Interest Rate Exposure Risk Cash is invested overnight with high credit quality financial institutions and therefore we are not exposed to market risk on our cash holdings from changing interest rates. Based on our overall interest rate exposure as of April 30, 2026, including all interest rate sensitive instruments, a change in interest rates of 1% would not have a material impact on our results of operations. Foreign Currency Exchange Risk As of April 30, 2026, approximately 1% of our total cash and cash equivalents were in currencies other than U.S. dollars (primarily the Euro, Canadian dollar and Korean Won) and we have no plans of repatriation. We make purchases from certain vendors and receive payment from certain customers in currencies other than U.S. dollars. Although we have not experienced significant foreign exchange rate losses to date, we may in the future, especially to the extent that we do not engage in currency hedging activities. The economic impact of currency exchange rate movements on our operating results is complex because such changes are often linked to variability in real growth, inflation, interest rates, governmental actions and other factors. These changes, if material, may cause us to adjust our financing and operating strategies. Derivative Fair Value Exposure Risk Interest Rate Swap On May 19, 2023, in connection with the closing of the OpCo Financing Facility, the Company entered into an ISDA 2002 Master Agreement and an ISDA Schedule to the 2002 Master Agreement with Investec Bank plc as a hedge provider, and an ISDA 2002 Master Agreement and an ISDA Schedule to the 2002 Master Agreement with Bank of Montreal (Chicago Branch) as a hedge provider. On May 22, 2023, OpCo Borrower executed the related trade confirmations for these interest rate swap agreements with these hedge providers to protect against adverse price movements in the floating SOFR rate associated with 100% of the aggregate principal balance of the Term Loan outstanding. Pursuant to the terms of such agreements, OpCo Borrower will pay a fixed rate of interest of 3.716%. The net interest rate across the Financing Agreement and the swap transaction is 6.366% in the first four years and 6.866% thereafter. The obligations of OpCo Borrower to the hedge providers under the interest rate swap agreements are treated as obligations under the Financing Agreement and, accordingly, are secured, on a pari passu basis, by the same collateral securing the obligations of OpCo Borrower under the Financing Agreement. The Company has not elected hedge accounting treatment and, as a result, the 58 Table of Contents derivative will be remeasured to fair value quarterly with the resulting gains/losses recorded to other income/expense. The fair value adjustments for the three and six months ended April 30, 2026 resulted in gains of $0.3 million and $0.7 million, respectively. The fair value adjustments for the three and six months ended April 30, 2025 resulted in losses of $1.6 million and $0.8 million, respectively. ​ Project Fuel Price Exposure Risk Certain of our PPAs for project assets in our generation portfolio expose us to fluctuating fuel price risks as well as the risk of being unable to procure the required amounts of fuel and the lack of alternative available fuel sources. We seek to mitigate our fuel risk using strategies including: (i) fuel cost reimbursement mechanisms in our PPAs to allow for pass through of fuel costs (full or partial) where possible, which we have done with our 14.9 MW operating project in Bridgeport, CT; (ii) procuring fuel under fixed price physical supply contracts with investment grade counterparties, which we have done for twenty years for our Tulare BioMAT project, the initial seven years of the twenty year PPA for our LIPA Yaphank Project (through September 2028), six years of the twenty year PPA for our 14.0 MW and 2.8 MW Derby Projects (through October 2029), and the initial four years of the twenty year hydrogen production and power purchase agreement for our Toyota project (through May 2027); and (iii) potentially entering into future financial hedges with investment grade counterparties to offset potential negative market fluctuations. The Company does not take a fundamental view on natural gas or other commodity pricing and seeks commercially available means to reduce commodity exposure. If the Company is unable to secure fuel on favorable economic terms, it may result in impairment charges. We currently have four projects with fuel sourcing risk, which are the Toyota Project, our 14.0 MW and 2.8 MW Derby Projects and our 7.4 MW LIPA Yaphank Project, all of which require natural gas for which there is no pass-through mechanism. A fuel supply contract has been executed for the Toyota project through May 2027. Six-year (through October 2029) fuel supply contracts have been executed for the 14.0 MW and 2.8 MW Derby Projects. We are currently in the midst of a seven-year contract (through September 2028) for our 7.4 MW LIPA Yaphank Project. The Company will look to extend the duration of these contracts should market and credit conditions allow. If the Company is unable to secure fuel on favorable economic terms, it may result in impairment charges to the Derby Project assets or the LIPA Yaphank Project asset and further impairment charges for the Toyota Project asset. Historically, this risk has not been material to our financial statements as our operating projects prior to April 30, 2026 either did not have fuel price risk exposure, had fuel cost reimbursement mechanisms in our related PPAs to allow for pass through of fuel costs (full or partial), or had established long term fixed price physical supply contracts. To provide a meaningful assessment of the fuel price risk arising from price movements of natural gas, the Company performed a sensitivity analysis to determine the impact a change in natural gas commodity pricing would have on our Consolidated Statements of Operations and Comprehensive Loss (assuming that all projects with fuel price risk were operating). A $1/Metric Million British Thermal Unit (“MMBTu”) increase in market pricing compared to our underlying project models would result in a cost impact of approximately $26,000 to our Consolidated Statements of Operations and Comprehensive Loss on an annual basis. We have also conducted a sensitivity analysis on the impact of renewable natural gas pricing and a $10/MMBTu increase in market pricing compared to our underlying project models would result in an impact of approximately $2.0 million to our Consolidated Statements of Operations and Comprehensive Loss on an annual basis. The Company net settled certain natural gas purchases under previous normal purchase normal sale contract designations during the fiscal year ended October 31, 2023 for one contract and the second quarter of fiscal year 2024 for other contracts, and recorded mark-to-market net losses of $4.8 million and $1.2 million during the three and six months ended April 30, 2026, respectively. The Company recorded a mark-to-market net loss of $0.8 million and a mark-to-market net gain of $1.1 million during the three and six months ended April 30, 2025, respectively.