2026 Annually Adjusted Rates (AARs) NS Power Application November 7, 2025 REDACTED
AI summary The document is an application by NS Power for 2026 Annually Adjusted Rates (AARs), submitted on November 7, 2025. The content is redacted, so no further details are available.
Application for Annually Adjusted Rates for 2026 Redacted 1 TABLE OF CONTENTS 2 3 1.0 Introduction 7 4 1.1 Prior AAR Proceeding Directives 8 5 1.2 Board Directive regarding Time-varying Pricing Structure for AARs 9 6 2.0 Marginal Cost Anal...
AI summary The document outlines an application for annually adjusted rates for 2026, including sections on marginal cost analysis, tariff structures, and various board directives related to pricing and billing procedures. It covers topics such as load following, real-time pricing, shore power, wholesale market tariffs, and renewable to retail market tariffs.
Application for Annually Adjusted Rates for 2026 Redacted 1 The components of the energy production cost changes are outlined in the table below. 2 3
AI summary The document outlines the components of energy production cost changes for 2026, as part of an application for annually adjusted rates. However, the specific details of these changes are redacted and not visible in the provided text.
Figure 1: Cost of Energy Generation $/MWh by Gen. Source 2026 AAR 2025 AAR Percent Change (%) Solid Fuel Oil & Gas NB Imports ML Surplus 4
AI summary The text presents a table titled 'Cost of Energy Generation' with columns for 2026 AAR, 2025 AAR, and Percent Change (%), but no data is provided in the rows. The table includes categories like Solid Fuel, Oil & Gas, NB Imports, and ML Surplus.
- 5 In addition, in the 2019 AARs proceeding NS Power committed to providing a comparison of values - 6 associated with each assumption from the current and previous year's application and PLEXOS - output reports. 16 The PLEXOS model used...
AI summary The document discusses NS Power's use of the PLEXOS model in the 2026 AARs proceeding, including modeling assumptions and sensitivity analyses on fuel prices. It references the 2019 AARs proceeding and a 2025 Q3 Fuel and Purchased Power model.
Application for Annually Adjusted Rates for 2026 Redacted 1 transitioned load remains interruptible. Starting with 2026, this load will continue to be served as 2 interruptible under the Transmission RTP Tariff instead of High Voltage (HV)...
AI summary Nova Scotia Power (NSP) is proposing changes to the calculation of 1P-RTP Adders for the 2026 Annually Adjusted Rates (AAR) application. This includes eliminating the avoided fuel cost adjustment and applying hourly marginal energy costs for energy charges, citing issues with forecasting under current methods due to air emissions limits and non-dispatchable generation.
6 Figure 4: Shore Power Tariff Charges by Voltage and Cost Components in Cents per kWh 2025 2026 Variance EHV Fuel Cost 9.187 n/a n/a Fixed Cost Adder 3.919 n/a n/a Total 13.106 n/a n/a HV Fuel Cost 9.276 n/a n/a Fixed Cost Adder 4.130 n/a...
AI summary The table in Figure 4 outlines the shore power tariff charges by voltage and cost components in cents per kWh for 2025 and 2026, showing variations in fuel cost, fixed cost adder, and total charges across different voltage levels and system components.
11 C2 . 8 The calculations for the SP rates are provided in Appendix C2 . The proposed SP Tariff is provided 9 as Appendix C1 . A redline version is provided in Appendix H . Please also refer to Partially 10 Confidential Appendix D for ene...
AI summary The document references appendices containing calculations for SP rates, the proposed SP Tariff, and energy requirement figures used in rate calculations. It also mentions a redline version of the tariff and a partially confidential appendix.
Application for Annually Adjusted Rates for 2026 Redacted 1 As approved by the Board in the original proceeding to set these rates,32 the BUTU Tariff and the 2 Spill Tariff were each assigned 50 percent of the associated administration cos...
AI summary The document discusses the application for annually adjusted rates for 2026, including the use of an inflation rate to adjust administration costs and the proposed increase in customer charges. It references past Board decisions and the methodology used to calculate energy charges.
10 Figure 5: BUTU Energy Charge Components in Cents per kWh 2026 Energy Charge Components Marginal Cost Methodology Embedded Cost Methodology Proposed Rates Energy-related Purchased Power and Fuel Cost 6.736 6.984 6.984 Energy-related Fixe...
AI summary Figure 5 outlines the BUTU Energy Charge Components in cents per kWh for 2026, showing energy-related purchased power and fuel costs, as well as energy-related fixed generation costs under different methodologies and proposed rates.
14 6.1.4 Proposed BUTU Rates 15 16 The proposed BUTU Tariff charges for 2026 are set out in Figure 7 . 17
AI summary The document outlines the proposed BUTU Tariff charges for 2026, as detailed in Figure 7. This section is part of a broader discussion on rate proposals within the regulatory proceeding.
8 6.2 Spill Tariff 9 10 The Spill Tariff has two components: an Administration Charge and an Energy Credit. 11 - 12 The Administration Charge is proposed to increase from the currently approved $2,409.46 to - 13 $2,487.77 per supplier, per...
AI summary The Spill Tariff consists of an Administration Charge and an Energy Credit. The Administration Charge is proposed to increase by 3.25% in 2026, and the Energy Credit is based on the Company's forecast average marginal energy cost. Supporting details are provided in Appendix E2, and the proposed rates are outlined in Figure 8 and Appendix E1.
23 6.3 Board Directive regarding Reciprocal and Non-reciprocal Billing 24 25 The Board provided the following directive in its Order, dated March 25, 2025, approving the 2025 26 AARs:
AI summary The Board issued a directive on reciprocal and non-reciprocal billing in its Order dated March 25, 2025, approving the 2025 AARs. This directive outlines the Board's stance on billing practices related to utility services.
1 Figure 9: Energy Balancing Service Tariff Charges 2025 2026 Variance Administration Charge ($/customer/month) 401.58 414.63 13.05 Energy Charge (cents per kWh) Fuel Cost (cents per kWh) 8.919 6.736 (2.183) Fixed Cost Adder (cents per kWh...
AI summary Figure 9 presents Energy Balancing Service Tariff Charges for 2025 and 2026, showing changes in administration charges, energy charges, fuel costs, fixed cost adders, and energy credits. The administration charge increases, while energy charges decrease significantly.
Application for Annually Adjusted Rates for 2026 Redacted 1 The proposed SS rate charges for 2026 as compared to 2025 are set out in Figure 10 . 2
AI summary The document outlines the proposed SS rate charges for 2026 as compared to 2025, referencing Figure 10 for details.
3 Figure 10: Standby Service Tariff Charges 2025 2026 Variance Administration Charge ($/customer/month) 401.58 414.63 13.05 Demand Charge ($/kW) 3.397 5.452 2.055 4
AI summary Figure 10 presents standby service tariff charges for 2025 and 2026, showing an increase in both administration and demand charges. The administration charge rises from $401.58 to $414.63 per customer per month, while the demand charge increases from $3.397 to $5.452 per kW.
9 7.3 Renewable to Retail Transition Tariff 10 - 11 The RtR Transition Tariff (RTT) is designed to recover from the LRSs NS Power's embedded - 12 fixed costs and deferred costs (ordinarily recovered through bundled service rates) which are...
AI summary The Renewable to Retail Transition Tariff (RTT) is designed to recover NS Power's embedded and deferred fixed costs from the LRSs, which are not otherwise recovered through other RtR tariffs. RTT includes two rate components: the Energy Charge and the Demand Charge.
2026 AAR Application Appendix A1 Page 1 of 5 REDACTED (CONFIDENTIAL INFORMATION REMOVED) GENERATION REPLACEMENT AND LOAD FOLLOWING TARIFF Page 1 of 5
AI summary This document is the first page of a redacted appendix from the 2026 Annual Application Report (AAR) related to the Generation Replacement and Load Following Tariff. It is part of a regulatory proceeding involving Nova Scotia Power and the Nova Scotia Energy Board.
Backup Service The actual or estimated average time coincident incremental cost of generation including transmission losses for the period service is provided plus 0.500 cents per kWh for additional Operating and Maintenance costs, service...
AI summary The Backup Service rate includes the average time coincident incremental cost of generation, transmission losses, and additional costs such as operating and maintenance, service charges, and administration and general compensation, with an additional 0.500 cents per kWh.
Optional Generation Load Following Average incremental cost of generation expressed in cents per kWh as determined by the generation forecast for the rate year plus add on charges as defined for back-up service. This price will be 7.236 ce...
AI summary The document outlines the average incremental cost of generation for the rate year, set at 7.236 cents per kWh, including add-on charges for back-up service as determined by the generation forecast.
2026 AAR Application Appendix A1 Page 2 of 5 REDACTED (CONFIDENTIAL INFORMATION REMOVED) GENERATION REPLACEMENT AND LOAD FOLLOWING TARIFF Page 2 of 5
AI summary This document is part of the 2026 Annual Application Report (AAR) Appendix A1, focusing on the Generation Replacement and Load Following Tariff. The content has been redacted, indicating that sensitive or confidential information has been removed.
REDACTED 2026 AAR Application Appendix A2 Page 1 of 1 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Marginal Cost ($/MWh) 2026 Peak Off-peak All periods Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Year 67.36 REDACTED 2026 AAR Application...
AI summary The document contains redacted appendices from the 2026 AAR Application, including a table with marginal cost data and a page labeled 'Appendix A3'. The content is confidential and not fully visible.
Modelling Assumptions used in PLEXOS The PLEXOS model used for the 2025 Annually Adjusted Rates forecast is based on the 2025 Q3 fuel and purchased power forecast model.
AI summary The PLEXOS model used for the 2025 Annually Adjusted Rates forecast is based on the 2025 Q3 fuel and purchased power forecast model.
2026 Annually Adjusted Rates Confidential Appendix A5 has been removed due to confidentiality.
AI summary Confidential Appendix A5 from the 2026 Annually Adjusted Rates has been removed due to confidentiality reasons.
REDACTED 2026 AAR Application Appendix A6 Page 1 of 4 REDACTED (CONFIDENTIAL INFORMATION REMOVED) System Marginal Cost ($/MWh) 2026 Peak Off-peak All periods Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Year 70.45 REDACTED 2026 AAR Appl...
AI summary The document presents system marginal cost data for 2026 under different sensitivity scenarios, including baseline, prices adjusted downwards, and ML surplus energy not included. The year-round system marginal cost is reported as 70.45, 62.38, and 73.31 respectively for each scenario.
Sensitivity 4: No New Wind System Marginal Cost ($/MWh) 2026 Peak Off-peak All periods Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Year 73.31 2026 Annually Adjusted Rates Confidential Appendix A7 has been removed due to confidentiality.
AI summary This section, 'Sensitivity 4: No New Wind,' presents a table outlining system marginal costs for 2026, with the annually adjusted rates in Confidential Appendix A7 removed due to confidentiality concerns.
REDACTED 2026 AAR Application Appendix B2 Page 1 of 19 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 1P-RTP ADDER CALCULATION Approved Year 2025 Proposed Year 2026 Exclude the GRLF, LRT and Shore Power rate classes. Exclude the following rat...
AI summary The document presents a comparison of cost components for the 1P-RTP Adder calculation between the approved Year 2025 and proposed Year 2026, excluding specific rate classes. It details the breakdown of generation, transmission, and customer costs, along with the percentage variance between the two years.
REDACTED 2026 AAR Application Appendix B2 Page 6 of 19 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Approved Year 2025 Proposed Year 2026 Exclude the GRLF, LRT and Shore Power rate classes. Exclude the following rate classes: the GRLF, OATT...
AI summary The document presents a comparison of approved and proposed costs for various voltage classes in 2025 and 2026, highlighting significant variances in customer administration costs and the exclusion of specific rate classes for the 2026 AAR application. Certain voltage classes show substantial percentage changes in costs, while others remain relatively stable.
REDACTED 2026 AAR Application Appendix B2 Page 14 of 19 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Case 2023 GRA 2026 GRA COS COS TEMPLATE TEMPLATE % COL 1 COL 2 Variance Fixed Generation Costs OM&G $135,308,637 $143,317,278 5.9% Capital...
AI summary The document presents financial data comparing 2023 and 2026 GRA (General Rate Application) figures, including fixed generation, transmission, and distribution costs, with notable variances in OM&G, capital, and ROE expenses. The data highlights significant increases in distribution costs and overall total expenses.
2026 Annually Adjusted Rates Method Used to Calculate 1P-RTP Tariffs
AI summary The document discusses the use of the 2026 annually adjusted rates method in calculating 1P-RTP tariffs, indicating a focus on rate design and the implementation of updated tariff structures.
2026 AAR Application Appendix B3 Page 2 of 11 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 2026 Annually Adjusted Rates Method Used to Calculate 1P-RTP Tariffs
AI summary This document discusses the use of the 2026 Annually Adjusted Rates Method in calculating 1P-RTP Tariffs, highlighting the approach used for rate adjustments.
2026 AAR Application Appendix B3 Page 4 of 11 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 2026 Annually Adjusted Rates Method Used to Calculate 1P-RTP Tariffs
AI summary The 2026 AAR Application Appendix B3 outlines the use of the 2026 Annually Adjusted Rates Method in calculating the 1P-RTP Tariffs, indicating a regulatory process involving rate calculation and tariff design.
A B C D E F G H I J K L M Formular A/C B/C G/G11 H I I J-I J/A K/B Categorized amount in Costing Determinants Millions Adders in $ / kWh Customer Class Sales On Off 3 CPS Amount in On Off On Off Line Relative % Millions Apportion On Off On...
AI summary The document presents a detailed breakdown of transmission and distribution costs, including sales, peak and off-peak usage, line losses, and cost apportionment across different customer classes. It also includes notes on line losses and cost categorization.
2026 AAR Application Appendix B3 Page 5 of 11 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 2026 Annually Adjusted Rates Method Used to Calculate 1P-RTP Tariffs
AI summary This section of the 2026 AAR Application Appendix B3 outlines the use of the 2026 Annually Adjusted Rates Method in calculating the 1P-RTP Tariffs, which is part of the General Rate Application process.
2026 AAR Application Appendix B3 Page 6 of 11 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 2026 On peak rates in Cents/ kWh Fig 3 rates in Cents/ kWh Variance Fixed Cost Adder Fuel ADJ Grand Total Generation Transmission Distribution Custom...
AI summary The document provides a detailed breakdown of 2026 on-peak and off-peak electricity rates in cents per kWh for Transmission and Distribution, including fixed cost adders, fuel adjustment mechanisms, and grand totals. It highlights the structure of the rate application and associated cost components.
2026 AAR Application Appendix B3 Page 10 of 11 REDACTED (CONFIDENTIAL INFORMATION REMOVED) A B C D E F G H I J K L Formular A/C B/C D H E H I/A 100 I/A 100 Costing Determinants F G 12 Off On Adders Cents/ kWh Average Cost per Cost per Cust...
AI summary The document presents financial and cost data related to transmission and distribution for different customer classes, including sales, cost determinants, and allocation percentages. It includes tables with figures for total generation, transmission, and distribution costs, as well as percentages of on and off-peak sales.
- (2) A fixed cost adder adjusted concurrent with changes in base cost rates coming into effect as a result of a General Rate Case application. Base Energy Charge Components Transmission Voltage of 69 kV or Higher (cents per kWh) Distribut...
AI summary The text describes a fixed cost adder that is adjusted in tandem with changes in base cost rates resulting from a General Rate Case application. A table provides details on base energy charge components, including fuel cost and fixed cost adder for different voltage levels.
Penalty for Non-Compliance All energy served after the 10-minute deadline has expired will be billed at $5.00 per kWh. In addition a fixed charge of $2,000.00 will be applied. The penalty charge is applicable above and beyond the Port Auth...
AI summary A penalty of $5.00 per kWh and a fixed charge of $2,000.00 applies to energy served after the 10-minute deadline, in addition to the Port Authority's monthly bill.
SPECIAL CONDITIONS (1) The Port Authority owns and is responsible for the maintenance and operation of all electrical equipment required for the supply of port electricity to docked ships other than the meters and
AI summary The Port Authority is responsible for maintaining and operating all electrical equipment necessary for supplying electricity to docked ships, excluding meters and other specified components.
2026 AAR Application Appendix C2 Page 1 of 1 REDACTED (CONFIDENTIAL INFORMATION REMOVED) SHORE POWER CALCULATION 2026 MWh Requirement Unit Revenue Unit Production Total non-demand Cost at Total at Generator's related fixed cost Generator's...
AI summary This table outlines the shore power calculation for 2026, including MWh requirements, unit fuel costs, and revenue by voltage class. It details line losses, generation, transmission, and distribution costs, as well as unit fixed costs and rates. A footnote directs readers to the 'Usage Statistics' tab in Appendix D for further information on energy requirements.
CUSTOMER CHARGE The monthly customer charge under this tariff is calculated according to the following formula: Monthly customer charge = $$\frac{\text{forecast annual administration costs}}{\text{forecast number of customers subscribed 12...
AI summary The monthly customer charge under the tariff is calculated using forecast annual administration costs divided by the forecast number of customers subscribed multiplied by 12, resulting in a charge of $414.63 per month.
- (2) Demand-related fixed generation cost, coming into effect as a result of a General Rate Application. Demand Charge Components $ per kW of billing demand Demand-related Purchased Power Cost $6.252 Demand-related Fixed Generation Cost $...
AI summary The document outlines the demand-related fixed generation cost, which is part of a General Rate Application. It includes a table showing the demand charge components, such as demand-related purchased power cost and demand-related fixed generation cost, totaling to $11.704 per kW of billing demand.
- (2) Energy-related fixed generation cost, coming into effect as a result of a General Rate Application. Energy Charge Components cents per kWh Energy-related Purchased Power and Fuel Cost 6.984 Energy-related Fixed Generation Cost 2.166...
AI summary This section introduces an energy-related fixed generation cost that is being implemented due to a General Rate Application. The cost is 2.166 cents per kWh, contributing to a total energy charge of 9.150 cents per kWh. The Fuel Adjustment Mechanism (FAM) is also referenced.
ADMINISTRATION CHARGE The monthly administration charge under this tariff is calculated according to the following formula: Monthly customer charge = forecast annual administration costs forecast number of suppliers supplying wholesale cus...
AI summary The monthly administration charge under the tariff is calculated based on forecast annual administration costs divided by the forecast number of suppliers supplying wholesale customers, multiplied by 12, resulting in a charge of $2,487.77 per month.
ENERGY CREDIT Compensation for spill energy delivered to NSPI will be at the Company's forecast average annual marginal energy costs of 6.736 cents per kilowatt hour as approved for use with the GRLF rate.
AI summary The compensation for spill energy delivered to NSPI is set at the Company's forecast average annual marginal energy costs of 6.736 cents per kilowatt hour, as approved for use with the GRLF rate.
Proposed Annual Inflation Rate 3.25% 2025 2026 Variance Administration Costs of the BUTU and Spill Tariffs $57,827.11 $59,706.49 $1,879.38 3.25% Administrative Charge Under Spill Rate Annual Cost (50% of total) $28,913.56 $29,853.25 $939.6...
AI summary The document presents a table detailing proposed annual inflation rates of 3.25% for various cost components, including administration costs of the BUTU and Spill Tariffs, administrative charges, customer charges, and tariff rate components such as capacity credit, demand charges, and energy charges for the years 2025 and 2026.
Monthly Fuel Cost Allocation Jan-26 Feb-26 Mar-26 Apr-26 May-26 Jun-26 Jul-26 Aug-26 Sep-26 Oct-26 Nov-26 Dec-26 Total PHP $43,189 $31,812 $51,318 $1,639 $64,024 $62,638 $91,100 $87,357 $81,993 $2,564 $62,356 $43,127 $623,117 Municipal $13...
AI summary The document presents a table showing the monthly fuel cost allocation for various categories such as PHP, Municipal, and Unmetered from January to December 2026, along with totals for each month and the year. The data includes figures for different classes and overall totals.
Monthly Energy Allocators Rate Class Jan-26 Feb-26 Mar-26 Apr-26 May-26 Jun-26 Jul-26 Aug-26 Sep-26 Oct-26 Nov-26 Dec-26 Total kWh requirements ATL Domestic Total 707,116,004 662,646,274 625,765,329 481,109,226 389,926,477 315,832,492 344,...
AI summary The text presents a table showing monthly energy requirements across various rate classes in Nova Scotia from January 2026 to December 2026, with totals provided for each category.
Annual Peak of ATL 2,356,954 Annual Energy Requirement of ATL 11,303,785,142 System Coincident Load Factor 54.748044% Total FAM related costs and Incremental Cost to OATT customers $ 103,820,358 $ 91,433,115 $ 88,369,434 $ 72,524,007 $ 65,...
AI summary The text presents data on the annual peak and energy requirement of ATL, along with various costs and financial figures related to energy generation and distribution, including FAM-related costs, purchased biomass generation, and other line items such as BLT fuel costs and exports.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: Monthly charge = $$\frac{\text{forecast annual administration costs}}{\text{forecast number of LRS' s...
AI summary The monthly administration charge is calculated annually using a formula based on forecasted annual administration costs and the forecasted number of LRS' subscribed. The charge is set at $414.63 per month.
ENERGY CHARGE Energy charge for top-up service is made up of the following two components: - (1) Annually adjusted fuel cost component based on NS Power's incremental cost of serving the LRS' forecasted incremental top-up load.
AI summary The energy charge for top-up service includes an annually adjusted fuel cost component based on NS Power's incremental cost of serving the LRS' forecasted incremental top-up load.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: Monthly charge = forecast annual administration costs forecast number of LRS' subscribed \ 12 This ch...
AI summary The monthly administration charge is set annually based on forecasted annual administration costs divided by the forecasted number of LRS' subscribed, multiplied by 12. The charge is set at $414.63 per month.
Renewable to Retail Classes Jan, Feb, Dec Mar, Apr May, Jun Jul, Aug, Sep Oct, Nov Domestic 1.00 1.34 2.13 2.26 1.65 Small General 1.00 1.24 1.62 1.59 1.35 General 1.00 1.21 1.47 1.36 1.20 Large General 1.00 0.99 0.93 0.86 0.99 Small Indus...
AI summary The document presents a table of rate classes and their corresponding multipliers for different months, indicating variations in pricing across different customer categories. It also mentions 'PR' as Planning Reserve, based on criteria from the Northeast Power Coordinating Council.
2026 AAR Application Appendix F1 Page 7 of 9 REDACTED (CONFIDENTIAL INFORMATION REMOVED) STANDBY SERVICE TARIFF Page 4 of 4 Renewable to Retail (4) Nothing contained in this Standby Service Tariff or any service agreement shall be construe...
AI summary This section of the Standby Service Tariff outlines that NS Power retains the right to apply for changes to rates, terms, and conditions, including those in the Standby Service Tariff, Energy Balancing Service Tariff, and Renewable to Retail Market Transition Tariff, as needed.
PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...
AI summary The Renewable to Retail Market Transition Tariff (RTT) is established under the Electricity Act to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing, income tax, and OM&G, and are recovered through Bundled Service. Deferred costs are those approved by the Nova Scotia Energy Board for future recovery.
SPECIAL CONDITIONS (1) Nothing contained in this RTT or any service agreement shall be construed as affecting or in any way limiting the right of NS Power to make application to the Nova Scotia Energy Board for a change in any rates, terms...
AI summary This special condition states that the RTT and related service agreements do not restrict NS Power's right to apply for changes in rates, terms, and conditions to the Nova Scotia Energy Board, including those related to the Standby Service Tariff and Energy Balancing Service Tariff.
SECURITY FOR PAYMENTS NS Power shall invoice PHP weekly, and PHP shall pay the billed amount net 7 days. As security for payment, PHP shall provide NS Power a letter of credit from time to time. The form, amount, and issuer of the letter o...
AI summary NS Power requires PHP to provide a letter of credit as security for payments, with the form, amount, and issuer to be satisfactory to NS Power. Any additional costs or lag time caused by the letter of credit will be borne by PHP, not NS Power or its customers.
SEPARATE SERVICE AGREEMENT NS Power reserves the right to have a separate service agreement if, in the opinion of NS Power, issues not specifically set out herein must be addressed for the ongoing benefit of NS Power and its customers.
AI summary NS Power may enter into a separate service agreement if, in its opinion, additional issues need to be addressed for the ongoing benefit of NS Power and its customers.
VCC: UNIT UTILIZATION OVERVIEW No PHP Load With PHP Load Delta Unit CF (%) Hours/yr Starts/yr UF CF (%) Hours/yr Starts/yr UF UF Delta Sustaining Capital Delta 01 - Lingan 1 02 - Lingan 2 03 - Lingan 3 04 - Lingan 4 05 - Point Aconi 06 - P...
AI summary The document presents a table titled 'VCC: UNIT UTILIZATION OVERVIEW,' which compares unit utilization metrics for various power generation units with and without the PHP Load, including metrics such as capacity factor, hours per year, starts per year, and utilization factor. The total sustaining capital delta is listed as $787,508.
SECURITY FOR PAYMENTS NS Power shall invoice PHP weekly, and PHP shall pay the billed amount net 7 days. As security for payment, PHP shall provide NS Power a letter of credit from time to time. The form, amount, and issuer of the letter o...
AI summary NS Power requires PHP to pay weekly invoices within 7 days and provide a letter of credit as security. PHP must cover any additional costs or lag time caused by the letter of credit, not NS Power or its customers.
SEPARATE SERVICE AGREEMENT NS Power reserves the right to have a separate service agreement if, in the opinion of NS Power, issues not specifically set out herein must be addressed for the ongoing benefit of NS Power and its customers.
AI summary NS Power retains the right to establish a separate service agreement if, in its opinion, additional issues need to be addressed for the ongoing benefit of NS Power and its customers.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: This charge will be $401.58414.63 per month.
AI summary The monthly administration charge is set annually and applies to each LRS. The charge is specified as $401.58414.63 per month.
- (2) Fixed cost adder reflective of fixed cost energy-related generation costs. Energy Charge Components cents per kWh Fuel Cost 8.919 6.736 Fixed Cost Adder 3.264 2.166 Total 12.183 8.902 The charge is applicable to top-up energy consume...
AI summary The text outlines a fixed cost adder for energy-related generation costs, showing changes in fuel cost and fixed cost adder components, with the total energy charge per kWh decreasing from 12.183 to 8.902 cents.
Backup Service The actual or estimated average time coincident incremental cost of generation including transmission losses for the period service is provided plus 0.500 cents per kWh for additional Operating and Maintenance costs, service...
AI summary The Backup Service rate includes the average time coincident incremental cost of generation, transmission losses, and additional costs such as operating and maintenance, service charges, and administration and general compensation, with an additional 0.500 cents per kWh.
Optional Generation Load Following Average incremental cost of generation expressed in cents per kWh as determined by the generation forecast for the rate year plus add on charges as defined for back-up service. This price will be 9.4197.2...
AI summary The text outlines the average incremental cost of generation for the rate year, expressed in cents per kWh, including add-on charges for back-up service, with a specific price of 9.4197.236 cents per kWh.
ENERGY CHARGE NSPI's actual hourly marginal energy costs, plus the following fixed cost adders for on-peak and offpeak usage: On-peak (7:00 am – 11:00 pm, non-holiday weekdays): 8.903 10.008 ¢/kWh Off-peak (11:00 pm – 7:00am, non-holiday w...
AI summary NSPI's energy charge includes hourly marginal costs and fixed cost adders for on-peak and off-peak usage, with weekend and holiday rates set to off-peak prices. The adders are annually developed and submitted for approval. A credit is applied for customer-owned transformers during peak demand.
The Energy Charge is made up of the following components: Energy Charge Components cents per kWh Fixed Cost Adder from Energy Balancing Service Tariff 3.2642.166 Annually Adjusted Energy Savings Credit 0.000 Annual Energy Cost Adjustment (...
AI summary The Energy Charge comprises several components, including a Fixed Cost Adder from the Energy Balancing Service Tariff, an Annually Adjusted Energy Savings Credit, and an Annual Energy Cost Adjustment. The charge applies to the LRS' monthly displaced energy on NS Power's generation system, calculated as the total monthly LRS load minus the top-up quantity determined under the Energy Balancing Service Tariff.
SPECIAL CONDITIONS (1) Nothing contained in this RTT or any service agreement shall be construed as affecting or in any way limiting the right of NS Power to make application to the Nova Scotia Utility and ReviewEnergy Board for a change i...
AI summary This section outlines special conditions in the RTT, emphasizing that NS Power retains the right to apply for changes in rates, terms, and conditions to the Nova Scotia Utility and Review Energy Board, including those related to various service tariffs.
AVAILABILITY - (1) This tariff is available to port authorities of Nova Scotia for the sole purpose of providing port electricity to cruise ships docked in ports to meet their own consumption needs in displacement of the on-board self-gene...
AI summary This tariff is available to Nova Scotia port authorities for providing electricity to cruise ships, with specific demand thresholds and supply interruption requirements. It is seasonal, available from April 1 to November 30, and outlines the priority order for capacity calls during supply shortfalls.
Penalty for Non-Compliance All energy served after the 10-minute deadline has expired will be billed at $5.00 per kWh. In addition a fixed charge of $2,000.00 will be applied. The penalty charge is applicable above and beyond the Port Auth...
AI summary A penalty of $5.00 per kWh is applied for all energy served after the 10-minute deadline, along with a fixed charge of $2,000.00. This penalty applies in addition to the Port Authority's monthly bill.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: This charge will be $401.58414.63 per month.
AI summary The monthly administration charge applicable to each LRS is set annually and is currently calculated to be $401.58414.63 per month.
DETERMINATION OF MONTHLY STANDRY CONTRACT DEMAND Monthly Standby Contract Demand (MSCD) in kW is determined using the following formula: $$MSCD = LWPFD - min (LWPFD, (\sum_{i=1}^{nn} CCi GCi)/(1+PR))$$
AI summary The document provides a formula for calculating the Monthly Standby Contract Demand (MSCD) in kW, which is determined by subtracting the minimum of the load without power factor demand (LWPFD) and a calculated value from the LWPFD.
Where: - "k" is the number of otherwise applicable bundled service rate classes to RtR customers of an LRS. - o "CMPFDi" is hourly kW Class Monthly Peak Firm Demand of the LRS firm load in each tariff class at the time of system coincident...
AI summary The text defines key terms related to bundled service rate classes for LRS customers, including CMPFDi and CMDAFi, and references an effective date and page number from an appendix in the 2026 AAR Application.
STANDBY SERVICE TARIFF Page 4 of 4 Renewable to Retail (4) Nothing contained in this Standby Service Tariff or any service agreement shall be construed as affecting or in any way limiting the right of NS Power to make application to the No...
AI summary The Standby Service Tariff page 4 outlines that NS Power retains the right to apply for changes to rates, terms, and conditions through the Nova Scotia Utility and Review Energy Board, including those related to the Standby Service Tariff, Energy Balancing Service Tariff, and Renewable to Retail Market Transition Tariff.
CUSTOMER CHARGE The monthly customer charge under this tariff is calculated according to the following formula: This charge will be $401.58414.63 per month.
AI summary The monthly customer charge under the tariff is set at $401.58414.63 per month, as calculated by the specified formula.
DEMAND CHARGE The demand charge for this service is made up of the following two components: - (1) Annually adjusted demand-related purchased power cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism, or...
AI summary The demand charge for the service consists of two components, with the first being an annually adjusted demand-related purchased power cost influenced by factors such as the Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
ENERGY CHARGE The energy charge is made up of the following two components: - (1) Annually adjusted energy-related purchased power and fuel cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism or General R...
AI summary The energy charge consists of two components, with the first being annually adjusted energy-related purchased power and fuel costs, influenced by factors such as the Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
MINIMUM MONTHLY CHARGE The minimum monthly charge will be the customer charge plus the demand charge.
AI summary The minimum monthly charge is defined as the sum of the customer charge and the demand charge.
ADMINISTRATION CHARGE The monthly administration charge under this tariff is calculated according to the following formula: Monthly customer charge = $\frac{\text{forecast annual administration costs}}{\text{forecast number of suppliers su...
AI summary The monthly administration charge is calculated using a formula that divides forecast annual administration costs by the forecast number of suppliers supplying wholesale customers multiplied by 12. The calculated charge is approximately $0.968 per month.
ENERGY CREDIT Compensation for spill energy delivered to NSPI will be at the Company's forecast average annual marginal energy costs of 8.9196.736 cents per kilowatt hour as approved for use with the GRLF rate.
AI summary The document specifies that compensation for spill energy delivered to Nova Scotia Power Inc. (NSPI) will be based on the Company's forecast average annual marginal energy costs, set at 8.9196.736 cents per kilowatt hour, as approved for use with the GRLF rate.
MINIMUM MONTHLY CHARGE The minimum monthly charge shall be the administration charge.
AI summary The document defines the minimum monthly charge as the administration charge, establishing a clear and straightforward billing mechanism for customers.
2026 AAR Application Appendix J Page 1 of 3 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Date: October 15, 2025 To: Annually Adjusted Rates Stakeholders From: Regulatory Affairs, NS Power Subject: NS Power Proposal for Changes to 1P-RTP Tar...
AI summary Nova Scotia Power Inc. (NS Power) is proposing changes to the calculation of One-Part Real Time Pricing (1P-RTP) Adders in response to the Board's directive on its 2025 AAR Application. The changes are due to challenges in calculating avoided fuel costs in the complex air emission market.
2026 AAR Application Appendix J Page 2 of 3 REDACTED (CONFIDENTIAL INFORMATION REMOVED) - 1. The growing complexity of the air emission market makes the continued application of the current avoided fuel cost methodology increasingly diffic...
AI summary The text discusses the challenges with the current avoided fuel cost methodology in the context of the 1P-RTP service, arguing that it leads to volatility and unreliability. It notes the shift from this methodology to a marginal fuel cost approach as directed by the Board in its 2017 decision. This change aligns the 1P-RTP tariffs with the costing approach used for other AARs, using an annual average of forecasted hourly marginal costs.
Next Steps Stakeholders are requested to provide comments on the proposed approach (if any), as outlined in this letter, by Friday, October 24, 2025, following which NS Power will address stakeholders' comments in consideration of its 2026...
AI summary Stakeholders are invited to comment on the proposed changes to transmission rates in the 1P-RTP and Shore Power Tariffs, which would eliminate separate rates for EHV and HV transmission levels if the Board accepts the proposed change in the 2026-2027 Cost of Service Study. NS Power will consider these comments when filing its 2026 AAR Application.
Exhibit N-1, Appendix J, p. 2. Exhibit N-1, Matter No. M11989, p. 17. Annually Adjusted Rates for 2026 (M12551) NSPI Responses to CA Information Requests
AI summary The document references Exhibit N-1, Appendix J, and includes information related to Matter No. M11989 and Matter No. M12551, which involve annually adjusted rates for 2026 and NSPI's responses to information requests.
Date Filed: December 19, 2025 NSPI (CA) IR-4 Page 2 of 6 Annually Adjusted Rates for 2026 (M12551) NSPI Responses to CA Information Requests
AI summary The document outlines NSPI's responses to information requests related to the annually adjusted rates for 2026, under matter number M12551.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to CA Information Requests
AI summary The document outlines NSPI's responses to information requests from the Commissioner of the Environment and Sustainable Resource Development regarding annually adjusted rates for 2026.
2 Exhibit N-1, Matter No. M08383, p. 8. Annually Adjusted Rates for 2026 (M12551) NSPI Responses to CA Information Requests
AI summary This document refers to Exhibit N-1 from Matter No. M08383, page 8, which discusses NSPI's responses to information requests from the Commissioner of the Environment and Sustainable Resource Development regarding annually adjusted rates for 2026.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to CA Information Requests
AI summary This document outlines NSPI's responses to information requests from the Commissioner of the Environment and Sustainable Resource Development regarding annually adjusted rates for 2026.
Exhibit N-1, Matter No. M08383, p. 13. Annually Adjusted Rates for 2026 (M12551) NSPI Responses to CA Information Requests
AI summary The document refers to Exhibit N-1 from Matter No. M08383, page 13, which details NSPI's responses to the Commissioner of the Environment and Sustainable Resource Development's information requests regarding annually adjusted rates for 2026 (M12551).
REDACTED 1 Request IR-7: 2 3 Re: Application, p.14 and Confidential Appendix A7, identifying factors that cause actual 4 import volumes to vary from forecast. 5 6 (a) Please provide a list of the factors, including but not limited to those...
AI summary The text outlines a request (IR-7) for NS Power to identify factors causing discrepancies between forecasted and actual import volumes during 2021-2025, and to explain if these factors will affect 2026 imports from the NB/ISONE market. It also requests information on how forecasts were developed and whether historical averages are sufficient to account for changes.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to IG Information Requests
AI summary The document pertains to the Annual Adjusted Rates for 2026 (M12551) and includes NSPI's responses to information requests from the Independent Generator (IG).
NON-CONFIDENTIAL 1 Company is not yet in a position to confirm whether access to all historical records will be 2 available. 3 4 (b) No, the material requested, that was not available as a result of the cyber incident, has no 5 bearing on...
AI summary The company is unable to confirm access to historical records and states that the cyber incident did not impact data used for AAR rate calculations. Additionally, the company lacks the necessary granularity in forecasted NB imports to provide the requested analysis.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to IG Information Requests
AI summary The document outlines NSPI's responses to information requests regarding the Annually Adjusted Rates for 2026 (M12551). It provides details on the rate application and related regulatory considerations.
Date Filed: December 19, 2025 NSPI (IG) IR-5 Page 2 of 2 5 M12184 – NS Power Reply to Compliance Filing Comments, page 3. December 5, 2025. Annually Adjusted Rates for 2026 IG IR-5 Attachment 1 Page 1 of 8
AI summary The document references a compliance filing comment response by NS Power regarding Annually Adjusted Rates for 2026. It includes a citation to a specific matter number and page reference.
SECURITY FOR PAYMENTS NS Power shall invoice PHP weekly, and PHP shall pay the billed amount net 7 days. As security for payment, PHP shall provide NS Power a letter of credit from time to time. The form, amount, and issuer of the letter o...
AI summary NS Power requires PHP to pay weekly invoices within 7 days and provide a satisfactory letter of credit as security. PHP is responsible for any additional costs or lag time caused by the letter of credit.
SEPARATE SERVICE AGREEMENT NS Power reserves the right to have a separate service agreement if, in the opinion of NS Power, issues not specifically set out herein must be addressed for the ongoing benefit of NS Power and its customers. Ann...
AI summary NS Power may enter into a separate service agreement if additional issues arise that are not covered in the current agreement, for the benefit of NS Power and its customers. The document also references annually adjusted rates for 2026.
SECURITY FOR PAYMENTS NS Power shall invoice PHP weekly, and PHP shall pay the billed amount net 7 days. As security for payment, PHP shall provide NS Power a letter of credit from time to time. The form, amount, and issuer of the letter o...
AI summary NS Power requires PHP to pay weekly invoices within 7 days and provide a satisfactory letter of credit as security. PHP is responsible for any additional costs or lag time caused by the letter of credit.
REDACTED (CONFIDENTIAL INFORMATION REMOVED) Annually Adjusted Rates for 2026 (M12551) NSPI Responses to MEU Information Requests
AI summary This document outlines the annually adjusted rates for 2026 (M12551) and includes NSPI's responses to MEU information requests. The content focuses on regulatory proceedings related to rate adjustments and information disclosure.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to MEU Information Requests
AI summary The document outlines NSPI's responses to MEU information requests regarding annually adjusted rates for 2026, providing details on rate adjustments and related considerations.
Annually Adjusted Rates for 2026 (NSEB M12551) NSPI Responses to NSEB Information Requests Request IR-1: Appendix A2 presents the annual marginal generation costs by month. (a) Please explain why for February and March. (b) Please provide...
AI summary The document discusses NSPI's response to NSEB's information request regarding annual marginal generation costs, explaining variations in February and March, and the exclusion of Output Based Pricing System costs. It also addresses the forecast of marginal costs for Peak in June and July, citing the integration of renewable energy and GHG emission regulations.
Annually Adjusted Rates for 2026 (NSEB M12551) NSPI Responses to NSEB Information Requests
AI summary The document pertains to the NSEB M12551 proceeding concerning annually adjusted rates for 2026, including NSPI's responses to information requests from the Nova Scotia Energy Board.
NON-CONFIDENTIAL 1 Request IR-12: 2 3 The Back UpTop-Up Tariff 2026 customer charge is proposed to be increased by 3.25%. NS 4 Power considers this increase to be consistent with the Board's directive in the 2019 AAR 5 Decision. 6 7 (a) Pl...
AI summary NS Power proposes a 3.25% increase in the Back UpTop-Up Tariff 2026 customer charge, citing the 2019 AAR Decision. The company explains that the rate is higher than the 2.2% inflation rate reported by Statistics Canada in 2025, as it accounts for factors beyond cost-of-living adjustments, such as market competitiveness and employee retention.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to REI Information Requests 1 Request IR-1: 2 3 Reference: Section 2.0 Marginal Cost Analysis, pages 11-14. 4 (a) Please provide the number of hours and percentage of hours for each...
AI summary The document outlines information requests related to the Annually Adjusted Rates for 2026 (M12551), specifically focusing on the marginal cost analysis for 2023, 2024, and 2025. It requests data on the number of hours and percentages of hours each generator class was forecasted to be the marginal unit in the PLEXOS model, as well as any variances between forecast and actual performance.
10 2023 Total Hours 2023 (%) 2024 Total Hours 2024 (%) Q1 2025 Total Hours 2025 (%) Lingan 1 734 8.4 1,046 11.9 251 11.6 Lingan 2 146 1.7 272 3.1 170 7.9 Lingan 3 982 11.2 981 11.2 170 7.9 Lingan 4 971 11.1 599 6.8 195 9.0 Point Aconi 1 69...
AI summary The table presents data on total hours for various power generation sites across 2023, 2024, and Q1 2025, with percentages indicating their contribution. This data is related to the Annually Adjusted Rates for 2026 (M12551) and NSPI's responses to REI information requests.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to REI Information Requests 1 Request IR-2: 2 3 Reference: Page 12, lines 7-9 and footnote 17. 4 5 6 The PLEXOS model used for the 2026 AAR forecast is the 2025 Q3 Fuel and Purchased...
AI summary The document discusses a response by Nova Scotia Power Inc. (NSPI) to a request regarding the PLEXOS model used for the 2026 AAR forecast, clarifying that the model was based on updated assumptions and pricing data as of September 24, 2025, rather than August 2024 as previously stated.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to REI Information Requests
AI summary The document pertains to the annual adjustment of rates for 2026, with NSPI providing responses to REI information requests related to the matter.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to REI Information Requests 1 Request IR-11: 2 3 Reference: Renewable to Retail Market Tariffs, page 31 states "Estimates for the current 4 scope of work referenced remain in the ran...
AI summary NSPI has updated its Capital Work Order with actual costs to October 2025, noting variances due to changes in Commercial Operation Dates of Licensed Retail Suppliers. The work was filed as part of the December 2025 package with Matter number M12588.
Annually Adjusted Rates for 2026 REI IR-11 Attachment 1 Page 5 of 5 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Actuals Estimates to Complete Totals RtR Set Up Projects 2023 2024 2025 (end Oct) 2025 Nov-Dec 2026 Labour $ 122,016 $ 94,397 $...
AI summary The document outlines the costs associated with Real-Time Retail (RtR) Set Up Projects from 2023 to 2026, including labor, contracts, consulting, software, overheads, interest, and contingency costs. The total estimated cost for these projects is $5,312,938.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to REI Information Requests
AI summary This document outlines NSPI's responses to REI information requests regarding annually adjusted rates for 2026. It provides details on the rate adjustments and related financial considerations.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to REI Information Requests
AI summary The document pertains to the Annual Adjustment Rate for 2026 (M12551) and includes NSPI's responses to REI information requests. It is part of a regulatory proceeding related to rate adjustments and information disclosure.
PARTIALLY CONFIDENTIAL (Attachment Only) 2026 AAR Appendix Cross-reference Provided in 2026 AAR Appendix M12451 NSEB Exhibit No. Refer to 2026 COSS – Exhibit 5, page 1, Energy 2026 COSS – Exhibit 5, cell E48 N-17(C)-(i) Attachment 1 F2 202...
AI summary The document contains a partially confidential attachment with cross-references to various exhibits and matters related to the 2026 AAR and COSS, including references to exhibits, attachments, and matter numbers. NS Power has granted access to REI counsel in this matter.
Annually Adjusted Rates for 2026 REI IR-12 Attachment 1 Page 1 of 5 REDACTED (CONFIDENTIAL INFORMATION REMOVED) EXHIBIT 5 Page 1 of 5
AI summary The document is an exhibit from a regulatory proceeding discussing annually adjusted rates for 2026, focusing on regulatory and economic issues related to electricity. It includes confidential information that has been redacted.
CLASSIFICATION OF OPERATING EXPENSES FOR THE YEAR ENDING DECEMBER 31, 2026 (IN THOUSANDS OF DOLLARS) (1) TOTAL COMPANY (2) DEMAND EXPENSES (3) ENERGY EXPENSES (4) CUSTOMER EXPENSES GENERATION FUNCTION (1) FUEL 434,033 $0 $434,033 - (2) PUR...
AI summary This document provides a classification of operating expenses for the year ending December 31, 2026, categorized into demand, energy, and customer expenses. It includes details on fuel costs, purchases, maintenance, depreciation, and other financial items related to generation and operations.
CLASSIFICATION OF OPERATING EXPENSES (1) TOTAL COMPANY (2) DEMAND EXPENSES (3) ENERGY EXPENSES (4) CUSTOMER EXPENSES TRANSMISSION FUNCTION (1) Transmission - HV (not aplicable as a separate item) (2) O&M - HV Before Storm Expense (3) O&M -...
AI summary The document presents a classification of operating expenses for transmission functions, including HV and EHV, with detailed breakdowns of O&M, depreciation, interest, and other financial items. The data includes figures for 2026 and references to REI IR-12 Attachment 1.
NOVA SCOTIA POWER INC. CLASSIFICATION OF OPERATING EXPENSES (1) TOTAL COMPANY (2) DEMAND EXPENSES (3) ENERGY EXPENSES (4) CUSTOMER EXPENSES DISTRIBUTION FUNCTION (1) Before Streetlights: (2) SUBSTATIONS $2,076 $2,076 $0 - (3) OVERHEAD LINE...
AI summary The document presents a detailed breakdown of Nova Scotia Power Inc.'s operating expenses, categorized into demand, energy, and customer expenses. It includes depreciation, taxes, and other financial items related to distribution functions and corporate operations.
Annually Adjusted Rates for 2026 REI IR-12 Attachment 3 Page 1 of 6 REDACTED (CONFIDENTIAL INFORMATION REMOVED) EXHIBIT 6 PAGE 1 OF 6 NOVA SCOTIA POWER INC.
AI summary This document is an exhibit from Nova Scotia Power Inc. related to the Annually Adjusted Rates for 2026, part of a regulatory proceeding. It is labeled as confidential and contains information relevant to the rate-setting process.
ALLOCATION OF OPERATING EXPENSES (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL (7) MEDIUM INDUSTRIAL INDUSTRIAL INDUSTRIAL (8) LARGE (9) PHP (10) MUNICIPAL (11) UNMETERED (12) ALLOCATION FACTOR (1...
AI summary The document presents a detailed breakdown of operating expenses allocated across various categories and customer segments, including grants, interest, taxes, non-operating revenue, and return on investment. It includes allocation factors and references to specific exhibits and orders.
DEMAND CLASSIFICATION (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (9) (10) (11) ALLOCATION COMPANY DOMESTIC GENERAL GENERAL LARGE INDUSTRIAL INDUSTRIAL INDUSTRIAL PHP MUNICIPAL UNMETERED FACTOR (1) Transmissi...
AI summary The document presents a detailed breakdown of demand classification across various categories, including transmission, operating and maintenance expenses, depreciation, interest, corporate taxes, and revenue, with associated allocations and factors. It includes various line items and references to regulatory and financial processes.
ALLOCATION OF OPERATING EXPENSES FOR THE YEAR ENDING DECEMBER 31, 2026 (IN THOUSANDS OF DOLLARS) (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL (7) MEDIUM INDUSTRIAL INDUSTRIAL INDUSTRIAL (8) LARGE...
AI summary This table presents the allocation of operating expenses for the year ending December 31, 2026, across various categories and customer segments, including total company, domestic, small general, general, large, small, medium industrial, large industrial, PHP, municipal, and unmetered. It includes figures for other revenue, return, total retail, total customer, and total net expenses.
Annually Adjusted Rates for 2026 REI IR-12 Attachment 4 Page 1 of 2 REDACTED (CONFIDENTIAL INFORMATION REMOVED) FIGURE 6-8
AI summary The document contains a redacted figure related to annually adjusted rates for 2026 under the Regulatory Energy Information (REI) IR-12 Attachment 4. The content is confidential and not fully disclosed.
NOVA SCOTIA POWER INC. CAPACITY BASED ANCILLARY SERVICES 2026 REVENUE REQUIREMENT AND RATE DESIGN (1) (2) (3) (4) (5) (6) (7) (8) (9) Revenue Requirement ($/kW-yr) Services Required (MW) Revenue Requirement ($000/yr) Usage (MW) Rate for Ne...
AI summary The document presents a table outlining the revenue requirement and rate design for Nova Scotia Power Inc.'s capacity-based ancillary services in 2026, including various services such as regulation, load following, and operating reserves, along with their associated costs and rates.
Annually Adjusted Rates for 2026 REI IR-12 Attachment 4 Page 2 of 2 REDACTED (CONFIDENTIAL INFORMATION REMOVED) FIGURE 6-10
AI summary The document contains a redacted figure related to annually adjusted rates for 2026 under the Regulatory Energy Information (REI) IR-12 Attachment 4. Specific details have been removed due to confidentiality.
NON-CONFIDENTIAL 1 Request IR-13: 2 3 Reference: Energy Balancing Service Tariff, pages 31-32 and Appendix F2. 4 5 (a) Please compare the forecasted export sales for 2025 and 2026 and provide an 6 explanation. 7 8 (b) Please explain how th...
AI summary The document discusses a request (IR-13) related to the Energy Balancing Service (EBS) tariff, including forecasted export sales, transmission loss factor calculations, and percentage changes in EBS components. The response indicates that EBS rates are based on cost-of-service studies from previous GRA filings and refers to specific sections of the 2026-2027 GRA for further details.
5 8 13 17 2 The double percent digit reduction in the fuel cost components are due to the overall lower 3 cost of energy generation as provided in Figure 1: Cost of Energy Generation in the 4 evidence of the Application. 6 The reduction of...
AI summary The text discusses a 33.66% reduction in the Fixed Cost Adder, attributed to changes in the Cost of Service (COS) methodology and increased energy requirements in the above-the-line rate classes. It references the 2023 and 2026 Cost of Service Studies (COSS) and refers to an application related to the Annually Adjusted Rates for 2026 (M12551).
NON-CONFIDENTIAL 1 Request IR-14: 2 3 Reference: Standby Service, page 34. 4 5 With respect to Figure 10, please add a column to show the percentage change for each 6 component of the Standby Service Tariff compared to 2025 rates. Where th...
AI summary The request asks for a percentage change column in Figure 10 of the Standby Service Tariff compared to 2025 rates, with detailed explanations for changes exceeding 10%. The response refers to a figure but does not provide the data or explanations requested.
13 Variance 2025 2026 Amount Percent 13.05 3.25 Administration Charge ($/customer/month) 401.58 414.63 Demand Charge ($/kW) 3.397 5.452 2.055 60.5 14
AI summary The text presents a table showing changes in administration and demand charges from 2025 to 2026, including variance amounts and percentages. The administration charge increases from $401.58 to $414.63 per customer per month, while the demand charge rises from $3.397 to $5.452 per kW, with a significant variance of 60.5%.
Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 10 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) This alternative was rejected for two reasons: - The purpose of the Market Rules is to define the rights and obligations of t...
AI summary The alternative proposal was rejected because it conflates the rights and obligations between NSPSO and Market Participants with those between NS Power and LRS. The proposed amendments to the WMP Agreement and Wholesale Market Rules were deemed irrelevant and potentially confusing for Wholesale Market Participants. The required Market Rule amendments under the selected option are considered minor.
3.3 Interruptible Service Interruptible service has been made available by NS Power as a Bundled Service option to qualifying large industrial customers. Those customers undertake to interrupt their load on demand (or by remote trigger) of...
AI summary Interruptible service is offered by NS Power to qualifying large industrial customers as a Bundled Service option, with penalties for non-compliance. Customers on interruptible service are not counted in firm load, and switching to firm service requires additional capacity development. Stakeholders indicated that interruptibility status remains unchanged when switching between Bundled Service and RtR service.
3.5 Behind-the-Meter RtR supply During the stakeholder consultations, it was suggested by a stakeholder that the RtR framework should accommodate a model which would permit a LRS to connect a renewable low impact generator directly to a nu...
AI summary The document discusses a proposed model for Behind-the-Meter (B-t-M) Real Time Retail (RtR) supply, where a Local Resource Supplier (LRS) connects renewable generators to multiple customers behind a single NS Power meter. This could shift cost burdens to NS Power and its remaining customers, conflicting with the 'no-harm' provisions of the Electricity Act.
• And in the micro-grid configuration: - o customer monthly charges on all but one customer; and - o an amount that could arise from consolidation of customer load shape (whereby the diversity is lost to NS Power) and possibly from the cus...
AI summary The text discusses the micro-grid configuration and the implications of customer load shape consolidation and customer class differences. It references the Retailers Regulations from 2015, which classify B-t-M as a form of RtR supply, requiring LRS to execute an LRS Participation Agreement and be subject to RtR tariffs rather than Bundled Service tariffs. Two methods to meet the no-harm requirement are outlined: secondary metering and enhanced recovery of embedded costs.
4.3 Rates and Expense Recovery As noted in the 2014 Cost-of-Service analysis[10,](#page-78-3) the revenue recovery per retail rate class varies from 4.4% below allocated expense for the Large Industrial class to 4.4% above allocated expens...
AI summary The document discusses revenue recovery ratios for different retail rate classes, noting small variations from allocated expenses due to historical rate development and policy continuity. Recovery ratios are determined at the Bundled Service level, but not directly applied to the Distribution Tariff, which is set for a 1.00 recovery ratio across all classes.
5.1 Context The supply-related cost represents the largest component of the existing cost of Bundled Service, as it includes the asset-related cost (including financing and return on equity) of all generating plant, the fixed and variable...
AI summary The supply-related cost is the largest component of the Bundled Service cost, including asset-related costs, O,M & G costs, and fuel costs. To avoid economic disadvantage, NS Power must recover the same amount from RtR customers as would have been recovered from Bundled Service customers, adjusted for avoided costs. Recovery will occur through Energy Balancing Service, Standby Service, and RtR Market Transition Tariff revenue.
5.3.2 Interaction with Imbalance Tariff OATT Schedule 4 services cover the differences in the Wholesale Market between the scheduled and the actual supply-demand balance (for single point services) or between scheduled and actual quantitie...
AI summary The document discusses the interaction between top-up and spill tariffs with the OATT Schedule 4 imbalance tariff, considering two options to avoid double counting of deviations. It outlines the implications of each option, including cost, benefits, incentives, and complexity, and proposes a forecast discrepancy schedule (Schedule 4A) for the RtR Market.
Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 33 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) fee would be based on each customer's historic load and class, using a rate that might be adjusted from time to time but with...
AI summary The text discusses the method for calculating fees based on a customer's historic load and class, with the rate potentially adjusted over time but without retroactive changes.
8.2.3 Exit fee Characteristics of an exit fee would be: - Predetermined for each customer on exit; - Charges per unit of historic energy consumption and demand set for each customer class in advance and capable of annual adjustment for app...
AI summary The text outlines the characteristics of an exit fee, including its predetermined nature, charges based on historic energy consumption, and the need for estimates regarding generation technology, demand-supply balance, and stranding duration. It also highlights uncertainties, financial implications, and the need for defining customer and LRS responsibilities.
NON-CONFIDENTIAL 1 Request IR-1: 2 3 Refer to M12551, Exhibit N-1, the Application for the 2026 Annually Adjusted Rates (AARs) 4 submitted by NS Power (the "Application"), Section 6.1.1, BUTU Customer Charge, at pages 5 24 – 25 of 45, wher...
AI summary The document outlines a request (IR-1) regarding the justification for a 3.25 percent escalator in the BUTU Customer Charge, as part of NS Power's Application for 2026 Annually Adjusted Rates (AARs). The response explains that the escalator reflects the forecast increase in NS Power's salary costs relative to the administrative function of the AAR tariffs.
M12551, Exhibit N-1 NS Power's Application for the 2026 Annually Adjusted Rates (AARs) (the "Application"), page 25 of 45, at lines 8-20, and Appendix E2. 1 use the escalator factor is based on the 2019 Annually Adjusted Board letter decis...
AI summary NS Power's 2026 AAR application proposes a 3.25% escalation factor for administrative charges in the Spill Tariff, based on a supporting calculation in Appendix E2.1. The Board previously rejected a higher administrative cost in 2019 and directed the use of an adjusted 2018 amount. The response refers to NSEB IR-12 for justification, stating the same escalation applies to other 2026 AAR tariffs.
3 1 Request IR-5: 2 3 Refer to M12551, Exhibit N-1, the Application, Section 7.2 Standby Service Tariffs and 4 Figure 10: Standby Service Tariff Charges, which shows the Administration Charge 5 ($/customer/month) of $401.58 for 2025 and $4...
AI summary The document requests an explanation for the proposed increase in the 2026 Administration Charge for standby service tariffs, asking if it reflects the same 3.25 percent increase applied in other AAR tariffs and requesting supporting calculations. The response confirms the increase and refers to NSEB IR-12 and SBA IR-2 for further details.
Please refer to: Michael Murphy Email: [[email protected]](mailto:[email protected]) Assistant: Alissa Whalen Assistant's email: [[email protected]](mailto:[email protected]) January 20, 2026 VIA EMAIL Crystal Henwood,...
AI summary The Consumer Advocate submits that they do not object to NS Power's 2026 annually adjusted tariff rates application, but wishes to comment on the modelling of power imports and NS Power's justification for the change in the 1P-RTP method.
January 20, 2026 VIA EMAIL Ms. Crystal Henwood Clerk of the Board Nova Scotia Energy Board 1601 Lower Water Street, 3rd Floor Halifax NS B3J 3 S3 Dear Ms. Henwood: Re: M12551 - Nova Scotia Power Incorporated -Application for Approval of 20...
AI summary Nova Scotia Power Incorporated (NS Power) has submitted an application for approval of its 2026 Annually Adjusted Rates (AARs), including the ELIADC Tariff. The Small Business Advocate (SBA) has raised concerns regarding the ELIADC Tariff and refers to its prior comments in M12184.
Risk Tran sf er The SBA recognizes that the AARs have historically included updates to marginal cost rates and administrative charges, however, there remains the possibility of asymmetric risk in the presence of highly volatile marginal co...
AI summary The SBA highlights the risk of asymmetric risk due to volatile marginal cost forecasts and data limitations from a cyber incident, emphasizing the need for transparency and class-level rate impact analysis from proposed AAR rate changes.
Administrative Costs With respect to administrative costs, the SBA recognizes that the Board has previously permitted escalation of administrative costs by an inflationary factor in M09866. 6 The factor utilized in this 2 M12184 Exhibit N-...
AI summary The SBA acknowledges the Board's previous allowance for administrative cost escalation based on an inflationary factor but notes that the current proposed factor (3.25%) is higher than the reported inflation rate (2.2%). NS Power argues the factor includes non-inflationary considerations related to competitiveness in the job market. The SBA suggests further justification may be needed to maintain administrative cost discipline.
James A. MacDuff Direct +1 (902) 444 8619 [email protected] Purdy's Wharf Tower II 1300-1969 Upper Water Street PO Box 730 Halifax NS Canada B3J 2V1 Tel +1 (902) 425 6500 Fax +1 (902) 425 6350 January 20, 2026 Ms. Crystal Hen...
AI summary The Berwick Electric Commission, Riverport Electric Light Commission, and the Towns of Antigonish and Mahone Bay submit comments to the Nova Scotia Energy Board regarding NS Power's 2026 Annually Adjusted Rates and associated tariffs. The submission is in response to NS Power's application filed on November 7, 2025.
In its 2026 Application, NS Power requested approval of 2026 BUTU Tariff Charges as shown in Figure 7 on page 27 as follows: 2025 2026 Variance Customer Charge ($/customer/month) 401.58 414.63 13.05 Energy Charge (cents per kWh) 10.577 9.1...
AI summary NS Power has requested approval for the 2026 BUTU Tariff Charges, which include changes to customer, energy, and demand charges. Additionally, approval for the 2026 Spill Tariff Charges was requested, involving adjustments to administration and energy credit rates.
Choice of Non-Reciprocal Billing Arrangement At page 3 of its decision approving the 2025 BUTU Tariff and Spill Tariff charges (Matter M11989), the Board highlighted the change to the service arrangement under the BUTU Tariff in 2025, with...
AI summary The document discusses the implementation of a non-reciprocal billing arrangement under the BUTU Tariff in 2025, following the elimination of reciprocal top-up and spill energy by the More Access to Energy Act. The MEUs and AREA have not yet issued invoices for the 2025 charges, and NS Power is awaiting decisions on the 2026-27 GRA and 2026 AARs to determine the billing arrangement for 2026.
January 20, 2026 James A. MacDuff Direct +1 (902) 444 8619 [email protected] Purdy's Wharf Tower II 1300-1969 Upper Water Street PO Box 730 Halifax NS Canada B3J 2V1 Tel +1 (902) 425 6500 Fax +1 (902) 425 6350 Ms. Crystal Hen...
AI summary Port Hawkesbury Paper supports the proposed 2026 ELIADC Energy Charge of $75.87/MWh, requesting its effective date be January 1, 2026. They filed for interim approval, which NS Power and others do not oppose, though the Consumer Advocate and Industrial Group question the timing of the effective date.
ile all others await the Board's final decision. This piecemeal approach is particularly inappropriate in the context of a rate that is already in flux and subject to multiple concurrent proceedings." The rates paid by the General, Large I...
AI summary PHP requests approval of the 2026 ELIADC Energy Charge of $75.87/MWh, noting that the rate is not in flux as the ELIADC Tariff has been approved for a third term. The approval of AARs is not contingent on alignment with rate increases for Above-the-Line customers. The ELIADC rate is subject to amendment by the Board's final 2026 AAR Decision and Order.
Via Electronic Mail Crystal Henwood Regulatory Affairs Officer/Clerk Nova Scotia Energy Board 3rd Floor, 1601 Lower Water Street PO Box 1692, Unit "M" Halifax NS B3J 3S3 Dear Ms. Henwood: Re: M12551 - NSPI - 2026 Annually Adjusted Rates (A...
AI summary Renewall Energy Inc. (REI), the sole Licensed Retail Supplier in Nova Scotia's Renewable to Retail market, submits comments on NSPI's 2026 AAR application, opposing the use of an unapproved Cost of Service Study and proposing changes to tariff methodologies and reporting requirements.
Only a Board-Approved COSS should be used in setting AARs The 2026 AAR rates should reflect the Board-approved COSS methodology rather than the unapproved 2026 COSS. NSPI's application relies on this unapproved methodology without offering...
AI summary The 2026 AAR rates should be based on a Board-approved COSS methodology, not the unapproved 2026 COSS. NSPI's reliance on the unapproved methodology undermines regulatory oversight and fairness, and REI opposes the premature use of the 2026 COSS in setting AAR rates.
The AAR Application is not the Forum to apply new Cost Allocation Methods The AAR process is designed to be streamlined and formula-driven. Introducing an unapproved COSS that incorporates significant methodological changes is inconsistent...
AI summary The AAR process is intended to be streamlined and formula-driven, and introducing an unapproved COSS with significant methodological changes is inconsistent with this framework. NSPI has not provided sufficient justification for applying the new methodology in the AAR context, risking incorrect cost allocations in customer rates.
No True-Up Mechanism Exists to Correct for any COSS Changes NSPI sets the AARs using forecasts that, with the exception of the ELIADC Tariff, are not subject to a true-up. While the Board has previously found that the absence of a true-up...
AI summary The document highlights the absence of a true-up mechanism to correct for changes in the Cost of Service Study (COSS) methodology, which could lead to regulatory asymmetry and risk. REI recommends using the currently approved COSS methodology for setting 2026 AAR rates to avoid methodological risk and ensure rates reflect Board-approved cost allocations.
Material Impact on RTT Rates The marginal cost calculation, combined with the COSS methodology changes, significantly impact the 2026 RTT charge. The RTT Total Energy Charge is proposed to increase from 0.802 cents/kWh (2025) to 4.363 cent...
AI summary The 2026 RTT charge is expected to increase significantly due to changes in the COSS methodology and the impact of the SO2 CoV. This increase has led to a 444.3% rise in the Energy Charge and a 60.5% increase in the Demand Charge, creating financial risks for REI and affecting market competition.
The Marginal Costs Proposed in the 2026 AAR Application are Unsupportable REI takes particular issue with NSPI's forecasting inputs of marginal costs in setting AAR amounts. Within this Application, the average annual marginal cost forecas...
AI summary REI challenges NSPI's 2026 AAR application, citing a 24% reduction in forecasted marginal costs from 2025 and expressing concerns about the lack of historical validation, asymmetric risk allocation, and monthly variability in these costs.
n this proceeding for 2025 illustrates the volatility of marginal generation and the inaccuracy of the assumptions used,[19](#page-6-0) and yet only represent one aspect of the marginal cost accuracy. NSPI's failure to analyze or model the...
AI summary The document highlights NSPI's failure to analyze and model the accuracy of annual versus monthly marginal cost pricing, despite having access to historical data. This lack of transparency and validation increases risk for RtR customers and undermines forecasting accuracy.
(b) Asymmetric Forecasting Risk Impacts While the Board has recognized the reasonableness of setting AAR rates based on forecasts given that both parties bear forecast risk, this risk-sharing disproportionately impacts REI. Theoretically t...
AI summary The document discusses the asymmetric impact of forecasting risks on REI and NSPI, highlighting that while both parties theoretically share forecast risk, the actual financial burden falls disproportionately on REI. A significant increase in the RTT Tariff due to forecast errors results in substantial costs for REI, unlike NSPI, whose earnings remain unaffected due to the FAM mechanism.
(c) Marginal Costs should be Reviewed and Calculated Monthly Going Forward NSPI uses annual average marginal costs for AAR tariffs, which obscures material monthly variation and results in cross-subsidization among months. REI is not propo...
AI summary NSPI uses annual average marginal costs for AAR tariffs, which obscures monthly variation and causes cross-subsidization. REI argues that monthly marginal cost forecasting would improve accuracy, align cost recovery with cost causation, and provide better price signals. NSPI dismisses monthly pricing as immaterial, but REI disagrees, emphasizing the importance of cost causation regardless of customer response.
3. INCORRECT SS TARIFF VALUES AND METHODOLOGY NSPI has applied for approval of a Demand Charge under the SS Tariff of $5.452/kW, representing a variance of $2.055/kW from 2025.[30](#page-8-6) Appendix F3 provides the explanation for this C...
AI summary NSPI has applied for approval of a Demand Charge under the SS Tariff at $5.452/kW, but the calculation is based on incorrect values and a changed methodology involving an additional Interruptible Credit cost. Discrepancies are noted between Appendix F3 and the 2026-2027 GRA Application exhibits.
4. IMPROVED MINIMUM REPORTING FOR AAR APPLICATIONS The ability to review NSPI's forecasting accuracy year over year is essential to promote transparency, accountability and improve forecasting. 4138-8807-8436 [ 31 ](#page-9-1) See : N-1(i)...
AI summary The document discusses the need for improved minimum reporting in Annually Adjusted Rates (AAR) applications, emphasizing the importance of transparency and accuracy in NSPI's forecasting. REI requests that NSPI report on forecasted versus actual monthly and hourly marginal costs and provide explanations for variances. NSPI currently tracks hourly marginal units by generator but lacks detailed fuel-type data due to a cybersecurity incident.
CONCLUSION REI respectfully requests that the Board direct NSPI to: 1. Recalculate the 2026 AAR rates using the most recently approved COSS methodology rather than the unapproved 2026 COSS, or alternatively, make the 2026 AAR rates interim...
AI summary REI requests the Board to direct NSPI to recalculate 2026 AAR rates using the approved COSS methodology, initiate a tariff amendment proceeding for RtR tariffs, address errors in SS Tariff Demand Charges, and provide forecast versus actual marginal cost data for 2021–2026.
2026 Annually Adjusted Rates (AARs) NS Power Reply Evidence January 27, 2026 Non-confidential
AI summary This document is NS Power's reply evidence submitted on January 27, 2026, related to the 2026 Annually Adjusted Rates (AARs). It is part of a regulatory proceeding and is non-confidential.
1.0 INTRODUCTION On November 7, 2025, NS Power Incorporated (NS Power, Company) filed its Application for the 2026 Annually Adjusted Rates (AARs) with the Nova Scotia Energy Board (NSEB, Board). The Company requested approval of the follow...
AI summary NS Power filed an application for 2026 Annually Adjusted Rates (AARs) with the Nova Scotia Energy Board. The application includes several tariff rates, and responses from various stakeholders have been received. Most parties support the proposed rates, except for Renewall Energy Incorporated, which raised concerns related to the SS Tariff. The Consumer Advocate and Municipal Electric Utilities expressed support for the proposed charges.
3.0 EVIDENCE OF THE SMALL BUISNESS ADVOCATE - The SBA framed its evidence and submissions around risk allocation, administrative cost - discipline, and process considerations. The SBA provided:
AI summary The Small Business Advocate (SBA) presented evidence focusing on risk allocation, administrative cost discipline, and process considerations in the regulatory proceeding.
Risk Transfer The SBA recognizes that the AARs have historically included updates to marginal cost rates and administrative charges, however, there remains the possibility of asymmetric risk in the presence of highly volatile marginal cost...
AI summary The SBA highlights concerns about asymmetric risk in AARs due to volatile marginal cost forecasts and data limitations from a cyber incident. It argues that bundled service and small business customers bear the risk when forecast assumptions do not align with outcomes, emphasizing the need for transparency and class-level rate impact analysis.
M12551, Exhibit N-9, NS Power 2026 AARs, SBA Submissions, January 20, 2026, page 2. 1 The SBA provided: Cross Subsidization
AI summary The SBA submission discusses the issue of cross subsidization in the context of NS Power's 2026 AARs. This theme highlights potential inequities in how different customer groups may be financially supported or burdened by the rate structure.
Administrative Costs With respect to administrative costs, the SBA recognizes that the Board has previously permitted escalation of administrative costs by an inflationary factor in M09866. The factor utilized in this proceeding of 3.25% i...
AI summary The SBA acknowledges the Board's previous allowance for administrative cost escalation but questions the 3.25% inflationary factor, which exceeds Statistics Canada's 2.2% rate. NS Power argues the factor reflects more than just inflation, citing competitiveness in the job market. The SBA suggests further justification is needed to maintain administrative cost discipline.
DATE FILED: January 27, 2026 Page 13 of 22 1 5.0 EVIDENCE OF RENEWALL ENERGY INC. 2 3 REI framed its evidence and submission around the use of the proposed Cost of Service Study 4 (COSS) methodology, RtR Tariff review and design, SS Tariff...
AI summary REI submitted evidence related to the proposed Cost of Service Study (COSS) methodology, RtR Tariff review, and SS Tariff calculations. REI requested the recalculation of 2026 AAR rates using the most recently approved COSS methodology or that the rates be interim. NS Power responded that the 2026 COSS was developed collaboratively with Customer Representatives and that the 2026-2027 GRA proposed methodology remains open for the Board's final determination.
DATE FILED: January 27, 2026 Page 14 of 22 M12551, Exhibit N-12, NS Power 2026 AARs, REI Submissions, January 21, 2026, pages 11-12. REI which was an intervenor in M12451, did not comment or raise any concerns in that proceeding regarding...
AI summary REI, an intervenor in M12451, did not comment on the proposed 2026 COSS. REI requested changes to the RtR tariff framework and expanded marginal cost reporting. NS Power responded that the AAR process is not the appropriate forum for structural tariff redesign.
Company notes that the nature of utility pricing and tariffs is that these are subject to change within, and across, years as cost drivers and market conditions change. Concerning REI's fourth request, the Company's position is that these...
AI summary The Company argues that annual applications provide sufficient marginal cost information for the AAR process, as detailed in Section 2.0 and Appendices A2 through A7. The text references several exhibits and board decisions related to the 2026 AAR Application.
7.0 CONCLUSION NS Power respectfully submits that: 1. With the exception of REI's concerns related specifically to the SS Tariff, which the Company addressed in Section 5.0, no party opposed the Company's proposed annually adjusted tariff...
AI summary NS Power concludes its submission by stating that no party opposed the proposed 2026 annually adjusted tariff rates, except for REI's concerns regarding the SS Tariff, which were addressed. The 2026 AARs assume no RtR market activity in 2026, with recovery beginning in 2027. Remaining issues are administrative and do not hinder the approval of the 2026 AARs.
8.0 RELIEF SOUGHT - In addition of the relief sought in the Application, NS Power respectfully requests that the proposed - 2026 charges under the BUTU and SS tariffs, be amended as per Attachments 5 and 7 to this - submission. DATE FILED:...
AI summary NS Power is requesting amendments to the 2026 charges under the BUTU and SS tariffs, as outlined in Attachments 5 and 7 of their submission.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: This charge will be $401.58414.63 per month.
AI summary The monthly administration charge for Load Replacement Service (LRS) is set annually and is currently calculated to be $401.58414.63 per month.
MINIMUM MONTHLY CHARGE The minimum monthly charge will be the administration charge.
AI summary The minimum monthly charge is defined as the administration charge within the regulatory proceeding.
DETERMINATION OF MONTHLY STANDBY CONTRACT DEMAND Monthly Standby Contract Demand (MSCD) in kW is determined using the following formula: $$MSCD = LWPFD - min (LWPFD, (\sum_{ij=1}^{nn} CCi GCi)/(1+PR))$$ Where: "LWPFD" is LRS Winter Peak Fi...
AI summary The Monthly Standby Contract Demand (MSCD) is calculated using a formula involving LRS Winter Peak Firm Demand (LWPFD) and other variables, with LWPFD itself determined by a summation of weighted firm demand factors.
Classes Jan, Feb, Dec Mar, Apr May, Jun Jul, Aug, Sep Oct, Nov Domestic 1.00 1.00 1.34 1.27 2.13 1.67 2.26 2.17 1.65 1.47 Small General 1.00 1.00 1.24 1.21 1.62 1.32 1.59 1.09 1.35 1.28 General 1.00 1.00 1.21 1.12 1.47 1.32 1.36 1.05 1.20...
AI summary The document presents a table showing rate adjustments for various classes of electricity consumers in Nova Scotia across different months. The rates are marked with underlines and deletions, indicating changes and adjustments over time.
CUSTOMER CHARGE The monthly customer charge under this tariff is calculated according to the following formula: Monthly customer charge = $$\frac{\text{forecast annual administration costs}}{\text{forecast number of customers subscribed 12...
AI summary The monthly customer charge is calculated using forecast annual administration costs divided by the forecast number of customers subscribed multiplied by 12, resulting in a charge of $401.58414.63 per month.
- (2) Demand-related fixed generation cost, coming into effect as a result of a General Rate Application. Demand Charge Components $ per kW of billing demand Demand-related Purchased Power Cost $4.3686.252 Demand-related Fixed Generation C...
AI summary The text outlines a demand-related fixed generation cost introduced through a General Rate Application. It includes a table with demand charge components, specifying costs per kW of billing demand, and defines Contract Demand requirement as the firm demand requested by a wholesale customer and agreed to be supplied by NSPI.
ENERGY CHARGE The energy charge is made up of the following two components: - (1) Annually adjusted energy-related purchased power and fuel cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism or General R...
AI summary The energy charge consists of two components, one of which is annually adjusted energy-related purchased power and fuel cost, influenced by factors such as Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
- (2) Energy-related fixed generation cost, coming into effect as a result of a General Rate Application. Energy Charge Components cents per kWh Energy-related Purchased Power and Fuel Cost 7.9266.984 Energy-related Fixed Generation Cost 2...
AI summary The document outlines the energy-related fixed generation cost, which is part of a General Rate Application. It includes a table showing the breakdown of energy charge components, with energy-related fixed generation cost listed as 2.6512.166 cents per kWh.
CUSTOMER CHARGE The monthly customer charge under this tariff is calculated according to the following formula: Monthly customer charge = $$\frac{\text{forecast annual administration costs}}{\text{forecast number of customers subscribed 12...
AI summary The monthly customer charge under the tariff is calculated using a formula that divides forecast annual administration costs by the forecast number of customers multiplied by 12, resulting in a charge of $414.63 per month.
Confidential (Attachments only) Crystal Henwood Clerk of the Board Nova Scotia Energy Board 1601 Lower Water Street, 3rd Floor Halifax, NS B3J 3S3 Re: M12551 2026 Annually Adjusted Rates – Compliance Filing Dear Ms. Henwood: Nova Scotia Po...
AI summary Nova Scotia Power submitted its 2026 Annually Adjusted Rates (AAR) Application on November 7, 2025. The Nova Scotia Energy Board approved the application on March 9, 2026, subject to potential amendments based on the GRA decision. The Board's March 11, 2026 Order outlines this approval.
NS Power is directed as follows: 1. If the updated Cost of Service Study is not approved as filed, currently before the Board in the NS Power GRA matter M12451, NS Power is directed to make any required adjustments to the 2026 AARs in a co...
AI summary NS Power is required to file a compliance filing for the 2026 AARs following the Board's decision in the GRA matter M12451. The Board approved an extension of the filing deadline to two weeks after the Board's Order in M12451 was issued on April 30, 2026.
Revised AAR Tariffs and Rates The Company has updated the applicable AAR Tariffs and rates to reflect the M12451 COSS changes. The following AAR Tariffs required revision: - One-Part Transmission Real-Time Pricing Tariff (1P T-RTP); - One-...
AI summary Nova Scotia Power has revised several AAR Tariffs to reflect changes from M12451 COSS. Specific tariffs requiring updates include 1P T-RTP, 1P DV-RTP, Shore Power, BUTU, RTR EBS, RTR SS, and RTR RTT. Some tariffs, such as GRLF and Spill, remained unchanged. Supporting data and confidentiality justifications are consistent with the 2026 AAR Application.
Table 1 – References to Supporting Data and Calculations for Revised 2026 AARs Tariff Supporting Data & Calculations GRLF Not applicable; no changes required. 1P T-RTP Appendix B2 1P DV-RTP Appendix B2 Shore Power Appendix C BUTU Appendix...
AI summary The document outlines references to supporting data and calculations for the Revised 2026 AARs, detailing which tariffs are associated with specific appendices and noting that certain tariffs do not require changes. The compliance filing includes additional appendices.
- Appendix A clean versions of revised 2026 AAR Tariff sheets - Appendix D Cost of Service - Appendix E4 BCF Allocation - Appendix G an electronic copy of updated figures provided in the 2026 AAR Application - Appendix H redline versions o...
AI summary The document outlines the submission of revised 2026 AAR Tariff sheets, including clean and redline versions, following the Board's March 11, 2026 Order approving AARs effective April 1, 2026, subject to GRA Decision amendments.
2026 AAR Compliance Filing Appendix A Page 1 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) ONE PART TRANSMISSION REAL TIME PRICING TARIFF Page 1 of 3
AI summary The document is the 2026 AAR Compliance Filing Appendix A, part of a transmission real-time pricing tariff, with confidential information redacted. It is the first page of a 25-page document.
ENERGY CHARGE NSPI's actual hourly marginal energy costs, plus the following fixed cost adders for on-peak and offpeak usage: On-peak (7:00 am – 11:00 pm, non-holiday weekdays): 5.274 ¢/kWh Off-peak (11:00 pm – 7:00am, non-holiday weekdays...
AI summary NSPI's energy charge includes on-peak and off-peak fixed cost adders, with weekend and holiday rates set at the off-peak price. These adders are developed annually and submitted to the Nova Scotia Energy Board for approval. A credit is provided for customers owning transformers based on monthly peak demand.
ENERGY CHARGE NSPI's actual hourly marginal energy costs, plus the following fixed cost adders for on-peak and offpeak usage: On-peak (7:00 am – 11:00 pm, non-holiday weekdays): 9.925 ¢/kWh Off-peak (11:00 pm – 7:00am, non-holiday weekdays...
AI summary NSPI sets energy charges with on-peak and off-peak rates, with weekend and holiday rates aligned to off-peak prices. Annual adjustments are submitted to the Nova Scotia Energy Board for approval, and a credit is applied for customer-owned transformers based on peak demand.
- (2) A fixed cost adder adjusted concurrent with changes in base cost rates coming into effect as a result of a General Rate Case application. Base Energy Charge Components Transmission Voltage of 69 kV or Higher (cents per kWh) Distribut...
AI summary The text outlines a fixed cost adder that is adjusted in tandem with changes in base cost rates resulting from a General Rate Case application. A table provides base energy charge components, including fuel cost and fixed cost adder at different voltage levels.
Penalty for Non-Compliance All energy served after the 10-minute deadline has expired will be billed at $5.00 per kWh. In addition a fixed charge of $2,000.00 will be applied. The penalty charge is applicable above and beyond the Port Auth...
AI summary A penalty of $5.00 per kWh and a fixed charge of $2,000.00 is imposed for energy served after the 10-minute deadline, in addition to the Port Authority's monthly bill.
2026 AAR Compliance Filing Appendix A Page 11 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) WHOLESALE MARKET BACKUP/TOP-UP SERVICE TARIFF Page 1 of 6
AI summary This document is a page from a compliance filing related to the 2026 Annually Adjusted Rates (AAR) process, specifically discussing the Wholesale Market Backup/Top-Up Service Tariff. The content is partially redacted due to confidentiality concerns.
CUSTOMER CHARGE The monthly customer charge under this tariff is calculated according to the following formula: Monthly customer charge = $$\frac{\text{forecast annual administration costs}}{\text{forecast number of customers subscribed 12...
AI summary The monthly customer charge is calculated based on forecast annual administration costs divided by the forecast number of customers subscribed, resulting in a charge of $414.63 per month.
- (2) Demand-related fixed generation cost, coming into effect as a result of a General Rate Application. Demand Charge Components $ per kW of billing demand Demand-related Purchased Power Cost $6.222 Demand-related Fixed Generation Cost $...
AI summary The document outlines the introduction of a demand-related fixed generation cost as part of a General Rate Application. It includes a table showing the cost components, specifically the demand-related purchased power cost and demand-related fixed generation cost, which together total $11.822 per kW of billing demand.
ENERGY CHARGE The energy charge is made up of the following two components: - (1) Annually adjusted energy-related purchased power and fuel cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism or General R...
AI summary The energy charge consists of two components, primarily the annually adjusted energy-related purchased power and fuel cost, which is influenced by mechanisms such as the Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
- (2) Energy-related fixed generation cost, coming into effect as a result of a General Rate Application. Energy Charge Components cents per kWh Energy-related Purchased Power and Fuel Cost 6.974 Energy-related Fixed Generation Cost 2.155...
AI summary This section discusses the implementation of energy-related fixed generation cost as part of a General Rate Application. A table outlines the breakdown of energy charge components, including energy-related purchased power and fuel cost, and energy-related fixed generation cost, totaling 9.129 cents per kWh. The Fuel Adjustment Mechanism (FAM) is also introduced.
MINIMUM MONTHLY CHARGE The minimum monthly charge will be the customer charge plus the demand charge.
AI summary The minimum monthly charge is defined as the sum of the customer charge and the demand charge.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: Monthly charge = forecast annual administration costs forecast number of LRS' subscribed \ 12 This ch...
AI summary The monthly administration charge is set annually for each Load Serving Retailer (LRS) based on forecasted annual administration costs and the number of LRSs. The charge is currently set at $414.63 per month.
SPECIAL CONDITIONS - (1) NS Power reserves the right to have a separate service agreement, if in the opinion of NS Power issues not specifically set out herein, must be addressed for the ongoing benefit of NS Power and its customers. - (2)...
AI summary NS Power reserves the right to enter into separate service agreements when necessary for the benefit of its customers and the power supply system. LRS' RtR Customers and generators must ensure their operations do not compromise system integrity, with specific requirements outlined in written operating agreements. NS Power may apply to the Nova Scotia Energy Board for changes to rates, terms, and conditions.
2026 AAR Compliance Filing Appendix A Page 20 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) STANDBY SERVICE TARIFF Page 1 of 4 Renewable to Retail
AI summary This document is part of a 2026 AAR Compliance Filing and includes a Standby Service Tariff titled 'Renewable to Retail'. The text is redacted, and no further details are provided.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: Monthly charge = forecast annual administration costs forecast number of LRS' subscribed \ 12 This ch...
AI summary The monthly administration charge is calculated annually based on forecasted administration costs and the number of Load Serving Retailers (LRS) subscribed, resulting in a fixed monthly charge of $414.63.
2026 AAR Compliance Filing Appendix A Page 23 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) STANDBY SERVICE TARIFF Page 4 of 4 Renewable to Retail (4) Nothing contained in this Standby Service Tariff or any service agreement shall be c...
AI summary This section of the Standby Service Tariff states that NS Power retains the right to apply to the Nova Scotia Energy Board for changes to rates, terms, and conditions, including those in the Standby Service Tariff, Energy Balancing Service Tariff, and Renewable to Retail Market Transition Tariff.
PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...
AI summary This Renewable to Retail Market Transition Tariff (RTT) is established under the Electricity Act to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing, return on equity, income tax, and OM&G, and are approved for recovery by the Nova Scotia Energy Board.
SPECIAL CONDITIONS Effective: April 1, 2026 (1) Nothing contained in this RTT or any service agreement shall be construed as affecting or in any way limiting the right of NS Power to make application to the Nova Scotia Energy Board for a c...
AI summary This special condition, effective April 1, 2026, ensures that NS Power retains the right to apply to the Nova Scotia Energy Board for changes to rates, terms, and conditions, including those in the RTT, Standby Service Tariff, and Energy Balancing Service Tariff.
Scenario A UNIT POWER PRODUCTION COSTS RTP Avoided Costs On Scenario A (2024) Monthly Hours in 2025 Off Total Ave MC On Off RTP Ave Hourly KW Req On Off Total RTPKWh Req On Off Total Sales On Off Total Jan Feb Mar Apr May Jun Jul Aug Sep O...
AI summary Scenario A outlines unit power production costs and RTP avoided costs for 2024 and 2025, detailing monthly hours, average costs, and other metrics. It includes data for each month and compares on and off scenarios. Scenario B provides similar data for 2026 with additional details on monthly hours and total costs.
Case 2023 GRA 2026 GRA COS COS TEMPLATE TEMPLATE % COL 1 COL 2 Variance Fixed Generation Costs OM&G $135,308,637 $141,523,198 4.6% Capital $231,659,690 $194,573,460 -16.0% ROE $101,798,828 $88,981,576 -12.6% $468,767,155 $425,078,233 -9.3%...
AI summary The document presents a comparative analysis of fixed generation, transmission, and distribution costs between the 2023 and 2026 GRA (General Rate Application) scenarios, highlighting significant changes in OM&G, capital, and ROE (Return on Equity) costs, as well as overall cost variances.
Summarized Rate base from Schedule 2a in 2026 COSS INITIAL CLASSIFICATION AS PER 2026 GRA Application Filing OM&G - Other CTs 2,999 2,999 - 0% - DSM Amortization - - - 0% - FCR Deferral - - - 0% - Reg. Affairs -Advocay Expenses 1,364 617 7...
AI summary The document presents a summarized rate base from Schedule 2a in the 2026 COSS, detailing various classifications such as OM&G, DSM amortization, FCR deferral, and expenses related to generation, transmission, and distribution. It includes figures for different asset categories, depreciation, and revenue components.
FOR THE YEAR ENDING DECEMBER 31, 2026 (1) MWH (2) ENERGY LINE (3) ENERGY (4) CLASS NON- (5) SYSTEM (6) SYSTEM COINCIDENT COINCIDENT COINCIDENT (7) LINE (8) DEMAND SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT (10) 3CP (11) 3CP (11) SUB-TOTAL 9,8...
AI summary The table presents data for the year ending December 31, 2026, including various energy metrics such as MWH, energy line, system coincidence, and demand system. It includes subtotals and breakdowns for different classes and voltage-based service levels, such as EHV and HV.
EXHIBIT 2A Page 3 of 3 NOVA SCOTIA POWER INC.
AI summary The document is an exhibit from a regulatory proceeding involving Nova Scotia Power Inc. It is part of a larger submission and appears to be related to a rate application or financial disclosure.
CLASSIFICATION OF AVERAGE RATE BASE (1) (2) (3) (4) (5) (6) (7) (8) (9) (47) CASH - OTHER 0 0 162,574 0 0 0 0 0 162,574 (48) MAT. & SUPPLIES - FUEL 0 0 0 0 0 0 0 0 0 (49) MAT. & SUPPLIES - OTHER 0 0 658 0 0 0 0 0 658 (50) DEF. CHG Financin...
AI summary The document presents a table detailing the classification of average rate base, including various line items such as cash, materials and supplies, deferred charges, and subtotals. The table provides figures for different categories across multiple years and includes a total average rate base amount of $4,225,148.
CLASSIFICATION OF OPERATING EXPENSES (1) TOTAL COMPANY (2) DEMAND EXPENSES (3) ENERGY EXPENSES (4) CUSTOMER EXPENSES DISTRIBUTION FUNCTION (1) Before Streetlights: (2) SUBSTATIONS $2,078 $2,078 $0 - (3) OVERHEAD LINES Before Storm Expense...
AI summary The document presents a detailed breakdown of operating expenses categorized into demand, energy, and customer expenses for a utility company. It includes line items such as substation costs, overhead and underground lines, depreciation, taxes, and corporate profits and losses.
Base Cost of Fuel Cost of Service Allocation of Fuel Expenses among Rate Classes FOR THE YEAR ENDING DECEMBER 31, 2026
AI summary The document outlines the allocation of fuel expenses among rate classes for the year ending December 31, 2026, focusing on the base cost of fuel and the cost of service.
Monthly Fuel Cost Allocation Jan-26 Feb-26 Mar-26 Apr-26 May-26 Jun-26 Jul-26 Aug-26 Sep-26 Oct-26 Nov-26 Dec-26 Total General Large General $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 Small Industrial $0...
AI summary The document presents a table detailing the monthly fuel cost allocation for various customer categories in Nova Scotia from January 2026 to December 2026. All values in the table are reported as zero for most categories, except for Domestic and Small General, which show significant fuel costs.
Annual Peak of ATL 2,356,954 Annual Energy Requirement of ATL 11,303,785,142 O- 4 0-! 4 1 1 F4 Adjustment Total FAM related costs $ ($3,456,101) 99,292,393 $ ($3,456,101) 87,034,418 $ ($3,456,101) 84,132,033 $ ($3,456,101) 68,695,346 $ $16...
AI summary The text presents data on the Annual Peak and Annual Energy Requirement of ATL, along with tables showing various costs and energy generation figures. It includes information on FAM related costs, purchased biomass generation, and other energy-related metrics.
ENERGY CHARGE NSPI's actual hourly marginal energy costs, plus the following fixed cost adders for on-peak and offpeak usage: On-peak (7:00 am – 11:00 pm, non-holiday weekdays): 5.3085.274 ¢/kWh Off-peak (11:00 pm – 7:00am, non-holiday wee...
AI summary NSPI's energy charge includes hourly marginal costs and fixed adders for on-peak and off-peak usage, with weekend and holiday rates set to off-peak levels. Adders are developed annually and submitted to the Nova Scotia Energy Board for approval. A credit is applied for customer-owned transformers during peak demand.
ENERGY CHARGE NSPI's actual hourly marginal energy costs, plus the following fixed cost adders for on-peak and offpeak usage: On-peak (7:00 am – 11:00 pm, non-holiday weekdays): 10.0089.925 ¢/kWh Off-peak (11:00 pm – 7:00am, non-holiday we...
AI summary NSPI's energy charge includes on-peak and off-peak fixed cost adders, with weekend and holiday rates set at off-peak levels. These adders are developed annually and submitted for approval by the Nova Scotia Energy Board. A credit is also applied for customer-owned transformers during peak demand periods.
ENERGY CHARGE The energy charge is made up of the following two components: - (1) Annually adjusted energy-related purchased power and fuel cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism or General R...
AI summary The energy charge consists of two components, one of which is annually adjusted energy-related purchased power and fuel cost, influenced by factors such as the Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: Monthly charge = forecast annual administration costs forecast number of LRS' subscribed \ 12 This ch...
AI summary The monthly administration charge is calculated annually based on forecasted administration costs and the number of Load Serving Retailers (LRS) subscribed, resulting in a fixed monthly charge of $414.63.
- (2) Fixed cost adder reflective of fixed cost energy-related generation costs. Energy Charge Components cents per kWh Fuel Cost 6.736 Fixed Cost Adder 2.1662.155 Total 8.9028.891 The charge is applicable to top-up energy consumed in each...
AI summary The text introduces a fixed cost adder of 2.1662.155 cents per kWh, which reflects fixed cost energy-related generation costs. This charge applies specifically to top-up energy consumed in each hour, in addition to the fuel cost of 6.736 cents per kWh, resulting in a total energy charge of 8.9028.891 cents per kWh.
2026 AAR Compliance Filing Appendix H Page 20 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) STANDBY SERVICE TARIFF Page 1 of 4 Renewable to Retail
AI summary This document is part of a compliance filing related to the 2026 AAR and includes a section on the Standby Service Tariff. The content is partially redacted, and key details are omitted due to confidentiality.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: Monthly charge = forecast annual administration costs forecast number of LRS' subscribed \ 12 This ch...
AI summary The monthly administration charge is calculated annually based on forecasted administration costs and the number of Load Serving Retailers (LRS) subscribed, resulting in a fixed monthly charge of $414.63.
2026 AAR Compliance Filing Appendix H Page 23 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) STANDBY SERVICE TARIFF Page 4 of 4 Renewable to Retail (4) Nothing contained in this Standby Service Tariff or any service agreement shall be c...
AI summary This section of the Standby Service Tariff outlines that NS Power retains the right to apply to the Nova Scotia Energy Board for changes to rates, terms, and conditions, including those related to the Standby Service Tariff, Energy Balancing Service Tariff, and Renewable to Retail Market Transition Tariff.
PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...
AI summary This Renewable to Retail Market Transition Tariff (RTT) is established under the Electricity Act to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing, return on equity, income tax, and OM&G, and are approved for recovery by the Nova Scotia Energy Board.
The Energy Charge is made up of the following components: Energy Charge Components cents per kWh Fixed Cost Adder from Energy Balancing Service Tariff 2.1662.155 Annually Adjusted Energy Savings Credit 0.000 Annual Energy Cost Adjustment 2...
AI summary The Energy Charge is composed of several components, including a Fixed Cost Adder, an Annually Adjusted Energy Savings Credit, and an Annual Energy Cost Adjustment. It applies to the LRS' monthly displaced energy on NS Power's generation system, calculated as the total monthly LRS load minus the top-up quantity determined under the Energy Balancing Service Tariff.
November 10, 2025 [[email protected]](mailto:[email protected]) Michael Willet Director, Regulatory Finance Nova Scotia Power Inc. PO Box 910 Halifax, NS B3J 2W5 Dear Mr. Willet: M12551 - Nova Scotia Power Inc. 2026 Annua...
AI summary Nova Scotia Power Inc. submitted its 2026 Annually Adjusted Rates for approval, including various tariffs. The Board has approved the confidentiality undertaking and will review the matter as a paper proceeding with specific timelines for interventions, information requests, and submissions.
[[email protected]](mailto:[email protected]) Michael Willett Director, Regulatory Finance Nova Scotia Power Inc. PO Boc 910 Halifax, NS B3J 3S8 Dear Mr. Willett: M12551 – Nova Scotia Power Inc. – 2026 Annually Adjusted R...
AI summary Nova Scotia Power Inc. is preparing to file its 2026 Annually Adjusted Rates (AARs) application, as directed by the Nova Scotia Utility and Review Board (NSUARB) in matter M11989. The NSUARB was succeeded by the Nova Scotia Energy Board following the proclamation of the Energy and Regulatory Boards Act on April 1, 2025.
Conclusion The Board approves the AARs as filed, subject to retaining jurisdiction to make amendments if adjustments are required to them as a result of the GRA decision. The Board approves the ELIADC tariff, on an interim basis effective...
AI summary The Board approves the AARs with an interim effective date and final effective date of April 1, 2026, and issues several directives to NS Power, including revising sensitivity analyses, providing data on inflation adjustments, and initiating stakeholder engagement on tariff amendments.
IN THE MATTER OF THE PUBLIC UTILITIES ACT - and - IN THE MATTER OF AN APPLICATION by NOVA SCOTIA POWER INCORPORATED for the approval of the Annually Adjusted Rates for 2026 BEFORE: Richard Melanson, LL.B. Panel Chair Jennifer L. Nicholson,...
AI summary Nova Scotia Power Incorporated has applied for the approval of annually adjusted rates for 2026 under the Public Utilities Act. The proceeding is before a panel consisting of Richard Melanson, Jennifer Nicholson, and Bruce Fisher.
ORDER On November 7, 2025, NS Power filed its application for approval of the 2026 Annually Adjusted Rates (AARs). On December 12, 2025, Port Hawkesbury Paper requested an interim order approving the 2026 Extra Large Industrial Active Dema...
AI summary NS Power applied for approval of 2026 Annually Adjusted Rates (AARs). Port Hawkesbury Paper requested an interim order for the 2026 ELIADC tariff, which was approved. The Board's decision on AARs is effective April 1, 2026, with potential amendments based on the updated Cost of Service Study.
The Board orders the following. - 1. NS Power's Annually Adjusted Rates, Schedules A to J, are approved for the period April 1, 2026, to December 31, 2026, or until such date as future rates are approved, and are attached as the following...
AI summary The Board approves NS Power's Annually Adjusted Rates for the period April 1, 2026, to December 31, 2026, or until future rates are approved. The approved rates include various schedules related to generation, transmission, distribution, and demand control.
Backup Service The actual or estimated average time coincident incremental cost of generation including transmission losses for the period service is provided plus 0.500 cents per kWh for additional Operating and Maintenance costs, service...
AI summary The Backup Service is defined by the average time coincident incremental cost of generation, including transmission losses, plus an additional 0.500 cents per kWh for Operating and Maintenance costs, service charges, and Administration & General compensation.
Optional Generation Load Following Average incremental cost of generation expressed in cents per kWh as determined by the generation forecast for the rate year plus add on charges as defined for back-up service. This price will be 7.236 ce...
AI summary The document outlines the average incremental cost of generation for the rate year, set at 7.236 cents per kWh, including add-on charges for back-up service as determined by the generation forecast.
ENERGY CHARGE NSPI's actual hourly marginal energy costs, plus the following fixed cost adders for on-peak and offpeak usage: On-peak (7:00 am – 11:00 pm, non-holiday weekdays): 5.308 ¢/kWh Off-peak (11:00 pm – 7:00am, non-holiday weekdays...
AI summary NSPI's energy charge includes on-peak and off-peak fixed cost adders, with weekend and holiday rates set at off-peak levels. These adders are annually adjusted and submitted for approval. A credit is provided for customer-owned transformers based on peak demand.
- (2) A fixed cost adder adjusted concurrent with changes in base cost rates coming into effect as a result of a General Rate Case application. Base Energy Charge Components Transmission Voltage of 69 kV or Higher (cents per kWh) Distribut...
AI summary The text discusses a fixed cost adder that is adjusted in line with changes in base cost rates resulting from a General Rate Case application. The table provides breakdowns of base energy charges, including fuel costs and fixed cost adders for different voltage levels.
Penalty for Non-Compliance All energy served after the 10-minute deadline has expired will be billed at $5.00 per kWh. In addition a fixed charge of $2,000.00 will be applied. The penalty charge is applicable above and beyond the Port Auth...
AI summary The document outlines penalties for non-compliance with energy service deadlines, including a $5.00 per kWh charge for energy served after the 10-minute deadline and a fixed charge of $2,000.00, applicable in addition to the Port Authority's monthly bill.
- (2) Demand-related fixed generation cost, coming into effect as a result of a General Rate Application. Demand Charge Components $ per kW of billing demand Demand-related Purchased Power Cost $6.252 Demand-related Fixed Generation Cost $...
AI summary The text introduces a demand-related fixed generation cost, effective due to a General Rate Application. It outlines a table with components of the demand charge, including purchased power cost and fixed generation cost, and defines the Contract Demand requirement as the firm demand requested by a wholesale customer and agreed to be supplied by NSPI.
- (2) Energy-related fixed generation cost, coming into effect as a result of a General Rate Application. Energy Charge Components cents per kWh Energy-related Purchased Power and Fuel Cost 6.984 Energy-related Fixed Generation Cost 2.166...
AI summary The document outlines the energy-related fixed generation cost, which is part of a General Rate Application. It includes a table showing the breakdown of energy charge components, such as purchased power and fuel cost, and fixed generation cost, with a total of 9.150 cents per kWh. The Fuel Adjustment Mechanism (FAM) is also mentioned.
The FAM Actual Adjustment (AA) and Balance Adjustment (BA) charges or credits (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the FAM Tariff, shall apply, in addition to the energy charge.
AI summary The FAM Actual Adjustment (AA) and Balance Adjustment (BA) charges or credits, measured in cents per kilowatt-hour, are applicable to the current rate year's Tariff and are shown in the FAM Tariff, in addition to the energy charge.
AVAILABILITY The tariff is available to wholesale customers as defined in section 2(d) of the Electricity Act , Chapter 25 of the Acts of 2004. (d) "wholesale customer" means Nova Scotia Power Incorporated or a municipal utility. The tarif...
AI summary The tariff is available to wholesale customers, defined under the Electricity Act, and outlines the terms for backup/top-up service, including application procedures, timelines, and metering requirements for third-party generators.
ADMINISTRATION CHARGE The monthly administration charge under this tariff is calculated according to the following formula: Monthly customer charge = forecast annual administration costs forecast number of suppliers supplying wholesale cus...
AI summary The monthly administration charge is calculated based on forecast annual administration costs divided by the forecast number of suppliers supplying wholesale customers, multiplied by 12, resulting in a charge of $2,487.77 per month.
ENERGY CREDIT Compensation for spill energy delivered to NSPI will be at the Company's forecast average annual marginal energy costs of 6.736 cents per kilowatt hour as approved for use with the GRLF rate.
AI summary The Energy Credit section outlines that compensation for spill energy delivered to NSPI will be based on the Company's forecast average annual marginal energy costs of 6.736 cents per kilowatt hour, as approved for use with the GRLF rate.
MINIMUM MONTHLY CHARGE The minimum monthly charge shall be the administration charge.
AI summary The minimum monthly charge is defined as the administration charge in this regulatory proceeding document.
MINIMUM MONTHLY CHARGE The minimum monthly charge will be the administration charge.
AI summary The minimum monthly charge is defined as the administration charge in this regulatory proceeding.
SPECIAL CONDITIONS - (1) NS Power reserves the right to have a separate service agreement, if in the opinion of NS Power issues not specifically set out herein, must be addressed for the ongoing benefit of NS Power and its customers. - (2)...
AI summary NS Power retains the right to enter into separate service agreements when necessary to protect its interests and those of its customers. Load Serving Retailers (LRS) and their customers must ensure their operations do not compromise power system integrity, with specific requirements outlined in written agreements. NS Power may apply to the Nova Scotia Energy Board for changes to rates, terms, and conditions.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: Monthly charge = forecast annual administration costs forecast number of LRS'subscribed \ 12 This cha...
AI summary The monthly administration charge is set annually for each Load Serving Retailer (LRS) based on a formula that divides forecasted annual administration costs by the number of LRSs and multiplies by 12. The charge is set at $414.63 per month.
Classes Jan, Feb, Dec Mar, Apr May, Jun Jul, Aug, Sep Oct, Nov Domestic 1.00 1.34 2.13 2.26 1.65 Small General 1.00 1.24 1.62 1.59 1.35 General 1.00 1.21 1.47 1.36 1.20 Large General 1.00 0.99 0.93 0.86 0.99 Small Industrial 1.00 1.25 1.23...
AI summary The document presents a table of rate classes with varying percentages for different months, indicating potential variations in pricing structures or adjustments. The note mentions 'PR' as Planning Reserve based on Northeast Power Coordinating Council criteria, suggesting regulatory or planning considerations.
SEPARATE SERVICE AGREEMENT Effective: April 1, 2026 NS Power reserves the right to have a separate service agreement if, in the opinion of NS Power, issues not specifically set out herein must be addressed for the ongoing benefit of NS Pow...
AI summary NS Power retains the right to establish a separate service agreement if, in its opinion, additional issues need to be addressed for the ongoing benefit of NS Power and its customers, effective April 1, 2026.
IN THE MATTER OF THE PUBLIC UTILITIES ACT - and - IN THE MATTER OF AN APPLICATION by NOVA SCOTIA POWER INCORPORATED for the approval of the Annually Adjusted Rates for 2026 BEFORE: Richard Melanson, LL.B. Panel Chair Jennifer L. Nicholson,...
AI summary This document outlines a proceeding under the Public Utilities Act, involving Nova Scotia Power Incorporated's application for the approval of Annually Adjusted Rates for 2026.
ORDER The Board's decision dated March 9, 2026, approved the 2026 Annually Adjusted Rates (AARs) effective April 1, 2026. The Board retained its jurisdiction to amend the AARs following the outcome of the updated Cost of Service Study in t...
AI summary The Board approved the 2026 Annually Adjusted Rates (AARs) effective April 1, 2026, and retained jurisdiction to amend them based on the updated Cost of Service Study in the NS Power General Rate Application (GRA) matter M12451. NS Power filed a compliance filing with revisions to seven AARs following the Board's decision on the 2026-2027 GRA.
The Board orders the following. - 1. NS Power's Annually Adjusted Rates, Schedules B to E and G to I, are amended effective April 1, 2026, for the period April 1, 2026, to December 31, 2026, or until such date as future rates are approved,...
AI summary The Board has amended NS Power's Annually Adjusted Rates, including several schedules related to transmission, distribution, and renewable energy services, effective April 1, 2026. All other rates from the April 1, 2026, order remain unchanged.
ENERGY CHARGE NSPI's actual hourly marginal energy costs, plus the following fixed cost adders for on-peak and offpeak usage: On-peak (7:00 am - 11:00 pm, non-holiday weekdays): 5.274 ¢/kWh Off-peak (11:00 pm - 7:00am, non-holiday weekdays...
AI summary The document outlines NSPI's energy charge structure, including on-peak and off-peak fixed cost adders, weekend and holiday rates, annual submission requirements to the Nova Scotia Energy Board, and a customer-owned transformer credit. These rates are based on budgeted costs and include adjustments for peak demand.
ENERGY CHARGE NSPI's actual hourly marginal energy costs, plus the following fixed cost adders for on-peak and offpeak usage: On-peak (7:00 am – 11:00 pm, non-holiday weekdays): 9.925 ¢/kWh Off-peak (11:00 pm – 7:00am, non-holiday weekdays...
AI summary NSPI's energy charge includes on-peak and off-peak fixed cost adders, with weekend and holiday rates set at off-peak levels. These adders are developed annually and submitted for approval by the Nova Scotia Energy Board. A credit is also applied for customer-owned transformers based on monthly peak demand.
- (2) A fixed cost adder adjusted concurrent with changes in base cost rates coming into effect as a result of a General Rate Case application. Energy Base Charge Components Transmission Voltage of Higher 69 kV or (cents per kWh) Distribut...
AI summary The text describes a fixed cost adder that is adjusted in conjunction with changes in base cost rates resulting from a General Rate Case application. The table provides specific values for fuel cost and fixed adder components across different voltage levels.
Penalty for Non-Compliance All energy served after the 10-minute deadline has expired will be billed at $5.00 per kWh. In addition a fixed charge of $2,000.00 will be applied. The penalty charge is applicable above and beyond the Port Auth...
AI summary A penalty of $5.00 per kWh is applied to energy served after a 10-minute deadline, plus a fixed charge of $2,000.00. This penalty is in addition to the Port Authority's monthly bill.
CUSTOMER CHARGE The monthly customer charge under this tariff is calculated according to the following formula: This charge will be $414.63 per month.
AI summary The monthly customer charge under the tariff is set at $414.63 per month, calculated according to a specified formula.
DEMAND CHARGE The demand charge for this service is made up of the following two components: - (1) Annually adjusted demand-related purchased power cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism, or...
AI summary The demand charge for the service consists of two components, with the first being an annually adjusted demand-related purchased power cost, influenced by factors such as the Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
- (2) Demand-related fixed generation cost, coming into effect as a result of a General Rate Application. Demand Charge Components $ per kW of billing demand Demand-related Purchased Power Cost $6.222 Demand-related Fixed Generation Cost $...
AI summary The text introduces a demand-related fixed generation cost that is part of a General Rate Application. It outlines the components of the demand charge, including purchased power and fixed generation costs, and defines contract demand in the context of wholesale customers and suppliers.
- (2) Energy-related fixed generation cost, coming into effect as a result of a General Rate Application. Energy Charge Components cents per kWh Energy-related Purchased Power and Fuel Cost 6.974 Energy-related Fixed Generation Cost 2.155...
AI summary The document introduces an energy-related fixed generation cost that is part of a General Rate Application. It includes a table showing the breakdown of energy charge components, including a 2.155 cents per kWh fixed generation cost and a Fuel Adjustment Mechanism (FAM) section.
The FAM Actual Adjustment (AA) and Balance Adjustment (BA) charges or credits (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the FAM Tariff, shall apply, in addition to the energy charge.
AI summary The document specifies that the FAM Actual Adjustment (AA) and Balance Adjustment (BA) charges or credits, in cents per kilowatt-hour, apply in addition to the energy charge for the current rate year as outlined in the FAM Tariff.
AVAILABILITY The tariff is available to wholesale customers as defined in section 2(d) of the Electricity Act , Chapter 25 of the Acts of 2004. (d) "wholesale customer" means Nova Scotia Power Incorporated or a municipal utility. The tarif...
AI summary The tariff is available to wholesale customers, as defined under the Electricity Act, and outlines the process for requesting backup/top-up service, including requirements for notice, contract details, and metering. Applications must be submitted by specific deadlines depending on the CCF value, and service terms vary based on the application type.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: This charge will be $414.63 per month.
AI summary The monthly administration charge is set at $414.63 per month for each Load Serving Retailer (LRS) and is determined annually using a specified formula.
ENERGY CREDIT 6.736 cents per kilowatt-hour. The Energy Credit for spill service is set annually and is applicable to spilled energy in each hour.
AI summary The Energy Credit for spill service is set at 6.736 cents per kilowatt-hour and is applied annually to spilled energy in each hour.
MINIMUM MONTHLY CHARGE The minimum monthly charge will be the administration charge.
AI summary The minimum monthly charge is defined as the administration charge in this regulatory proceeding document.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: This charge will be $414.63 per month.
AI summary The monthly administration charge is set at $414.63 per month and applies to each Load Serving Retailer (LRS). The charge is determined annually using a specific formula.
DEMAND CHARGE $5.601 per month, per kilowatt (kW) of monthly standby contract demand.
AI summary The document specifies a demand charge of $5.601 per month, per kilowatt (kW) of monthly standby contract demand.
MINIMUM MONTHLY CHARGE The minimum monthly charge will be the administration charge.
AI summary The minimum monthly charge is defined as the administration charge in this regulatory proceeding.
SPECIAL CONDITIONS - (1) NS Power reserves the right to have a separate service agreement, if in the opinion of NS Power issues not specifically set out herein, must be addressed for the ongoing benefit of NS Power and its customers. - (2)...
AI summary The document outlines special conditions for service agreements, emphasizing NS Power's right to manage service terms and ensure system integrity. It highlights requirements for LRS customers and generators to maintain power supply stability and NS Power's authority to request rate changes from the Nova Scotia Energy Board.
PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...
AI summary The Renewable to Retail Market Transition Tariff (RTT) aims to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing, return on equity, and OM&G, and are not otherwise recovered through other tariffs. The RTT is established under Section 3G(2) of the Electricity Act (Nova Scotia).
November 7, 2025 Crystal Henwood Clerk of the Board Nova Scotia Energy Board 1601 Lower Water Street, 3rd Floor Halifax, NS B3J 3S3 Re: NS Power Annually Adjusted Rates for 2026 Dear Ms. Henwood: Below please find Nova Scotia Power Inc.'s...
AI summary Nova Scotia Power Inc. has submitted proposed tariffs for the Annually Adjusted Rates (AAR) for 2026, including cost support and redline and clean versions of ten different tariffs, to the Nova Scotia Energy Board.
NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: The Public Utilities Act , R.S.N.S. 1989, c.380 as amended - and - IN THE MATTER OF: NS Power's Application for 2026 Annually Adjusted Rates (AAR)
AI summary This document pertains to a regulatory proceeding under the Public Utilities Act, involving NS Power's application for 2026 Annually Adjusted Rates (AAR).
November 10, 2025 [[email protected]](mailto:[email protected]) Michael Willet Director, Regulatory Finance Nova Scotia Power Inc. PO Box 910 Halifax, NS B3J 2W5 Dear Mr. Willet: M12551 - Nova Scotia Power Inc. 2026 Annua...
AI summary Nova Scotia Power Inc. submitted its 2026 Annually Adjusted Rates for approval, including various tariff structures. The Board has approved the confidentiality undertaking and will review the matter as a paper proceeding with specific timelines for interventions, information requests, and evidence submissions.
NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: The Public Utilities Act , R.S.N.S. 1989, c.380 as amended - and - IN THE MATTER OF: Nova Scotia Power's Application for 2026 Annually Adjusted Rates (AAR)
AI summary This document pertains to a regulatory proceeding under the Public Utilities Act, involving Nova Scotia Power's application for 2026 Annually Adjusted Rates (AAR).
NOTICE OF INTERVENTION OF: K + S Windsor Salt Ltd. CKF Inc. Crown Fibre Tube Inc. Irving Shipbuilding Inc. Maritime Paper Products Ltd. Michelin North America (Canada) Inc. Compass Minerals Canada Corp. Farnell Packaging Ltd. P & H Milling...
AI summary The Industrial Group, consisting of large and medium industrial customers of NSPI, requests to intervene in this matter as their costs and rates may be affected by the outcome. They are addressing issues established by the NSEB.
NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: The Public Utilities Act - and - IN THE MATTER OF: Nova Scotia Power Inc's Application for 2026 Annually Adjusted Rates (AAR)
AI summary The Nova Scotia Energy Board is considering Nova Scotia Power Inc's application for 2026 Annually Adjusted Rates (AAR) under the Public Utilities Act.
NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: The PUBLIC UTILITIES ACT -and- IN THE MATTER OF: NOVA SCOTIA POWER'S APPLICATION FOR 2026 ANNUALLY ADJUSTED RATES (AAR)
AI summary This document pertains to a regulatory proceeding under the Public Utilities Act, concerning Nova Scotia Power's application for 2026 Annually Adjusted Rates (AAR).
NOTICE OF INTERVENTION OF: CONSUMER ADVOCATE TAKE NOTICE that the Consumer Advocate hereby intervenes in the above Application and proceeding. The Consumer Advocate represents the interests of residential ratepayers, who may be impacted by...
AI summary The Consumer Advocate intervenes in the proceeding, representing residential ratepayers. They will address issues raised by the Energy Board and any other relevant matters. Legal representation is provided by David Roberts and Michael Murphy from Pink Larkin, with John Wilson as a consultant.
NOVA SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S. 1989, c. 380 as amended – and – IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of its 2026 Annually Adjusted Rates (...
AI summary The document outlines an application by Nova Scotia Power Incorporated for approval of its 2026 Annually Adjusted Rates (AARs) under the Public Utilities Act, R.S.N.S. 1989, c. 380 as amended.
NOVA SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act – and – IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of its 2026 Annually Adjusted Rates (AARs)
AI summary The Nova Scotia Utility and Review Board is considering an application by Nova Scotia Power Incorporated for approval of its 2026 Annually Adjusted Rates (AARs) under the Public Utilities Act.
NOTICE OF INTERVENTION TO: The Nova Scotia Utility and Review Board ("Board") AND TO: Nova Scotia Power Inc. ("NSPI") 1. The BERWICK ELECTRIC COMMISSION, the RIVERPORT ELECTRIC LIGHT COMMISSION, the TOWN OF MAHONE BAY, and the TOWN OF ANTI...
AI summary The Berwick Electric Commission, Riverport Electric Light Commission, Town of Mahone Bay, and Town of Antigonish request intervenor status in a proceeding involving Nova Scotia Power Inc. They purchase power from NSPI and are affected by the Spill Tariff. They provide contact information for their representative, James MacDuff.
NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: The Public Utilities Act , R.S.N.S. 1989, c.380 as amended - and - IN THE MATTER OF: Nova Scotia Power's Application for 2026 Annually Adjusted Rates (AAR)
AI summary This document pertains to a regulatory proceeding under the Public Utilities Act, concerning Nova Scotia Power's application for 2026 Annually Adjusted Rates (AAR).
NOTICE OF INTERVENTION OF RENEWALL ENERGY INC. TAKE NOTICE that Renewall Energy Inc. (" REI ") requests to intervene in this matter. REI is a licensed retail supplier of renewable low-impact electricity in the Province of Nova Scotia and i...
AI summary Renewall Energy Inc. (REI) is requesting intervention in a regulatory proceeding related to the Renewable to Retail (RtR) market in Nova Scotia. REI is a licensed retail supplier of renewable electricity and is subject to annually adjusted tariffs. The proceeding involves issues related to the RtR market and specific tariffs, including the Energy Balancing Service (EBS), Standby Service (SS), and Renewable to Retail Market Transition (RTT) tariffs.
IN THE MATTER OF an application by NOVA SCOTIA POWER INCORPORATED for approval of the 2026 Annually Adjusted Rates (AAR's)
AI summary This document outlines an application by Nova Scotia Power Incorporated for the approval of the 2026 Annually Adjusted Rates (AARs). The proceeding involves the regulatory approval process for rate adjustments.
NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: THE PUBLIC UTILITIES ACT - and - IN THE MATTER OF: IN THE MATTER OF AN APPLICATION by NOVA SCOTIA POWER INCORPORATED for Approval of its 2026 Annually Adjusted Rates (AARs)
AI summary The Nova Scotia Energy Board is considering an application by Nova Scotia Power Incorporated for approval of its 2026 Annually Adjusted Rates (AARs) under the Public Utilities Act.
Document: 325987 Date Filed: 12/01/25 Page 1 1 Request IR-1: 2 Appendix A2 presents the annual marginal generation costs by month. 3 a) Please explain why for February and March. 4 b) Please provide the values for Marginal Costs excluding...
AI summary The document outlines several requests for information related to marginal generation costs, pricing systems, and updates to annually adjusted rates. It includes inquiries about specific months, cost exclusions, forecast price factors, and omitted updates in the 2026 AARs.
Request IR-11: - Appendix J refers to the 1P-RTP moving from an annually adjusted rate to one set through a - General Rate Application. However, toward the bottom of page 2 of 3 in the appendix NS Power - states that these "methodological...
AI summary The text raises questions about the transition of the 1P-RTP tariff from an annually adjusted rate to a General Rate Application, the alignment with other AARs, and the proposed increase in the Back UpTop-Up Tariff 2026 customer charge. It also references a figure in Appendix G2 EO.
- In Appendix I EO there are Demand Side Management Cost Recovery Rider Charges. Why are - these included as part of the AARs? Document: 325987 Date Filed: 12/01/25 Page 5
AI summary The document asks why Demand Side Management Cost Recovery Rider Charges are included as part of the Annually Adjusted Rates (AARs) in Appendix I EO.
1 M12551 2 3 NOVA SCOTIA ENERGY BOARD 4 5 IN THE MATTER OF: The Public Utilities Act, R.S.N.S. 1989, c.380, as amended 6 7 IN THE MATTER OF: An application by NOVA SCOTIA POWER 8 INCORPORATED (NS Power) for approval of its 2026 9 Annually...
AI summary This document outlines an information request related to NS Power's 2026 Annually Adjusted Rates (AARs) under the Public Utilities Act. The request is directed to Michael Willett, Director of Regulatory Finance at NS Power, and responses are due by December 22, 2025.
Refer to M12551, Exhibit N-1, the Application for the 2026 Annually Adjusted Rates (AARs) submitted by NS Power (the "Application"), Section 6.1.1, BUTU Customer Charge, at pages 24 – 25 of 45, where NS Power described the reason for incre...
AI summary The document refers to the Application for 2026 Annually Adjusted Rates (AARs) submitted by NS Power, requesting justification for a 3.25 percent increase in the BUTU Customer Charge. The increase is attributed to the Board's directive to review inflation rates, and the inquiry seeks clarification on the source and calculation of the escalator, as well as its application in other tariff applications.
Request IR-2: - Refer to M12551, Exhibit N-1, the Application Section 6.2 Spill Tariff Administration Charge, where NS Power has proposed an increase from $2,409.46 to $2,486.77 per supplier per month in 2026, based on a "supporting calcul...
AI summary The document requests clarification on how Appendix E2 in M12551, Exhibit N-1, justifies the 3.25 percent escalation factor for the Spill Tariff, specifically whether it differs from the justification for other 2026 AAR tariffs that include the same escalation factor.
Request IR-5: Refer to M12551, Exhibit N-1, the Application, Section 7.2 Standby Service Tariffs and Figure 10: Standby Service Tariff Charges, which shows the Administration Charge ($/customer/month) of $401.58 for 2025 and $414.63 for 20...
AI summary The text references a request (IR-5) regarding the proposed increase in the 2026 Administration Charge for standby service tariffs, asking whether this increase aligns with the 3.25 percent increase applied in other AAR tariffs and requesting an explanation and calculation for this adjustment.
7.3.1.2 Annually Adjusted Energy Savings Credit The Annually Adjusted Energy Savings Credit is designed to credit the LRS with any non-fuel energy-related cost savings arising from freed-up capacity on NS Power's system as a result of a de...
AI summary The Annually Adjusted Energy Savings Credit is a mechanism to credit LRS with non-fuel energy-related cost savings from freed-up capacity on NS Power's system when bundled service load departs to the RtR market. NS Power does not project savings in this category for 2026 and maintains a zero value. Questions are raised regarding the rationale and supporting information from LRS companies.
M12551 NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S. 1989, c.380, as amended IN THE MATTER OF: An application by NOVA SCOTIA POWER INCORPORATED (NS Power) for approval of its 2026 Annually Adjusted Rates (AA...
AI summary The Small Business Advocate has submitted a series of information requests to NS Power regarding the justification for a 3.25 percent escalator in the BUTU Customer Charge, its source and calculation, whether it is based on third-party estimates or customer charge increases elsewhere in Canada, and if it has been used in other 2026 applications.
026? 2. Has NS Power received any additional information from existing LRS companies that support NS Power’s projected savings of zero? If so, please provide copies or summaries of this information. 1. M12551, Exhibit N-1 NS Power’s Applic...
AI summary The document contains a series of questions and references to exhibits and pages in NS Power’s Application for the 2026 Annually Adjusted Rates (AARs), focusing on whether NS Power has received additional information from existing LRS companies that support its projected savings of zero.
1 2025 M12551 2 NOVA SCOTIA ENERGY BOARD 3 IN THE MATTER OF: The Public Utilities Act , R.S.N.S. 1989, c.380 as amended 4 - and - 5 IN THE MATTER OF: Nova Scotia Power's Application for 2026 Annually Adjusted 6 Rates (AAR) 7 8 INFORMATION...
AI summary This document is an information request from Renewall Energy Inc. to Nova Scotia Power Incorporated under the Public Utilities Act, seeking details on the marginal cost analysis for various generator classes in the PLEXOS model used for calculating average annual marginal costs for 2023, 2024, and 2025.
- 30 (d) If a true-up mechanism were implemented to reconcile forecast versus 31 actual marginal costs, please explain how this would affect: 1 2 (i) the risks or benefits to NS Power identified in part (a) above; 3 (ii) the need for or be...
AI summary The document outlines requests related to implementing a true-up mechanism to reconcile forecast versus actual marginal costs, including its impact on risks and benefits to NS Power, the need for frequent updates, and forecast risk allocation. It also requests updated financial data and information on planned filings for a capital work order.
- 31 (d) If NS Power believes a cap exists: 1 (i) Please identify the specific tariff provision, Board order, or 2 Board approval that establishes such cap, and provide the 3 history of how this cap was determined; 4 (ii) Quantify the maxi...
AI summary The text outlines a request for NS Power to identify any cap on payments to RtR customers and explain its calculation. It also discusses the Annually Adjusted Energy Savings Credit and Demand Savings Credit, noting that NS Power does not project savings in these categories and proposes maintaining a zero value in 2026.
2025 M12551 NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S. 1989, c.380 as amended - and - IN THE MATTER OF: Nova Scotia Power’s Application for 2026 Annually Adjusted Rates (AAR)
AI summary This document pertains to Nova Scotia Power’s application for 2026 Annually Adjusted Rates (AAR) under the Public Utilities Act. It outlines the regulatory proceeding related to rate adjustments for the year 2026.
Reference: Section 2.0 Marginal Cost Analysis, pages 11-14. 1. Please provide the number of hours and percentage of hours for each of the years 2023, 2024 and 2025 year-to-date plus forecast that each generator class (e.g coal, natural gas...
AI summary The text requests detailed information on generator class marginal unit hours for 2023, 2024, and 2025, as well as clarification on the inclusion of OBPS compliance obligations in the PLEXOS model used for calculating average annual marginal costs. The PLEXOS model used for the 2026 AAR forecast is based on the 2024 Q3 forecast model with updated assumptions.
1. Where the forecast marginal generator is an import, has NS Power assessed the accuracy of these forecasts on a monthly and annual basis? If yes, please provide the results of such assessments for the past three years. If no, please expl...
AI summary The document raises questions about NS Power's forecasting practices for marginal cost calculations, specifically regarding the accuracy of monthly and annual forecasts, the comparison of actual versus forecasted hours of import usage, and the potential benefits of switching to monthly marginal cost pricing for AARs. It also inquires about the operational and administrative impacts of such a change.
rates. Where the change is greater than 10% for a particular component, please provide a detailed explanation of the driver(s), including the relative contribution of each driver to the total change. Reference: Appendix F3, page 137 Standb...
AI summary The document requests detailed explanations regarding the Interruptible Service Credit and its inclusion in the 2026 Standby Demand Charge calculation. It also highlights the need for closer scrutiny of the Annual Energy Cost Adjustment due to the increasing influence of environmental costs and regulations on marginal costs.
capacity in the event the RtR customer returns to NS Power’s service. The Company does not project savings in this cost category and proposes that the current value of zero remain in effect in 2026. 1. Please confirm the assumptions in 202...
AI summary The text requests clarification on assumptions related to load transitioning from NS Power’s service to RtR, firm capacity contributions, and the purpose of certain tariff components. It also asks for a Market Design White Paper and a revised figure showing percentage changes in RTT components compared to 2025 rates.
please provide a detailed explanation of the driver(s), including the relative contribution of each driver to the total change. Reference: Board Directive regarding Interruptible Service, p. 37. 1. Please confirm that REI, in fact, provide...
AI summary The document requests detailed explanations of the drivers behind changes, referencing a Board Directive on Interruptible Service. It also seeks confirmation and documentation regarding REI's response to NS Power’s proposed project, timelines for approval, and any potential impediments to the project’s implementation during the 2026/2027 winter season.
1 2025 M12551 2 NOVA SCOTIA ENERGY BOARD 3 IN THE MATTER OF: The Public Utilities Act , R.S.N.S. 1989, c.380 as amended 4 - and - 5 IN THE MATTER OF: Nova Scotia Power's Application for 2026 Annually Adjusted 6 Rates (AAR) 7 8 INFORMATION...
AI summary The Nova Scotia Energy Board has issued an information request to Nova Scotia Power Incorporated regarding the 2026 Annually Adjusted Rates (AAR) application. The request asks for the annual revenue forecast by rate class and how changes in customer status and wind farm operations may impact the forecast.
In accordance with the Board's directive in the 2025 AARs, a review comparing the monthly forecasted NB imports to actual NB imports is provided in Confidential Appendix A7. As a result of the cyber incident, NS Power is only able to provi...
AI summary The text discusses the impact of a cyber incident on NSPI's ability to provide historical data on New Brunswick imports and the adjustment of energy charges based on hourly marginal costs. It also raises questions about the reliability of avoided fuel cost calculations and their impact on other rates and methodologies.
2025 M12551 NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S. 1989, c.380 as amended - and - IN THE MATTER OF: Nova Scotia Power’s Application for 2026 Annually Adjusted Rates (AAR)
AI summary This document pertains to Nova Scotia Power’s application for 2026 Annually Adjusted Rates (AAR) under the Public Utilities Act, R.S.N.S. 1989, c.380 as amended.
1. 1. Assuming this Application is approved as filed, effective January 1, 2026, what is the annual revenue forecast to be collected from each rate class under the AAR? In providing your answer, please identify the load forecast being used...
AI summary The text presents questions regarding the annual revenue forecast under the AAR, load forecasts, and the impact of the Goose Harbour Wind Farm and PHP becoming an ATL customer. It also addresses the impact of a cyber incident on NSPI’s ability to access historical data and formulate AARs for 2026.
ed, including the year-end calculations of benefits. Reference: Section 8.0, ELIADC, pages 38-43, and Appendix G1. And Reference: M12184, Submissions of Bates White, dated November 26, 2025. Preamble: In response to NSPI’s ELIADC Third Ter...
AI summary Bates White submitted recommendations to remove fixed costs from the CBL Energy Charge in response to NSPI’s ELIADC Third Term Application. The proceeding asks whether these concerns impact the ELIADC Energy Charge and whether NSPI agrees with the recommended revision to the FCR definition.
1 M12551 2 3 4 NOVA SCOTIA UTILITY AND REVIEW BOARD 5 IN THE MATTER OF: The Public Utilities Act, R.S.N.S. 1989, c. 380 6 7 -and - 8 9 10 IN THE MATTER OF: NOVA SCOTIA POWER'S APPLICATION FOR 2026 ANNUALLY ADJUSTED RATES (AAR) 11 12 13 14...
AI summary This document is an information request from the Nova Scotia Consumer Advocate to Nova Scotia Power Inc. regarding the application for 2026 annually adjusted rates (AAR). The request is part of a regulatory proceeding under the Public Utilities Act, and responses are due by December 22, 2025.
ate on Items Arising from 2024 and 2025 Annually Adjusted Rates Proceedings (January 31, 2025), Matter No. M11989. [E](#page-1-3)xhibit N-2, Matter No. M11989, CA RIR-5(b). [E](#page-1-5)xhibit N-1, Appendix J, p. 2. [E](#page-1-7)xhibit N...
AI summary The document outlines a regulatory proceeding related to annually adjusted rates for 2024 and 2025, including questions about the marginal system capacity for 2026, the impact of removing load served under the 1P-RTP Tariff, and adjustments to Appendix B2 using the SO2 method. It also requests cost recovery summaries for the proposed 1P-RTP and an alternate version.
Request IR-6: In its decision on the 2025 AARs, the Board stated: The Board agrees with Mr. Wilson that it is prudent to have a sensitivity analysis for potential delayed wind resources in the 2026 AARs. In the 2025 ACE Plan M12012, Append...
AI summary The Board directed NS Power to provide sensitivity analyses for potential delays in wind resources scheduled for 2025 and 2026. NS Power states that a 'no new wind' scenario is not plausible, but the Board questions why this scenario was included. The Board also requests clarification on the Q3 2025 forecast, the difference between forecasts and anticipated operations, an alternate scenario with delays to 2027, and whether Sensitivity 4 results would impact rate-setting.
FCA component of 1P-RTP Tariffs for distribution to stakeholders in Q2 2025, for review at the first stakeholder session.”[[1]](#footnote-2) Please explain whether this occurred and, if not, why not. In the 2025 AAR proceeding, NS Power st...
AI summary The document discusses NS Power's explanation regarding the FCA component of 1P-RTP Tariffs not being distributed to stakeholders in Q2 2025 and the impact of recent emissions standards on the 1P-RTP tariff methodology, citing concerns over volatility and reliability of the current avoided fuel cost methodology.
1. Please explain whether it is still NS Power’s position that the SO2 emissions limit will not be an issue for the design of the 1P-RTP Tariff after renewable energy sources are added to the system. Please address this question specifical...
AI summary The document requests clarification on NS Power’s position regarding SO2 emissions limits and the 1P-RTP Tariff design, as well as how system composition might change if the load served under the 1P-RTP Tariff was not present, particularly concerning the marginal system capacity for 2026 and the potential retirement of Lingan 2.
ing the “adjustment for the projected imbalance” is the SO2 emissions limit issue. 2. Please explain any other reasons that NS Power has for eliminating the “adjustment for the projected imbalance.” In its 2018 AAR application, NS Power st...
AI summary The text discusses NS Power's reasons for eliminating the 'adjustment for the projected imbalance' and the treatment of unit commitment costs under different AAR tariff designs. It also references the Board's requirement for sensitivity analyses regarding potential delays in wind resource in-service dates in the 2026 AAR application.
ates. If the answer differs by rate, please state your opinion by rate. Re: Application, p.14 and Confidential Appendix A7, identifying factors that cause actual import volumes to vary from forecast. 1. Please provide a list of the factors...
AI summary The document requests NS Power to identify factors affecting import volume variations from forecasts, explain expected impacts on 2026 imports, detail forecast development timelines, and assess whether historical averages account for changes. It also asks for a comparison of forecasted and model import limits for 2026.
believe so, please provide a sensitivity analysis that adequately accounts for such changes. 5. Please provide a comparison of monthly forecast import volumes and monthly model import limits for 2026. 1. NS Power, Letter re: Update on Item...
AI summary The text includes a request for a sensitivity analysis and a comparison of monthly forecast import volumes and model import limits for 2026. It also lists several exhibits and matters related to NS Power and NSUARB decisions.
NOVA SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: THE PUBLIC UTILITIES ACT and IN THE MATTER OF: An Application by Nova Scotia Power Inc. ("NS Power") for approval of its Annually Adjusted Rates for 2026 NON-CONFIDENTIAL INFORMATION R...
AI summary The Nova Scotia Utility and Review Board is handling an application by Nova Scotia Power Inc. for approval of its 2026 annually adjusted rates. The Berwick Electric Commission, Riverport Electric Light Commission, and the Towns of Mahone Bay and Antigonish have submitted non-confidential information requests to NS Power, with responses due by December 22, 2025.
MEU Information Requests to NS Power 1 2 IR-1 3 4 Reference: Application, page 23, footnote 27. "As of the time of this application, the portion of 5 MEUs' demand and energy to be served under the Municipal Tariff in 2026 has not been fina...
AI summary The MEUs are seeking information from NS Power regarding the forecast billing demand and energy requirements for 2026 under different billing arrangements (reciprocal and non-reciprocal) for BUTU service, as well as the forecast amount of overall Spill Tariff energy in each scenario.
M12551 NOVA SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: THE PUBLIC UTILITIES ACT and IN THE MATTER OF: An Application by Nova Scotia Power Inc. (“NS Power”) for approval of its Annually Adjusted Rates for 2026 NON-CONFIDENTIAL INFORM...
AI summary The MEUs are requesting information regarding the finalization of the portion of their demand and energy to be served under the Municipal Tariff in 2026, which depends on the Board’s decisions on the 2026-2027 GRA and 2026 AARs. These decisions will determine the Municipal and BUTU rates for 2026, which in turn will influence whether the MEUs choose a reciprocal or non-reciprocal billing arrangement with specific contract demand thresholds.
that provide the most benefits and why, ways to improve the tariff or tariff administration, and a comparison of current year outcomes to prior years to help to evaluate ELIADC performance over time." On October 31, 2025, NS Power filed it...
AI summary NS Power filed its Compliance Filing on October 31, 2025, which was approved by the Board on December 10, 2025. The approved Tariff includes a provision requiring information on the CBL Energy Charge and VCC for 2026 to be provided to the Board by November 7, 2025.
On November 7, 2025, NS Power filed for approval of its 2026 AARs, including the ELIADC Energy Charge. Section 8.2 of the Application provided as follows: Energy Charge by Component 2026 ($/MWh) CBL Energy Charge 69.85 CBLA 5.00 Variable C...
AI summary NS Power filed for approval of its 2026 AARs, including the ELIADC Energy Charge. The proposed energy charge is $75.87/MWh, composed of various components. PHP reviewed the application and supports the proposed charge without making further submissions.
Section 69(1) of the Public Utilities Act states (emphasis added): "When a public utility has submitted for the approval of the Board a schedule of rates, tolls and charges, or a proposed change in any existing schedule of rates, tolls and...
AI summary Section 69(1) of the Public Utilities Act allows the Board to grant interim approval of rate changes submitted by a public utility, with or without modification, and establishes that the interim approved rates become the only lawful rates until final approval or disapproval is issued. Section 69(3) permits interim approval to be granted ex parte without public hearing or notice.
blic Utilities Act further states that: "Notwithstanding any other provisions of this Act, the interim approval referred to in this Section may be given ex parte and without public hearing or notice." Since the proposed 2026 ELIADC Energy...
AI summary PHP requests interim approval of the 2026 ELIADC Energy Charge to ensure amendments to the ELIADC Tariff are effective January 1, 2026. NS Power does not oppose this request, and the Board may follow a similar process as in Matter M11989. The Public Utilities Act allows for ex parte interim approval.
December 19, 2025 Crystal Henwood Clerk of the Board Nova Scotia Energy Board 1601 Lower Water Street, 3rd Floor Halifax, NS B3J 3S3 Re: M12551 2026 AAR IR Responses Dear Ms. Henwood: Enclosed are Nova Scotia Power Inc.'s (NS Power, Compan...
AI summary Nova Scotia Power Inc. submitted responses to information requests related to matter M12551. They noted that some redacted information does not require confidential treatment and provided justification for the confidentiality of other redacted information.
December 24, 2025 Via email To: Nova Scotia Power and Interested Parties: M12551 - Nova Scotia Power Inc. – 2026 Annually Adjusted Rates Interim Approval of the ELIADC Tariff Nova Scotia Power Inc. (NS Power) filed an application with the...
AI summary NS Power has applied for interim approval of its 2026 Annually Adjusted Rates, including the ELIADC Energy Charge. Port Hawkesbury Paper supports the proposed rate and requests interim approval effective January 1, 2026. The Board is seeking comments from NS Power and other parties involved in the application.
Please refer to: David Roberts Email: [[email protected]](mailto:[email protected]) Assistant: Alissa Whalen Assistant's email: [[email protected]](mailto:[email protected]) January 19, 2026 VIA SECURE FILE TRANSFER C...
AI summary The Consumer Advocate requests that the Board consider the impact of interim approval of the ELIADC tariff on other rate classes and suggests that any interim relief should be effective later than January 1, 2026, due to potential cost increases for other rate classes.
From: [Henwood, Crystal D](mailto:[email protected]) To: [Melissa MacAdam](mailto:[email protected]) Cc: [Alissa Whalen](mailto:[email protected]); [Annie Beth Sampson](mailto:[email protected]); [Bill Ma...
AI summary The Board has agreed to a one-day extension for a request related to the 2026 ELIADC Energy Charge. The email also includes a note about submitting documents via a secure file transfer service starting November 3, 2025.
Statement of Confidentiality This message (including any attachments) may contain private or protected information meant for a specific person or organization. If you received this by mistake, please let the sender know, do not communicate...
AI summary The email is a confidentiality notice related to a regulatory proceeding concerning NS Power's comments on a request for interim approval of the 2026 ELIADC Energy Charge. It was sent by Melissa MacAdam to Crystal Henwood and several other stakeholders.
Delivered by E-mail Crystal Henwood Regulatory Affairs Officer/Clerk Nova Scotia Energy Board 3rd Floor, 1601 Lower Water Street PO Box 1692, Unit "M" Halifax NS B3J 3S3 Dear Ms. Henwood: Re: M12551 - NSPI - 2026 Annually Adjusted Rates (A...
AI summary The Industrial Group submits comments on behalf of Port Hawkesbury Paper LP's request for interim approval of the 2026 ELIADC Energy Charge of $75.87/MWh. PHP argues that the charge is a reduction in the existing rate schedule and requests interim approval under the Public Utilities Act. NSPI does not oppose the request.
Statutory Framework Section 69(1) of the Public Utilities Act authorizes the Board to grant interim approval of a submitted schedule or change where, in the Board's opinion, it either constitutes a reduction in the existing schedule of rat...
AI summary Section 69(1) of the Public Utilities Act allows the Board to grant interim approval of rate schedules under certain conditions. The Board has discretion but must ensure rates are just and reasonable, considering the public interest and all ratepayers, not just those seeking relief.
Minimal Timing Prejudice PHP seeks interim approval retroactive to January 1, 2026, subject to adjustment with the final decision. The procedural schedule in this matter provides for submissions January 20, 2026; and reply submissions Janu...
AI summary PHP is seeking retroactive interim approval for rates effective January 1, 2026, with a final decision expected by February 1, 2026. The Industrial Group recommends that NSPI file AAR applications earlier in the year to align rate increases for all customer classes and suggests moving the filing date to early/mid-October.
Brianne E. Rudderham Direct Dial : 902.420.3323 [[email protected]](mailto:[email protected]) File No: SM064773.00005 January 19, 2026 Delivered by E-mail Crystal Henwood Regulatory Affairs Officer/Clerk Nova Scot...
AI summary Renewall Energy Inc. (REI) is requesting a one-day extension to file its submissions and evidence for the 2026 Annually Adjusted Rates (AAR) application due to inclement weather causing a power outage and preventing access to necessary documents.
January 19, 2026 [[email protected]](mailto:[email protected]) Brianne Rudderham Stewart McKelvey 600 – 1741 Lower Water St. Halifax, NS B3J 2X2 Dear Ms. Rudderham: M12551 - 2026 Annually Adjusted Rates (AARs) – E...
AI summary The Board has approved Renewall's request for an extension to file submissions and evidence for the 2026 Annually Adjusted Rates (AARs) proceeding, setting the new deadline as January 21, 2026.
January 20, 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: M12551 - Nova Scotia Power Incorporated (NSPI) -Application for Approval...
AI summary Nova Scotia Power Incorporated (NSPI) filed an application for approval of 2026 Annually Adjusted Rates (AARs), including the ELIADC Tariff for Port Hawkesbury Paper (PHP). PHP requested interim approval of the ELIADC Tariff, citing the Board's prior approval in M12184 and Section 69(1) of the Public Utilities Act.
[[email protected]](mailto:[email protected]) Michael Willett Director, Regulatory Finance Nova Scotia Power Inc. PO Boc 910 Halifax, NS B3J 3S8 Dear Mr. Willett: M12551 – Nova Scotia Power Inc. – 2026 Annually Adjusted R...
AI summary Nova Scotia Power Inc. (NS Power) is preparing its 2026 Annually Adjusted Rates (AARs) application as directed by the Nova Scotia Energy Board, which succeeded the Nova Scotia Utility and Review Board following the proclamation of the Energy and Regulatory Boards Act in April 2025.
ce to customers. NS Power reported that it proposed a draft Terms of Reference for an interruptible service pilot with REI in July 2025. NS Power remains amenable to discussing this service structure. When NS Power filed this AAR applicati...
AI summary NS Power proposed a draft Terms of Reference for an interruptible service pilot with Renewall Energy Inc. (REI) in July 2025. The Board is concerned about using an unapproved COSS in the AAR application, which could affect marginal cost calculations for REI. Adjustments to the AARs can be made post-decision in the GRA matter M12451.
IN THE MATTER OF THE PUBLIC UTILITIES ACT - and - IN THE MATTER OF AN APPLICATION by NOVA SCOTIA POWER INCORPORATED for the approval of the Annually Adjusted Rates for 2026 BEFORE: Richard Melanson, LL.B. Panel Chair Jennifer L. Nicholson,...
AI summary This document pertains to an application by Nova Scotia Power Incorporated for the approval of annually adjusted rates for 2026 under the Public Utilities Act. The proceeding is before a panel consisting of Richard Melanson, Jennifer Nicholson, and Bruce Fisher.
ORDER On November 7, 2025, NS Power filed its application for approval of the 2026 Annually Adjusted Rates (AARs). On December 12, 2025, Port Hawkesbury Paper requested an interim order approving the 2026 Extra Large Industrial Active Dema...
AI summary NS Power submitted an application for 2026 Annually Adjusted Rates (AARs). Port Hawkesbury Paper requested an interim approval for the 2026 ELIADC tariff, which was granted. The Board approved the 2026 AARs effective April 1, 2026, with the possibility of amendment based on the updated Cost of Service Study.
The Board orders the following. - 1. NS Power's Annually Adjusted Rates, Schedules A to J, are approved for the period April 1, 2026, to December 31, 2026, or until such date as future rates are approved, and are attached as the following...
AI summary The Board has approved NS Power's Annually Adjusted Rates for the period April 1, 2026, to December 31, 2026, or until future rates are approved. The approved rates include multiple tariff schedules, such as Generation Replacement, Transmission Real Time Pricing, and Extra Large Industrial Active Demand Control Tariff.
Backup Service The actual or estimated average time coincident incremental cost of generation including transmission losses for the period service is provided plus 0.500 cents per kWh for additional Operating and Maintenance costs, service...
AI summary The Backup Service is defined by the average time coincident incremental cost of generation, including transmission losses, plus an additional 0.500 cents per kWh for Operating and Maintenance costs, service charges, and Administration & General compensation.
Optional Generation Load Following Average incremental cost of generation expressed in cents per kWh as determined by the generation forecast for the rate year plus add on charges as defined for back-up service. This price will be 7.236 ce...
AI summary The document outlines the average incremental cost of generation for the rate year, set at 7.236 cents per kWh, including add-on charges for back-up service as determined by the generation forecast.
- (2) A fixed cost adder adjusted concurrent with changes in base cost rates coming into effect as a result of a General Rate Case application. Base Energy Charge Components Transmission Voltage of 69 kV or Higher (cents per kWh) Distribut...
AI summary This section describes a fixed cost adder that is adjusted in line with changes in base cost rates resulting from a General Rate Case application. The table provides breakdowns of base energy charges, including fuel cost and fixed cost adder components for different voltage levels.
A credit equal to 32 cents per peak kilovolt-ampere of monthly peak demand will be applied where the transformer is owned by the customer and the customer is served at a transmission voltage level.
AI summary The document outlines a credit mechanism where customers who own transformers and are served at a transmission voltage level receive a credit of 32 cents per peak kilovolt-ampere of monthly peak demand.
Penalty for Non-Compliance All energy served after the 10-minute deadline has expired will be billed at $5.00 per kWh. In addition a fixed charge of $2,000.00 will be applied. The penalty charge is applicable above and beyond the Port Auth...
AI summary A penalty of $5.00 per kWh is applied to energy served after the 10-minute deadline, along with a fixed charge of $2,000.00, applicable in addition to the Port Authority's monthly bill.
DEMAND CHARGE The demand charge for this service is made up of the following two components: - (1) Annually adjusted demand-related purchased power cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism, or...
AI summary The demand charge for the service includes an annually adjusted demand-related purchased power cost, which is influenced by factors such as the Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
- (2) Demand-related fixed generation cost, coming into effect as a result of a General Rate Application. Demand Charge Components $ per kW of billing demand Demand-related Purchased Power Cost $6.252 Demand-related Fixed Generation Cost $...
AI summary The text introduces a demand-related fixed generation cost resulting from a General Rate Application, with specific rates provided for demand-related purchased power cost and demand-related fixed generation cost, totaling $11.868 per kW of billing demand. It also defines Contract Demand requirement in the context of wholesale customers and NSPI.
ENERGY CHARGE The energy charge is made up of the following two components: - (1) Annually adjusted energy-related purchased power and fuel cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism or General R...
AI summary The energy charge consists of two components, one of which is annually adjusted energy-related purchased power and fuel cost, influenced by factors such as the Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
- (2) Energy-related fixed generation cost, coming into effect as a result of a General Rate Application. Energy Charge Components cents per kWh Energy-related Purchased Power and Fuel Cost 6.984 Energy-related Fixed Generation Cost 2.166...
AI summary The document introduces an energy-related fixed generation cost, effective due to a General Rate Application. It includes a table with energy charge components and mentions the Fuel Adjustment Mechanism (FAM).
AVAILABILITY The tariff is available to wholesale customers as defined in section 2(d) of the Electricity Act , Chapter 25 of the Acts of 2004. (d) "wholesale customer" means Nova Scotia Power Incorporated or a municipal utility. The tarif...
AI summary The tariff is available to wholesale customers, including Nova Scotia Power Incorporated and municipal utilities, under specific terms and conditions. Applications for service must be submitted annually by certain deadlines, with service commencing in the subsequent year. Metering equipment must be installed for third-party generators.
ENERGY CREDIT Compensation for spill energy delivered to NSPI will be at the Company's forecast average annual marginal energy costs of 6.736 cents per kilowatt hour as approved for use with the GRLF rate.
AI summary The document specifies that compensation for spill energy delivered to NSPI will be based on the Company's forecast average annual marginal energy costs of 6.736 cents per kilowatt hour, as approved for use with the GRLF rate.
MINIMUM MONTHLY CHARGE The minimum monthly charge shall be the administration charge.
AI summary The minimum monthly charge is defined as the administration charge in this regulatory proceeding document.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: Monthly charge = forecast annual administration costs forecast number of LRS' subscribed \ 12 This ch...
AI summary The monthly administration charge is set annually based on forecasted administration costs and the number of LRS (Licensed Retail Suppliers) subscribed, calculated as $414.63 per month.
MINIMUM MONTHLY CHARGE The minimum monthly charge will be the administration charge.
AI summary The document specifies that the minimum monthly charge is equivalent to the administration charge, indicating a direct relationship between these two financial terms in the regulatory proceeding.
DEMAND CHARGE $5.616 per month, per kilowatt (kW) of monthly standby contract demand.
AI summary The document specifies a demand charge of $5.616 per month, per kilowatt (kW) of monthly standby contract demand.
SPECIAL CONDITIONS - (1) NS Power reserves the right to have a separate service agreement, if in the opinion of NS Power issues not specifically set out herein, must be addressed for the ongoing benefit of NS Power and its customers. - (2)...
AI summary This section outlines special conditions for standby service agreements, including NS Power's right to create separate service agreements, requirements for LRS' RtR customers and generators, and considerations for power supply system integrity. It also reserves NS Power's right to apply for changes in rates or terms to the Nova Scotia Energy Board.
PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...
AI summary The Renewable to Retail Market Transition Tariff (RTT) is established under Section 3G(2) of the Electricity Act (Nova Scotia) to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing costs, and OM&G, and are recovered through Bundled Service, not through other applicable tariffs.
The Energy Charge is made up of the following components: Energy Charge Components cents per kWh Fixed Cost Adder from Energy Balancing Service Tariff 2.166 Annually Adjusted Energy Savings Credit 0.000 Annual Energy Cost Adjustment 2.198...
AI summary The Energy Charge consists of several components, including a Fixed Cost Adder from the Energy Balancing Service Tariff, an Annually Adjusted Energy Savings Credit, and an Annual Energy Cost Adjustment. The charge applies to the LRS' monthly displaced energy on NS Power's generation system, calculated as the total monthly LRS load minus the top-up quantity.
SPECIAL CONDITIONS (1) Nothing contained in this RTT or any service agreement shall be construed as affecting or in any way limiting the right of NS Power to make application to the Nova Scotia Energy Board for a change in any rates, terms...
AI summary This section of the RTT (Renewable to Retail Market Transition Tariff) outlines that nothing in the tariff or service agreements restricts NS Power's ability to apply to the Nova Scotia Energy Board for changes to rates, terms, and conditions, including those in the RTT, Standby Service Tariff, or Energy Balancing Service Tariff.
SECURITY FOR PAYMENTS NS Power shall invoice PHP weekly, and PHP shall pay the billed amount net 7 days. As security for payment, PHP shall provide NS Power a letter of credit from time to time. The form, amount, and issuer of the letter o...
AI summary NS Power requires PHP to pay weekly invoices net 7 days and to provide a satisfactory letter of credit as security for payment. Any additional costs or lag time caused by the letter of credit must be covered by PHP, not NS Power or its customers.
SEPARATE SERVICE AGREEMENT Effective: April 1, 2026 NS Power reserves the right to have a separate service agreement if, in the opinion of NS Power, issues not specifically set out herein must be addressed for the ongoing benefit of NS Pow...
AI summary NS Power retains the right to establish a separate service agreement if, in its opinion, new issues arise that require addressing for the ongoing benefit of NS Power and its customers, effective April 1, 2026.
March 27, 2026 Crystal Henwood Clerk of the Board Nova Scotia Energy Board 1601 Lower Water Street, 3rd Floor Halifax, NS B3J 3S3 Re: M12551 2026 Annually Adjusted Rates (AAR) Compliance Filing – Extension Request Dear Ms. Henwood: On Marc...
AI summary NS Power has requested an extension for its 2026 AAR Compliance Filing, following the Board's decision on the GRA matter (M12451). The Board directed NS Power to file a compliance filing two weeks after the GRA decision and established a timeline for intervenor and NS Power reply submissions.
March 30, 2026 [[email protected]](mailto:[email protected]) Blake Williams VP, Legal and Regulatory Nova Scotia Power Inc. PO Box 910 Halifax, NS B3J 2W5 Dear Mr. Williams: M12551 - Nova Scotia Power Inc. – 2026 Annually A...
AI summary NS Power requested an extension for the 2026 AAR Compliance Filing, which the Board approved, extending the deadline to two weeks after the Board's Order in M12451.
May 5, 2026 [[email protected]](mailto:[email protected]) Jennifer Power Senior Regulatory Counsel Nova Scotia Power Inc. PO Box 910 1223 Lower Water Street Halifax, NS B3J 3S8 Dear Ms. Power: M12551 – 2026 Annually Adjuste...
AI summary NS Power has initiated stakeholder engagement to comply with the Board's directive on the 2026 Annually Adjusted Rates (AARs) matter M12551. This includes addressing issues raised by Renewall Energy Inc., such as cost allocation, monthly marginal cost pricing, and a true-up mechanism. The Board has acknowledged progress and expects an update by June 15, 2026.
May 12, 2026 [[email protected]](mailto:[email protected]) Blake Williams VP, Legal and Regulatory Nova Scotia Power Inc. PO Box 910 Halifax, NS B3J 2W5 Dear Mr. Williams: M12551 - Nova Scotia Power Inc. – 2026 Annually Adj...
AI summary Nova Scotia Power Inc. (NS Power) submitted a compliance filing to adjust demand charges in the Standby Service Tariff and Wholesale Market BUTU Tariff following a data input error. However, the Renewable to Retail Market Transition Tariff's demand charge was not adjusted. The Board requests confirmation that the revised demand charge will be consistently applied across all relevant tariffs.
May 13, 2026 Crystal Henwood Clerk of the Board Nova Scotia Energy Board 1601 Lower Water Street, 3rd Floor Halifax, NS B3J 3S3 Re: M12551 – 2026 Annually Adjusted Rates (AARs) – Reply to Board Letter on AAR Compliance Filing Dear Ms. Henw...
AI summary NS Power filed its 2026 AAR compliance filing on May 11, 2026, following the NSEB's approval of the 2026 AARs. The Board requested clarification on the demand charge in the RTT tariff, which NS Power confirmed will be consistent with the SS and BUTU tariffs going forward. The correct demand charge of $5.601 per kW was included in the AAR Compliance Filing.
May 15, 2026 Interested parties: M12551 – 2026 Annually Adjusted Rates – Compliance Filing The Nova Scotia Energy Board's decision dated March 9, 2026, approved the 2026 Annually Adjusted Rates (AARs) effective April 1, 2026. The Board ret...
AI summary The Nova Scotia Energy Board approved the 2026 Annually Adjusted Rates (AARs) effective April 1, 2026, and NS Power submitted a compliance filing with revisions to seven AARs following the Board's decision on the 2026-2027 GRA. Comments on the revised AARs are invited from interested parties by May 25, 2026.
May 27, 2026 [[email protected]](mailto:[email protected]) Blake Williams VP, Legal and Regulatory Nova Scotia Power Inc. PO Box 910 Halifax, NS B3J 2W5 Dear Mr. Williams: M12551 - Nova Scotia Power Inc. – 2026 Annually Adj...
AI summary The Board has reviewed and approved Nova Scotia Power Inc.'s 2026 Annually Adjusted Rates (AAR) compliance filing. The changes, effective April 1, 2026, will result in a modest rate decrease for existing customers, requiring a credit or refund to be processed by NS Power.
IN THE MATTER OF THE PUBLIC UTILITIES ACT - and - IN THE MATTER OF AN APPLICATION by NOVA SCOTIA POWER INCORPORATED for the approval of the Annually Adjusted Rates for 2026 BEFORE: Richard Melanson, LL.B. Panel Chair Jennifer L. Nicholson,...
AI summary This proceeding involves Nova Scotia Power Incorporated's application for the approval of Annually Adjusted Rates for 2026 under the Public Utilities Act. The application is before a panel consisting of Richard Melanson, Jennifer L. Nicholson, and Bruce H. Fisher.
ORDER The Board's decision dated March 9, 2026, approved the 2026 Annually Adjusted Rates (AARs) effective April 1, 2026. The Board retained its jurisdiction to amend the AARs following the outcome of the updated Cost of Service Study in t...
AI summary The Board approved the 2026 Annually Adjusted Rates (AARs) on March 9, 2026, and retained jurisdiction to amend them based on the updated Cost of Service Study in the NS Power General Rate Application (GRA) matter M12451. NS Power filed a compliance filing with revisions to seven AARs on May 11, 2026.
The Board orders the following. - 1. NS Power's Annually Adjusted Rates, Schedules B to E and G to I, are amended effective April 1, 2026, for the period April 1, 2026, to December 31, 2026, or until such date as future rates are approved,...
AI summary The Board has amended NS Power's Annually Adjusted Rates, including several schedules related to transmission, distribution, and renewable energy services, effective April 1, 2026. All other rates approved in the April 1, 2026, order remain unchanged.
ENERGY CHARGE NSPI's actual hourly marginal energy costs, plus the following fixed cost adders for on-peak and offpeak usage: On-peak (7:00 am - 11:00 pm, non-holiday weekdays): 5.274 ¢/kWh Off-peak (11:00 pm - 7:00am, non-holiday weekdays...
AI summary NSPI's energy charge includes hourly marginal costs and fixed cost adders for on-peak and off-peak usage. On-peak adders are higher than off-peak, and weekend and holiday rates match off-peak. A credit is applied for customer-owned transformers based on monthly peak demand. These adders are annually developed and submitted for approval.
ENERGY CHARGE NSPI's actual hourly marginal energy costs, plus the following fixed cost adders for on-peak and offpeak usage: On-peak (7:00 am – 11:00 pm, non-holiday weekdays): 9.925 ¢/kWh Off-peak (11:00 pm – 7:00am, non-holiday weekdays...
AI summary NSPI's energy charge includes hourly marginal costs and fixed cost adders for on-peak and off-peak usage, with weekend and holiday rates set at off-peak levels. These adders are annually adjusted and submitted for approval. A credit is applied for customer-owned transformers based on peak demand.
- (2) A fixed cost adder adjusted concurrent with changes in base cost rates coming into effect as a result of a General Rate Case application. Energy Base Charge Components Transmission Voltage of Higher 69 kV or (cents per kWh) Distribut...
AI summary The text describes a fixed cost adder that is adjusted in line with changes in base cost rates resulting from a General Rate Case application. The table outlines energy base charge components, including fuel cost and fixed adder rates for different voltage levels.
Penalty for Non-Compliance All energy served after the 10-minute deadline has expired will be billed at $5.00 per kWh. In addition a fixed charge of $2,000.00 will be applied. The penalty charge is applicable above and beyond the Port Auth...
AI summary A penalty of $5.00 per kWh and a fixed charge of $2,000.00 applies to energy served after a 10-minute deadline, in addition to the Port Authority's monthly bill.
WHOLESALE MARKET BACKUP/TOP-UP SERVICE TARIFF
AI summary The document introduces the Wholesale Market Backup/Top-Up Service Tariff, which outlines the rates and terms for backup and top-up services in the wholesale market. It includes a reference to a visual element, likely a chart or table, for further details.
CUSTOMER CHARGE The monthly customer charge under this tariff is calculated according to the following formula: This charge will be $414.63 per month.
AI summary The monthly customer charge under the tariff is set at $414.63 per month, calculated according to a specified formula.
- (2) Demand-related fixed generation cost, coming into effect as a result of a General Rate Application. Demand Charge Components $ per kW of billing demand Demand-related Purchased Power Cost $6.222 Demand-related Fixed Generation Cost $...
AI summary The text introduces a demand-related fixed generation cost, which is part of a General Rate Application. It outlines demand charge components, including a demand-related purchased power cost and a demand-related fixed generation cost, with a total of $11.822 per kW of billing demand. The Contract Demand requirement is defined as the firm demand requested by a wholesale customer and agreed to be supplied by NSPI.
- (2) Energy-related fixed generation cost, coming into effect as a result of a General Rate Application. Energy Charge Components cents per kWh Energy-related Purchased Power and Fuel Cost 6.974 Energy-related Fixed Generation Cost 2.155...
AI summary This section outlines the energy-related fixed generation cost, which is part of a General Rate Application. It includes a table with energy charge components, highlighting the energy-related purchased power and fuel cost, as well as the energy-related fixed generation cost, totaling 9.129 cents per kWh. The Fuel Adjustment Mechanism (FAM) is also mentioned.
The FAM Actual Adjustment (AA) and Balance Adjustment (BA) charges or credits (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the FAM Tariff, shall apply, in addition to the energy charge.
AI summary The document outlines the application of FAM Actual Adjustment (AA) and Balance Adjustment (BA) charges or credits in cents per kilowatt-hour, which are to be applied in addition to the energy charge as part of the Tariff for the current rate year.
AVAILABILITY The tariff is available to wholesale customers as defined in section 2(d) of the Electricity Act , Chapter 25 of the Acts of 2004. (d) "wholesale customer" means Nova Scotia Power Incorporated or a municipal utility. The tarif...
AI summary The tariff is available to wholesale customers, defined as Nova Scotia Power Incorporated or municipal utilities. It applies to the scheduled backup/top-up load of participating customers under specific terms, including written notice requirements, contract demand, and third-party supplier arrangements. Applications must be submitted annually by certain deadlines, and metering equipment must be installed as per the Generation Interconnection Agreement.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: This charge will be $414.63 per month.
AI summary The monthly administration charge is set at $414.63 per month and applies to each Load Serving Retailer annually according to a specified formula.
ENERGY CREDIT 6.736 cents per kilowatt-hour. The Energy Credit for spill service is set annually and is applicable to spilled energy in each hour.
AI summary The Energy Credit for spill service is set at 6.736 cents per kilowatt-hour and is applied annually to spilled energy in each hour.
MINIMUM MONTHLY CHARGE The minimum monthly charge will be the administration charge.
AI summary The minimum monthly charge is defined as the administration charge, establishing a baseline fee for service.
ADMINISTRATION CHARGE The monthly administration charge is applicable to each LRS and is set annually according to the following formula: This charge will be $414.63 per month.
AI summary The monthly administration charge is set at $414.63 per month and applies to each Load Serving Retailer (LRS), determined annually using a specified formula.
MINIMUM MONTHLY CHARGE The minimum monthly charge will be the administration charge.
AI summary The minimum monthly charge is defined as the administration charge in this regulatory proceeding.
PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...
AI summary This Renewable to Retail Market Transition Tariff (RTT) is established under the Electricity Act to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing costs, and operational expenses, and are not otherwise recovered through other applicable tariffs.
The Energy Charge is made up ofthe following components: Energy Charge Components cents per kWh Adder Tariff Fixed Cost from Energy Balancing Service 2.155 Annually Adjusted Energy Savings Credit 0.000 Annual Energy Cost Adjustment 2.171 T...
AI summary The Energy Charge comprises several components, including an Adder Tariff, Annual Energy Cost Adjustment, and others, totaling 4.326 cents per kWh. It applies to the LRS' monthly displaced energy on NS Power's generation system, calculated as the total monthly LRS load minus the top-up quantity determined under the Energy Balancing Service Tariff.
SPECIAL CONDITIONS (1) Nothing contained in this RTT or any service agreement shall be construed as affecting or in any way limiting the right of NS Power to make application to the Nova Scotia Energy Board for a change in any rates, terms...
AI summary This section of the RTT outlines that NS Power retains the right to apply to the Nova Scotia Energy Board for changes to rates, terms, and conditions, including those specified in the RTT, Standby Service Tariff, and Energy Balancing Service Tariff.
June 15, 2026 Crystal Henwood Clerk of the Board Nova Scotia Energy Board 1601 Lower Water Street, 3rd Floor Halifax, NS B3J 3S3 Re: M12551 2026 Annually Adjusted Rates – Stakeholder Engagement Update On March 9, 2026, the Nova Scotia Ener...
AI summary The Nova Scotia Energy Board (NSEB) approved the 2026 Annually Adjusted Rates (AARs) but directed NS Power to initiate stakeholder engagement on issues raised by Renewall Energy Inc. (REI) regarding Renewable to Retail (RtR) tariffs by April 30, 2026. The Board emphasized the need for a realistic timeline for any future application.
in these matters. Given the scope of these additional work streams also includes potential revisions to the RTR Tariffs, it may be the outcome of these projects will also affect the outcome of M12551. NS Power will continue to keep the Boa...
AI summary The text discusses ongoing work streams, including potential revisions to RTR Tariffs, and their possible impact on M12551. NS Power will provide updates in the 2027 AAR Application, filed by November 6, 2027.
June 22, 2026 [[email protected]](mailto:[email protected]) [[email protected]](mailto:[email protected]) Nancy Rubin Brianne Rudderham Stewart McKelvey Suite 600 – 1741 Lower Water Street P.O. B...
AI summary NS Power provided an update on stakeholder engagement related to the 2026 Annually Adjusted Rates (AAR) decision, specifically regarding the Renewable to Retail (RtR) tariffs. NS Power has shared marginal cost data with Renewall Energy Inc. (REI) but has not received feedback. The Board is seeking REI's comments on the status of the issue, with a response due by July 6, 2026.
Delivered by E-mail Crystal Henwood Regulatory Affairs Officer/Clerk Nova Scotia Energy Board 3rd Floor, 1601 Lower Water Street PO Box 1692, Unit "M" Halifax NS B3J 3S3 Dear Ms. Henwood: Re: M12551 - 2026 Annually Adjusted Rates – Stakeho...
AI summary Renewable Energy Inc. (REI) is responding to the Nova Scotia Energy Board's request for an update on stakeholder engagement related to the Renewable to Retail (RtR) matters following the 2026 Annually Adjusted Rates decision.
ANTICIPATED COMMENCEMENT OF RETAIL OPERATIONS REI anticipates commencing retail operations as approved under its license, before December 31, 2026. While REI will require the updates to the RtR tariff framework to be in place before it beg...
AI summary REI plans to start retail operations by December 31, 2026, pending updates to the RtR tariff framework. REI expects these updates, including those for distributed generation and net billing, to be implemented before entering the market in Q4 2026. REI is willing to engage with NS Power and the Board on these matters.
mprehensive way. REI would welcome the opportunity to discuss with the Board and with NS Power the appropriate vehicle and timeline for that proceeding. Document: 331778 REI indicates it anticipates entering the market in Q4 2026, or by De...
AI summary REI plans to enter the market by December 31, 2026, and anticipates discussing the appropriate vehicle and timeline for proceeding with the Board and NS Power. The Board is concerned about the short timeframe for considering RtR tariff adjustments, as they may impact other customers and require stakeholder input. The Board suggests that the Annually Adjusted Rates process may not be suitable for setting the cost recovery mechanism for the renewable to retail market, and a separate process may be more advisable.
August 31, 2026 Crystal Henwood Clerk of the Board Nova Scotia Energy Board 1601 Lower Water Street, 3rd Floor Halifax, NS B3J 3S3 Re: M12551 – 2026 Annually Adjusted Rates – Stakeholder Engagement Update (RtR Tariffs) Dear Ms. Henwood: No...
AI summary NS Power responded to the Board's July 15, 2026 letter regarding the 2026 Annually Adjusted Rates (AAR) and Renewable to Retail (RtR) tariff amendments. NS Power provided additional marginal cost data and explained its position that introducing time-variable pricing (TVP) for AARs is premature due to limited data availability. A review of RtR market elements is planned for 2028.
(c) RtR Market Element Updates Application (M12339/M13008) On July 31, 2026, NS Power filed its RtR Market Element Updates Application (M13008), in accordance with the Board's November 19, 2025 directive in M12339.[1](#page-2-0) That appli...
AI summary NS Power filed an application (M13008) on July 31, 2026, proposing revisions to several tariffs and the establishment of a new DAS Tariff, in accordance with a prior directive (M12339). The application was developed with REI and Power Advisory LLC, and no changes were proposed for certain other regulations. The DAS Tariff administration fee will be determined in the 2027 AAR Application.
Disclaimer: These summaries were generated by AI from the filings they describe. We take care to make them accurate, but errors are possible - and they aren't advice. Only the filings themselves are the record: if you're relying on something here, confirm it against the source documents or the Nova Scotia Energy Board's own record. Full disclaimer →