Ameresco, Inc. (AMRC) FY 2024 MD&A

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

You should read the following discussion and analysis of our financial condition and results of operations together with our consolidated financial statements and the related notes and other financial information included in Item 8 of this Report. Some of the information contained in this discussion and analysis are set forth elsewhere in this Report, including information with respect to our plans and strategy for our business and related financing, and includes forward-looking statements that involve risks and uncertainties. You should review the “Risk Factors” included in Item 1A of this Report for a discussion of important factors that could cause actual results to differ materially from the results described in or implied by the forward-looking statements contained in the following discussion and analysis.

Overview

Ameresco is a leading energy solutions provider dedicated to helping customers navigate the energy transition. Our comprehensive portfolio includes implementing smart energy efficiency solutions, upgrading aging infrastructure, and developing, constructing, and operating distributed energy resources.

Drawing from decades of experience, Ameresco reduces energy use and delivers diversified generation solutions to Federal, state and local governments, utilities, educational and healthcare institutions, housing authorities, and commercial and industrial customers.

We provide solutions primarily throughout North America and Europe, and our revenues are derived principally from energy efficiency projects, which entail the design, engineering, and installation of equipment and other measures that incorporate a range of innovative technology and techniques to improve the efficiency and control the operation of a facility’s energy infrastructure; this can include designing and constructing a central plant or cogeneration system for a customer providing power, heat and/or cooling to a building, or other small-scale plant that produces electricity, gas, heat or cooling from renewable sources of energy. We also derive revenue from long-term O&M contracts, energy supply contracts for renewable energy operating assets that we own, integrated-PV, and consulting and enterprise energy management services.

In addition to organic growth, strategic acquisitions of complementary businesses and assets, and joint venture arrangements have been an important part of our growth enabling us to broaden our service offerings and expand our geographical reach.

Key Factors and Trends

Regulatory Environment and Federal Policies

Federal policies play an important role in our business and our business benefits from regulatory measures and various tax credits, such as the Investment Tax Credit (“ITC”) and the Production Tax Credit (“PTC”) and funds appropriated through the IRA and the IIJA. The scope of these tax credits and the availability of funding through the IRA and IIJA may evolve with the new U.S. administration. Recent presidential executive orders that directed a review and potential termination of funds appropriated through the IRA and the IIJA have resulted in some pauses and cancellations of our projects. We also anticipate that federal workforce reductions and other cost savings initiatives may cause additional delays, extend our sales cycles and impact new award activity. However, we continue to believe there is a long-term demand for our budget neutral, cost-saving solutions.

Supply Chain Disruptions and Other Global Factors

We continue to monitor the impact of global economic conditions on our operations, financial results, and liquidity, such as the impact of tariffs, supply chain challenges, the wars in Ukraine and the Middle East, evolving relations between the U.S. and China, and other geopolitical tensions. Import duties, tariffs and other import restrictions, including the Uyghur Forced Labor Protection Act, restrict the global supply of, and raise prices for, supplies needed for our business. In addition, tariffs and trade restrictions that have been introduced any may be introduced as part of the 'America First' trade policy may further increase the cost of components needed for our offerings and may strain trade relations, create inflationary pressures and cause additional supply chain disruptions. The impact to our future operations and results of operations as a result of these global trends remains uncertain and the challenges we face, including increases in costs for logistics and supply chains, intermittent supplier delays, and

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shortages of certain components needed for our business, such as electrical equipment, steel and aluminum as well as BESS equipment or components required for our projects and clean energy solutions may continue or become more pronounced.

During the year ended December 31, 2024, we were impacted by supply chain disruptions and varying levels of inflation, as a result macroeconomic conditions, causing delays in the timely delivery of material to customer sites and delays and disruptions in the completion of certain project, and increased shipping and transportation costs, as well as increased component and labor costs. This negatively impacted our results of operations during the year ended December 31, 2024. We expect to experience continued supply chain challenges beyond this year. We continue to monitor macroeconomic conditions to remain flexible and to optimize and evolve our business as appropriate to address the challenges presented from these conditions.

These tariffs, restrictions, and strained trade relations may affect our ability to source materials and products, potentially leading to increased costs and operational challenges and decreased demand for or offerings. We are closely monitoring the regulatory environment and actions of the current administrations that could impact our business.

Climate Change and Effects of Seasonality

The global emphasis on climate change and reducing carbon emissions has created opportunities for our industry. Sustainability has been at the forefront of our business since its inception, and we are committed to staying at the leading edge of innovation taking place in the energy sector. We believe the next decade will be marked by dramatic changes in the power infrastructure with resources shifting to more distributed assets, storage, and microgrids to increase overall reliability and resiliency. The sustainability efforts are impacted by regulations, and changes in the regulatory climate may impact the demand for our products and offerings. See “Our business depends in part on federal, state, provincial and local government support or the imposition of additional taxes, tariffs, duties, or other assessments on renewable energy or the equipment necessary to generate or deliver it, for energy efficiency and renewable energy, and a decline in such support could harm our business” and “Compliance with environmental laws could adversely affect our operating results” in Item 1A, Risk Factors.

Climate change also brings risks, as the impacts have caused us to experience more frequent and severe weather interferences, and this trend is expected to continue. We are subject to seasonal fluctuations and construction cycles, particularly in climates that experience colder weather during the winter months, such as the northern United States and Canada, and climates that experience extreme weather events, such as wildfires, storms or flooding, hurricanes, or at educational institutions, where large projects are typically carried out during summer months when their facilities are unoccupied. In addition, government customers, many of which have fiscal years that do not coincide with ours, typically follow annual procurement cycles and appropriate funds on a fiscal-year basis even though contract performance may take more than one year. Further, government contracting cycles can be affected by the timing of, and delays in, the legislative process related to government programs and incentives that help drive demand for energy efficiency and renewable energy projects. As a result, our revenues and operating income in the third and fourth quarter are typically higher, and our revenues and operating income in the first quarter are typically lower, than in other quarters of the year, however, this may become harder to predict with the potential effects of climate change. As a result of such fluctuations, we may occasionally experience declines in revenues or earnings as compared to the immediately preceding quarter, and comparisons of our operating results on a period-to-period basis may not be meaningful.

Our annual and quarterly financial results are also subject to significant fluctuations as a result of other factors, many of which are outside our control. See “Our business is affected by seasonal trends and construction cycles, and these trends and cycles could have an adverse effect on our operating results” and “Extreme weather events and other natural disasters, particularly those exacerbated by climate change, could materially affect our ability to complete our projects and develop our assets” in Item 1A, Risk Factors.

The Southern California Edison (“SCE”) Agreement

In October 2021, we entered into a contract with SCE to design and build three grid scale BESS at three sites near existing substation parcels throughout SCE’s service territory in California with an aggregate capacity of 537.5 MW (“the SCE Agreement”). The engineering, procurement and construction price is approximately $892.0 million, in the aggregate, including two years of O&M revenues, subject to customary potential adjustments for changes in the work. As previously disclosed, due to supply chain delays, weather and other events, we were unable to complete the projects by August 1, 2022 (the “Guaranteed Completion Date”). On August 30 2024, we reached an agreement with SCE on the substantial completion of two out of three battery energy storage system projects. We received approximately $110 million on September 5, 2024 as milestone payments, reflecting both an offset of liquidated damages which are still in dispute and $3 million that SCE withheld for additional work SCE required. Upon final acceptance of these two projects, we will invoice SCE for the remaining final acceptance milestone payments for these projects. The SCE Agreement also confirmed that the final resolution related to our obligation to pay the liquidated damages withheld and the applicability and scope of any force majeure relief as well as any cost recovery we may be entitled to remain subject to dispute. We are continuing discussions with SCE on these matters and our view continues to be that liquidated damages should not be applied. If we fail to come to an agreement with SCE about the applicability and scope of force

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majeure relief and liquidated damages, we may be required to pay liquidated damages up to an aggregate maximum of $89 million and may not be able to recover costs associated with the force majeure events.

A majority of our revenues under this contract were recognized in 2022 based upon costs incurred in 2022 relative to total expected costs on this project.

Stock-based Compensation

During the year ended December 31, 2024, we granted 791,503 common stock options to certain employees and 122,366 restricted stock units (“RSUs”) to our employees and non-employee directors under our 2020 Stock Incentive Plan. Our stock-based compensation expense increased from $10.3 million for the year ended December 31, 2023 to $14.1 million for the year ended December 31, 2024. Stock-based compensation increased in 2024, primarily due to the increase in options and RSUs granted, partially offset by a decrease in the weighted average fair value of stock options and RSUs granted.

In addition, our unrecognized stock-based compensation expense decreased from $30.1 million at December 31, 2023 to $28.0 million at December 31, 2024, and is expected to be recognized over a weighted-average period of two years. See Note 14 “Stock-based Compensation and Other Employee Benefits” for additional information.

Backlog and Awarded Projects

Backlog is an important metric for us because we believe strong order backlogs indicate growing demand and a healthy business over the medium to long term, conversely, a declining backlog could imply lower demand.

The following table presents our backlog:

Total project backlog represents energy efficiency projects that are active within our sales cycle, either full-contracted or awarded. Our sales cycle begins with the initial contact with the customer and ends, when successful, with a signed contract, also referred to as fully-contracted backlog. Our sales cycle recently has been averaging 18 to 42 months. Awarded backlog is created when a potential customer awards a project to Ameresco following a request for proposal. Once a project is awarded but not yet contracted, we typically conduct a detailed energy audit to determine the scope of the project as well as identify the savings that may be expected to be generated from upgrading the customer’s energy infrastructure. At this point, we also determine the subcontractor, what equipment will be used, and assist in arranging for third party financing, as applicable. Recently, awarded projects have been taking an average of 12 to 24 months to result in a signed contract and convert to fully-contracted backlog. It may take longer, as it depends on the size and complexity of the project. Historically, approximately 90% of our awarded backlog projects have resulted in a signed contract. After the customer and Ameresco agree to the terms of the contract and the contract becomes executed, the project moves to fully-contracted backlog. The contracts reflected in our fully-contracted backlog typically have a construction period of 12 to 36 months and we typically expect to recognize revenue for such contracts over the same period.

Our O&M backlog represents expected future revenues under signed, multi-year customer contracts for the delivery of O&M services, primarily for energy efficiency and renewable energy construction projects completed by us for our customers.

We define our 12-month backlog as the estimated amount of revenues that we expect to recognize in the next twelve months from our fully-contracted backlog. See Note 2 “Summary of Significant Accounting Policies” for our revenue recognition policies. See

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“We may not recognize all revenues from our backlog or receive all payments anticipated under awarded projects and customer contracts” and “In order to secure contracts for new projects, we typically face a long and variable selling cycle that requires significant resource commitments and requires a long lead time before we realize revenues” in Item 1A, Risk Factors.

Assets in Development

Assets in development, which represents the potential design/build project value of small-scale renewable energy plants that have been awarded or for which we have secured development rights, were estimated at $2.3 billion as of December 31, 2024, and $2.4 billion, including $90 million attributable to a non-controlling interest, as of December 31, 2023. The portion related to spending for EaaS assets was approximately $538.4 million and $399.8 million at December 31, 2024 and 2023, respectively. These are also important metrics because they help us gauge our future capacity to generate electricity or deliver renewable gas fuel which contributes to our recurring revenue stream.

Results of Operations

The following table sets forth certain financial data from the consolidated statements of income for the periods indicated (1):

Our results of operations for the year-ended December 31, 2024 reflect a year-over-year increase in terms of revenues, operating income, and net income attributable to common shareholders. All financial result comparisons are against the prior year period.

•Revenue: total revenues increased primarily due to a $337.4 million, or 34%, increase in our project revenue attributed to the timing of revenue recognized based upon costs incurred to date relative to total expected costs on active projects.

•Cost of Revenues and Gross Profit: the increase in cost of revenues is primarily due to the increased project revenues described above, however, our gross profit as a percent of revenues decreased primarily due to cost overruns on two large-scale legacy projects and a mix of lower-margin projects.

•Earnings from Unconsolidated Entities: the decrease in earnings from unconsolidated entities is due to the sale of one of our equity method investments during the first quarter of 2024.

•Gain on Sale of Business, Net: in 2024, we divested an energy technology and advisory services company and recognized a gain of $38.0 million, net of transaction expenses.

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•Selling, General and Administrative Expenses: the increase is primarily due to higher net salaries and benefits of $8.3 million, of which $3.8 million is from increased non-cash stock-based compensation expense, higher insurance of $1.6 million and occupancy costs of $1 million, partially offset by a decrease in professional fees of $2.0 million.

•Asset Impairments: This year includes long-lived asset impairment charges of $12.4 million recorded in 2024 primarily related to one of our landfill gas to energy assets and solar panels purchased under the IRS safe harbor provisions for renewable energy projects. Last year included long-lived asset impairment charges of $1.6 million related to two of our landfill gas to energy assets, and a goodwill impairment charge of $1.6 million, which was $2.2 million after taking into account the effect of deferred income taxes related to one of our reporting units.

•Interest and Other Expenses, Net: Interest and other expenses, net, includes gains and losses from derivatives transactions, foreign currency transactions, interest expense, interest income, amortization of financing costs and certain government incentives. Interest and other expenses, net increased primarily due to higher interest expenses, net of interest income of $28.9 million related to increased levels of project debt and higher rate paid on our second lien term loan, and foreign currency transaction losses of $3.8 million versus gains of $0.6 million last year.

•Income Tax Benefit: the benefit for income taxes is based on various rates set by federal, state, provincial, and local authorities and is affected by generated tax credits and differences between financial accounting and tax reporting requirements. The tax benefit was lower in 2024 as compared to 2023 because we incurred additional tax expense from the deferred effect of an increase in our future effective state tax rates resulting from apportionment changes and the Section 179D Energy Efficient Commercial Buildings Deduction available for 2024 was lower due to the timing of project completions, offset by higher tax credits generated as a result of new U.S. Treasury regulations related to renewable gas projects. The tax benefit for 2023 was favorable, primarily due to higher deductions under Section 179D and deferred state tax benefits resulting from reduced state tax rates.

•Net Income and Earnings Per Share: Net income attributable to common shareholders decreased due to the reasons described above. Basic earnings per share for 2024 was $1.08, a decrease of $0.12 per share compared to 2023. Diluted earnings per share for 2024 was $1.07, a decrease of $0.10 per share, compared to 2023.

Business Segment Analysis

Our reportable segments for the year ended December 31, 2024 were North America Regions, U.S. Federal, Europe, and Renewable Fuels (formerly Alternative Fuels). On January 1, 2024, we changed the structure of our internal organization, and our U.S. Regions and Canada are now included in North America Regions. Additionally, our Asset Sustainability Group was formerly included in Canada, but is now included in “All Other”. As a result, previously reported amounts have been reclassified for comparative purposes. See Note 20 “Business Segment Information” for additional information about our segments.

Revenues

•North America Regions: the increase is primarily due to a $243.3 million, or 47%, increase in project revenues attributable to the timing of revenue recognized based upon costs incurred to date relative to total expected costs on active projects.

•U.S. Federal: the decrease is primarily due to a $48.2 million, or 14%, decrease in project revenue attributable to the timing of revenue recognized as a result of the phase of active projects compared to the prior year, partially offset by increases of $11.1 million in energy asset revenue and $6.6 million in O&M revenue.

•Renewable Fuels: the increase is primarily due to higher project revenues of $43.4 million and a $15.6 million increase in energy asset revenues resulting from the continued growth of our operating portfolio, increased production levels and stronger pricing on renewable identification numbers (“RIN’s”) generated from our renewable natural gas facilities.

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•Europe: revenues increased primarily due to higher project revenue of $100.1 million, or 72%, resulting from the timing of revenue recognized based upon costs incurred to date relative to total expected costs on active projects in the United Kingdom compared to the prior period.

•All Other: All other revenues were higher primarily due to increased consulting revenue.

Income (Loss) before Income Taxes and Unallocated Corporate Activity

•North America Regions: the increase is primarily due to the higher revenues described above, offset by lower gross profit as a percent of revenues primarily due to cost overruns on two large-scale legacy projects and increased depreciation and intangible amortization and interest expense, and a loss on derivatives this year versus a gain last year.

•U.S. Federal: the decrease is due primarily to the decreased revenues described above, higher interest expense, net of $3.6 million and lower earnings from unconsolidated entities of $1.1 million.

•Renewable Fuels: the decrease is primarily due to higher asset impairment charges of $7.6 million on one of our landfill gas to energy assets and higher interest expense of $9.5 million, partially offset by the higher revenues described above.

•Europe: the decrease is primarily due to a higher mix of lower-margin projects, increased salaries and benefits, net, and higher interest expense, partially offset by decreased bank discount fees.

•All Other: the increase is primarily due to a gain of $38.0 million on the sale of business, net and increased consulting revenue.

•Unallocated corporate activity includes all corporate level selling, general and administrative expenses and other expenses not allocated to the reportable segments. We do not allocate any indirect expenses to the segments. Corporate expenses increased primarily due higher interest expense, net of $11.1 million, higher net salaries and benefit costs of $7.6 million, including an increase in non-cash stock-based compensation expense of $3.8 million, and foreign currency transaction losses of $2.5 million versus gains of $0.5 million last year.

Liquidity and Capital Resources

Overview

Since inception, we have funded operations primarily through cash flow from operations, advances from Federal ESPC projects, our senior secured credit facility, second lien term loan, and various forms of other debt (see “Energy Asset Financing” below).

Working capital requirements can be susceptible to fluctuations during the year due to timing differences between costs incurred, the timing of milestone-based customer invoices and actual cash collections. Working capital may also be affected by seasonality, growth rate of revenue, long lead-time equipment purchase patterns, advances from Federal ESPC projects, and payment terms for payables relative to customer receivables.

We expect to incur additional expenditures in connection with the following activities:

•equity investments, project asset acquisitions, and business acquisitions that we may fund from time to time

•capital investment in current and future energy assets

•material, equipment, and other expenditures for large projects

We regularly monitor and assess our ability to meet funding requirements. We believe that cash and cash equivalents, working capital and availability under our revolving senior secured credit facility, combined with our right (subject to lender consent) to increase our revolving credit facility by $100.0 million, plus develop and sell asset transactions, sales of tax attributes, and our general access to credit and equity markets, will be sufficient to fund our operations through at least February 2026.

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We continue to evaluate and take action, as necessary, to preserve adequate liquidity and ensure that our business can continue to operate and that we can meet our capital and debt service requirements. This may include limiting discretionary spending across the organization and re-prioritizing our capital projects amid times of political unrest, the duration of supply challenges, and the rate and duration of the inflationary pressures, and other events affecting our liquidity. For example, recent increases in inflation and interest rates have impacted overall market returns on assets. We have therefore been particularly prudent in our capital commitments over the past few quarters, ensuring that our assets in development continue to align with our hurdle rates.

Divestiture of a Business

On December 31, 2024, we completed the sale of a business. As a result of this transaction, we received net proceeds of $54.2 million, and recorded a gain of $38.0 million, net of transaction costs of $2.2 million, from this disposition. At closing we prepaid $57.0 million towards our senior secured term loan.

August 2023 Purchase and Sale Agreement

On August 4, 2023, we entered into a purchase and sale agreement to acquire an energy asset project and the right to acquire 100% of the stock of BCE in a two-phased transaction, exclusive of each other. Phase 1, the purchase of the energy asset project, closed on August 4, 2023 and did not constitute a business in accordance with ASC 805-50, Business Combinations.

The adjusted purchase price for phase 1 was $88.0 million, of which $5.0 million was paid in cash, $46.7 million was financed through a seller’s note, and we assumed a construction loan on the energy asset project for $36.3 million. The construction loan was converted to a term loan in February 2024 and has a maturity date of April 2030. We also received cash of $11.2 million. In January 2024 we paid off the remaining balance on the seller’s note in the amount of $29.4 million. We sold back to the seller ITCs for the project acquired as part of this transaction for the fair market value of these credits and we received $21.0 million in early 2024 for the transfer of these credits. In addition, we assumed a land lease for the energy asset project. See Note 8 “Leases” for additional information on the lease.

In the second phase, which closed on January 12, 2024, we acquired BCE, including its interest in one of our consolidated joint venture and its interests in project subsidiaries developing or with rights to develop solar, battery, and microgrid assets for a purchase price of $39.1 million, of which $6.6 million was paid at the closing. The remaining $32.5 million was financed by a seller’s note accruing interest of 5.0%, through August 2024 and was adjusted to 9% per annum until the note was paid off in full in November 2024. We may be required to make additional contingent payments for this acquisition based on certain projects achieving commercial operation and if the projects qualify for higher energy tax credits than expected.

Senior Secured Credit Facility — Revolver and Term Loans

During the year ended December 31, 2024, we entered into a number of amendments to our fifth amended and restated senior secured credit facility (the “Senior Secured Credit Facility”) , which extended the maturity date of our delayed draw term loan A (“DDTLA”). The overall rate table for all loans under the agreement was also increased by 0.25%. The amendments increased the total funded debt to EBITDA covenant ratio from a maximum of 3.50 to 3.75 for the quarter ending December 31, 2024, and 3.50 thereafter. On June 28, 2024, we entered into amendment number six to the fifth amended and restated senior secured credit facility to modify certain of the covenants and other terms to permit us to enter into the second lien credit agreement (as defined below) and to incur indebtedness and make certain other conforming changes in connection with our entry into the second lien credit agreement. The remaining balance on the DDTLA of $15 million was paid off with the proceeds from the second lien credit agreement.

As of December 31, 2024, the balance on the senior secured credit facility was $148.0 million and we had funds available of $21.1 million.

On January 23, 2025, we refinanced our Senior Secured Credit Facility by entering into a sixth amended and restated senior secured credit agreement (“Restated Credit Agreement”). At closing we paid approximately $2.0 million in lender’s fees.

The restated credit agreement amended and restated the Senior Secured Credit Facility to provide for the following facilities:

•a $225 million revolving credit facility, maturing on December 28, 2028, and

•a $100 million term loan A, maturing on December 28, 2028.

Second Lien Term Loan

On June 28, 2024, we entered into a second lien credit agreement which provided a term loan in a principal amount of $100 million with a maturity date of June 28, 2029. The term loan bears an interest rate of Secured Overnight Financing Rate (“SOFR”) (4.692% at December 31, 2024), plus an applicable margin of 5.875% per annum. Interest is payable quarterly and unpaid interest

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and principal is due in the aggregate on June 28, 2029.

Energy Asset Financing

Energy Asset Construction and Operating Facilities, Sale-leasebacks, and Financing Leases

We have entered into a number of construction and term loan agreements for the purpose of constructing and owning certain renewable energy plants. The physical assets and the operating agreements related to the renewable energy plants are generally owned by wholly owned, single member “special purpose” subsidiaries of Ameresco. These construction and term loans are structured as project financings made directly to a subsidiary, and upon commercial operation and achieving certain milestones in the credit agreement, the related construction loan converts into a term loan. While we are required under generally accepted accounting principles (“GAAP”) to reflect these loans as liabilities on our consolidated balance sheets, they are generally non-recourse and not direct obligations of Ameresco, Inc., except to the extent of completion guarantees and EPC contracts and certain equity contribution obligations under our August 2023 Construction Credit Facility as described in more detail below.

Our project financing facilities contain various financial and other covenant requirements which include debt service coverage ratios and total funded debt to EBITDA, as defined. Any failure to comply with the financial or other covenants of our project financings would result in inability to distribute funds from the wholly-owned subsidiary to Ameresco, Inc. or constitute an event of default in which the lenders may have the ability to accelerate the amounts outstanding, including all accrued interest and unpaid fees.

Other than what is included above, significant financings during the year ended December 31, 2024 were as follows:

•April 2023, 6.82%, due July 31, 2024 - one of our consolidated joint venture subsidiaries (“JV”) entered into a construction loan agreement with two lenders for a principal amount of up to $140.8 million under an energy asset credit facility. We acquired the remaining interest in this JV in January 2024 when we closed on the acquisition of BCE. In August 2024, this construction loan was repaid through a sale-leaseback financing under lease agreements entered into between the same parties, as part of the original closing. See “August 2024 Master Sale-leaseback” below.

•August 2023, 8.53%, due August 31, 2026 - we entered into a construction and development loan agreement, which provides a loan in a principal amount of up to $300.0 million. At the closing, we drew down $200.0 million under this facility, of which approximately $187.0 million was used to reimburse Ameresco for development and construction costs. On December 18, 2024, we amended the loan agreement to increase the principal amount up to $400.0 million, extend the maturity date to December 15, 2027, and set a minimum rate of interest at 6.00% and a Term SOFR Floor of 2.00%. Additionally, an accordion option providing for an option to increase the principal amount to $500.0 million, for which we paid a $0.3 million fee. The accordion option can be exercised no later than June 18, 2026 and only if certain circumstances are met. At closing, we incurred $3.2 million in lenders fees and debt issuance costs. The obligations under the loan are guaranteed by all the subsidiaries that are part of the loan portfolio and are secured by the subsidiaries’ assets as well as Ameresco Inc.'s equity interest in the subsidiary which is the borrower entity. In the case of default under the facility, a default under our Senior Secured Credit Facility or a change in control of Ameresco, Inc., we are required to make capital contributions to the borrower entity who then would be required to use the proceeds from the capital contributions to repay the construction and development loan.

As of December 31, 2024, our total energy asset construction and operating facilities outstanding was $1.0 billion. See Note 9 “Debt and Financing Lease Liabilities” for additional information about these loans.

Sale-leasebacks and Financing Leases

We have entered into sale-leaseback arrangements for solar PV energy assets with multiple investors and in accordance with Topic 842, Leases, all sale-leaseback transactions that occurred after December 31, 2018, were accounted for as failed sales and the proceeds received from the transactions were recorded as long-term financing facilities.

During the year ended December 31, 2024, we discovered a defect in a Battery Energy Storage System (“BESS”) that we installed for a customer under a long-term power purchase agreement for a project financed under the August 2018 master sale-leaseback agreement. As a result, the BESS had to be removed. Our financing partner has agreed to temporarily waive any events of default and refrain from pursuing remedies available under the master sale-leaseback associated with the BESS failure until December 31, 2025 to allow remediation of the issue (subject to certain conditions). We have fully funded lease payments due under the master lease agreement through December 31, 2025 into a reserve account from which lease payments will be made.

August 2024 Master Sale-leaseback - On April 18, 2023 we entered into lease agreements with two investors and on August 14, 2024 we sold and leased back an energy asset for $234.8 million, of which 50% was allocated to each investor under these agreements. One lease has an expiration date of August 14, 2034 with an option to extend to August 14, 2044 while the other has

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an expiration date of August 14, 2044. At closing, we used $140.8 million of the proceeds to pay off the April 2023 construction credit facility and made rent prepayments of $60.1 million.

As of December 31, 2024, our total sale-leasebacks classified as long-term financing facilities outstanding was $399.4 million.

As of December 31, 2024, our total financing leases outstanding was $12.9 million. These are our sale-leaseback arrangements entered into as of December 31, 2018 which remain under the previous guidance.

See Notes 8 “Leases” and 9 “Debt and Financing Lease Liabilities” for additional information on these financing facilities.

While we are required under GAAP to reflect these lease payments as liabilities on our consolidated balance sheets, they are generally non-recourse and not direct obligations of Ameresco Inc., except that we have guaranteed certain obligations relating to taxes and project warranties, operation, and maintenance.

Federal ESPC Liabilities

We have arrangements with certain third-parties to provide advances to us during the construction or installation of projects for certain customers, typically federal governmental entities, in exchange for our assignment to the lenders of our rights to the long-term receivables arising from the ESPCs related to such projects. These financings totaled $555.4 million in principal amounts as of December 31, 2024 and $533.1 million as of December 31, 2023. Under the terms of these financing arrangements, we are required to complete the construction or installation of the project in accordance with the contract with our customer, and the liability remains on our consolidated balance sheets until the completed project is accepted by the customer.

We are the primary obligor for financing received, but only until final acceptance of the work by the customer. At this point recourse to us ceases and the ESPC receivables are transferred to the investor. The transfers of receivables under these agreements do not qualify for sales accounting until final customer acceptance of the work, so the advances from the investors are not classified as operating cash flows. Cash draws that we received under these ESPC agreements were $164.8 million during the year ended December 31, 2024 and are recorded as financing cash inflows. The use of the cash received under these arrangements is to pay project costs classified as operating cash flows and totaled $158.9 million during the year ended December 31, 2024. Due to the manner in which the ESPC contracts with the third-party investors are structured, our reported operating cash flows are materially impacted by the fact that operating cash flows only reflect the ESPC contract expenditure outflows and do not reflect any inflows from the corresponding contract revenues. Upon acceptance of the project by the federal customer the ESPC receivable and corresponding ESPC liability are removed from our consolidated balance sheets as a non-cash settlement. See Note 2, “Summary of Significant Accounting Policies”, to our consolidated financial statements in this Report.

Other

We issue letters of credit and performance bonds, from time to time, with our third-party lenders, to provide collateral.

Selected Measures of Liquidity and Capital Resources

Cash Flows

The following table summarizes our changes in cash, cash equivalents, and restricted cash:

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Our service offering also includes the development, construction, and operation of small-scale renewable energy plants. Small-scale renewable energy projects, or energy assets, can either be developed for the portfolio of assets that we own and operate or designed and built for customers. Expenditures related to projects that we own are recorded as cash outflows from investing activities. Expenditures related to projects that we build for customers are recorded as cash outflows from operating activities as cost of revenues.

Cash Flows from Operating Activities

Our cash flow from operating activities in 2024 improved over 2023 primarily due to a decrease in the use of cash from Federal ESPC receivables of $101.4 million, increase in cash flows of $90.5 million from accounts payable, accrued expenses, and other current liabilities, $68.2 million from unbilled revenue, and $63.7 million from prepaid expenses and other current assets which includes the sale of ITCs on energy assets for $47.5 million. These were partially offset by decreased cash flows of $149.5 million from accounts receivable.

Cash Flows from Investing Activities

During 2024, we made capital investments of $417.0 million in new energy assets and $17.1 million in major maintenance of energy assets, compared to $538.4 million and $7.6 million, respectively, in 2023. As noted above, we sold a business in December 2024 and received net proceeds of $54.2 million,

We currently plan to invest approximately $350.0 million to $400.0 million in capital investments in 2025, principally for the construction or acquisition of new renewable energy plants.

Cash Flows from Financing Activities

Our primary sources of financing during 2024 were proceeds of $643.5 million from energy asset debt financings, $170.8 million from advances on Federal ESPC projects and energy assets, proceeds from the second lien term loan of $100.0 million, contributions from non-controlling interest of $35.4 million, partially offset by repayments of energy asset debt and financing leases totaling $424.4 million, repayments of long-term corporate debt of $127.0 million, and payments on the seller’s promissory note of $61.9 million.

During 2023, we received net proceeds of $843.5 million from long-term energy asset debt financings, $168.9 million from advances on Federal ESPC projects and energy assets, partially offset by repayments of long-term corporate debt of $155.0 million, repayments of energy asset debt totaling $148.1 million, and net payments on our senior secured revolving credit facility of $43.0 million.

We currently plan additional financings of $300.0 million to $350.0 million in 2025 to fund the construction or acquisition of new renewable energy plants as discussed above.

We may also, from time to time, finance our operations through issuance or offering of equity or debt securities.

Critical Accounting Policies and Estimates

Preparing our consolidated financial statements in accordance with GAAP involves us making estimates and assumptions that affect reported amounts of assets and liabilities, net sales, and expenses, and related disclosures in the accompanying notes at the date of our financial statements. We base our estimates on historical experience, industry and market trends, and on various other assumptions that we believe to be reasonable under the circumstances. However, by their nature, estimates are subject to various assumptions and uncertainties, and changes in circumstances could cause actual results to differ from these estimates, sometimes materially.

We believe that our policies and estimates that require our most significant judgments are considered our critical accounting policies and are discussed below. In addition, refer to Note 2 “Summary of Significant Accounting Policies” for further details.

Revenue Recognition

As described in Note 2, we recognize revenue from the installation or construction of projects over time using the cost-based input method. We use the total costs incurred on the project relative to the total expected costs to satisfy the performance obligation. When the estimate on a contract indicates a loss or claims against costs incurred reduce the likelihood of recoverability of such costs, we record the entire estimated loss in the period the loss becomes known. In addition, some contracts contain an element of variable consideration, including liquidated damages and/or penalties, which requires payment to the customer in the event that construction timelines or milestones are not met. We estimate the total consideration payable by the customer when the contracts contain variable consideration provisions, based on the most likely amount anticipated to be recognized for transferring the

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promised goods or services. As a result, we may constrain revenue to the extent that a significant reversal in the amount of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is subsequently resolved.

To the extent a contract is deemed to have multiple performance obligations, we allocate the transaction price of the contract to each performance obligation using our best estimate of the standalone selling price of each distinct good or service in the contract.

Significant judgement is required to estimate the total expected costs and variable consideration for projects that typically have a construction period of 12 to 36 months. Any increase or decrease in estimated costs to complete a performance obligation without a corresponding change to the contract price could impact the calculation of cumulative revenue to date and gross profit on the project. Similarly, if we recognize revenue based upon our current estimate of variable consideration, and our estimate is later adjusted, we may be required to increase or decrease cumulative revenue to date and gross profit on the project. Factors that may result in a change to our estimates include unforeseen engineering problems, construction delays, the performance of contractors and major material suppliers, and unusual weather conditions, among others.

We have a long history of working with multiple types of projects and preparing cost estimates, and we rely on the expertise of key personnel to prepare what we believe are reasonable best estimates given available facts and circumstances. Due to the nature of the work involved, however, judgment is involved to estimate the costs to complete and the amounts estimated could have a material impact on the revenue we recognize in each accounting period. We cannot estimate unforeseen events and circumstances which may result in actual results being materially different from previous estimates.

Impairment Assessments

We evaluate our long-lived assets, including goodwill and intangible assets, for impairment as events or changes in circumstances indicate the carrying value of these assets may not be fully recoverable, and at least annually (fourth quarter) for goodwill and intangible assets that have indefinite lives. In 2023, we changed the assessment date from December 31st to October 31st. Examples of such triggering events applicable to our assets include a significant decrease in the market price of a long-lived asset or asset group, a current-period operating or cash flow loss combined with a history of operating or cash flow losses, a projection or forecast that demonstrates continuing losses associated with the use of a long-lived asset or asset group, or adverse industry or economic trends.

We evaluate recoverability of long-lived assets and definite-lived intangible assets by estimating the undiscounted future cash flows associated with the expected uses and eventual disposition of those assets. When these comparisons indicate that the carrying value of those assets is greater than the undiscounted cash flows, we recognize an impairment loss for the amount that the carrying value exceeds the fair value.

The process of evaluating the potential impairment of long-lived assets, goodwill and intangible assets requires significant judgment. For goodwill, we estimate the reporting unit’s fair value and compare it with the carrying value of the reporting unit, including goodwill. If the fair value is greater than the carrying value of its reporting unit, no impairment is recorded. Fair value is determined using both an income approach and a market approach. The estimates and assumptions used in our calculations include revenue growth rates, expense growth rates, expected capital expenditures to determine projected cash flows, expected tax rates and an estimated discount rate to determine present value of expected cash flows. These estimates are based on historical experiences, our projections of future operating activity and our weighted-average cost of capital. Unforeseen events and changes in circumstances or market conditions could adversely affect these estimates, which could result in an impairment charge.

We had no goodwill impairments for the year ended December 31, 2024 and reporting units with goodwill had estimated fair values that exceeded their carrying values by at least 49%. During the year ended December 31, 2023, one reporting unit had a fair value that was 2% less than the carrying value and we recorded a $1,644 goodwill impairment, which was $2,222 net of tax and was primarily driven by a decline in projected cash flows, including revenues and profitability. One reporting unit with goodwill had an estimated fair value that exceeded its carrying value by 16%. All other reporting units with goodwill had estimated fair values that exceeded their carrying values by at least 65% as of December 31, 2023.

Derivative Financial Instruments

We account for our interest rate swaps and our make-whole provisions as derivative financial instruments which are carried on our consolidated balance sheets at fair value.

The fair value of our interest rate swaps are determined based on observable market data in combination with expected cash flows for each instrument. Among the key drivers of value are interest rates, since the future floating rates are unknown. The value of our interest rate swaps will change in subsequent periods as counterparty credit risk and forward expectations of the floating rate

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change. Therefore, depending on how the yield curve changes in subsequent measuring periods, a swap can become an asset or a liability for us. In addition, model inputs used in swap analyses can also substantially affect the fair value of the swaps.

Our make-whole provisions fulfill the requirements of embedded derivative instruments that were required to be bifurcated from the host agreement. The fair value of these make-whole provisions are determined based on available market data and a with and without model. There are several assumptions and estimates used in the calculation of the fair value of derivatives, such as discount rate and risk premium.

Any changes in the fair value of our derivatives designated as hedging instruments are recorded as adjustments to other comprehensive (loss) income and any changes in fair value of our derivatives not designated hedging instruments are recorded in interest and other expenses, net in our consolidated statements of income. See Note 19 “Derivative Instruments and Hedging Activities” for more information.

Income Taxes

We are subject to income taxes in the U.S. and six foreign jurisdictions. Significant judgment is required in determining income tax expense, deferred tax assets and liabilities and uncertain tax positions. The underlying assumptions are also highly susceptible to change from period to period. We took advantage of the Safe Harbor commence-construction provisions contained in IRS Notice 2018-59 by pre-purchasing solar equipment in 2019 thereby preserving the ability to take 30% ITC for projects placed in service before 2024. However, the IRA signed by the President on August 16, 2022 increased the ITC rate back to 30% for projects placed in service after January 1, 2022 and before January 1, 2033. If these or other deductions and credits expire without being extended, or otherwise are reduced or eliminated, our effective tax rate would increase, which could increase our income tax expense and reduce our net income. In addition, our tax rate has historically been significantly impacted by the IRC Section 179D deduction. This deduction is related to energy-efficient improvements we provide under government contracts. The Consolidated Appropriations Act, 2021 made permanent the Section 179D Energy Efficient Commercial Building Deduction. That Act made changes to the way the deduction is calculated. If those changes result in lower levels of energy efficiency improvements, it could impact the deduction available and the tax rate. On December 12, 2024, the U.S. Department of the Treasury and IRS issued final regulations regarding ITCs for Section 48 of the Internal Revenue Code, including the ITCs for energy generation, energy storage technology, qualified biogas property, and interconnection property. We are taking additional ITCs on our renewable gas projects consistent with the regulation language permitting separate ownership.

We accrue for the estimated additional tax and interest that may result from tax authorities disputing uncertain tax positions. We believe we have made adequate provisions for income taxes for all years that are subject to audit based upon the latest information available. We operate within multiple taxing jurisdictions and are subject to tax audits in these jurisdictions. These audits can involve complex issues and may require an extended period of time to resolve. We recognize tax benefits from uncertain tax positions only if we believe that it is more likely than not that the tax position will be sustained on examination by the taxing authorities based on the technical merits of the position. Although we believe that we have adequately reserved for our uncertain tax positions, we can provide no assurance that the final tax outcome of these matters will not be materially different. We adjust these reserves when facts and circumstances change, such as the closing of a tax audit or the refinement of an estimate. To the extent that the final tax outcome of these matters is different than the amounts recorded, such differences may affect the provision for income taxes in the period in which such determination is made and could have an impact on our results of operations.

On a quarterly basis, we assess our current and projected earnings by jurisdiction to determine whether or not our earnings during the periods when the temporary differences become deductible will be sufficient to realize the related future tax benefits. Should we determine that we would not be able to realize all or part of our net deferred tax asset in a particular jurisdiction in the future, a valuation allowance to the deferred tax asset would be charged to income in the period such determination was made. This valuation allowance is maintained for deferred tax assets that we estimate are more likely than not to be unrealizable based on available evidence at the time the estimate is made. The determination of whether a valuation allowance for deferred tax assets is appropriate is subject to considerable judgment and requires an evaluation of all positive and negative evidence, including our historical financial results, the source and consistency of those results, whether they should be adjusted for certain one-time or nonrecurring items, whether losses cumulatively exceed income over a reasonable period of time, the availability of tax planning strategies, availability of carryback and carryforward periods, and other factors, including our expectations of future taxable income. Adjustments to income tax expense to the extent we establish a valuation allowance or adjust this allowance in a period could have a material impact on our financial condition and results of operations.

Recent Accounting Pronouncements

See Note 2 of the “Notes to Consolidated Financial Statements” for a discussion of recent accounting standards.

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