Topic:"Rate Design" in M13133

NS Power Application for Financing Order to Reduce Costs for Customers Redacted - 1 As detailed within this Application, the proposed securitization satisfies the requirements of the - 2 Securitization Regulations and will provide substant...

AI summary NS Power is requesting a Financing Order from the Board to authorize the securitization of Securitized Costs and Financing Costs, which is expected to reduce customer costs, facilitate the retirement of thermal generation assets, and moderate rate impacts over the recovery period.

5 6.4 IESO-NS Deferral 6 - 7 The total 2027 revenue requirement associated with the securitization of the IESO-NS Deferral is - 8 allocated to customer classes based on each class's forecast 2027 share of sales. This methodology - 9 is con...

AI summary The text discusses the allocation of the 2027 revenue requirement from the securitization of the IESO-NS Deferral to customer classes based on their forecasted share of sales. It references Appendix H for detailed allocation information.

1 8.0 RATE IMPACT 2 - 3 The four securitization components have an estimated total revenue requirement of approximately - 4 $67.2 million in 2027. Recovery of the portion allocated to the FAM customer classes, totaling - 5 approximately $6...

AI summary The estimated total revenue requirement for the four securitization components is approximately $67.2 million in 2027, with an average rate increase of 3.3 percent for FAM customer classes. Appendix E provides detailed impacts on class revenues for each component.

5 Year 3 and Subsequent Years - 6 The BA will consist of: - 7 o BA1 , which reconciles the over-collection or under-collection of Securitized 8 Surcharges from Year 2; and - 9 o BA2 , which reconciles the over-collection or under-collectio...

AI summary The Balancing Adjustment (BA) for Year 3 and subsequent years includes BA1, which reconciles over-collection or under-collection of Securitized Surcharges from Year 2, and BA2, which reconciles over-collection or under-collection related to the collection or refund of Year 1's BA1 amount.

NS Power Application for Financing Order to Reduce Costs for Customers Redacted - any difference between estimated Ongoing Financing Costs financed by Securitized Bonds and the actual Ongoing Financing Costs incurred by the Company or an A...

AI summary The document outlines the calculation of Balancing Adjustments (BA) and BA riders in relation to Securitized Surcharges and Financing Orders, including formulas for determining BA(t), BA1(t), BA2(t), and the BA rider based on forecast sales and reconciliation amounts.

14 11.5 Servicer and Successor Servicer 15 - 16 NS Power will serve as the initial servicer, responsible for billing, collecting, and remitting the - 17 Securitized Surcharge, filing true-up adjustments, and performing other administrative...

AI summary NS Power is designated as the initial servicer for the Securitized Surcharge, with responsibilities including billing, collection, and administrative duties. A successor servicer may be appointed if NS Power is unable or unwilling to continue, to ensure uninterrupted collection for bondholders.

10 11.7 Flexibility in Bond Terms 11 - 12 Pursuant to section 3(3)(g) of the Securitization Regulations, NS Power requests flexibility be - 13 afforded to it in establishing the terms and conditions of the Securitized Bonds, including but...

AI summary NS Power is requesting flexibility in bond terms under the Securitization Regulations, allowing for adjustments in repayment schedules, interest rates, and financing costs, provided the transaction remains aligned with prevailing interest rates and delivers quantifiable net present value benefits to customers.

1 13.0 IMPACT ON THE DECARBONIZATION DEFERRAL ACCOUNT (DDA) 2 3 As described in Section 2.1, the proposed securitization applies to $740.6 million of unrecovered 4 net book value and deferred financing costs associated with thermal generat...

AI summary The document discusses the impact of securitization on the Decarbonization Deferral Account (DDA), noting that it would reduce the DDA balance significantly but still require recovery of decommissioning and sustaining capital costs. NS Power argues the DDA remains important for transparent and cost-effective recovery of thermal generation asset retirement costs.

NS Power Application for Financing Order to Reduce Costs for Customers Redacted Financing Order Requirements Under Section 5(1) Application Reference (b) A description and estimate of the amount and categories of Financing Costs that may b...

AI summary NS Power has applied for a Financing Order to reduce customer costs, proposing the issuance of Securitized Bonds and the imposition of Securitized Surcharges. The application outlines requirements for cost recovery, justification for the order, and mechanisms for adjusting surcharges to ensure fair and reasonable recovery of financing costs.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the Domestic Service Tariff.

AI summary This optional tariff aims to encourage customers to shift their load from peak to off-peak periods and is available to those eligible under the Domestic Service Tariff.

Effective December 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-84-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in all...

AI summary Starting December 1, 2025, NS Power will implement an Interim Energy Charge under the Board's decision on the 2025/26 Time-varying Pricing (TVP) Tariffs (M12499). The charge will apply during all hours and be equivalent to standard offer rates. Critical Peak Events will not be scheduled during this period, and NS Power must notify customers when system functionality is restored.

DOMESTIC SERVICE CRITICAL PEAK PRICING TARIFF Page 2 of 4 Rate Code 70

AI summary This document outlines the Domestic Service Critical Peak Pricing Tariff, specifically Rate Code 70, which is part of a pricing structure designed to manage electricity demand during peak periods.

ENERGY CHARGE cents per kilowatt-hour During a Critical Non-critical Peak Event Peak Hours Effective November 1, 2026 182.067 15.411 Effective January 1, 2027 191.990 15.956 The Critical Peak Event is of a four-hour duration and can be cal...

AI summary The document outlines the energy charge rates for Critical Peak and Non-critical Peak hours, effective November 1, 2026, and January 1, 2027. Critical Peak Events are four hours long and can occur between 6:00 AM and 11:00 PM during the winter period.

The Critical Peak Event pricing applies when a Critical Peak Event is called. In all other hours in the Winter Period, and for all hours in the Non-Winter Period, the rate shall be the Non-critical Peak Hours rate in the table above.

AI summary The document outlines the application of Critical Peak Event pricing during designated events and specifies that the Non-critical Peak Hours rate applies during other times in the Winter and Non-Winter Periods.

CRITICAL PEAK EVENT PROCEDURE - (1) In the Winter Period, Critical Peak Events exclude all hours on the following holidays: January 1, Nova Scotia Heritage Day, Good Friday, Easter Monday, November 11, December 25 and December 26. If Janua...

AI summary The Critical Peak Event Procedure outlines how Critical Peak Events are scheduled and managed during the Winter Period, excluding certain holidays. Events are scheduled by NSPI based on conditions like high energy usage or outages, and customers are notified in advance with a higher energy charge during these periods.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the Domestic Service Tariff.

AI summary This optional tariff aims to encourage customers to shift their electricity usage from peak to off-peak periods. It is available to customers eligible for service under the Domestic Service Tariff.

Effective November 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-88-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in all...

AI summary Effective November 1, 2025, NS Power will implement an interim energy charge following the NSEB's decision on their 2025/26 TVP tariffs. The interim charge applies until system functionality is restored, with specific notification and rate restoration procedures depending on the restoration timeline.

DOMESTIC SERVICE TIME OF USE TARIFF Rate Code 80

AI summary The document introduces a Domestic Service Time of Use Tariff, identified by Rate Code 80, which likely involves varying electricity rates based on usage times.

Page 2 of 4 cents per kilowatt-hour Interim Energy Charge On-peak On-peak Off-peak (Winter Period) (morning) Off-peak (evening) November 1 through March 31 7:00 AM to 11:00 AM to 5:00 PM to 9:00 PM to 11:00 AM 5:00 PM 9:00 PM 7:00 AM Effec...

AI summary The document outlines the interim energy charge rates for different periods and times of day, including on-peak and off-peak rates during winter and non-winter periods. The rates are effective from November 1, 2025, and April 1, 2027, with specific details on when off-peak pricing applies, including weekends and holidays.

2026 Securitization Rider Application Appendix G-1 (Redline) Page 13 of 86 REDACTED (CONFIDENTIAL INFORMATION REMOVED) DOMESTIC SERVICE TIME-OF-DAY TARIFF (OPTIONAL) Page 3 of 3 Rate Codes 05, 06 If the building is used principally for the...

AI summary This section outlines the application of the Domestic Service Time-of-Day Tariff for buildings used primarily for personal purposes, with alternative tariffs for commercial use. Rate Codes 05 and 06 are specified for this purpose.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the Small General Tariff.

AI summary This optional tariff aims to encourage customers to shift their electricity usage from peak to off-peak periods. It is available to customers eligible for service under the Small General Tariff.

Effective December 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-97-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in all...

AI summary Effective December 1, 2025, the Nova Scotia Energy Board's decision on NS Power's application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499) outlines the implementation of an Interim Energy Charge, the suspension of Critical Peak Events, and the conditions for restoring Critical Peak Pricing rates once system functionality is restored.

SMALL GENERAL CRITICAL PEAK PRICING TARIFF Page 2 of 4 Rate Code 72

AI summary This document page introduces Rate Code 72, which is associated with the Critical Peak Pricing Tariff. It is part of a small general tariff structure and is likely related to time-varying pricing mechanisms.

2026 Securitization Rider Application Appendix G-1 (Redline) Page 19 of 86 REDACTED (CONFIDENTIAL INFORMATION REMOVED) SMALL GENERAL CRITICAL PEAK PRICING TARIFF Page 4 of 4 Rate Code 72 - (c) The customer must be on electronic billing and...

AI summary This section outlines eligibility criteria for the Critical Peak Pricing Tariff, requiring customers to be on electronic billing, have a MyAccount profile, and not be enrolled in seasonal or net metering services. NSPI may also limit participation or temporarily close enrollment.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the Small General Tariff.

AI summary This optional tariff aims to encourage customers to shift their energy usage from peak to off-peak periods. It is available to customers eligible for service under the Small General Tariff.

Effective November 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-101-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in al...

AI summary The document outlines the effective changes to Time-varying Pricing (TVP) Tariffs starting November 1, 2025, as per the Nova Scotia Energy Board's decision. It specifies the Interim Energy Charge, billing procedures for Small General Time of Use Tariff customers, and the conditions for restoring TVP rates once system functionality is restored.

DEMAND CHARGE per month per kilowatt of maximum demand Effective upon the date of the Board's Order $9.809 Effective January 1, 2027 $10.697 32 cents per kilowatt reduction in demand charge where the transformer was owned by the customer p...

AI summary The document outlines the demand charge rates effective from the date of the Board's Order and January 1, 2027, along with a reduction credit for customers with transformers owned prior to 1974 or under a specific special condition.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the General Tariff.

AI summary This optional tariff aims to encourage customers to shift their load from peak to off-peak periods. It is available to customers eligible for service under the General Tariff.

INTERIM ENERGY CHARGE Effective December 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-107-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energ...

AI summary An interim energy charge is implemented effective December 1, 2025, following the NSEB's decision on NS Power's TVP tariff application. The charge applies during all hours and is set to standard offer rates while system functionality is unavailable. Critical Peak Events are not scheduled during this period, and NS Power must notify customers when functionality is restored.

2026 Securitization Rider Application Appendix G-1 (Redline) Page 28 of 86 REDACTED (CONFIDENTIAL INFORMATION REMOVED) GENERAL CRITICAL PEAK PRICING TARIFF Page 3 of 4 Rate Code 73 - (5) No more than 18 Critical Peak Events may be schedule...

AI summary The document outlines the rules for Critical Peak Events under the Critical Peak Pricing Tariff. It specifies that no more than 18 events can occur per winter season, with a limit of three per week and three on weekends. Customers are required to be notified in advance and update their contact information with NSPI if it changes.

GENERAL CRITICAL PEAK PRICING TARIFF Page 4 of 4

AI summary This document outlines the General Critical Peak Pricing Tariff, specifically Page 4 of 4, which likely contains details about the tariff structure, pricing during peak periods, and related regulatory considerations.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the General Tariff.

AI summary This optional tariff aims to encourage customers to shift their energy usage from peak to off-peak periods. It is available to customers who are eligible for service under the General Tariff.

DEMAND CHARGE per month per kilowatt of maximum demand Effective upon the date of the Board's Order $9.809 Effective January 1, 2027 $10.697 32 cents per kilowatt reduction in demand charge where the transformer was owned by the customer p...

AI summary The document outlines the demand charge rates effective from the date of the Board's Order and January 1, 2027, along with a reduction credit for customers with transformers owned prior to 1974 or under a specific special condition.

2026 Securitization Rider Application Appendix G-1 (Redline) Page 33 of 86 REDACTED (CONFIDENTIAL INFORMATION REMOVED) GENERAL TIME OF USE TARIFF Page 4 of 4 Rate Code 83 (2) When the customer requires non-standard service provisions, the...

AI summary The document outlines general rules for time-of-use tariffs, including provisions for non-standard service requirements and ensuring customer load does not negatively impact the power supply system. It also mentions specific rate codes and considerations for multi-unit residential buildings.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the General Tariff.

AI summary This optional tariff aims to encourage customers to shift their energy usage from peak to off-peak periods. It is available to customers eligible for service under the General Tariff.

2026 Securitization Rider Application Appendix G-1 (Redline) Page 36 of 86 REDACTED (CONFIDENTIAL INFORMATION REMOVED) MULTI-UNIT RESIDENTIAL BUILDINGS TIME OF USE TARIFF Page 3 of 3 Rate Code 89 metering as opposed to the cost of secondar...

AI summary The text outlines provisions related to metering and service requirements for multi-unit residential buildings under a time-of-use tariff. It addresses adjustments to metered kWh usage, customer responsibilities for transformers, and considerations for maintaining power supply integrity.

DEMAND CHARGE As follows, per month 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.

AI summary The demand charge is calculated monthly based on the maximum demand of the current month or the highest actual demand recorded in the previous December, January, or February within the prior eleven months.

2026 Securitization Rider Application Appendix G-1 (Redline) Page 38 of 86 REDACTED (CONFIDENTIAL INFORMATION REMOVED) LARGE GENERAL TARIFF Page 2 of 2 (2,000 kVA or 1,800 kW and over) Rate Code 12 Securitization Cost Recovery charges or c...

AI summary The document outlines the application of Securitization Cost Recovery charges or credits in cents per kilowatt-hour for the 2026 rate year, as part of the Securitization Rider, which applies in addition to the energy charge for large general tariff customers.

SPECIAL CONDITIONS - (1) Metering will normally be at the low voltage side of the bulk power transformer. Should the customer's requirements make it necessary for the Company to provide primary metering, then the customer will be required...

AI summary Special conditions outline requirements for metering, billing demand thresholds, and the possibility of separate service agreements. Customers may need to contribute to capital costs for primary metering, and the company may withdraw tariff availability if billing demand thresholds are not met.

2026 Securitization Rider Application Appendix G-1 (Redline) Page 40 of 86 REDACTED (CONFIDENTIAL INFORMATION REMOVED) SMALL INDUSTRIAL TARIFF Page 2 of 2 (up to 249 kVA or 224 kW) Rate Code 21 Securitization Cost Recovery charges or credi...

AI summary This section of the 2026 Securitization Rider Application discusses the application of Securitization Cost Recovery charges or credits to the Small Industrial Tariff (Rate Code 21), which are applied in addition to the energy charge for customers with up to 249 kVA or 224 kW.

2026 Securitization Rider Application Appendix G-1 (Redline) Page 45 of 86 REDACTED (CONFIDENTIAL INFORMATION REMOVED) LARGE INDUSTRIAL TARIFF Page 3 of 6 (2,000 kVA or 1,800 kW and over) Rate Code 23 - (2) Metering will normally be at the...

AI summary This section outlines the conditions for the Large Industrial Tariff, including metering requirements, minimum load demands, service agreements, and power supply integrity considerations for customers with high electrical loads.

INTERRUPTIBLE RIDER TO THE LARGE INDUSTRIAL TARIFF (RATE CODE 25) Customers who qualify for interruptible service will receive a per month per kilovolt ampere reduction in demand charge for billed interruptible demand, as shown in the tabl...

AI summary The interruptible rider to the Large Industrial Tariff (Rate Code 25) provides a monthly demand charge reduction based on billed interruptible demand, defined as the difference between contracted firm demand and billing demand. Credits apply only when billing demand is less than contracted firm demand, with specific rules for calculating billed interruptible demand.

2026 Securitization Rider Application Appendix G-1 (Redline) Page 47 of 86 REDACTED (CONFIDENTIAL INFORMATION REMOVED) LARGE INDUSTRIAL TARIFF Page 5 of 6 (2,000 kVA or 1,800 kW and over) Rate Code 23 (4) Failure to comply in whole or in p...

AI summary The document outlines the penalty charges for non-compliance with load interruption requirements under the Large Industrial Tariff. It specifies a Threshold Penalty and a Performance Penalty, with the latter calculated using a formula based on residual demand and average demand during the interruption event. The text also details procedures for converting between interruptible and firm service rates.

2026 Securitization Rider Application Appendix G-1 (Redline) Page 48 of 86 REDACTED (CONFIDENTIAL INFORMATION REMOVED) LARGE INDUSTRIAL TARIFF Page 6 of 6 (2,000 kVA or 1,800 kW and over) Rate Code 23 - (2) The customer will make all neces...

AI summary The document outlines requirements for large industrial customers on a specific tariff, emphasizing their responsibility to maintain power supply integrity. It mentions considerations like reliability, harmonic levels, and voltage flicker, and discusses meter reading adjustments based on voltage transformation.

DEMAND CHARGE As follows, per month per kilovolt ampere of the higher of: - (a) maximum actual demand of the current month; or - (b) the maximum actual demand of the previous December, January, or February occurring in the previous eleven...

AI summary The demand charge is calculated based on the higher of the current month's maximum actual demand or the highest demand from the previous December, January, or February within the last 11 months, excluding demand peaks during the first two hours after an outage restoration. Customers are expected to manage demand peaks after outages.

625 72 24 13.51 14.33 626 100 33 15.23 16.16 627 200 67 21.76 23.09 per month ($) kWh per Rate Code Watts month 2026 2027 Other 724 55 18 9.82 10.50 740 190 63 26.01 27.45 741 261 87 32.19 33.96 742 124 41 19.19 20.29 743 84 28 16.08 17.01...

AI summary The text presents a table with rate codes, watts, and associated costs for different lighting rates in 2026 and 2027. It includes various rate codes and corresponding monthly charges and energy consumption values.

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.

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.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the Domestic Service Tariff.

AI summary This optional tariff aims to encourage customers to shift their energy usage from peak to off-peak periods. It is available to customers eligible for service under the Domestic Service Tariff.

Effective December 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-170-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in al...

AI summary Effective December 1, 2025, the Nova Scotia Energy Board's decision on NS Power's 2025/26 Time-varying Pricing (TVP) Tariffs (M12499) introduces an Interim Energy Charge during periods of system unavailability. Critical Peak Events are suspended during this period, and specific notification and rate restoration procedures apply depending on when system functionality is restored.

cents per kilowatt-hour Interim Energy Charge During a Critical Peak Event Non-critical Peak Hours Effective upon the date of the Board's Order n/a 18.324 1 M12499 – Board Decision, 325286, page 5. October 28, 2025. DOMESTIC SERVICE CRITIC...

AI summary This document outlines the interim energy charge rates for domestic service critical peak pricing tariff, specifying a rate of 18.324 cents per kilowatt-hour during non-critical peak hours, effective upon the date of the Board's Order.

DOMESTIC SERVICE CRITICAL PEAK PRICING TARIFF Page 4 of 4 Rate Code 70 - (d) NSPI may limit the number of customers who may subscribe to this tariff at a time, and/or close enrollment for any period of time. - (e) The customer cannot be ta...

AI summary The document outlines restrictions for the Domestic Service Critical Peak Pricing Tariff, including limitations on customer enrollment, incompatibility with seasonal service, and exclusion of Net Metering service under specific regulations.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the Domestic Service Tariff.

AI summary This optional tariff aims to encourage customers to shift their energy usage from peak to off-peak periods. It is available to customers eligible for service under the Domestic Service Tariff.

Effective November 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-174-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in al...

AI summary Effective November 1, 2025, the Interim Energy Charge applies to all hours during winter and non-winter periods and aligns with standard offer rates. NS Power must notify TVP customers when system functionality is restored, with specific timelines for resuming on-peak and offpeak rates depending on the restoration date.

DOMESTIC SERVICE TIME-OF-DAY TARIFF (OPTIONAL) Page 3 of 3 Rate Codes 05, 06 If the building is used principally for the owner's personal pursuits and hobbies, the Domestic tariff shall be applied. If the building is used principally for c...

AI summary The document outlines the application of the Domestic tariff for buildings used primarily for personal pursuits and hobbies, and specifies that General or Industrial tariffs apply for commercial use.

Effective December 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-183-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in al...

AI summary Effective December 1, 2025, the Interim Energy Charge will apply during all hours in both winter and non-winter periods, aligning with standard offer rates. No Critical Peak Events will be scheduled during this period. NS Power will notify customers when system functionality is restored and will adjust rates accordingly based on the restoration date.

SMALL GENERAL CRITICAL PEAK PRICING TARIFF Page 3 of 4 Rate Code 72 (6) Customers will be notified of a Critical Peak Event in advance. By 4:00 pm the day prior to the event, the Customer will receive a notification message. The Customer i...

AI summary The document outlines the notification procedure for Critical Peak Events under the Small General Critical Peak Pricing Tariff. Customers must be notified by 4:00 pm the day before an event, and they are responsible for ensuring their contact information is up to date with NSPI.

SMALL GENERAL CRITICAL PEAK PRICING TARIFF Page 4 of 4 Rate Code 72 - (c) The customer must be on electronic billing and have a MyAccount profile. - (d) NSPI may limit the number of customers who may subscribe to this tariff at a time, and...

AI summary The Critical Peak Pricing Tariff Rate Code 72 outlines eligibility criteria for customers, including requirements for electronic billing, MyAccount profile, limitations on enrollment, and ineligibility for seasonal and net metering services.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the Small General Tariff.

AI summary This optional tariff aims to encourage customers to shift their load from peak to off-peak periods. It is available to those eligible under the Small General Tariff.

- (a) The customer must commence service under this tariff on November 1st, unless NSPI grants a waiver. - (b) The customer must be equipped with a standard Smart Meter. - (c) NSPI may limit the number of customers who may subscribe to thi...

AI summary This tariff outlines conditions for service commencement, equipment requirements, enrollment limitations, and service exclusions for customers under Rate Code 11. It specifies that service must start on November 1st, requires a Smart Meter, allows NSPI to limit enrollment, and prohibits seasonal and net metering services.

GENERAL CRITICAL PEAK PRICING TARIFF Page 3 of 4 Rate Code 73 - (5) No more than 18 Critical Peak Events may be scheduled per Winter season (November through March inclusive). No more than three Critical Peak Events will be scheduled per w...

AI summary This section outlines the limitations on the number of Critical Peak Events scheduled per winter season and per week, as well as the requirements for customer notification. Customers must be informed by 4:00 pm the day before an event and are responsible for updating their contact information with NSPI.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the General Tariff.

AI summary This optional tariff aims to encourage customers to shift their load from peak to off-peak periods. It is available to customers who are eligible for service under the General Tariff.

GENERAL TIME OF USE TARIFF Page 4 of 4 Rate Code 83 - (2) When the customer requires non-standard service provisions, the Company may require the customer to own any transformer normally provided by the Company. - (3) The customer will mak...

AI summary Rate Code 83 outlines conditions for non-standard service provisions, requiring customers to own transformers and ensuring their load does not negatively impact the power supply system's integrity. Factors like reliability, harmonic levels, voltage flicker, and stability are considered in assessing potential impacts.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the General Tariff.

AI summary This optional tariff aims to encourage customers to shift their energy usage from peak to off-peak periods. It is available to customers eligible for service under the General Tariff.

MULTI-UNIT RESIDENTIAL BUILDINGS TIME OF USE TARIFF Page 3 of 3 Rate Code 89 metering as opposed to the cost of secondary metering. Adjustment to the metered kWh usage will be made when metering is on the high voltage side. Meter readings...

AI summary This section outlines metering adjustments, customer responsibilities for non-standard service provisions, and considerations for maintaining power supply system integrity, including factors like reliability, harmonic levels, and voltage flicker.

DEMAND CHARGE As follows, per month 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.

AI summary The demand charge is calculated monthly based on the maximum demand of the current month or the highest actual demand from the previous December, January, or February within the last eleven months.

INTERRUPTIBLE RIDER TO THE LARGE INDUSTRIAL TARIFF (RATE CODE 25) Customers who qualify for interruptible service will receive a per month per kilovolt ampere reduction in demand charge for billed interruptible demand, as shown in the tabl...

AI summary This section outlines the interruptible rider to the Large Industrial Tariff (Rate Code 25), which provides a monthly reduction in demand charges based on billed interruptible demand. Billed interruptible demand is calculated as the difference between contracted firm demand and total billing demand, with specific rules for when credits apply.

LARGE INDUSTRIAL TARIFF Page 5 of 6 (2,000 kVA or 1,800 kW and over) Rate Code 23 (4) Failure to comply in whole or in part with a requirement to interrupt load will result in penalty charges. The penalty will be comprised of two parts, a...

AI summary The document outlines penalty charges for non-compliance with load interruption requirements under the Large Industrial Tariff. It specifies two types of penalties—Threshold Penalty and Performance Penalty—based on customer demand during interruptions and sets conditions for converting between interruptible and firm service.

rated at less than 69 kV) used to distribute electricity to ultimate usage points such as homes and industries either directly from nearby generators or from interchanges from the Transmission System. Distribution System Access : The servi...

AI summary The text defines key terms related to the distribution system and tariff structure, including Distribution System Access, Distribution Tariff, and Good Utility Practice. It outlines the services provided by NS Power to the RtR Customer and the components of the Distribution Tariff Rate Schedules.

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.

10.1 Provision and Ownership NS Power will provide, install and seal all revenue class meters as necessary for application of this Distribution Tariff. The meters will be used for determining charges for Distribution System Access under th...

AI summary NS Power is responsible for providing, installing, and sealing revenue class meters for RtR Customers under the Distribution Tariff. These meters will be used to determine charges for Distribution System Access. All metering equipment remains the property of NS Power and must comply with the Electricity and Gas Inspection Act regulations.

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 applicable Distribution Tariff rate accordingly.

(a) Continuous Burning – Operating Only Number of kWh per per month ($) Rate Code Bulb Length Bulbs per Unit month 2026 2027 Other 117 72 4 486 15.49 16.20 118 24 2 66 2.10 2.20 DISTRIBUTION TARIFF RATE SCHEDULES\ Page 7 of 12 Number of kW...

AI summary The document presents rate schedules for different lighting systems, including continuous burning and photocell operation, with details on rate codes, bulb lengths, number of bulbs per unit, energy consumption, and associated costs for the years 2026 and 2027.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the Domestic Service Tariff.

AI summary This optional tariff aims to encourage customers to shift their electricity usage from peak to off-peak periods. It is available to those eligible under the Domestic Service Tariff.

Effective December 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-56-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in all...

AI summary Starting December 1, 2025, NS Power will implement an Interim Energy Charge under the NSEB Decision on TVP Tariffs. The charge will apply during all hours, and no Critical Peak Events will occur during this period. NS Power must notify customers when system functionality is restored and adjust rates accordingly depending on the restoration timeline.

DOMESTIC SERVICE CRITICAL PEAK PRICING TARIFF Page 2 of 4 Rate Code 70

AI summary The document outlines the Domestic Service Critical Peak Pricing Tariff, specifically Rate Code 70, which is part of a regulatory proceeding in Nova Scotia.

2026 Securitization Rider Application Appendix G-2 (Clean) Page 6 of 87 REDACTED (CONFIDENTIAL INFORMATION REMOVED) DOMESTIC SERVICE CRITICAL PEAK PRICING TARIFF Page 4 of 4 Rate Code 70 - (d) NSPI may limit the number of customers who may...

AI summary The tariff details for Rate Code 70 outline restrictions on customer eligibility for the Domestic Service Critical Peak Pricing Tariff, including limitations on subscription numbers, seasonal service, and Net Metering.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the Domestic Service Tariff.

AI summary This optional tariff aims to encourage customers to shift their energy usage from peak to off-peak periods. It is available to those eligible under the Domestic Service Tariff.

Effective November 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-60-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in all...

AI summary Starting November 1, 2025, NS Power will implement an Interim Energy Charge as per the NSEB decision on the 2025/26 Time-varying Pricing (TVP) Tariffs. This charge applies during both winter and non-winter periods and aligns with standard offer rates. NS Power will notify customers when system functionality is restored and resume TVP rates accordingly.

DOMESTIC SERVICE TIME OF USE TARIFF Rate Code 80

AI summary The text introduces a Domestic Service Time of Use Tariff with Rate Code 80, indicating a specific pricing structure for electricity based on usage times.

2026 Securitization Rider Application Appendix G-2 (Clean) Page 13 of 87 REDACTED (CONFIDENTIAL INFORMATION REMOVED) DOMESTIC SERVICE TIME-OF-DAY TARIFF (OPTIONAL) Page 3 of 3 Rate Codes 05, 06 If the building is used principally for the o...

AI summary The document outlines the application of the Domestic tariff for buildings used primarily for personal pursuits and hobbies, and the application of General or Industrial tariffs for buildings used for commercial purposes.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the Small General Tariff.

AI summary This optional tariff aims to encourage customers to shift their load from peak to off-peak periods. It is available to customers eligible for service under the Small General Tariff.

Effective December 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-69-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in all...

AI summary Effective December 1, 2025, the Nova Scotia Energy Board's decision on NS Power's 2025/26 Time-varying Pricing (TVP) Tariffs (M12499) introduces an Interim Energy Charge during periods of system unavailability. Critical Peak Events will not be scheduled during this period, and NS Power must notify customers once functionality is restored, with specific grace periods depending on the restoration date.

SMALL GENERAL CRITICAL PEAK PRICING TARIFF Page 2 of 4 Rate Code 72

AI summary This document outlines a small general critical peak pricing tariff under Rate Code 72, indicating a specific rate structure for electricity pricing during peak demand periods.

2026 Securitization Rider Application Appendix G-2 (Clean) Page 19 of 87 REDACTED (CONFIDENTIAL INFORMATION REMOVED) SMALL GENERAL CRITICAL PEAK PRICING TARIFF Page 4 of 4 Rate Code 72 - (c) The customer must be on electronic billing and h...

AI summary This section outlines eligibility criteria for the Critical Peak Pricing Tariff, including requirements for electronic billing, profile creation, and restrictions on seasonal and net metering services.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the Small General Tariff.

AI summary This optional tariff aims to encourage customers to shift their energy usage from peak to off-peak periods. It is available to customers eligible for service under the Small General Tariff.

2026 Securitization Rider Application Appendix G-2 (Clean) Page 24 of 87 REDACTED (CONFIDENTIAL INFORMATION REMOVED) GENERAL TARIFF Page 2 of 3 Rate Code 11 Securitization Cost Recovery charges or credits (in cents per kilowatt-hour) appli...

AI summary This section outlines the application of Securitization Cost Recovery charges or credits in cents per kilowatt-hour as part of the Tariff for the current rate year, as specified in the Securitization Cost Recovery Rider, which applies in addition to the energy charge.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the General Tariff.

AI summary This optional tariff aims to encourage customers to shift their energy usage from peak to off-peak periods. It is available to customers eligible for service under the General Tariff.

Interim Energy Charge cents per kilowatt-hour During a For the first 200 kilowatt- For all cents per kilowatt-hour Interim Energy Charge During a Critical Peak Event For the first 200 kilowatt hours per month per maximum demand For all add...

AI summary The document outlines the interim energy charge rates during a Critical Peak Event and for different usage tiers. Rates are set at 14.782 cents per kilowatt-hour for the first 200 kilowatt-hours and 11.718 cents for additional usage, with higher rates effective from November 1, 2026, and January 1, 2027.

MAXIMUM PER KWH CHARGE/MINIMUM BILL The maximum charge per kWh, applying to that portion of the bill which is not concerned with determination of the cost of the Critical Peak Events, will be that for a billing load factor of 10% except th...

AI summary The document outlines the maximum per kWh charge and minimum monthly bill, specifying that the maximum charge applies to the portion of the bill not related to Critical Peak Events and is based on a billing load factor of 10%, with a minimum monthly bill threshold.

GENERAL CRITICAL PEAK PRICING TARIFF Page 4 of 4

AI summary The document refers to a Critical Peak Pricing Tariff, which is a type of time-varying pricing mechanism designed to manage electricity demand during peak periods.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the General Tariff.

AI summary This optional tariff aims to encourage customers to shift their electricity usage from peak to off-peak periods. It is available to customers eligible for service under the General Tariff.

2026 Securitization Rider Application Appendix G-2 (Clean) Page 33 of 87 REDACTED (CONFIDENTIAL INFORMATION REMOVED) GENERAL TIME OF USE TARIFF Page 4 of 4 Rate Code 83 - (2) When the customer requires non-standard service provisions, the...

AI summary The document outlines general time-of-use tariff provisions for Rate Code 83, including customer responsibilities for non-standard service provisions and ensuring load does not disrupt power supply integrity. It also mentions a multi-unit residential buildings time-of-use tariff for Rate Code 89.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the General Tariff.

AI summary This optional tariff aims to encourage customers to shift their energy usage from peak to off-peak periods. It is available to customers eligible for service under the General Tariff.

2026 Securitization Rider Application Appendix G-2 (Clean) Page 36 of 87 REDACTED (CONFIDENTIAL INFORMATION REMOVED) MULTI-UNIT RESIDENTIAL BUILDINGS TIME OF USE TARIFF Page 3 of 3 Rate Code 89 metering as opposed to the cost of secondary...

AI summary The document outlines provisions related to metering and service requirements for multi-unit residential buildings under a time-of-use tariff. It specifies adjustments to metered kWh usage and customer responsibilities regarding power supply integrity.

DEMAND CHARGE As follows, per month 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.

AI summary The demand charge is calculated based on the maximum demand of the current month or the highest actual demand from the previous December, January, or February within the last eleven months, measured in kilovolt amperes per month.

2026 Securitization Rider Application Appendix G-2 (Clean) Page 42 of 87 REDACTED (CONFIDENTIAL INFORMATION REMOVED) MEDIUM INDUSTRIAL TARIFF Page 2 of 2 (250 kVA or 225 kW to 1,999 kVA or 1,799 kW) Rate Code 22 Securitization Cost Recover...

AI summary This document outlines the application for a 2026 Securitization Rider, detailing how Securitization Cost Recovery charges or credits are applied to the Medium Industrial Tariff Rate Code 22, in addition to the energy charge for the current rate year.

2026 Securitization Rider Application Appendix G-2 (Clean) Page 45 of 87 REDACTED (CONFIDENTIAL INFORMATION REMOVED) LARGE INDUSTRIAL TARIFF Page 3 of 6 (2,000 kVA or 1,800 kW and over) Rate Code 23 - (2) Metering will normally be at the l...

AI summary This section outlines tariff requirements for large industrial customers, including metering arrangements, minimum load requirements, service agreements, and conditions to maintain power supply integrity. Specific attention is given to capital contributions for primary metering and operational agreements to ensure system reliability.

INTERRUPTIBLE RIDER TO THE LARGE INDUSTRIAL TARIFF (RATE CODE 25) Customers who qualify for interruptible service will receive a per month per kilovolt ampere reduction in demand charge for billed interruptible demand, as shown in the tabl...

AI summary The document outlines the interruptible rider to the Large Industrial Tariff (Rate Code 25), which provides a monthly reduction in demand charges for customers who qualify for interruptible service. The reduction is based on the difference between contracted firm demand and billing demand, with specific rules for when credits apply.

2026 Securitization Rider Application Appendix G-2 (Clean) Page 47 of 87 REDACTED (CONFIDENTIAL INFORMATION REMOVED) LARGE INDUSTRIAL TARIFF Page 5 of 6 (2,000 kVA or 1,800 kW and over) Rate Code 23 (4) Failure to comply in whole or in par...

AI summary This section outlines penalty charges for non-compliance with load interruption requirements under the Large Industrial Tariff. It defines Threshold and Performance Penalties, including formulas for calculating the latter. It also details procedures for converting between interruptible and firm service rates.

DEMAND CHARGE As follows, per month per kilovolt ampere of the higher of: - (a) maximum actual demand of the current month; or - (b) the maximum actual demand of the previous December, January, or February occurring in the previous eleven...

AI summary The demand charge is calculated monthly based on the higher of the current month's maximum actual demand or the highest demand from the previous December, January, or February within the last eleven months, excluding post-outage peak demands. Customers are encouraged to manage demand peaks following service restoration.

The maximum charge per kWh will be that for a billing load factor of 10% except that the minimum monthly bill for the electric power and energy portion of the Miscellaneous Lighting Rate shall be $ as follows per month if such unmetered se...

AI summary The text outlines the maximum charge per kWh based on a billing load factor of 10%, with a specific minimum monthly bill for the electric power and energy portion of the Miscellaneous Lighting Rate when billed separately from metered accounts.

10.1 Provision and Ownership NS Power will provide, install and seal all revenue class meters as necessary for application of this Distribution Tariff. The meters will be used for determining charges for Distribution System Access under th...

AI summary NS Power is responsible for providing, installing, and sealing revenue class meters for RtR Customers under the Distribution Tariff. These meters, including interval meters with remote polling capability, must comply with the Electricity and Gas Inspection Act regulations and remain NS Power's property. Metering requirements are detailed in NS Power Regulations Section 4 - Metering.

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 tariff rate accordingly.

DISTRIBUTION TARIFF RATE SCHEDULES\ Page 3 of 12 Unmetered Demand Charge ($/kVA) Minimum Monthly Charge ($/month) Effective upon the date of the Board's Order $23.264 $22.00 Effective January 1, 2027 $24.333 $22.73 Unmetered – Miscellaneou...

AI summary The document presents updated demand charges and minimum monthly charges for unmetered and miscellaneous small load services, effective upon the Board's Order and January 1, 2027. It outlines the applicability of demand charges based on maximum demand over a specified period.

PURPOSE This is an optional tariff designed to promote the shifting of load from peak to off-peak periods. This tariff is available to customers who are eligible for service under the Domestic Service Tariff.

AI summary This optional tariff aims to encourage customers to shift their electricity usage from peak to off-peak periods. It is available to customers eligible under the Domestic Service Tariff.

Effective December 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-143-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in al...

AI summary Effective December 1, 2025, the Nova Scotia Energy Board's decision on NS Power's 2025/26 Time-varying Pricing (TVP) Tariffs (M12499) establishes an Interim Energy Charge during periods of system unavailability. Critical Peak Events will not be scheduled during this period, and NS Power must notify customers when functionality is restored, with specific rate adjustments depending on the restoration timeline.

Effective November 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-147-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in al...

AI summary Starting November 1, 2025, the Interim Energy Charge applies to all hours during winter and non-winter periods, matching standard offer rates. NS Power must notify TVP customers when system functionality is restored, with specific timelines for resuming on-peak and off-peak rates depending on the restoration date.

Effective December 1, 2025, in accordance with the Nova Scotia Energy Board (NSEB, Board) Decision[1](#page-156-0) on NS Power's Application for 2025/26 Time-varying Pricing (TVP) Tariffs (M12499): - The Interim Energy Charge applies in al...

AI summary This document outlines the implementation of an Interim Energy Charge by NS Power starting December 1, 2025, following the NSEB's decision on the 2025/26 Time-varying Pricing (TVP) Tariffs. It specifies that no Critical Peak Events will occur during this interim period and details the conditions for restoring the approved Critical Peak Pricing (CPP) rates.

Page 2 of 3 Interim Energy Charge cents per kil owatt-hour (Winter and Non-winter Periods) for the first 200 kilowatt-hours per month for all additional kilowatt-hours Effective upon the date of the Board's Order 18.919 17.112 ENERGY CHARG...

AI summary The document outlines the interim energy charge rates for different periods and usage levels, specifying varying rates for winter and non-winter months, including on-peak and off-peak hours. The rates are effective from specific dates and include notes about holidays and weekends when off-peak pricing applies.

- (a) The customer must commence service under this tariff on November 1st, unless NSPI grants a waiver. - (b) The customer must be equipped with a standard Smart Meter. - (c) NSPI may limit the number of customers who may subscribe to thi...

AI summary This section outlines the conditions for customers subscribing to Rate Code 11, including the requirement to use a Smart Meter, limitations on enrollment, and restrictions on seasonal and Net Metering service from NSPI.

MAXIMUM PER KWH CHARGE/MINIMUM BILL The maximum charge per kWh, applying to that portion of the bill which is not concerned with determination of the cost of the Critical Peak Events, will be that for a billing load factor of 10% except th...

AI summary The document sets a maximum charge per kWh for billing load factors of 10%, with a minimum monthly bill threshold. This applies to portions of the bill unrelated to Critical Peak Events.

per month Effective upon the date of the Board's Order $22.00 GENERAL CRITICAL PEAK PRICING TARIFF Page 4 of 4

AI summary The document outlines a critical peak pricing tariff, effective upon the date of the Board's Order, with a rate of $22.00 per month.

The maximum charge per kWh will be that for a billing load factor of 10% except that the minimum monthly bill for the electric power and energy portion of the Miscellaneous Lighting Rate shall be $ as follows per month if such unmetered se...

AI summary The text outlines the maximum charge per kWh based on a 10% billing load factor, with a specified minimum monthly bill for the electric power and energy portion of the Miscellaneous Lighting Rate when billed separately from metered accounts.

10.1 Provision and Ownership NS Power will provide, install and seal all revenue class meters as necessary for application of this Distribution Tariff. The meters will be used for determining charges for Distribution System Access under th...

AI summary NS Power is responsible for providing, installing, and sealing revenue class meters for RtR Customers under the Distribution Tariff. These meters, including interval meters with remote polling capability, will be owned by NS Power and must comply with the Electricity and Gas Inspection Act regulations. Metering requirements are detailed in NS Power Regulations Section 4 - Metering.

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 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 incorporated into the distribution tariff rates for each rate class. The RtR Customer is responsible for covering the costs of these losses.

difference between non-fuel - revenue under PHP's current tariff and an above the line - tariff. And so we have included in the application a - breakdown in the calculation of that, and that is the - forecast deferral as of December 31st o...

AI summary The text discusses financial aspects of a tariff application, including revenue differences, deferrals related to the ISO and fuel costs, bond issuance, and thermal assets. It outlines unrecovered costs, financial estimates, and references the DDA annual report.

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 it facilitates the potential - transition of PHP to an above-the-line tariff that can - provide increased contribution towards fixed costs for - customers on a go-forward basis and assists in the - introduction of PHP's wind resource to...

AI summary The text discusses the securitization transaction involving the transition of the Public Health Program (PHP) to an above-the-line tariff, which would help cover fixed costs and integrate PHP's wind resource into the Nova Scotia grid. The International Energy Services Organization (IESO) deferral is also mentioned, with costs totaling $20.2 million. The IESO is described as a long-lived organization supporting energy transition goals.

ent of - this long-lived organization are appropriate to include in - the securitization transaction. - And I just included a note here. - We've included it in the Application as well, but I think - important to reiterate, both of these it...

AI summary The discussion centers on deferral mechanisms, specifically the PHP and IESO deferrals, which are based on forecasted future values. Any discrepancies between the forecast and actual balances will be adjusted via the FAM. Concerns are raised about the long-term deferral of costs and their fairness to future customers.

ar? Including FAM the FAM costs. - MR. FLEMMING: So Libby, I'll start, - and then maybe some folks in the room have something that - they want to add that and I do have some more detailed - fuel costs as well in the upcoming page here. - B...

AI summary The discussion revolves around the costs associated with the FAM and the IESO deferral balance, emphasizing the need to distribute these costs over current and future customers. The speaker highlights the long-term value of the energy transition and the securitization transaction, while a question is raised about the discrepancy between the IESO deferral balance and the submitted budget.

recognized in the - current policy context of what we see from the provincial - government lately, but probably more immediately from the - federal government last week with their announcement of a - $2 billion investment in electric heati...

AI summary The speaker discusses the importance of avoiding significant rate increases in the near term to align with provincial and federal policy objectives, particularly those related to electrification and renewable energy. They note that growing the load base helps spread fixed costs over more customers, benefiting future users. The securitization rider is also mentioned as a new fixed cost that could be mitigated by increasing load.

crease really jeopardizes that policy objective, I - think. - So sorry. That was a bit of a - sidetrack, but Craig. - MR. FLEMMING: Yeah, so thank you. - So Daniel, I was going to start by - I was going to start my response the same way Bl...

AI summary The discussion centers on the potential rate increase of approximately 7 to 8 percent, with adjustments based on the balance of $150 million and expected under-recovery of about 2 percent. The conversation also touches on the role of the FAM and securitization in managing these financial aspects.

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.

ve - gone and where we are already in '26, it's very clear that - we're going to be under-recovered in '27 with a BCF not - intending to be done until 2028. - So it's not under a guise and I think - it's a very reasonable approach to be to...

AI summary The speaker discusses the challenges of under-recovery in 2027 due to delayed BCF implementation and the need for a more nimble FAM process to handle fuel costs separately. They emphasize the volatility of fuel markets and the need for a more responsive approach to avoid financial imbalances and protect customer interests.

that that - will be in 2028 through adjusted general rates and then - the IESO deferral assumed recovery in 2027, beginning in - 2027 through an IESO rider. - And so looking at all of that and so - comparing the 30-year securitization mort...

AI summary The discussion focuses on the financial implications of securitization, comparing a 30-year securitization mortgage-style bond with a scenario where assets are recovered over a 13-year period. The analysis shows a $265.6 million net present value decrease in customer payments, or an increase in customer benefits, representing a 21% savings.

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.

NOVA SCOTIA ENERGY BOARD NOTICE OF PUBLIC HEARING Application by Nova Scotia Power Incorporated For Approval of a Financing Order authorizing the securitization of $1 billion in costs, collected through a Securitization Cost Recovery Rider...

AI summary Nova Scotia Power Incorporated has applied for approval to securitize $1 billion in costs through a Securitization Cost Recovery Rider. The costs include asset retirement, fuel and purchased power under-recoveries, and deferral account balances. The application is filed under the Public Utilities Act and Financing Orders and Securitized Bonds Regulations.

NOVA SCOTIA ENERGY BOARD NOTICE OF PUBLIC HEARING Application by Nova Scotia Power Incorporated For Approval of a Financing Order authorizing the securitization of $1 billion in costs, collected through a Securitization Cost Recovery Rider...

AI summary Nova Scotia Power Incorporated has applied for approval to securitize $1 billion in costs through a Securitization Cost Recovery Rider, including costs related to thermal generation asset retirement, fuel and purchased power under-recoveries, and deferral accounts. The request is made under the Public Utilities Act and Financing Orders and Securitized Bonds Regulations.

NOVA SCOTIA ENERGY BOARD NOTICE OF PUBLIC HEARING Application by Nova Scotia Power Incorporated For Approval of a Financing Order authorizing the securitization of $1 billion in costs, collected through a Securitization Cost Recovery Rider...

AI summary Nova Scotia Power Incorporated has applied for approval to securitize $1 billion in costs, collected through a Securitization Cost Recovery Rider. The costs include deferred financing costs, fuel and purchased power costs, and deferral account balances, among others.

NOVA SCOTIA ENERGY BOARD NOTICE OF PUBLIC HEARING Application by Nova Scotia Power Incorporated For Approval of a Financing Order authorizing the securitization of $1 billion in costs, collected through a Securitization Cost Recovery Rider...

AI summary Nova Scotia Power Incorporated has applied for approval of a financing order authorizing the securitization of $1 billion in costs, collected through a Securitization Cost Recovery Rider. The costs include thermal generation asset retirements, fuel and purchased power costs, and deferral account balances.

Application by Nova Scotia Power Incorporated For Approval of a Financing Order authorizing the securitization of $1 billion in costs, collected through a Securitization Cost Recovery Rider The Board has received an application from NS Pow...

AI summary Nova Scotia Power Incorporated has applied for approval of a financing order to securitize $1 billion in costs, collected through a Securitization Cost Recovery Rider. The costs include thermal generation asset retirements, fuel and purchased power costs, and deferral accounts.

Application by Nova Scotia Power Incorporated For Approval of a Financing Order authorizing the securitization of $1 billion in costs, collected through a Securitization Cost Recovery Rider The Board has received an application from NS Pow...

AI summary Nova Scotia Power Incorporated has applied for approval to securitize $1 billion in costs, including thermal generation asset retirements, fuel and purchased power costs, and deferral accounts, through a Securitization Cost Recovery Rider. The application is under the Public Utilities Act and Financing Orders and Securitized Bonds Regulations.

October 16, 2026 VIA EMAIL Ms. Crystal Henwood Clerk of the Board Nova Scotia Energy Board 1601 Lower Water Street, 3rd Floor Halifax NS B3J 3S3 Dear Ms. Henwood: Re: M13133 – Application for Financing Order authorizing the Securitization...

AI summary The Small Business Advocate (SBA) supports the Industrial Group's request for further clarification on the procedure for allocating securitized costs to different rate classes. The SBA is concerned about the allocation of costs, particularly those related to the IESO-NS deferral, and suggests allowing a further process for intervenors to provide evidence and submissions.

27 Request IR-8: - 28 Section 2.3 of the application addresses the PHP Deferral account. NS Power says the "…PHP 29 Deferral account was approved by the Board during the 2026-2027 GRA to address uncertainty 30 associated with the treatment...

AI summary The document discusses the PHP Deferral account and its approval by the Board during the 2026-2027 GRA. It requests confirmation regarding the forecast amount, the ELID tariff application, and how deviations from GRA assumptions will be handled in Securitized Costs.

4 Request IR-12: - 5 On p. 15 of its application, with respect to the inclusion of Fuel and Purchased Power costs, the 6 PHP Deferral and the IESO Deferral in the transaction, NS Power states that "[t]he proposed 7 securitization is consis...

AI summary The document requests an explanation of how the Fuel and Purchased Power costs, PHP Deferral, and IESO Deferral in the current application align with the securitization approach discussed in the 2026-2027 GRA, which focused on the securitization of DDA assets that will become stranded.

13 Request IR-13: - 14 On pp. 16-17 of its application and pp. 35-36 of the technical conference transcript, NS Power 15 advances the benefits of the securitization of Fuel and Purchased Power costs, the PHP Deferral 16 and IESO Deferral f...

AI summary The document raises concerns about the securitization of Fuel and Purchased Power costs and the PHP and IESO Deferral, questioning whether transferring current costs to future customers aligns with intergenerational equity and policy objectives around electrification. It also inquires about rate increases and their impact on electrification goals.

1 Request IR-14: - 2 On p. 17 of its application, NS Power noted that, if not securitized, the September 2026 FAM - 3 balance would need to be collected through the existing FAM process resulting in an increase of - 4 about 7 8%. - 5 a) Wh...

AI summary The document outlines a series of questions regarding the securitization of the Fuel Adjustment Mechanism (FAM) balance by NS Power, including potential rate increases, customer impact, deferral of balances, and comparisons with other jurisdictions. It also asks about the scope of securitization and future rate adjustments.

16 Request IR-17: - 17 On pg. 23 of its application, NS Power states that the "requested Financing Order would include 18 a Formula-based True-up Mechanism to provide for periodic adjustments to the Securitized 19 Surcharge to correct any...

AI summary NS Power's application proposes a Formula-based True-up Mechanism to adjust the Securitized Surcharge periodically. The Board is requesting clarification on the definition of 'periodic adjustments' and whether they occur annually on November 1st or under other circumstances.

26 Request IR-18: - 27 On p. 24 of the application, lines 19-23, NS Power estimates the net present value of total 28 customer payments under traditional recovery principles at "…$1.242 billion over a 13-year 29 recovery period." The Board...

AI summary The document requests clarification on why NS Power selected a 13-year recovery period for thermal assets and asks for a revised NPV analysis using a 20-year recovery period through the DDA, including sensitivity tables.

33 Request IR-29: - 34 Section 11.8 of the application addresses the requirement of an indemnity agreement from the - 35 Province of Nova Scotia to proceed with securitization. The letter from Deputy Minister Kelliann - 36 Dean dated Octob...

AI summary The document discusses Section 11.8 of an application related to an indemnity agreement from the Province of Nova Scotia for securitization. A letter from Deputy Minister Kelliann Dean dated October 8, 2026, is noted as not a commitment to provide the indemnity. The question asks when NS Power anticipates a definitive answer from the Province.

18 Request IR-31: - 19 Using a $900 million figure as an alternative scenario for a securitized bond issuance (about equal 20 to excluding FAM prepaid balances, the PHP deferral and the IESO deferral): - 21 a) Please provide an NPV calcula...

AI summary The document requests an NPV calculation for a $900 million securitized bond issuance and asks for rate increases by customer class in 2027, including the general rate increase, securitization surcharge, IESO rider, forecasted Demand Side Management rider increase, and other anticipated rate impacts.

Request IR-4: - Reference: Section 9.0, including Figure 9; Section 12.1; Appendix F; Appendices A, B CONF, - C and C Attachment 1 CONF, E and H - Please provide, by securitized-cost component: - a) the forecast-to-actual differences expec...

AI summary Request IR-4 asks for detailed information on securitization cost components, including forecast-to-actual differences, recovery mechanisms, treatment of pre-bond-issuance collections, and reconciliation of calculations to confidential schedules.

Request IR-2: NSPI states: NS Power's Q3 Forecast includes a forecast Fuel Adjustment Mechanism (FAM) under- recovery of $41.7 million, before interest, in Q4 2026 and 2027. The $64.9 million FAM prepayment consists of this forecast under-...

AI summary NSPI proposes a $23.2 million additional FAM prepayment to be securitized over 30 years, aiming to moderate fuel rate impacts in 2028 and manage transitional energy costs. This approach seeks to distribute costs across current and future customers and align with long-term energy transition goals.

Request IR-5: Section 2.3 PHP Deferral proposes that $12.2 million as of December 31, 2026 is proposed for securitization made up of the actual deferral account balance as at August 30, 2026; the forecast deferrals from September 1, 2026 t...

AI summary Request IR-5 seeks clarification on NSPI's proposal to securitize a PHP deferral balance, including the timing of the deferral balance reference, the interest portion, and the justification for securitizing accrued interest under the Public Utilities Act.

Request IR-6: Section 2.4 IESO Deferral states that $20.2 million as of December 31, 2026 is proposed for securitization made up of the actual deferral account balance as at August 30, 2026; the forecast deferrals from September 1, 2026 th...

AI summary The document requests clarification on the proposed securitization of $20.2 million as of December 31, 2026, including the reference date for the deferral account balance and the treatment of accrued interest under the Public Utilities Act.

Request IR-9: Please refer to Exhibit N-1, the Application, Section 2.4 IESO Deferral, page. 15 of 51, lines 3-9, which sets out the proposed deferral of the IESO-NS account, including the actual deferral amount up to Augst 20, 2026 and th...

AI summary The document refers to Exhibit N-1 and requests clarification on the deferral of the IESO-NS account, including the actual and forecasted deferral amounts. It also asks how cost overruns from the 2025/2026 period, which have been securitized, will be addressed, and what happens if the approved 2026/2027 revenue requirement is less than the securitized amount, depending on the timing of the decision.

22 Reference: Exhibit N-1, Appendix C; and Figure 1, p. 10. (a) Please provide a schedule, in excel format, similar in approach to Appendix C, but limited solely to the forecast 2027 fuel shortfall (i.e. the forecast FAM under-recovery for...

AI summary The request asks for an Excel schedule showing the impact on 2027 GRA rates if the 2027 fuel shortfall were recovered through the FAM process instead of being securitized, and also asks for the resulting rate impact by customer class.

Request: a) Please confirm if the values shown on the "Summary" worksheet of "2026 Securitization Rider Application Appendix A EO.xlsx" are fixed or if they will change. If values are expected to change, please provide an overview of what...

AI summary The text requests confirmation on the fixed nature of values in a securitization rider application, potential changes to costs, and the role of specific prepayment amounts in adjusting the total securitization issuance value. It references multiple applications and regulatory matters, including the ELID tariff and AAR application.

- Reference: N-1, section 2.3 and Appendix A, tab "2 PHP Deferral." - a. Please provide a narrative explanation as to why the "PHP Deferral" includes Non-Fuel costs only (and not Fuel Costs). - b. Please provide the basis for "accrued inte...

AI summary The text requests an explanation for why the 'PHP Deferral' includes only Non-Fuel costs and not Fuel Costs, and the basis for accrued interest calculated at the Bank of Canada policy rate plus 1.75 percent.

Request IR-16: - Reference: N-1, Section 2.3. - a. If NS Power's Application is not approved, please explain how NS Power would recover the PHP Deferral Account amounts. - b. Regarding "the Company's Q3 Forecast," please provide the foreca...

AI summary Request IR-16 includes questions about NS Power's ability to recover PHP Deferral Account amounts if its application is not approved, as well as inquiries about the Q3 forecast for PHP's load and Goose Harbour wind farm output.

1 Request IR-11: 2 Reference: N-1, Appendix C, Figure 6 (pg. 11), and pages 12 – 13. Preamble: Figure 6 shows that the Large Industrial (both Firm and Interruptible) portion of the Balancing Adjustment (BA) for under-recovered FAM costs is...

AI summary The document requests detailed reconciliation and breakdown of fuel adjustment mechanism (FAM) balances, focusing on the Large Industrial class. It asks for class-level calculations, explanations of discrepancies between Balancing Adjustment (BA) and Actual Adjustment (AA) balances, and clarification on allocation methods and historical decisions affecting FAM balances.

14 Request IR-15: 15 Reference: N-1, Application, page 14, lines 9-13; and Appendix A, tab "2 - PHP Deferral." "The balance of the Port Hawkesbury Paper (PHP) Deferral account, forecast to be $12.2 million as of December 31, 2026, is propo...

AI summary The document discusses the proposed securitization of the Port Hawkesbury Paper (PHP) Deferral account, which is forecast to be $12.2 million as of December 31, 2026. It also requests clarification on why the 'Fuel' variance, totaling $3.6 million, is excluded from the deferral and securitization process, while interest is applied only to the 'Non-fuel' variance.

14 Request IR-17: 15 Reference: N-1, Application, page 14, lines 21-25. "[A]ny difference between the forecast balance of $12.2 million and the actual PHP Deferral account balance at December 31, 2026 be applied as an adjustment to the $64...

AI summary The text discusses the adjustment of the Fuel Adjustment Mechanism (FAM) prepayment based on the forecast and actual balance of the PHP Deferral account by December 31, 2026. It requests an explanation of how discrepancies would be applied through the Balancing Adjustment (BA) mechanism, including customer class impacts and timing, and why the adjustment is applied to the FAM prepayment rather than the PHP Deferral account itself.

8 Request IR-18: - 9 Reference: N-1, Application, page 31, Figure 7: Securitization Rider for Below the Line 10 (BTL) customer class in 2027. - 11 Preamble: Figure 7, lists the Extra Large Industrial Dispatchable ("ELID") rate class as 12...

AI summary The text requests an explanation of why the ELID rate class is classified as Below-the-Line for the 2027 Securitization Rider, why it lacks a Fuel & Purchased Power rider despite future costs, and why certain costs should not be charged to the ELID class if incurred while it is taking service.

21 Request IR-20: - 22 Reference: N-1, Application, page 15, lines 3-8; and Appendix A, tab "3 NSIESO - 23 Deferral." "The balance of the Nova Scotia Independent Energy System Operator (IESO-NS) Deferral account, forecast to be approximate...

AI summary The document discusses the proposed securitization of a $20.2 million IESO-NS Deferral account balance, including questions about the impact of a potential Board determination, the breakdown of the deferral balance by month, consideration of under-spend from 2025-2026, and the rationale for requiring ratepayers to pay accrued interest at 6.59%.

21 REASONS FOR INCLUSION AS SECURITIZED COSTS - 22 Request IR-21: - 23 Reference: N-1, Application, Section 2.5, pages 15 18; - 24 Preamble: NSPI discusses its rationale for including the proposed costs in the 25 securitization transaction...

AI summary Nova Scotia Power Inc. (NSPI) outlines 21 reasons for including certain costs in a securitization transaction, emphasizing lower financing costs, intergenerational cost sharing, rate stability, and support for the Province's energy transition. The request references sections of an application and asks for an explanation of relevant utility rate-setting principles, including Bonbright's principles and cost causation.

1 intergenerational equity, the matching of costs and benefits, and the used 2 and useful principle. 3 (b) For each component of the proposed securitization (thermal assets and 4 associated financing costs, under-recovered fuel and purchas...

AI summary The text requests an explanation of how the proposed securitization and 30-year recovery period align with principles of intergenerational equity, cost-benefit matching, and the nature of costs, benefits, and responsible customers for various components of the securitization.

12 Reference: N-1 Application, page 21, Figure 4 and page 22, lines 4-13 "NS Power proposes an annual servicing fee of 0.05 percent of the initial principal amount of the Securitized Bonds to cover costs and expenses in servicing the Secur...

AI summary NS Power proposes a 0.05% annual servicing fee on Securitized Bonds to cover costs of servicing, which includes billing and collecting the Securitized Surcharge. The Board is asked to confirm if these functions overlap with current activities, whether the fee is justified, and how it will be accounted for in future GRAs.

1 customers, identify the mechanism and explain the resulting reallocation. 2 (e) Please provide worked numerical examples showing the annual true-up 3 consequences of customer entry, customer departure, class migration and 4 a material in...

AI summary The text requests detailed numerical examples explaining the annual true-up consequences of customer entry, departure, class migration, and load changes, including over or under-collection and the customer classes responsible for adjustments.

Request IR-7: - References: Application page 25 and Appendix B (Confidential) - Nova Scotia Power has calculated a Net Present Value difference as between the proposed plan - and the assumed "Traditional Recovery" of more than $265 Million...

AI summary Nova Scotia Power has calculated a $265 million Net Present Value difference between a proposed plan and the 'Traditional Recovery' approach. The request asks for an analysis of how much of this difference is due to the lower cost of capital and the longer 30-year term of the Securitized Financing, as well as a comment on the inter-generational fairness implications of the term choice.