OPAL Fuels Inc. (OPAL)

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

In this Management's Discussion and Analysis of Financial Condition and Results of Operations section, references to "OPAL," "we," "us," "our," and the "Company" refer to OPAL Fuels Inc. and its consolidated subsidiaries. The following discussion and analysis should be read in conjunction with our consolidated financial statements and related notes set forth in Part II, Item 8 - "Financial Statements and Supplementary Data" and the risk factors identified in Part I, Item 1A - "Risk Factors" of this Annual Report. For further discussion regarding our results of operations for the year ended December 31, 2023 as compared to the year ended December 31, 2022, refer to Part II, Item 7 - "Management’s Discussion and Analysis of Financial Condition and Results of Operations" in our Annual Report on Form 10-K for the fiscal year ended December 31, 2023, as filed with the SEC on March 15, 2024. In addition to historical information, this discussion and analysis includes certain forward-looking statements which reflect our current expectations. The Company's actual results may materially differ from these forward-looking statements.

Overview

The Company is a vertically integrated leader in the capture and conversion of biogas into low carbon intensity Renewable Power and RNG. OPAL Fuels is also a leader in the marketing and distribution of RNG to heavy duty trucking and other hard to de-carbonize industrial sectors. RNG is chemically identical to the natural gas used for cooking, heating homes and fueling natural gas engines, with one significant difference: RNG is produced by recycling methane emissions created by decaying organic waste as opposed to natural gas which is a fossil fuel pumped from the ground. We have participated in the biogas-to-energy industry for over 20 years.

Biogas is generated by microbes as they break down organic matter in the absence of oxygen, and comprised of non-fossil waste gas, with high concentrations of methane, which is the primary component of RNG and the source for combustion utilized by Renewable Power plants to generate electricity. Biogas can not only be collected and processed to remove impurities for use as RNG (a form of high-Btu fuel) and injected into existing natural gas pipelines as it is fully interchangeable with fossil natural gas, but partially treated biogas can be used directly in heating applications (as a form of medium-Btu fuel) or in the production of Renewable Power. Our principal sources of biogas are (i) landfill gas, which is produced by the decomposition of organic waste at landfills, and (ii) dairy manure, which is processed through anaerobic digesters to produce the biogas.

We also design, develop, construct, operate and service Fueling Stations for trucking fleets across the country that use natural gas to displace diesel as their transportation fuel. We have participated in the alternative vehicle fuels industry for over a decade and have established an expanding network of Fueling Stations for dispensing RNG. In addition, we have recently begun implementing design, development, and construction services for hydrogen fueling stations, and we are pursuing opportunities to diversify our sources of biogas to other waste streams.

As of December 31, 2024, we owned and operated 26 projects, 11 of which are RNG projects and 15 of which are Renewable Power Projects. As of that date, our RNG projects in operation had a design capacity of 8.8 million MMBtus per year and our Renewable Power Projects in operation had a nameplate capacity of 105.8 MW per hour. In addition to these projects in operation, we are actively pursuing expansion of our RNG-generating capacity and, accordingly, have a portfolio of RNG projects in construction or in development, with six of our current Renewable Power Projects being considered candidates for conversion to RNG projects in the foreseeable future.

Recent Developments

Wasatch Resource Recovery Facility

On March 17, 2025, Fortistar, through its subsidiary Wasatch RNG LLC (“Wasatch RNG”), acquired all of the limited liability company interests outstanding in Alpro SD, LLC (“Alpro” and such acquired interest, the “Alpro Interest”). Alpro owns a 50% limited liability company interest in Wasatch Resource Recovery, LLC (the “Project” or “Wasatch” and such ownership interest, the “Wasatch Interest”) and a 50% tenancy-in-common interest in certain real estate and operating assets used by Wasatch (the “Project Interest”). As a result of the acquisition, Wasatch RNG has the option to increase the Wasatch Interest and the Project Interest.

The Project captures and converts biogas generated from food waste to produce pipeline quality renewable natural gas (RNG). The Project generates revenue from long-term contracted gas sales, tipping fees, and digestate (fertilizer) sales. The conversion of food waste to RNG presents a potential growth and diversification opportunity for OPAL Fuels.

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In connection with the acquisition, Fortistar Services 2 LLC and OPAL Fuels LLC entered into an amendment to its existing Administrative Services Agreement, pursuant to which OPAL Fuels will provide certain services to Wasatch RNG in exchange for certain agreed upon fees and expense reimbursements. These services include oversight of the plan to improve the operations and productivity of the Project.

Additionally, Wasatch RNG and OPAL Fuels entered into an Option Agreement, pursuant to which Wasatch RNG granted an option to OPAL Fuels to purchase the Alpro Interest. The exercise period of the option commenced upon closing of the acquisition and will terminate on the third anniversary of the closing of the acquisition, or ninety days following a change of control of OPAL Fuels. The exercise price of the option would be determined such that Wasatch RNG would earn an internal rate of return on its invested capital of 10% percent per year if the option is exercised in the first year, 15% per year if exercised in the second year, and 20% per year if exercised in the third year.

OPAL Term Loan Amendment

On March 3, 2025, OPAL Fuels Intermediate HoldCo LLC, as the borrower (the “Borrower”), certain subsidiaries of the Borrower, as guarantors (the “Guarantors”), the lenders and issuers of letters of credit party thereto and Bank of America, N.A. as the administrative agent (the “Administrative Agent”) entered into that certain Amendment No. 1 to Credit and Guarantee Agreement (the “Credit Agreement Amendment”), with respect to that certain Credit and Guarantee Agreement (the “Credit Agreement”) dated September 1, 2023, by and among the Borrower, the Administrative Agent, the financial institutions from time to time parties thereto as lenders and as issuers of letters of credit, and the other agents and persons from time to time party thereto (as amended, restated, amended and restated, supplemented or otherwise modified and in effect from time to time).

The Credit Agreement Amendment makes certain changes to the applicability of certain financial covenants and modifies other covenants to clarify the use of loan proceeds. Additionally, the Credit Agreement Amendment permits the organizational restructuring of the Guarantors in a manner designed to facilitate the sale of federal investment tax credits and the ability to raise additional future capital.

The Credit Agreement Amendment also eases the conditions precedent to making new Projects eligible for borrowing under the Credit Agreement, extends the availability period for delay draw term loans under the Credit Agreement through March 5, 2026, and extends the commencement of repayment of such term loans until March 31, 2026.

In connection with the Credit Agreement Amendment, the Borrower paid the Administrative Agent, for the account of each lender, a one-time nonrefundable fee of $1,250,000.

Critical Accounting Policies and Estimates

The discussion and analysis of our financial condition and results of operations is based upon our consolidated financial statements, which have been prepared in accordance with generally accepted accounting principles in the United States ("U.S. GAAP") and the rules and regulations of the SEC, which apply to interim financial statements. The preparation of those financial statements requires us to make estimates and judgments that affect the reported amounts of assets and liabilities, revenues, expenses and warrants and related disclosure of contingent assets and liabilities at the date of our financial statements. Actual results may differ from these estimates under different assumptions and conditions.

Critical accounting policies are those that reflect significant judgments of uncertainties and potentially result in materially different results under different assumptions and conditions. We have described below what we believe are our most critical accounting policies, because they generally involve a comparatively higher degree of judgment in their application. For a detailed description of all our accounting policies, see Note 2. Summary of Significant Accounting Policies, to our consolidated financial statements included herein.

Revenue Recognition

Renewable Power

We sell Renewable Power produced from LFG-fueled power plants to utility companies through our PPAs. Revenue is recognized based on contract specified rates per MWh when delivered to the customer, as this considered to be completion of the performance obligation. Certain PPAs contain a lease element which we account for as operating lease revenue on a straight-line basis over the lease term. The Company utilizes commodity swap contracts to hedge against the unfavorable price fluctuations in market prices of electricity. The Company does not apply hedge accounting to these contracts. As

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such, unrealized and realized gain (loss) is recognized as component of Renewable Power revenues in the consolidated statement of operations.

Transportation fuel — Fuel Purchase Agreements

We own Fueling Stations for use by customers under fuel sale agreements. We bill these customers at an agreed upon price for each gallon sold and recognize revenue based on the amounts invoiced in accordance with the “right to invoice” practical expedient. These contracts may contain an embedded lease of the equipment which we account for as operating lease revenue. For some public stations where there is no contract with the customer, we recognize revenue at the point in time that the customer takes control of the fuel.

Interstate Gas Pipeline Delivery

We have agreements with two natural gas producers whereby we are contracted to transport the producers’ gas to an agreed delivery point on an interstate gas pipeline via our RNG gathering system. Revenue is recognized over time using the output method which is based on quantity of natural gas transported.

Environmental Attributes

We generate RECs, RINs, ISCC Carbon Credits and LCFS credits. These Environmental Attributes are sold to third parties that utilize these credits in order to comply with federal and state requirements. Revenue is recognized at the point in time when the credits are transferred to and accepted by the third party buyer. We also provide Environmental Attributes generation and monetization services to customers that own renewable gas generation facilities and we recognize revenues from these services when the credits are minted on behalf of the customer.

Operation and Maintenance

We have operating and maintenance agreements pursuant to which we operate, maintain, and repair landfill site gas collection systems. Revenue is based on the volume per million British thermal units (“MMBtu”) of landfill gas collected and the MWhs produced at that site. This revenue is recognized as Renewable Power revenue when landfill gas is collected and Renewable Power is delivered. In addition, we have operations and maintenance agreements in which we are contracted to maintain and repair Fueling Stations. Revenue is based on the volumes of gas dispensed at the site. This revenue is recognized as Fuel Station Services revenue when the site dispenses gas.

Construction Type Contracts — Third Party

We have various fixed price contracts for the construction of fueling stations for customers. Revenue from these contracts, including change orders, are recognized over time, with progress measured by the percentage of cost incurred to date to estimated total cost for each contract.

The Company provides all third-party construction contracts with a warranty, typically for a period of one year after substantial completion of the construction project. Based on the guidance and indicative factors provided by ASC 606, the Company concluded that it offers assurance-type warranties as it does not provide a service to the customer beyond fixing defects that existed at the time of completion. Therefore, these warranties are accounted for under ASC Topic 460, Guarantees ("ASC 460"), and not as a separate performance obligation.

Generally, the company estimates warranty costs based on historical claims experience, and other factors. Actual warranty claims may differ from the estimates, and adjustments to the liability are made as necessary.

Impairment of Goodwill

When a business is acquired, goodwill is recognized to reflect any future economic benefits that are not separately recognized, such as synergies. For the purposes of impairment testing, U.S. GAAP requires goodwill to be allocated to reporting unit(s) at the acquisition date and to be tested for impairment at least annually, and in between annual tests whenever events or changes in circumstances indicate that the respective reporting unit’s fair value is less than its carrying value. Significant judgment is required when identifying the reporting units for goodwill allocation, during our assessment of relevant events and circumstances for qualitative impairment indicators, and when estimating the undiscounted cash flows of reporting unit(s) for quantitative impairment assessments.

Our goodwill impairment assessment is performed during the fourth quarter as of December 31 of each year or at the time facts or circumstances indicate that a reporting unit’s goodwill may be impaired. In conformity with GAAP, we

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generally first perform a qualitative assessment over whether it is more likely than not that a reporting unit’s fair value is less than its carrying value to determine if a quantitative assessment is required. If, after performing the qualitative assessment, we conclude it is more likely than not that the fair value of the reporting unit is less than its carrying value, then a quantitative test is required. Our qualitative assessment includes evaluation of relevant events and circumstances, such as, macroeconomic conditions, industry and market considerations, cost factors, overall performance, and other relevant events.

When applying a quantitative assessment, we use a combination of income and market valuation methodologies. Specifically, we employ a discounted cash flow analysis (DCF) and the guideline public company method. This approach results in a fair value measurement based on significant inputs that are not observable in the market, categorizing it within Level 3 of the fair value hierarchy. Key assumptions in the DCF projection include growth in RIN prices, future sales volumes based on production capacities, and terminal value based on a range of terminal earnings before interest, taxes, depreciation, and amortization (EBITDA). The future cash flows are discounted to present value using the weighted average cost of capital (WACC) of the company and its closest competitors.

As of December 31, 2024, we performed a quantitative assessment for Goodwill in our RNG Fuel segment and determined that there is no impairment necessary on the goodwill recorded in the books as of December 31, 2024.

Impairment of Long-Lived Assets

Our long-lived assets held and used with finite useful lives including plant equipment, buildings, patents, and PPAs are reviewed for impairment whenever events or changes in circumstances indicate that the asset group may not be recoverable. In determining the asset group, we assess the interdependency of revenues between assets, shared cost structures, the interchangeability of assets used in operations, and how assets are managed and utilized by the business. Events that may trigger a recoverability assessment include a significant adverse change in the extent or manner in which the long-lived asset group is being used or in its physical condition, and the expectation that, more likely than not, the long-lived asset or asset group will be sold or otherwise disposed of significantly before the end of its previously estimated useful life. Recoverability of long-lived assets to be held and used is measured by a comparison of the carrying amount of an asset group to future net undiscounted cash flows expected to be generated by the asset group. Our cash flow estimates reflect conditions and assumptions that existed as of the measurement date which is the same as the triggering event date. The assets are considered recoverable and an impairment loss is not recognized when the undiscounted net cash flows exceed the net carrying value of the asset group. If the assets are not recoverable, then an impairment loss is recognized to the extent that the carrying value of the asset group exceeds its fair value. We base the fair value of our assets or asset groups off of the estimated discounted future cash flows using market participant assumptions. Alternatively, we use cost approach to measure fair value of our assets or asset groups. The cost approach is based on the premise that a prudent investor would pay no more for an asset of similar utility than its replacement or reproduction cost. The cost to replace the asset would include the cost of constructing a similar asset of equivalent utility at prices applicable at the time of the valuation date. To arrive at an estimate of the fair value using the cost approach, the replacement cost new is determined and reduced for depreciation of the asset. Replacement cost new is defined as the current cost of producing or constructing a similar new item having the nearest equivalent utility as the property being valued. Assets disposed of are reported at the lower of the carrying amount or fair value less selling costs. Significant judgment is required when determining asset group composition, during our assessment of relevant events and circumstances, when determining an appropriate discount rate, and when estimating the undiscounted and discounted future cash flows of the asset group.

Based on our assessment for the year ended December 31, 2024, the impairment recorded on our Plant, Property and Equipment amounted $2.0 million.

Fair Value Measurements

The objective of a fair value measurement is to estimate the exit price, which is the price that would be received to sell an asset or paid to transfer a liability that the Company holds, in an orderly market transaction at the measurement date. We follow GAAP guidance which establishes a three-tier hierarchy for inputs used in fair value measurements, as well as prioritizes valuation techniques that maximize the use of observable inputs and minimizes the use of unobservable inputs. In summary, level 1 inputs are considered the most observable inputs and are more specifically the unadjusted quoted price for identical assets or liabilities in an active market the Company has access to. Level 2 inputs are considered less observable inputs such as quoted prices for similar assets or liabilities in an active market the Company has access to. Lastly, level 3 inputs are unobservable inputs in which little to no market activity exists for the asset or liability at the measurement date. As such, level 3 estimates are subject to a more significant level of estimation uncertainty. Furthermore, when multiple inputs are used and are categorized in different levels of the input hierarchy, then the fair value measurement

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in its entirety is categorized in the same level as its lowest level input that is significant to the fair value measurement. Our assessment of the significance of an input to a fair value measurement requires judgment and may affect the fair value measurement’s placement in the fair value hierarchy.

Refer to Note 9. Derivative Financial Instruments and Fair Value Measurements, to our consolidated financial statements, for details on our assets and liabilities regularly recorded at fair value and the respective placements in the fair value hierarchy.

Income Taxes

The Company accounts for income taxes in accordance with ASC Topic 740, Accounting for Income Taxes (“ASC Topic 740”), which requires the recognition of tax benefits or expenses on temporary differences between the financial reporting and tax bases of its assets and liabilities by applying the enacted tax rates in effect for the year in which the differences are expected to reverse. Such net tax effects on temporary differences are reflected on the Company’s consolidated balance sheets as deferred tax assets and liabilities. Deferred tax assets are reduced by a valuation allowance when the Company believes that it is more-likely-than-not that some portion or all of the deferred tax assets will not be realized.

Refer to Note 15. Income Taxes, to our consolidated financial statements, for additional information.

Emerging Growth Company Status

We are an emerging growth company as defined in the JOBS Act. The JOBS Act provides emerging growth companies with certain exemptions from public company reporting requirements for up to five fiscal years while a company remains an emerging growth company. As part of these exemptions, we need only provide two fiscal years of audited financial statements instead of three, we have reduced disclosure obligations such as for executive compensation, and we are not required to comply with auditor attestation requirements from Section 404(b) of the Sarbanes-Oxley Act regarding our internal control over financial reporting. Additionally, the JOBS Act has allowed us the option to delay adoption of new or revised financial accounting standards until private companies are required to comply with new or revised financial accounting standards.

Use of Estimates

The preparation of the consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the consolidated financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The significant estimates and assumptions of the Company relate to the useful lives of property, plant and equipment, goodwill impairment, fair value of the deconsolidated VIEs, the value of stock-based compensation, asset retirement obligations and the fair value of derivatives including earnout liabilities and commodity swap contracts.

Key Factors and Trends Influencing our Results of Operations

The principal factors affecting our results of operations and financial condition are the markets for RNG, Renewable Power, and associated Environmental Attributes, and access to suitable biogas production resources. Additional factors and trends affecting our business are discussed in "Risk Factors" elsewhere in this report.

Market Demand for RNG

Demand for our converted biogas and associated Environmental Attributes, including RINs and LCFS credits, is heavily influenced by United States federal and state energy regulations together with commercial interest in renewable energy products. Markets for RINs and LCFS credits arise from regulatory mandates that require refiners and blenders to incorporate renewable content into transportation fuels. The EPA annually sets proposed renewable volume obligations ("RVOs") for D3 RINs in accordance with the mandates established by the Energy Independence and Security Act of 2007. In June 2023, the EPA set RVOs for 2023 through 2025 via a new Set rule. This 3 year RVO is expected to reduce volatility in RIN pricing for the associated period. On the state level, the economics of RNG are enhanced by low-carbon fuel initiatives, particularly well-established programs in California and Oregon (with several other states also actively considering LCFS initiatives similar to those in California, Washington and Oregon). Federal and state regulatory

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developments could result in significant future changes to market demand for the RINs and LCFS credits we produce. This would have a corresponding impact to our revenue, net income, and cash flow.

Transportation, including heavy-duty trucking, generates approximately 30% of overall carbon dioxide and other climate-harming GHG emissions in the United States, and transitioning this sector to low and negative carbon fuels is a critical step towards reducing overall global GHG emissions. The adoption rate of RNG-powered vehicles by commercial transportation fleets will significantly impact demand for our products.

We are also exposed to the commodity prices of natural gas and diesel, which serve as alternative fuel for RNG and therefore impact the demand for RNG.

Renewable Power Markets

We also generate revenues from sales of Renewable Power generated by our biogas-to-Renewable Power projects, and associated ISCC Carbon Credits and RECs. ISCC Carbon Credits and RECs exist because of legal and governmental regulatory requirements in Europe and the United States, respectively, and a change in law or in governmental policies concerning Renewable Power, LFG, or ISCC Carbon Credits or RECs could affect the market for, and the pricing of, such power and credits.

We periodically evaluate opportunities to convert existing Renewable Power projects to RNG production. We have been negotiating with several of our landfill and Renewable Power counterparties to enter into arrangements that would enable the LFG resource to produce RNG. Changes in the price we receive for Renewable Power, associated ISCC Carbon Credits and RECs, together with the revenue opportunities and conversion costs associated with converting our LFG sites to RNG production, could have a significant impact on our future profitability.

Regulatory landscape

We operate in an industry that is subject to and currently benefits from environmental regulations. Government policies can increase demand for our products by providing incentives to purchase RNG and Environmental Attributes. These government policies are modified and in flux constantly and any adverse changes to these policies could have a material effect on the demand for our products. For more information, see our risk factor titled "The financial performance of our business depends upon tax and other government incentives for the generation of RNG and Renewable Power, any of which could change at any time and such changes may negatively impact our growth strategy." Government regulations have become increasingly stringent and complying with changes in regulations may result in significant additional operating expenses.

Seasonality

We experience seasonality in our results of operations. Sale of RNG may be impacted by higher consumption by some of our customers during summer months. Additionally, the price of RNG is higher during the fall and winter months due to increase in overall demand for natural gas during the winter months. Revenues generated from our renewable electricity projects in the northeast U.S., all of which sell electricity at market prices, are affected by warmer and colder weather, and therefore a portion of our quarterly operating results and cash flows are affected by pricing changes due to regional temperatures. These seasonal variances are managed in part by certain off-take agreements at fixed prices.

Key Components of Our Results of Operations

We generate revenues from the sale of RNG fuel, Renewable Power, and associated Environmental Attributes, as well as from the construction, fuel supply, and servicing of Fueling Stations for commercial transportation vehicles using natural gas to power their fleets. These revenue sources are presented in our statement of operations under the following captions:

RNG Fuel

The RNG Fuel segment includes RNG supply as well as the associated generation and sale of commodity natural gas and environmental credits, and consists of:

◦RNG Production Facilities – the design, development, construction, maintenance and operation of facilities that convert raw biogas into pipeline quality natural gas; and

◦Our interests in both operating and construction projects.

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Fuel Station Services

Through our Fuel Station Services segment, we provide construction and maintenance services to third-party owners of vehicle Fueling Stations and perform fuel dispensing activities including generation and minting of environmental credits. This segment includes:

◦Manufacturing division that builds Compact Fueling Systems and Defueling systems;

◦Design/Build contracts where we serve as general contractor for construction of Fueling Stations, typically structured as Guarantee Maximum Price or fixed priced contracts for customers, generally lasting less than one year;

◦Service and maintenance contracts for RNG/CNG Fueling Stations; and

◦RNG and CNG Fuel Dispensing Stations - This includes both the dispensing (or sale) of RNG, CNG, and environmental credit generation and monetization. We operate Fueling Stations that dispense both CNG and RNG fuel for vehicles.

Renewable Power

The Renewable Power segment generates renewable power and associated Environmental Attributes such as ISCC Carbon Credits and RECs through combustion of biogas from landfills which is then sold to public utilities throughout the United States.

Our costs of sales associated with each revenue category are as follows:

RNG Fuel

Includes royalty payments to biogas site owners for the biogas we use; service provider costs; salaries and other indirect expenses related to the production process, utilities, transportation, storage, and insurance; and depreciation of production facilities.

Fuel Station Services

Includes equipment supplier costs; service provider costs; and salaries and other indirect expenses.

Renewable Power

Includes royalty payments, land usage costs; service provider costs; salaries and other indirect expenses related to the production process; utilities; and depreciation of production facilities.

Project development and start up costs includes certain development costs such as legal, consulting fees for joint venture structuring, royalties to the landfill owner, fines, settlements, site lease expenses and certification costs on our RNG projects under construction. Additionally, the Company also incurs certain expenses on new RNG projects that went operational for the first two years such as virtual pipeline costs (incurred until a physical interconnect pipeline is built) and ramp up costs incurred during the certification period.

Selling, general, and administrative expense consists of costs involving corporate overhead functions, including the cost of services provided to us by an affiliate, and marketing costs.

Depreciation and amortization primarily relate to depreciation associated with property, plant, and equipment and amortization of acquired intangibles arising from PPAs and interconnection contracts. We are in the process of expanding our RNG and Renewable Power production capacity and expect depreciation costs to increase as new projects are placed into service.

Concentration of customers and associated credit risk

The following table summarizes the percentage of consolidated accounts receivable, net by customers that equal or exceed 10% of the consolidated accounts receivable, net as of December 31, 2024 and 2023. No other single customer accounted for 10% or greater of our consolidated accounts receivables in these periods:

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(1) Relates to sales of environmental attributes under Purchase and Sale agreement and Renewable Power sale agreements with NextEra.

*Less than 10%

The following table summarizes the percentage of consolidated revenues from customers that equal 10% or greater of the consolidated revenues in the period. No other single customer accounted for more than 10% of consolidated revenues in these periods:

Results of Operations for the years ended December 31, 2024 and 2023:

Operational data

The following table summarizes the operational data achieved for the years ended December 31, 2024 and 2023:

Landfill RNG Facility Capacity and Utilization Summary

(1) Design Capacity for RNG facilities is measured as the volume of feedstock biogas that the facility is capable of accepting at the inlet and processing during the associated period. Design Capacity is presented as OPAL’s ownership share (i.e., net of joint venture partners’ ownership) of the facility and is calculated based on the number of days in the period. New facilities that come online during a quarter are pro-rated for the number of days in commercial operation.

(2) Inlet Design Capacity Utilization is measured as the Volume of Inlet Gas for a period, divided by the total Design Capacity for such period. The Volume of Inlet Gas varies over time depending on, among other factors, (i) the quantity and quality of waste deposited at the landfill, (ii) waste management practices by the landfill, and (iii) the construction, operations and maintenance of the landfill gas collection system used to recover the landfill gas. The Design Capacity for each facility will typically be correlated to the amount of landfill gas expected to be generated by the landfill during the term of the related gas rights agreement. The Company expects Inlet Design Capacity Utilization to be in the range of 75-85% on an aggregate basis over the next several years. Typically, newer facilities perform at the lower end of this range and demonstrate increasing utilization as they mature and the biogas resource increases at open landfills.

(3) Utilization of Inlet Gas is measured as RNG Fuel Volume Produced divided by the Volume of Inlet Gas. Utilization of Inlet Gas varies over time depending on availability and efficiency of the facility and the quality of landfill gas (i.e., concentrations of methane, oxygen, nitrogen, and other gases). The Company generally expects Utilization of Inlet Gas to be in the range of 80% to 90%.

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(4) Excludes Sunoma and Biotown.

(1) Design Capacity for Renewable Power facilities is the manufacturer’s expected capacity at ISO conditions for each facility and may not reflect actual production from the projects, which depends on many variables including, but not limited to, (i) quantity and quality of the biogas, (ii) operational up-time of the facility, including dispatch and maintenance downtime and (iii) actual efficiency of the facility.

(2) Design Capacity Utilization for Renewable Power facilities is measured as Renewable Power Produced divided by Design Capacity for the period. Given (i) built-in un-utilized capacity from historical designs, (ii) availability (a function of higher maintenance requirements compared to RNG facilities) and (iii) commencement of operations of the Emerald RNG facility, which will result in low levels of dispatch for the Arbor Hills facility (which will operate on a standby basis but remain in the operating portfolio), the Company’s Design Capacity Utilization is expected to remain below 50%.

RNG projects

Below is a table setting forth the RNG projects in operation and construction in our portfolio:

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(1) Reflects the Company’s ownership share of design capacity for projects that are not 100% owned by the Company (i.e., net of joint venture partners’ ownership). Design capacity is measured as the volume of feedstock biogas that the plant is capable of accepting at the inlet and processing and may not reflect actual production of RNG from the projects, which will depend on many variables including, but not limited to, (i) quantity and quality of the biogas, (ii) operational up-time of the facility and (iii) actual efficiency of the facility.

(2) We record our ownership interests in these projects as equity method investments in our consolidated financial statements.

(3) This project has provisions that will adjust or “flip” the percentage of distributions to be made to us over time, typically triggered by achievement of hurdle rates that are calculated as internal rates of return on capital invested in the project.

(4) Expected Commercial Operation Date (“COD”) for commencement of the RNG projects in construction is based on the Company’s estimate as of the date of this report. CODs are estimates and are subject to change as a result of, among other factors out of the Company’s control: (i) regulatory/permitting approval timing, (ii) disruption in supply chains and (iii) construction timing.

(5) Please see Part I, Item 3: Legal Proceedings and Note 17 - Commitments and Contingencies to the financial statements.

(6) The construction of the Cottonwood, Burlington and Kirby Canyon projects began in the second, third and fourth quarters of 2024, respectively.

(7) The Polk County project began commercial operations in October 2024.

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Renewable Power Projects

Below is a table setting forth the Renewable Power projects in operation in our portfolio:

(1) Nameplate capacity is the manufacturer’s expected capacity at ISO conditions for each facility and may not reflect actual production from the projects, which depends on many variables including, but not limited to, (i) quantity and quality of the biogas, (ii) operational up-time of the facility and (iii) actual productivity of the facility.

(2) We have determined that some of our Renewable Power projects are currently RNG conversion candidates. The Company identifies suitable RNG conversion candidates based on highest return of capital which is driven by certain factors including, but not limited to (i) the quantity and quality of LFG, (ii) the proximity to pipeline interconnect and (iii) the ability to enter into contracts, including site leases and gas rights agreements, with host sites. The Company may change its decision to convert a Renewable Power Project into an RNG project in the future. The Company believes disclosing Renewable Power conversion candidates provides visibility into the effect of those conversions on the existing Renewable Power portfolio.

(3) Although the RNG conversion is completed, it is currently contemplated that the Arbor Hills Renewable Power plant will continue limited operations on a stand-by, emergency basis through March of 2031.

(4) Construction of the Fall River project has been delayed due to permitting issues.

Comparison of the Years Ended December 31, 2024 and 2023

The following table presents the period-over-period change for each line item in the Company's consolidated statements of operations for the twelve months ended December 31, 2024 and 2023 .

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Revenues

(1) Revenues from Environmental Attributes in RNG Fuel segment relate to revenues earned from sales of RINs and LCFSs

(2) Revenues from RNG marketing in Fuel Station Services segment relate to revenues earned from sales of RINs and LCFSs as well as revenue from Environmental Attribute generation and monetization services.

(3) Revenues from Environmental Attributes in Renewable Power segment include revenues earned from sales of ISCC carbon sales and RECs.

RNG Fuel

Revenue from RNG Fuel increased by $22.1 million, or 33%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. This is primarily due to a $21.1 million increase in Environmental Attributes, driven by $9.1 million of higher price and $12.0 million from increased volume, primarily from commencement of operations at Prince William and Polk. Revenue from Brown Gas Sales increased $0.5 million, also primarily due to the impact of Prince William and Polk coming online in 2024. Additionally, there was $0.5 million increase in revenues earned from providing management services to unconsolidated entities.

Fuel Station Services

Revenue from Fuel Station Services increased by $31.9 million, or 24%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. This was primarily attributable to a $31.0 million increase in RNG marketing revenues, driven by a $17.1 million increase in RIN and LCFS minting services from higher RNG volumes (Emerald ramp-up, Prince William), and an $18.0 million increase in RIN sales from higher volume and pricing, and a $4.1 million decrease in 3rd party LCFS sales as the company chose to hold some unsold LCFS credits in inventory at the end of 2024. Also within Fuel Station Service there was a $6.8 million increase in OPAL owned stations due to higher volumes, and a $3.2 million increase in service and maintenance revenues from an increased number of stations serviced, partially offset by a $9.2 million decrease in construction revenues primarily related to timing as new 2024 projects started construction later in the year.

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Renewable Power

Revenue from Renewable Power decreased by $10.1 million, or 18%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. This change was attributable primarily to a $7.4 million decrease in Electricity Sales, of which a $4.6 million decrease was related to facility shutdowns for conversion to RNG Fuel and $2.8 million was related to lower price. Also within Renewable Power was a $2.7 million decrease in Environmental Attributes, primarily related to the same facility shutdowns mentioned above. Regulatory changes implemented by the European Union Commission took effect on November 21, 2024 that excluded biomethane produced outside of the European Union from being certified as eligible to be sold in accordance with the European Union Renewable Energy Directive. As a result, all of our contracts governing sales of ISCC Carbon Credits were terminated on November 21, 2024. Following such terminations, we expect to continue to earn revenues from sale of electricity generated by these Renewable Power facilities and the associated Environmental Attributes.

Cost of sales

RNG Fuel

Cost of sales from RNG Fuel increased by $6.5 million, or 20%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. The increase was primarily related to start of operations at our Prince William and Polk RNG facilities in 2024.

Fuel Station Services

Cost of sales from Fuel Station Services increased by $13.5 million, or 12%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. This change was attributable primarily to a $18.3 million increase in dispensing fees to generate Environmental Attributes, $3.3 million increase in FPA tolling expense, and a $2.0 million increase in Service and maintenance expenses, partially offset by an $11.0 million decrease in construction expense, in line with the decrease in construction revenues.

Renewable Power

Cost of sales from Renewable Power decreased by $4.1 million, or 11%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. This savings is primarily related to converting some of our projects from Renewable Power facilities to RNG facilities.

Project development and start up costs

Project development and start up costs increased by $14.2 million or 293%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. This is primarily due to a $13.9 million increase in virtual pipeline costs for Prince William and ITC transaction related expenses.

Selling, general, and administrative

Selling, general, and administrative increased $1.9 million or 4% for the year ended December 31, 2024 compared to the year ended December 31, 2023. This increase was primarily due to increases in corporate spending for professional services, marketing, and support for new RNG facilities.

Depreciation, amortization, and accretion

Depreciation, amortization, and accretion expense increased by a total of $3.3 million, or 23%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. This change was primarily due to new RNG facilities and OPAL owned dispensing stations, both starting operations in 2024.

Impairment loss

Impairment loss increased by a total of $2.0 million, or 100%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. This change was primarily due to the impairment of Renewable Energy facility in 2024.

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Income from equity method investments

Net income attributable to equity method investments increased by $7.7 million, or 140%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. This is primarily attributable to Emerald, which had its first full year of operations in 2024 after coming online in the second half of 2023.

Interest and financing expense, net

Interest and financing expenses, net increased by $10.3 million, or 111%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. This is primarily due to an increase in interest expense on the OPAL Term Loan of $9.8 million primarily due to an increase in outstanding debt, increase of $1.2 million in commitment and other fees, decrease of $1.0 million in interest income, partially offset by a decrease of $1.6 million on the Convertible Note Payable.

Change in fair value of derivatives, net

Change in fair value of derivatives, net decreased by $5.8 million, or 78%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. This change was attributable primarily to a lower gain in the current year associated with the mark-to-market adjustments to the earnout liabilities. These liabilities were recorded in the consolidated balance sheet upon completion of the Business Combination.

Other income

Other income decreased by $122.3 million, or 98%, for the year ended December 31, 2024 compared to the year ended December 31, 2023. This change is primarily related to a gain $122.9 million recognized on deconsolidation of VIEs, Emerald and Sapphire in 2023.

Loss on debt extinguishment

On May 30, 2023, OPAL Intermediate Holdco 2 assigned to Paragon its rights and obligations under OPAL Term Loan II. The joint venture partner of Paragon reimbursed OPAL Intermediate Holdco 2 $0.8 million as its portion of the transaction costs incurred.

The Company expensed the remaining deferred financing costs of $1.9 million as loss on debt extinguishment in its consolidated statement of operations for the year ended December 31, 2023. Additionally, we completed a debt restructuring of the OPAL Term Loan in third quarter of 2023 which was accounted for as a debt modification for the existing lenders by performing an analysis on a lender by lender basis under ASC 470-50 Debt modifications and exchanges. As a result, the Company recorded debt extinguishment of $0.3 million representing the fees allocated to the lenders who were repaid in full as part of loss on debt extinguishment in the consolidated statement of operations for the year ended December 31, 2023.

There was no loss on debt extinguishment for the year ended December 31, 2024.

Loss on warrant exchange

In March 2023, we issued 49,633 shares to certain warrant holders as consideration for their prior agreement to tender all warrants held by the warrant holders in the voluntary exchange offer which closed on December 22, 2022. We recorded $338 thousand representing the fair value of the shares issued based on the closing price on March 30, 2023 as part of Loss on warrant exchange on its consolidated statement of operations for the year ended December 31, 2023. No such loss has been recorded in 2024.

Net income attributable to redeemable non-controlling interests

Net income attributable to redeemable non-controlling interests for the year ended December 31, 2024 and 2023 is $2.9 million and $97.4 million, respectively. The net income for the years ended December 31, 2024 and 2023 reflects the net income belonging to OPAL Fuels equity holders based on pro-rata ownership.

Net income (loss) attributable to non-redeemable non-controlling interests

Net income (loss) attributable to non-redeemable non-controlling interests for the year ended December 31, 2024 increased by $0.8 million or 227%, compared to the year ended December 31, 2023. This reflects the joint venture partners'

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income (loss) in certain RNG facilities in which we sold a portion of our ownership interests but are consolidated in our financial statements. These entities for the year ended December 31, 2024, were Sunoma and Central Valley. These entities for the year ended December 31, 2023, were Sunoma and Central Valley as well as Emerald, Sapphire for the first five months of 2023. The increase was primarily attributable to higher net income earned by Sunoma.

Dividends on redeemable preferred non-controlling interests

The dividends on redeemable preferred non-controlling interests for the year ended December 31, 2024 decreased by $0.5 million or 5%. They carry an 8% dividend payable quarterly. This decrease is primarily due to lower interest accrued on paid-in-kind interest in the current period compared to the same prior-year period as the dividends are being paid quarterly instead of being paid-in-kind.

Liquidity and Capital Resources

Liquidity

As of December 31, 2024, our liquidity was $223.6 million consisting of $178.4 million of unused capacity under our $450 million senior secured credit facility, $20.9 million of unused capacity under the associated revolver, and 24.3 million of cash, cash equivalents. Refer to Note 7.

We expect that our available cash together with our other assets, expected cash flows from operations, and access to expected sources of capital will be sufficient to meet our existing commitments for a period of at least twelve months from the date of this report. Any reduction in demand for our products or our ability to manage our production facilities may result in lower cash flows from operations which may impact our ability to make investments and may require changes to our growth plan.

To fund future growth, we anticipate seeking additional capital through equity or debt financings. The amount and timing of our future funding requirements will depend on many factors, including the pace and results of our project development efforts. We may be unable to obtain any such additional financing on acceptable terms or at all. Our ability to access capital when needed is not assured and, if capital is not available when, and in the amounts, needed, we could be required to delay, scale back or abandon some or all of our development programs and other operations, which could materially harm our business, prospects, financial condition, and operating results.

As part of our operations we have arrangements for office space for our corporate headquarters under the Administrative Services Agreement as well as operating leases for office space, warehouse space, and our vehicle fleet.

We intend to make payments under our various debt instruments when due and pursue opportunities for earlier repayment and/or refinancing if and when these opportunities arise.

OPAL Term Loan

On March 3, 2025, OPAL Fuels Intermediate HoldCo LLC, as the borrower (the “Borrower”), certain subsidiaries of the Borrower, as guarantors (the “Guarantors”), the lenders and issuers of letters of credit party thereto and Bank of America, N.A. as the administrative agent (the “Administrative Agent”) entered into that certain Amendment No. 1 to Credit and Guarantee Agreement (the “Credit Agreement Amendment”), with respect to that certain Credit and Guarantee Agreement (the “Credit Agreement”) dated September 1, 2023, by and among the Borrower, the Administrative Agent, the financial institutions from time to time parties thereto as lenders and as issuers of letters of credit, and the other agents and persons from time to time party thereto (as amended, restated, amended and restated, supplemented or otherwise modified and in effect from time to time).

The Credit Agreement Amendment makes certain changes to the applicability of certain financial covenants and modifies other covenants to clarify the use of loan proceeds. Additionally, the Credit Agreement Amendment permits the organizational restructuring of the Guarantors in a manner designed to facilitate the sale of federal investment tax credits and the ability to raise additional future capital.

The Credit Agreement Amendment also eases the conditions precedent to making new Projects eligible for borrowing under the Credit Agreement, extends the availability period for delay draw term loans under the Credit Agreement through March 5, 2026, and extends the commencement of repayment of such term loans until March 31, 2026.

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In connection with the Credit Agreement Amendment, the Borrower paid the Administrative Agent, for the account of each lender, a one-time nonrefundable fee of $1.2 million.

Sunoma Loan

On August 27, 2020, Sunoma, an indirect wholly-owned subsidiary of the Company entered into a debt agreement (the "Sunoma Loan Agreement") with Live Oak Banking Company for an aggregate principal amount of $20 million. Sunoma paid $0.635 million in financing fees. The amounts outstanding under the Sunoma Loan are secured by the assets of Sunoma. On July 19, 2022, Sunoma completed the conversion of the construction loan into a permanent loan and increased the commitment from $20 to $23 million. The maturity date is July 19, 2033. The outstanding loans under the Sunoma Loan Agreement bear interest at an annual fixed rates of 7.8%, and 8.2% per annum during the term.

The Sunoma Loan Agreement contains certain financial covenants which require Sunoma to maintain (i) a maximum debt to net worth ratio not to exceed 5:1, (ii) a minimum current ratio not less than 1.0 and (iii) a minimum debt service coverage ratio of trailing four quarters not less than 1.25. As of December 31, 2024, Sunoma is in compliance with the financial covenants under the Sunoma Loan Agreement.

As of December 31, 2024 and December 31, 2023, the outstanding loan balance (current and non-current) excluding deferred financing costs was $20.8 and $22.5 million, respectively.

The significant assets of Sunoma are parenthesized in the consolidated balance sheets as of December 31, 2024 and December 31, 2023. See Note 12. Variable Interest Entities for additional information.

Redeemable Series A Preferred Units of OPAL Fuels LLC

In November 2021, NextEra subscribed for an aggregate of $100,000,000 of Series A preferred units issued by OPAL Fuels LLC. The Series A preferred units have limited rights to prevent OPAL Fuels LLC from taking certain actions including (i) major issuances of new debt or equity (ii) executing transactions with affiliates which are not at arm-length basis (iii) major disposition of assets and (iv) major acquisition of assets outside of OPAL Fuels LLC’s primary business. The Series A preferred units are entitled to receive dividends at the rate of 8% per annum. Dividends begin accruing for each unit from the date of issuance and are payable each quarter end regardless of whether they are declared. The dividends are mandatory and cumulative. The Company was allowed to elect to issue additional Series A preferred units ( paid-in-kind) in lieu of cash for the first eight dividend payment dates. As of December 31, 2024 and 2023, there was accrued preferred dividend payable of $0 and $2,013, respectively.

At any time after issuance, OPAL Fuels LLC may redeem the Series A preferred units for a price equal to original issue price of $100 per unit plus any accrued and unpaid dividends. Upon written notice from NextEra at any time after November 29, 2025, we would be required to redeem the Series A preferred units. In the event the Company does not redeem the Series A preferred units when requested, Nextera will have the following rights and remedies: (1) NextEra’s affiliate may extend the RNG Marketing Agreement by 12 months; or (2) the dividend rate would increase depending on the length of time the Series A preferred units remain unredeemed to up to 20% per annum, and if more than $25,000,000 preferred equity is outstanding for more than six months after November 29, 2025, NextEra may appoint a director to OPAL Fuel Inc.’s Board of Directors; or (3) NextEra may convert the Series A preferred equity into common equity of the OPAL Fuels LLC at a conversion price at a 20% to 30% discount to their value (the discount is 20% during the first 12 months after November 29, 2025, 25% for the next 12 months thereafter and 30% thereafter).

Cash Flows

The following table presents the Company's cash flows for the years ended December 31, 2024 and 2023:

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Net Cash Provided by Operating Activities

Net cash provided by operating activities for the year ended December 31, 2024 was $33.0 million, a decrease of $5.2 million compared to net cash used in operating activities of $38.3 million for the year ended December 31, 2023. The decrease in cash provided by operating activities was primarily due to lower year over year operating income of $112.7 million and a negative working capital changes of $16.6 million offset by increase of $122.3 million in non-cash expenses and $2.1 million increase of portion of distributions from equity method investments allocated to operating activities.

Net Cash Used in Investing Activities

Net cash used in investing activities for the year ended December 31, 2024 was $134.6 million, an increase of $60.4 million compared to the $74.1 million used in investing activities for the year ended December 31, 2023. This was primarily driven by a decrease in cash from sale of short term investments of $45.2 million, higher payments made for the construction of various RNG generation and dispensing facilities in 2024 compared to 2023 of $13.4 million, an increase of $13.3 million in contributions to equity method investments, a $0.5 million decrease in distributions from equity method investments, offset by a decrease from deconsolidation of VIEs of $11.9 million in 2023.

Net Cash Provided by Financing Activities

Net cash provided by financing activities for the year ended December 31, 2024 was $83.5 million, an increase of $77.6 million compared to the $5.9 million provided by financing activities for the year ended December 31, 2023. This increase was primarily driven by an increase of $158.9 million due to lower repayments on the Senior Secured Facility, the Convertible Note payable and OPAL Term Loan facilities in current year, an increase of $16.4 million due to no payment on termination of put options in current year, an increase of $3.4 million due to lower preferred dividend payments in the current year, offset by a $87.2 million decrease in proceeds from the OPAL Term Loan, net of issuance costs, decrease in proceeds from non-controlling interests of $12.8 million, and a decrease of $0.8 million in reimbursement of financing costs by a joint venture partner.

Capital expenditures and other cash commitments

We require cash to fund our capital expenditures, operating expenses, working capital and other requirements, including costs associated with fuel sales; outlays for the design and construction of new Fueling Stations and RNG production facilities; debt repayments and repurchases; maintenance of our electrification production facilities supporting our operations, including maintenance and improvements of our infrastructure; supporting our sales and marketing activities, including support of legislative and regulatory initiatives; any investments in other entities; any mergers or acquisitions, including acquisitions to expand our RNG production capacity; pursuing market expansion as opportunities arise, including geographically and to new customer markets; to fund other activities or pursuits and for other general corporate purposes.

As of December 31, 2024, we currently anticipate spending approximately $194 million in capital expenditures for the next 12 months for projects and fuel stations currently under construction and our share of contributions in our equity method investment projects. These expenditures do not include any expected contributions from our joint venture partners and primarily relate to our development and construction of new renewable energy facilities and the purchase of equipment used in our Fueling Station services and Renewable Power operations.

In addition to the above, we also have lease commitments on our vehicle fleets and office leases and quarterly amortization payment obligations under various debt facilities. Please see Note 7. Borrowings and Note 8. Leases to our consolidated financial statements for additional information.

We plan to fund these expenditures primarily through cash on hand, cash generated from operations and availability under existing debt facilities.

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

In this Management's Discussion and Analysis of Financial Condition and Results of Operations section, references to "OPAL", "we", "us", "our", and the "Company" refer to OPAL Fuels Inc. and its consolidated subsidiaries. The following discussion and analysis should be read in conjunction with our consolidated financial statements and related notes set forth in Part II, Item 8 - "Financial Statements and Supplementary Data" and the risk factors identified in Part I, Item 1A - "Risk Factors" of this Annual Report. For further discussion regarding our results of operations for the year ended December 31, 2022 as compared to the year ended December 31, 2021, refer to Part II, Item 7 - "Management’s Discussion and Analysis of Financial Condition and Results of Operations" in our Annual Report on Form 10-K for the fiscal year ended December 31, 2022, as filed with the SEC on March 29, 2023. In addition to historical information, this discussion and analysis includes certain forward-looking statements which reflect our current expectations. The Company's actual results may materially differ from these forward-looking statements.

Overview

The Company is a vertically integrated leader in the capture and conversion of biogas into low carbon intensity Renewable Power and renewable natural gas (RNG). OPAL Fuels is also a leader in the marketing and distribution of RNG to heavy duty trucking and other hard to de-carbonize industrial sectors. RNG is chemically identical to the natural gas used for cooking, heating homes and fueling natural gas engines, with one significant difference: RNG is produced by recycling harmful methane emissions created by decaying organic waste as opposed to natural gas which is a fossil fuel pumped from the ground. We have participated in the biogas-to-energy industry for over 20 years.

Biogas is generated by microbes as they break down organic matter in the absence of oxygen, and comprised of non-fossil waste gas, with high concentrations of methane, which is the primary component of RNG and the source for combustion utilized by Renewable Power plants to generate electricity. Biogas can not only be collected and processed to remove impurities for use as RNG (a form of high-Btu fuel) and injected into existing natural gas pipelines as it is fully interchangeable with fossil natural gas, but partially treated biogas can be used directly in heating applications (as a form of medium-Btu fuel) or in the production of Renewable Power. Our principal sources of biogas are (i) landfill gas, which is produced by the decomposition of organic waste at landfills, and (ii) dairy manure, which is processed through anaerobic digesters to produce the biogas.

We also design, develop, construct, operate and service Fueling Stations for trucking fleets across the country that use natural gas to displace diesel as their transportation fuel. We have participated in the alternative vehicle fuels industry for approximately 13 years and have established an expanding network of Fueling Stations for dispensing RNG. In addition, we have recently begun implementing design, development, and construction services for hydrogen fueling stations, and we are pursuing opportunities to diversify our sources of biogas to other waste streams.

As of December 31, 2023, we owned and operated 25 projects, eight of which are RNG projects and 17 of which are Renewable Power Projects. As of that date, our RNG projects in operation had a design capacity of 5.2 million MMBtus per year and our Renewable Power Projects in operation had a nameplate capacity of 112.5 MW per hour. In addition to these projects in operation, we are actively pursuing expansion of our RNG-generating capacity and, accordingly, have a portfolio of RNG projects in construction or in development, with eight of our current Renewable Power Projects being considered candidates for conversion to RNG projects in the foreseeable future.

Recent developments

Inflation Reduction Act

The Inflation Reduction Act (the "IRA") was signed into law on August 16, 2022. The bill invests nearly $369 billion in energy and climate policies. The provisions of the IRA are intended to, among other things, incentivize domestic clean energy investment, manufacturing, and deployment. The IRA incentivizes the deployment of clean energy technologies by extending and expanding federal incentives such as ITCs and the PTC. We view the enactment of the IRA as favorable for the overall business climate for the renewable energy industry. However, there is uncertainty related to the applicability of the IRA to our current and planned projects and the scope of the IRA and its interpretations may change if there is a change in the U.S. administration or if government agencies’ authority to interpret federal law is restricted as a result of the Supreme Court’s review of the Chevron doctrine under which federal government agencies have been awarded board authority to interpret broad or ambiguous legislation. We may also continue to experience a delay in our sales cycles and new award activity as our customers consider the applicability of the IRA and as financing projects may take longer as

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result of this uncertainty. The IRA may increase the competition in our industry and as such increase the demand and cost for labor, equipment and commodities needed for our projects.

On November 17, 2023, the Treasury and the IRS proposed regulations regarding ITCs on renewable energy projects where IRS specified certain types of RNG equipment are ineligible for ITCs which could negatively impact the profitability of our RNG business and our ability to finance our RNG projects. On February 16, 2024, the Treasury and the IRS released a correction to the proposed regulations clarifying that certain of such equipment may be eligible for ITCs. These regulations are merely proposed, and Treasury and the IRS are collecting and reviewing comments received regarding the proposed regulations. The proposed regulations also contain provisions that we believe create uncertainty relating to the ownership, installation or modification of equipment and property on which ITCs can be claimed.

If the final regulations are enacted in a form that limits, in whole or in part, the amount of ITCs for certain of our construction costs, this would reduce the amount of ITCs available and thus could have a material adverse effect on our operations and our business.

ATM Program

On November 17, 2023, we entered into an At Market Issuance Sales Agreement (the “Sales Agreement”) with each of B. Riley Securities, Inc., Cantor Fitzgerald & Co. and Stifel, Nicolaus & Company, Incorporated (each, an “Agent,” and collectively, the “Agents”) pursuant to which we may issue and sell shares of our Class A common stock having an aggregate offering price of up to $75 million from time to time through the Agents.

The issuance and sale of Class A common stock under the Sales Agreement are effected pursuant to the registration statement on Form S-3 (File No. 333-273584) that we filed with the United States Securities and Exchange Commission (the “SEC”) on August 1, 2023 as amended on August 11, 2023, and declared effective by the SEC on September 6, 2023, together with a related prospectus supplement. Sales of our Class A common stock through the Agents may be made by any method that is deemed an “at the market offering” as defined in Rule 415(a)(4) promulgated under the Securities Act of 1933, as amended. We will pay each Agent, upon the sale by such Agent of Class A common stock pursuant to the Sales Agreement, an amount equal to up to 3.0% of the gross proceeds of each such sale of Class A common stock.

From the date of execution of the Sales Agreement through December 31, 2023, we issued and sold 90,103 shares of Class A common stock for total proceeds, net of commissions and related costs of $0.4 million.

Asset Sale and Purchase Agreement

On October 20, 2023, our wholly-owned subsidiary entered into an Asset Purchase and Sale Agreement (for the purposes of this paragraph, the “Agreement”) with Washington Gas Light Company ("WGL"). The subsidiary is currently constructing a production facility (the “Facility”) at the Prince William County landfill located in Manassas, Virginia, on a parcel located on the landfill, to process landfill gas into RNG. The Agreement obligates the subsidiary to develop, plan and permit a gas pipeline extension and associated interconnection facilities (the “Pipeline Project”) to deliver RNG from the Facility to an interconnection point on WGL’s pipeline. Per the terms and conditions of the Agreement, WGL will purchase the Project from the subsidiary after the final completion of the Project at a purchase price of $25 million. The closing is contingent upon approval of the Agreement by the Virginia State Corporation Commission, as well as the satisfaction of customary closing conditions, and the outside closing date is on or prior to October 20, 2024. As of December 31, 2023, the Company recorded capital expenditure of $1.8 million which is included in its Property, Plant and Equipment on our consolidated balance sheet.

Critical Accounting Policies and Estimates

The discussion and analysis of our financial condition and results of operations is based upon our consolidated financial statements, which have been prepared in accordance with generally accepted accounting principles in the United States ("U.S. GAAP") and the rules and regulations of the SEC, which apply to interim financial statements. The preparation of those financial statements requires us to make estimates and judgments that affect the reported amounts of assets and liabilities, revenues, expenses and warrants and related disclosure of contingent assets and liabilities at the date of our financial statements. Actual results may differ from these estimates under different assumptions and conditions.

Critical accounting policies are those that reflect significant judgments of uncertainties and potentially result in materially different results under different assumptions and conditions. We have described below what we believe are our most critical accounting policies, because they generally involve a comparatively higher degree of judgment in their

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application. For a detailed description of all our accounting policies, see Note 2. Summary of Significant Accounting Policies, to our consolidated financial statements included herein.

Revenue Recognition

Renewable Power

We sell Renewable Power produced from LFG-fueled power plants to utility companies through our PPAs. Revenue is recognized based on contract specified rates per MWh when delivered to the customer, as this considered to be completion of the performance obligation. Certain PPAs contain a lease element which we account for as operating lease revenue on a straight-line basis over the lease term. The Company utilizes commodity swap contracts to hedge against the unfavorable price fluctuations in market prices of electricity. The Company does not apply hedge accounting to these contracts. As such, unrealized and realized gain (loss) is recognized as component of Renewable Power revenues in the consolidated statement of operations.

Transportation fuel — Fuel Purchase Agreements

We own Fueling Stations for use by customers under fuel sale agreements. We bill these customers at an agreed upon price for each gallon sold and recognize revenue based on the amounts invoiced in accordance with the “right to invoice” practical expedient. These contracts may contain an embedded lease of the equipment which we account for as operating lease revenue. For some public stations where there is no contract with the customer, we recognize revenue at the point in time that the customer takes control of the fuel.

Interstate Gas Pipeline Delivery

We have agreements with two natural gas producers whereby we are contracted to transport the producers’ gas to an agreed delivery point on an interstate gas pipeline via our RNG gathering system. Revenue is recognized over time using the output method which is based on quantity of natural gas transported.

Environmental Attributes

We generate RECs, RINs, ISCC Carbon Credits and LCFS credits. These Environmental Attributes are sold to third parties that utilize these credits in order to comply with federal and state requirements. Revenue is recognized at the point in time when the credits are transferred to and accepted by the third party buyer. We also provide Environmental Attributes generation and monetization services to customers that own renewable gas generation facilities and we recognize revenues from these services when the credits are minted on behalf of the customer.

Operation and Maintenance

We have operating and maintenance agreements pursuant to which we operate, maintain, and repair landfill site gas collection systems. Revenue is based on the volume per million British thermal units (“MMBtu”) of landfill gas collected and the MWhs produced at that site. This revenue is recognized as Renewable Power revenue when landfill gas is collected and Renewable Power is delivered. In addition, we have operations and maintenance agreements in which we are contracted to maintain and repair Fueling Stations. Revenue is based on the volumes of gas dispensed at the site. This revenue is recognized as Fuel Station Services revenue when the site dispenses gas.

Construction Type Contracts — Third Party

We have various fixed price contracts for the construction of fueling stations for customers. Revenue from these contracts, including change orders, are recognized over time, with progress measured by the percentage of cost incurred to date to estimated total cost for each contract.

Impairment of Goodwill

When a business is acquired, goodwill is recognized to reflect any future economic benefits that are not separately recognized, such as synergies. For the purposes of impairment testing, U.S. GAAP requires goodwill to be allocated to reporting unit(s) at the acquisition date and to be tested for impairment at least annually, and in between annual tests whenever events or changes in circumstances indicate that the respective reporting unit’s fair value is less than its

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carrying value. Significant judgment is required when identifying the reporting units for goodwill allocation, during our assessment of relevant events and circumstances for qualitative impairment indicators, and when estimating the undiscounted cash flows of reporting unit(s) for quantitative impairment assessments.

Our goodwill impairment assessment is performed during the fourth quarter of each year or at the time facts or circumstances indicate that a reporting unit’s goodwill may be impaired. In conformity with GAAP, we generally first perform a qualitative assessment over whether it is more likely than not that a reporting unit’s fair value is less than its carrying value to determine if a quantitative assessment is required. If, after performing the qualitative assessment, we conclude it is more likely than not that the fair value of the reporting unit is less than its carrying value, then a quantitative test is required. Our qualitative assessment includes evaluation of relevant events and circumstances, such as, macroeconomic conditions, industry and market considerations, cost factors, overall performance, and other relevant events.

If applying a quantitative assessment, we would estimate a reporting unit’s fair value based on the income approach. With this approach, the fair value measurement is based on significant inputs that are not observable in the market and thus the fair value measurement is categorized within Level 3 of the fair value hierarchy. Our assumptions include future cash flow projections, a discount rate range based on the weighted average cost of capital, and a terminal value based on a range of terminal earnings before interest, taxes, depreciation, and amortization.

As of December 31, 2023, we performed a qualitative assessment for Goodwill in our RNG Fuel and Fuel Station Services segments and determined that there are no impairment triggers present and therefore no quantitative assessment was performed. Based on the qualitative assessment, we determined that no impairment is necessary on the goodwill recorded in the books as of December 31, 2023.

Impairment of Long-Lived Assets

Our long-lived assets held and used with finite useful lives including plant equipment, buildings, patents, and PPAs are reviewed for impairment whenever events or changes in circumstances indicate that the asset group may not be recoverable. In determining the asset group, we assess the interdependency of revenues between assets, shared cost structures, the interchangeability of assets used in operations, and how assets are managed and utilized by the business. Events that may trigger a recoverability assessment include a significant adverse change in the extent or manner in which the long-lived asset group is being used or in its physical condition, and the expectation that, more likely than not, the long-lived asset or asset group will be sold or otherwise disposed of significantly before the end of its previously estimated useful life. Recoverability of long-lived assets to be held and used is measured by a comparison of the carrying amount of an asset group to future net undiscounted cash flows expected to be generated by the asset group. Our cash flow estimates reflect conditions and assumptions that existed as of the measurement date which is the same as the triggering event date. The assets are considered recoverable and an impairment loss is not recognized when the undiscounted net cash flows exceed the net carrying value of the asset group. If the assets are not recoverable, then an impairment loss is recognized to the extent that the carrying value of the asset group exceeds its fair value. We base the fair value of our assets or asset groups off of the estimated discounted future cash flows using market participant assumptions. Assets disposed of are reported at the lower of the carrying amount or fair value less selling costs. Significant judgment is required when determining asset group composition, during our assessment of relevant events and circumstances, when determining an appropriate discount rate, and when estimating the undiscounted and discounted future cash flows of the asset group.

Based on our assessment for the year ended December 31, 2023, there is no impairment recorded on our Plant, Property and Equipment.

Fair Value Measurements

The objective of a fair value measurement is to estimate the exit price, which is the price that would be received to sell an asset or paid to transfer a liability that the Company holds, in an orderly market transaction at the measurement date. We follow GAAP guidance which establishes a three-tier hierarchy for inputs used in fair value measurements, as well as prioritizes valuation techniques that maximize the use of observable inputs and minimizes the use of unobservable inputs. In summary, level 1 inputs are considered the most observable inputs and are more specifically the unadjusted quoted price for identical assets or liabilities in an active market the Company has access to. Level 2 inputs are considered less observable inputs such as quoted prices for similar assets or liabilities in an active market the Company has access to. Lastly, level 3 inputs are unobservable inputs in which little to no market activity exists for the asset or liability at the measurement date. As such, level 3 estimates are subject to a more significant level of estimation uncertainty. Furthermore,

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when multiple inputs are used and are categorized in different levels of the input hierarchy, then the fair value measurement in its entirety is categorized in the same level as its lowest level input that is significant to the fair value measurement. Our assessment of the significance of an input to a fair value measurement requires judgment and may affect the fair value measurement’s placement in the fair value hierarchy.

Refer to Note 9. Derivative Financial Instruments and Fair Value Measurements, to our consolidated financial statements, for details on our assets and liabilities regularly recorded at fair value and the respective placements in the fair value hierarchy.

Income Taxes

The Company accounts for income taxes in accordance with ASC Topic 740, Accounting for Income Taxes (“ASC Topic 740”), which requires the recognition of tax benefits or expenses on temporary differences between the financial reporting and tax bases of its assets and liabilities by applying the enacted tax rates in effect for the year in which the differences are expected to reverse. Such net tax effects on temporary differences are reflected on the Company’s consolidated balance sheets as deferred tax assets and liabilities. Deferred tax assets are reduced by a valuation allowance when the Company believes that it is more-likely-than-not that some portion or all of the deferred tax assets will not be realized. The Company calculates the interim tax provision in accordance with the provisions of ASC Subtopic 740-270, Income Taxes; Interim Reporting. For interim periods, the Company estimates the annual effective income tax rate and applies the estimated rate to the year-to-date income or loss before income taxes.

Refer to Note 15. Income Taxes, to our consolidated financial statements, for additional information.

Emerging Growth Company Status

We are an emerging growth company as defined in the JOBS Act. The JOBS Act provides emerging growth companies with certain exemptions from public company reporting requirements for up to five fiscal years while a company remains an emerging growth company. As part of these exemptions, we need only provide two fiscal years of audited financial statements instead of three, we have reduced disclosure obligations such as for executive compensation, and we are not required to comply with auditor attestation requirements from Section 404(b) of the Sarbanes-Oxley Act regarding our internal control over financial reporting. Additionally, the JOBS Act has allowed us the option to delay adoption of new or revised financial accounting standards until private companies are required to comply with new or revised financial accounting standards.

Use of Estimates

The preparation of the consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the consolidated financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The significant estimates and assumptions of the Company relate to the useful lives of property, plant and equipment, goodwill impairment, fair value of the deconsolidated VIEs, the value of stock-based compensation, asset retirement obligations and the fair value of derivatives including earnout liabilities and commodity swap contracts.

Key Factors and Trends Influencing our Results of Operations

The principal factors affecting our results of operations and financial condition are the markets for RNG, Renewable Power, and associated Environmental Attributes, and access to suitable biogas production resources. Additional factors and trends affecting our business are discussed in "Risk Factors" elsewhere in this report.

Market Demand for RNG

Demand for our converted biogas and associated Environmental Attributes, including RINs and LCFS credits, is heavily influenced by United States federal and state energy regulations together with commercial interest in renewable energy products. Markets for RINs and LCFS credits arise from regulatory mandates that require refiners and blenders to incorporate renewable content into transportation fuels. The EPA annually sets proposed renewable volume obligations ("RVOs") for D3 (cellulosic biofuel with a 60% greenhouse gas (“GHG”) reduction requirement) RINs in accordance with the mandates established by the Energy Independence and Security Act of 2007. In June 2023, the EPA set RVOs for 2023 through 2025 via a new Set rule. This 3 year RVO is expected to reduce volatility in RIN pricing for the associated period. On the state level, the economics of RNG are enhanced by low-carbon fuel initiatives, particularly well-established

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programs in California and Oregon (with several other states also actively considering LCFS initiatives similar to those in California, Washington and Oregon). Federal and state regulatory developments could result in significant future changes to market demand for the RINs and LCFS credits we produce. This would have a corresponding impact to our revenue, net income, and cash flow.

Transportation, including heavy-duty trucking, generates approximately 30% of overall CO₂ and other climate-harming GHG emissions in the United States, and transitioning this sector to low and negative carbon fuels is a critical step towards reducing overall global GHG emissions. The adoption rate of RNG-powered vehicles by commercial transportation fleets will significantly impact demand for our products.

We are also exposed to the commodity prices of natural gas and diesel, which serve as alternative fuel for RNG and therefore impact the demand for RNG.

Renewable Power Markets

We also generate revenues from sales of Renewable Power generated by our biogas-to-Renewable Power projects, and associated ISCC Carbon Credits and RECs. ISCC Carbon Credits and RECs exist because of legal and governmental regulatory requirements in Europe and the United States, respectively, and a change in law or in governmental policies concerning Renewable Power, LFG, or ISCC Carbon Credits or RECs could affect the market for, and the pricing of, such power and credits.

We periodically evaluate opportunities to convert existing Renewable Power projects to RNG production. We have been negotiating with several of our landfill and Renewable Power counterparties to enter into arrangements that would enable the LFG resource to produce RNG. Changes in the price we receive for Renewable Power, associated ISCC Carbon Credits and RECs, together with the revenue opportunities and conversion costs associated with converting our LFG sites to RNG production, could have a significant impact on our future profitability.

Regulatory landscape

We operate in an industry that is subject to and currently benefits from environmental regulations. Government policies can increase demand for our products by providing incentives to purchase RNG and Environmental Attributes. These government policies are modified and in flux constantly and any adverse changes to these policies could have a material effect the demand for our products. For more information, see our risk factor titled "The financial performance of our business depends upon tax and other government incentives for the generation of RNG and Renewable Power, any of which could change at any time and such changes may negatively impact our growth strategy." Government regulations have become increasingly stringent and complying with changes in regulations may result in significant additional operating expenses.

Seasonality

We experience seasonality in our results of operations. Sale of RNG may be impacted by higher consumption by some of our customers during summer months. Additionally, the price of RNG is higher during the fall and winter months due to increase in overall demand for natural gas during the winter months. Revenues generated from our renewable electricity projects in the northeast U.S., all of which sell electricity at market prices, are affected by warmer and colder weather, and therefore a portion of our quarterly operating results and cash flows are affected by pricing changes due to regional temperatures. These seasonal variances are managed in part by certain off-take agreements at fixed prices.

Key Components of Our Results of Operations

We generate revenues from the sale of RNG fuel, Renewable Power, and associated Environmental Attributes, as well as from the construction, fuel supply, and servicing of Fueling Stations for commercial transportation vehicles using natural gas to power their fleets. These revenue sources are presented in our statement of operations under the following captions:

•RNG Fuel. The RNG Fuel segment includes RNG supply as well as the associated generation and sale of commodity natural gas and environmental credits, and consists of:

◦RNG Production Facilities – the design, development, construction, maintenance and operation of facilities that convert raw biogas into pipeline quality natural gas; and

◦Our interests in both operating and construction projects.

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•Fuel Station Services. Through our Fuel Station Services segment, we provide construction and maintenance services to third-party owners of vehicle Fueling Stations and performs fuel dispensing activities including generation and minting of environmental credits. This segment includes:

◦Manufacturing division that builds Compact Fueling Systems and Defueling systems;

◦Design/Build contracts where we serve as general contractor for construction of Fueling Stations, typically structured as Guarantee Maximum Price or fixed priced contracts for customers, generally lasting less than one year;

◦Service and maintenance contracts for RNG/CNG Fueling Stations; and

◦RNG and CNG Fuel Dispensing Stations - This includes both the dispensing (or sale) of RNG, CNG, and environmental credit generation and monetization. We operate Fueling Stations that dispense both CNG and RNG fuel for vehicles.

•Renewable Power. The Renewable Power segment generates renewable power and associated Environmental Attributes such as ISCC Carbon Credits and RECs through combustion of biogas from landfills which is then sold to public utilities throughout the United States.

Our costs of sales associated with each revenue category are as follows:

•RNG Fuel. Includes royalty payments to biogas site owners for the biogas we use; service provider costs; salaries and other indirect expenses related to the production process, utilities, transportation, storage, and insurance; and depreciation of production facilities.

•Fuel Station Services. Includes equipment supplier costs; service provider costs; and salaries and other indirect expenses.

•Renewable Power. Includes royalty payments, land usage costs; service provider costs; salaries and other indirect expenses related to the production process; utilities; and depreciation of production facilities.

Project development and start up costs includes certain development costs such as legal, consulting fees for joint venture structuring, royalties to the landfill owner, fines, settlements, site lease expenses and certification costs on our RNG projects under construction. Additionally, the Company also incurs certain expenses on new RNG projects that went operational for the first two years such as virtual pipeline costs (incurred until a physical interconnect pipeline is built) and ramp up costs incurred during the certification period.

Selling, general, and administrative expense consists of costs involving corporate overhead functions, including the cost of services provided to us by an affiliate, and marketing costs.

Depreciation and amortization primarily relate to depreciation associated with property, plant, and equipment and amortization of acquired intangibles arising from PPAs and interconnection contracts. We are in the process of expanding our RNG and Renewable Power production capacity and expect depreciation costs to increase as new projects are placed into service.

Concentration of customers and associated credit risk

The following table summarizes the percentage of consolidated accounts receivable, net by customers that equal or exceed 10% of the consolidated accounts receivable, net as of December 31, 2023 and 2022. No other single customer accounted for 10% or greater of our consolidated accounts receivables in these periods:

(1) Relates to sales of environmental attributes under Purchase and Sale agreement with NextEra.

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The following table summarizes the percentage of consolidated revenues from customers that equal 10% or greater of the consolidated revenues in the period. No other single customer accounted for more than 10% of consolidated revenues in these periods:

Results of Operations for the years ended December 31, 2023 and 2022:

Operational data

The following table summarizes the operational data achieved for the years ended December 31, 2023 and 2022:

Landfill RNG Facility Capacity and Utilization Summary

(1) Design Capacity for RNG facilities is measured as the volume of feedstock biogas that the facility is capable of accepting at the inlet and processing during the associated period. Design Capacity is presented as OPAL’s ownership share (i.e., net of joint venture partners’ ownership) of the facility and is calculated based on the number of days in the period. New facilities that come online during a quarter are pro-rated for the number of days in commercial operation.

(2) Inlet Design Capacity Utilization is measured as the Volume of Inlet Gas for a period, divided by the total Design Capacity for such period. The Volume of Inlet Gas varies over time depending on, among other factors, (i) the quantity and quality of waste deposited at the landfill, (ii) waste management practices by the landfill, and (iii) the construction, operations and maintenance of the landfill gas collection system used to recover the landfill gas. The Design Capacity for each facility will typically be correlated to the amount of landfill gas expected to be generated by the landfill during the term of the related gas rights agreement. The Company expects Inlet Design Capacity Utilization to be in the range of 75-85% on an aggregate basis over the next several years. Typically, newer facilities perform at the lower end of this range and demonstrate increasing utilization as they mature and the biogas resource increases at open landfills.

(3) Utilization of Inlet Gas is measured as RNG Fuel Volume Produced divided by the Volume of Inlet Gas. Utilization of Inlet Gas varies over time depending on availability and efficiency of the facility and the quality of landfill gas (i.e., concentrations of methane, oxygen, nitrogen, and other gases). The Company generally expects Utilization of Inlet Gas to be in the range of 80% to 90%.

(4) Data not available for the Company's dairy projects, i.e., Sunoma and Biotown. Total RNG fuel design capacity for the three and twelve months ended December 31, 2023 is 1.3 million MMBtu and 4.3 million MMBtu, respectively. Including Sunoma and Biotown, RNG fuel volume produced is 0.8 and 2.7 million MMBtu for the three and twelve months ended December 31, 2023, respectively.

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(1) Design Capacity for Renewable Power facilities is the manufacturer’s expected capacity at ISO conditions for each facility and may not reflect actual production from the projects, which depends on many variables including, but not limited to, (i) quantity and quality of the biogas, (ii) operational up-time of the facility, including dispatch and maintenance downtime and (iii) actual efficiency of the facility.

(2) Design Capacity Utilization for Renewable Power facilities is measured as Renewable Power Produced divided by Design Capacity for the period. Given (i) built-in un-utilized capacity from historical designs, (ii) availability (a function of higher maintenance requirements compared to RNG facilities) and (iii) commencement of operations of the Emerald RNG facility, which will result in low levels of dispatch for the Arbor Hills facility (which will operate on a standby basis but remain in the operating portfolio), the Company’s Design Capacity Utilization is expected to remain below 50%.

RNG projects

Below is a table setting forth the RNG projects in operation and construction in our portfolio:

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(1) Reflects the Company’s ownership share of design capacity for projects that are not 100% owned by the Company (i.e., net of joint venture partners’ ownership). Design capacity is measured as the volume of feedstock biogas that the plant is capable of accepting at the inlet and processing and may not reflect actual production of RNG from the projects, which will depend on many variables including, but not limited to, (i) quantity and quality of the biogas, (ii) operational up-time of the facility and (iii) actual efficiency of the facility.

(2) We record our ownership interests in these projects as equity method investments in our consolidated financial statements.

(3) Emerald completed commissioning and commenced operations during the third quarter of 2023.

(4) This project has provisions that will adjust or “flip” the percentage of distributions to be made to us over time, typically triggered by achievement of hurdle rates that are calculated as internal rates of return on capital invested in the project.

(5) Expected Commercial Operation Date (“COD”) for commencement of the RNG projects in construction is based on the Company’s estimate as of the date of this report. CODs are estimates and are subject to change as a result of, among other factors out of the Company’s control: (i) regulatory/permitting approval timing, (ii) disruption in supply chains and (iii) construction timing.

(6) Please see Item 3: Legal Proceedings and Note 17 - Commitments and Contingencies to the financial statements.

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Renewable Power Projects

Below is a table setting forth the Renewable Power projects in operation in our portfolio:

(1) Nameplate capacity is the manufacturer’s expected capacity at ISO conditions for each facility and may not reflect actual production from the projects, which depends on many variables including, but not limited to, (i) quantity and quality of the biogas, (ii) operational up-time of the facility and (iii) actual productivity of the facility.

(2) We have determined that some of our Renewable Power Projects are currently RNG conversion candidates. The Company identifies suitable RNG conversion candidates based on highest return of capital which is driven by certain factors including, but not limited to (i) the quantity and quality of LFG, (ii) the proximity to pipeline interconnect and (iii) the ability to enter into contracts, including site leases and gas rights agreements, with host sites. The Company may change its decision to convert a Renewable Power Project into an RNG project in the future. The Company believes disclosing renewable power conversion candidates provides visibility into the effect of those conversions on the existing Renewable Power portfolio.

(3) Although the RNG conversion is completed, it is currently contemplated that the Arbor Hills renewable power plant will continue limited operations on a stand-by, emergency basis through March of 2031.

(4) Prince William I renewable power plant discontinued operations in Q1 2024.

(5) Prince William II discontinued operations in Q1 2024.

(6) It is expected to complete construction in fourth quarter of 2024.

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Comparison of the Years Ended December 31, 2023 and 2022

The following table presents the period-over-period change for each line item in the Company's consolidated statements of operations for the twelve months ended months ended December 31, 2023 and 2022 .

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Revenues

(1) Revenues from Environmental Attributes in RNG Fuel segment and RNG marketing in Fuel Station Services segment relate to revenues earned from sales of RINs and LCFSs.

(2) Revenues from Environmental Attributes in Renewable Power segment include revenues earned from sales of ISCC carbon sales and RECs.

RNG Fuel

Revenue from RNG Fuel decreased by $6.9 million, or 9%, for the year ended December 31, 2023 compared to the year ended December 31, 2022. This is primarily due to a decrease of $7.1 million in pricing and $0.5 million due to decrease in volumes relating to brown gas sales. The revenues from sale of Environmental Attributes remained flat year over year as lower RIN pricing was offset by higher volumes of sales. Additionally, there was $0.6 million increase in revenues earned from providing management services to unconsolidated entities.

Fuel Station Services

Revenue from Fuel Station Services increased by $17.6 million, or 15%, for the year ended December 31, 2023 compared to the year ended December 31, 2022. This was primarily attributable to increase of $16.4 million in RNG marketing revenues due to higher Environmental Credit sales and marketing services, $2.3 million increase in service and maintenance revenues from increase in number of sites offset by decrease in construction revenues of $0.7 million.

Renewable Power

Revenue from Renewable Power increased by $9.8 million, or 22%, for the year ended December 31, 2023 compared to the year ended December 31, 2022. This change was attributable primarily to an increase of $14.6 million from sale of ISCC Carbon Credits and REC sales, offset by decrease of $2.6 million from shutdown of one of our facilities and $2.7 million decrease in revenues at two of our Renewable Power facilities due to conversion into RNG facilities. Additionally, the increase also resulted from one facility which was shut down for maintenance for majority of the year in 2022 but was operational in 2023.

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Cost of sales

RNG Fuel

Cost of sales from RNG Fuel marginally decreased by $0.3 million, or 1%, for the year ended December 31, 2023 compared to the year ended December 31, 2022.

Fuel Station Services

Cost of sales from Fuel Station Services increased by $16.5 million, or 17%, for the year ended December 31, 2023 compared to the year ended December 31, 2022. This change was attributable primarily to an increase of $13.4 million of dispensing fees to generate Environmental Attributes, $0.9 million in construction costs, $2.7 million in service related costs offset by decrease in $1.2 million due to lower brown gas pricing.

Renewable Power

Cost of sales from Renewable Power increased by $5.0 million, or 16%, for the year ended December 31, 2023 compared to the year ended December 31, 2022. This is primarily due to an increase of $1.3 million due to PPA termination expense, $2.5 million in planned maintenance expense and an $0.7 million increase in royalty expense at one of our facilities related to royalties on ISCC Carbon Credit sales.

Project development and start up costs

Project development and start up costs decreased by $1.6 million or 24%, for the year ended December 31, 2023compared to the year ended December 31, 2022. This is primarily due to decrease in virtual pipeline costs incurred on New River in 2022 which were not incurred after first quarter of 2023.

Selling, general, and administrative

Selling, general, and administrative expenses remained flat for the year ended December 31, 2023 compared to the year ended December 31, 2022.

Depreciation, amortization, and accretion

Depreciation, amortization, and accretion expense increased by a total of $1.4 million, or 11%, for the year ended December 31, 2023 compared to the year ended December 31, 2022. This change was primarily due to an $0.3 million increase from New River as depreciation for New River represented a partial year in 2022, $1.0 million increase in Beacon and our Renewable Power facilities and a $0.2 million increase from amortization of right-of-use assets for finance leases and increase in depreciation expense in our Fuel Station Services segment due to increase in the number of owned stations.

Income from equity method investments

Net income attributable to equity method investments decreased by $0.3 million, or 4%, for the year ended December 31, 2023 compared to the year ended December 31, 2022. This is primarily due to the recording of a $3.2 million gain on settlement of commodity swap contracts as our portion from GREP in the third quarter of 2022 and an increase in net income from Pine Bend and Noble Road offset by the amortization of basis differences of $3.0 million in 2023.

Interest and financing expense, net

Interest and financing expenses, net increased by $2.7 million, or 40%, for the year ended December 31, 2023 compared to the year ended December 31, 2022. This is primarily due to an increase in interest expense on the OPAL Term Loan of $3.3 million primarily due to an increase in outstanding debt, $1.2 million on the Convertible Note Payable (we recorded a gain of $2.9 million in 2022) and $0.5 million in commitment fees offset by a decrease of $3.5 million in interest expense on our Senior Secured Credit Facility as the debt was repaid in full in March 2023.

Change in fair value of derivatives, net

Change in fair value of derivatives, net decreased by $25.7 million, or 78%, for the year ended December 31, 2023 compared to the year ended December 31, 2022. This change was attributable primarily to a decrease in gain of $30.2 million on our earnout liabilities, change in the fair value of a contingent payment to a non-controlling interest in one of our VIEs of $4.3 million, change in fair value of interest rate swaps and put option, offset by a negative change in fair

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value of warrant liabilities of $9.0 million. These liabilities were recorded in the consolidated balance sheet upon completion of the Business Combination.

Other income

Other income increased by $122.5 million, or 6306%, for the year ended December 31, 2023 compared to the year ended December 31, 2022. This change is primarily related to a gain $122.9 million recognized on deconsolidation of VIEs, Emerald and Sapphire.

Loss on debt extinguishment

On May 30, 2023, OPAL Intermediate Holdco 2 assigned to Paragon its rights and obligations under OPAL Term Loan II. The joint venture partner of Paragon reimbursed OPAL Intermediate Holdco 2 $0.8 million as its portion of the transaction costs incurred.

The Company expensed the remaining deferred financing costs of $1.9 million as loss on debt extinguishment in its consolidated statement of operations for the year ended December 31, 2023. Additionally, we completed a debt restructuring of the OPAL Term Loan in third quarter of 2023 which was accounted for as a debt modification for the existing lenders by performing an analysis on a lender by lender basis under ASC 470-50 Debt modifications and exchanges. As a result, the Company recorded debt extinguishment of $0.3 million representing the fees allocated to the lenders who were repaid in full as part of loss on debt extinguishment in the consolidated statement of operations for the year ended December 31, 2023.

There was no loss on debt extinguishment for the year ended December 31, 2022.

Loss on warrant exchange

On December 22, 2022, we completed the exchange offer of outstanding Public Warrants and Private Warrants and issued 3,309,296 shares of Class A common stock in exchange for the warrants tendered in the Offer. Pursuant to the Warrant Amendment dated December 21, 2022, we exercised our right to exchange the remaining outstanding Warrants and issued 497,080 shares of Class A common stock on December 23, 2022. Following the completion of the exchange, the Public Warrants were suspended from trading on the Nasdaq and delisted. There are no longer any Warrants outstanding. We recorded $3.4 million as a loss on exchange of Warrants in our consolidated statement of operations for the year ended December 31, 2022.

In March 2023, we issued 49,633 shares to certain warrant holders as consideration for their prior agreement to tender all warrants held by the warrant holders in the voluntary exchange offer which closed on December 22, 2022. We recorded $338 thousand representing the fair value of the shares issued based on the closing price on March 30, 2023 as part of Loss on warrant exchange on its consolidated statement of operations for the year ended December 31, 2023.

Net income attributable to redeemable non-controlling interests

Net income attributable to redeemable non-controlling interests for the year ended December 31, 2023 and 2022 is $97.4 million and $22.4 million, respectively. The net income for the years ended December 31, 2023 and 2022 reflects the net income belonging to OPAL Fuels equity holders based on pro-rata ownership.

Net loss attributable to non-redeemable non-controlling interests

Net loss attributable to non-redeemable non-controlling interests for the year ended December 31, 2023 decreased by $0.8 million or 70%, compared to the year ended December 31, 2022. This reflects the joint venture partners' loss in those entities we sold a portion of our membership interests in certain RNG facilities which are consolidated in our financial statements. The decrease is primarily due to deconsolidation of Emerald and Sapphire which were previously recorded as non-controlling interests but are now accounted for as equity method investments. These entities for the year ended December 31, 2023, were Sunoma, Central Valley and Emerald, Sapphire for the first four months of 2023. The entities accounted for as non-redeemable non-controlling interests for the year ended December 31, 2022 were Sunoma, Emerald, Sapphire and Central Valley.

Dividends on redeemable preferred non-controlling interests

On November 29, 2021, we entered into an exchange agreement with Hillman whereby Hillman exchanged its ownership interests in the four RNG projects of $30.0 million into 300,000 series A-1 preferred units at a par value of $100 per unit and 1.4% of the common units of OPAL Fuels. On the same day, we entered into a subscription agreement with NextEra for up to 1,000,000 Series A preferred units, which were issued to NextEra during first and second quarters of

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2022 for total proceeds of $100.0 million. Upon completion of the Business Combination, these were converted to redeemable preferred non-controlling interests.

Redeemable preferred non-controlling interests carry an 8% dividend payable quarterly either in cash or paid-in-kind for the first eight quarters at our option. During the third quarter of 2023, the Company repaid $16.5 million of paid-in-kind preferred dividend. As of December 31, 2023, there was $2.6 million of accrued dividend for the fourth quarter of 2023 which was paid in January 2024.

The dividends on redeemable preferred non-controlling interests for the year ended December 31, 2023 increased by $3.1 million or 39% primarily due to full year of dividends on Series A preferred units with NextEra compared to partial year in 2022.

Liquidity and Capital Resources

Liquidity

As of December 31, 2023, our liquidity consisted of cash and cash equivalents including restricted cash of $47.2 million and $9.9 million of short term investments. Additionally, we have availability of $263.4 million under the delayed draw term loan and $36.2 million under the revolver facility under the OPAL Term Loan.

We expect that our available cash together with our other assets, expected cash flows from operations, and access to expected sources of capital will be sufficient to meet our existing commitments for a period of at least twelve months from the date of this report. Any reduction in demand for our products or our ability to manage our production facilities may result in lower cash flows from operations which may impact our ability to make investments and may require changes to our growth plan.

To fund future growth, we anticipate seeking additional capital through equity or debt financings. The amount and timing of our future funding requirements will depend on many factors, including the pace and results of our project development efforts. We may be unable to obtain any such additional financing on acceptable terms or at all. Our ability to access capital when needed is not assured and, if capital is not available when, and in the amounts, needed, we could be required to delay, scale back or abandon some or all of our development programs and other operations, which could materially harm our business, prospects, financial condition, and operating results.

As of December 31, 2023, we had total indebtedness excluding deferred financing costs of $209.1 million which primarily consists of $186.6 million under the OPAL Term Loan and $22.5 million under Sunoma Loan.

As part of our operations we have arrangements for office space for our corporate headquarters under the Administrative Services Agreement as well as operating leases for office space, warehouse space, and our vehicle fleet.

We intend to make payments under our various debt instruments when due and pursue opportunities for earlier repayment and/or refinancing if and when these opportunities arise.

See Note 7. Borrowings, to our consolidated financial statements.

Cash Flows

The following table presents the Company's cash flows for the years ended December 31, 2023 and 2022:

Net Cash Provided by Operating Activities

Net cash provided by operating activities for the year ended December 31, 2023 was $38.3 million, an increase of $39.6 million compared to net cash used in operating activities of $1.4 million for the year ended December 31, 2022. The

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increase in cash provided by operating activities was primarily attributable to positive capital changes primarily related to accounts receivable, accounts receivable, related party, accounts payable, related party, environmental credits held for sale and contract assets.

Net Cash Used in Investing Activities

Net cash used in investing activities for the year ended December 31, 2023 was $74.1 million, a decrease of $109.9 million compared to the $184.0 million used in investing activities for the year ended December 31, 2022. This was primarily driven by a decrease in cash invested in short term investments of $120.1 million, deconsolidation of VIEs net cash of $11.9 million, an increase in distribution from equity method investment of $2.7 million, a decrease in payments made for the construction of various RNG generation and dispensing facilities of $17.6 million offset by an increase in cash paid for investments in other entities of $7.7 million and the repayment of Note receivable of $10.8 million in the third quarter of 2022.

Net Cash Provided by Financing Activities

Net cash provided by financing activities for the year ended December 31, 2023 was $5.9 million, a decrease of $214.7 million compared to the $220.6 million provided from financing activities for the year ended December 31, 2022. This was primarily due to a decrease of $138.9 million from closing of the Business Combination and $100.0 million decrease from proceeds from issuance of Redeemable Preferred Units to NextEra in the prior year, the repurchase of $16.4 million of shares of our Class A common stock in connection with the exercise of the put option and decrease of $10.4 million proceeds from non-redeemable non-controlling interests.This was offset by an increase in proceeds of $144.1 million from OPAL Term Loan post amendment in September 2023, accompanied by repayment of existing balance of $87.6 million on the OPAL Term Loan, Convertible Note Payable of $30.1 million and paid-in-kind preferred dividends of $16.6 million. Additionally, the Company paid $10.9 million in transaction fees.

Capital expenditures and other cash commitments

We require cash to fund our capital expenditures, operating expenses, working capital and other requirements, including costs associated with fuel sales; outlays for the design and construction of new Fueling Stations and RNG production facilities; debt repayments and repurchases; maintenance of our electrification production facilities supporting our operations, including maintenance and improvements of our infrastructure; supporting our sales and marketing activities, including support of legislative and regulatory initiatives; any investments in other entities; any mergers or acquisitions, including acquisitions to expand our RNG production capacity; pursuing market expansion as opportunities arise, including geographically and to new customer markets; to fund other activities or pursuits and for other general corporate purposes.

As of December 31, 2023, we anticipate spending approximately $179.3 million in capital expenditures for the next 12 months for projects and fuel stations currently under construction and our share of contributions in our equity method investment projects. These expenditures do not include any expected contributions from our joint venture partners and primarily relate to our development and construction of new renewable energy facilities and the purchase of equipment used in our Fueling Station services and Renewable Power operations.

In addition to the above, we also have lease commitments on our vehicle fleets and office leases and quarterly amortization payment obligations under various debt facilities. Please see Note 7. Borrowings and Note 8. Leases to our consolidated financial statements for additional information.

We plan to fund these expenditures primarily through cash on hand, cash generated from operations and availability under existing debt facilities.

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

In this Management's Discussion and Analysis of Financial Condition and Results of Operations section, references to "OPAL", "we", "us", "our", and the "Company" refer to OPAL Fuels Inc. and its consolidated subsidiaries. The following discussion and analysis should be read in conjunction with our consolidated financial statements and related notes set forth in Item 8. Financial Statements and Supplementary Data and the risk factors identified in Item 1A. Risk Factors of this Annual Report. For further discussion regarding our results of operations for the year ended December 31, 2021 as compared to the year ended December 31, 2020, refer to the audited consolidated financial statements and notes thereto included in the Company's Current Report on Form 8-K, which was filed with Securities and Exchange Commission (the "SEC") on July 27, 2022. In addition to historical information, this discussion and analysis includes certain forward-looking statements which reflect our current expectations. The Company's actual results may materially differ from these forward-looking statements.

Overview

We are a renewable energy company specializing in the capture and conversion of biogas for the (i) production of RNG for use as a vehicle fuel for heavy and medium-duty trucking fleets, (ii) generation of electricity generated from renewable sources ("Renewable Power") for sale to utilities, (iii) generation and sale of Environmental Attributes (as defined below) associated with RNG and Renewable Power, and (iv) sales of RNG as pipeline quality natural gas. We also design, develop, construct, operate and service Fueling Stations for trucking fleets across the country that use natural gas to displace diesel as their transportation fuel. The Biogas Conversion Projects currently use LFG and dairy manure as the source of the biogas. In addition, we have recently begun implementing design, development, and construction services for hydrogen Fueling Stations, and we are pursuing opportunities to diversify our sources of biogas to other waste streams. The term “Environmental Attributes” refers to federal, state and local government incentives in the United States, provided in the form of renewable identification numbers (“RINs,”) RECs, low carbon fuel standard (“LCFS”) credits, rebates, tax credits and other incentives to end users, distributors, system integrators and manufacturers of renewable energy projects, that promote the use of renewable energy. We separately design, develop, construct, operate and service Fueling Stations for vehicle fleets across the country that dispense RNG and/or CNG to displace diesel as a fleet transportation fuel.

As of the date of this report, we owned and operated 25 projects, seven of which are RNG projects and 18 of which are Renewable Power Projects. As of that date, our RNG projects in operation had a design capacity of 3.9 million MMBtus per year and our Renewable Power Projects in operation had a nameplate capacity of 118.6 MW per hour. In addition to these projects in operation, we are actively pursuing expansion of our RNG-generating capacity and, accordingly, have a portfolio of RNG projects in construction or in development, with four of our current Renewable Power Projects being considered candidates for conversion to RNG projects in the foreseeable future.

The Company was formerly known as Arclight Clean Transition Corp II ("Arclight"), which was a blank check company incorporated in Cayman Islands on January 13, 2021. Arclight was formed for the purpose of effecting a merger, share exchange, asset acquisition, reorganization or similar business combination with one or more businesses. OPAL Fuels LLC was formed in December 2020 as a wholly owned subsidiary of OPAL HoldCo under the laws of the State of Delaware. On December 31, 2020, Fortistar LLC and certain of its affiliated entities contributed their respective ownership interests in the following legal entities to OPAL Fuels in a common-control reorganization: TruStar Energy Holdings LLC, Fortistar RNG LLC, Fortistar Methane 3 Holdings LLC, Fortistar Methane 3 LLC, Fortistar Contracting LLC, and Fortistar Methane 4 LLC. On December 2, 2021, the Company, OPAL Holdco and OPAL Fuels entered into the Business Combination Agreement.

Business combination

On July 21, 2022, we completed the Business Combination. After giving effect to the Business Combination, the redemption of public shares as described below, the consummation of the related PIPE investment, and the separation of the former ArcLight units, there were (i) 25,671,390 shares of our Class A common stock issued and outstanding, (ii) 144,399,037 shares of our Class D common stock issued and outstanding, (iii) no shares of Class B common stock, par value $0.0001 per share (“Class B common stock”) issued and outstanding (shares of Class B common stock do not have any economic value but entitle the holder thereof to one vote per share) and (iv) no shares of our Class C common stock, par value $0.0001 per share, (“Class C common stock”) issued and outstanding (shares of Class C common stock entitle the holder thereof to five votes per share). The Class A common stock and warrants commenced trading on the Nasdaq Capital Market under the symbols “OPAL” and “OPALW,” respectively, on July 22, 2022.

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Recent developments

Warrant exchange

On November 18, 2022, the Company announced the commencement of the Offer and consent solicitation relating to its outstanding (i) Public Warrants, and (ii) private placement warrants to purchase shares of Class A common stock (the “Private Placement Warrants”) and together with the public warrants, the (“Warrants”). The Company offered all holders of the warrants the opportunity to receive 0.250 shares of Class A common stock in exchange for each outstanding warrant tendered by the holder and exchanged pursuant to the Offer. Concurrently with the Offer, the Company solicited consents from holders of the warrants to amend the Warrant Agreement to permit the Company to require that each warrant that is outstanding upon the closing of the Offer be exchanged for 0.225 shares of Class A common stock, which is a ratio 10% less than the exchange ratio applicable to the Offer (such amendment, the “Warrant Amendment”).

On December 22, 2022, the Company completed the exchange offer and issued 3,309,296 shares of Class A common stock in exchange for the warrants tendered in the Offer. Pursuant to the Warrant Amendment dated December 21, 2022, the Company effected the Post-Offer Exchange and issued 497,080 shares of Class A common stock. As a result of the completion of the Offer and the Post-Offer Exchange, there are no outstanding warrants. Accordingly, the public warrants were suspended from trading on the Nasdaq and delisted.

UPS Agreement

On December 15, 2022, the Company entered into the UPS Agreement pursuant to which the Company will provide operations and maintenance services to 51 UPS renewable natural gas dispensing stations across the United States. Under the terms of the agreement, the Company will receive an amount based on an agreed price per gas gallon equivalent dispensed at each station.

Senior Secured Credit Facility

On December 19, 2022, FM3, an indirect subsidiary of the Company, which is the borrower under the Senior Secured Credit Facility, dated as of September 21, 2015, provided by a lender group led by MUFG Union Bank Ltd, as administrative agent, and guaranteed by certain direct subsidiaries of FM3, and Opal Fuels, a direct subsidiary of the Company, and the other parties to the Senior Secured Credit Facility entered into the FM3 Amendment. The FM3 Amendment amended the Senior Secured Credit Facility, among other things, to (a) extend the maturity date of the obligations thereunder from December 20, 2022 to March 20, 2023, (b) permit Opal Fuels to purchase the rights and obligations of certain exiting lenders at par, (c) prepay a portion of the outstanding loans made by the remaining lenders and (d) permit the release of certain project company subsidiaries of FM3 from the collateral securing the obligations under the Senior Secured Credit Facility. Upon consummation of the FM3 Amendment, Opal Fuels holds approximately $45,000 of the outstanding loans under the FM3 Credit Agreement as an affiliate lender. On March 20, 2023, the Company repaid in full the remaining outstanding loan of $22,750.

OPAL Term Loan II

On August 4, 2022, OPAL Fuels Intermediate Holdco 2, an indirect wholly-owned subsidiary the Company, entered into the OPAL Term Loan II with a syndicate of lenders. The indebtedness is guaranteed by certain of the direct and indirect subsidiaries of OPAL Intermediate Holdco 2. The OPAL Term Loan II provides for an approximately two year DDTL Facility of up to a maximum aggregate principal amount of $100,000 and the DSR Facility of up to a maximum aggregate principal amount of $5,000. The proceeds of the DDTL Facility are to be used to fund a portion of the construction of the RNG projects owned, either in full or through a joint venture with a third party, by the subsidiary guarantors and the proceeds of the DSR Facility are to be used solely to satisfy the balance to be maintained in the debt service reserve account. In connection with the transaction, the Company paid $2,200 as financing fees to the lenders and incurred $1,376 as third party fees.

Critical Accounting Policies and Estimates

The discussion and analysis of our financial condition and results of operations is based upon our interim unaudited consolidated financial statements, which have been prepared in accordance with generally accepted accounting principles in the United States ("U.S. GAAP") and the rules and regulations of the SEC, which apply to interim financial statements. The preparation of those financial statements requires us to make estimates and judgments that affect the

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reported amounts of assets and liabilities, revenues, expenses and warrants and related disclosure of contingent assets and liabilities at the date of our financial statements. Actual results may differ from these estimates under different assumptions and conditions.

Critical accounting policies are those that reflect significant judgments of uncertainties and potentially result in materially different results under different assumptions and conditions. We have described below what we believe are our most critical accounting policies, because they generally involve a comparatively higher degree of judgment in their application. For a detailed description of all our accounting policies, see Note 2 Significant Accounting Policies, to our consolidated financial statements included herein.

Revenue Recognition

Renewable Power

We sell Renewable Power produced from LFG fueled power plants to utility companies through our PPAs. Revenue is recognized based on contract specified rates per MWh when delivered to the customer, as this considered to be completion of the performance obligation. Certain PPAs contain a lease element which we account for as operating lease revenue on a straight-line basis over the lease term. The Company utilizes commodity swap contracts to hedge against the unfavorable price fluctuations in market prices of electricity. The Company does not apply hedge accounting to these contracts. As such, unrealized and realized gain (loss) is recognized as component of Renewable Power revenues in the consolidated statement of operations.

Gas — Fuel Purchase Agreements

We own Fueling Stations for use by customers under fuel sale agreements. We bill these customers at an agreed upon price for each gallon sold and recognize revenue based on the amounts invoiced in according with the “right to invoice” practical expedient. These contracts may contain an embedded lease of the equipment which we account for as operating lease revenue. For some public stations where there is no contract with the customer, we recognize revenue at the point in time that the customer takes control of the fuel.

Interstate Gas Pipeline Delivery

We have agreements with two natural gas producers whereby we are contracted to transport the producers’ gas to an agreed delivery point on an interstate gas pipeline via our RNG gathering system. Revenue is recognized over time using the output method which is based on quantity of natural gas transported.

Environmental Attributes

We generate RECs, RINs, and LCFS credits. These Environmental Attributes are sold to third parties that utilize these credits in order to comply with federal and state requirements. Revenue is recognized at the point in time when the credits are transferred to and accepted by the third party buyer.

Operation and Maintenance

We have operating and maintenance agreements in which we are contracted to operate, maintain, and repair landfill site gas collection systems. Revenue is based on the volume of per million British thermal units (“MMBtu”) of landfill gas collected and the MWhs produced at that site. This revenue is recognized as Renewable Power revenue when landfill gas is collected and Renewable Power is delivered. In addition, we have O&M agreements in which we are contracted to maintain and repair Fueling Stations. Revenue is based on the volumes of GGEs of gas dispensed at the site. This revenue is recognized as Fuel Station Services revenue when the site dispenses volumes.

Construction Type Contracts — Third Party

We have various fixed price contracts for the construction of fueling stations for customers. Revenue from these contracts, including change orders, are recognized over time, with progress measured by the percentage of cost incurred to date to estimated total cost for each contract.

Impairment of Goodwill and Long-Lived Assets

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Impairment of Goodwill

When a business is acquired, goodwill is recognized to reflect any future economic benefits that are not separately recognized, such as synergies. For purposes of impairment testing, GAAP requires goodwill to be allocated to reporting unit(s) at the acquisition date and to be tested for impairment at least annually, and in between annual tests whenever events or changes in circumstances indicate that the respective reporting unit’s fair value is less than its carrying value. Significant judgment is required when identifying the reporting units for goodwill allocation, during our assessment of relevant events and circumstances for qualitative impairment indicators, and when estimating the undiscounted cash flows of reporting unit(s) for quantitative impairment assessments.

Our goodwill impairment assessment is performed during the fourth quarter of each year or at the time facts or circumstances indicate that a reporting unit’s goodwill may be impaired. In conformity with GAAP, we generally first perform a qualitative assessment over whether it is more likely than not that a reporting unit’s fair value is less than its carrying value to determine if a quantitative assessment is required. If, after performing the qualitative assessment, we conclude it is more likely than not that the fair value of the reporting unit is less than its carrying value, then a quantitative test is required. Our qualitative assessment includes evaluation of relevant events and circumstances, such as, macroeconomic conditions, industry and market considerations, cost factors, overall performance, and other relevant events.

As part of our quantitative assessment, we estimate a reporting unit’s fair value based on the income approach. With this approach, the fair value measurement is based on significant inputs that are not observable in the market and thus the fair value measurement is categorized within Level 3 of the fair value hierarchy. Our assumptions include future cash flow projections, a discount rate range based on the weighted average cost of capital, and a terminal value based on a range of terminal earnings before interest, taxes, depreciation, and amortization.

Impairment of Long-Lived Assets

Our long-lived assets held and used with finite useful lives including plant equipment, buildings, patents, and PPAs are reviewed for impairment whenever events or changes in circumstances indicate that the asset group may not be recoverable. In determining the asset group, we assess the interdependency of revenues between assets, shared cost structures, the interchangeability of assets used in operations, and how assets are managed and utilized by the business. Events that may trigger a recoverability assessment include a significant adverse change in the extent or manner in which the long-lived asset group is being used or in its physical condition, and the expectation that, more likely than not, the long-lived asset or asset group will be sold or otherwise disposed of significantly before the end of its previously estimated useful life. Recoverability of long-lived assets to be held and used is measured by a comparison of the carrying amount of an asset group to future net undiscounted cash flows expected to be generated by the asset group. Our cash flow estimates reflect conditions and assumptions that existed as of the measurement date which is the same as the triggering event date. The assets are considered recoverable and an impairment loss is not recognized when the undiscounted net cash flows exceed the net carrying value of the asset group. If the assets are not recoverable, then an impairment loss is recognized to the extent that the carrying value of the asset group exceeds its fair value. We base the fair value of our assets or asset groups off of the estimated discounted future cash flows using market participant assumptions. Assets disposed of are reported at the lower of the carrying amount or fair value less selling costs. Significant judgment is required when determining asset group composition, during our assessment of relevant events and circumstances, when determining an appropriate discount rate, and when estimating the undiscounted and discounted future cash flows of the asset group.

Based on our assessment for the year ended December 31, 2022, there is no impairment recorded on our Plant, Property and Equipment.

Fair Value Measurements

The objective of a fair value measurement is to estimate the exit price, which is the price that would be received to sell an asset or paid to transfer a liability that the Company holds, in an orderly market transaction at the measurement date. We follow GAAP guidance which establishes a three-tier hierarchy for inputs used in fair value measurements, as well as prioritizes valuation techniques that maximize the use of observable inputs and minimizes the use of unobservable inputs. In summary, level 1 inputs are considered the most observable inputs and are more specifically the unadjusted quoted price for identical assets or liabilities in an active market the Company has access to. Level 2 inputs are considered less observable inputs such as quoted prices for similar assets or liabilities in an active market the Company has access to. Lastly, level 3 inputs are unobservable inputs in which little to no market activity exists for the asset or liability at the

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measurement date. As such, level 3 estimates are subject to a more significant level of estimation uncertainty. Furthermore, when multiple inputs are used and are categorized in different levels of the input hierarchy, then the fair value measurement in its entirety is categorized in the same level as its lowest level input that is significant to the fair value measurement. Our assessment of the significance of an input to a fair value measurement requires judgment and may affect the fair value measurement’s placement in the fair value hierarchy.

Refer to Note 10. Derivative Financial Instruments and Fair Value Measurements, to our consolidated financial statements, for details on our assets and liabilities regularly recorded at fair value and the respective placements in the fair value hierarchy.

Income Taxes

The Company accounts for income taxes in accordance with ASC Topic 740, Accounting for Income Taxes (“ASC Topic 740”), which requires the recognition of tax benefits or expenses on temporary differences between the financial reporting and tax bases of its assets and liabilities by applying the enacted tax rates in effect for the year in which the differences are expected to reverse. Such net tax effects on temporary differences are reflected on the Company’s consolidated balance sheets as deferred tax assets and liabilities. Deferred tax assets are reduced by a valuation allowance when the Company believes that it is more-likely-than-not that some portion or all of the deferred tax assets will not be realized. The Company calculates the interim tax provision in accordance with the provisions of ASC Subtopic 740-270, Income Taxes; Interim Reporting. For interim periods, the Company estimates the annual effective income tax rate and applies the estimated rate to the year-to-date income or loss before income taxes.

Refer to Note 16. Income taxes, to our consolidated financial statements, for additional information.

Emerging Growth Company Status

We are an emerging growth company as defined in the JOBS Act. The JOBS Act provides emerging growth companies with certain exemptions from public company reporting requirements for up to five fiscal years while a company remains an emerging growth company. As part of these exemptions, we need only provide two fiscal years of audited financial statements instead of three, we have reduced disclosure obligations such as for executive compensation, and we are not required to comply with auditor attestation requirements from Section 404(b) of the Sarbanes-Oxley Act regarding our internal control over financial reporting. Additionally, the JOBS Act has allowed us the option to delay adoption of new or revised financial accounting standards until private companies are required to comply with new or revised financial accounting standards.

Use of Estimates

The preparation of the consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the consolidated financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The significant estimates and assumptions of the Company relate to the useful lives of property, plant and equipment, the value of stock-based compensation and the fair value of derivatives including warrant liabilities, earnout liabilities, put option on a forward purchase agreement, interest rate swaps and commodity swap contracts. Actual results could differ from those estimates.

Key Factors and Trends Influencing our Results of Operations

The principal factors affecting our results of operations and financial condition are the markets for RNG, Renewable Power, and associated Environmental Attributes, and access to suitable biogas production resources. Additional factors and trends affecting our business are discussed in "Risk Factors" elsewhere in this report.

Market Demand for RNG

Demand for our converted biogas and associated Environmental Attributes, including RINs and LCFS credits, is heavily influenced by United States federal and state energy regulations together with commercial interest in renewable energy products. Markets for RINs and LCFS credits arise from regulatory mandates that require refiners and blenders to incorporate renewable content into transportation fuels. The EPA annually sets proposed renewable volume obligations

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("RVOs") for D3 (cellulosic biofuel with a 60% greenhouse gas (“GHG”) reduction requirement) RINs in accordance with the mandates established by the Energy Independence and Security Act of 2007. The Environmental Protection Agency's issuance of timely and sufficient annual RVOs to accommodate the RNG industry's growing production levels is necessary to stabilize the RIN market.The EPA is required to set RVOs for 2023 and beyond and the EPA introduced proposed Set rule in December 2022 with rule finalization expected in June 2023. Until the rules and RVOs are finalized, this may create additional uncertainty as to RIN pricing. On the state level, the economics of RNG are enhanced by low-carbon fuel initiatives, particularly well-established programs in California and Oregon (with several other states also actively considering LCFS initiatives similar to those in California and Oregon). Federal and state regulatory developments could result in significant future changes to market demand for the RINs and LCFS credits we produce. This would have a corresponding impact to our revenue, net income, and cash flow.

Commercial transportation, including heavy-duty trucking, generates approximately 30% emissions of overall CO₂ and other climate-harming GHGs in the United States, and transitioning this sector to low and negative carbon fuels is a critical step towards reducing overall global GHG emissions. The adoption rate of RNG-powered vehicles by commercial transportation fleets will significantly impact demand for our products.

We are also exposed to the commodity prices of natural gas and diesel, which serve as alternative fuel for RNG and therefore impact the demand for RNG.

Renewable Power Markets

We also generate revenues from sales of RECs and Renewable Power generated by our biogas-to-Renewable Power projects. RECs exist because of legal and governmental regulatory requirements, and a change in law or in governmental policies concerning Renewable Power, landfill gas ("LFG"), or the sale of RECs could affect the market for, and the pricing of, the RECs that we generate through production at our Biogas Conversion Projects. We periodically evaluate opportunities to convert existing biogas-to-Renewable Power projects to RNG production. This strategy has been an increasingly attractive avenue for growth when RNG from landfills become eligible for D3 RINs. We have been negotiating with several of our Renewable Power off-takers to enter arrangements that would free up the LFG resource to produce RNG. Changes in the price we receive for RECs and Renewable Power, together with the revenue opportunities and conversion costs associated with converting our LFG sites to RNG production, could have a significant impact on our future profitability.

Regulatory landscape

We operate in an industry that is subject to and currently benefits from environmental regulations. Government policies can increase demand for our products by providing incentives to purchase RNG and Environmental Attributes. These government policies are modified and in flux constantly and any adverse changes to these policies could have a material effect the demand for our products. For more information, see our risk factor titled "The financial performance of our business depends upon tax and other government incentives for the generation of RNG and Renewable Power, any of which could change at any time and such changes may negatively impact our growth strategy." Government regulations have become increasingly stringent and complying with changes in regulations may result in significant additional operating expenses.

Seasonality

We experience seasonality in our results of operations. Sale of RNG may be impacted by higher consumption by some of our customers during summer months. Additionally, the price of RNG is higher during the fall and winter months due to increase in overall demand for natural gas during the winter months. Revenues generated from our renewable electricity projects in the northeast U.S., all of which sell electricity at market prices, are affected by warmer and colder weather, and therefore a portion of our quarterly operating results and cash flows are affected by pricing changes due to regional temperatures. These seasonal variances are managed in part by certain off-take agreements at fixed prices.

Impact of COVID-19

In response to the COVID-19 pandemic, we instituted a safety committee that oversees our compliance with federal, state, and local government mandates, and ensures that the Company adheres to Centers for Disease Control guidelines to maintain safe working conditions for our employees. Some of the protocols we implemented include limiting in-person work to essential personnel and performing temperature checks. Since March 2020, where practicable, our employees have worked remotely and minimized travel and other non-essential contact. Additionally, we are providing our employees with COVID-19 testing at no cost and personal protective equipment for their safety and well-being.

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As of the date of this report, the COVID-19 pandemic has had a relatively minimal economic impact on our results of operations.

The duration and future economic severity of the COVID-19 remains uncertain, and our results of operations and financial condition could potentially face material adverse effect(s) in the future due to COVID-19.

Key Components of Our Results of Operations

We generate revenues from the sale of RNG fuel, Renewable Power, and associated Environmental Attributes, as well as from the construction, fuel supply, and servicing of Fueling Stations for commercial transportation vehicles using natural gas to power their fleets. These revenue sources are presented in our statement of operations under the following captions:

•RNG Fuel. The RNG Fuel segment includes RNG supply and dispensing activities as well as the associated generation and sale of commodity natural gas and environmental credits, and consists of:

◦RNG Production Facilities – the design, development, construction, maintenance and operation of facilities that convert raw biogas into pipeline quality natural gas

◦Included here are the Company's interests in both operating and construction projects.

◦RNG and CNG Fuel Dispensing Stations - This includes both the dispensing (or sale) of RNG, commodity natural gas, and environmental credit generation and monetization. The Company operates Fueling Stations that dispense both CNG and RNG fuel for vehicles.

•Fuel Station Services. Through its Fuel Station Services segment, the Company provides construction and maintenance services to third-party owners of Fueling Stations. This segment includes:

◦Service and maintenance contracts for RNG/CNG Fueling Stations.

◦Manufacturing division that builds compact fueling systems and defueling systems.

◦Design/build contracts where the Company serves as general contractor for construction of Fueling Stations, typically structured as guarantee maximum price or fixed priced contracts for customers, generally lasting less than one year.

•Renewable Power Portfolio. The Renewable Power portfolio segment generates Renewable Power through combustion of biogas from landfills and digester gas collection systems which is then sold to public utilities throughout the United States. The Renewable Power portfolio operates primarily in Southern California.

Our costs of sales associated with each revenue category are as follows:

•RNG Fuel. Includes royalty payments to biogas site owners for the biogas we use; service provider costs; salaries and other indirect expenses related to the production process, utilities, transportation, storage, and insurance; and depreciation of production facilities.

•Fuel Station Services. Includes equipment supplier costs; service provider costs; and salaries and other indirect expenses.

•Renewable Power. Includes land usage costs; service provider costs; salaries and other indirect expenses related to the production process; utilities; and depreciation of production facilities.

Selling, general, and administrative expense consists of costs involving corporate overhead functions, including the cost of services provided to us by an affiliate, and marketing costs.

Depreciation and amortization primarily relate to depreciation associated with property, plant, and equipment and amortization of acquired intangibles arising from PPAs and interconnection contracts. We are in the process of expanding our RNG and Renewable Power production capacity and expect depreciation costs to increase as new projects are placed into service.

Concentration of customers and associated credit risk

The following table summarizes the percentage of consolidated accounts receivable, net by customers that equal or exceed 10% of the consolidated accounts receivable, net as of December 31, 2022 and 2021. No other single customer accounted for 10% or greater of our consolidated accounts receivable,net as of December 31, 2022 and 2021.

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The following table summarizes the percentage of consolidated revenues from customers that equal 10% or greater of the consolidated revenues in the period (no other single customer accounted for more than 10% of consolidated revenues in these periods):

Results of Operations for the years ended December 31, 2022 and 2021:

Operational data

The following table summarizes the operational data achieved for the years ended December 31, 2022 and 2021:

RNG projects

Below is a table setting forth the RNG projects in operation and construction in our portfolio:

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(1) The Design capacity represents the Company's proportional ownership in the project. Design capacity may not reflect actual production of RNG from the projects, which will depend on many variables including, but not limited to, quantity and quality of the biogas, operational up-time of the facility, and actual productivity of the facility.

(2) Certain projects have provisions that will adjust, or “flip,” the percentage of distributions to be made to us over time, typically triggered by achievement of hurdle rates that are calculated as internal rates of return on capital invested in the project.

(3) We record our ownership interests in these projects as equity method investments in our consolidated financial statements.

Renewable Power Projects

Below is a table setting forth the Renewable Power projects in operation in our portfolio:

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(1) Nameplate capacity is the maximum permitted output for each facility and may not reflect actual MW production from the projects, which depends on many variables including, but not limited to, quantity and quality of the biogas, operational up-time of the facility, and actual productivity of the facility.

(2) See RNG Projects Table above, reference “Michigan 1” under “RNG Projects In Construction.” It is currently contemplated that the Michigan 1E renewable power plant will continue limited operations on a stand-by, emergency basis through March of 2031.

(3) See RNG Projects Table above, reference “Prince William” under “RNG Projects In Construction.”

(4) See RNG Projects Table above, reference “Prince William” under “RNG Projects In Construction.”

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Comparison of the Years Ended December 31, 2022, and 2021

The following table presents the period-over-period change for each line item in the Company's consolidated statements of operations for the twelve months ended months ended December 31, 2022 and 2021 .

Revenues

RNG Fuel

Revenue from RNG Fuel increased by $56.5 million, or 80%, for the year ended December 31, 2022 compared to the year ended December 31, 2021. $18.0 million of this increase was attributable primarily to the impact of full year of Beacon revenues in 2022 versus only eight months in 2021. Additionally, revenues increased by $3.1 million from

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methanol pathway credits, $9.0 million increase from brown gas sales and $26.4 million increase from sale of environmental credits.

Fuel Station Services

Revenue from Fuel Station Services increased by $18.8 million, or 37%, for the year ended December 31, 2022 compared to the year ended December 31, 2021. This was primarily attributable to an increase of $15.5 million from fuel station construction projects which were completed into 2022, coupled with an incremental $1.6 million from increase in volumes at existing and new service sites and $1.7 million from sale of portable fueling stations.

Renewable Power

Revenue from Renewable Power decreased by $5.9 million, or 13%, for the year ended December 31, 2022 compared to the year ended December 31, 2021. This change was attributable primarily to a decrease of $5.1 million due to conversion of one of our electricity generation facilities into an RNG facility and a decrease of $0.8 million due to the closure of one of our electricity generation facilities as our gas rights agreement concluded.

Cost of sales

RNG Fuel

Cost of sales from RNG Fuel increased by $37.9 million, or 92%, for the year ended December 31, 2022 compared to the year ended December 31, 2021. This change was attributable primarily to the inclusion of full year of Beacon’s cost of sales upon consolidation in May 2021 resulting in an increase of $9.2 million, a $3.2 million increase in development costs for building new RNG facilities, $10.3 million increase from new RNG facilities such as Sunoma and New River, $14.7 million increase relating to increased dispensing fees from an increased volume of environmental credits generated and $0.7 million write down charges relating to our brown gas inventory to its net realizable value due to decrease in prices. Additionally, there were savings of $1.2 million from deconsolidation of Pine Bend and Noble Road as of December 31, 2021.

Fuel Station Services

Cost of sales from Fuel Station Services increased by $18.7 million, or 44%, for the year ended December 31, 2022 compared to the year ended December 31, 2021. This change was attributable primarily to an increase in costs of $17.1 million for third-party construction projects completed in 2022 and an increase of $1.2 million in service from higher volumes dispensed.

Renewable Power

Cost of sales from Renewable Power marginally increased by $0.4 million, or 1%, for the year ended December 31, 2022 compared to the year ended December 31, 2021.

Selling, general, and administrative

Selling, general, and administrative expenses increased by a total of $19.2 million, or 65%, for the year ended December 31, 2022 compared to the year ended December 31, 2021. This change was attributable primarily to higher insurance expense of $5.1 million relating to the insurance policies for Arclight’s former directors and the Company’s current management, higher employee headcount and related compensation and benefit expenses of $6.9 million to support our organic growth year-over-year, a $3.7 million increase in professional fees related to audit, tax, legal and consulting fees, a $2.5 million increase in IT-related expenses, $0.8 million stock-based compensation expense and $0.4 million related to corporate governance expenses for a public company. These costs are related to setting up the administrative, compliance, and governance structure required for operating a public company which do not qualify for capitalization.

Depreciation, amortization, and accretion

Depreciation, amortization, and accretion increased by a total of $2.5 million, or 23%, for the year ended December 31, 2022 compared to the year ended December 31, 2021. This change was primarily due to $2.0 million increase from two new RNG facilities coming online - Sunoma and New River, $0.4 million increase from amortization of right-of-use assets for finance leases from adoption of ASC 842, $0.6 million increase from downstream dispensing sites becoming operational offset by decrease in depreciation for Renewable Power business by $0.3 million.

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Interest and financing expense, net

Interest and financing expenses, net decreased by $0.8 million, or 11%, for the year ended December 31, 2022 compared to the year ended December 31, 2021. The decrease is primarily attributable to $2.9 million decrease in the Convertible Note Payable as a result of the favorable $2.9 million in change in fair market value as well as an increase in interest income of $2.0 million from the Note receivable and short term investments and $3.7 million was capitalized as part of Property, plant and equipment. These savings were offset by $1.0 million higher expense on the Senior Secured Credit Facility, $0.2 million higher interest expense on the OPAL Term Loan, $0.9 million increase in amortization of deferred financing costs, $1.8 million increase in Sunoma Loan as interest on Sunoma Loan was capitalized in 2021.

Change in fair value of derivatives, net

Change in fair value of derivatives, net increased by $33.0 million, or 333%, for the year ended December 31, 2022 compared to the year ended December 31, 2021. This change was attributable primarily to gain of $37.1 million on our earnout liabilities, change in fair value of contingent payment to a non-controlling interest of one our VIEs, change in fair value of interest rate swaps and put option, offset by negative change in fair value of warrant liabilities. These liabilities were recorded in the consolidated balance sheet upon completion of the Business Combination.

Other income

Other income increased by $1.9 million, or 100%, for the year ended December 31, 2022 compared to the year ended December 31, 2021. This change is primarily related to a gain recognized on redemption of Note receivable.

Loss on warrant exchange

On December 22, 2022, the Company completed the exchange offer of outstanding Public Warrants and Private Warrants and issued 3,309,296 shares of Class A common stock in exchange for the warrants tendered in the Offer. Pursuant to the Warrant Amendment dated December 21, 2022, the Company exercised its right to exchange the remaining outstanding Warrants and issued 497,080 shares of Class A common stock on December 23, 2022. Following the completion of the exchange, the Public Warrants were suspended from trading on the Nasdaq and delisted. There are no longer any Warrants outstanding. The Company recorded $3,368 as loss on exchange of Warrants.

Income from equity method investments

Net income attributable to equity method investments increased by $3.5 million, or 155%, for the year ended December 31, 2022 compared to the year ended December 31, 2021. This change was attributable primarily to the increase in net income from Pine Bend, Noble Road and GREP that exceeded income from Beacon during comparable period in 2021. Upon the step acquisition of the 56% of controlling interest in Beacon in May 2021, the results of Beacon were consolidated in the financial statements. Pine Bend and Noble Road were deconsolidated as of December 31, 2021.

Gain on acquisition of equity method investment

The gain on acquisition of equity method investment decreased by $19.8 million for the year ended December 31, 2022 compared to the year ended December 31, 2021. This change was attributable primarily to the fair value adjustment resulting from our step acquisition of the remaining interest in Beacon in May 2021.

Gain on deconsolidation of VIEs

The gain on deconsolidation of VIEs decreased by $15.0 million, or 100% for the year ended December 31, 2022. This is primarily due to deconsolidation of Pine Bend and Noble Road as of December 31, 2021, which was not a recurring item in 2022.

Net income attributable to redeemable non-controlling interests

Net income attributable to redeemable non-controlling interests for the year ended December 31, 2022 and 2021 is $22.4 million and $41.4 million, respectively. The net income for the year ended December 31, 2022 reflects the net income belonging to OPAL Fuels equity holders prior to Business Combination for the period January 1, 2022 through July 21, 2022 and portion of net income belonging to OPAL Fuels equity holders from July 21, 2022 through December 31, 2022 based on pro-rata ownership.

Net loss attributable to non-redeemable non-controlling interests

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Net loss attributable to non-redeemable non-controlling interests for the year ended December 31, 2022 increased by $0.3 million or 43%, compared to the year ended December 31, 2021. This reflects the joint venture partners' loss in those entities we sold a portion of our membership interests in certain RNG facilities which are consolidated in our financial statements. These entities for the year ended December 31, 2022, were Sunoma, Emerald, Sapphire and Central Valley. The entities accounted for as non-redeemable non-controlling interests for the year ended December 31, 2021 were Sunoma and Central Valley.

Paid-in-kind preferred dividends

On November 29, 2021, we entered into an exchange agreement with Hillman whereby Hillman exchanged its ownership interests in the four RNG projects of $30.0 million into 300,000 series A-1 preferred units at a par value of $100 per unit and 1.4% of the common units of OPAL Fuels. On the same day, we entered into a subscription agreement with NextEra for up to 1,000,000 Series A preferred units, which were issued to NextEra during first and second quarters of 2022 for total proceeds of $100.0 million. Upon completion of the Business Combination, these were converted to redeemable preferred non-controlling interests.

Redeemable preferred non-controlling interests carry an interest of 8% dividend payable quarterly either in cash or paid-in-kind for the first eight quarters at the option of the Company. The Company recorded the dividend payable of $7.9 million and $0.2 million for the years ended December 31, 2022 and 2021, respectively as paid-in-kind dividends.

Liquidity and Capital Resources

Liquidity

As of December 31, 2022, our liquidity consisted of cash and cash equivalents including restricted cash of $77.2 million and $65.0 million of short term investments. Additionally, we entered into the OPAL Term Loan II where we have undrawn availability of $105.0 million. We also drew down on the remaining $10.0 million available under OPAL Term Loan I in March 2023.

We expect that our available cash together with our other assets, expected cash flows from operations, available lines of credit under various debt facilities and access to expected sources of capital will be sufficient to meet our existing commitments for a period of at least twelve months from the date of this report. If we were to experience any significant further reduction in levels of gas collection, delays in commencement or completion of construction of our projects, adverse regulatory or price changes that affect the value of our environmental credits, or unplanned outages at our production facilities, it would result in lower cash flows from operations which could impact our ability to make investments or require changes to our growth plan. See “Risk Factors” and “Cautionary Statement Regarding Forward-Looking Statements.”

To fund future growth, we anticipate seeking additional capital through equity or debt financings. The amount and timing of our future funding requirements will depend on many factors, including the pace and results of our project development efforts. We may be unable to obtain any such additional financing on acceptable terms or at all. Our ability to access capital when needed is not assured and, if capital is not available when, and in the amounts, needed, we could be required to delay, scale back or abandon some or all of our development programs and other operations, which could materially harm our business, prospects, financial condition, and operating results.

As of December 31, 2022, we had total indebtedness excluding deferred financing costs of $170.4 million which primarily consists of $22.8 million under the Senior Secured Credit Facility, $28.5 million under the Convertible Note Payable, $96.1 million under the OPAL Term Loan, $0.1 million under the Municipality loan and $23.0 million under Sunoma Loan.

As part of our operations we have arrangements for office space for our corporate headquarters under the Administrative Services Agreement as well as operating leases for office space, warehouse space, and our vehicle fleet.

We intend to make payments under our various debt instruments when due and pursue opportunities for earlier repayment and/or refinancing if and when these opportunities arise.

See Note 8. Borrowings, to our consolidated financial statements.

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Cash Flows

The following table presents the Company's cash flows for the years ended December 31, 2022 and 2021:

Net Cash Provided by Operating Activities

Net cash used in operating activities for the year ended December 31, 2022 was $1.4 million, a decrease of $20.2 million compared to net cash provided of $18.9 million for the year ended December 31, 2021. The decrease in cash provided by operating activities was primarily attributable to lower margins reducing our operating income year-over-year and higher transaction costs that were not capitalized associated with becoming a public company and negative working capital changes primarily related to accounts receivable.

Net Cash Used in Investing Activities

Net cash used in investing activities for the year ended December 31, 2022 was $184.0 million, an increase of $66.8 million compared to the $117.2 million used in investing activities for the year ended December 31, 2021. This was primarily driven by cash invested in short term investments of $65.0 million, payments made for the construction of various RNG generation and dispensing facilities of $131.4 million as compared to $89.6 million in the prior year. These amounts were partially offset by proceeds from repayment of Note receivable of $10.9 million and lower distribution from equity method investment of $1.6 million.

Net Cash Provided by Financing Activities

Net cash provided from financing activities for the year ended December 31, 2022 was $220.6 million, an increase of $95.5 million compared to the $125.0 million provided from financing activities for the year ended December 31, 2021. The current year activity is primarily driven by proceeds received from the consummation of Business Combination of $138.9 million, issuance of redeemable preferred non-controlling interests for total proceeds of $100.0 million, proceeds from the OPAL Term Loan of $40.0 million, proceeds from the Sunoma Loan of $4.6 million and a capital contribution from a related party of $23.2 million related to a joint venture. This was offset by debt repayments of $58.6 million and $18.9 million on the Senior Secured Credit Facility and the OPAL Term Loan, respectively, and $8.3 million in financing costs.

Capital expenditures and other cash commitments

We require cash to fund our capital expenditures, operating expenses, working capital and other requirements, including costs associated with fuel sales; outlays for the design and construction of new Fueling Stations and RNG production facilities; debt repayments and repurchases; maintenance of our electrification production facilities supporting our operations, including maintenance and improvements of our infrastructure; supporting our sales and marketing activities, including support of legislative and regulatory initiatives; any investments in other entities; any mergers or acquisitions, including acquisitions to expand our RNG production capacity; pursuing market expansion as opportunities arise, including geographically and to new customer markets; to fund other activities or pursuits and for other general corporate purposes.

As of December 31, 2022, we have budgeted for $231.0 million in capital expenditures for the next 12 months, of which $184.7 million is committed under existing contracts. These expenditures represent net capital expenditures to be incurred by the Company after expected contributions from our joint venture and non-controlling interest partners. They primarily relate to our development of new RNG facilities and the purchase of equipment used in our Fueling Station services and Renewable Power operations.

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In addition to the above, we also have lease commitments on our vehicle fleets and office leases and quarterly amortization payment obligations under various debt facilities. Please see Note 8. Borrowings and Note 9. Leases to our consolidated financial statements for additional information.

We plan to fund these expenditures primarily through cash on hand, cash generated from operations and availability under existing debt facilities.

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

References to the “company,” “our,” “us” or “we” refer to ArcLight Clean Transition Corp. II. The following discussion and analysis of the company’s financial condition and results of operations should be read in conjunction with the financial statements and the notes thereto contained elsewhere in this report. Certain information contained in the discussion and analysis set forth below includes forward-looking statements that involve risks and uncertainties.

Cautionary Note Regarding Forward-Looking Statements

This Annual Report on Form
10-K
includes forward-looking statements within the meaning of Section 27A of the Securities Act and Section 21E of the Securities Exchange Act. We have based these forward-looking statements on our current expectations and projections about future events. These forward-looking statements are subject to known and unknown risks, uncertainties and assumptions about us that may cause our actual results, levels of activity, performance or achievements to be materially different from any future results, levels of activity, performance or achievements expressed or implied by such forward-looking statements. In some cases, you can identify forward-looking statements by terminology such as “may,” “should,” “could,” “would,” “expect,” “plan,” “anticipate,” “believe,” “estimate,” “continue,” or the negative of such terms or other similar expressions. Factors that might cause or contribute to such a discrepancy include, but are not limited to, those described in our other SEC filings.

Overview

We are a blank check company incorporated on January 13, 2021 as a Cayman Islands exempted company for the purpose of effecting a merger, share exchange, asset acquisition, share purchase, reorganization or similar business combination with one or more businesses or entities (the “Business Combination”), that we have not yet to finalize. Our sponsor is ArcLight CTC Holdings II, L.P., a Delaware limited partnership.

Our registration statement for our initial public offering (the “Initial Public Offering”) was declared effective on March 22, 2021. On March 25, 2021, we consummated our Initial Public Offering of 31,116,305 units (the “Units” and, with respect to the Class A ordinary shares included in the Units being offered, the “Public Shares”), including the partial exercise of the underwriters’ option to purchase 3,616,305 additional Units (the “Over-Allotment Units”), at $10.00 per Unit, generating gross proceeds of approximately $311.2 million, and incurring offering costs of approximately $17.6 million, of which approximately $10.9 million was for deferred underwriting commissions.

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Simultaneously with the closing of the Initial Public Offering, we consummated the private placement (“Private Placement”) of 9,223,261 warrants (each, a “Private Placement Warrant” and collectively, the “Private Placement Warrants”), at a price of $1.00 per Private Placement Warrant with the sponsor, generating gross proceeds of approximately $9.2 million.

Upon the closing of the Initial Public Offering and the Private Placement, approximately $311.2 million of the net proceeds of the Initial Public Offering and certain of the proceeds of the Private Placement were placed in a Trust Account with Continental Stock Transfer & Trust Company acting as trustee and invested in United States “government securities” within the meaning of Section 2(a)(16) of the Investment Company Act of 1940, as amended, or the Investment Company Act, having a maturity of 185 days or less or in money market funds meeting certain conditions under Rule
2a-7
promulgated under the Investment Company Act, which invest only in direct U.S. government treasury obligations, as determined by the Company, until the earlier of: (i) the completion of a Business Combination and (ii) the distribution of the Trust Account as described below.

If we are unable to complete a Business Combination within 24 months from the closing of the Initial Public Offering, or March 25, 2023 (unless such date is extended in accordance with the Company’s amended and restated memorandum and articles of association) (the “Combination Period”), we will (i) cease all operations except for the purpose of winding up; (ii) as promptly as reasonably possible but not more than ten business days thereafter, redeem the Public Shares, at a per-share price, payable in cash, equal to the aggregate amount then on deposit in the Trust Account, including interest earned on the funds held in the Trust Account and not previously released to us to pay its income taxes, if any (less up to $100,000 of interest to pay dissolution expenses) divided by the number of the then-outstanding Public Shares, which redemption will completely extinguish Public Shareholders’ rights as shareholders (including the right to receive further liquidation distributions, if any); and (iii) as promptly as reasonably possible following such redemption, subject to the approval of the remaining shareholders and the board of directors, liquidate and dissolve, subject in the case of clauses (ii) and (iii), to the Company’s obligations under Cayman Islands law to provide for claims of creditors and the requirements of other applicable law.

Proposed Business Combination

On December 2, 2021, the Company, Opal HoldCo LLC, a Delaware limited liability company (“

Opal HoldCo

”), and Opal Fuels LLC, a Delaware limited liability company (“

Opal Fuels

”), entered into a Business Combination Agreement (as it may be amended, supplemented or otherwise modified from time to time, the “

Business Combination Agreement

”).

The Business Combination Agreement and the transactions contemplated thereby (collectively, the “

Business Combination

”) were unanimously approved by the boards of directors of each of the Company and Opal and also approved by Opal Holdco, the sole member of Opal Fuels. The Business Combination Agreement provides for, among other things, the following transactions: (i) each outstanding Class B ordinary share, par value $0.0001 per share, of the Company will convert into one Class A ordinary share, par value $0.0001 per share, of the Company; (ii) the Company will change the jurisdiction of its incorporation by deregistering as an exempted company in the Cayman Islands and domesticating to, and continuing as a corporation incorporated under the laws of, the State of Delaware (the “

Domestication

”) and, in connection with the Domestication, (A) the Company’s name will be changed to “Opal Fuels Inc.” (“

New Opal

”), (B) each outstanding Class A ordinary share of the Company will become one share of Class A common stock, par value $0.0001 per share, of New Opal (the “

New Opal Class

A Common Stock

”), (C) each outstanding warrant to purchase one Class A ordinary share of the Company will become a warrant to purchase one share of New Opal Class A common stock and (D) New Opal will file its certificate of incorporation and adopt bylaws to serve as its governing documents in connection with the Domestication; and (iii) (A) Opal Fuels will cause its existing limited liability company agreement to be amended and restated, (B) Opal Fuels will cause all of its limited liability company interests existing immediately prior to the closing of the Business Combination (the “

Closing

”)
to be re-classified into a
number of common units (collectively, the “

Opal Units

”) based
on a pre-transaction equity value
for Opal equal to $1,501,870,000, less all principal and accrued interest outstanding immediately after the Closing pursuant to that certain convertible promissory note, dated as of May 1, 2021 (as amended, including that certain First Amendment to Convertible Note, dated November 29, 2021”), held by ARCC Beacon LLC, a Delaware limited liability company (“

Ares

”), (C) the Company will contribute the (x) the amount of cash in the

Trust Account

established by the Company with the proceeds from its initial public offering as of immediately prior to the Closing (and before, for the avoidance of doubt, giving effect to

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the exercise of redemption rights by any of the Company’s shareholders (the “

Public Share Redemptions

”)), minus (y) the aggregate amount of cash required to fund the ACT Share Redemptions and any other obligations to be funded from the Trust Account, plus (z) the aggregate cash proceeds actually received in respect of the PIPE Investment (as defined below) and (E) New Opal will issue to Opal Fuels, and Opal Fuels will in turn distribute to Opal HoldCo and Hillman RNG Investments, LLC (“

Hillman

”) a number of shares of Class D common stock, par value $0.0001 per share, of New Opal (the “

New Opal Class

D Common Stock

”), and distribute to Ares (together with Opal HoldCo and Hillman, collectively, the “

Opal Equityholders

”) shares of Class B common stock, par value $0.0001 per share, of New Opal (the “

New Opal Class

B Common Stock

”) (neither of which will have any economic value but will entitle the holder thereof to five votes per share or one vote per share, respectively), equal to the number of Opal Units held by each of the Opal Equityholders.

In addition, if New Opal’s annual EBITDA for the calendar year 2023 exceeds $238,000,000 (the “

First Earnout Triggering Event

”), New Opal will issue to Opal HoldCo, Ares and Hillman (collectively, the “

Earnout Participants

”) an aggregate of 5,000,000 shares of New Opal Class B Common Stock and New Opal Class D Common Stock and corresponding Opal Units (collectively, the “

First Earnout Tranche

”) in accordance with the allocations set forth in the Business Combination Agreement. Additionally, if New Opal’s annual EBITDA for the calendar year 2024 exceeds $446,000,000 (the “

Second Earnout Triggering Event

”), New Opal will issue to the Earnout Participants an aggregate of 5,000,000 additional shares of New Opal Class B Common Stock and New Opal Class D Common Stock and corresponding Opal Units (collectively, the “

Second Earnout Tranche

”) in accordance with the allocations set forth in the Business Combination Agreement. In the event that the First Earnout Triggering Event does not occur but the Second Earnout Triggering Event does occur, New Opal will be obligated to issue both the First Earnout Tranche and the Second Earnout Tranche upon the occurrence of the Second Earnout Triggering Event.

The Business Combination is expected to close late in the first half of 2022, following the receipt of the required approval by the Company’s shareholders and the fulfillment of other customary closing conditions.

PIPE Financing (Private Placement)

Concurrently with the execution of the Business Combination Agreement, the Company entered into subscription agreements (the “

Subscription Agreements

”) with certain investors, including, among others, an affiliate of the Company, as well as additional third-party investors. Pursuant to the Subscription Agreements, each investor agreed to subscribe for and purchase, and the Company agreed to issue and sell to such investors, immediately prior to the Closing, an aggregate of 12,500,000 shares of the Company’s common stock for a purchase price of $10.00 per share, for aggregate gross proceeds of $125,000,000 (the “

PIPE Investment

”).

The closing of the PIPE Investment is contingent upon, among other things, the substantially concurrent consummation of the Business Combination. The Subscription Agreements provide that the Company will grant the investors in the PIPE Investment certain customary registration rights.

Investor Rights Agreement

The Business Combination Agreement contemplates that, at the Closing, Opal Fuels, Ares, Hillman and the Class B Shareholders (collectively the “

New Opal Holders

”) will enter into an Investor Rights Agreement (the “

Investor Rights Agreement

”), pursuant to which, among other things, (i) the Company and the Company’s sponsor will agree to terminate the Registration and Shareholder Rights Agreement, dated as of March 25, 2021, entered into by them in connection with the Company’s initial public offering, (ii) New Opal will provide the New Opal Holders certain registration rights with respect to certain shares of New Opal Class A common stock held by them or otherwise issuable to them pursuant to the Business Combination Agreement, Second A&R LLC Agreement or the certificate of incorporation of New Opal and (iii) the New Opal Holders will agree not to transfer, sell, assign or otherwise dispose of their shares of New Opal Class A common stock for up to 180 days following the Closing, subject to certain exceptions.

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Results of Operations

Our entire activity since inception through December 31, 2021 relates to our formation, the preparation for the Initial Public Offering, and since the closing of the Initial Public Offering, the search for a prospective initial Business Combination. We have neither engaged in any operations nor generated any revenues to date. We will not generate any operating revenues until after completion of our initial Business Combination. We will generate
non-operating
income in the form of interest income on cash and cash equivalents and
non-operating
income in the form of interest and investment income on investments held in Trust Account from the proceeds derived from the Initial Public Offering. We expect to incur increased expenses as a result of being a public company (for legal, financial reporting, accounting and auditing compliance), as well as for due diligence expenses. Additionally, we recognize
non-cash
gains and losses within other income (expense) related to changes in recurring fair value measurement of our warrant liabilities at each reporting period.

For the period from January 13, 2021 (inception) through December 31, 2021, we had a net loss of approximately $16.2 million from changes in the value of derivative warrant liabilities of approximately $10.8 million, approximately $4.9 million in general and administrative costs and financing costs attributable to the warrant liabilities of approximately $463,000, partially offset by a gain of approximately $12,000 on investments held in Trust Account.

Liquidity and Capital Resources

As of December 31, 2021, we had approximately $812,000 in our operating bank account and working capital of approximately $1.4 million.

Our liquidity needs up to December 31, 2021 had been satisfied through a payment of $25,000 from the sponsor to cover certain expenses on behalf of the Company in exchange for the issuance of the Founder Shares (as defined below), a loan under a promissory note from our sponsor of approximately $172,000 (the “Note”), and the net proceeds from the consummation of the Private Placement not held in the Trust Account. The Note was repaid in full on March 26, 2021. In addition, in order to finance transaction costs in connection with a Business Combination, our officers, directors and Initial Shareholders may, but are not obligated to, provide the Company with Working Capital Loans. To date, there are no amounts outstanding under any Working Capital Loans.

Based on the foregoing, management believes that we will have sufficient working capital and borrowing capacity from the sponsor or an affiliate of the sponsor, or certain of our officers and directors to meet our needs through the earlier of the consummation of a Business Combination or one year from this filing. Over this time period, we will be using these funds for paying existing accounts payable, identifying and evaluating prospective initial Business Combination candidates, performing due diligence on prospective target businesses, paying for travel expenditures, selecting the target business to merge with or acquire, and structuring, negotiating and consummating the Business Combination.

We continue to evaluate the impact of the
COVID-19
pandemic and have concluded that the specific impact is not readily determinable as of the date of the balance sheet. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.

Contractual Obligations

We do not have any long-term debt obligations, capital lease obligations, operating lease obligations, purchase obligations or long-term liabilities, other than an administrative services agreement to pay our sponsor $10,000 per month for office space, secretarial and administrative services provided to us (see “

Administrative Services Agreement” below)

.

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Registration and Shareholder Rights

The holders of the Founder Shares, Private Placement Warrants, and warrants that may be issued upon conversion of Working Capital Loans (and any Class A ordinary shares issuable upon the exercise of the Private Placement Warrants and warrants that may be issued upon conversion of Working Capital Loans) are entitled to registration rights pursuant to a registration and shareholder rights agreement. The holders of these securities are entitled to make up to three demands, excluding short form demands, that we will register such securities. In addition, the holders have certain “piggy-back” registration rights with respect to registration statements filed subsequent to the completion of the initial Business Combination. We will bear the expenses incurred in connection with the filing of any such registration statements.

Underwriting Agreement

We granted the underwriters a
45-day option
from the date of the prospectus to purchase up to 4,125,000 additional Units at the Initial Public Offering price less the underwriting discounts and commissions. On March 25, 2021, the underwriters partially exercised the over-allotment option to purchase an additional 3,616,305 Units. The remaining unexercised over-allotment option expired at the conclusion of the 45-day option period.

The underwriters were entitled to an underwriting discount of $0.20 per unit, or approximately $6.2 million in the aggregate, paid upon the closing of the Initial Public Offering. In addition, $0.35 per unit, or approximately $10.9 million in the aggregate, will be payable to the underwriters for deferred underwriting commissions. The deferred fee will become payable to the underwriters from the amounts held in the Trust Account solely in the event that the Company completes a Business Combination, subject to the terms of the underwriting agreement.

Administrative Services Agreement

On March 25, 2021, we entered into an agreement that provided that, commencing on the date that our securities were first listed on Nasdaq through the earlier of consummation of the initial Business Combination and the liquidation, we agreed to pay the sponsor $10,000 per month for office space, secretarial and administrative services provided to us. We incurred $100,000 in expenses in connection with such services for the period from January 13, 2021 (inception) ended December 31, 2021 as reflected in the accompanying statements of operations.

In addition, the sponsor, officers and directors, or their respective affiliates will be reimbursed for any

out-of-pocket

expenses incurred in connection with activities on our behalf, such as identifying potential target businesses and performing due diligence on suitable Business Combinations. Our audit committee will review on a quarterly basis all payments that were made by us to the sponsor, executive officers or directors, or their affiliates. Any such payments prior to an initial Business Combination will be made using funds held outside the Trust Account.

Deferred Legal Fees

We entered into an engagement letter to obtain legal advisory services, pursuant to which our legal counsel agreed to defer their fees until the closing of the initial Business Combination. As of December 31, 2021, the Company recorded an aggregate of approximately $4.0 million in connection with such arrangement as deferred legal fees in the accompanying balance sheet.

Critical Accounting Policies

This management’s discussion and analysis of our financial condition and results of operations is based on our financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. The preparation of our statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities in our financial statements. On an ongoing basis, we evaluate our estimates and judgments, including those related to fair value of financial instruments and accrued expenses. We base our estimates on historical experience, known trends and events and various other factors that we believe to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates under different assumptions or conditions. We have identified the following as its critical accounting policies:

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Class A Ordinary shares subject to possible redemption

We account for our Class A ordinary shares subject to possible redemption in accordance with the guidance in the Financial Accounting Standards Board’s (“FASB”) Accounting Standards Codification (“ASC”) Topic 480 “Distinguishing Liabilities from Equity” (“ASC 480”). Class A ordinary shares subject to mandatory redemption (if any) is classified as liability instruments and are measured at fair value. Conditionally redeemable Class A ordinary shares (including Class A ordinary shares that feature redemption rights that are either within the control of the holder or subject to redemption upon the occurrence of uncertain events not solely within our control) are classified as temporary equity. At all other times, Class A ordinary shares are classified as shareholders’ equity. Our Class A ordinary shares feature certain redemption rights that are considered to be outside of our control and subject to the occurrence of uncertain future events. Accordingly, as of December 31, 2021, 31,116,305 Class A ordinary shares subject to possible redemption are presented at redemption value as temporary equity, outside of the shareholders’ equity section of our balance sheet.

Immediately upon the closing of the Initial Public Offering, we recognized the accretion from initial book value to redemption amount, which approximates fair value. The change in the carrying value of Class A ordinary shares subject to possible redemption resulted in charges against additional
paid-in
capital (to the extent available), accumulated deficit and Class A ordinary shares.

Derivative Warrant Liabilities

We do not use derivative instruments to hedge exposures to cash flow, market, or foreign currency risks. We evaluate all of our financial instruments, including issued share purchase warrants, to determine if such instruments are derivatives or contain features that qualify as embedded derivatives, pursuant to ASC 480 and FASB ASC Topic 815, “Derivatives and Hedging” (“ASC 815”). The classification of derivative instruments, including whether such instruments should be recorded as liabilities or as equity, is
re-assessed
at the end of each reporting period.

The warrants issued in our Initial Public Offering and the underwriters’ exercise of their overallotment option and Private Placement Warrants are recognized as derivative liabilities in accordance with ASC 815. Accordingly, we recognize the warrant instruments as liabilities at fair value and adjust the instruments to fair value at each reporting period. The liabilities are subject to remeasurement at each balance sheet date until exercised, and any change in fair value is recognized in the Company’s statement of operations. The fair value of warrants issued in connection with the Initial Public Offering and Private Placement were initially measured at fair value using a Monte Carlo simulation model and subsequently, the fair value of the Private Placement warrants have been estimated using a Monte Carlo simulation model each measurement date. The fair value of Warrants issued in connection with our Initial Public Offering have subsequently been measured based on the listed market price of such warrants. Derivative warrant liabilities are classified as non-current liabilities as their liquidation is not reasonably expected to require the use of current assets or require the creation of current liabilities.

Investments Held in Trust Account

Our portfolio of investments is comprised of U.S. government securities, within the meaning set forth in Section 2(a)(16) of the Investment Company Act, with a maturity of 185 days or less, or investments in money market funds that invest in U.S. government securities and generally have a readily determinable fair value, or a combination thereof. When our investments held in the Trust Account are comprised of U.S. government securities, the investments are classified as trading securities. When our investments held in the Trust Account are comprised of money market funds, the investments are recognized at fair value. Trading securities and investments in money market funds are presented on the balance sheet at fair value at the end of each reporting period. Gains and losses resulting from the change in fair value of these securities is included in net gain on investments held in Trust Account in the accompanying statement of operations. The estimated fair values of investments held in the Trust Account are determined using available market information.

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Net loss per ordinary shares

We have two classes of shares: Class A ordinary shares and Class B ordinary shares. Income and losses are shared pro rata between the two classes of shares. Net income (loss) per ordinary share is computed by dividing net income (loss) by the weighted-average number of ordinary shares outstanding during the periods. We have not considered the effect of the warrants sold in the Initial Public Offering and the Private Placement to purchase an aggregate of 15,446,522, of the Company’s Class A ordinary shares in the calculation of diluted net income (loss) per share, since their inclusion would be anti-dilutive under the treasury stock method. As a result, diluted net income (loss) per share is the same as basic net income (loss) per share for the period January 13, 2021 (inception) through December 31, 2021. Accretion associated with the Class A ordinary shares subject to possible redemption is excluded from earnings per share as the redemption value approximates fair value.

Recent Accounting Pronouncements

In August 2020, the FASB issued Accounting Standards Update (“ASU”)
2020-06,
“Debt — Debt with Conversion and Other Options (Subtopic
470-20)
and Derivatives and Hedging — Contracts in Entity’s Own Equity (Subtopic
815-40)”
(“ASU
2020-06”)
to simplify accounting for certain financial instruments. ASU
2020-06
eliminates the current models that require separation of beneficial conversion and cash conversion features from convertible instruments and simplifies the derivative scope exception guidance pertaining to equity classification of contracts in an entity’s own equity. The new standard also introduces additional disclosures for convertible debt and freestanding instruments that are indexed to and settled in an entity’s own equity. ASU
2020-06
amends the diluted earnings per share guidance, including the requirement to use the
if-converted
method for all convertible instruments. ASU
2020-06
is effective for the Company on January 1, 2024 and should be applied on a full or modified retrospective basis, with early adoption permitted beginning on January 1, 2021. The Company is currently assessing the impact, if any, that ASU
2020-06
would have on its financial position, results of operations or cash flows.

Our management does not believe that any other recently issued, but not yet effective, accounting standards, if currently adopted, would have a material effect on the accompanying financial statements.

Off-Balance Sheet Arrangements

As of December 31, 2021, we did not have any
off-balance
sheet arrangements as defined in Item 303(a)(4)(ii) of Regulation
S-K.

JOBS Act

On April 5, 2012, the JOBS Act was signed into law. The JOBS Act contains provisions that, among other things, relax certain reporting requirements for qualifying public companies. We qualify as an “emerging growth company” under the JOBS Act and are allowed to comply with new or revised accounting pronouncements based on the effective date for private (not publicly traded) companies. We elected to delay the adoption of new or revised accounting standards, and as a result, we may not comply with new or revised accounting standards on the relevant dates on which adoption of such standards is required for
non-emerging
growth companies. As a result, our financial statements may not be comparable to companies that comply with new or revised accounting pronouncements as of public company effective dates.

As an “emerging growth company”, we are not required to, among other things, (i) provide an auditor’s attestation report on our system of internal controls over financial reporting pursuant to Section 404, (ii) provide all of the compensation disclosure that may be required of
non-emerging
growth public companies under the Dodd-Frank Wall Street Reform and Consumer Protection Act, (iii) comply with any requirement that may be adopted by the PCAOB regarding mandatory audit firm rotation or a supplement to the auditor’s report providing additional information about the audit and the financial statements (auditor discussion and analysis), and (iv) disclose certain executive compensation related items such as the correlation between executive compensation and performance and comparisons of the CEO’s compensation to median employee compensation. These exemptions will apply for a period of five years following the completion of our initial public offering or until we are no longer an “emerging growth company,” whichever is earlier.

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