N-1Application - Redacted
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17 Figure 1: Summary of Securitized Costs ($ million) Securitized Costs Eligible Costs Thermal Assets¹ $ 713.0 Thermal Assets Financing Cost Deferral² 27.6 PHP Deferral² 12.2 IESO Deferral² 20.2 Fuel and Purchased Power – Q3 2026 FAM Asset...
AI summary The text presents a summary of securitized costs, including thermal assets, financing cost deferrals, and other eligible costs totaling $987.5 million, with additional financing fees bringing the total securitization bond proceeds to $1,000.0 million. NS Power will reclassify the thermal asset balance to the Securitization Regulatory Asset.
NS Power Application for Financing Order to Reduce Costs for Customers Redacted - 1 ² NS Power will reduce the existing regulatory asset balance and reclassify this balance to the Securitization 2 Regulatory Asset. - 3 ³ NS Power is seekin...
AI summary NS Power is requesting approval from the NSEB to reclassify existing regulatory assets and record Upfront Financing Costs as a Regulatory Asset to align with the recovery of these costs through the Securitization Rider. The proposed Securitized Bonds amount to $1 billion, exceeding forecasted Securitized Costs of $987.5 million.
22 2.1 Thermal Assets - 24 NS Power seeks to securitize $740.6 million, consisting of the unrecovered net book value of - 25 thermal generation assets within the scope of the DDA as at December 31, 2025, together with - 26 deferred financi...
AI summary NS Power is seeking to securitize $740.6 million, which includes the unrecovered net book value of thermal generation assets as of December 31, 2025, and deferred financing costs from May 1, 2026, to November 30, 2026, calculated at a 6.59% WACC. This approach aligns with the 2026-2027 GRA and excludes costs already recovered through customer rates to avoid duplication.
22 11.6 Priority of Payments - 24 Securitized Surcharge collections remitted to the LP or the indenture trustee are expected to be - 25 applied generally in the following order of priority, subject to the terms of the definitive transactio...
AI summary This section outlines the priority of payments for Securitized Surcharge collections, specifying that funds are applied in a defined order: Ongoing Financing Costs, interest on Securitized Bonds, principal on Securitized Bonds, replenishment of reserve accounts, and finally the release of any surplus.
REDACTED 2026 Securitization Rider Application Appendix C Attachment 2 Page 8 of 8 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Annual Peak of ATL Annual Energy Requirement of ATL 2,481,214 21,735,437,100 20,325,436,463 20,325,436,463 94% S...
AI summary The document presents detailed financial and operational data related to the 2026 Securitization Rider Application, including rate base calculations, plant costs, and generation-related assets. It includes tables with figures for various plants and their associated costs, as well as classifications for rate base components.
DEMAND CHARGE per month per kilovolt ampere of maximum demand Effective upon the date of the Board's Order $10.710 Effective January 1, 2027 $11.269 32 cents per kilovolt ampere reduction in demand charge where the transformer is owned by...
AI summary The document outlines the demand charge rates effective upon the Board's Order and on January 1, 2027, as well as a reduction in demand charge for customers owning the transformer.
11.1 Application of Distribution Tariff Rates The Distribution Tariff amounts payable by the RtR Customer will be calculated by NS Power using the RtR Customer's meter readings and the Distribution Tariff Rate Schedule applicable to the Rt...
AI summary The Distribution Tariff amounts payable by the RtR Customer are calculated based on meter readings and applicable rate schedules. If the customer's operational or consumption characteristics change, NS Power will adjust the applied tariff rate accordingly.
11.3 Real Power Losses Distribution System Real Power Losses associated with Distribution System Access are incorporated in the Distribution Tariff rates applicable to each RtR Customer's rate class. The RtR Customer is responsible for the...
AI summary Real power losses in the distribution system are factored into the distribution tariff rates for each rate-to-rate (RtR) customer's rate class, and the responsibility for these costs falls on the RtR customer.
As follows, per kilovolt ampere of maximum demand of the current month or the maximum actual demand of the previous December, January, or February occurring in the previous eleven (11) months. per month Effective upon the date of the Board...
AI summary The text outlines a distribution cost adder, specifying rates per kilovolt ampere of maximum demand for different periods. The rates are set at $9.268 effective upon the date of the Board's Order and $10.006 effective January 1, 2027.
8. RTR CUSTOMER RESPONSIBILITIES The RtR Customer shall be responsible for: - (a) payment of all fees and charges arising in connection with the Distribution Tariff; - (b) compliance with the terms and conditions of the Distribution Tariff...
AI summary The RtR Customer is responsible for paying fees related to the Distribution Tariff, complying with its terms, obtaining renewable low-impact electricity from an LRS, and managing contractual arrangements with the LRS.
Effective November 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-73-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in all...
AI summary The document outlines the implementation of the Interim Energy Charge effective November 1, 2025, following the NSEB's decision on NS Power's 2025/26 Time-varying Pricing (TVP) Tariffs (M12499). It specifies billing procedures for Small General Time of Use Tariff customers and outlines conditions for restoring TVP rates once system functionality is restored.
8. RTR CUSTOMER RESPONSIBILITIES The RtR Customer shall be responsible for: - (a) payment of all fees and charges arising in connection with the Distribution Tariff; - (b) compliance with the terms and conditions of the Distribution Tariff...
AI summary The RtR Customer is responsible for paying fees related to the Distribution Tariff, complying with its terms and conditions, obtaining renewable low-impact electricity from an LRS, and managing contractual arrangements with the LRS.
N-3Transcript of Technical Conference held October 15, 2026
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ery - tight timelines that the Board's working under here. - INTERNATIONAL REPORTING INC. CERTIFIED COURT REPORTERS MS. RUBIN: We can send it - immediately. - MR. WILLIAMS: Okay. Any other - questions on what was intended to be the intro?...
AI summary The discussion focuses on the securitization of costs, including thermal assets and PHP deferral, as part of a bond transaction. The timeline for the financing transaction is highlighted, with deferred financing costs considered from May to November 2025. This is related to the General Rate Application and the GRA decision.
eral Rate Application. - Folks who have seen our decarbonization deferral account, - or DDA, annual report may recognize the balances totaling - the total unrecovered net book value of 713 as being - consistent with that report. - So these...
AI summary The text discusses the decarbonization deferral account (DDA) and its net book value as of December 31, 2025, which includes unrecovered costs from various assets. It also mentions the inclusion of the PHP deferral in the proposed transaction to support future fixed costs for customers.
e of the volatility in those bond - markets and we would be looking to lock in the lowest - yield possible. And we're aware of the fact that, to the - extent that time drags on, yields could go up. - And so we will not be wasting any - INT...
AI summary The discussion revolves around the potential rate increase in 2027, with a focus on fuel costs and the Financial Accountability Mechanism (FAM). The conversation highlights concerns about the impact of delayed decisions on bond yields and customer costs, as well as the need to lock in low rates quickly.
t interest to the benefit of customers on the - FAM. - MR. ROSCOE: That's helpful, Craig. - MR. MacDOUGALL: With respect to the - over or under-recovery and the additional FAM prepayments, - do they then they don't go into the FAM in the f...
AI summary The discussion centers on the Financial Accountability Mechanism (FAM) and its implications for Nova Scotia Power's rate base and customer benefits. It touches on the allocation of over-recovery funds to the FAM and the impact on equity returns and customer savings.
in the LP. - So the LP's got back income no offsetting deduction, if - that makes sense. - MS. McNAMARA: So would the tax - expense in the LP be offset by a deduction in Nova Scotia - Power? - MR. FERGUSON: That's right. Like not - perfect...
AI summary The discussion revolves around the tax implications of transferring assets to a limited partnership (LP) and how this affects Nova Scotia Power's credit metrics. The transfer removes the equity component of financing, reducing taxable income and allowing Nova Scotia Power to reduce debt and equity in line with its capital structure.
uld then use that money to pay bondholders. - The other pieces of the cashflow here - INTERNATIONAL REPORTING INC. CERTIFIED COURT REPORTERS relate to the intercompany loan, and so Nova Scotia Power - would pay interest to the limited part...
AI summary The discussion centers on the securitization process, focusing on the allocation of financing and ongoing costs to different components, and the treatment of revenue requirements for thermal assets using existing methodologies, including the 2027 total system coincident load factor and the 3 CP methodology for cost allocation.
2026. So this would be very - consistent and familiar to most on the call from normal - AA/BA applications. Attachment 1 to that appendix would - include the FAM calculation model. Attachment 2 and - Attachment 3 would be the calculations...
AI summary The document discusses the treatment of the FAM balance, including the calculation model and credit application to customer classes, as well as the deferral treatment of the PHP, which impacts revenue and cost responsibility in generation and transmission functions. Cost allocation methods, such as the 3CP and annual energy requirements, are also outlined.
ts for 2027 for each class is used to - allocate the various costs to customer classes. - For the transmission related portion - that's 100 percent demand and would utilize the 3 CP - methodology. - And the last component is the IESO - Nov...
AI summary The document discusses the allocation of costs to customer classes using the 3CP methodology and the IESO's approach for revenue requirement distribution. It also outlines rate impacts, including a 3.3% increase in 2027 for FAM classes and separate treatment of OATT Munis.