 and 2020; September 30, 2021 and 2020 and December 31, 2020 are contained in Note 24.
| | | | | | | | | | | | | | | | | | | | |
| | Year ended December 31, 2020 |
| (in thousands, except per share data) | | As previously reported | | Increase/(Decrease) | | As Restated |
| Revenues: | | | | | | |
| Consumables | | $ | 48,122 | | | $ | 5,786 | | | $ | 53,908 | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Total revenues | | 61,577 | | | 5,786 | | | 67,363 | |
| | | | | | |
| Consumables cost of revenues, exclusive of depreciation and amortization | | $ | 45,176 | | | $ | 5,786 | | | 50,962 | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Total operating expenses | | 102,558 | | | 5,786 | | | 108,344 | |
| Operating loss | | $ | (40,981) | | | $ | — | | | $ | (40,981) | |
Note 3 - Customer Supply Agreement
|
| | | | | | |
| (in thousands) | | Amount | | Weighted Average Useful Life (years) |
| Customer relationships | | $ | 2,200 |
| | 5 |
| Developed technology | | 1,600 |
| | 5 |
| Trade name | | 300 |
| | 2 |
| Total intangibles acquired | | $ | 4,100 |
| | |
In addition to the sale by the Company and purchase by Cabot of Furnace Products, the Company and Cabot have agreed to additional terms whereby Cabot reimburses the Company for certain capital expenditures incurred by the Company that are necessary to manufacture the Furnace Products. Reimbursements are comprised of revenues earned from capital expenditures incurred that will benefit both the Company and Cabot (referred to as "Shared Capital") and revenues earned from capital expenditures incurred that will benefit Cabot exclusively (referred to as "Specific Capital"). In the event that Cabot ceases to make purchases under the Supply Agreement, Cabot is obligated to pay the balance of any outstanding payments for Specific Capital.
Note 4 - Acquisition of Marshall Mine
Concurrently with the execution of the Supply Agreement, on September 30, 2020, the Company entered into an agreement to purchase (the "Mine Purchase Agreement") from Cabot 100% of the membership interests in Marshall Mine, LLC (the "Marshall Mine Acquisition") for a nominal purchase price. Marshall Mine, LLC owns a lignite mine located outside of Marshall, Texas (the "Marshall Mine"). The Company independently determined to immediately commence activities to shutter the Marshall Mine and to incur the associated reclamation costs.
In conjunction with the execution of the Supply Agreement and the Mine Purchase Agreement, on September 30, 2020, the Company entered into a reclamation contract (the "Reclamation Contract") with a third party that provides a capped cost, subject to certain contingencies, in the initial amount of approximately $19.7 million plus an obligation to pay certain direct costs of approximately $3.6 million (collectively, the "Reclamation Costs") over the estimated reclamation period of 10 years (the "Reclamation Period"). Under the terms of the Supply Agreement, Cabot is obligated to reimburse the Company for $10.2 million of the Reclamation Costs (the "Reclamation Reimbursement"), payments of which are due semi-annually over the estimated reclamation period and are inclusive of interest. In the event that Cabot has a change in control as described in the Supply Agreement, all outstanding balances of the Reclamation Reimbursement shall be due and payable in full. See further discussion of the Reclamation Costs and Reclamation Reimbursement in Note 5.
As the owner of the Marshall Mine, the Company is required to post a surety bond to ensure performance of its reclamation activities and entered into the Surety Agreement on September 30, 2020. As of December 31, 2021, the Company had a $16.6 million surety bond (the "Surety Bond") posted with the local regulatory agency. The Surety Bond will remain in place until the Marshall Mine is fully shuttered, and it may be reduced in amount from time to time as the Company progresses with its reclamation activities. As of December 31, 2021 and 2020, for the obligations due under the Reclamation Contract, the
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The amounts of revenues and income before income taxes for the period from the Acquisition Date to December 31, 2018 for Carbon Solutions are as follows:
|
| | | | |
| (in thousands) | | Year ended December 31, 2018 |
| Revenues | | $ | 5,580 |
|
| Net loss | | $ | (391 | ) |
Unaudited Pro Forma Financial Information
The following represents the pro forma effectsCompany posted cash collateral of the Carbon Solutions Acquisition as if it had occurred on January 1, 2017. The pro forma pre-tax income for 2018 has been calculated after applying the Company’s accounting policies in effect for that year. In addition, pro forma net income includes: (1) the impact on Carbon Solutions of the adoption of ASC 606 effective January 1, 2018, which resulted in a reclassification of $5.9$10.0 million from Revenues to Cost of Revenue for freight costs billed to customers and had no impact to income from operations; (2) the reduction in depletion, depreciation and amortization resulting from the purchase price adjustments to Property, plant and equipment and Mine development costs; (3) the adjustment to interest expense from the combination of the Senior Term Loan that was used to fund the Carbon Solutions Acquisition and the elimination of certain debt of Carbon Solutions as a result of pay-offs by the Company as of the Acquisition Date; and (4) the removal of $9.7 million in transaction costs incurred in 2018, together with the income tax effect on (1) through (4). The pro forma results do not include any anticipated synergies or other expected benefits of the Carbon Solutions Acquisition. The unaudited pro forma financial information below is not necessarily indicative of either future results of operations or results that might have been achieved had the Carbon Solutions Acquisition been consummated as of January 1, 2017.
|
| | | | |
| | | Year ended December 31, |
| (in thousands) | | 2018 |
| Revenues | | $ | 78,591 |
|
| Net income | | $ | 31,562 |
|
Note 3 - Inventories, net
The following table summarizes the Company's inventories recorded at the lower of average cost or net realizable value as of December 31, 2019 and 2018:
|
| | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2019 | | 2018 |
Product inventory (1) | | $ | 13,515 |
| | $ | 19,403 |
|
| Raw material inventory | | 1,945 |
| | 2,388 |
|
| | | $ | 15,460 |
| | $ | 21,791 |
|
(1) As of December 31, 2019 and 2018, Product inventory includes zero and $5.0 million, respectively, attributedwhich is reported as "Restricted Cash, long-term" in the Consolidated Balance Sheets.The Marshall Mine Acquisition included the acquisition of certain assets that will be consumed and the assumption of certain liabilities that will be paid in reclamation of the Marshall Mine, in addition to the increase inincurrence of an obligation for the Reclamation Costs. The Company determined that the Marshall Mine Acquisition should be accounted for as an asset acquisition as it did not meet the definition of a business. The Company's conclusion was based on the Marshall Mine not having any economic reserves, as the Company commenced full reclamation as of September 30, 2020, and therefore lacked inputs.
As the Marshall Mine Acquisition represented a transaction with a customer of net assets acquired and liabilities assumed from Cabot, the Company accounted for the excess of the fair value of inventoryliabilities assumed over assets acquired as upfront consideration transferred to a customer, Cabot (the "Upfront Customer Consideration"). The amount of the Upfront Customer Consideration was recognized net of an additional asset recognized in the Marshall Mine Acquisition, which was comprised of a receivable from Cabot (the "Cabot Receivable") for the Carbon Solutions Acquisition.Reclamation Reimbursements. The Cabot Receivable is further discussed in Note 5.
The total Upfront Customer Consideration is amortized on a straight-line basis as a reduction to revenue over the expected 15-year contractual period of the Supply Agreement.
The Company paid a nominal cash amount to Cabot in the form of cash for the Marshall Mine and also assumed liabilities whose fair value exceeded the fair value of assets acquired. The net assets acquired and liabilities assumed and the additional assets recorded for the Marshal Mine Acquisition as of September 30, 2020 are shown in the table below. Subsequent to this date, the Company completed additional analysis and adjustments were made as noted in the table below:
| | | | | | | | | | | | | | | | | | | | |
| (in thousands) | | As Originally Reported | | Adjustments | | As Adjusted |
| Assets acquired: | | | | | | |
| Receivables | | $ | — | | | $ | 513 | | | $ | 513 | |
| Property, plant and equipment | | 3,863 | | | — | | | 3,863 | |
| Spare parts | | 100 | | | — | | | 100 | |
| | | | | | |
| Liabilities assumed: | | | | | | |
| Accounts payable and accrued expenses | | (673) | | | 160 | | | (513) | |
| Asset retirement obligation | | (21,328) | | | — | | | (21,328) | |
| Net assets acquired and liabilities assumed from Marshall Mine acquisition | | (18,038) | | | 673 | | | (17,365) | |
| Cabot receivable | | 9,749 | | | — | | | 9,749 | |
| Upfront Customer Consideration | | $ | 8,289 | | | $ | (673) | | | $ | 7,616 | |
The Company also evaluated the Marshall Mine entity as a VIE, and determined that because of its structure and closing-stage status, it does not have sufficient equity at-risk and would not likely be able to obtain additional subordinated financial support to complete its closing stage obligations. The Company purchased all of the membership interests in Marshall Mine, LLC and determined that it met the definition of a VIE and that the Company is the primary beneficiary. Therefore, Marshall Mine, LLC’s assets and liabilities are consolidated.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The following tables summarize the assets and liabilities of Marshall Mine and their classification in the Company's Consolidated Balance Sheets:
| | | | | | | | | | | | | | | | | | | | |
| | As of December 31, | | |
| (in thousands) | | 2021 | | 2020 | | Balance sheet component |
| Cash | | $ | 914 | | | $ | 495 | | | Current assets |
| Cabot receivable, short-term | | 2,056 | | | 921 | | | Current assets |
| Property and equipment, net | | 1,968 | | | 3,254 | | | Non-current assets |
| Cabot receivable, long-term | | 6,846 | | | 8,852 | | | Non-current assets |
| Restricted cash | | 10,027 | | | 5,000 | | | Non-current assets |
| Upfront customer consideration | | 6,982 | | | 7,490 | | | Non-current assets |
| Other | | — | | | 50 | | | Non-current assets |
| | $ | 28,793 | | | $ | 26,062 | | | |
| | | | | | |
| Accounts payable and accrued liabilities | | $ | 1,065 | | | $ | 407 | | | Current liabilities |
| Asset retirement obligation, short-term | | 1,775 | | | 9,370 | | | Current liabilities |
| Asset retirement obligation, long-term | | 4,546 | | | 8,760 | | | Non-current liabilities |
| | $ | 7,386 | | | $ | 18,537 | | | |
Note 5 - Marshall Mine Asset Retirement Obligation and related Cabot Receivable
Asset Retirement Obligation
In connection with the Supply Agreement, Mine Purchase Agreement and the Reclamation Contract, the Company assumed the obligation to reclaim and restore the land associated with the Marshall Mine. The Company determined that the Marshall Mine did not have any remaining economic reserves. As of September 30, 2020, the Company recorded an ARO (the "Marshall Mine ARO") as its best estimate for the total Reclamation Costs of $21.3 million as measured at the estimated future cash flows of $23.7 million, inclusive of contingency costs, discounted to their present value using a discount rate based on a credit-adjusted, risk-free rate of 7.0%.
As of June 30, 2021 and December 31, 2021, the Company revised its estimate of future obligations owed for the reclamation of the Marshall Mine primarily based on scope reductions related to future reclamation requirements. As a result, the Company reduced the Marshall Mine ARO by $1.9 million as of June 30, 2021 and $0.8 million as of December 31, 2021 and recorded a corresponding gain on change in estimate of $2.7 million for the year ended December 31, 2021. This is included as "Gain on change in estimate, asset retirement obligation" in the Consolidated Statement of Operations for the year ended December 31, 2021.
Cabot Receivable
As previously disclosed, under the terms of the related Supply Agreement, Cabot is obligated to pay the Reclamation Reimbursement to the Company for $10.2 million of the Reclamation Costs, inclusive of interest. As of September 30, 2020, the Company recorded the Cabot Receivable for the Reclamation Reimbursement at its estimated fair value, which was measured using a discounted cash flows valuation model that considered the estimated credit risk associated with the obligor’s (Cabot’s) future performance. Interest is accreted on a monthly basis and recognized as interest income. There were no significant related fees or costs associated with the Cabot Receivable.
As of September 30, 2020, the Company recorded the Cabot Receivable at its estimated fair value of $9.7 million, reflecting a discount rate of approximately 1.5% or $0.5 million. Allowances for this asset are assessed periodically, and no allowance was deemed necessary as of December 31, 2021 or 2020.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Note 6 - Impairment
As part of its periodic review of the carrying value of long-lived assets, the Company assessed its long-lived assets for potential impairment. In assessing impairment of its APT segment's long-lived asset groups as of June 30, 2021, the Company considered factors such as the significant decline in both the APT segment's trailing twelve months revenues and current and future years’ forecasted revenues. These factors were largely due to the significant drop in coal-fired power dispatch amid historically low prices of alternative power generation sources, such as natural gas, leading to an increase in natural gas usage as well as other competing energy sources.
As of June 30, 2020, the Company completed an undiscounted cash flow analysis of its APT segment's long-lived assets (the "Asset Group"), which were comprised of its manufacturing plant and related assets and its lignite mine assets. The estimated undiscounted cash flows from the Asset Group was $54.7 million, which was less than the carrying value of the Asset Group of $58.3 million. Accordingly, the Company completed an assessment of the Asset Group’s fair value and estimated the fair value of the Asset Group at $32.2 million. This resulted in an impairment and write-down of the Asset Group (the "Impairment Charge") of $26.1 million as of June 30, 2020. The Impairment Charge is reflected as "Impairment of long-lived assets" in the Consolidated Statement of Operations for the year ended December 31, 2020, and was allocated to the APT segment.
The following table summarizes the allocation to the Asset Group of the Impairment Charge of $26.1 million recorded as of June 30, 2020:
| | | | | | | | |
| (in thousands) | | |
| Property, plant and equipment, net | | $ | 18,986 | |
| Intangible assets, net | | 1,445 | |
| Other long-term assets, net | | 5,672 | |
| | |
| Total impairment | | $ | 26,103 | |
The Company engaged an independent third party to perform the valuation of the Asset Group in order to determine the estimated fair value of the Asset Group. This valuation was based on the use of several established valuation models including an expected future discounted cash flow model using Level 3 inputs.
Note 7 - COVID-19
In March 2020, the federal government passed the Coronavirus Aid, Relief, and Security Act (the "CARES Act"), which
provided among other things the creation of the Paycheck Protection Plan ("PPP"), which was sponsored and administered by the U.S. Small Business Administration ("SBA"). On April 20, 2020, the Company executed a loan agreement (the "PPP Loan") under the PPP, evidenced by a promissory note, with BOK, NA dba Bank of Oklahoma ("BOK"), providing for $3.3 million in proceeds, which was funded to the Company on April 21, 2020. The PPP Loan was scheduled to mature on April 21, 2022, unless forgiven subject to terms and conditions established by the SBA. The Company initially recorded the PPP Loan as a debt obligation and accrued interest over its term.
On July 27, 2021, the Company received formal notification in the form of a letter dated July 19, 2021 from BOK that the SBA
approved the Company’s PPP Loan forgiveness application for the PPP Loan in the amount of $3.3 million (including accrued
interest). For the year ended December 31, 2021, the Company recorded a gain on extinguishment of the PPP Loan in the amount of $3.3 million in the Consolidated Statement of Operations, which is included as a component of "Other income (expense)."
The CARES Act also provided the deferral of payroll tax payments for all payroll taxes incurred through December 31, 2020. The Company elected to defer payments of payroll taxes for the periods allowed under the CARES Act in the amount of $0.4 million and paid $0.2 million during the fourth quarter of 2021, with the balance due no later than December 31, 2022.
Note 8 - Equity Method Investments
Tinuum Group, LLC
As of December 31, 2021 and 2020, the Company’s ownership in Tinuum Group was 42.5%. Tinuum Group supplies technology, equipment and technical services to cyclone-fired and other boiler users, but its primary purpose is to place into operation facilities that produce and sell RC that lower emissions and therefore qualifies for Section 45 tax credits. NexGen
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Refined Coal, LLC ("NexGen") and GSFS Investments I Corp. ("GSFS"), an affiliate of The Goldman Sachs Group, Inc. ("GS"), own the remaining 42.5% and 15.0%, respectively of Tinuum Group. GSFS' ownership interest is in the form of Class B units that do not have voting rights but provide certain preferences over ADA and NexGen as to liquidation and profit distribution.
The Company determined that Tinuum Group is a VIE, however, it concluded that it was not the primary beneficiary and therefore did not consolidate Tinuum Group, and accounted for it under the equity method of accounting. The Company's conclusion that it was not the primary beneficiary was based on the Company's and NexGen's shared power of Tinuum Group.
The following tables summarize the assets, liabilities and results of operations of Tinuum Group:
| | | | | | | | | | | | | | |
| | As of December 31, |
| (in thousands) | | 2021 | | 2020 |
| Current assets | | $ | 39,387 | | | $ | 142,440 | |
| Non-current assets | | $ | 220 | | | $ | 28,649 | |
| Current liabilities | | $ | 15,558 | | | $ | 44,278 | |
| Non-current liabilities | | $ | — | | | $ | 5,186 | |
| | | | |
| Members equity attributable to Class A members | | $ | 8,890 | | | $ | 59,221 | |
| Member equity attributable to Class B members | | $ | 9,887 | | | $ | 18,769 | |
| Noncontrolling interests | | $ | 5,272 | | | $ | 43,635 | |
| | | | | | | | | | | | | | | | |
| | Years Ended December 31, | | |
| (in thousands) | | 2021 | | 2020 | | |
| Gross profit | | $ | 6,995 | | | $ | 6,649 | | | |
| Operating, selling, general and administrative expenses | | 49,414 | | | 58,008 | | | |
| Loss from operations | | (42,419) | | | (51,359) | | | |
| Other income | | 9,726 | | | 17,260 | | | |
| | | | | | |
| Loss attributable to noncontrolling interest | | 126,948 | | | 91,501 | | | |
| Net income available to Class A and B members | | $ | 94,255 | | | $ | 57,402 | | | |
| ADES equity earnings from Tinuum Group | | $ | 61,837 | | | $ | 24,396 | | | |
For the year ended December 31, 2021, the Company recognized earnings from Tinuum Group's net income available to members that was different from its pro-rata share of Tinuum Group's net income available to members, as cash distributions for the year ended December 31, 2021 exceeded the carrying value of the Tinuum Group equity investment. For the year ended December 31, 2020, the Company recognized its pro-rata share of Tinuum Group's net income available to its members.
The carrying value of the Company's investment in Tinuum Group is zero as long as the cumulative amount of distributions received from Tinuum Group exceeds the Company's cumulative pro-rata share of Tinuum Group's net income available to Class A members. For periods during which the ending balance of the Company's investment in Tinuum Group is zero, the Company only recognizes equity earnings from Tinuum Group to the extent that cash distributions are received from Tinuum Group during the period. For periods during which the ending balance of the Company's investment is greater than zero (e.g., when the cumulative earnings in Tinuum Group exceeds cumulative cash distributions received), the Company recognizes its pro-rata share of Tinuum Group's net income available to Class A members for the period, less any amount necessary to recover the cumulative earnings short-fall balance as of the end of the immediately preceding period. As shown in the table below, the Company’s carrying value in Tinuum Group for the years ended December 31, 2021 and 2020 was zero and $3.4 million, respectively.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The following table presents the Company's investment balance, equity earnings, cash distributions and cash distributions in excess of the investment balance for the years ended December 31, 2021 and 2020 (in thousands):
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Description | | Date(s) | | Investment balance | | ADES equity earnings (loss) | | Cash distributions | | Memorandum Account: Cash distributions and equity loss in (excess) of investment balance |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| Beginning balance | | 12/31/2019 | | $ | 32,280 | | | $ | — | | | $ | — | | | $ | — | |
| | | | | | | | | | |
| ADES proportionate share of net income from Tinuum Group | | 2020 activity | | 24,396 | | | 24,396 | | | — | | | — | |
| | | | | | | | | | |
| Cash distributions from Tinuum Group | | 2020 activity | | (53,289) | | | — | | | 53,289 | | | — | |
| | | | | | | | | | |
| Total investment balance, equity earnings (loss) and cash distributions | | 12/31/2020 | | $ | 3,387 | | | $ | 24,396 | | | $ | 53,289 | | | $ | — | |
| ADES proportionate share of net income from Tinuum Group | | 2021 activity | | 40,058 | | | 40,058 | | | — | | | — | |
| | | | | | | | | | |
| Cash distributions from Tinuum Group | | 2021 activity | | (65,224) | | | — | | | 65,224 | | | — | |
| Adjustment for current year cash distributions in excess of investment balance | | 2021 activity | | 21,779 | | | 21,779 | | | — | | | (21,779) | |
| Total investment balance, equity earnings and cash distributions | | 12/31/2021 | | $ | — | | | $ | 61,837 | | | $ | 65,224 | | | $ | (21,779) | |
Additional information related to Tinuum Group is included in Item 15 - "Exhibits and Financial Statement Schedules" ("Item 15") of this Report.
Tinuum Services, LLC
In 2010, the Company, together with NexGen, formed Tinuum Services for the purpose of operating and maintaining RC facilities, including those RC facilities leased or sold to third parties. The Company determined that Tinuum Services is not a VIE and evaluated Tinuum Services for potential consolidation under the voting interest model. Because the Company does not own greater than 50% of the outstanding voting shares, it has accounted for its investment in Tinuum Services under the equity method of accounting. As of December 31, 2021 and 2020, the Company’s investment in Tinuum Services was $2.4 million and $4.2 million, respectively.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The following tables summarize the assets, liabilities and results of operations of Tinuum Services:
| | | | | | | | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2021 | | 2020 |
| Current assets | | $ | 159,013 | | | $ | 301,670 | |
| Non-current assets | | $ | 19 | | | $ | 45,575 | |
| Current liabilities | | $ | 14,343 | | | $ | 187,097 | |
| Non-current liabilities | | $ | — | | | $ | 6,451 | |
| Equity | | $ | 6,263 | | | $ | 8,483 | |
| Noncontrolling interests | | $ | 138,426 | | | $ | 145,214 | |
| | | | | | | | | | | | | | | | |
| | | Years Ended December 31, | | |
| (in thousands) | | 2021 | | 2020 | | |
| Gross loss | | $ | (68,465) | | | $ | (87,723) | | | |
| Operating, selling, general and administrative expenses | | 166,075 | | | 171,095 | | | |
| Loss from operations | | (234,540) | | | (258,818) | | | |
| Other income (expenses) | | 3,830 | | | (1,282) | | | |
| Loss attributable to noncontrolling interest | | 246,094 | | | 273,262 | | | |
| Net income | | $ | 15,384 | | | $ | 13,162 | | | |
| | | | | | |
Included in the Consolidated Statement of Operations of Tinuum Services for the years ended December 31, 2021 and 2020 were losses related to VIE entities that are consolidated within Tinuum Services. These losses do not impact the Company's equity earnings from Tinuum Services as 100% of those losses are attributable to a noncontrolling interest and eliminated in the calculations of Tinuum Services' net income attributable to the Company's interest.
The following table details the carrying value of the Company's respective equity method investments included in the "Equity method investments" line item on the Consolidated Balance Sheets and indicates the Company's maximum exposure to loss:
| | | | | | | | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2021 | | 2020 |
| Equity method investment in Tinuum Group | | $ | — | | | $ | 3,387 | |
| Equity method investment in Tinuum Services | | 2,391 | | | 4,242 | |
| Equity method investment in other | | — | | | 63 | |
| | | | |
| | | | |
| Total equity method investments | | $ | 2,391 | | | $ | 7,692 | |
The Company evaluates its equity method investments for impairment whenever events or changes in circumstances indicate that the carrying amount of the investment might not be recoverable. As of December 31, 2021, the Company concluded the carrying amount of its investment in Tinuum Services was not fully recoverable due to the remaining expected future cash distributions to be received as Tinuum Services shutters its operations in 2022 as a result of the expiration of the Section 45 tax credit period as of December 31, 2021. As a result, the Company wrote-down its investment in the amount of $0.7 million, which is included in the "Earnings from equity method investments" line item in the Consolidated Statement of Operations for the year ended December 31, 2021.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The following table details the components of the Company's respective earnings or loss from equity method investments included in the "Earnings from equity method investments" line item in the Consolidated Statements of Operations:
| | | | | | | | | | | | | | | | |
| | Year ended December 31, | | |
| (in thousands) | | 2021 | | 2020 | | |
| Earnings from Tinuum Group | | $ | 61,837 | | | $ | 24,396 | | | |
| Earnings from Tinuum Services | | 6,952 | | | 6,582 | | | |
| Loss from other | | (63) | | | — | | | |
| | | | | | |
| | | | | | |
| Earnings from equity method investments | | $ | 68,726 | | | $ | 30,978 | | | |
The following table details the components of the cash distributions from the Company's respective equity method investments included as a component of cash flows from operating activities in the Consolidated Statements of Cash Flows. Distributions from equity method investees are reported in the Consolidated Statements of Cash Flows as "return on investment" in Operating cash flows until such time as the carrying value in an equity method investee company is reduced to zero; thereafter, such distributions are reported as "distributions in excess of cumulative earnings" as a component of cash flows from investing activities.
| | | | | | | | | | | | | | |
| | Year ended December 31, |
| (in thousands) | | 2021 | | 2020 |
| Distributions from equity method investees, return on investment | | | | |
| Tinuum Group | | $ | 14,142 | | | $ | 53,289 | |
| Tinuum Services | | 8,802 | | | 9,152 | |
| | | | |
| | | | |
| | | | |
| | $ | 22,944 | | | $ | 62,441 | |
| Distributions from equity method investees in excess of cumulative earnings | | | | |
| Tinuum Group | | $ | 51,082 | | | $ | — | |
| | | | |
| | | | |
| | | | |
| | | | |
| | $ | 51,082 | | | $ | — | |
Note 49 - Inventories, net
The following table summarizes the Company's inventories recorded at the lower of average cost or net realizable value as of December 31, 2021 and 2020:
| | | | | | | | | | | | | | |
| | As of December 31, |
| (in thousands) | | 2021 | | 2020 |
| Product inventory | | $ | 4,901 | | | $ | 8,361 | |
| Raw material inventory | | 2,949 | | | 1,521 | |
| | | | |
| | $ | 7,850 | | | $ | 9,882 | |
| | | | |
| | | | |
| | | | |
| | | | |
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Note 10 - Property, Plant and Equipment
The carryingcost basis and accumulated depreciation of property, plant and equipment at December 31, 20192021 and 2018 are:2020 are summarized in the table below: | | | | | Life in Years | | As of December 31, | | Life in Years | | As of December 31, |
| (in thousands) | | 2019 | | 2018 | (in thousands) | | 2021 | | 2020 |
| Land and land improvements | | 0-31 | | $ | 1,764 |
| | $ | 2,302 |
| Land and land improvements | | 0-31 | | $ | 1,225 | | | $ | 891 | |
| Plant and operating equipment | | 1-31 | | 44,015 |
| | 32,999 |
| Plant and operating equipment | | 2-29 | | 31,266 | | | 25,703 | |
| Furniture and fixtures | | 1-7 | | 1,201 |
| | 701 |
| Furniture and fixtures | | 2-11 | | 1,388 | | | 1,259 | |
| Machinery and equipment | | 1-7 | | 1,235 |
| | 1,277 |
| Machinery and equipment | | 2-10 | | 697 | | | 688 | |
| Leasehold improvements | | 1-3 | | 245 |
| | 249 |
| Leasehold improvements | | 2-3 | | 2,089 | | | 2,089 | |
| Construction in progress | | 2,985 |
| | 6,668 |
| Construction in progress | | 1,190 | | | 2,143 | |
| | | 51,445 |
| | 44,196 |
| | 37,855 | | | 32,773 | |
| Less accumulated depreciation | | (7,444 | ) | | (1,499 | ) | Less accumulated depreciation | | (7,684) | | | (3,340) | |
| Total property, plant and equipment, net | | $ | 44,001 |
| | $ | 42,697 |
| Total property, plant and equipment, net | | $ | 30,171 | | | $ | 29,433 | |
Included in plant and operating equipment as of December 31, 20192021 and 20182020 is mining equipment financed under various lease facilities, and obligations due under these facilities are included in finance lease obligations and capital lease obligations, respectively, in the Consolidated Balance Sheet.Sheets. The total amount recorded for right of use ("ROU")ROU assets as of December 31, 20192021 and 2020 related to finance lease obligations was $5.9$1.7 million and $2.4 million, respectively, net of accumulated depreciation of $2.3 million. The total amount recorded for assets under capital lease obligations as of December 31, 2018 was $8.1$1.1 million net of accumulated depreciation of $0.1and $0.5 million.
Depreciation expense for the years ended December 31, 20192021 and 20182020 was $6.0$5.5 million and $0.5$6.8 million, respectively.
Note 5 - Equity Method Investments
Tinuum Group, LLC
As of December 31, 2019 and 2018, the Company’s ownership in Tinuum Group was 42.5%. Tinuum Group supplies technology, equipment and technical services to cyclone-fired and other boiler users, but its primary purpose is to place into operation facilities that produce and sell RC that lower emissions and therefore qualifies for Section 45 tax credits. NexGen Refined Coal, LLC ("NexGen") and GSFS Investments I Corp. (“GSFS”), an affiliate of The Goldman Sachs Group, Inc. ("GS"), own the remaining 42.5% and 15.0%, respectively of Tinuum Group. GSFS' ownership interest is in the form of Class B units that do not have voting rights but provide certain preferences over ADA and NexGen as to liquidation and profit distribution, including a guaranteed 15% annual return on GSFS' unrecovered investment balance, which is calculated as the original GSFS investment, plus a 15% annual return thereon, less any distributions, including the allocation of Section 45 tax credits to the members. In February 2018, the unrecovered investment balance associated with the Class B units was repaid in full.
The Company has determined that Tinuum Group is a VIE, however, the Company does not have the power to direct the activities that most significantly impact Tinuum Group's economic performance and has therefore accounted for the investment under the equity method of accounting. The Company determined the voting partners of Tinuum Group have identical voting rights, equity control interests and board control interests, and therefore, concluded that the power to direct the activities that most significantly impact Tinuum Group's economic performance was shared.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The following tables summarize the assets, liabilities and results of operations of Tinuum Group: |
| | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2019 | | 2018 |
| Current assets | | $ | 128,473 |
| | $ | 54,958 |
|
| Non-current assets | | $ | 125,820 |
| | $ | 92,991 |
|
| Current liabilities | | $ | 59,392 |
| | $ | 50,908 |
|
| Non-current liabilities | | $ | 13,340 |
| | $ | 14,446 |
|
| Members equity attributable to Class A members | | $ | 117,006 |
| | $ | 49,102 |
|
| Members equity attributable to Class B members | | $ | 28,967 |
| | $ | 16,983 |
|
| Noncontrolling interests | | $ | 35,588 |
| | $ | 16,510 |
|
|
| | | | | | | | |
| | | Years Ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Gross profit | | $ | 104,976 |
| | $ | 107,135 |
|
| Operating, selling, general and administrative expenses | | 37,641 |
| | 23,662 |
|
| Income from operations | | 67,335 |
| | 83,473 |
|
| Other expenses | | (95 | ) | | (5,674 | ) |
| Class B preferred return | | — |
| | (12 | ) |
| Loss attributable to noncontrolling interest | | 78,544 |
| | 58,013 |
|
| Net income available to Class A and B members | | $ | 145,784 |
| | $ | 135,800 |
|
| ADES equity earnings from Tinuum Group | | $ | 60,286 |
| | $ | 47,175 |
|
As shown above, the Company reported earnings from its equity investment in Tinuum Group of $60.3 million and $47.2 million for the years ended December 31, 2019 and 2018, respectively.
The carrying value of the Company's investment in Tinuum Group shall be zero as long as the cumulative amount of distributions received from Tinuum Group exceeds the Company's cumulative pro-rata share of Tinuum Group's net income available to Class A members. For periods during which the ending balance of the Company's investment in Tinuum Group is zero, the Company only recognizes equity earnings from Tinuum Group to the extent that cash distributions are received from Tinuum Group during the period. For periods during which the ending balance of the Company's investment is greater than zero (e.g., when the cumulative earnings in Tinuum Group exceeds cumulative cash distributions received), the Company recognizes its pro-rata share of Tinuum Group's net income available to Class A members for the period, less any amount necessary to recover the cumulative earnings short-fall balance as of the end of the immediately preceding period. As shown in the table below, the Company’s carrying value in Tinuum Group for the years ended December 31, 2019 and 2018 were $32.3 million and zero, respectively.
The amount of equity earnings or loss reported on the Consolidated Statement of Operations may differ from a mathematical calculation of earnings or loss attributable to the equity interest based upon the factor of the equity interest and the net income or loss available to Class A members as shown on Tinuum Group’s statement of operations. Additionally, for periods during which the carrying value of the Company's investment in Tinuum Group is greater than zero, distributions from Tinuum Group are reported on the Consolidated Statements of Cash Flows as "Distributions from equity method investees, return on investment" in Operating cash flows. For periods during which the carrying value of the Company's investment in Tinuum Group is zero, such cash distributions are reported on the Consolidated Statements of Cash Flows as "Distributions from equity method investees in excess of investment basis" in Investing cash flows.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The following table presents the Company's investment balance, equity earnings, cash distributions and cash distributions in excess of the investment balance for the years ended December 31, 2018 and December 31, 2019 (in thousands):
|
| | | | | | | | | | | | | | | | | | |
| Description | | Date(s) | | Investment balance | | ADES equity earnings (loss) | | Cash distributions | | Memorandum Account: Cash distributions and equity loss in (excess) of investment balance |
| Beginning balance | | 12/31/2017 | | $ | — |
| | $ | — |
| | $ | — |
| | $ | (12,218 | ) |
| ADES proportionate share of net income from Tinuum Group (1) | | 2018 activity | | 57,721 |
| | 57,721 |
| | — |
| | — |
|
| Recovery of cash distributions in excess of investment balance (prior to cash distributions) | | 2018 activity | | (12,218 | ) | | (12,218 | ) | | — |
| | 12,218 |
|
| Cash distributions from Tinuum Group | | 2018 activity | | (47,175 | ) | | — |
| | 47,175 |
| | — |
|
| Adjustment for current year cash distributions in excess of investment balance | | 2018 activity | | 1,672 |
| | 1,672 |
| | — |
| | (1,672 | ) |
| Total investment balance, equity earnings (loss) and cash distributions | | 12/31/2018 | | $ | — |
| | $ | 47,175 |
| | $ | 47,175 |
| | $ | (1,672 | ) |
| Impact of adoption of accounting standards (2) | | 2019 activity | | $ | 37,232 |
| | $ | — |
| | $ | — |
| | $ | — |
|
| ADES proportionate share of net income from Tinuum Group | | 2019 activity | | 61,958 |
| | 61,958 |
| | — |
| | — |
|
| Recovery of cash distributions in excess of investment balance (prior to cash distributions) | | 2019 activity | | (1,672 | ) | | (1,672 | ) | | — |
| | 1,672 |
|
| Cash distributions from Tinuum Group | | 2019 activity | | (65,238 | ) | | — |
| | 65,238 |
| | — |
|
| Total investment balance, equity earnings and cash distributions | | 12/31/2019 | | $ | 32,280 |
| | $ | 60,286 |
| | $ | 65,238 |
| | $ | — |
|
(1) The amounts of the Company's 42.5% proportionate share of net income as shown in the table above differ from mathematical calculations of the Company’s 42.5% equity interest in Tinuum Group multiplied by the amounts of Net Income available to Class A members as shown in the table above of Tinuum Group's results of operations due to adjustments related to the Class B preferred return.
(2) As discussed in Note 1, Tinuum Group adopted ASC 606 and ASC 842 as of January 1, 2019. As a result of Tinuum Group’s adoption of these standards, the Company recorded a cumulative adjustment of $27.4 million, net of the impact of income taxes, related to the Company's percentage of Tinuum Group's cumulative effect adjustment that increased the Company's Retained earnings as of January 1, 2019.
Additional information related to Tinuum Group pursuant to Regulation S-X Rule of the Securities and Exchange Act of 1934 is included in Item 15 - "Exhibits and Financial Statement Schedules" ("Item 15") of this Report.
Tinuum Services, LLC
In 2010, the Company, together with NexGen, formed Tinuum Services for the purpose of operating and maintaining RC facilities, including those RC facilities leased or sold to third parties. The Company has determined that Tinuum Services is not a VIE and has evaluated the consolidation analysis under the Voting Interest Model. The Company has a 50% voting and economic interest in Tinuum Services, which is equivalent to the voting and economic interest of NexGen. Therefore, as the Company does not hold greater than 50% of the outstanding voting interests, either directly or indirectly, it has accounted for the investment under the equity method of accounting.
As of December 31, 2019 and 2018, the Company’s 50% investment in Tinuum Services was $6.8 million and $6.6 million, respectively.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The following tables summarize the assets, liabilities and results of operations of Tinuum Services: |
| | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2019 | | 2018 |
| Current assets | | $ | 308,249 |
| | $ | 300,288 |
|
| Non-current assets | | $ | 99,261 |
| | $ | 100,233 |
|
| Current liabilities | | $ | 155,367 |
| | $ | 219,959 |
|
| Non-current liabilities | | $ | 55,746 |
| | $ | 66,760 |
|
| Equity | | $ | 13,626 |
| | $ | 13,134 |
|
| Noncontrolling interests | | $ | 182,771 |
| | $ | 100,668 |
|
|
| | | | | | | | |
| | | Years Ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Gross loss | | $ | (102,172 | ) | | $ | (85,377 | ) |
| Operating, selling, general and administrative expenses | | 199,691 |
| | 173,500 |
|
| Loss from operations | | (301,863 | ) | | (258,877 | ) |
| Other expenses | | (1,422 | ) | | 37 |
|
| Loss attributable to noncontrolling interest | | 321,077 |
| | 272,905 |
|
| Net income | | $ | 17,792 |
| | $ | 14,065 |
|
| ADES equity earnings from Tinuum Services | | $ | 8,896 |
| | $ | 7,033 |
|
Included in the Consolidated Statement of Operations of Tinuum Services for the years ended December 31, 2019 and 2018 were losses related to VIE entities that are consolidated within Tinuum Services of $321.1 million and $272.9 million, respectively. These losses do not impact the Company's equity earnings from Tinuum Services as 100% of those losses are attributable to a noncontrolling interest and eliminated in the calculations of Tinuum Services' net income attributable to the Company's interest.
The following table details the carrying value of the Company's respective equity method investments included in the Equity method investments line item on the Consolidated Balance Sheet and indicates the Company's maximum exposure to loss:
|
| | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2019 | | 2018 |
| Equity method investment in Tinuum Group | | $ | 32,280 |
| | $ | — |
|
| Equity method investment in Tinuum Services | | 6,813 |
| | 6,567 |
|
| Equity method investment in other | | 62 |
| | 67 |
|
| Total equity method investments | | $ | 39,155 |
| | $ | 6,634 |
|
The Company evaluates the investments for impairment whenever events or changes in circumstances indicate that the carrying amount of the investment might not be recoverable. No impairments were recorded during the years ended December 31, 2019 and 2018.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The following table details the components of the Company's respective earnings or loss from equity method investments included in the Earnings from equity method investments line item on the Consolidated Statements of Operations:
|
| | | | | | | | |
| | | Year ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Earnings from Tinuum Group | | $ | 60,286 |
| | $ | 47,175 |
|
| Earnings from Tinuum Services | | 8,896 |
| | 7,033 |
|
| Loss from other | | (6 | ) | | — |
|
| Earnings from equity method investments | | $ | 69,176 |
| | $ | 54,208 |
|
The following table details the components of the cash distributions from the Company's respective equity method investments included in the Consolidated Statements of Cash Flows. Distributions from equity method investees are reported on the Consolidated Statements of Cash Flows as “return on investment” in Operating cash flows until such time as the carrying value in an equity method investee company is reduced to zero; thereafter, such distributions are reported as “distributions in excess of cumulative earnings” in Investing cash flows.
|
| | | | | | | | |
| | | Year ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Distributions from equity method investees, return on investment | | | | |
| Tinuum Group | | $ | 65,238 |
| | $ | — |
|
| Tinuum Services | | 8,650 |
| | 5,500 |
|
| Included in Operating Cash Flows | | $ | 73,888 |
| | $ | 5,500 |
|
| Distributions from equity method investees in excess of cumulative earnings | | | | |
| Tinuum Group | | $ | — |
| | $ | 47,175 |
|
| Included in Investing Cash Flows | | $ | — |
| | $ | 47,175 |
|
During the years ended December 31, 2019 and 2018, the Company, in the aggregate, made contributions to equity method investments of zero and $0.8 million, respectively.
Note 611 - Debt Obligations
|
| | | | | | | | |
| | | Years ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Senior Term Loan due December 2021, related party | | $ | 40,000 |
| | $ | 70,000 |
|
| Less: net unamortized debt issuance costs | | (1,163 | ) | | (1,990 | ) |
| Less: net unamortized debt discount | | (1,200 | ) | | (2,052 | ) |
| Senior Term Loan due December 2021, net | | 37,637 |
| | 65,958 |
|
| Finance lease obligations (1) | | 6,729 |
| | 8,167 |
|
| | | 44,366 |
| | 74,125 |
|
| Less: Current maturities | | (23,932 | ) | | (24,067 | ) |
| Total long-term borrowings | | $ | 20,434 |
| | $ | 50,058 |
|
(1) As of December 31, 2018, obligations related to capital lease obligations as defined in ASC 840. | | | | | | | | | | | | | | |
| | Years ended December 31, |
| (in thousands) | | 2021 | | 2020 |
| Finance lease obligations | | $ | 4,163 | | | $ | 5,526 | |
| Senior Term Loan principal, related party | | — | | | 16,000 | |
| Less: net unamortized debt issuance costs | | — | | | (465) | |
| Less: net unamortized debt discount | | — | | | (480) | |
| Senior Term Loan, net | | — | | | 15,055 | |
| PPP Loan | | — | | | 3,305 | |
| | | | |
| Total borrowings | | 4,163 | | | 23,886 | |
| Less: Current maturities | | (1,011) | | | (18,441) | |
| Total long-term borrowings | | $ | 3,152 | | | $ | 5,445 | |
Senior Term Loan
InOn December 7, 2018, the Company, and ADA-ES, Inc. ("ADA"), a wholly-owned subsidiary, and certain other subsidiaries of the Company as guarantors, The Bank of New York Mellon as administrative agent, and Apollo Credit Strategies Master Fund Ltd and Apollo A-N Credit Fund (Delaware) L.P. (collectively "Apollo”), affiliates of a beneficial owner of greater than five5 percent of the Company's common stock and a related party, entered into the Senior Term Loan in the amount of $70.0 million, less original issue discount of $2.1 million. Proceeds from the Senior Term Loan were used to fund the Carbon Solutions
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Acquisition as disclosed in Note 2. The Company also paid debt issuance costs of $2.0 million related to the Senior Term Loan. The Senior Term Loan has a term of 36 months
On June 1, 2021 and bears interest at a rate equalprior to 3-month LIBOR (subject to a 1.5% floor) + 4.75% per annum, which is adjusted quarterly to the current 3-month LIBOR rate, and interest is payable quarterly in arrears. Quarterly principal payments of $6 million were required beginning in March 2019, and the Company may prepay the Senior Term Loan at any time without penalty. The Senior Term Loan is secured by substantially all of the assets ofLoan's maturity date, the Company includingpaid the cash flows from Tinuum Group and Tinuum Services (collectively, the "Tinuum Entities"), but excluding the Company's equity interests in the Tinuum entities.
The Senior Term Loan includes, among others, the following covenants: (1) Beginning December 31, 2018 and as of the end of each fiscal quarter thereafter, the Company must maintain a minimum cashremaining principal balance of $5.0 million and shall not permit "expected future net cash flows from the refined coal business" (as defined in the Senior Term Loan) to be less than 1.75 times the outstanding principal amount of the Senior Term Loan; (2) Beginning in January 2019, annual collective dividends and buybacks of Company shares in an aggregate amount, not to exceed $30 million, is permitted so long as (a) no default or event of default exists under the Senior Term Loan and (b) expected future net cash flows fromall remaining accrued interest through this date. The Company did not incur any prepayment fees associated with the refined coal business as of the end of the most recent fiscal quarter exceed $100 million.early pay-off.
As of December 31, 2019, the following table presents the future aggregate annual maturities of the Company’s Senior Term Loan excluding unamortized discounts
Advanced Emissions Solutions, Inc. and deferred financing costs:Subsidiaries
Notes to Consolidated Financial Statements
|
| | | | |
| Year ended December 31, | | |
| (in thousands) | | Principal Amount |
| 2020 | | $ | 24,000 |
|
| 2021 | | 16,000 |
|
| 2022 | | — |
|
| 2023 | | — |
|
| 2024 | | — |
|
| Total | | $ | 40,000 |
|
Line of Credit
In September 2013, ADA, as borrower, and the Company, as guarantor, entered into the Line of Credit with a bank (the "Lender")the Lender for an aggregate principal amount of $10.0 million that was secured by certain amounts due to the Company from certain Tinuum Group RC leases. The Line of Credit has beenwas amended 1316 times from the period from December 2, 2013 through December 31, 2018, including two amendments executedMarch 23, 2021, which included a reduction in the principal amount to $5.0 million in September 2018.
On September 30, 2018,March 23, 2021, ADA, as borrower, the Company as guarantor, and the Lender entered into an amendment (the "Twelfth Amendment") to the Line of Credit. The Twelfth Amendment decreased the Line of Credit to $5.0 million due to decreased collateral requirements,(the "Fifteenth Amendment"), which extended the maturity date of the Line of Credit to September 30, 2020December 31, 2021 and permittedincreased the Line of Credit to be used as collateral (in place of restricted cash) for letters of credit ("LC's") up tominimum cash requirement from $5.0 million related to equipment projects and certain other agreements. Under the Twelfth Amendment, there was no minimum cash balance requirement based on the Company meeting certain conditions and maintaining minimum trailing twelve-month EBITDA (earnings before interest, taxes, depreciation and amortization), as previously defined in the "Eleventh Amendment" to the Line of Credit, of $24.0$6.0 million.
On December 7, 2018, ADA, as borrower,July 29, 2021, the Company as guarantor, and the Lender entered into a further amendmentthe Sixteenth Amendment (the "Sixteenth Amendment") to the Line of Credit, which provided, among other things, for ADACredit. The Sixteenth Amendment amends certain terms and conditions related to be able to enter into the Senior Term Loan as a guarantor so long as the principal amount of the Senior Term Loan does not exceed $70.0 million. Additionally, the financial covenants incollateral securing the Line of Credit were amended and restated to be consistent with the aforementioned Senior Term Loan covenants, including maintaining a minimum cash balance of $5.0 million.
Credit. As of December 31, 2019,2021 and 2020, there were no outstanding borrowings under the Line of Credit. The Line of Credit expired on December 31, 2021.
Note 712 - Leases
The financial statement impact from the adoption of ASC 842 as of January 1, 2019 is due to recording ROUCompany's operating and finance lease right-of-use ("ROU") assets and related lease liabilities for operating lease commitments that were outstanding as of December 31, 2018. The Company elected the
Advanced Emissions Solutions, Inc.2021 and Subsidiaries
Notes to Consolidated Financial Statements
transitional practical expedients allowed under ASC 842, which include among other things that the Company need not reassess: (1) whether any existing contracts are or contain leases, inclusive of land easements; (2) the lease classification or lease term for existing leases; and (3) initial direct costs for any existing leases. In addition, the Company elected for all classes of underlying assets the practical expedient to not separate nonlease components from lease components and to account for each separate lease component and the nonlease components associated with that lease component as a single lease component.
ASC 842 defines a lease as a contract, or part of a contract, that conveys the right to control the use of an identified asset for a period of time in exchange for consideration. Control over the use of an identified asset means that an entity has both the right to obtain substantially all2020 consisted of the economic benefits from the usefollowing items (in thousands):
| | | | | | | | | | | | | | |
| | Year ended December 31, |
| Leases | | 2021 | | 2020 |
| Operating Leases | | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
Operating lease right-of-use assets, net of accumulated amortization (1) | | $ | 6,000 | | | $ | 1,930 | |
| | | | |
| Operating lease obligations, current | | $ | 2,157 | | | $ | 1,883 | |
| Long-term operating lease obligations | | 4,178 | | | 1,109 | |
| Total operating lease obligation | | $ | 6,335 | | | $ | 2,992 | |
| | | | |
| Finance Leases | | | | |
| | | | |
| | | | |
| | | | |
Finance lease right-of-use assets, net of accumulated amortization (2) | | $ | 1,743 | | | $ | 2,385 | |
| | | | |
| Finance lease obligations, current | | $ | 1,011 | | | $ | 1,550 | |
| Long-term finance lease obligations | | 3,152 | | | 3,976 | |
| Total finance lease obligations | | $ | 4,163 | | | $ | 5,526 | |
(1) Operating lease assets are reported net of an identified assetaccumulated amortization of $1.9 million and the right to direct the use of that identified asset. The determination of whether a contract contains a lease may require significant assumptions and judgments.
Historically, Carbon Solutions has used leasing to fund the majority of its capital needs for mining and manufacturing equipment. As$0.8 million as of December 31, 2019, the Company has obligations under finance2021 and operating leases in the amounts2020, respectively.
(2) Finance lease assets are reported net of $6.7accumulated amortization of $1.1 million and $5.2$0.5 million as of December 31, 2021 and 2020, respectively.
Finance leases
ROU assets under finance leases are mining equipment used at the Company’s lignite mine, which provides the key raw material for manufacturing the Company’s products. ROU assets under operating leases are primarily plant equipment used at the Company’s manufacturing facility, but also include other office equipment, vehicles and office facilities. As of December 31, 2019, the Company has ROU assets, net of accumulated amortization, under finance leases and operating leases of $5.9 million and $5.1 million, respectively.
Certain of the finance and operating leases have options permitting renewals for additional periods and buy-out options. Renewal and buy-out options for applicable leases have not been includedreported in the measurement of the respective lease liabilities as the Company is not reasonably certain that it will exercise the respective option or the lessor does not have an exclusive right to exercise the option.
Variable lease payments represent payments made by a lessee for the right to use an underlying asset that vary because of changes in facts or circumstances occurring after the commencement date of a lease other than the passage of time. Variable lease payments that are based on an index or rate, calculated by using the index or rate that exists on the lease commencement date, are included in the measurement of a lease liability. Certain of the Company’s operating leases for office facilities contain variable lease components that are not based on an index or rate,"Property, plant and the Company recognizes these payments as lease expense in the period in which the obligation for those payments is incurred.
The Company calculates lease liabilities based on the present value of lease payments discounted by the rate implicit in the lease or, if not readily determinable, the Company’s incremental borrowing rate.
The Company records lease liabilities and related ROU assets for all leases that have a term of greater than one year. For short-term leases (leases with terms of less than one year), the Company expenses lease payments on a straight-line basis over the lease term.
Finance leases
Leases classified as capital leases under ASC 840 and the related assets and liabilities were recorded and classified as finance leases as of January 1, 2019 based on their carrying values of $8.1 million and $8.2 million, respectively, as of December 31, 2018. ROU assets under finance leasesequipment line item, and finance lease liabilities are included in Property, plant and equipment and Current portion and Long-termthe "Current portion of borrowings, respectively,long-term debt" and "Long-term debt, net of current portion" line items in the Consolidated Balance SheetSheets as of December 31, 2019.2021 and 2020.
Finance lease liabilities are subsequently measured by increasing the carrying amount to reflect interest expense on the finance lease liability and reducing the carrying amount of the lease liability to reflect lease payments made during the period. Interest on finance lease liabilities is determined in each period during the lease term as the amount that produces a constant periodic discount rate on the remaining balance of the lease liability. ROU assets under finance leases are amortized over the remaining lease term on a straight-line basis. Interest expense related to finance lease liabilities and amortization of ROU assets under finance leases are included in Interest expensethe "Interest expense" and Depreciation,"Depreciation, amortization, depletion and accretion,accretion" line respectively, in the Consolidated Statement of Operations for the years ended December 31, 2021 and 2020.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Operating leases
ROU assets under operating leases are included in the "Other long-term assets line item, and operating lease liabilities are included in "Other liabilities" and "Other long-term liabilities" line items, respectively, in the Consolidated Balance Sheets as of December 31, 2021 and 2020.
Lease expense for operating leases for the year ended December 31, 2021 was $4.0 million, of which $3.5 million is included in "Consumables cost of revenues, exclusive of depreciation and amortization" line item and $0.5 million is included in "General and administrative" line item in the Consolidated Statement of Operations for the year ended December 31, 2019.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Operating leases
Operating lease liabilities as of January 1, 2019 were calculated at the present value, using a discount rate of the lease, of the remaining minimum rental payments (as defined under ASC 840). As the rate implicit in all of the operating leases was not readily determinable, the Company determined its discount rate as of January 1, 2019 based on an estimate of its incremental borrowing rate. This rate was based on the Company’s effective borrowing rate on the Senior Term Loan, considering the collateral requirements contained therein, in effect as of January 1, 2019. ROU assets under operating leases as of January 1, 2019 were determined as the calculated value of the operating lease liabilities less accrued lease payments and accrued lease incentives. As of December 31, 2018, the total amount of accrued lease payments and accrued lease incentives was approximately $0.1 million. ROU assets under operating leases and operating lease liabilities are included in Other long-term assets and Other liabilities and Other long-term liabilities, respectively, in the Consolidated Balance Sheet as of December 31, 2019.
Operating lease liabilities are subsequently measured at the present value of the lease payments not yet paid discounted using the discount rate for the lease established at the inception date of the lease (or January 1, 2019 for operating leases in effect as of December 31, 2018). ROU assets under operating leases are subsequently measured at the amounts of the related operating lease liability, adjusted for, as applicable, prepaid or accrued lease payments, the remaining balance of any lease incentives received, unamortized initial direct costs and impairment.2021. Lease expense from operating leases is recognized as a single lease cost over the remaining lease term on a straight-line basis. Variable lease payments not included in operating lease liabilities are recognized as expense in the period in which the obligation for those payments is incurred. Under ASC 842, lease expense for operating leases for the year ended December 31, 20192020 was $4.4 million, of which $3.9$3.8 million is included in Consumables -the "Consumables cost of revenue,revenues, exclusive of depreciation and amortization,amortization" line item and $0.5$0.6 million is included in Generalthe "General and administrativeadministrative" line item in the Consolidated Statement of Operations for the year ended December 31, 2019.
In August 2019, the Company entered into a new lease agreement covering approximately 21,000 square feet of office space for a term of 3.5 years and recorded an ROU asset of $1.2 million and a corresponding operating lease liability of $1.2 million.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
2020.
Lease financial information as of and for the yearyears ended December 31, 20192021 and 2020 is provided in the following table:
| | | | | Year ended December 31, | | Year ended December 31, |
| (in thousands) | | 2019 | (in thousands) | | 2021 | | 2020 |
| Finance lease cost: | | | Finance lease cost: | | | | |
| Amortization of right-of-use assets | | $ | 2,149 |
| Amortization of right-of-use assets | | $ | 642 | | | $ | 1,471 | |
| Interest on lease liabilities | | 365 |
| Interest on lease liabilities | | 288 | | | 401 | |
| Operating lease cost | | 3,673 |
| Operating lease cost | | 2,430 | | | 2,340 | |
| Short-term lease cost | | 771 |
| Short-term lease cost | | 1,650 | | | 2,067 | |
| Variable lease cost (1) | | 371 |
| Variable lease cost (1) | | 40 | | | 163 | |
| Sublease income | | — |
| |
| | Total lease cost | | $ | 7,329 |
| Total lease cost | | $ | 5,050 | | | $ | 6,442 | |
| | | | | | | |
| Other Information: | | | Other Information: | |
| Cash paid for amounts included in the measurement of lease liabilities: | | | Cash paid for amounts included in the measurement of lease liabilities: | |
| Operating cash flows from finance leases | | $ | 365 |
| Operating cash flows from finance leases | | $ | 288 | | | $ | 401 | |
| Operating cash flows from operating leases | | $ | 3,180 |
| Operating cash flows from operating leases | | $ | 2,764 | | | $ | 2,200 | |
| Financing cash flows from finance leases | | $ | 1,354 |
| Financing cash flows from finance leases | | $ | 1,190 | | | $ | 1,360 | |
| Right-of-use assets obtained in exchange for new finance lease liabilities | | $ | — |
| Right-of-use assets obtained in exchange for new finance lease liabilities | | $ | — | | | $ | 158 | |
| Right-of-use assets obtained in exchange for new operating lease liabilities | | $ | 1,309 |
| Right-of-use assets obtained in exchange for new operating lease liabilities | | $ | 6,108 | | | $ | 59 | |
| Weighted-average remaining lease term - finance leases | | 4.2 years |
| Weighted-average remaining lease term - finance leases | | 2.9 years | | 3.5 years |
| Weighted-average remaining lease term - operating leases | | 2.4 years |
| Weighted-average remaining lease term - operating leases | | 4.3 years | | 1.8 years |
| Weighted-average discount rate - finance leases | | 6.1 | % | Weighted-average discount rate - finance leases | | 6.4 | % | | 6.2 | % |
| Weighted-average discount rate - operating leases | | 8.5 | % | Weighted-average discount rate - operating leases | | 6.7 | % | | 8.5 | % |
(1) Primarily includes common area maintenance, property taxes and insurance payable to lessors.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The following table summarizes the Company's future lease payments under finance and operating leases as of December 31, 2019:2021:
| | | | | | | | | | | | | | | | | | | | |
| (in thousands) | | Operating
Lease
Commitments | | Finance
Lease
Commitments | | Total Lease Commitments |
| 2022 | | $ | 2,502 | | | $ | 1,008 | | | $ | 3,510 | |
| 2023 | | 2,005 | | | 980 | | | 2,985 | |
| 2024 | | 739 | | | 1,929 | | | 2,668 | |
| 2025 | | 566 | | | 569 | | | 1,135 | |
| 2026 | | 566 | | | — | | | 566 | |
| Thereafter | | 871 | | | — | | | 871 | |
| Total lease payments | | 7,249 | | | 4,486 | | | 11,735 | |
| Less: Imputed interest | | (914) | | | (323) | | | (1,237) | |
| Present value of lease payments | | $ | 6,335 | | | $ | 4,163 | | | $ | 10,498 | |
|
| | | | | | | | | | | | |
| (in thousands) | | Operating
Lease
Commitments | | Finance
Lease
Commitments | | Total Lease Commitments |
| 2020 | | $ | 2,710 |
| | $ | 1,707 |
| | $ | 4,417 |
|
| 2021 | | 1,969 |
| | 1,802 |
| | 3,771 |
|
| 2022 | | 721 |
| | 951 |
| | 1,672 |
|
| 2023 | | 359 |
| | 951 |
| | 1,310 |
|
| 2024 | | — |
| | 1,929 |
| | 1,929 |
|
| Thereafter | | — |
| | 568 |
| | 568 |
|
| Total lease payments | | 5,759 |
| | 7,908 |
| | 13,667 |
|
| Less: Imputed interest | | (567 | ) | | (1,179 | ) | | (1,746 | ) |
| Present value of lease payments | | $ | 5,192 |
| | $ | 6,729 |
| | $ | 11,921 |
|
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Disclosures under ASC 840
As previously disclosed in the Company's 2018 Annual Report on Form 10-K and under ASC 840, the following table summarizes the Company’s future minimum non-cancellable lease payments due under capital and operating leases as of December 31, 2018:
|
| | | | | | | | |
| (in thousands) | | Operating
Lease
Commitments | | Capital
Lease
Commitments |
| 2019 | | $ | 3,619 |
| | $ | 1,749 |
|
| 2020 | | 2,273 |
| | 1,707 |
|
| 2021 | | 1,632 |
| | 1,802 |
|
| 2022 | | 310 |
| | 951 |
|
| 2023 | | 221 |
| | 951 |
|
| Thereafter | | — |
| | 2,482 |
|
| Total minimum lease payments | | $ | 8,055 |
| | 9,642 |
|
| Less: Imputed interest | | | | (1,475 | ) |
| Present value of minimum lease payments | | | | $ | 8,167 |
|
Rent expense for the year ended December 31, 2018 was $0.3 million and was included in General and administrative expense in the Consolidated Statements of Operations.
As of December 31, 2018, mining equipment financed under capital leases of $8.1 million, net of accumulated amortization of $0.1 million, was included in Property, plant and equipment in the Consolidated Balance Sheet.
Note 813 - Revenues
Contract Assets and Liabilities
Contract assets are comprised of unbilledTrade receivables and are included in Receivables, net in the Consolidated Balance Sheet. Unbilled receivables represent a conditional right to consideration in exchange for goods or services transferred to a customer.
Trade receivables represent an unconditional right to consideration in exchange for goods or services transferred to a customer. The Company invoices its customers in accordance with the terms of the contract. Credit terms are generally net 30 from the date of invoice. The timing between the satisfaction of performance obligations and when payment is due from the customer is generally not significant. The Company records allowances for doubtful trade receivables when it is probable that the balances will not be collected.
Contract liabilities are comprised of deferred revenue, which represents an obligation to transfer goods or services to a customer for which the Company has received consideration from the customer and, if deliverable within one year or less, is included in Other current liabilities in the Consolidated Balance Sheet and, if deliverable outside of one year, is included in Other long-term liabilities in the Consolidated Balance Sheet.
Trade receivables, net
The following table shows the components of Trade receivables, net: | | | | | As of December 31, | | | As of December 31, |
| (in thousands) | | 2019 | | 2018 | (in thousands) | | 2021 | | 2020 |
| Trade receivables | | $ | 8,057 |
| | $ | 10,121 |
| Trade receivables | | $ | 10,476 | | | $ | 12,241 | |
| Less: Allowance for doubtful accounts | | (627 | ) | | (567 | ) | Less: Allowance for doubtful accounts | | — | | | (37) | |
| Trade receivables, net | | $ | 7,430 |
| | $ | 9,554 |
| Trade receivables, net | | $ | 10,476 | | | $ | 12,204 | |
| | |
DuringCabot Receivable
The following table shows the years endedcomponents of the Cabot Receivable:
| | | | | | | | | | | | | | |
| | As of |
| (in thousands) | | December 31, 2021 | | December 31, 2020 |
| Receivables, net | | $ | 2,146 | | | $ | 921 | |
| Other long-term assets, net | | 6,846 | | | 8,852 | |
| Total Cabot Receivable | | $ | 8,992 | | | $ | 9,773 | |
Upfront Customer Consideration
As described in Note 4, as of September 30, 2020, the Company recorded an asset for Upfront Customer Consideration of $7.6 million in connection with the Supply Agreement, which is amortized on a straight-line basis as a reduction to revenue over the expected 15-year contractual period of the Supply Agreement. The unamortized balance is included in Other long-term assets, net on the Company's Consolidated Balance Sheets as of December 31, 20192021 and 2018, the Company recognized $0.1 million and $0.2 million, respectively, as bad debt expense related to specific accounts whose ultimate collection was in doubt.2020.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Disaggregation of Revenue and Earnings from Equity Method Investments
DuringFor the yearyears ended December 31, 20192021 and 2018,2020, all performance obligations related to revenues recognized were satisfied at a point in time. The Company disaggregates its revenues by its major components as well as between its two2 operating segments, which are further discussed in Note 1519 to the consolidated financial statements. The Company does not disaggregate revenue by geographic region as revenue is generated primarily from customers inIn the United States; however, in the PGIAPT segment for the year ended December 31, 2019,2021 and 2020, approximately 13% and 15%, respectively, of PGIAPT revenue was generated in Canada. The following tables disaggregate revenues by major source for the year ended December 31, 20192021 and 2018 (in thousands):2020:
| | | | | | | | | | | | | | | | | | | | | | |
| | Year ended December 31, 2021 |
| | Segment | | | | |
| (in thousands) | | APT | | RC | | | | Total |
| Revenue component | | | | | | | | |
| Consumables | | $ | 85,882 | | | $ | — | | | | | $ | 85,882 | |
| License royalties, related party | | — | | | 14,368 | | | | | 14,368 | |
| Other | | 44 | | | — | | | | | 44 | |
| | | | | | | | |
| Revenues from customers | | 85,926 | | | 14,368 | | | | | 100,294 | |
| | | | | | | | |
| Earnings from equity method investments | | — | | | 68,726 | | | | | 68,726 | |
| | | | | | | | |
| Total revenues and earnings from equity method investments | | $ | 85,926 | | | $ | 83,094 | | | | | $ | 169,020 | |
| | | | | | | | | | | | | | | | | | | | | | |
| | Year ended December 31, 2020 |
| | Segment | | | | |
| (in thousands) | | APT | | RC | | | | Total |
| Revenue component | | | | | | | | |
Consumables (1) | | $ | 53,908 | | | $ | — | | | | | $ | 53,908 | |
| License royalties, related party | | — | | | 13,440 | | | | | 13,440 | |
| Other | | 15 | | | — | | | | | 15 | |
| | | | | | | | |
| Revenues from customers | | 53,923 | | | 13,440 | | | | | 67,363 | |
| | | | | | | | |
| Earnings from equity method investments | | — | | | 30,978 | | | | | 30,978 | |
| | | | | | | | |
| Total revenues and earnings from equity method investments | | $ | 53,923 | | | $ | 44,418 | | | | | $ | 98,341 | |
(1) Consumables revenues for the year ended December 31, 2020 have been restated. See restatement discussion in Note 2.
|
| | | | | | | | | | | | | | | | |
| | | Year ended December 31, 2019 |
| | | Segment | | | | |
| (in thousands) | | PGI | | RC | | Other | | Total |
| Revenue component | | | | | | | | |
| Consumables | | $ | 50,458 |
| | $ | — |
| | $ | 2,729 |
| | $ | 53,187 |
|
| License royalties, related party | | — |
| | 16,899 |
| | — |
| | 16,899 |
|
| Revenues from customers | | 50,458 |
| | 16,899 |
| | 2,729 |
| | 70,086 |
|
| | | | | | | | | |
| Earnings from equity method investments | | — |
| | 69,176 |
| | — |
| | 69,176 |
|
| | | | | | | | | |
| Total revenues and earnings from equity method investments | | $ | 50,458 |
| | $ | 86,075 |
| | $ | 2,729 |
| | $ | 139,262 |
|
|
| | | | | | | | | | | | | | | | |
| | | Year ended December 31, 2018 |
| | | Segment | | | | |
| (in thousands) | | PGI | | RC | | Other | | Total |
| Revenue component | | | | | | | | |
| Consumables | | $ | 8,628 |
| | $ | — |
| | $ | 105 |
| | $ | 8,733 |
|
| License royalties, related party | | — |
| | 15,140 |
| | — |
| | 15,140 |
|
| Other | | 72 |
| | — |
| | — |
| | 72 |
|
| Revenues from customers | | 8,700 |
| | 15,140 |
| | 105 |
| | 23,945 |
|
| | | | | | | | | |
| Earnings from equity method investments | | — |
| | 54,208 |
| | — |
| | 54,208 |
|
| | | | | | | | | |
| Total revenues and earnings from equity method investments | | $ | 8,700 |
| | $ | 69,348 |
| | $ | 105 |
| | $ | 78,153 |
|
Note 914 - Commitments and Contingencies
Legal Proceedings
The Company is from time to time subject to, and is presently involved in, various pending or threatened legal actions and proceedings, including those that arise in the ordinary course of its business. Such matters are subject to many uncertainties and outcomes, the financial impacts of which are not predictable with assurance and that may not be known for extended periods of time. The Company records a liability in its consolidated financial statements for costs related to claims, settlements, and judgments where management has assessed that a loss is probable, and an amount can be reasonably estimated. The Company did not have any significant legal proceedings.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Restricted Cash
As of December 31, 2021 and 2020, the Company had long-term restricted cash of $10.0 million and $5.0 million, respectively, as required under the Surety Agreement related to the Reclamation Contract. As of December 31, 2020, the Company had short-term restricted cash of $5.0 million as required under a minimum cash balance requirement of a Senior Term Loan covenant.
Surety Bonds
As of December 31, 2021, the Company had outstanding surety bonds of $24.1 million related to performance requirements under reclamation contracts associated with both the Five Forks Mine and the Marshall Mine.
Other Commitments and Contingencies
The Company also has certain limited obligations contingent upon future events in connection with the activities of Tinuum Group. The Company, NexGen and two entities affiliated with NexGen have provided GSFS with limited guaranties (the "Tinuum Group Party Guaranties") related to certain losses it may suffer as a result of inaccuracies or breach of representations
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
and covenants. The Company also is a party to a contribution agreement with NexGen under which any party called upon to pay on a Tinuum Group Party Guaranty is entitled to receive contribution from the other party equal to 50% of the amount paid. No liability or expense provision has been recorded by the Company related to this contingent obligation as the Company believes that it is not probable that a loss will occur with respect to Tinuum Group Party Guaranties.
Note 1015 - Stockholders' Equity
The Company has two classes of capital stock authorized, common stock and preferred stock, which are described as follows:
Preferred Stock
The Company's Board of Directors (the "Board'"Board") is authorized to provide out of the unissued shares of Preferred Stock and to fix the number of shares constituting a series of Preferred Stock and, with respect to each series, to fix the number of shares and designation of such series, the voting powers, if any, the preferences and relative, participating, option or other special rights, if any, and any qualifications, limitations or restrictions thereof, of the shares of such series. As of December 31, 20192021 and 2018,2020, there were no shares of Preferred Stock designated or outstanding.
Common Stock
Holders of common stock are entitled to one1 vote for each share held of record on all matters submitted to a vote of the stockholders. Additionally, holders of common stock are entitled to receive dividends when and if declared by the Board, subject to any statutory or contractual restrictions on payment of dividends and to any restrictions on the payment of dividends imposed by the terms of any outstanding shares of preferred stock.
Upon dissolution, liquidation or the sale of all or substantially all of the Company's assets, after payment in full of any amounts required to be paid to creditors and to the holders of preferred stock having liquidation preferences, if any, the holders of shares of common stock will be entitled to receive the Company's remaining assets for distribution on a pro rata basis.
Stock Repurchase Programs
In November 2018, the Board authorized the Company to purchase up to $20.0 million of its outstanding common stock. Thisstock under a stock repurchase program (the "Stock Repurchase Program"), which was to remain in effect until December 31, 2019 unless otherwise modified by the Board. As of November 2019, $2.9 million remained outstanding related to this program. In November 2019, the Board authorized an incremental $7.1 million to this stock repurchase programthe Stock Repurchase Program and provided that the programit will remain in effect until all amounts are utilized or the programit is otherwise modified by the Board. Previously, the Board had authorized the Company to purchase up to $20.0 million of its outstanding common stock under a separate repurchase program that was in effect until July 31, 2018.
DuringFor the years ended December 31, 20192021 and 2018,2020, under the collective stock repurchase programs authorized by the Board,Stock Repurchase Program, the Company purchased 533,345zero and 2,350,42220,613 shares of its common stock for cash of $5.8 millionzero and $25.3$0.2 million, inclusive of commissions and fees, respectively. Of these amounts, zero and $15.6 million, respectively, was purchased in single blocks through privately negotiated transactions. As of December 31, 2019,2021, the Company had $7.1$7.0 million remaining under its stock repurchase program.
Quarterly Cash Dividend
Dividends declared to holders of the Company's common shares during the years ended December 31, 2019 and December 31, 2018 were $18.6 million and $20.3 million, respectively. A portion of the dividends remains accrued subsequent to the payment dates and represents dividends accumulated on nonvested shares of common stock held by employees of the Company that contain forfeitable dividend rights that are not payable until the underlying shares of common stock vest. These amounts are included in both Other current liabilities and Other long-term liabilities on the Consolidated Balance Sheet as of December 31, 2019 and 2018.Stock Repurchase Program.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Dividends declared and paid quarterly per share on all outstanding shares of common stock during the years ended December 31, 2019 and 2018 were as follows: |
| | | | | | | | | | | | |
| | | 2019 | | 2018 |
| | | Per share | | Date paid | | Per share | | Date paid |
| Dividends declared during quarter ended: | | | | | | | | |
| March 31 | | $ | 0.25 |
| | March 7, 2019 | | $ | 0.25 |
| | March 8, 2018 |
| June 30 | | 0.25 |
| | June 7, 2019 | | 0.25 |
| | June 8, 2018 |
| September 30 | | 0.25 |
| | September 6, 2019 | | 0.25 |
| | September 6, 2018 |
| December 31 | | 0.25 |
| | December 13, 2019 | | 0.25 |
| | December 6, 2018 |
| | | $ | 1.00 |
| | | | $ | 1.00 |
| | |
Tax Asset Protection Plan
United StatesU.S. federal income tax rules, and Section 382 of the Internal Revenue Code in particular, could substantially limit the use of net operating losses and other tax assets if ADESthe Company experiences an "ownership change" (as defined in the Internal Revenue Code). In general, an ownership change occurs if there is a cumulative change in the ownership of ADESthe Company by "5 percent stockholders" that exceeds 50 percentage points over a rolling three-year period.
On May 5, 2017, the Board approved the declaration of a dividend of rights to purchase Series B Junior Participating Preferred Stock for each outstanding share of common stock as part of a tax asset protection plan (the "TAPP") designed to protect the Company’s ability to utilize its net operating losses and tax credits. The TAPP is intended to act as a deterrent to any person acquiring beneficial ownership of 4.99% or more of the Company’s outstanding common stock.
On April 6, 2018,9, 2021, the Board approved the FirstFourth Amendment to the Tax Asset Protection Plan (the "Amendment"TAPP ("Fourth Amendment") that amends the TAPP.TAPP, as previously amended by the First, Second and Third Amendments that were approved the Board on April 6, 2018, April 5, 2019 and April 9, 2020, respectively. The Fourth Amendment amends the definition of "Final Expiration Date" under the TAPP to extend the duration of the TAPP and makes associated changes in connection therewith. At the Company's 20182021 annual meeting of stockholders, the Company's stockholders approved the Fourth Amendment, thus the Final Expiration Date will be the close of business on December 31, 2019, which was subsequently extended, as described below.2022.
On April 5, 2019, the Board approved the Second Amendment to the TAPP (the "Second Amendment") that amends the TAPP, as previously amended. The Second Amendment amends the definition of the “Final Expiration Date” under the TAPP to extend the duration of the TAPP and makes associated changes in connection therewith. At the Company's 2019 annual meeting of stockholders, the Company's stockholders approved the Second Amendment, thus the Final Expiration Date became the close of business on December 31, 2020.
Note 1116 - Stock-Based Compensation
The Plans
The Company currently has incentive plans, includingOn June 20, 2017, the Amended and Restated 2010 Non-Management Compensation and Incentive Plan, as amended (the “2010 Plan”) andCompany's stockholders approved the 2017 Omnibus Incentive Plan (the “2017 Plan”"2017 Plan") as described below. Collectively, these plans are called the “Stock Plans" and permit the Company to issue stock-based, which permits grants of awards including common stock, restricted stock, stock options and other rights and benefits under the plans to employees, directors and non-employees.
The 2010 Plan - During 2010, Awards may be in the Company adopted the 2010 Plan which permits grantsform of stock awards to employees, which may be shares, rights to purchase restricted stock, bonuses of restricted stock, or other rights or benefits as described under the plan. The Company reserved 600,000 shares of its common stock for these purposes. The Plan was amended and restated as of July 19, 2012 to make non-material changes to assure Internal Revenue Code Section 409A compliance. Upon the adoption of the 2017 Plan in June 2017, the Company no longer grants any awards from the 2010 Plan.
The 2017 Plan - During 2017, the Company adopted the 2017 Plan which permits grants of awards to employees, directors and non-employees, which may be shares, rights to purchase restricted stock, bonuses of restricted stock, or other rights or benefits under the plan. As of December 31, 2019,2021, the Company has 2,000,000644,540 shares of its common stock authorized for issuance under the 2017 Plan.
Expense
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
RSA's - Restricted Stock Awards ("RSA's") are typically granted with vesting terms of three years. The fair value of RSA's is determined based on the closing price of the Company’s common stock on the authorization date of the grant multiplied by the number of shares subject to the stock award. Compensation expense for RSA's is generally recognized over the vesting term on a straight-line basis.
Stock Options - Stock options generally vest over three years or upon satisfaction of performance-based conditions and have a contractual limit of five years from the date of grant to exercise. The fair value of stock options granted is determined on the date of grant using the Black-Scholes option pricing model and the related expense is recognized on a straight-line basis over the entire vesting period. No stock options were granted during the years ended December 31, 2019 and 2018.
When options are granted, the Company uses historical data to estimate inputs used in the Black-Scholes option pricing model.
Risk-free interest rate - The risk-free interest rate for stock options granted during the period was determined by using a zero-coupon U.S. Treasury rate for the periods that coincided with the expected terms listed above.
Dividends - As historically no dividends had been paid as of the date by which grants occurred, no dividend yield was included in the calculations when the outstanding options were granted.
Expected volatility - To calculate expected volatility, the historical volatility of the Company's common stock was used.
Expected term - The Company’s expected term of options was based upon historical exercise behavior and consideration of the options' vesting and contractual terms.
RSU's - Restricted Stock Units ("RSU's") are typically granted with vesting terms of one year. The fair value of RSU's is determined based on the closing price of the Company’s common stock on the authorization date of the grant multiplied by the number of shares subject to the stock award. Compensation expense is generally recognized over the service period of the award on a straight-line basis.
PSU's - Performance share units ("PSU's") generally vest over three years and are based on the grantee’s continuous service with the Company, performance measures or a combination of both. Each PSU represents a contingent right to receive shares of the Company’s common stock if the Company meets certain performance measures over the requisite period.
Compensation expense is recognized for PSU awards on a straight-line basis over the vesting period based on the estimated fair value at the date of grant using a Monte Carlo simulation model. No PSU's were granted during the years ended December 31, 2019 or 2018.
Risk-free interest rate - The risk-free interest rate for PSU's granted during the period was determined by using a zero-coupon, U.S. Treasury rate for the periods that coincided with the expected terms listed above.
Dividends - As historicallythe PSU's granted receive dividend equivalent units, no discount was applied for any dividends had been paid as of the date by which grants occurred, no dividend yield was included in the calculations.declared.
Expected volatility - To calculate expected volatility, the historical volatility of the Company's common stock was used.
Performance period - The Company’s performance period is based upon the vesting term of the Company’s PSU awards.
The Company recorded the following compensation expense related to the Stock Plans: | | | | | Years Ended December 31, | | | Years Ended December 31, | |
| (in thousands) | | 2019 | | 2018 | (in thousands) | | 2021 | | 2020 | |
| RSA expense | | $ | 2,011 |
| | $ | 2,222 |
| RSA expense | | $ | 1,816 | | | $ | 2,304 | | |
| Stock option expense | | — |
| | 58 |
| |
| RSU expense | | — |
| | 210 |
| |
| | PSU expense | | PSU expense | | 111 | | | 192 | | |
| Total stock-based compensation expense | | $ | 2,011 |
| | $ | 2,490 |
| Total stock-based compensation expense | | $ | 1,927 | | | $ | 2,496 | | |
|
Stock-based compensation expense related to manufacturing employees and administrative employees is included in the Cost"Consumables cost of goods soldrevenues, excluding depreciation and Payrollamortization and "Payroll and benefits line items, respectively,items" in
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
the Consolidated Statements of Operations. Stock-based compensation expense related to non-employee directors and consultants is included in the General"General and administrativeadministrative" line item in the Consolidated Statements of Operations.
During the year ended December 31, 2019 and 2018, the Company modified the terms of awards granted to zero and 13
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
employees in connection with its restructuring plans and termination of the impacted employees discussed in Note 19. These modifications resulted in the accelerated vesting and incremental expense related to certain performance-based awards and restricted stock awards. As a result, during 2019 and 2018, the Company recognized incremental stock-based compensation of zero and $0.8 million, respectively, which was included in the Payroll and benefits line item in the Consolidated Statements of Operations.
The amount of unrecognized compensation cost as of December 31, 2019,2021, and the expected weighted-average period over which the cost will be recognized is as follows: | | | | | As of December 31, 2019 | | As of December 31, 2021 |
| (in thousands) | | Unrecognized Compensation Cost | | Expected Weighted-Average Period of Recognition (in years) | (in thousands) | | Unrecognized Compensation Cost | | Expected Weighted-Average Period of Recognition (in years) |
| RSA expense | | $ | 2,521 |
| | 1.47 | RSA expense | | $ | 1,961 | | | 1.79 |
| | PSU expense | | PSU expense | | 282 | | | 1.71 |
| Total unrecognized stock-based compensation expense | | $ | 2,521 |
| | 1.47 | Total unrecognized stock-based compensation expense | | $ | 2,243 | | | 1.62 |
Activity
Restricted Stock
A summary of the status and activity of RSA's and RSU'sfor the year ended December 31, 2021 is presented in the following table:
| | | | Restricted Stock | | | Weighted-Average Grant Date Fair Value | |
| (in thousands, except for share and per share amounts) | | (in thousands, except for share and per share amounts) | | Awards | | | RSA's | |
| | | | | Restricted Stock | | Weighted-Average Grant Date Fair Value | |
| (in thousands, except for share and per share amounts) | | Awards | | Units | | RSA's | | RSU's | |
| For the year ended December 31, 2019 | | | | | | | | | |
| Non-vested at January 1, 2019 | | 280,852 |
| | 20,000 |
| | $ | 9.92 |
| | $ | 10.52 |
| |
| | For the year ended December 31, 2021 | | For the year ended December 31, 2021 | | | | | | |
| Non-vested at January 1, 2021 | | Non-vested at January 1, 2021 | | 373,860 | | | | $ | 7.25 | | |
| Granted | | 287,288 |
| | — |
| | $ | 11.03 |
| | $ | — |
| Granted | | 445,383 | | | | $ | 5.54 | | |
| Vested | | (108,081 | ) | | (20,000 | ) | | $ | 9.77 |
| | $ | 10.52 |
| Vested | | (206,894) | | | | $ | 7.47 | | |
| Forfeited | | (8,715 | ) | | — |
| | $ | 10.79 |
| | $ | — |
| Forfeited | | (80,726) | | | | $ | 5.90 | | |
| Non-vested at December 31, 2019 | | 451,344 |
| | — |
| | $ | 10.65 |
| | $ | — |
| |
| Non-vested at December 31, 2021 | | Non-vested at December 31, 2021 | | 531,623 | | | | $ | 5.94 | | |
The weighted-average grant date fair value of RSA's granted or modified duringfor the years ended December 31, 20192021 and 20182020 was $11.03$5.54 and $11.00, respectively. The weighted-average grant date fair value of RSU's granted or modified during the years ended December 31, 2019 and 2018 was zero and $10.52,$5.20, respectively. The total grant-date fair value of RSA's vested duringfor the years ended December 31, 20192021 and 20182020 was $1.1$1.5 million and $2.0$3.4 million, respectively. The aggregate intrinsic value of non-vested RSA's and RSU's outstanding as of December 31, 20192021 was $4.7 million and zero, respectively.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Stock Options
A summary of option activity under the Stock Plans is presented below: |
| | | | | | | | | | | | | |
| (in thousands, except for share and per share amounts) | | Number of
Options
Outstanding and
Exercisable | | Weighted-
Average
Exercise
Price | | Aggregate Intrinsic Value | | Weighted-
Average
Remaining
Contractual
Term (in years) |
| For the year ended December 31, 2019 | | | | | | | | |
| Options outstanding at January 1, 2019 | | 529,780 |
| | $ | 12.23 |
| | | | |
| Options granted | | — |
| | $ | — |
| | | | |
| Options exercised | | (209,780 | ) | | $ | 9.14 |
| | | | |
| Options expired / forfeited | | (20,000 | ) | | $ | 20.07 |
| | | | |
| Options outstanding at December 31, 2019 | | 300,000 |
| | $ | 13.87 |
| | $ | — |
| | 0.43 |
| Options vested and exercisable at December 31, 2019 | | 300,000 |
| | $ | 13.87 |
| | $ | — |
| | 0.43 |
The weighted-average grant-date fair value of options vesting during the years ended December 31, 2019 and 2018 was zero and $0.3 million, respectively. The weighted-average grant-date fair value of options exercised during the year ended December 31, 2019 and 2018 was $0.6 million and $0.3 million, respectively. The Company received proceeds of $0.2 million from the exercise of stock options during the year ended December 31, 2019. The Company did not receive cash from the exercise of stock options during the year ended December 31, 2018.
Cash flows resulting from excess tax benefits, if any, are classified as part of cash flows from financing activities. Excess tax benefits are realized tax benefits from tax deductions for vested RSA's and exercised options in excess of the deferred tax asset attributable to stock compensation costs for such equity awards. The Company recorded no excess tax benefits for the years ended December 31, 2019 and 2018.$3.5 million.
PSU's
There were no PSU's granted during the years ended December 31, 2019 and 2018. PSU's outstanding remainedremain unvested until the third anniversary date of their issuance date, at which time the actual number of vested shares waswill be determined based uponon the actual price performances of the Company’s common stock relative to a broad stock index and a peer group performance index.
The following table shows the PSU's that were settled by issuing the Company's common stock relative to a peer group performance index and broad stock index. |
| | | | | | | | | | | | | | | | | | | | |
| | | Year of Grant | | Net Number of Issued Shares upon Vesting | | Shares Withheld to Settle Tax Withholding Obligations | | TSR Multiple Range | | Russell 3000 Multiple |
| | | | | | Low | | High | | Low | | High |
| For year ended December 31, 2018 | | | | | | | | | | | | | | |
| | | 2015 | | 12,311 |
| | 4,061 |
| | 112.50 |
| | 112.50 |
| | — |
| | — |
|
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
A summary of PSU activity for the year ended December 31, 2021 is presented in the table below:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Units | | Weighted-Average
Grant Date
Fair Value | | Aggregate Intrinsic Value (in thousands) | | Weighted-Average
Remaining
Contractual
Term (in years) |
| For the year ended December 31, 2021 | | | | | | | | |
| PSU's outstanding, January 1, 2021 | | 50,127 | | | $ | 6.17 | | | | | |
| Granted | | 62,448 | | | 7.09 | | | | | |
| Vested / Settled | | — | | | — | | | | | |
| Forfeited / Canceled | | (24,549) | | | 6.78 | | | | | |
| PSU's outstanding, December 31, 2021 | | 88,026 | | | $ | 6.17 | | | $ | 583 | | | 1.71 |
Note 1217 - Supplemental Financial Information
Supplemental Balance Sheet Information
The following table summarizes the components of Prepaid"Prepaid expenses and other assetscurrent assets" and Other"Other long-term assets, net net"as presented in the Consolidated Balance Sheet:Sheets:
| | | | | | | | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2021 | | 2020 |
| Prepaid expenses and other current assets: | | | | |
| Prepaid expenses | | $ | 2,571 | | | $ | 1,690 | |
| Prepaid income taxes and income tax refunds | | 2,782 | | | 1,605 | |
| | | | |
| Other | | 1,308 | | | 1,302 | |
| | $ | 6,661 | | | $ | 4,597 | |
| Other long-term assets: | | | | |
Upfront customer consideration (1) | | $ | 6,982 | | | $ | 7,490 | |
Cabot receivable (1) | | 6,846 | | | 8,852 | |
| Right of use assets, operating leases, net | | 6,000 | | | 1,930 | |
| Spare parts, net | | 4,598 | | | 3,727 | |
| Mine development costs, net | | 5,330 | | | 4,338 | |
| Mine reclamation asset, net | | 1,742 | | | 1,712 | |
| Highview investment | | 552 | | | 552 | |
| Other long-term assets | | 1,193 | | | 1,388 | |
| | $ | 33,243 | | | $ | 29,989 | |
|
| | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2019 | | 2018 |
| Prepaid expenses and other current assets: | | | | |
| Prepaid expenses | | $ | 1,708 |
| | $ | 1,233 |
|
| Prepaid income taxes | | 4,228 |
| | 2,940 |
|
| Other | | 1,896 |
| | 1,397 |
|
| | | $ | 7,832 |
| | $ | 5,570 |
|
| Other long-term assets: | | | | |
| Right of use assets, operating leases, net | | $ | 5,073 |
| | $ | — |
|
| Spare parts, net | | 3,453 |
| | 3,278 |
|
| Mine development costs, net | | 7,084 |
| | 2,531 |
|
| Mine reclamation asset, net | | 2,451 |
| | 408 |
|
| Highview investment | | 552 |
| | 552 |
|
| Other long-term assets | | 1,718 |
| | 1,224 |
|
| | | $ | 20,331 |
| | $ | 7,993 |
|
Spare parts include critical spares required to support plant operations. Parts and supply costs are determined using the lower of cost or estimated replacement cost. Parts are recorded as maintenance expenses in the period in which they are consumed.
Mine development costs include acquisition costs, the cost of other development work and mitigation costs related to the Five Forks Mine and are depleted over the estimated life of the related mine reserves, which is 21 years.estimated to be 13 years as of December 31, 2021. The Company performs an evaluation of the recoverability of the carrying value of mine development costs to determine if facts and circumstances indicate that their carrying value may be impaired and if any adjustment is warranted. There were no indicators of impairment as of December 31, 2019. Mine reclamation asset represents anthe ARO asset retirement obligation assetrelated to the Five Forks Mine and is depreciated over theits estimated life of the mine.life.
The Company holds a long-term investment (the "Highview Investment") in Highview Enterprises Limited ("Highview"), a London, England based developmental stage company specializing in power storage. In November 2014, the Company acquired an 8% ownership interest in the common stock of Highview for $2.8 million in cash. The Company accounts for the
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Highview Investment as an investment recorded at cost, less impairment, plus or minus observable changes in price for identical or similar investments of the same issuer.
The Highview Investment is evaluated for indicators of impairment such as an event or change in circumstances that may have a significant adverse effect on the fair value of the investment. There were no changes to the carrying value of the Highview Investment for the years ended December 31, 20192021 and 20182020 as there were no indicators of impairment or observable price changes for equity issued by Highview. Since inception of Highview Investment, the Company has recognized $2.2 million of cumulative impairment losses.
The following table details the components of "Other current liabilities" and "Other long-term liabilities" as presented in the Consolidated Balance Sheets:
| | | | | | | | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2021 | | 2020 |
| Other current liabilities: | | | | |
| Current portion of operating lease obligations | | $ | 2,157 | | | $ | 1,883 | |
| Accrued interest | | — | | | 69 | |
| Income and other taxes payable | | 807 | | | 1,305 | |
| Current portion of mine reclamation liability | | 1,775 | | | 9,370 | |
| | | | |
| | | | |
| | | | |
| | | | |
| Other current liabilities | | 385 | | | 369 | |
| | $ | 5,124 | | | $ | 12,996 | |
| Other long-term liabilities: | | | | |
| Operating lease obligations, long-term | | $ | 4,178 | | | $ | 1,109 | |
| Mine reclamation liabilities | | 8,184 | | | 12,077 | |
| | | | |
| | | | |
| Other | | — | | | 287 | |
| | $ | 12,362 | | | $ | 13,473 | |
The Mine reclamation liability related to the Five Forks Mine is included in Other long-term liabilities. The Mine reclamation liability related to Marshall Mine, which was assumed in the Marshall Mine Acquisition is included in Other current liabilities" and "Other long-term liabilities." The Mine reclamation liabilities represent AROs. Changes in the AROs were as follows:
| | | | | | | | | | | | | | |
| | As of December 31, |
| (in thousands) | | 2021 | | 2020 |
| Asset retirement obligations, beginning of year | | $ | 21,447 | | | $ | 2,721 | |
| Asset retirement obligations assumed | | — | | | 21,328 | |
| Accretion | | 1,102 | | | 543 | |
| Liabilities settled | | (10,010) | | | (3,565) | |
| Changes due to scope and timing of reclamation | | (2,580) | | | 420 | |
| Asset retirement obligations, end of year | | 9,959 | | | 21,447 | |
| Less current portion | | 1,775 | | | 9,370 | |
| Asset retirement obligations, long-term | | $ | 8,184 | | | $ | 12,077 | |
Supplemental Consolidated Statements of Operations Information
Gain on Settlement
On December 29, 2020, the Company and a former customer (the "Parties") reached a settlement (the "Settlement") on various litigation matters (the "Litigation Matters") that resulted in the former customer (the "Former Customer") agreeing to pay to the Company cash of $2.5 million (the "Settlement Amount"), which was received on January 27, 2021. This payment was in exchange for full dissolution of all claims and counterclaims that the two Parties asserted or could have asserted against each other in the Litigation Matters, or which have arisen or may arise against each other but are presently unknown, arising out of or related to the Litigation Matters and related to any other of the Parties’ business dealings, conduct and/or transactions through
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
the date of the Settlement, including all claims for damages, fees, costs, sanctions, or any other amounts due or to become due in connection with the foregoing.
The Company applied the Settlement Amount cash proceeds to both an outstanding trade account receivable and note receivable due from the Former Customer and recognized the excess cash received as a gain of $1.1 million, which is reported as "Gain on settlement" as a component of operating expenses in the Consolidated Statements of Operations for the year ended December 31, 2020.
Gain on Change in estimate, asset retirement obligation
As discussed in Note 4, for the year ended December 31, 2021, recorded a gain on change in estimate of $2.7 million based on its revisions in its estimate of future obligations owed for the reclamation of Marshall Mine.
The following table details the components of Other current liabilities and Other long-term liabilities as presented"Interest expense" in the Consolidated Balance Sheet:Statements of Operations:
| | | | | | | | | | | | | | | | |
| | Years Ended December 31, | | |
| (in thousands) | | 2021 | | 2020 | | |
| Interest on Senior Term Loan | | $ | 206 | | | $ | 1,708 | | | |
| Debt discount and debt issuance costs | | 945 | | | 1,418 | | | |
| 453A interest | | 13 | | | 331 | | | |
| | | | | | |
| Other | | 326 | | | 463 | | | |
| | $ | 1,490 | | | $ | 3,920 | | | |
|
| | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2019 | | 2018 |
| Other current liabilities: | | | | |
| Current portion of operating lease obligations | | $ | 2,382 |
| | $ | — |
|
| Accrued interest | | 213 |
| | 407 |
|
| Income and other taxes payable | | 678 |
| | 479 |
|
| Other current liabilities | | 1,038 |
| | 1,252 |
|
| | | $ | 4,311 |
| | $ | 2,138 |
|
| Other long-term liabilities: | | | | |
| Operating lease obligations, long-term | | $ | 2,810 |
| | $ | — |
|
| Mine reclamation liability | | 2,721 |
| | 624 |
|
| Other | | 229 |
| | 316 |
|
| | | $ | 5,760 |
| | $ | 940 |
|
Included in Other long-term liabilities isThe following table details the Mine reclamation liability, which represents an asset retirement obligation. Changes components of "Other"in the asset retirement obligation were as follows:Consolidated Statements of Operations:
| | | | | | | | | | | | | | | | |
| | Years Ended December 31, | | |
| (in thousands) | | 2021 | | 2020 | | |
| Interest income | | $ | 326 | | | $ | 127 | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Other | | 314 | | | 5 | | | |
| | $ | 640 | | | $ | 132 | | | |
Note 18 - Income Taxes
|
| | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2019 | | 2018 |
| Asset retirement obligation, beginning of year | | $ | 624 |
| | $ | — |
|
| Asset retirement obligation assumed in Carbon Solutions Acquisition | | 1,776 |
| | 626 |
|
| Accretion | | 205 |
|
| 2 |
|
| Liabilities settled | | (78 | ) |
| (4 | ) |
| Changes due to scope and timing of reclamation | | 194 |
|
| — |
|
| Asset retirement obligations, end of year | | $ | 2,721 |
|
| $ | 624 |
|
As partThe provision for income taxes consists of the Carbon Solutions Acquisition, the Company assumed an asset retirement obligation related to the Five Forks Mine. The Company recorded the liability at its estimated fair value and periodically adjusts to reflect changes in the estimated present value resulting from the passage of time and revisions to the estimates of either the timing or amount of the reclamation costs. Refer to Note 2 for details regarding adjustments made to the fair values of the asset retirement obligation from the preliminary purchase price allocation.following:
The Company’s mining activities are subject to various domestic laws and regulations governing the protection of the environment. The Company conducts its operations to protect public health and the environment and believes its operations are in compliance with applicable laws and regulations in all material respects. The Company has made, and expects to make in the future, expenditures to comply with such laws and regulations, but cannot predict the full amount of such future expenditures. Estimated future reclamation costs are based principally on current legal and regulatory requirements. | | | | | | | | | | | | | | | | |
| | | Years Ended December 31, | | |
| (in thousands, except for rate) | | 2021 | | 2020 | | |
| Current portion of income tax expense: | | | | | | |
| Federal | | $ | 2,741 | | | $ | 1,666 | | | |
| State and other | | 2,326 | | | 1,354 | | | |
| | | | | | |
| | 5,067 | | | 3,020 | | | |
| Deferred portion of income tax expense (benefit): | | | | | | |
| Federal | | 9,527 | | | 5,068 | | | |
| State and other | | 1,078 | | | (1,577) | | | |
| | | | | | |
| | 10,605 | | | 3,491 | | | |
| Total income tax expense | | $ | 15,672 | | | $ | 6,511 | | | |
| Effective tax rate | | 21 | % | | (47) | % | | |
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Supplemental Consolidated Statements of Operations Information
The following table details the components of Interest expense in the Consolidated Statements of Operations:
|
| | | | | | | | |
| | | Years Ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Interest on Senior Term Loan | | $ | 4,112 |
| | $ | 366 |
|
| Debt discount and debt issuance costs | | 1,678 |
| | 94 |
|
| 453A interest | | 1,039 |
| | 1,585 |
|
| Other | | 345 |
| | 106 |
|
| | | $ | 7,174 |
| | $ | 2,151 |
|
The following table details the components of Other in the Consolidated Statements of Operations: |
| | | | | | | | |
| | | Years Ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Interest income | | $ | 261 |
| | $ | 239 |
|
| Other | | 166 |
| | (19 | ) |
| | | $ | 427 |
| | $ | 220 |
|
Note 13 - Fair Value Measurements
Fair Value of Financial Instruments
The carrying amounts of financial instruments, including cash and cash equivalents, accounts receivable, accounts payable, deposits and accrued expenses, approximate fair value due to the short maturity of these instruments. Accordingly, these instruments are not presented in the table below. The following table provides the estimated fair values of the remaining financial instruments:
|
| | | | | | | | | | | | | | | | |
| | | As of December 31, 2019 | | As of December 31, 2018 |
| (in thousands) | | Carrying Value | | Fair Value | | Carrying Value | | Fair Value |
| Financial Instruments: | | | | | | | | |
| Highview Investment | | $ | 552 |
| | $ | 552 |
| | $ | 552 |
| | $ | 552 |
|
| Highview Obligation | | $ | 220 |
| | $ | 220 |
| | $ | 213 |
| | $ | 213 |
|
Concentration of credit risk
As of December 31, 2019, the Company’s financial instruments that are exposed to concentrations of credit risk consist primarily of cash and cash equivalents. The Company holds cash and cash equivalents at three financial institutions as of December 31, 2019. If those institutions were unable to perform their obligations, the Company would be at risk regarding the amount of its cash balance in excess of the federal deposit insurance corporation limits ($250 thousand).
Assets and Liabilities Measured at Fair Value on a Recurring Basis
As of December 31, 2019 and December 31, 2018, the Company had no material financial instruments carried and measured at fair value on a recurring basis.
Assets and Liabilities Measured at Fair Value on a Non-Recurring Basis
The Company completed the Carbon Solutions Acquisition, in which the fair value of the purchase consideration totaled $66.5 million. The Company's estimated fair values of the assets acquired and liabilities assumed are disclosed in Note 2. The fair value measurements represent Level 3 measurements as they were based on significant inputs not observable in the market.
The Company has applied the measurement alternative for investments without readily determinable fair values under ASC Topic 321 - Investments in Equity Securities ("ASC 321") for the Highview Investment. Fair value measurements, if any,
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
resulting from the Company's application of the guidance in ASC 321 represent either Level 2 or Level 3 measurements. There were no changes to the carrying value of the Highview Investment for the years ended December 31, 2019 and 2018 as there were no indicators of impairment or observable price changes for equity issued by Highview.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Note 14 - Income Taxes
The provision for income taxes consists of the following: |
| | | | | | | | |
| | | Years Ended December 31, |
| (in thousands, except for rate) | | 2019 | | 2018 |
| Current portion of income tax expense: | | | | |
| Federal | | $ | 2,133 |
| | $ | 882 |
|
| State and other | | 1,211 |
| | 4,308 |
|
| | | 3,344 |
| | 5,190 |
|
| Deferred portion of income tax expense (benefit): | | | | |
| Federal | | 10,491 |
| | 4,766 |
|
| State and other | | (1,836 | ) | | 467 |
|
| | 8,655 |
| | 5,233 |
|
| Total income tax expense | | $ | 11,999 |
| | $ | 10,423 |
|
| Effective tax rate | | 25 | % | | 23 | % |
Income tax expense differsdiffered from the amount that would be computed by applying the U.S. statutory federal income tax rate of 21% to income before income taxes for the years ended December 31, 20192021 and 2018 to income before income taxes2020 as a result of the following:follows: | | | | | Years Ended December 31, | | | Years Ended December 31, | |
| (in thousands) | | 2019 | | 2018 | (in thousands) | | 2021 | | | 2020 | |
| | Federal statutory rate | | $ | 10,027 |
| | $ | 9,634 |
| Federal statutory rate | | $ | 15,975 | | | | $ | (2,896) | | |
| State income taxes, net of federal benefit | | 1,597 |
| | 3,625 |
| State income taxes, net of federal benefit | | 2,283 | | | | (410) | | |
| | Permanent differences | | 286 |
| | 130 |
| Permanent differences | | (680) | | | | 326 | | |
| Tax credits | | (338 | ) | | (7,031 | ) | Tax credits | | (443) | | | | (417) | | |
| Valuation allowances | | (288 | ) | | 4,462 |
| Valuation allowances | | (1,290) | | | | 9,148 | | |
| Changes in tax rates | | 229 |
| | (464 | ) | Changes in tax rates | | (33) | | | | (97) | | |
| Stock-based compensation | | 112 |
| | (216 | ) | Stock-based compensation | | 86 | | | | 285 | | |
| UTP liability | | 236 |
| | — |
| |
| Return to provision and other true-ups | | Return to provision and other true-ups | | (40) | | | | 572 | | |
| Other | | 138 |
| | 283 |
| Other | | (186) | | | | — | | |
| Expense for the provision for income taxes | | $ | 11,999 |
| | $ | 10,423 |
| |
| Income tax expense | | Income tax expense | | $ | 15,672 | | | | $ | 6,511 | | |
Deferred income taxes are provided for the effects of temporary differences between the tax basis of an asset or liability and their reported amounts in the accompanying Consolidated Balance Sheets. These temporary differences result in taxable or deductible amounts in future years. Details of the Company’s deferred tax assets and liabilities are summarized as follows:
| | | | | | | | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2021 | | 2020 |
| Deferred tax assets | | | | |
| Tax credits | | $ | 86,097 | | | $ | 93,874 | |
| Equity method investments | | 1,584 | | | 5,149 | |
| Net operating loss carryforwards | | 2,388 | | | 2,906 | |
| Intangible assets | | 5,126 | | | 2,765 | |
| ARO, net of reimbursements | | — | | | 2,167 | |
| Employee related liabilities | | 1,971 | | | 827 | |
| Other investments | | 556 | | | 548 | |
| Operating lease obligations | | 1,585 | | | 508 | |
| | | | |
| Other | | 138 | | | 69 | |
| Total deferred tax assets | | 99,445 | | | 108,813 | |
| Less valuation allowance | | (87,468) | | | (88,758) | |
| Deferred tax assets | | 11,977 | | | 20,055 | |
| Less: Deferred tax liabilities | | | | |
| Property and equipment and other | | (8,203) | | | (7,039) | |
| | | | |
| Upfront customer consideration | | (1,747) | | | (1,847) | |
| Right of use operating lease assets | | (1,497) | | | (270) | |
| Inventory | | (197) | | | (295) | |
| ARO, net of reimbursements | | (333) | | | — | |
| | | | |
| Total deferred tax liabilities | | (11,977) | | | (9,451) | |
| Net deferred tax assets | | $ | — | | | $ | 10,604 | |
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
|
| | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2019 | | 2018 |
| Deferred tax assets | | | | |
| Tax credits | | $ | 98,541 |
| | $ | 104,553 |
|
| Operating lease obligations | | 1,307 |
| | — |
|
| Employee related liabilities | | 1,065 |
| | 1,515 |
|
| Intangible assets | | 1,574 |
| | 1,623 |
|
| Equity method investments | | — |
| | 9,588 |
|
| Net operating loss carryforwards | | 2,956 |
| | 2,479 |
|
| Other investments | | 555 |
| | 583 |
|
| Reserves | | 587 |
| | 45 |
|
| Other | | 244 |
| | 335 |
|
| Total deferred tax assets | | 106,829 |
| | 120,721 |
|
| Less valuation allowance | | (79,610 | ) | | (79,898 | ) |
| Deferred tax assets | | 27,219 |
| | 40,823 |
|
| Less: Deferred tax liabilities | | | | |
| Property and equipment and other | | (11,087 | ) | | (8,284 | ) |
| Equity method investments | | (736 | ) | | — |
|
| Right of use operating lease assets | | (1,301 | ) | | — |
|
| Total deferred tax liabilities | | (13,124 | ) | | (8,284 | ) |
| Net deferred tax assets | | $ | 14,095 |
| | $ | 32,539 |
|
Accounting for income taxes requires that companies assess whether a valuation allowance should be recorded against theira deferred tax asset based on an assessment of the amount of the deferred tax asset that is “more likely than not” to be realized. Valuation allowances are established, when necessary, to reduce deferred tax assets to the amount that is more likely than not to be realized.
The Company assesses thea valuation allowance recorded against deferred tax assets at each reporting date. The determination of whether a valuation allowance for deferred tax assets is appropriate requires the evaluation of positive and negative evidence that can be objectively verified. Consideration must be given to all sources of taxable income available to realize a deferred tax asset, including, as applicable, the future reversal of existing temporary differences, future taxable income forecasts exclusive of the reversal of temporary differences and carryforwards, taxable income in carryback years and tax planning strategies. In estimating taxes, the Company assesses the relative merits and risks of the appropriate tax treatment of transactions taking into account statutory, judicial and regulatory guidance.
As of December 31, 2019,2021, the Company concluded it is more likely than not the Company will not generate sufficient taxable income within the applicable net operating loss and tax credit carry-forward periods to realize $14.1 millionany of its net deferred tax assets, which resulted inassets. For the year ended December 31, 2021, the Company reduced a decrease in the valuation allowance from December 31, 20182020 by $1.3 million, but as of $0.3 million.December 31, 2021 has a valuation allowance equal to 100% of its net deferred tax assets. In reaching this conclusion, the Company primarily considered: (1) the future reversal of existing temporary differences; and (2)considered forecasts of continued future taxable income.losses.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The following table presents the approximate amount of state net operating loss carryforwards and federal tax credit carryforwards available to reduce future taxable income, along with the respective range of years that the net operating loss and tax credit carryforwards would expire if not utilized: | | | | | As of December 31, | | As of December 31, |
| (in thousands) | | 2019 | | Beginning expiration year | | Ending expiration year | (in thousands) | | 2021 | | Beginning expiration year | | Ending expiration year |
| | State and other operating loss carryforwards | | State and other operating loss carryforwards | | $ | 2,388 | | | 2026 | | 2036 |
| Federal tax credit carryforwards | | $ | 98,541 |
| | 2032 | | 2039 | Federal tax credit carryforwards | | $ | 86,097 | | | 2032 | | 2040 |
| State and other operating loss carryforwards | | $ | 2,956 |
| | 2021 | | 2039 | |
The following table sets forth a reconciliation of the beginning and ending unrecognized tax benefitspositions on a gross basis for the years ended December 31, 20192021 and 2018:2020: | | | | | Years Ended December 31, | | | Years Ended December 31, | |
| (in thousands) | | 2019 | | 2018 | (in thousands) | | 2021 | | 2020 | |
| Balance as of January 1 | | $ | 54 |
| | $ | 54 |
| Balance as of January 1 | | $ | 946 | | | $ | 946 | | |
| Increases for tax positions of prior years | | 892 |
| | — |
| |
| | Lapse of applicable statute of limitations | | Lapse of applicable statute of limitations | | (892) | | | — | | |
| Balance as of December 31 | | $ | 946 |
| | $ | 54 |
| Balance as of December 31 | | $ | 54 | | | $ | 946 | | |
Included inFor the balance of unrecognized tax benefits as ofyears ended December 31, 2019 are $0.7 million of tax benefits that, if utilized, would result in adjustments to deferred taxes.
The2021 and 2020, the Company did not record any adjustments or recognize interest expense for uncertain tax positions for the years ended December 31, 2019 and 2018.positions. Interest and penalties related to uncertain tax positions are accrued and included in the Interest expense "Interest expense"line item in the Consolidated Statements of Operations. Additionally, the Company recognizes interest expense related to the federal tax treatment of RC facilities at Tinuum Group in the Interest"Interest expense line"line item in the Consolidated Statements of Operations. Additional information related to the components of Interest expense "Interest expense"is included in Note 12.17.
The Company files income tax returns in the U.S. and various states. The Company is no longer subject to U.S. federal examinations by tax authorities for years before 2015.2018. The Company is generally no longer subject to state examinations by tax authorities for years before 2013.2014.
Note 19 - Business Segment Information
Operating segments are defined as components of an enterprise about which separate financial information is available that is evaluated regularly by a company's chief operating decision maker ("CODM"), or a decision making group, in deciding how to allocate resources and in assessing financial performance. As of December 31, 2021, the Company's CODM was the Company's CEO. The Company's operating and reportable segments are organized by products and services provided.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
As of December 31, 2021, the Company has 2 reportable segments: (1) Refined Coal ("RC"); and (2) Advanced Purification Technologies ("APT").
The business segment measurements provided to and evaluated by the CODM are computed in accordance with the principles listed below:
•The accounting policies of the operating segments are the same as those described in the summary of significant accounting policies except as described below.
•Segment revenues include equity method earnings and losses from the Company's equity method investments.
•Segment operating income (loss) includes segment revenues and allocation of certain corporate general and administrative expenses, which includes Payroll and benefits, General and administrative, and Depreciation, amortization, depletion and accretion.
•RC segment operating income includes interest expense directly attributable to the RC segment.
As of December 31, 2021 and 2020, substantially all of the Company's material assets were located in the U.S. and the majority of its customers are U.S. companies. The following table presents the Company's operating segment results for the years ended December 31, 2021 and 2020:
| | | | | | | | | | | | | | | | |
| | | Years Ended December 31, | | |
| (in thousands) | | 2021 | | 2020 | | |
| Revenues: | | | | | | |
| Refined Coal: | | | | | | |
| Earnings in equity method investments | | $ | 68,726 | | | $ | 30,978 | | | |
| | | | | | |
| License royalties, related party | | 14,368 | | | 13,440 | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | 83,094 | | | 44,418 | | | |
| Advanced Purification Technologies: | | | | | | |
Consumables (1) | | 85,882 | | | 53,908 | | | |
| Other | | 44 | | | 15 | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | 85,926 | | | 53,923 | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Total segment reporting revenues | | 169,020 | | | 98,341 | | | |
| | | | | | |
| Adjustments to reconcile to reported revenues: | | | | | | |
| | | | | | |
| Earnings in equity method investments | | (68,726) | | | (30,978) | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Total reported revenues | | $ | 100,294 | | | $ | 67,363 | | | |
| | | | | | |
| Segment operating income (loss) | | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Refined Coal | | $ | 82,634 | | | $ | 42,689 | | | |
| | | | | | |
| | | | | | |
Advanced Purification Technologies (2) | | 5,649 | | | (39,958) | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Total segment operating income | | $ | 88,283 | | | $ | 2,731 | | | |
(1) Revenues - Consumables for the year ended December 31, 2020 have been restated. See restatement discussion in Note 2.
(2) Included in APT segment operating income (loss) for the years ended December 31, 2021 and 2020 was $7.4 million and $7.9 million, respectively, of depreciation, amortization, depletion and accretion expenses on mine and plant related long-lived assets and liabilities. Further included in the APT segment operating income for the year ended December 31, 2021 was $2.7 million related to a gain on change in estimate, asset retirement obligation. Additionally, included in APT segment operating loss for the year ended December 31, 2020 was an impairment charge of $26.1 million and the Gain on Settlement of $1.1 million.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
A reconciliation of reportable segment operating income to consolidated income (loss) before income taxes is as follows:
| | | | | | | | | | | | | | | | |
| | | Years Ended December 31, | | |
| (in thousands) | | 2021 | | 2020 | | |
| | | | | | |
| Total reported segment operating income | | $ | 88,283 | | | $ | 2,731 | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Adjustments to reconcile to income (loss) before income tax expense attributable to the Company: | | | | | | |
| Corporate payroll and benefits | | (2,478) | | | (2,866) | | | |
| | | | | | |
| Corporate legal and professional fees | | (6,014) | | | (4,954) | | | |
| Corporate general and administrative | | (3,358) | | | (5,096) | | | |
| Corporate depreciation and amortization | | (505) | | | (551) | | | |
| | | | | | |
| Corporate interest expense, net | | (854) | | | (3,060) | | | |
| | | | | | |
| | | | | | |
| Other income, net | | 999 | | | 5 | | | |
| | | | | | |
| Income (loss) before income tax expense | | $ | 76,073 | | | $ | (13,791) | | | |
Corporate general and administrative expenses include certain costs that benefit the business as a whole but are not directly related to one of the Company's segments. Such costs include, but are not limited to, accounting and human resources staff, information systems costs, legal fees, facility costs, audit fees and corporate governance expenses.
A reconciliation of reportable segment assets to the Company's consolidated assets is as follows:
| | | | | | | | | | | | | | |
| | As of December 31, |
| (in thousands) | | 2021 | | 2020 |
| Assets: | | | | |
Refined Coal (1) | | $ | 4,884 | | | $ | 11,516 | |
Advanced Purification Technologies (2) | | 83,516 | | | 80,877 | |
| Total segment assets | | 88,400 | | | 92,393 | |
| | | | |
Corporate (3) | | 97,036 | | | 54,278 | |
| Consolidated | | $ | 185,436 | | | $ | 146,671 | |
(1) Includes $2.4 million and $7.7 million of investments in equity method investees as of December 31, 2021 and 2020, respectively.
(2) Includes $36.7 million and $34.6 million of long-lived assets, net. Expenditures for additions to long-lived assets were $7.4 million and $7.3 million, respectively, for the years ended December 31, 2021 and 2020.
(3) Includes the Company's net deferred tax assets of zero and $10.6 million as of December 31, 2021 and 2020, respectively.
Note 1520 - Business Segment InformationFair Value Measurements
Operating segmentsFair Value of Financial Instruments
The carrying amounts of financial instruments, including cash and cash equivalents, accounts receivable, accounts payable, deposits and accrued expenses, approximate their fair values due to the short maturity of these instruments. The carrying amounts of the Senior Term Loan and other obligations, including finance leases, approximate their fair values based on credit terms and market interest rates currently available for similar instruments. Accordingly, these instruments are defined as components of an enterprise about which separate financial information is available that is evaluated regularly by a company's chief operating decision maker ("CODM"), or a decision making group, in deciding how to allocate resources and in assessing financial performance. As of December 31, 2019, the Company's CODM was the Company's CEO. The Company's operating and reportable segments are organized by products and services provided.
As of December 31, 2019, the Company has two reportable segments: (1) Refined Coal ("RC"); and (2) Power Generation and Industrials ("PGI"). The majority of Carbon Solutions operations has been includednot presented in the PGI segment; whereas a portion has been included in All Other and Corporate.
table below. The business segment measurements provided to and evaluated byfollowing table provides the CODM are computed in accordance with the principles listed below:
The accounting policiesestimated fair values of the operating segments are the same as those described in the summary of significant accounting policies except as described below.remaining financial instruments:
Segment revenues include equity method earnings and losses from the Company's equity method investments.
Segment operating income (loss) includes segment revenues and allocation of certain "Corporate general and administrative expenses," which includes Payroll and benefits, Legal and professional fees, and General and administrative.
RC segment operating income includes interest expense directly attributable to the RC segment. | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | As of December 31, 2021 | | As of December 31, 2020 |
| (in thousands) | | Carrying Value | | Fair Value | | Carrying Value | | Fair Value |
| Financial Instruments: | | | | | | | | |
| | | | | | | | |
| | | | | | | | |
| | | | | | | | |
| | | | | | | | |
| Highview Investment | | $ | 552 | | | $ | 552 | | | $ | 552 | | | $ | 552 | |
| | | | | | | | |
| | | | | | | | |
| | | | | | | | |
| | | | | | | | |
| | | | | | | | |
| | | | | | | | |
| | | | | | | | |
| Highview Obligation | | $ | 227 | | | $ | 227 | | | $ | 228 | | | $ | 228 | |
| | | | | | | | |
| | | | | | | | |
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Concentration of credit risk
As of December 31, 20192021, the Company’s financial instruments that are exposed to concentrations of credit risk consist primarily of cash and 2018, substantially all of the Company's material assets are located in the U.S.cash equivalents. The Company holds cash and all significant customers are U.S. companies. The following table presents the Company's operating segment results for the years ended December 31, 2019 and 2018: |
| | | | | | | | |
| | | Years Ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Revenues: | | | | |
| Refined Coal: | | | | |
| Earnings in equity method investments | | $ | 69,176 |
| | $ | 54,208 |
|
| License royalties, related party | | 16,899 |
| | 15,140 |
|
| | | 86,075 |
| | 69,348 |
|
| Power Generation and Industrials: | | | | |
| Consumables | | 50,458 |
| | 8,628 |
|
| Other | | — |
| | 72 |
|
| | | 50,458 |
| | 8,700 |
|
| Total segment reporting revenues | | 136,533 |
| | 78,048 |
|
| | | | | |
| Adjustments to reconcile to reported revenues: | | | | |
| Earnings in equity method investments | | (69,176 | ) | | (54,208 | ) |
| Corporate and other | | 2,729 |
| | 105 |
|
| Total reported revenues | | $ | 70,086 |
| | $ | 23,945 |
|
| | | | | |
| Segment operating income (loss) | | | | |
| Refined Coal (1) | | $ | 83,471 |
| | $ | 64,854 |
|
| Power Generation and Industrials (2) | | (11,606 | ) | | (2,621 | ) |
| Total segment operating income | | $ | 71,865 |
| | $ | 62,233 |
|
(1) Included in the RC segment operating income for the years ended December 31, 2019 and 2018 is 453A interest expense of $1.0 million and $1.6 million, respectively. Also included in the RC segment operating income for the year ended December 31, 2018 was $0.4 million of severance expense.
(2) Included in the PGI segment operating income for the year ended December 31, 2019 and 2018 was approximately $4.7 million and $1.0 million, respectively, of amortization expense related to the fair value of inventory. Also included in the PGI segment operating income for the year ended December 31, 2019 and 2018 was $6.7 million and $0.5 million, respectively, of depreciation, amortization, and depletion on mine and plant related long-lived assets.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
A reconciliation of reportable segment operating income to the Company's consolidated net income is as follows:
|
| | | | | | | | |
| | | Years Ended December 31, |
| (in thousands) | | 2019 | | 2018 |
| Total reported segment operating income | | $ | 71,865 |
| | $ | 62,233 |
|
| Other operating (loss) income | | (1,994 | ) | | 2 |
|
| | 69,871 |
| | 62,235 |
|
| | | | | |
| Adjustments to reconcile to income before income tax expense attributable to the Company: | | | | |
| Corporate payroll and benefits | | (2,592 | ) | | (4,970 | ) |
| Corporate legal and professional fees | | (7,485 | ) | | (7,700 | ) |
| Corporate general and administrative | | (6,836 | ) | | (3,305 | ) |
| Corporate depreciation and amortization | | (82 | ) | | (134 | ) |
| Corporate interest expense, net | | (5,767 | ) | | (521 | ) |
| Other income, net | | 427 |
| | 272 |
|
| Income before income tax expense | | $ | 47,536 |
| | $ | 45,877 |
|
Corporate general and administrative expenses include certain costs that benefit the business as a whole but are not directly related to one of the Company's segments. Such costs include, but are not limited to, accounting and human resources staff, information systems costs, legal fees, facility costs, audit fees and corporate governance expenses.
A reconciliation of reportable segment assets to the Company's consolidated assets is as follows: |
| | | | | | | | |
| | | As of December 31, |
| (in thousands) | | 2019 | | 2018 |
| Assets: | | | | |
Refined Coal(1) | | $ | 43,953 |
| | $ | 11,468 |
|
| Power Generation and Industrials | | 80,912 |
| | 85,786 |
|
| Total segment assets | | 124,865 |
| | 97,254 |
|
All Other and Corporate(2) | | 48,934 |
| | 62,410 |
|
| Consolidated | | $ | 173,799 |
| | $ | 159,664 |
|
(1) Includes $39.2 million and $6.6 million of investments in equity method investeescash equivalents at three financial institutions as of December 31, 20192021. If those institutions were unable to perform their obligations, the Company would be at risk regarding the amount of its cash balance in excess of the federal deposit insurance corporation limits ($250 thousand).
Assets and 2018, respectively.Liabilities Measured at Fair Value on a Recurring Basis
(2) Includes the Company's net deferred tax assets of $14.1 million and $32.5 million asAs of December 31, 20192021 and 2018, respectively.December 31, 2020, the Company had no material financial instruments carried and measured at fair value on a recurring basis.
Assets and Liabilities Measured at Fair Value on a Non-Recurring Basis As disclosed in Note 4, the Company completed the asset acquisition of Marshall Mine, LLC. The estimated fair values of the assets acquired and liabilities assumed were determined based on Level 3 inputs.
As disclosed in Note 6, the Company recorded an impairment charge related to the Asset Group based on a valuation model that included an expected future discounted cash flow model using Level 3 inputs.
As noted in Note 17, the Company accounts for the Highview Investment as an investment recorded at cost, less impairment, plus or minus observable changes in price for identical or similar investments of the same issuer. Fair value measurements, if any, represent either Level 2 or Level 3 measurements.
Note 1621 - Major Customers
Revenues from external customers who represent 10% or more of the Company’s revenues for the years ended December 31, 20192021 and 20182020 were as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | Years ended December 31, | | |
| Customer | | Revenue Type | | Segment(s) | | 2021 | | 2020 | | |
| A | | License royalties, related party | | RC | | 14% | | 20% | | |
| B | | Consumables (1) | | APT | | 14% | | 6% | | |
| C | | Consumables (1) | | APT | | 10% | | 11% | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
(1) Consumables revenues for the year ended December 31, 2020 have been restated. See restatement discussion in Note 2.
|
| | | | | | | | |
| | | | | | Years ended December 31, |
| Customer | | Revenue Type | | Segment(s) | | 2019 | | 2018 |
| A | | License royalties, related party | | RC | | 24% | | 63% |
| B | | Consumables | | PGI | | 10% | | —% |
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Note 1722 - Related Party Transactions
Accounts Receivable
The following table shows the Company's receivable balance associated with related parties as of December 31, 20192021 and 2018:2020: | | | | | As of December 31, | | | As of December 31, |
| (in thousands) | | 2019 | | 2018 | (in thousands) | | 2021 | | 2020 |
| Receivable from related party - Tinuum Group | | $ | 4,246 |
| | $ | 4,284 |
| Receivable from related party - Tinuum Group | | $ | 2,481 | | | $ | 3,453 | |
|
Revenues
The following table shows the income recognized with related parties during the years ended December 31, 20192021 and 2018:2020: | | | | | Years Ended December 31, | | | Years Ended December 31, | |
| (in thousands) | | 2019 | | 2018 | (in thousands) | | 2021 | | 2020 | |
| License royalties, related party - Tinuum Group | | $ | 16,899 |
| | $ | 15,140 |
| License royalties, related party - Tinuum Group | | $ | 14,368 | | | $ | 13,440 | | |
|
The above Tinuum Group royalties are included in the License"License royalties, related partyparty" line in the Consolidated Statements of Operations.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Note 1823 - Defined Contribution Savings Plans
The Company sponsors twoa qualified defined contribution savings plans (collectively theplan (the "401(k) Plans"Plan") that allowallows participation by eligible employees who may defer a portion of their gross pay. The Company makes contributions to the 401(k) PlansPlan based on percentages of an employee's eligible compensation as specified in the 401(k) Plans,Plan, and such employer contributions are in the form of cash. As of January 1, 2020, the Company merged the 401(k) Plans.
The following table presents the amount of the Company's contributions made to the 401(k) Plan:Plans: | | | | | Years Ended December 31, | | Years Ended December 31, |
| (in thousands) | | 2019 | | 2018 | (in thousands) | | 2021 | | 2020 | |
| 401(k) Plans employer contributions | | $ | 553 |
| | $ | 139 |
| 401(k) Plans employer contributions | | $ | 479 | | | $ | 484 | | |
Due to the increase in employees resulting from the Carbon Solutions Acquisition, there was an increase in employer contributions made to the 401(k) Plan for the year ended December 31, 2019.
Note 19 - Restructuring
In December 2018, the Company recorded restructuring charges in connection with the departures of certain executives of Carbon Solutions in conjunction with the Carbon Solutions Acquisition. As part of the Carbon Solutions Acquisition, the Company also assumed a salary severance liability for an additional executive of Carbon Solutions in the amount of $0.6 million. Additionally, the Company recorded restructuring charges in 2018 in connection with a reduction in force that commenced in May 2018 as part of the Company's further alignment of the business with strategic objectives, which included the departure of certain executive officers. These charges related to cash severance arrangements with departing employees and executives, as well as stock-based compensation charges related to the acceleration of vesting of certain stock awards.
During the year ended December 31, 2019, the Company did not record material restructuring charges.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
A summary of the net pretax charges incurred by segment is as follows:
|
| | | | | | | | | | | | | | | | | | | |
| | | | | Pretax Charge |
| (in thousands, except employee data) | | Approximate Number of Employees | | Refined Coal | | PGI | | All Other and Corporate | | Total |
| Year ended December 31, 2018 | | | | | | | | | | |
| Restructuring charges | | 16 |
| | $ | 448 |
| | $ | 996 |
| | $ | 1,685 |
| | $ | 3,129 |
|
| Changes in estimates | | | | — |
| | — |
| | — |
| | — |
|
| Total pretax charge, net of reversals | | | | $ | 448 |
| | $ | 996 |
| | $ | 1,685 |
| | $ | 3,129 |
|
The following table summarizes the Company's utilization of restructuring accruals for the years ended December 31, 2019 and 2018:
|
| | | | |
| (in thousands) | | Employee Severance |
| Beginning accrual as of January 1, 2018 | | $ | — |
|
| Expense provision | | 3,129 |
|
| Cash payments and other | | (1,491 | ) |
| Change in estimates | | — |
|
| Severance liability acquired | | 570 |
|
| Accrual as of December 31, 2018 | | 2,208 |
|
| Expense provision | | 172 |
|
| Cash payments and other | | (2,051 | ) |
| Change in estimates | | (75 | ) |
| Accrual as of December 31, 2019 | | $ | 254 |
|
For the years ended December 31, 2019 and 2018, included in the Expense provision and Cash payments and other line items in the above table is stock-based compensation of zero and $0.8 million, respectively, resulting from the accelerated vesting of modified equity-based compensation awards for certain terminated employees.
Restructuring accruals related to personnel are included in the Accrued payroll and related liabilities line item in the Consolidated Balance Sheet. Restructuring expenses related to personnel are included in the Payroll and benefits and Research and development, net line items in the Consolidated Statements of Operations. Restructuring accruals related to facilities are included in the Other current liabilities line item in the Consolidated Balance Sheet. Restructuring expenses related to facilities are included in the Rent and occupancy line item in the Consolidated Statements of Operations.
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
Note 2024 - Quarterly Financial Results (unaudited)
Summarized quarterly results for the two years ended December 31, 20192021 and December 31, 20182020 are as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | For the Quarter Ended |
| (in thousands, except per share data) | | December 31, 2021 | | September 30, 2021 | | June 30, 2021 | | March 31, 2021 |
| Revenues | | $ | 25,764 | | | $ | 30,858 | | | $ | 21,065 | | | $ | 22,607 | |
| Cost of revenues | | 16,904 | | | 19,956 | | | 14,732 | | | 13,984 | |
| Other operating expenses | | 8,076 | | (1) | 7,603 | | | 5,894 | | | 8,293 | |
| Operating income | | 784 | | | 3,299 | | | 439 | | | 330 | |
| Earnings from equity method investments | | 6,782 | | | 22,195 | | | 21,437 | | | 18,312 | |
| | | | | | | | |
| Other (expenses) income, net | | (86) | | | 3,340 | | | (343) | | | (416) | |
| Income before income tax expense | | 7,480 | | | 28,834 | | | 21,533 | | | 18,226 | |
| Income tax expense | | 1,659 | | | 4,581 | | | 4,943 | | | 4,489 | |
| Net income | | $ | 5,821 | | | $ | 24,253 | | | $ | 16,590 | | | $ | 13,737 | |
| Earnings per common share – basic | | $ | 0.32 | | | $ | 1.33 | | | $ | 0.91 | | | $ | 0.76 | |
| Earnings per common share – diluted | | $ | 0.31 | | | $ | 1.31 | | | $ | 0.90 | | | $ | 0.75 | |
| Weighted-average number of common shares outstanding | | | | | | | | |
| Basic | | 18,302 | | | 18,292 | | | 18,271 | | | 18,166 | |
| Diluted | | 18,545 | | | 18,489 | | | 18,398 | | | 18,274 | |
|
| | | | | | | | | | | | | | | | |
| | | For the Quarter Ended |
| (in thousands, except per share data) | | December 31, 2019 | | September 30, 2019 | | June 30, 2019 | | March 31, 2019 |
| Revenues | | $ | 16,047 |
| | $ | 19,133 |
| | $ | 15,577 |
| | $ | 19,329 |
|
| Cost of revenues, exclusive of operating expenses shown below | | 11,104 |
| | 11,939 |
| | 12,292 |
| | 14,108 |
|
| Other operating expenses | | 9,630 |
|
| 9,585 |
| | 7,545 |
| | 8,776 |
|
| Operating loss | | (4,687 | ) | | (2,391 | ) | | (4,260 | ) | | (3,555 | ) |
| Earnings from equity method investments | | 12,125 |
| | 14,426 |
| | 20,935 |
| | 21,690 |
|
| Other expenses, net | | (1,269 | ) | | (1,517 | ) | | (1,927 | ) | | (2,034 | ) |
| Income before income tax expense | | 6,169 |
| | 10,518 |
| | 14,748 |
| | 16,101 |
|
| Income tax (benefit) expense | | (2,929 | ) | (1) | 6,595 |
| | 6,634 |
| | 1,699 |
|
| Net income | | $ | 9,098 |
| | $ | 3,923 |
| | $ | 8,114 |
| | $ | 14,402 |
|
| Earnings per common share – basic | | $ | 0.50 |
| | $ | 0.22 |
| | $ | 0.45 |
| | $ | 0.79 |
|
| Earnings per common share – diluted | | $ | 0.50 |
| | $ | 0.21 |
| | $ | 0.44 |
| | $ | 0.78 |
|
| Weighted-average number of common shares outstanding | | | | | | | | |
| Basic | | 18,066 |
| | 18,112 |
| | 18,172 |
| | 18,268 |
|
| Diluted | | 18,275 |
| | 18,339 |
| | 18,377 |
| | 18,433 |
|
|
| | | | | | | | | | | | | | | | |
| | | For the Quarter Ended |
| (in thousands, except per share data) | | December 31, 2018 | | September 30, 2018 | | June 30, 2018 | | March 31, 2018 |
| Revenues | | $ | 10,626 |
| (2) | $ | 5,147 |
| | $ | 4,273 |
| | $ | 3,899 |
|
| Cost of revenues, exclusive of operating expenses shown below | | 4,032 |
| (2) | 954 |
| | 704 |
| | 563 |
|
| Other operating expenses | | 9,745 |
| (2), (3) | 4,161 |
| | 5,138 |
| | 5,048 |
|
| Operating (loss) income | | (3,151 | ) | | 32 |
| | (1,569 | ) | | (1,712 | ) |
| Earnings from equity method investments | | 16,351 |
| | 9,715 |
| | 15,889 |
| | 12,253 |
|
| Other expenses, net | | (930 | ) | | (313 | ) | | (378 | ) | | (310 | ) |
| Income before income tax expense | | 12,270 |
| (2), (3) | 9,434 |
| | 13,942 |
| | 10,231 |
|
| Income tax expense (benefit) | | 5,272 |
| (4) | 3,931 |
| | (1,349 | ) | | 2,569 |
|
| Net income | | $ | 6,998 |
| | $ | 5,503 |
| | $ | 15,291 |
| | $ | 7,662 |
|
| Earnings per common share – basic | | $ | 0.36 |
| | $ | 0.28 |
| | $ | 0.76 |
| | $ | 0.37 |
|
| Earnings per common share – diluted | | $ | 0.36 |
| | $ | 0.28 |
| | $ | 0.75 |
| | $ | 0.37 |
|
| Weighted-average number of common shares outstanding | | | | | | | | |
| Basic | | 19,339 |
| | 19,726 |
| | 20,062 |
| | 20,502 |
|
| Diluted | | 19,439 |
| | 19,876 |
| | 20,195 |
| | 20,584 |
|
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | For the Quarter Ended |
| (in thousands, except per share data) | | December 31, 2020 | | September 30, 2020 | | June 30, 2020 | | March 31, 2020 |
| Revenues | | $ | 19,743 | | | $ | 21,270 | | | $ | 12,726 | | | $ | 13,624 | |
| Cost of revenues | | 12,076 | | | 16,812 | | | 8,659 | | | 12,852 | |
| Other operating expenses | | 6,117 | | (1) | 7,283 | | | 35,132 | | | 9,413 | |
| Operating income (loss) | | 1,550 | | | (2,825) | | | (31,065) | | | (8,641) | |
| Earnings from equity method investments | | 5,019 | | | 9,518 | | | 8,168 | | | 8,273 | |
| | | | | | | | |
| Other expenses, net | | (943) | | | (864) | | | (814) | | | (1,167) | |
| Income (loss) before income tax expense | | 5,626 | | | 5,829 | | | (23,711) | | | (1,535) | |
| Income tax expense | | 5,196 | | (2) | 854 | | | 103 | | | 358 | |
| Net income (loss) | | $ | 430 | | | $ | 4,975 | | | $ | (23,814) | | | $ | (1,893) | |
| Earnings (loss) per common share – basic | | $ | 0.02 | | | $ | 0.27 | | | $ | (1.32) | | | $ | (0.11) | |
| Earnings (loss) per common share – diluted | | $ | 0.02 | | | $ | 0.27 | | | $ | (1.32) | | | $ | (0.11) | |
| Weighted-average number of common shares outstanding | | | | | | | | |
| Basic | | 18,109 | | | 18,093 | | | 18,014 | | | 17,932 | |
| Diluted | | 18,167 | | | 18,103 | | | 18,014 | | | 17,932 | |
(1) During the fourth quarter of 2019,2020, the Company recorded income tax benefita gain of $2.91.1 million primarily due to a decrease in current income tax expense compared to current income tax recorded form the nine months ended September 30, 2019. This decrease was primarily due to a decrease in income before income tax expense for the year ended December 31, 2019 comparedrelated to the estimated annual income before income tax expense that was usedSettlement reached with the Former Customer as further described in computing current income tax expense for the nine months ended September 30, 2019.Note 17.
(2) During the fourth quarter of 2018, the Company completed the Carbon Solutions Acquisition and the operating results for the fourth quarter of 2018 include the operations of Carbon Solutions for the period from December 7 to December 31, 2018. For this period, Carbon Solutions contributed $5.6 million to Revenues, $3.4 million to Cost of Revenue, $2.6 million to Other Operating Expenses and $0.4 million to Loss before income tax expense.
(3) During the fourth quarter of 2018, the Company incurred $3.4 million in transaction costs and $1.1 million in severance charges for executives related to the Carbon Solutions Acquisition that were recorded in Other Operating Expenses.
(4) During the fourth quarter of 2018,2020, the Company recorded income tax expense of $5.3$5.2 million primarily due to an increase of $4.5 million toin the valuation allowance on itsas of December 31, 2020 related to the Company's deferred tax assets.
As discussed in Note 2, the Company concluded that its historical presentation of shipping and handling costs billed to customers as a component of cost of revenues rather than as a component of revenues was incorrect and that the Company's presentation of both the "Revenues - Consumables" and "Consumables cost of revenues, exclusive of depreciation and amortization" line items for the year ended December 31, 2020 should be restated. The impact of this error resulted in an understatement of both the "Revenues - Consumables" and "Consumables cost of revenues, exclusive of depreciation and amortization" line items in the Consolidated Statements of Operations for each of the quarters included in 2020 and for the quarters ended March 31, 2021, June 30, 2021 and September 30, 2021 and is shown below for those periods. The amounts reported above for the three months ended March 31, 2021 and 2020, the three months ended June 30, 2021 and 2020, the three months ended September 30, 2021 and 2020 and the three months ended December 31, 2020 have been restated for this error. There was no impact to operating income (loss), income (loss) before income taxes, net income (loss) or earnings (loss) to any of the 2021 or 2020 periods.
The adjustments for restatement of the quarters ended September 30, 2021, June 30, 2021, and March 31, 2021 are as follows: | | | | | | | | | | | | | | | | | | | | | | |
| | | | For the Quarter Ended |
| | | | September 30, 2021 (Restated) | | June 30, 2021 (Restated) | | March 31, 2021 (Restated) |
| | | | Increase / (Decrease) | | Increase / (Decrease) | | Increase / (Decrease) |
| Revenues | | | | 2,004 | | | 1,432 | | | 1,510 | |
| Cost of revenues | | | | 2,004 | | | 1,432 | | | 1,510 | |
| Operating income | | | | — | | | — | | | — | |
Advanced Emissions Solutions, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
The adjustments for restatement of the quarters ended December 31, 2020, September 30, 2020, June 30, 2020, and March 31, 2020 are as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | For the Quarter Ended |
| | December 31, 2020 (Restated) | | September 30, 2020 (Restated) | | June 30, 2020 (Restated) | | March 31, 2020 (Restated) |
| | Increase / (Decrease) | | Increase / (Decrease) | | Increase / (Decrease) | | Increase / (Decrease) |
| Revenues | | 1,383 | | | 1,799 | | | 1,243 | | | 1,361 | |
| Cost of revenues | | 1,383 | | | 1,799 | | | 1,243 | | | 1,361 | |
| Operating income | | — | | | — | | | — | | | — | |
Note 2125 - Subsequent Events
Unless disclosed elsewhere in the notes to the Consolidated Financial Statements, the following areis the significant mattersmatter that occurred subsequent to December 31, 2019.
Dividends2021.
On February 7, 2020,25, 2022, the Board declaredCompany received $10.6 million in cash from Cabot (the "Cabot Payment") as a quarterly dividendresult of $0.25 per sharea change in control provision in the Supply Agreement (the "Change in Control"), which occurred as a result of common stock, which was paid onthe sale of Cabot by its parent, Cabot Corporation. Under the Change in Control, the Company received from Cabot full payment of all amounts outstanding under the Reclamation Reimbursement, payment of all unbilled amounts related to Specific Capital for expenditures incurred through February 28, 2022 and payment of additional Reclamation Costs (the "Cabot Reclamation Costs"). Under the Reclamation Contract, the Company is obligated to remit payment for the Cabot Reclamation Costs to the third party operator of Marshall Mine within a specified timeframe. The Company will account for the Cabot Payment in its March 10, 202031, 2022 quarter and does not anticipate any impacts to stockholders of record at the close of business on February 21, 2020. Supply Agreement except as described above.
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
None.
Item 9A. Controls and Procedures
Evaluation of Disclosure Controls and Procedures
As required by Rule 13a‑15(b) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”"Exchange Act"), we have evaluated, under the supervision of and with the participation of our management, including our principal executive officer and principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a‑15(e) and 15d‑15(e) under the Exchange Act) as of the end of the period covered by this annual report. Our disclosure controls and procedures are designed to ensure that information required to be disclosed in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms. Based upon this evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were not effective as of December 31, 2019.2021 due to a material weakness in our internal control over financial reporting described below.
Management’s Report on Internal Control over Financial Reporting
Management is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act. Internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of consolidated financial statements for external purposes in accordance with generally accepted accounting principles. The Company's internal control over financial reporting includes those policies and procedures that:
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1. | 1.Pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets; |
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2. | Provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the Company are being made only in accordance with authorizations of our management and directors; and |
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3. | 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 our financial statements. |
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, 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.
Under the supervision of, and with the participation of our management, including the principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework and criteria established in Internal Control-Integrated Framework in 2013, issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation, our management concluded that our internal control over financial reporting was effective as of December 31, 2019.
Moss Adams LLP, an independent registered public accounting firm, has issued an attestation report on our internal control over financial reporting as of December 31, 2019 and its report is included herein.
Changes in Internal Control Over Financial Reporting
During the fourth quarter of 2019, we completed the integration of Carbon Solutions into our internal control over financial reporting. Except for this change, there has been no change in our internal control over financial reporting (as defined in Rules 13a‑15(f) and 15d‑15(f) under the Exchange Act) during the fourth quarter of 2019 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
Report of Independent Registered Public Accounting Firm
To the Stockholders and the Board of Directors of
Advanced Emissions Solutions, Inc. and Subsidiaries
Opinion on Internal Control over Financial Reporting
We have audited Advanced Emissions Solutions, Inc. and subsidiaries’ (the “Company”) internal control over financial reporting as of December 31, 2019, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”). In our opinion, the Company maintained, in all material respects, effective control over financial reporting as of December 31, 2019, based on criteria established in Internal Control - Integrated Framework (2013) issued by COSO.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”), the consolidated balance sheets of Advanced Emissions Solutions, Inc. as of December 31, 2019 and 2018, the related consolidated statements of operations, stockholders’ equity and cash flows for the years then ended, and the related notes (collectively referred to as the “consolidated financial statements”), and our report dated March 16, 2020 expressed an unqualified opinion on those consolidated financial statementsand included an explanatory paragraph relating to the adoption of ASC 842 - Leases.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provideour assets;
2.Provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the companyCompany are being made only in accordance with authorizations of our management and directors of the company;directors; and (3) provide
3.Provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the company’sCompany’s assets that could have a material effect on theour financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, 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.
Under the supervision of, and with the participation of our management, including the principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework and criteria established in Internal Control-Integrated Framework in 2013, issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation, our management concluded that our internal control over financial reporting was not effective as of December 31, 2021 due to the material weakness described below.
/s/ Moss Adams LLPA material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting such that there is a reasonable possibility that a material misstatement of the Company's annual or interim financial statements will not be prevented or detected on a timely basis.
During the assessment process, we identified deficiencies in the design and operation of controls over (1) the selection and application of accounting principles; (2) the monitoring of interpretative guidance of previously adopted accounting standards; and (3) the annual review of policies and procedures related to material accounts. These deficiencies in combination were evaluated as having a reasonable possibility that a material misstatement would not be prevented or detected on a timely basis resulting in a material weakness in our internal controls.
Denver, ColoradoAs a result of these deficiencies, as described in Note 2 to the consolidated financial statements included in Item 8. "Financial Statements and Supplementary Data," the Company identified and corrected immaterial errors in previously reported revenues due to freight revenue being improperly classified as consumables cost of revenue instead of consumables revenues. The material weakness did not result in a material misstatement of our historical consolidated financial statements.
Management developed a plan to remediate the material weakness described above. Remediation efforts include (1) changes to the design of controls relating to the selection and application of accounting principles and the evaluation of changes in interpretative guidance relating to previously implemented accounting standards and (2) implementing an annual review of key accounting policies. The implementation of the remediation plan is in progress, and we expect to design and implement these changes in internal controls during the first half of fiscal year 2022.
Changes in Internal Control Over Financial Reporting
There has been no change in our internal control over financial reporting (as defined in Rules 13a‑15(f) and 15d‑15(f) under the Exchange Act) during the fourth quarter of 2021 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
Item 9B. Other Information
None.
Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections None.
PART III
Item 10. Directors, Executive Officers, and Corporate Governance
The information required by this Item is incorporated by reference to our definitive proxy statement for the Annual Meeting of Stockholders to be filed within 120 days from December 31, 2019.2021.
Item 11. Executive Compensation
The information required by this Item is incorporated by reference to our definitive proxy statement for the Annual Meeting of Stockholders to be filed within 120 days from December 31, 2019.2021.
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
The information required by this Item concerning security ownership of certain beneficial owners and management is incorporated by reference to our definitive proxy statement for the Annual Meeting of Stockholders to be filed within 120 days from December 31, 2019,2021, with the exception of the following information.
Securities Authorized for Issuance under Equity Compensation Plans
We have plans under which equity awards are authorized for grant or issuance as compensation to eligible employees, consultants, and members of the Board. Our stockholders have approved these plans. See Note 1116 - Stock-Based Compensation included in Item 8 of this Report for further information about the material terms of our equity compensation plans. The following table is a summary of the shares of our common stock authorized for issuance under the equity compensation plans as of December 31, 2019:2021:
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| Plan Category | | Number of securities to be issued upon exercise of outstanding options, warrants and rights | | Weighted-average exercise price of outstanding options, warrants and rights (2) | | Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in the first column) (3) |
| Equity compensation plans approved by security holders (1) | | 300,000 |
| | $ | 13.87 |
| | 2,077,538 |
|
| Equity compensation plans not approved by security holders | | — |
| | $ | — |
| | — |
|
| Total | | 300,000 |
| | | | 2,077,538 |
|
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| Plan Category | | Number of securities to be issued upon exercise of outstanding options, warrants and rights | | Weighted-average exercise price of outstanding options, warrants and rights | | Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in the first column) (2) |
| Equity compensation plans approved by security holders (1) | | — | | | $ | — | | | 880,564 | |
| Equity compensation plans not approved by security holders | | — | | | $ | — | | | — | |
| Total | | — | | | | | 880,564 | |
(1) Includes securities registered for issuance under the Amended and Restated 2007 Equity IncentiveADA-ES Profit Sharing Retirement Plan as amended, the Amended and Restated 2010 Non-Management Compensation and Incentive Plan, as amended, and the 2017 Omnibus Incentive Plan.
(2) The weighted-average price pertains only to 300,000 shares of common stock issuable upon the exercise of outstanding options.
(3) The number of securities is reduced by 451,344531,623 shares of restricted common stock for which restrictions have not lapsed.
Item 13. Certain Relationships and Related Transactions and Director Independence
The information required by this Item is incorporated by reference to our definitive proxy statement for the Annual Meeting of Stockholders to be filed within 120 days from December 31, 2019.2021.
Item 14. Principal Accountant Fees and Services
The information required by this Item is incorporated by reference to our definitive proxy statement for the Annual Meeting of Stockholders to be filed within 120 days from December 31, 2019.2021.
Item 15. Exhibits and Financial Statement Schedules
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(a) | The following consolidated financial statements of Advanced Emissions Solutions, Inc. are filed as part of this Report under Item 8: |
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(1) | Financial Statements – see Index to Consolidated Financial Statements in Item 8; |
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(2) | Financial Statement Schedules – All schedules are omitted because the required information is not applicable or is not present in amounts sufficient to require submission of the schedule or because the information required is included in the Consolidated Financial Statements and Notes thereto; and |
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(3) | Exhibits – Those exhibits required by Item 601 of Regulation S-K and by paragraph (b) below. |
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(b) | The following exhibits are filed as part of this Report or, where indicated, were heretofore filed and are hereby incorporated by reference: |
(a)The following consolidated financial statements of Advanced Emissions Solutions, Inc. are filed as part of this Report under Item 8:
(1) Financial Statements – see Index to Consolidated Financial Statements in Item 8;
(2) Financial Statement Schedules – All schedules are omitted because the required information is not applicable or is not present in amounts sufficient to require submission of the schedule or because the information required is included in the Consolidated Financial Statements and Notes thereto; and
(3) Exhibits – Those exhibits required by Item 601 of Regulation S-K and by paragraph (b) below.
(b)The following exhibits are filed as part of this Report or, where indicated, were heretofore filed and are hereby incorporated by reference:
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| Exhibit No. | | Description | | Form | | File No. | | Incorporated by Reference
Exhibit | | Filing Date |
| 3.1 | | | | 10-Q | | 000-54992 | | 3.1 | | August 9, 2013 |
| 3.2 | | | | 10-K | | 001-37822 | | 3.2 | | March 12, 2018 |
| 3.3 | | | | 8-K | | 001-37822 | | 3.1 | | May 8, 2017 |
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| 4.1 | | | | 10-Q | | 000-54992 | | 4.1 | | August 9, 2013 |
| 4.2 | | | | 8-K | | 001-37822 | | 3.2 | | May 8, 2017 |
| 4.3 | | | | 8-K | | 001-37822 | | 4.2 | | April 11, 2018 |
| 4.4 | | | | 8-K | | 001-37822 | | 4.3 | | April 11, 2019 |
| 4.5 | | | | 8-K | | 001-37822 | | 4.4 | | April 9, 2020 |
| 4.6 | | | | 8-K | | 001-37822 | | 4.5 | | April 13, 2021 |
| 10.1 | | | | 8-K | | 001-37822 | | 10.1 | | June 22, 2017 |
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| 10.2 | | | | 8-K | | 000-54992 | | 10.66 | | September 2, 2014 |
| 10.3 | | | | 10-Q | | 001-37822 | | 10.1 | | August 6, 2018 |
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| 10.4 | | | | 10-Q | | 001-37822 | | 10.3 | | August 10, 2020 |
| 10.5 | | | | 10-Q | | 001-37822 | | 10.4 | | August 10, 2020 |
| 10.6 | | | | 8-K | | 001-37822 | | 10.1 | | March 3, 2021 |
| 10.7 | | | | 10-Q | | 001-37822 | | 10.4 | | May 10, 2021 |
| 10.8 | | | | 10-Q | | 001-37822 | | 10.5 | | May 10, 2021 |
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| Exhibit No. | | Description | | Form | | File No. | | Incorporated by Reference
Exhibit | | Filing Date |
| 3.1 | | | | 10-Q | | 000-54992 | | 3.1 | | August 9, 2013 |
| 3.2 | | | | 10-K | | 001-37822 | | 3.2 | | March 12, 2018 |
| 3.3 | | | | 8-K | | 001-37822 | | 3.1 | | May 8, 2017 |
| 4.1 | | | | 10-Q | | 000-54992 | | 4.1 | | August 9, 2013 |
| 4.2 | | | | 8-K | | 001-37822 | | 3.2 | | May 8, 2017 |
| 4.3 | | | | 8-K | | 001-37822 | | 4.2 | | April 11, 2018 |
| 4.4 | | | | 8-K | | 001-37822 | | 4.3 | | April 11, 2019 |
| 10.1 | | | | 8-K | | 001-37822 | | 10.1 | | June 22, 2017 |
| 10.2 | | | | 10-K | | 000-54992 | | 10.19 | | February 29, 2016 |
| 10.3 | | | | 8-K | | 000-54992 | | 10.66 | | September 2, 2014 |
| 10.4 | | | | 10-Q/A | | 000-50216 | | 10.33 | | September 28, 2011 |
| 10.5 | | | | 10-Q | | 000-50216 | | 10.89 | | November 14, 2011 |
| 10.6 | | | | 10-Q | | 000-50216 | | 10.59 | | November 9, 2012 |
| 10.7 | | | | 10-Q | | 000-50216 | | 10.87 | | August 12, 2011 |
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| Exhibit No. | | Description | | Form | | File No. | | Incorporated by Reference
Exhibit | | Filing Date |
| 10.9 | | | | 8-K | | 001-37822 | | 10.1 | | May 11, 2020 |
| 10.10 | | | | 10-Q/A | | 000-50216 | | 10.33 | | September 28, 2011 |
| 10.11 | | | | 10-Q | | 000-50216 | | 10.89 | | November 14, 2011 |
| 10.12 | | | | 10-Q | | 000-50216 | | 10.59 | | November 9, 2012 |
| 10.13 | | | | 10-Q | | 000-50216 | | 10.87 | | August 12, 2011 |
| 10.14 | | | | 10-K | | 000-54992 | | 10.38 | | February 29, 2016 |
| 10.15 | | | | 10-Q | | 000-50216 | | 10.77 | | August 16, 2010 |
| 10.16 | | | | 10-K | | 000-50216 | | 10.81 | | March 28, 2011 |
| 10.17 | | | | 10-Q | | 000-54992 | | 10.63 | | November 12, 2013 |
| 10.18 | | | | 10-Q | | 000-50216 | | 10.74 | | August 16, 2010 |
| 10.19 | | | | 10-K | | 000-54992 | | 10.44 | | February 29, 2016 |
| 10.20 | | | | 10-K | | 000-50216 | | 10.49 | | March 15, 2012 |
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| 10.21 | | | | 10-Q | | 000-50216 | | 10.58 | | November 9, 2012 |
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| 10.22 | | | | 10-K | | 001-37822 | | 10.43 | | March 18, 2019 |
| 10.23 | | | | 10-K | | 001-37822 | | 10.44 | | March 18, 2019 |
| 10.24 | | | | 10-Q | | 001-37822 | | 10.1 | | November 12, 2019 |
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| 10.25 | | | | 8-K | | 001-37822 | | 10.1 | | September 30, 2020 |
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| Exhibit No. | | Description | | Form | | File No. | | Incorporated by Reference
Exhibit | | Filing Date |
| 10.8 | | | | 10-K | | 000-54992 | | 10.38 | | February 29, 2016 |
| 10.9 | | | | 10-Q | | 000-50216 | | 10.77 | | August 16, 2010 |
| 10.10 | | | | 10-K | | 000-50216 | | 10.81 | | March 28, 2011 |
| 10.11 | | | | 10-Q | | 000-54992 | | 10.63 | | November 12, 2013 |
| 10.12 | | | | 10-Q | | 000-50216 | | 10.74 | | August 16, 2010 |
| 10.13 | | | | 10-K | | 000-54992 | | 10.44 | | February 29, 2016 |
| 10.14 | | | | 10-K | | 000-50216 | | 10.49 | | March 15, 2012 |
| 10.15 | | | | 10-Q/A | | 000-50216 | | 10.84 | | September 28, 2011 |
| 10.16 | | | | 10-Q | | 000-50216 | | 10.86 | | August 12, 2011 |
| 10.17 | | | | 10-K | | 000-50216 | | 10.44 | | March 15, 2012 |
| 10.18 | | | | 10-K | | 000-50216 | | 10.50 | | March 15, 2012 |
| 10.19 | | | | 10-Q | | 000-50216 | | 10.58 | | November 9, 2012 |
| 10.20 | | | | 10-Q | | 000-54992 | | 10.62 | | November 12, 2013 |
| 10.21 | | | | 10-K | | 000-54992 | | 10.69 | | February 29, 2016 |
| 10.22 | | | | 10-Q | | 001-37822 | | 10.1 | | August 6, 2018 |
| 10.23 | | Purchase and Sale Agreement by and among Energy Capital Partners I, LP, Energy Capital Partners I-A, LP, Energy Capital Partners I-B IP, LP, Energy Capital Partners I (Crowfoot IP), LP, and Carbon Solutions Management, LLC, as Sellers, and Advanced Emissions Solutions, Inc., as Purchaser, dated as of November 15, 2018 | | 8-K | | 001-37822 | | 2.1 | | November 15, 2018 |
| 10.24 | | | | 8-K | | 001-37822 | | 10.1 | | December 13, 2018 |
| | | Exhibit No. | | Description | | Form | | File No. | | Incorporated by Reference
Exhibit | | Filing Date | Exhibit No. | | Description | | Form | | File No. | | Incorporated by Reference
Exhibit | | Filing Date |
| 10.25 | | | | 8-K | | 001-37822 | | 10.2 | | December 13, 2018 | |
| 10.26 | | | | 10-K | | 001-37822 | | 10.43 | | March 18, 2019 | 10.26 | | | | 8-K | | 001-37822 | | 10.2 | | September 30, 2020 |
| 10.27 | | | | 10-K | | 001-37822 | | 10.44 | | March 18, 2019 | 10.27 | | | | 8-K | | 001-37822 | | 10.1 | | March 29, 2021 |
| 10.28 | | | | 10-Q | | 001-37822 | | 10.1 | | November 12, 2019 | 10.28 | | | | 8-K | | 001-37822 | | 10.1 | | July 29, 2021 |
| | 21.1 | | | | 21.1 | | | |
| 23.1 | | | | 23.1 | | | |
| 23.2 | | | | 23.2 | | | |
| | 31.1 | | | | 31.1 | | | |
| 31.2 | | | | 31.2 | | | |
| 32.1 | | | | 32.1 | | | |
| 95 | | | | 95 | | | |
| 101 | | The following financial statements, formatted in XBRL: (i) Consolidated Balance Sheets as of December 31, 2019 and 2018, (ii) Consolidated Statements of Operations for the Years ended December 31, 2019 and 2018, (iii) Consolidated Statements of Changes in Stockholders’ Equity for the Years ended December 31, 2019 and 2018, (iv) Consolidated Statements of Cash Flows for the Years ended December 31, 2019 and 2018; and (v) Notes to the Consolidated Financial Statements. The information in Exhibit 101 is “furnished” and not “filed” as provided in Rule 401 of Regulation S-T. | | 101 | | The following financial statements, formatted in XBRL: (i) Consolidated Balance Sheets as of December 31, 2021 and 2020, (ii) Consolidated Statements of Operations for the Years ended December 31, 2021 and 2020, (iii) Consolidated Statements of Changes in Stockholders’ Equity for the Years ended December 31, 2021 and 2020, (iv) Consolidated Statements of Cash Flows for the Years ended December 31, 2021 and 2020; and (v) Notes to the Consolidated Financial Statements. The information in Exhibit 101 is “furnished” and not “filed” as provided in Rule 401 of Regulation S-T. | |
Notes:
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** | – Management contract or compensatory plan or arrangement. |
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*** | – Portions of this exhibit have been omitted pursuant to a request for confidential treatment. The non-public information has been separately filed with the Securities and Exchange Commission. |
* – Filed herewith.
** – Management contract or compensatory plan or arrangement.
*** – Portions of this exhibit have been omitted pursuant to a request for confidential treatment.
Filings for the Company were made under the name ADA-ES, Inc. (File No. 000-50216) prior to July 1, 2013, the effective date of our reorganization, and under the name Advanced Emissions Solutions, Inc. (File No. 000-54992) starting on July 1, 2013. Filings for the Company were made under the name Advanced Emissions Solutions, Inc. (File No. 001-37822) starting on July 6, 2016.
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(c) | The following financial statements are included in this report pursuant to Regulation S-X: |
| |
(1) | Tinuum Group, LLC and Subsidiaries; |
(c)The following financial statements are included in this Report:
(1) Tinuum Group, LLC and Subsidiaries;
a. Consolidated Financial Statements, December 31, 20192021 and 2018 (With2020 (with Independent Auditors' Reports Thereon)thereon);
Tinuum Group, LLC and Subsidiaries
CONSOLIDATED FINANCIAL STATEMENTS
As of and for the Years Ended
December 31, 20192021 and 20182020
TABLE OF CONTENTS
| | | | | | | | |
| | Page |
| | |
| REPORT OF INDEPENDENT AUDITORS | | |
| | |
| FINANCIAL STATEMENTS | | |
| | |
| CONSOLIDATED BALANCE SHEETS | | Page |
| | |
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM | | |
| | |
FINANCIAL STATEMENTS | | |
| | |
CONSOLIDATED BALANCE SHEETS | | |
| CONSOLIDATED STATEMENTS OF OPERATIONS | | |
| CONSOLIDATED STATEMENTS OF MEMBERS' EQUITY | | |
| CONSOLIDATED STATEMENTS OF CASH FLOWS | | |
NOTES TO CONSOLIDATED FINANCIAL STATMENTSSTATEMENTS | | |
Report of Independent Registered Public Accounting FirmAuditors
To the Board of Managers and Members of
Tinuum Group, LLC
OpinionReport on the Audit of the Financial Statements
Opinion
We have audited the accompanying consolidated balance sheetsfinancial statements of Tinuum Group, LLC and its subsidiaries, (the Company)which comprise the consolidated balance sheets as of December 31, 20192021 and 2018,2020, and the related consolidated statements of operations, members’ equity, and cash flows for the years then ended and the related notes (collectively referred to as the consolidated financial statements). statements.
In our opinion, the accompanying consolidated financial statements present fairly, in all material respects, the consolidated financial position of the CompanyTinuum Group, LLC and its subsidiaries as of December 31, 20192021 and 2018,2020, and the consolidated results of itstheir operations and itstheir cash flows for the years then ended in conformityaccordance with accounting principles generally accepted in the United States of America.
Change in Accounting Principle
As discussed in Note 1 to the consolidated financial statements, in 2019 the Company changed its method of accounting for revenue recognition due to the adoption of Accounting Standards Codification ("ASC") Topic No. 606, and its method of accounting for leases due to the adoption of ASC Topic No. 842.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) ("PCAOB") and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB and in accordance with auditing standards generally accepted in the United States of America. ThoseAmerica (GAAS). Our responsibilities under those standards requireare further described in the Auditor’s Responsibilities for the Audit of the Financial Statements section of our report. We are required to be independent of Tinuum Group, LLC and its subsidiaries and to meet our other ethical responsibilities, in accordance with the relevant ethical requirements relating to our audits. We believe that we plan and perform the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion.
Responsibilities of Management for the Financial Statements
Management is responsible for the preparation and fair presentation of the consolidated financial statements in accordance with accounting principles generally accepted in the United States of America, and for the design, implementation, and maintenance of internal control relevant to the preparation and fair presentation of financial statements that are free from material misstatement, whether due to fraud or error.
In preparing the consolidated financial statements, management is required to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about Tinuum Group, LLC and its subsidiaries’ ability to continue as a going concern within one year after the date that the consolidated financial statements are issued.
Auditor’s Responsibilities for the Audit of the Financial Statements
Our objectives are to obtain reasonable assurance about whether the consolidated financial statements as a whole are free offrom material misstatement, whether due to fraud or error, or fraud. The Companyand to issue an auditor’s report that includes our opinion. Reasonable assurance is a high level of assurance but is not required to have, nor were we engaged to perform,absolute assurance and therefore is not a guarantee that an audit conducted in accordance with GAAS will always detect a material misstatement when it exists. The risk of its internal control over financial reporting. As part of our audits we are required to obtain an understandingnot detecting a material misstatement resulting from fraud is higher than for one resulting from error, as fraud may involve collusion, forgery, intentional omissions, misrepresentations, or the override of internal control over financial reporting but not forcontrol. Misstatements are considered material if there is a substantial likelihood that, individually or in the purpose of expressing an opinionaggregate, they would influence the judgment made by a reasonable user based on the effectiveness ofconsolidated financial statements.
In performing an audit in accordance with GAAS, we:
•Exercise professional judgment and maintain professional skepticism throughout the Company’s internal control over financial reporting. Accordingly, we express no such opinion.audit.
Our audits included performing procedures to•Identify and assess the risks of material misstatement of the consolidated financial statements, whether due to fraud or error, or fraud, and performingdesign and perform audit procedures to respondresponsive to those risks. Such procedures includedinclude examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating
•Obtain an understanding of internal control relevant to the audit in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of Tinuum Group, LLC and its subsidiaries’ internal control. Accordingly, no such opinion is expressed.
•Evaluate the appropriateness of accounting principlespolicies used and the reasonableness of significant accounting estimates made by management, as well as evaluatingevaluate the overall presentation of the consolidated financial statements. We believe
•Conclude whether, in our judgment, there are conditions or events, considered in the aggregate, that our audits provideraise substantial doubt about Tinuum Group, LLC and its subsidiaries’ ability to continue as a going concern for a reasonable basis for our opinion.period of time.
We are required to communicate with those charged with governance regarding, among other matters, the planned scope and timing of the audit, significant audit findings, and certain internal control–related matters that we identified during the audit.
Emphasis of Matter Regarding Going Concern
The accompanying consolidated financial statements have been prepared assuming that Tinuum Group, LLC and its subsidiaries will continue as a going concern. As discussed in Note 1 to the consolidated financial statements, with the expiration of the production tax credit (PTC) as of December 31, 2021 all third-party investor contracts have expired or been terminated and Tinuum Group, LLC and its subsidiaries have terminated reduced emissions fuel production as of December 31, 2021, which has led to cash inflows ending in January 2022. To date, management has not developed an alternative business strategy that would support continued business operations. Given these events and conditions, substantial doubt exists about the Tinuum Group, LLC and its subsidiaries’ ability to continue as a going concern. Management’s evaluation of the events and conditions and management’s plans regarding these matters are also described in Note 1. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty. Our opinion is not modified with respect to this matter.
/s/ Moss Adams LLP
Denver, Colorado
March 13, 20204, 2022
We have served as the Company’s auditor since 2017.
TINUUM GROUP, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
As of December 31, 20192021 and 20182020
(in thousands)
| | | ASSETS | ASSETS | ASSETS |
| | | | | |
| | 2019 | | 2018 | | 2021 | | 2020 |
| CURRENT ASSETS | | | | CURRENT ASSETS | | | |
| Cash and cash equivalents | $ | 44,441 |
| | $ | 26,211 |
| Cash and cash equivalents | $ | 28,156 | | | $ | 50,540 | |
| Accounts receivable | 6,030 |
| | 7,218 |
| Accounts receivable | 7,727 | | | 8,029 | |
| Related party receivables | 56 |
| | 6,350 |
| Related party receivables | 102 | | | — | |
| Income tax receivable | | Income tax receivable | — | | | 5,966 | |
| Contract receivables – current | 42,916 |
| | — |
| Contract receivables – current | 3,342 | | | 47,264 | |
| Contract costs – current | 21,503 |
| | — |
| Contract costs – current | — | | | 5,541 | |
| Inventory | 11,866 |
| | 14,632 |
| Inventory | — | | | 13,730 | |
| Other current assets | 1,661 |
| | 547 |
| Other current assets | 60 | | | 11,370 | |
| Total current assets | 128,473 |
| | 54,958 |
| Total current assets | 39,387 | | | 142,440 | |
| | | | | |
| | Fixed assets, net | 50,323 |
| | 75,206 |
| Fixed assets, net | 220 | | | 24,508 | |
| Contract receivables – long term | 51,587 |
| | — |
| Contract receivables – long term | — | | | 4,122 | |
| Contract costs – long term | 5,226 |
| | — |
| |
| | Other assets, net | 18,684 |
| | 17,785 |
| Other assets, net | — | | | 19 | |
| TOTAL ASSETS | $ | 254,293 |
| | $ | 147,949 |
| TOTAL ASSETS | $ | 39,607 | | | $ | 171,089 | |
The following table presents certain assets of the consolidated variable interest entities ("VIEs"), which are included in the Consolidated Balance Sheets above. The assets in the table below include those assets that can only be used to settle obligations of consolidated VIEs, presented on the following page, and are in excess of those obligations. Additionally, the assets in the table below include third-party assets of consolidated VIEs only and exclude intercompany balances that eliminate in consolidation.
Assets of Consolidated VIEs to be Used to Settle Obligations of Consolidated VIEs
| | | | | | | | | | | | | | |
| | |
| | 2021 | | 2020 |
| ASSETS | | | | |
| Cash and cash equivalents | | $ | 9,539 | | | $ | 32,050 | |
| Accounts receivable | | 3,001 | | | 25 | |
| Income tax receivable | | — | | | 5,966 | |
| Inventory | | — | | | 13,724 | |
| Other current assets | | — | | | 403 | |
| Non-current assets | | — | | | 10,631 | |
| TOTAL ASSETS | | $ | 12,540 | | | $ | 62,799 | |
|
| | | | | | | |
| | |
| | 2019 | | 2018 |
| ASSETS | | | |
| Cash and cash equivalents | $ | 31,481 |
| | $ | 10,939 |
|
| Accounts receivable | 22 |
| | 1,574 |
|
| Inventory | 11,840 |
| | 14,632 |
|
| Other current assets | 381 |
| | 379 |
|
| Non-current assets | 14,838 |
| | 11,981 |
|
| TOTAL ASSETS | $ | 58,562 |
| | $ | 39,505 |
|
Statement continues on the next page
The accompanying notes are an integral part of the consolidated financial statements.statements
TINUUM GROUP, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
As of December 31, 20192021 and 20182020
(in thousands)
| | | | | | | | | | | | | | |
| LIABILITIES AND MEMBERS' EQUITY |
| | | | |
| | 2021 | | 2020 |
| CURRENT LIABILITIES | | | | |
| Accounts payable | | $ | 1,057 | | | $ | 6,446 | |
| Accrued liabilities | | 4,235 | | | 6,568 | |
| Related party payables | | 6,636 | | | 7,653 | |
| Deferred revenue | | — | | | 11,898 | |
| Note payable to customer | | — | | | 5,400 | |
| Secured promissory notes | | — | | | 6,313 | |
| Asset retirement obligations | | 1,795 | | | — | |
| Accrued retention compensation | | 1,835 | | | — | |
| Total current liabilities | | 15,558 | | | 44,278 | |
| | | | |
| | | | |
| Asset retirement obligations | | — | | | 2,070 | |
| Accrued retention compensation | | — | | | 3,116 | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| TOTAL LIABILITIES | | 15,558 | | | 49,464 | |
| | | | |
| | | | |
| | | | |
| MEMBERS' EQUITY | | | | |
| Members’ equity attributable to Class A Members | | 8,890 | | | 59,221 | |
| Member equity attributable to Class B Member | | 9,887 | | | 18,769 | |
| Noncontrolling interests | | 5,272 | | | 43,635 | |
| Total Members' equity | | 24,049 | | | 121,625 | |
| | | | |
| TOTAL LIABILITIES AND MEMBERS' EQUITY | | $ | 39,607 | | | $ | 171,089 | |
|
| | | | | | | |
| LIABILITIES AND MEMBERS' EQUITY |
| | | | |
| | 2019 | | 2018 |
| CURRENT LIABILITIES | | | |
| Accounts payable | $ | 5,128 |
| | $ | 5,828 |
|
| Accrued liabilities | 7,076 |
| | 3,169 |
|
| Related party payables | 10,278 |
| | 10,705 |
|
| Deferred revenue – current | 9,810 |
| | 31,206 |
|
| Line of credit | 5,500 |
| | — |
|
| Note payable to customer – current | 21,600 |
| | — |
|
| Total current liabilities | 59,392 |
| | 50,908 |
|
| | | | |
| Secured promissory notes | 6,491 |
| | 9,722 |
|
| Deferred revenue – long term | — |
| | 3,420 |
|
| Asset retirement obligations | 1,449 |
| | 1,304 |
|
| Note payable to customer – long term | 5,400 |
| | — |
|
| TOTAL LIABILITIES | 72,732 |
| | 65,354 |
|
| | | | |
| MEMBERS' EQUITY | | | |
| Members’ equity attributable to Class A Members | 117,006 |
| | 49,102 |
|
| Member equity attributable to Class B Member | 28,967 |
| | 16,983 |
|
| Noncontrolling interests | 35,588 |
| | 16,510 |
|
| Total members' equity | 181,561 |
| | 82,595 |
|
| | | | |
| TOTAL LIABILITIES AND MEMBERS' EQUITY | $ | 254,293 |
| | $ | 147,949 |
|
The following table presents certain liabilities of consolidated VIEs, which are included in the Consolidated Balance Sheets above. The liabilities in the table below include third-party liabilities of consolidated VIEs only and exclude intercompany balances that eliminate in consolidation. The liabilities also exclude intercompany amounts where creditors have recourse against the general credit of Tinuum Group, LLC.
Liabilities of Consolidated VIEs for Which Creditors Do Not Have Recourse Against the General Credit of Tinuum Group, LLC
| | | | | | | | | | | |
| |
| 2021 | | 2020 |
| LIABILITIES | | | |
| Accounts payable and accrued liabilities | $ | 1,244 | | | $ | 7,859 | |
| Related party payables | 2,358 | | | 3,747 | |
| Secured promissory notes | — | | | 6,313 | |
| Non-current liabilities | 1,795 | | | 1,670 | |
| TOTAL LIABILITIES | $ | 5,397 | | | $ | 19,589 | |
|
| | | | | | | |
| |
|
| | 2019 | | 2018 |
| LIABILITIES | | | |
| Accounts payable and accrued liabilities | $ | 6,745 |
| | $ | 6,266 |
|
| Related party payables | 5,462 |
| | 3,135 |
|
| Secured promissory notes | 6,491 |
| | 9,722 |
|
| Non-current liabilities | 1,091 |
| | 795 |
|
| TOTAL LIABILITIES | $ | 19,789 |
| | $ | 19,918 |
|
The accompanying notes are an integral part of the consolidated financial statements.
103104
TINUUM GROUP, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
For the Years Ended December 31, 20192021 and 20182020
(in thousands)
| | | | | | | | | | | | | | |
| | 2021 | | 2020 |
| REVENUES | | | | |
| Reduced emissions and unrefined fuel | | $ | 776,397 | | | $ | 619,101 | |
| REF Facility revenues – over time | | 104,905 | | | 89,478 | |
| REF Facility revenues – point-in-time | | (2,643) | | | (1,129) | |
| Other | | 606 | | | 594 | |
| | | | |
| TOTAL REVENUES | | 879,265 | | | 708,044 | |
| | | | |
| COST OF SALES (exclusive of depreciation shown separately below) | | | | |
| Feedstock purchases | | 776,397 | | | 619,101 | |
| Cost of REF facilities | | — | | | (12) | |
| Chemicals | | 37,260 | | | 27,496 | |
| Site and production fees | | 38,091 | | | 35,950 | |
| Royalties and fees | | 20,522 | | | 18,860 | |
| TOTAL COST OF SALES | | 872,270 | | | 701,395 | |
| | | | |
| GROSS PROFIT | | 6,995 | | | 6,649 | |
| | | | |
| OPERATING EXPENSES | | 13,881 | | | 11,217 | |
| | | | |
| IMPAIRMENT OF REF FACILITIES | | 15 | | | 2,968 | |
| | | | |
| DEPRECIATION AND AMORTIZATION EXPENSE | | 24,101 | | | 28,175 | |
| | | | |
| SELLING, GENERAL AND ADMINISTRATIVE EXPENSES | | 11,417 | | | 15,648 | |
| | | | |
| LOSS FROM OPERATIONS | | (42,419) | | | (51,359) | |
| | | | |
| OTHER (INCOME) EXPENSE | | | | |
| Interest income | | (570) | | | (1,744) | |
| Other expense | | (536) | | | 655 | |
| Interest expense | | 88 | | | 1,671 | |
| TOTAL OTHER (INCOME) EXPENSE | | (1,018) | | | 582 | |
| | | | |
| LOSS BEFORE INCOME TAXES | | (41,401) | | | (51,941) | |
| | | | |
| Deferred tax benefit | | (9,769) | | | (18,979) | |
| Income tax expense | | 1,061 | | | 1,137 | |
| | | | |
| NET LOSS | | (32,693) | | | (34,099) | |
| | | | |
| | | | |
| | | | |
| Loss attributable to noncontrolling interests | | 126,948 | | | 91,501 | |
| | | | |
| | | | |
| NET INCOME AVAILABLE TO MEMBERS | | $ | 94,255 | | | $ | 57,402 | |
|
| | | | | | | |
| | 2019 | | 2018 |
| REVENUES | | | |
| Reduced emissions and unrefined fuel | $ | 500,404 |
| | $ | 451,273 |
|
| Lease revenues | — |
| | 162,684 |
|
| REF Facility revenues – over time | 142,028 |
| | — |
|
| REF Facility revenues – point-in-time | 45,608 |
| | — |
|
| Other | 733 |
| | 1,103 |
|
| TOTAL REVENUES | 688,773 |
| | 615,060 |
|
| | | | |
| COST OF SALES (exclusive of depreciation shown separately below) | | | |
| Feedstock purchases | 500,404 |
| | 451,273 |
|
| Cost of REF facilities | 11,509 |
| | — |
|
| Chemicals | 22,521 |
| | 18,648 |
|
| Site and production fees | 27,523 |
| | 20,849 |
|
| Royalties and fees | 21,840 |
| | 17,155 |
|
| TOTAL COST OF SALES | 583,797 |
| | 507,925 |
|
| | | | |
| GROSS PROFIT | 104,976 |
| | 107,135 |
|
| | | | |
| OPERATING EXPENSES | 8,983 |
| | 7,935 |
|
| | | | |
| SELLING, GENERAL AND ADMINISTRATIVE EXPENSES | 12,297 |
| | 10,688 |
|
| | | | |
| DEPRECIATION AND AMORTIZATION EXPENSE | 16,361 |
| | 5,039 |
|
| | | | |
| INCOME FROM OPERATIONS | 67,335 |
| | 83,473 |
|
| | | | |
| OTHER (INCOME) EXPENSE | | | |
| Interest income | (2,526 | ) | | (35 | ) |
| Other expense | 1,674 |
| | 3,982 |
|
| Interest expense | 482 |
| | 368 |
|
| TOTAL OTHER (INCOME) EXPENSE | (370 | ) | | 4,315 |
|
| | | | |
| INCOME BEFORE INCOME TAXES | 67,705 |
| | 79,158 |
|
| | | | |
| Income tax expense | 465 |
| | 1,359 |
|
| | | | |
| NET INCOME | 67,240 |
| | 77,799 |
|
| | | | |
| Class B holders preferred return | — |
| | (12 | ) |
| Loss attributable to noncontrolling interests | 78,544 |
| | 58,013 |
|
| | | |
| NET INCOME AVAILABLE TO MEMBERS | $ | 145,784 |
| | $ | 135,800 |
|
The accompanying notes are an integral part of the consolidated financial statements.
104105
TINUUM GROUP, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF MEMBERS' EQUITY
Years Ended December 31, 20192021 and 20182020
(in thousands)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | Class A Members | | Class B Member | | Non-Controlling Interests | | Total Members' Equity |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| BALANCES, JANUARY 1, 2020 | | | | $ | 117,006 | | | $ | 28,967 | | | $ | 35,588 | | | $ | 181,561 | |
| | | | | | | | | | |
| Member contributions | | | | — | | | — | | | 113,465 | | | 113,465 | |
| Member distributions | | | | (106,577) | | | (18,808) | | | — | | | (125,385) | |
| Member distributions, noncontrolling interests | | | | — | | | — | | | (13,917) | | | (13,917) | |
| Net income available to members | | | | 48,792 | | | 8,610 | | | — | | | 57,402 | |
| Net loss attributable to noncontrolling interests | | | | — | | | — | | | (91,501) | | | (91,501) | |
| | | | | | | | | | |
| BALANCES, DECEMBER 31, 2020 | | | | 59,221 | | | 18,769 | | | 43,635 | | | 121,625 | |
| | | | | | | | | | |
| Member contributions | | | | — | | | — | | | 104,450 | | | 104,450 | |
| Member distributions | | | | (130,448) | | | (23,020) | | | — | | | (153,468) | |
| Member distributions, noncontrolling interests | | | | — | | | — | | | (15,865) | | | (15,865) | |
| Net income available to members | | | | 80,117 | | | 14,138 | | | — | | | 94,255 | |
| Net loss attributable to noncontrolling interests | | | | — | | | — | | | (126,948) | | | (126,948) | |
| | | | | | | | | | |
| BALANCES, DECEMBER 31, 2021 | | | | $ | 8,890 | | | $ | 9,887 | | | $ | 5,272 | | | $ | 24,049 | |
|
| | | | | | | | | | | | | | | | | | | |
| | Temporary Class B Member | | Class A Members | | Class B Member | | Non-Controlling Interests | | Total Members' Equity |
| BALANCES, JANUARY 1, 2018 | $ | 821 |
| | $ | 40,452 |
| | $ | — |
| | $ | 8,757 |
| | $ | 50,030 |
|
| Class B holders preferred return | 12 |
| | — |
| | — |
| | — |
| | 12 |
|
| Member contributions | — |
| | — |
| | — |
| | 65,766 |
| | 65,766 |
|
| Member distributions | (513 | ) | | (107,100 | ) | | (3,387 | ) | | — |
| | (111,000 | ) |
| Reclassification of member equity | (320 | ) | | 320 |
| | — |
| | — |
| | — |
|
| Net income available to members | — |
| | 115,430 |
| | 20,370 |
| | — |
| | 135,800 |
|
| Net loss attributable to noncontrolling interests | — |
| | — |
| | — |
| | (58,013 | ) | | (58,013 | ) |
| BALANCES, DECEMBER 31, 2018 | — |
| | 49,102 |
| | 16,983 |
| | 16,510 |
| | 82,595 |
|
| Change in accounting principle | — |
| | 74,463 |
| | 13,141 |
| | — |
| | 87,604 |
|
| Member contributions | — |
| | — |
| | — |
| | 97,622 |
| | 97,622 |
|
| Member distributions | — |
| | (130,475 | ) | | (23,025 | ) | | — |
| | (153,500 | ) |
| Net income available to members | — |
| | 123,916 |
| | 21,868 |
| | — |
| | 145,784 |
|
| Net loss attributable to noncontrolling interests | — |
| | — |
| | — |
| | (78,544 | ) | | (78,544 | ) |
| BALANCES, DECEMBER 31, 2019 | $ | — |
| | $ | 117,006 |
| | $ | 28,967 |
| | $ | 35,588 |
| | $ | 181,561 |
|
The accompanying notes are an integral part of the consolidated financial statements.
105106
TINUUM GROUP, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Years Ended December 31, 20192021 and 20182020
(in thousands)
| | | | | | | | | | | | | | | | |
| | 2021 | | 2020 | | |
| CASH, BEGINNING OF YEAR | | $ | 50,540 | | | $ | 44,441 | | | |
| | | | | | |
| CASH FLOWS FROM OPERATING ACTIVITIES | | | | | | |
| Net loss | | (32,693) | | | (34,099) | | | |
| Adjustments to reconcile net income to net cash provided by operating activities: | | | | | | |
| Depreciation and amortization | | 24,101 | | | 28,175 | | | |
| Amortization of contract costs | | 5,541 | | | 21,188 | | | |
| Noncash operating lease expense | | 182 | | | 176 | | | |
| Assets sold as part of REF Facility transaction | | — | | | (12) | | | |
| (Gain)/loss on sale of assets | | (384) | | | 264 | | | |
| Impairment of REF facilities | | (15) | | | 2,968 | | | |
| Gain on removal of asset retirement obligation | | (131) | | | (194) | | | |
| Accretion of asset retirement obligation | | 399 | | | 184 | | | |
| Effects of changes in operating assets and liabilities: | | | | | | |
| Accounts receivable | | 302 | | | (1,943) | | | |
| Related party receivables | | (102) | | | — | | | |
| Income tax receivable | | 5,966 | | | (5,062) | | | |
| Contract receivables | | 48,044 | | | 43,117 | | | |
| Inventory | | 13,730 | | | (1,864) | | | |
| Other assets | | 11,329 | | | 8,047 | | | |
| Accounts payable and accrued liabilities | | (7,509) | | | 1,010 | | | |
| Accrued retention compensation | | (1,281) | | | 3,116 | | | |
| Payments on operating leases | | (213) | | | (200) | | | |
| Related party payables | | (863) | | | (2,196) | | | |
| Deferred revenue | | (11,898) | | | 2,088 | | | |
| Settlement of asset retirement obligation | | (543) | | | — | | | |
| Net cash provided by operating activities | | 53,962 | | | 64,763 | | | |
| | | | | | |
| CASH FLOWS FROM INVESTING ACTIVITIES | | | | | | |
| Capital expenditures for fixed assets | | — | | | (5,648) | | | |
| Proceeds from sale of fixed assets | | 250 | | | 99 | | | |
| Net cash provided by/(used) in investing activities | | 250 | | | (5,549) | | | |
| | | | | | |
| CASH FLOWS FROM FINANCING ACTIVITIES | | | | | | |
| Borrowings under line of credit | | — | | | 8,900 | | | |
| Repayments under line of credit | | — | | | (14,400) | | | |
| Repayments on note payable to customer | | (5,400) | | | (21,600) | | | |
| Repayments under secured promissory note | | (6,313) | | | (178) | | | |
| Contributions from noncontrolling interest members | | 104,450 | | | 113,465 | | | |
| Distributions paid to minority interest members | | (15,865) | | | (13,917) | | | |
| Distributions paid to members | | (153,468) | | | (125,385) | | | |
| Net cash used in financing activities | | (76,596) | | | (53,115) | | | |
| | | | | | |
| NET (DECREASE)/INCREASE IN CASH | | (22,384) | | | 6,099 | | | |
|
| | | | | | | | |
| | | 2019 | | 2018 |
| CASH, BEGINNING OF YEAR | | $ | 26,211 |
| | $ | 13,309 |
|
| | | | | |
| CASH FLOWS FROM OPERATING ACTIVITIES | | | | |
| Net income | | 67,240 |
| | 77,799 |
|
| Adjustments to reconcile net income to net cash provided by operating activities: | | | | |
| Depreciation and amortization | | 16,361 |
| | 5,039 |
|
| Noncash operating lease expense | | 159 |
| | — |
|
| Assets sold as part of REF Facility transaction | | 11,509 |
| | — |
|
| Loss on sale of assets | | 1,803 |
| | 3,996 |
|
| Gain on removal of asset retirement obligation | | (129 | ) | | — |
|
| Accretion of asset retirement obligation | | 134 |
| | 115 |
|
| Deferred taxes | | (904 | ) | | 224 |
|
| Amortization of contract costs | | 871 |
| | — |
|
| Effects of changes in operating assets and liabilities: | |
|
| |
|
|
| Accounts receivable | | 1,188 |
| | (1,498 | ) |
| Related party receivables | | 6,294 |
| | (5,381 | ) |
| Contract receivables | | (7,387 | ) | | — |
|
| Inventory | | 2,766 |
| | (3,562 | ) |
| Payments on inventory purchase contract | | — |
| | (8,187 | ) |
| Other assets | | 263 |
| | (10 | ) |
| Accounts payable and accrued liabilities | | 2,033 |
| | 3,221 |
|
| Related party payables | | 1,524 |
| | 1,230 |
|
| Settlement of asset retirement obligation | | (230 | ) | | (30 | ) |
| Deferred revenue | | (13,795 | ) | | (380 | ) |
| Payments on operating leases | | (176 | ) | | — |
|
| Net cash provided by operating activities | | 89,524 |
| | 72,576 |
|
| | | | | |
| CASH FLOWS FROM INVESTING ACTIVITIES | | | | |
| Capital expenditures for fixed assets | | (17,891 | ) | | (16,914 | ) |
| Proceeds from sale of fixed assets | | 206 |
| | 36 |
|
| Net cash used in investing activities | | (17,685 | ) | | (16,878 | ) |
| | | | | |
| CASH FLOWS FROM FINANCING ACTIVITIES | | | | |
| Borrowings (repayments) under secured promissory note | | (3,231 | ) | | 2,438 |
|
| Borrowings under line of credit | | 5,500 |
| | 4,000 |
|
| Repayments under line of credit | | — |
| | (4,000 | ) |
| Contributions from noncontrolling interest members | | 97,622 |
| | 65,766 |
|
| Distributions paid to members | | (153,500 | ) | | (111,000 | ) |
| Net cash used in financing activities | | (53,609 | ) | | (42,796 | ) |
| | | | | |
| NET INCREASE IN CASH | | 18,230 |
| | 12,902 |
|
| | | | | |
| CASH, END OF YEAR | | $ | 44,441 |
| | $ | 26,211 |
|
The accompanying notes are an integral part of the consolidated financial statements.
106107
TINUUM GROUP, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Years Ended December 31, 20192021 and 20182020
(in thousands)
| | | | | | | | | | | | | | | | |
| | 2021 | | 2020 | | |
| | | | | | |
| CASH, END OF YEAR | | $ | 28,156 | | | $ | 50,540 | | | |
| | | | | | |
| SUPPLEMENTAL DISCLOSURES | | | | | | |
| Cash paid for interest | | $ | 104 | | | $ | 1,824 | | | |
| Cash paid for taxes | | 1,207 | | | 1,212 | | | |
| | | | | | |
| NON-CASH TRANSACTIONS | | | | | | |
| | | | | | |
| Asset proceeds included in reduction of accounts payable | | $ | 154 | | | $ | — | | | |
| Capital expenditures included in related party payables | | — | | | 429 | | | |
| Asset retirement obligation layer | | — | | | 631 | | | |
|
| | | | | | | | |
| | | 2019 | | 2018 |
| | | | | |
| SUPPLEMENTAL DISCLOSURES | | | | |
| Cash paid for interest | | $ | 389 |
| | $ | 342 |
|
| Cash paid for taxes | | 1,313 |
| | 808 |
|
| | | | | |
| NON-CASH TRANSACTIONS | | | | |
| Customer note for contract costs | | $ | 27,000 |
| | $ | — |
|
| Capitalized contract costs | | 600 |
| | — |
|
| Capital expenditures included in related party payables | | 1,951 |
| | 1,977 |
|
| Asset retirement obligation layer | | 370 |
| | 153 |
|
The accompanying notes are an integral part of the consolidated financial statements.
107108
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 20192021 and 20182020
(in thousands)
NOTE 1 - SIGNIFICANT ACCOUNTING POLICIES
Tinuum Group, LLC (together with its subsidiaries, “Tinuum”"Tinuum" or “TG”"TG" or the “Company”"Company") develops, manages, sells and leases facilities ("REF Facilities") used in the production and sale of reduced emissions fuel (“REF Facilities”)("REF" or refined coal). The production and sale of reduced emissions fuel (a/k/a refined coal or "REF")REF via these REF Facilities qualifies for production tax credits that are available under Section 45 of the Internal Revenue Code (“PTCs”("PTCs"). The value of the PTC is adjusted annually based on inflation adjustment factors published in the Federal Register. The 20192021 and 20182020 PTC rates were $7.173$7.384 and $7.031$7.301 per ton of REF produced, respectively. The PTC period expired as of December 31, 2021 and as a result the Company has ceased production of REF.
Tinuum is owned 42.5% by ADA-ES, Inc. (“ADA”("ADA"), 42.5% by NexGen Refined Coal, LLC (“NexGen”("NexGen") (collectively, Class A Members), and 15% by GSFS Investments I Corp. (“GSFS”("GSFS" or the “Class"Class B Member”Member"). ADA, NexGen, and GSFS are collectively referred to herein as the “Members.”
Tinuum placed in service two REF Facilities prior to January 1, 2010 and 26 additional28 REF Facilities prior to January 1, 2012. Each REF Facility has demonstrated the required emissions reductions from the production of REF to qualify for PTCs. The REF produced at these REF Facilities is burned at coal-fired generation stations (the owner of which is a “Generator”"Generator") and is expected to continuecontinues to qualify for PTCs for a period of ten10 years following the applicable placed in service date. The two28 REF Facilities, thatof which 23 were placed in service prior to January 1, 2010operating during the year ended December 31, 2021, no longer qualifyqualified for PTCs as of December 31, 2019.
At2021. Two of the REF Facilities’ ability to produce PTCs ended during December 31, 2019 and 2018, respectively, 20 and 19since those two REF Facilities had beenwere placed in service in 2009.
REF Facilities were either sold to or were under lease with third-party investors (“("TP Investors”Investors") who utilize the REF Facilities to produce REF (each of these REF Facilities is owned or leased by a “Producer Entity”). Some of the Producer Entities are owned or leased exclusively by a TP Investor and some are owned or leased by a TP Investor with some ownership percentage retained by the Company. The REF Facilities are located at coal-fired generation stations throughout the United States.
Tinuum may also produce REF from REF Facilities for the benefit of its Members. As of December 31, 2019 and 2018, none of the REF Facilities were retained to produce REF for the Members. In instances where Tinuum retains certain member interests in a Producer Entity, PTCs generated are allocated to Tinuum in proportion to its member interests and are therefore available for the benefit of Tinuum’s Members. As of December 31, 2020, 23 REF Facilities had been sold or were under lease to TP Investors. For the year ended December 31, 2021, 23 REF Facilities were owned or leased by TP Investors for some portion of the year ranging from six to nearly twelve months. All 23 REF Facilities had ceased operations as of December 31, 2021.
Tinuum Services, LLC (“TS”("TS"), operates and maintains the REF Facilities under respective operating and maintenance agreements. TS is owned 50% each by ADA and NexGen and is not consolidated with the accounts of Tinuum. TP Investors of REF Facilities and Tinuum for retained REF Facilities pay TS, subject to certain limitations, a fee for procuring certain proprietary chemical additives, an operating fee for the production of REF, and for the other operating and maintenance costs associated with running the REF Facilities.
Basis of Presentation
The accompanying consolidated financial statements are presented in accordance with accounting principles generally accepted in the United States of America (“GAAP”("GAAP") and include the accounts of the Company and several variable interest entities (“VIEs”("VIEs"), for which Tinuum is the primary beneficiary. An entity is referred to as a VIE if it meets any of the following criteria outlined in Accounting Standard Codification 810 - Consolidation (“ ("ASC 810”810"), which are: (i) the entity has equity that is insufficient to permit the entity to finance its activities without additional subordinated financial support from other parties,parties; (ii) the entity has equity investors that, as a group, lack the characteristics of a controlling financial interestinterest; or (iii) the entity is structured with non-substantive voting rights.
The Company consolidates a VIE when it has both the power to direct the activities that most significantly impact the VIE’s economic performance and the obligation to absorb losses of the entity that could be potentially significant to the VIE (i.e., it is the primary beneficiary).
All intercompany balances and transactions have been eliminated in consolidation.
Going Concern
Currently, with the expiration of the PTCs as of December 31, 2021, all TP Investor contracts have expired or been terminated and the Company has terminated REF production, which has led to cash inflows to TG ending in January 2022. To date, management has not developed an alternative business strategy that would support continued business operations. Management continues to engage in efforts to pursue an extension of the PTC period by the U.S. Congress, though at present no such
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2021 and 2020
(in thousands)
extension has been adopted. In the event of a PTC extension in a timely manner, management would investigate any opportunity to continue REF production.
Debt financing is no longer available to the Company.
Management has budgeted, and is planning, to reserve enough cash from the final cash inflows of 2021 and 2022 to satisfy anticipated remaining liabilities and obligations. These cash reserves will be utilized to conduct an orderly wind down of business operations. The decision to commence liquidation of the Company will be subject to approval by the Members.
Management has concluded that these factors, in the aggregate, raise substantial doubt about the Company’s ability to continue as a going concern. The consolidated financial statements have been prepared on a basis which assumes the Company will be able to continue as a going concern and contemplates the realization of assets and satisfaction of liabilities in the normal course of business, and does not include any adjustments to reflect the possible future effects on the recoverability and classification of assets or the amounts and classifications of liabilities that may result from uncertainty related to the Company’s ability to continue as a going concern.
Use of Estimates
The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2019 and 2018
(in thousands)
statements and the reported amounts of revenue and expenses during the reporting period. Management bases its estimates on historical experience and on various other assumptions that are believed to be reasonable under the circumstances. Significant estimates include the estimated contingent revenues recognized related to revenues recognized at a point-in-time, the estimated useful lives associated with REF Facilities and assumptions associated with asset retirement obligations ("ARO"(“ARO”). and the final realization of remediation efforts, and the estimate for any outstanding contingent liabilities. Ultimate realization of assets and settlement of liabilities in the future could differ from thosethese estimates.
During the third quarter of 2019, the Company reevaluated the estimated useful life of its REF Facilities. As a result, the Company determined that the estimated useful life of the REF Facilities should be reduced from 20 years as originally estimated to the remainder of the 10 year period from the date the REF Facility was originally placed in service. The Company accounted for the change in the useful life of the REF Facilities as a change in accounting estimate beginning August 1, 2019. The impact of the change in estimate resulted in a decrease in net income of $11,644 for the year ended December 31, 2019.
Cash and Cash Equivalents
The Company considers all highly liquid investments with original maturities of three months or less to be cash equivalents. The carrying value approximates fair value due to the short-term nature of these instruments. The Company maintains its cash and cash equivalents in accounts with a local financial institution. These accounts at times may exceed federally insured limits. The Company has not experienced any losses in these accounts and believes it is not exposed to any significant credit risk related to cash and cash equivalents.
Accounts Receivable
Accounts receivable consist primarily of payments due from TP Investors that own or lease the REF Facilities. The carrying amount of accounts receivable may be reduced by a valuation allowance that reflects management's best estimate of amounts that will not be collected. Under the Company’s agreements, interest can accrue on delinquent balances. No interest on delinquent balances was recorded for the years ended December 31, 20192021 and 2018.2020. Any allowance for doubtful accounts is based on management’s assessment of the collectability of specific customer accounts and the aging of the accounts receivable. If there is a deterioration of a major customer’s credit worthiness or actual defaults are higher than the historical experience, management’s estimates of the recoverability of amounts due to the Company could be adversely affected. As of December 31, 20192021 and 2018,2020, no allowance for doubtful accounts was considered necessary.
Inventory
Inventory is comprised primarily of feedstock fuel and chemicals used in the production and sale of REF at REF Facilities. Inventory is valued at the lower of cost or net realizable value using the average cost method.
Fixed Assets
Fixed assets are stated at historical cost less accumulated depreciation and consist primarily of the REF Facilities and ancillary equipment, including major additions and improvements. Expenditures for major improvements are capitalized, while maintenance and repair costs that do not significantly improve the related asset or extend its useful life are charged to expense as incurred. For financial reporting purposes, depreciation is calculated using the straight-line method over the estimated useful lives of the assets ranging from 3 to 10 years.
The Company records an ARO liability equal to the fair value of the estimated cost to retire a REF Facility. The ARO liability is initially recorded in the period in which the obligation meets the definition of a liability, which is generally when a REF
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2021 and 2020
(in thousands)
Facility is installed at a generation station ("Site"). The ARO liability is estimated by the Company based on legal removal requirements, historical removal experience, and anticipated future inflation rates. When the liability is initially recorded, the Company increases the carrying amount of the related long-lived asset by an amount equal to the original liability. The liability is increased over time to reflect the change in its present value, and the capitalized cost is depreciated over the useful life of the related long-lived asset. The ARO liability is removed when the Company is relieved of its removal obligation due to either completion of the removal activities at a generation stationSite or a transfer of the responsibility for the REF Facility removal to a third party. The Company reevaluates the adequacy of its recorded ARO liability at least annually. Actual costs of asset retirements, such as removing the REF Facility from a generation stationSite and related siteSite restoration, are charged against the related liability. Any difference between
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2019 and 2018
(in thousands)
costs incurred upon settlement of an ARO and the recorded liability is recognized in other expense as a gain or loss in the Company’s consolidated statements of operations.
Intangible Assets
Tinuum has two exclusive licenses from ADA for the patented and proprietary “CyClean™”"CyClean™" and “M-45™”"M-45™" technologies related to the production of REF. The patents underlying the CyClean™ technology license expire beginning in 2021; however, the license agreement includes potential future patents related to the technology. The costs associated with the exclusive CyClean™ license are included in other assets, net on the consolidated balance sheets and are being amortized over the useful economic life of the technology, or approximately 14 years, using the straight-line method. Amortization expense was $0 and $5 for each of the years ended December 31, 20192021 and 2018.2020, respectively.
Impairment of Long-Lived Assets
The Company reviews long-lived assets for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to future undiscounted net cash flows expected to be generated by the asset. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the fair value of the assets. Assets to be disposed of are reported at the lower of carrying amount or fair value less costs to sell. AtAs part of the Company’s on-going monitoring of its REF Facilities, the Company evaluated the REF Facility assets for potential impairment as of December 31, 20192020. Given the expiration of the original PTC period, December 31, 2021, and 2018, there were no such impairments.
Adoptionthe fact that the Company does not have an expectation of New Accounting Policies
Leases
Tinuum elected to early adopt ASC 842, Leases (“ASC 842”), effective January 1, 2019, concurrentadditional future cash flows associated with the adoptionREF Facilities beyond the PTC period, any REF Facilities that had not been invested by TP Investors have been considered to be impaired. Impairment was assessed based upon the future undiscounted cash flows of ASC 606, Revenue from Contracts with Customers ("ASC 606").each REF Facility as compared to its net book value. As a result, the Company on January 1, 2019, recognized right-of-use (“ROU”) assetsan impairment loss of $15 and lease liabilities on a modified retrospective basis. The practical expedients known as the “package of practical expedients or Group of 3” permit companies to retain prior conclusions about lease identification, lease classification and initial direct costs. The Company did not elect the “package of practical expedients” and thus has reassessed its contracts (both as lessee and lessor) under the updated ASC 842 criteria. Tinuum did elect the use-of hindsight practical expedient as it relates to the assessment of lease or contract terms.
Lessee contracts
In contracts where the Company is a lessee, each contract was reassessed using the new lease criteria and the Company identified operating and financing leases primarily related to its office space and office equipment. Tinuum’s accounting for finance leases, previously known as capital leases, remained substantially unchanged. Tinuum recognized ROU assets of $750 and an operating lease liability of $816 for operating leases and derecognized $66 of deferred rents on January 1, 2019.
The Company determines if a contractual arrangement is a lease at inception. Effective January 1, 2019, operating leases are included in the ROU assets within fixed assets, net; and lease liabilities are included within accrued liabilities, on the consolidated balance sheets.
Lessor contracts
Under ASC 842, the definition of a lease was modified to include the right to control the use of an identified asset. Utilizing the revised definition of a lease under ASC 842, the Company has reassessed its existing revenue generating contracts which include leases (“Leases”), membership interest purchase agreements (“MIPAs”) and asset purchase agreements ("APAs"). These contracts have historically been accounted for as leases under ASC 840, Leases ("ASC 840"), or via analogy based upon other accounting guidance that was superseded by the issuance of the ASC 606 guidance. As a result of this reassessment, the Company determined that the contracts previously accounted for as leases under ASC 840 no longer meet the control criteria of a lease and the MIPAs and APAs, previously accounted for via analogy to ASC 840, were required to be analyzed and recorded utilizing the guidance in ASC 606.
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2019 and 2018
(in thousands)
Revenues
On January 1, 2019 the Company adopted ASC 606, using the modified retrospective method. Comparative information has not been restated and continues to be accounted for under the historical revenue recognition accounting standards in effect for those periods. The Company recorded the cumulative effect of initially applying the new revenue standard as an adjustment to the opening balance of Members’ equity.
As part of the adoption of ASC 606, the Company elected the following transition practical expedients: (i) to reflect the aggregate of all contract modifications that occurred prior to the date of initial application when identifying satisfied and unsatisfied performance obligations, determining the transaction price, and allocating the transaction price, and (ii) to apply the standard to all contracts at the date of initial application. Because contract modifications are minimal, there was not a significant impact as a result of electing these practical expedients.
The adoption of ASC 606 primarily impacted the revenues previously recorded as lease revenue associated with APAs that previously were accounted for under ASC 360-20, Property, Plant and Equipment - Real Estate Sales (“ASC 360-20”), which had required the Company to evaluate whether such arrangements had any forms of continuing involvement that may have affected the revenue or profit recognition of these transactions. When such forms of continuing involvement were present, revenues were recognized in a manner similar to an operating lease.
The adoption of ASC 606, which superseded the real estate sales guidance under ASC 360-20, generally requires revenue to be recognized for APAs earlier than what Tinuum’s historical practice had been. Under ASC 606, revenue for APA transactions is recognized$2,968 as of a “point-in-time” when control ofand for the years ended December 31, 2021 and 2020, respectively.
Revenue Recognition
REF Facility transfers to the customer, rather than ratably over time.Facilities
At contract inception, under ASC 606, theThe Company identifies performance obligations by reviewing the combination of customer agreements for material distinct goods and services. Goods and services are distinct when the customer can benefit from them on their own and the promises to transfer these items are separately identifiable from other promises within the contract. When the Company is contracted to provide a single promise (an integrated system), it is treated as a single performance obligation as goods and services are provided with the same pattern of transfer. The Company has identified the provision of the technology sublicense combined with the use of the REF Facility to be a single performance obligation.
Commencing January 1, 2019, REF Facility revenues are recognized based upon the type of contract with the TP Investor. Generally, the Company has three types of contracts with customers (a) Leases, (b) MIPAsMember Interest Purchase Agreements ("MIPAs") and (c) APAs.Asset Purchase Agreements ("APAs"). In all instances the contracts relate to the use of the REF Facility and the related sublicensed patented technology which is necessary for each Producer Entity to produce REF utilizing the REF Facilities.Facility.
Depending upon the agreement, the Company may receive fixed payments or a combination of fixed and variable payments over the contract term. Variable payments are determined based upon the expected amount of REF production during the defined period. Certain prepayments are received upon execution of TP Investor agreements. Significant judgments and estimates are used in the Company’s revenue policies. Throughout the revenue cycle, the Company evaluates contractual evidence, monitors performance and evaluates variable consideration changes.
For the Leases and MIPA contracts,MIPAs, revenue is recognized “over time” using the output method, utilizing actual REF production volumes. In these agreements where a prepayment is received, that amount is recorded as deferred revenue and is amortized
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2021 and 2020
(in thousands)
into revenue in accordance with the amortization period of the respective TP Investor agreement. Contingent consideration associated with Leases or MIPAs is recorded based upon actual REF production volumes achieved, constrained by any contractual limitations or by production volumes that management estimates could occur.
Revenues recorded related to the APAs are recorded when the Company has completed delivery of the REF Facility and has transferred title and control of the REF Facility to the TP Investor. These revenues are recognized at a “point-in-time” based upon the net present value of the expected fixed purchase payments plus management’s estimate of any variable payments associated with the sale. Additionally, since the payments are made quarterly over a time period exceeding one year, a financing component exists to these transactions. InterestFor the years ended December 31, 2021 and 2020, interest recorded related to these contracts was $541 and $1,619, respectively, and is recorded as interest income in the statement of operations and was $2,346 for the year ended December 31, 2019. operations.
As a result of the recording of APA revenues as of a point-in-time, future cash flows will be received according to the contractual payment schedules, but no future revenues, other than changes in estimates,
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2019 and 2018
(in thousands)
will be recognized for these contracts. Changes in estimates for variable consideration can occur for a variety of reasons, including but not limited to (i) annual inflation adjustment factors being different from what was originally estimated and (ii) changes in actual versus expected production volumes of REF. For the years ended December 31, 2021 and 2020, the impact of the change in estimate resulted in a decrease in revenues of $2,643 and $1,129, respectively.
Generally, the REF Facility is collateral for the outstanding contract receivable balances recorded by Tinuum.
The Company recognizes a contract receivable when the Company transfers control of a REF Facility to the customer in advance of receiving consideration. Contracts with variable consideration are billed quarterly in arrears, once production volumes are known, under similar payment terms.
Reduced Emissions and Unrefined Fuel
The Company’s consolidated VIEs, which are Producer Entities, purchase and take title to feedstock fuel under purchase agreements with each respective Generator or other supplier of feedstock fuel. Each Producer Entity purchases chemicals from third-party vendors and applies them to the feedstock fuel to produce REF utilizing the REF Facility. The REF is sold by the Producer Entities, under REF sale agreements, to a Generator or to another third party at the discretion of the manager of each Producer Entity, as permitted under the applicable Generator agreements. The Company performs REF recertification or redetermination testing periodically as required by Section 45 with respect to production and sale of REF at each of its REF Facilities. During the years ended December 31, 2021 and 2020, each of the Producer Entities sold all of its REF and unrefined fuel (coal untreated but part of the REF process) to third parties that used the fuel to generate electricity and recorded such amounts as reduced emissions and unrefined fuel revenues.
Each VIE utilizes the combination of the REF Facility and the technology license to combine raw materials (feedstock coal and chemicals) to produce REF which is then sold as a separate manufactured product to its customer, the Generator. As a result, the Company recognizes both REF Facility revenues and reduced emissions and unrefined fuel on a gross basis.
An accounts receivable balance represents the Company’s right to consideration that is unconditional and only the passage of time is required before payment of that consideration is due. No allowance for doubtful accounts related to accounts receivable balances or impairment of contract receivables has been recorded as of December 31, 2021 and 2020.
Deferred revenue is recognized when the Company receives consideration in advance of performance.
Prior to adoption of ASC 606, under certain REF Facility transactions, an initial deposit or prepayment was received. Any prepayments received were recorded as deferred revenue and were amortized into revenue under the straight-line method over the amortization period defined in the respective agreement. As of December 31, 2018, the Company recorded $34,626 of deferred revenue related to prepayments.
The Company disaggregates revenue based upon the revenue recognition methodology (over time vs. point-in-time). The following table represents a disaggregation of revenue from contracts with customers for the year ended December 31, 2019 compared with the revenue that would have been recognized prior to the adoption of ASC 606.
|
| | | | | | | | | | | | |
| Statement of Operations | | As Reported | | Adjustments | | Balance without ASC 606 Adoption |
| REF Facility revenues - point-in-time | | $ | 45,608 |
| | $ | (45,608 | ) | | $ | — |
|
| REF Facility revenues - over time | | 142,028 |
| | 47,954 |
| | 189,982 |
|
| Interest income | | 2,526 |
| | (2,346 | ) | | 180 |
|
|
| | | | | | | | | | | | |
| Balance Sheet | | As Reported | | Adjustments | | Balance without ASC 606 Adoption |
| Contract receivables | | $ | 94,503 |
| | $ | (94,503 | ) | | $ | — |
|
| Contract costs | | 26,729 |
| | (26,729 | ) | | — |
|
| Interest receivable, within other current assets | | 541 |
| | (541 | ) | | — |
|
| Deferred revenues | | 9,810 |
| | 36,367 |
| | 46,177 |
|
Significant judgments and estimates are used in the Company’s revenue policies. Throughout the revenue cycle, the Company evaluates contractual evidence, monitors performance and evaluates variable consideration changes.
Taxes assessed by a governmental agency that are imposed on and concurrent with a specific revenue producing transaction collected by the Company from a customer are excluded from revenues.
Shipping and handling costs are not associated with Tinuum’s products and services and therefore are not included in revenues or costs of revenues.
No amounts have been recorded for returns, refunds, or other similar obligations.
Impact of ASC 606 and ASC 842 Adoption
The cumulative effect of the changes made to the consolidated balance sheet for the adoption of ASC 606 and ASC 842 on January 1, 2019 were as follows (in thousands):
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2019 and 2018
(in thousands)
|
| | | | | | | | | | | | | | | | |
| | | Balance at December 31, 2018 | | Adjustments Due to ASC 606 | | Adjustments Due to ASC 842 | | Balance at January 1, 2019 |
| Assets | | | | | | | | |
| Contract receivables | | $ | — |
| | $ | 87,116 |
| | $ | — |
| | $ | 87,116 |
|
| Interest receivables, within other current assets | | — |
| | 1,377 |
| | — |
| | 1,377 |
|
| Fixed assets, net | | 75,206 |
| | (11,910 | ) | | — |
| | 63,296 |
|
| ROU asset | | — |
| | — |
| | 750 |
| | 750 |
|
| | | | | | | | | |
| Liabilities | | | | | | | | |
| Deferred revenues | | $ | 34,626 |
| | $ | (11,021 | ) | | $ | — |
| | $ | 23,605 |
|
| Accrued expenses - | | | | | | | | |
| Operating lease liability | | — |
| | — |
| | 816 |
| | 816 |
|
| Deferred operating lease rents | | 66 |
| | — |
| | (66 | ) | | — |
|
| | | | | | | | | |
| Members' Equity | | $ | 82,595 |
| | $ | 87,604 |
| | $ | — |
| | $ | 170,199 |
|
Income Taxes
The Company, with the consent of its Members, has elected to be taxed under applicable sections of federal and state income tax laws as a limited liability company treated as a partnership for income tax purposes. As a result of this election, no federal income taxes are incurred by the Company. Instead, the Members are liable for income taxes on their pro rata share of the Company's income, deductions, losses, and credits. In certain states, the Company is taxed based upon shareholder equity or other enterprise considerations. In these instances, the Company records and pays the applicable tax directly to the state agency.
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2021 and 2020
(in thousands)
One of the Company’s consolidated VIEs has elected to be a C corporation for federal and state income tax purposes. As a result, that VIE’s income tax provision and related deferred tax assets and liabilities are included within the consolidated financial statements.
Deferred income taxes are provided for temporary differences arising from differences between the financial statement amount and tax basis of assets and liabilities existing at each balance sheet date, using enacted tax rates anticipated to be in effect when the related taxes are expected to be paid. A valuation allowance is established if it is more likely than not that a deferred tax asset will not be realized. The Company includes interest and penalties related to state tax as a component of income tax expense.
The Company applies the requirement of ASC 740, Income Taxes, related to accounting for uncertain tax positions.
Reclassifications
Certain reclassifications have been made toIn January 2021, the prior years’ financial statements to conform toCompany was notified that one of its consolidating VIEs was selected for audit by the current year presentation. These reclassifications hadIRS. Tinuum is the partnership representative and cooperated with the IRS audit requirements. The audit was completed by the IRS during 2021 with no effect on previously reported results of operations or Members’ equity.proposed adjustments.
Recent Accounting Pronouncements
In June 2016, the FASB issued ASU 2016-13, Financial Instruments - Credit Losses(Topic 326): Measurement of Credit Losses on Financial Instruments (“ASU 2016-13”). This ASU provides guidance for recognizing credit losses on financial instruments based on an estimate of current expected credit losses model. The FASB subsequently issued ASU 2019-04, Codification Improvements to Topic 326, Financial Instruments - Credit Losses, Topic 815, Derivatives and Hedging, and Topic 825, Financial Instruments and ASU 2019-11, Codification Improvements to Topic 326, Financial Instruments - Credit Losses to clarify and address certain items related to the amendments in ASU 2016-13. ASU 2019-10, Financial Instruments - Credit Losses (Topic 326), Derivatives and Hedging (Topic 815) and Leases (Topic 842) amends the mandatory effective date for ASU 2016-13. The
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2019 and 2018
(in thousands)
amendments are effective for fiscal years beginning after December 15, 2022 for private companies. Although the impact upon adoption will depend on the financial instruments held by the Company at that time, the Company does not anticipate a significant impact on its consolidated financial statements.
In October 2018, the FASB issued ASU 2018-17, Consolidation: Targeted Improvements to Related Party Guidance for Variable Interest Entities, which modifies the guidance related to indirect interests held through related parties under common control for determining whether fees paid to decision makers and service providers are variable interests. The guidance is effective for annual reporting periods beginning after December 15, 2019 and early adoption is permitted. The Company does not expect this standard tobelieve that there are any new accounting pronouncements that have been issued that might have a material impact on the Company’s consolidatedits financial statements.position or results of operations.
NOTE 2 - FIXED ASSETS
Reduced Emissions Fuel Facilities
Each of the REF Facilities and related components that were placed in service by the Company in 2009 and 2011 have demonstrated the qualified emissions reductions to qualify for PTCs. REF Facilities are stated at historical cost. Depreciation is calculated using the straight-line method over a 10-year10 year period, commencing with the original placed in service date in 2009 or 2011, as appropriate. The twodate. All REF Facilities originally placed in service in 2009 were fully depreciated as of December 31, 2019.2021.
Furniture, Fixtures and Equipment
Furniture, fixtures, and equipment is comprised of office furniture, fixtures and office equipment, including those under finance leases. These assets are recorded at cost and depreciated using the straight-line method with estimated useful lives ranging from 3 to 8 years.
The following table summarizes the components of gross and net carrying amounts for fixed assets as of December 31, 2021 and 2020:
| | | | | | | | | | | | | | |
| | 2021 | | 2020 |
| REF Facilities and related equipment | | $ | 73,649 | | | $ | 91,399 | |
| Assets associated with removal obligations | | 1,059 | | | 1,637 | |
| Furniture, fixtures, equipment and other | | 1,369 | | | 1,397 | |
| ROU assets | | 703 | | | 711 | |
| | | | |
| | | | |
| Accumulated depreciation | | (75,956) | | | (67,668) | |
| Impairment reserve | | (604) | | | (2,968) | |
| Fixed assets, net | | $ | 220 | | | $ | 24,508 | |
Depreciation expense was $24,101 and $28,175, for the years ended December 31, 2021 and 2020, respectively.
During 2021 the Company reevaluated certain REF Facility equipment for which an impairment reserve had been recognized in 2020. Certain REF Facility equipment was either disposed of or sold, resulting in an adjustment to the impairment reserve.
Under the site license agreements between the Producer Entities or Tinuum and the Generators, Tinuum may be required to return the siteSite upon which the REF Facility is located at a Site to its original condition at the end of the applicable contract period. In instances where the applicable agreements place this responsibility on the Company, the Company has recorded a liability for an ARO equal to the fair value of the estimated cost to retire the REF Facility and return each Site to its original condition. The ARO liability was estimated by the Company using estimated and historical facility removal costs and anticipated future inflation rates. This estimated future value was discounted to its present value using the Company’s credit-adjusted risk-free
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2021 and 2020
(in thousands)
rate. The carrying value of the asset is depreciated on a straight-line basis over the remaining estimated life of the REF Facility asset group. The ARO liability is increased over time to reflect the change in its present value, and the capitalized cost is depreciated over the useful life of the site license. In subsequent periods, the Company is required to make adjustments to AROs based on changes in the estimated fair values of the obligations. Corresponding increases in asset book values are depreciated over the remaining useful life of the related site license. Uncertainties as to the probability, timing, or amount of cash flows associated with AROs may affect management’s estimates of fair value. For the years ended December 31, 20192021 and 2018,2020, within operating expenses, the Company recorded $134$399 and $115$184 of accretion expense, respectively.
The following table describes changes to the Company’s ARO liability for the years ended December 31, 20192021 and 2018:2020:
| | | | | | | | | | | | | | |
| | 2021 | | 2020 |
| Beginning balance | | $ | 2,070 | | | $ | 1,449 | |
| Liabilities incurred, net | | — | | 631 |
| Gain on removal of liability | | (131) | | (194) | |
| Accretion | | 399 | | 184 |
| Settlement of obligations | | (543) | | — |
| Ending balance | | $ | 1,795 | | | $ | 2,070 | |
|
| | | | | | | | |
| | | 2019 | | 2018 |
| Beginning balance | | $ | 1,304 |
| | $ | 1,066 |
|
| Liabilities incurred, net | | 370 |
| | 153 |
|
| Removal of liability | | (129) |
| | — |
|
| Accretion | | 134 |
| | 115 |
|
| Settlement of obligations | | (230) |
| | (30) |
|
| Ending balance | | $ | 1,449 |
| | $ | 1,304 |
|
Furniture, Fixtures and Equipment
Furniture, fixtures, and equipment is comprised of office furniture, fixtures and office equipment, including those under finance leases. These assets are recorded at cost and depreciated using the straight-line method with estimated useful lives ranging from 3 to 8 years.
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2019 and 2018
(in thousands)
The following table summarizes the components of gross and net carrying amounts for fixed assets as of December 31, 2019 and 2018:
|
| | | | | | | | |
| | | 2019 | | 2018 |
| REF Facilities and related equipment | | $ | 86,832 |
| | $ | 101,559 |
|
| Assets associated with removal obligations | | 1,129 | | 1,304 |
|
| Furniture, fixtures and equipment | | 1,045 | | 1,091 |
|
| ROU assets | | 702 |
| | — |
|
| Other | | 369 |
| | 348 |
|
| Accumulated depreciation | | (39,754) |
| | (29,096) |
|
| Fixed assets, net | | $ | 50,323 |
| | $ | 75,206 |
|
Depreciation expense was $16,356 and $5,034, for the years ended December 31, 2019 and 2018, respectively.
NOTE 3 - INVENTORY
Inventory is comprised primarily of feedstock fuel and chemicals used in the production and sale of REF at REF Facilities. Inventory is valued at the lower of cost or net realizable value using the average cost method. The Company assesses the inventory valuation on a monthly basis and reduces the value for any obsolete inventory. No valuation allowance was considered necessary as of December 31, 20192021 and 2018.2020.
| | | | | | | | | | | | | | |
| | 2021 | | 2020 |
| Feedstock fuel | | $ | — | | | $ | 12,707 | |
| Chemicals | | — | | 1,023 |
| Total inventory | | $ | — | | | $ | 13,730 | |
|
| | | | | | | | |
| | | 2019 | | 2018 |
| Feedstock fuel | | $ | 11,187 |
| | $ | 14,150 |
|
| Chemicals | | 679 |
| | 482 |
|
| Total inventory | | $ | 11,866 |
| | $ | 14,632 |
|
NOTE 4 - REVENUES
REF Facility Revenues
As discussed in Note 1, revenue is recognized when a performance obligation is satisfied. The Company’s contracts can contain both fixed and variable components of the transaction price. Each contract is evaluated for these components and may be determined to include fixed consideration, variable consideration and financing components as part of the overall transaction price. The Company receives payments from customers based upon specific payment schedules established under each contract. Payment schedules can include a combination of down payments,prepayments, fixed payments and variable payments, based upon expected production volumes, and are generally made quarterly.
When a contract is determined to contain variable consideration, the transaction price is estimated using the expected value (i.e., the most likely amount method) to predict revenue for that contract. These variable amounts are estimated at contract inception based upon the projected REF production volumes associated with the specific Generator location. Estimated amounts are included in the transaction price to the extent it is probable that a significant reversal of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is resolved. Estimates of variable consideration are estimated based upon contractual terms, historical experience and projected REF production volumes.
Changes in estimates for variable consideration can occur for a variety of reasons, including but not limited to (i) annual inflation adjustment factors being different from what was originally estimated and (ii) changes in actual versus expected production volumes of REF. Changes in estimates may have a material effect on our consolidated statements of operations.
Eight and eleven, respectively, of theNine REF Facility transactions with TP Investors are transactions with a related party as of December 31, 20192021 and 2018.2020. These transactions generally have terms that extend to the date ten years after the placed in service date for
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2019 and 2018
(in thousands)
the particular REF Facility, subject to earlier termination by the TP Investor at periodic intervals or upon the occurrence of specified events. During 2019, twoAs of theseDecember 31, 2021 all transactions were terminated aswith a result of the Generators closing their coal-fired generation station and one additional transaction expired as that particular REF Facility met its date that was ten years after its place in service date.related party TP Investor had been terminated.
Under the various TP Investor agreements, Tinuum has committed to provide the REF Facility and the related sublicense for a term as identified in each contract. Most of the agreements expireexpired in 2021 or will expire by the first quarter of 2022. Generally, payments are made quarterly to Tinuum on a net 10 to 30 days basis, in advance of the respective quarter. Contracts with variable consideration are billed quarterly in arrears, once production volumes are known, under similar payment terms. No allowance for doubtful accounts related to accounts receivable balances or impairment of contract receivables has been recorded as of December 31, 2019 and 2018.
The opening and closing balances of the Company’s contract receivables and deferred revenues are as follows:
|
| | | | | | | | | | | | |
| | | Contract Receivables | | Deferred Revenue (current) | | Deferred Revenue (long-term) |
| Opening (January 1, 2019) | | $ | 87,116 |
| | $ | 22,566 |
| | $ | 1,039 |
|
| Closing (December 31, 2019) | | 94,503 |
| | 9,810 |
| | — |
|
| Increase/(decrease) | | $ | 7,387 |
| | $ | (12,756 | ) | | $ | (1,039 | ) |
TINUUM GROUP, LLC AND SUBSIDIARIES
The amounts of revenue recognized in the period that were included in opening deferred revenues current and long-term balances were $21,890 and $1,039, respectively. The differences between the opening and closing balances of the Company’s contract receivables and deferred revenues primarily result from the timing differences between the customers’ payment and the Company’s delivery of the performance obligation.NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The following is an estimate of the cash flows expected to be received from TP Investors through DecemberDECEMBER 31, 2021 assuming no variations and 2020
(in estimated production volumes, no modifications of payments, non-renewals or early terminations of contracts. It is possible that future payments from TP Investors may be modified or reduced. thousands)
Future REF Facility payments, including any eliminated in consolidation, are based on the estimated2021 levels of REF production. No estimated amounts related to point-in-time revenues have been included below:
|
| | | | |
| 2020 | | $ | 160,832 |
|
| 2021 | | 146,674 |
|
| Thereafter | | 9,074 |
|
| | | $ | 316,580 |
|
In December 2019, the Company agreed to provide a future price concession to a significant customer. A portion of the price concession is to bewas provided via a note payable (“Customer Note”) under which the Company willwould make monthly principal and interest payments to the customer commencing in January 2020 and continuing through March 2021. The Customer Note iswas $27,000 and the Company has recorded the amount as contract costs on the consolidated balance sheet and has allocated the payments to the customer as a reduction to the transaction price of the existing contracts with the customer. The reduction in the transaction price is beingwas recorded monthly, commencing with the contract date of December 2019 through the end of the term of the payments of March 31, 2021. The reduction in the transaction price is recorded as production volumes are achieved (over time). DuringFor the yearyears ended December 31, 2019,2021 and 2020, the Company reduced revenues were reduced by $871 under this price concession contract.contract by $5,226 and $20,903, respectively.
In certain instances, the Company employs outside parties to facilitate the commencement of a Lease, MIPA or APA transaction. Under these agreements, the Company typically pays the outside party a fee ("Fee"(“Fee”) relative to either the collection of revenues by the Company or the REF production volumes achieved. Under the Lease and MIPA transactions, any related contract costs are recorded as the production volumes or collection of revenues are achieved. These amounts are recorded as a component of cost of goods sold. Under the APA agreements, the Fees are capitalized as contract costs based on the estimated revenues recognized
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2019 and 2018
(in thousands)
at the commencement of the contract and are amortized as a reduction of revenue over the period of benefit. As ofFor the years ended December 31, 2019,2021 and 2020, Fees included in contract costs on the consolidated balance sheet were $600.$0 and $315, respectively.
Reduced Emissions and Unrefined Fuel Revenues
The Company’s consolidated VIEs, which are Producer Entities, purchase and take title to feedstock fuel under purchase agreements with each respective Generator or other supplier of feedstock fuel. Each Producer Entity purchases chemicals from third-party vendors and applies them to the feedstock fuel to produce REF utilizing REF Facilities. The REF is sold by the Producer Entities, under REF sale agreements, to a Generator or to another third party at the discretion of the Manager of each Producer Entity, as permitted under the applicable Generator agreements. The Company performs REF recertification or redetermination testing periodically as required by Section 45 with respect to production and sale of REF at each of its REF Facilities. During the years ended December 31, 2019 and 2018, each of the Producer Entities sold all of its REF and unrefined fuel (coal untreated but part of the REF process) to third parties that used the fuel to generate electricity and recorded such amounts as REF and unrefined fuel revenues.
Each VIE utilizes the combination of the REF Facility and the technology license to combine raw materials (feedstock coal and chemicals) to produce REF which is then sold as a separate manufactured product to its customer, the Generator. As a result, the Company recognizes both REF Facility revenues and reduced emissions and unrefined fuel on a gross basis.
NOTE 5 - VARIABLE INTEREST ENTITIES
TheFor the years ended December 31, 2021 and 2020, the Company consolidates sevennine entities (the “TG VIEs”) that were created as REF production companies. The operations include the purchase of feedstock fuel from a Generator, application of chemicals utilizing that Producer Entity’s REF Facility, and the subsequent sale of REF to the Generator. In sixall nine of the TG VIEs, CCS-AE, LLC (“CCS-AE”), a subsidiary of the Company, or another Tinuum entity is the manager (“Managing MemberMember”) and holds a 0.2% or 1.0% member interest, depending on the transaction. In the remaining TG VIE, TG has retained a 49.9% member interest and Tinuum is the manager. As the Managing Member of the TG VIEs, CCS-AE or Tinuum directs the activities that are considered most significant to the entities. Based upon the criteria set forth in ASC 810, the Company has determined that it is the primary beneficiary in the TG VIEs for the years ended December 31, 20192021 and 2018.2020. As such, the financial results of the TG VIEs are consolidated with the results of the Company, and the results attributable to the other owners are presented as noncontrolling interests within the consolidated financial statements.
Creditors of the TG VIEs have no recourse against the general credit of the Company (outside of its member interest or specific guarantee obligations) and the assets of the Company are not collateral for any TG VIE obligations. The operations of all sevennine entities are financed through capital calls of the respective members in proportion to their member interests. In the event that a member defaults on a capital call request made by the Managing Member, the Managing Member may (i) withhold distributions payable to the defaulting member or sue for the amount due, and/or (ii) elect to transfer the defaulting member’s interest to a separate legal entity controlled by the Managing Member, or (iii) suspend operations of the REF Facility. In certain instances, the TP Investor has the ability to put, and Tinuum has the ability to call, the other member interests at a purchase price equal to fair market value.
Under the provisions of certain of the TG VIEs’ various agreements, including the leases of REF Facilities or the partnership operations of the TG VIEs, the agreements terminate during time periods ranging from the fourth quarter of 2021 through December 31, 2022, unless terminated earlier by written consent of the members.
Under certain of the TG VIE agreements, capital call limitations exist, limiting the amount of capital calls if certain operational costs are exceeded.
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2019 and 2018
(in thousands)
NOTE 6 - NOTES PAYABLE
Line of Credit
In September 2019, the 2013 Revolver (“Revolver”) with BOK Financial (“BOK”), was amended and replaced with the Fifth Amendment to the Revolver (“Fifth Amendment”). The Fifth Amendment expired on December 31, 2020 and was not renewed and all balances were fully repaid. Under the Fifth Amendment, prior to expiration, the available borrowing limit was reduced to:was:
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2021 and 2020
(in thousands)
|
| | | | |
| | | Available Borrowing Limit |
| For the period ending December 30, 2019 through September 29, 2020 | | $ | 7,000 |
|
| For the period commencing September 30, 2020 through December 30, 2020 | | $ | 3,400 |
|
| For the period after December 31, 2020 | | $ | — |
|
| | | | | | | | |
| | Available Borrowing Limit |
| For the period ending December 30, 2019 through September 29, 2020 | | $ | 7,000 | |
| For the period commencing September 30, 2020 through December 30, 2020 | | $ | 3,400 | |
| For the period after December 31, 2020 | | $ | — | |
| | |
| | |
| | |
The Fifth Amendment also requiresrequired any outstanding borrowings to be fully repaid for a period of fifteen consecutive days during two non-consecutive calendar quarters.
Amounts outstanding under the Fifth Amendment may bewere repaid at the option of the Company. Any undrawn balance isduring the years ended December 31, 2020, was subject to a quarterly unused facility fee in the amount of 0.826% annually. Interest on outstanding balances iswas payable monthly and iswas accrued at the greater of 5.5% per annum or the prime rate (as defined in the agreement) plus 1.0%.
The Fifth Amendment iswas collateralized by the assets of the Company and the equity interests and proceeds related to such equity interests of each material subsidiary owned by the Company. The Fifth Amendment iswas also collateralized by the Company’s deposit accounts held at BOK. These accounts arewere not restricted by the Fifth Amendment.
Tinuum is required to be in compliance with certain covenants under the Fifth Amendment, including tangible net worth as defined in the agreement. As of December 31, 2019, and 2018, the Company was in compliance with the loan covenants. As of December 31, 2019 and 2018, respectively, the outstanding balance on the Revolver was $5,500 and $0.
Customer Note
As mentioned in Note 4, in December 2019, the Company agreed to provide a future price concession to a significant customer via a Customer Note. The Company will makemade monthly principal and interest payments to the customer commencingcustomer. Payments commenced in January 2020 and extended through March 2021. The2021, when the Customer Note amount is $27,000 andwas fully repaid. As of December 31, 2020, the Company has recorded the amount due to the customer as short-term and long-term notes payable in the consolidatedCustomer Note balance sheets.was $5,400. The Customer Note bears interest at 8% per annum.
Under the Customer Note, Tinuum has agreed to maintain a Cash Reserve Account of $3,000, to limit additional indebtedness to $7,000 (plus amounts to finance Company insurance premiums plus a maximum of $500 for finance leases) and to maintain compliance with certain loan covenants. At December 31, 2019,2020, the Company was in compliance with the loanCustomer Note covenants.
Secured promissory notePromissory Note
In February 2014, a VIE consolidated into the consolidated financial statements of the Company, entered into an $11,000 secured promissory note (the “Note”) with a Generator from which it purchases feedstock fuel, and to which it sells reduced emissions and unrefined fuel on a monthly basis. The purpose of the Note is to finance the purchases of feedstock fuel from the Generator. The amount of principal and interest owed is dependent upon the amount of feedstock fuel purchased and reduced emissions and unrefined fuel sold between the two parties and is net settled on a monthly basis. The Note iswas collateralized by the feedstock fuel inventory.
The Note bears interest at a per annum rate equal to the short-term applicable federal rate announced by the IRS in December of each year. The interest rate for the years ended December 31, 20192021 and 20182020 was 2.72%0.14% and 1.68%1.60% per annum, respectively. Interest is payable quarterly in arrears.
All outstanding amounts owed under the Note are due and payable on the earlier of December 31, 2021 or the termination or expiration of the Feedstock Coal Purchase Agreement between the TG VIE and the Generator.
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER The Note was fully repaid as of December 31, 2019 and 2018
(in thousands)
2021.
As of December 31, 2019,2021 and 2018,2020, respectively, the outstanding balance on the Note was $4,505$0 and $7,736$4,327 with interest payable of $32$0 and $40.$16, respectively.
In June 2018, a second VIE consolidated into the consolidated financial statements of the Company, entered into an $1,986 secured promissory note (“2018 Note”) with a Generator to fund the initial purchase of feedstock fuel. The 2018 Note bears interest at a per annum rate equal to the mid-term applicable federal rate announced by the IRS in December of each year. The rate was 3.03%0.48% and 2.82%1.67% for the years ended December 31, 20192021 and 2018,2020, respectively. Interest is payable quarterly in arrears. The 2018 Note is collateralized by the feedstock fuel inventory.
All outstanding amounts owed under the 2018 Note are due and payable on the earlier of December 31, 2025, or the termination or expiration of the Feedstock Coal Purchase Agreement between the Company and the Generator.
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2021 and 2020
(in thousands)
As of December 31, 20192021 and 2018,2020, respectively, the outstanding balance on the Note was $0 and $1,986. Interest payable of $5$1 and $3 was recorded as of both December 31, 20192021 and 2018.2020, respectively.
NOTE 7 - MEMBERS’ EQUITY
Under the Class B Unit Purchase Agreement (“Class B Agreement”) with GSFS, which was entered into upon the amendment and restatement of the Tinuum Operating Agreement in 2011, ADA and NexGen each entered into a limited guarantee agreement under which the parties are obligated to guarantee performance by Tinuum of its obligations to indemnify GSFS against certain losses it may suffer as a result of inaccuracies or breach in representations and covenants related to the Class B Agreement or REF Facilities’ lease agreements with GSFS affiliates. ADA and NexGen entered into a contribution agreement where, in the event of such a breach, they have agreed to contribute their pro rata share of any amounts under the limited guarantee.
The Class B units were considered conditionally redeemable as specified in the Second Amended and Restated Operating Agreement and the Class B Agreement. GSFS’ Class B units included a guaranteed 15% annual return calculated monthly based uponUpon satisfaction of the outstanding balance as of that date. The outstanding balance over time was based on the original investment, increased by the guaranteed return, and reduced by any distributions of cash or PTCs. In Februaryredemption criteria in 2018, the unrecovered investment balance inGSFS continues to own the Class B units was reduced to zero.
which have no further capital call requirements and have limited voting rights. In September 2019, the Second Amended and Restated Operating Agreement was amended to eliminate the preferential redemption provisions for the Class B shares and simultaneously reallocated certain tax attributes between the Class A and B Members.
As a result of the repayment of the guaranteed return and the unrecovered investment balance in February 2018, as of December 31, 2018, the Class B units were no longer considered conditionally redeemable and are now considered to be a non-voting class of Members’ equity. GSFS continues to own Class B units which have no further capital call requirements and have limited voting rights.
The Company had the following classes and percentages of Member units issued and outstanding at December 31, 20192021 and 2018.
|
| | | | | | | |
| Class A Units (voting) | | 85 | % |
| Class B Units (non-voting) | | 15 | % |
NOTE 8 - INCOME TAXES
During the years ended December 31, 20192021 and 2018,2020, the Company has concluded that there are no significant uncertain tax positions that would require recognition or disclosure in the financial statements. As of December 31, 2019,2021 and 2018,2020, the Company made no provision for interest or penalties related to uncertain positions.
Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts for income tax purposes related to one of the Company’s consolidated VIEs. Under a tax sharing agreement with the specific TP Investor of this VIE, the deferred tax assets are allocated specifically to the TP Investor and are not for the benefit of Tinuum or its members. Net deferredOn a quarterly basis, the TP Investor provides a cash payment to the VIE for the prior quarter’s tax assets are included within other long-term assets onbenefits generated, generally production tax credits and net operating losses. As a result, the quarterly estimated funding is presented as an income tax receivable in the consolidated balance sheet:sheets. As of December 31, 2021, an income tax payable is being presented as the estimated funding exceeded the actual TP investor provision.
The income tax payable as of December 31, 2021 is included in accrued liabilities in the consolidated balance sheets and consists of:
| | | | | | | | | | |
| | | | |
| | 2021 | | |
| | | | |
| Net operating losses | | $ | 28 | | | |
| Deferred tax liability | | — | | | |
| Production tax credits | | — | | | |
| TP Investor provision modification | | (93) | | | |
| Income tax payable | | $ | (65) | | | |
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2021 and 2020
(in thousands)
|
| | | | |
| | | 2019 |
| Net operating losses | | $ | 287 |
|
| Production tax credits | | 617 |
|
| Total deferred tax assets | | $ | 904 |
|
| | | | | | | | | | |
| | | | |
| | 2020 | | |
| | | | |
| Net operating losses | | $ | 1,026 | | | |
| Deferred tax liability | | (21) | | | |
| Production tax credits | | 4,961 | | | |
| Income tax receivable | | $ | 5,966 | | | |
Net operating loss carryforwards can be carried forward indefinitely and the PTCs can be carried forward for 20 years.
For the years ended December 31, 20192021 and 2018,2020, income tax expense (benefit) consisted of the following:
| | | | | | | | | | | | | | |
| | 2021 | | 2020 |
| Current | | $ | 1,061 | | | $ | 1,137 | |
| Deferred | | (9,769) | | (18,979) |
| Total income tax (benefit) expense | | $ | (8,708) | | | $ | (17,842) | |
|
| | | | | | | | |
| | | 2019 | | 2018 |
| Current | | $ | 1,369 |
| | $ | 1,135 |
|
| Deferred | | (904) |
| | 224 |
|
| Total income tax expense | | $ | 465 |
| | $ | 1,359 |
|
NOTE 9 - RELATED PARTY TRANSACTIONS
During 20192021 and 2018,2020, the Company incurred expenses and capital expenditures and had amounts payable (excluding capital distributions) to and revenues recognized from the following related party entities:
|
| | | | | | | | | | | | | | | | |
| | | ADA | | TS | | GSFS Affiliates | | NexGen and Affiliates |
| | | (a) | | (b) | | (c) | | (d) |
| As of December 31, 2019 | | | | | | | | |
| Accounts receivable | | $ | — |
| | $ | — |
| | $ | 56 |
| | $ | — |
|
| Accounts payable | | 4,104 |
| | 6,134 |
| | 20 |
| | 20 |
|
| | | | | | | | | |
| As of December 31, 2018 | | | | | | | | |
| Accounts receivable | | $ | — |
| | $ | 6,350 |
| | $ | — |
| | $ | — |
|
| Accounts payable | | 4,284 |
| | 6,397 |
| | — |
| | 24 |
|
| | | | | | | | | |
| Revenues Recognized During the Year Ended | | | | | | | | |
| December 31, 2019 | | $ | — |
| | $ | 45,608 |
| | $ | 121,794 |
| | $ | — |
|
| December 31, 2018 | | — |
| | 23,968 |
| | 121,229 |
| | — |
|
| | | | | | | | | |
| Expenses Incurred During the Year Ended | | | | | | | | |
| December 31, 2019 | | $ | 16,945 |
| | $ | 14,807 |
| | $ | — |
| | $ | 519 |
|
| December 31, 2018 | | 15,144 |
| | 11,222 |
| | — |
| | 551 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | ADA | | TS | | GSFS Affiliates | | NexGen and Affiliates |
| | (a) | | (b) | | (c) | | (d) |
| Accounts Receivable as of the Year Ended | | | | | | | | |
| December 31, 2021 | | $ | 102 | | | $ | — | | | $ | — | | | $ | — | |
| | | | | | | | |
| Accounts Payable as of the Year Ended | | | | | | | | |
| December 31, 2021 | | $ | 2,467 | | | $ | 4,154 | | | $ | — | | | $ | 15 | |
| December 31, 2020 | | 3,454 | | | 4,179 | | | — | | | 20 | |
| | | | | | | | |
| Revenues Recognized During the Year Ended | | | | | | | | |
| December 31, 2021 | | $ | — | | | $ | (2,230) | | | $ | 85,672 | | | $ | 34 | |
| December 31, 2020 | | — | | | (593) | | | 88,243 | | | — | |
| | | | | | | | |
| | | | | | | | |
| Expenses Incurred During the Year Ended | | | | | | | | |
| December 31, 2021 | | $ | 14,377 | | | $ | 18,668 | | | $ | — | | | $ | 240 | |
| December 31, 2020 | | 13,656 | | | 16,629 | | | — | | | 527 | |
| | | | | | | | |
|
| | | | |
(a) | ADA expenses include expenditures for royalties.royalties and consulting services. |
(b) | TS expenses include operating expenses associated with the operations of retained REF Facilities. TS revenues include Asset Purchase Agreement paymentsAPA point in time revenue estimates and management fee revenues from TP Investors included within the TS consolidated financial statements. |
(c) | GSFS affiliates revenues relate to REF Facility lease revenues recognized. |
(d) | NexGen and affiliates expenses include management fees and labor costs. |
The Company acquires substantial amounts of fixed assets from TS. For the years ended December 31, 20192021 and 2018,2020, the Company acquired $17,951$0 and $18,651,$5,549, respectively, of capital assets from its related party, TS.
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2021 and 2020
(in thousands)
For the year ended December 31, 2021, TS incurred, on the Company’s behalf, proceeds related to the sale of fixed assets in the amount of $250.
NOTE 10 - COMMITMENTS
Purchase Commitments
In November 2011, Tinuum entered into a technology licensing agreement with ADA whereby Tinuum agreed to pay ADA royalties based on a percentage of operating income from REF production at REF Facilities that utilize the M-45™ technology. During the years ended December 31, 20192021 and 2018,2020, respectively, the Company recognized royalty expense under cost of sales in the amounts of $16,900$14,354 and $15,141,$13,440 respectively.
In December 2015 the Company was assigned, by TS, a Master Supply Agreement with a chemical vendor. Under the agreement the Company had a commitment commencing January 1, 2015, for minimum purchase quantities of the specified chemical that if not achieved would require a shortfall payment amount (“Shortfall”) to be paid to the vendor on a monthly basis. Any Shortfall payment required would be applied to future chemical purchases once certain minimum volume levels were achieved. In 2018 an agreement was reached to further amend the Master Supply Agreement and the Company made an additional prepayment of $8,187 resulting in a total prepaid amount of $17,755 on deposit with the vendor as of both December 31, 2019 and 2018. This amount is included within long-term other assets2019. Beginning in August 2020, the Company’s consolidated balance sheets. The Company anticipatesstarted utilizing the prepaid deposit balance through ongoing chemical usageusage. The prepaid deposit balance was fully utilized as of December 31, 2021 and therefore the balance was $0 at December 31, 2021. As of December 31, 2020, the balance was $10,632 and was included within other current assets in the Company’s consolidated balance sheets.
Retention Compensation
It has been an ongoing practice of the Company to provide severance payments to employees that are involuntarily terminated for reasons other than for cause. In anticipation of the wind down of operations expected by 2022, the Company has formalized that practice into a retention compensation program. The purpose of the program is to incent employees to remain with the Company through the wind down dates necessary for the successful cessation of the Company. Certain executive employees have contracts that do not have a defined retention date but provide for severance payment provisions equivalent to one year of base salary that only become due and payable upon a decision by the endBoard of 2021.Managers to terminate an executive other than for cause. The potential estimated liability under these contracts is approximately $750. All non-executive employees have a retention bonus agreement with a defined dollar amount that is payable by the Company upon the earlier of the Company’s initiation of an involuntary termination or the employee remaining with the Company until the defined retention date within their agreement. Any employees electing to voluntarily terminate employment with the Company prior to their defined retention date will forfeit their retention bonus amount. Compensation expense of $3,116 and $2,048 was recognized for the years ended December 31, 2021 and 2020, respectively. A remaining liability of $3,613 is recorded and of this amount $1,835 is included in other current liabilities for TG employees and $1,778 is in the related party payables related to TS employees with retention dates in 2022.
401k Profit Sharing Plan and Other Benefits
The Company offers a defined contribution and profit sharing plan (the “Plan”) to employees who are over 18 years of age and have been employed by the Company for more than 30 days. Employees can deposit up to 80% of their eligible pay up to the statutory limit in the Plan. The Company contributes 3% of employees’ eligible pay to the Plan as safe harbor contributions. Commencing January 1, 2018, the Company began providingcontributions and an additional matching contribution equivalent to 50% of the first 6% of employee contributions. Company contributions charged to benefits expense was $186$157 and $221$194 for the years ended December 31, 20192021 and 2018,2020, respectively.
As of January 24, 2022, the Company has initiated the termination of the Plan. Accordingly, employees will be required to roll over their balances under the termination provisions stipulated by the Plan.
Office Lease
Tinuum’s ROU asset and lease liability are comprised of its lease for its corporate office space. The lease has an eight-year term that commenced in March 2014. The lease does not include renewal options that the Company expects to utilize. The Company has utilized its implicit borrowing rate of 5.75% to calculate the ROU asset and lease liabilities. Operating lease expense for each of the years ended December 31, 20192021 and 20182020 was $201.$197 and $199 respectively. Operating leases are included in the ROU assets within fixed assets, net, and lease liabilities are included within accrued liabilities on the consolidated balance
TINUUM GROUP, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2021 and 2020
(in thousands)
sheets. Real estate taxes and common area maintenance charges are expensed as incurred as operating expenses and are not included in the lease payments.
As of December 31, 2019,2021, future annual lease payments under lease agreements through December 31, 2022 are as follows:$233 less $7 of interest expense, reflecting a present value of lease liabilities of $226.
|
| | | | |
| 2020 | | $ | 226 |
|
| 2021 | | 233 |
|
| 2022 | | 240 |
|
| Total lease payments | | 699 |
|
| Less: interest expense | | (59) |
|
| Present value of lease liabilities | | $ | 640 |
|
Prior to the adoption of ASC 842, as of December 31, 2018, future minimum lease payments under lease agreements through December 31, 2022 were as follows:
|
| | | | |
| 2019 | | $ | 207 |
|
| 2020 | | 214 |
|
| 2021 | | 221 |
|
| 2022 | | 229 |
|
| Total | | $ | 871 |
|
NOTE 11 - CONCENTRATIONS
The Company’s operations are currentlywere dependent upon TP Investors leasing or purchasing REF Facilities. Further, under the terms of the various TP Investor agreements, the agreements may bewere subject to termination or modification by the TP Investor at periodic intervals or upon the occurrence of specified events which includeincluded amendments to Section 45 of the Internal Revenue Code. The termination or modification of all or a material portion of any TP Investor agreements would have had a significant adverse impact on the Company’s future operations and financial condition. During the year ended December 31, 2019, three TP Investor agreements were terminated, one due to the expiration of the PTC period of a specific REF Facility and the other two as a result of the Generator closing its coal-fired generating station.
Additionally, the production and sale of REF iswas dependent upon the plant operations of specific generating stations where the REF Facilities arewere located. Production at these locations could behave been impacted by the demand for electricity, the amount of fuel burned as compared to other electricity generation fuel sources utilized by the utility to produce electricity, disruptions due to foreseen or unforeseen plant outages, or changes in government regulations related to electricity generation or coal burning activities.
Certain of the chemicals utilized by the Company to produce REF arewere available from a limited number of vendors in the United States. The Company's future operations may becould have been materially and adversely affected if the Company encountersencountered difficulty procuring these chemicals, the quality of available chemicals deteriorates,deteriorated or there arewere significant price increases for the chemicals.
NOTE 12 - SUBSEQUENT EVENTS
Management evaluated subsequent events through March 13, 2020,4, 2022, the date financial statements were available to be issued.
Item 16. Form 10-K Summary
None.
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Exchange Act, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
Advanced Emissions Solutions, Inc.
(Registrant)
|
| | | | | | | | | | | | | |
| By | /s/ L. Heath Sampson | | By | /s/ Greg P. Marken | | By | /s/ Morgan Fields |
L. Heath Sampson | | Greg P. Marken | | Morgan Fields |
| Chief Executive Officer (Principal Executive Officer) | | Chief FinancialAccounting Officer (Principal Financial and Accounting Officer) |
| | |
Date: March 16, 20208, 2022 | | Date: March 16, 20208, 2022 |
Pursuant to the requirements of the Exchange Act, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.
| | | | | | | | | | | | | | |
| By | /s/ Carol Eicher | | By | /s/ Gilbert Li |
| Carol Eicher, Director | | Gilbert Li, Director |
| | |
| Date: March 8, 2022 | | Date: March 8, 2022 |
| | | | |
| By | /s/ J. Taylor Simonton | | By | /s/ L. Spencer Wells |
| J. Taylor Simonton, Director | | L. Spencer Wells, Director |
| | |
| Date: March 8, 2022 | | Date: March 8, 2022 |
| | | | |
| | | | |
By | /s/ Carol Eicher | | By | /s/ Brian Leen |
Carol Eicher, Director | | Brian Leen, Director |
| | |
Date: March 16, 2020 | | Date: March 16, 2020 | | |
| | | | |
By | /s/ Gilbert Li | | By | /s/ R. Carter Pate |
Gilbert Li, Director | | R. Carter Pate, Director |
| | |
Date: March 16, 2020 | | Date: March 16, 2020 | | |
| | | | |
By | /s/ L. Heath Sampson | | By | /s/ J. Taylor Simonton |
L. Heath Sampson, Director and Chief Executive Officer | | J. Taylor Simonton, Director |
| | |
Date: March 16, 2020 | | Date: March 16, 2020 |
| | | | |
By | /s/ L. Spencer Wells | | | |
L. Spencer Wells, Director | | |
| | |
Date: March 16, 2020 | | |