Topic:"Rate Rider" in M12551

Application for Annually Adjusted Rates for 2026 Redacted 1 LIST OF FIGURES 6 take service under the RTR Tariff and provide their recommendations in the 2025 AAR 7 application"9 – this is addressed in section 7.4. 8 9 1.2 Board Directive r...

AI summary The document discusses the application for annually adjusted rates for 2026 and references the Board's directive regarding time-varying pricing (TVP) structures for AARs. It notes the 2023 AAR decision, the extension of the TVP pilot, and the requirement for NS Power to engage with stakeholders after the pilot's completion and evaluation.

Application for Annually Adjusted Rates for 2026 Redacted 1 (2) Forward commodity market returns volatility of negative 1.5 standard deviations (-1.5 σ) 2 for the following fuel prices: AECO, AGT, HFO, AP12, Mass Hub Off-Peak, and Mass 3 H...

AI summary NS Power is applying for annually adjusted rates for 2026 and requests the removal of the 'no surplus energy flow' scenario from future applications, citing steady-state operations on the Labrador Island Link and Maritime Link. It also argues that the 'no new wind' scenario is not plausible given current project timelines and forecast information.

6 DATE FILED: November 7, 2025 Page 18 of 45 3 The calculations for the 2026 Fixed Cost adder are provided in Partially Confidential Appendix 4 B2 . Please also refer to Partially Confidential Appendix D for usage determinants used in rate...

AI summary The document discusses the 2026 Fixed Cost adder calculations and references partially confidential appendices for usage determinants and rate calculations. It also mentions the HV RTP Tariff and a customer's migration of interruptible load from the Large Industrial Interruptible Rider.

Application for Annually Adjusted Rates for 2026 Redacted 1 5.0 SHORE POWER TARIFF 2 3 Service under the Shore Power (SP) Tariff is a seasonal priority interruptible service, which 4 starting in 2026 is proposed to be differentiated by two...

AI summary The document outlines the proposed changes to the Shore Power (SP) Tariff for 2026, including voltage level differentiation and a decrease in rates due to changes in marginal fuel cost and non-fuel cost components, as detailed in the 2026-2027 General Rate Application (GRA) under matter M12451.

1 6.0 WHOLESALE MARKET TARIFFS 2 3 Two tariffs applicable to Wholesale Market participants are adjusted on an annual basis: the Back- 4 up/Top-up (BUTU) Tariff and the Wholesale Market Spill (Spill) Tariff. 5 6 The BUTU Tariff provides opt...

AI summary The document discusses the BUTU and Spill Tariffs applicable to Wholesale Market participants, noting that four Municipal Electric Utilities (MEUs) intend to take service under the BUTU Tariff in 2026. The 2026-2027 General Rate Application includes assumptions about reciprocal billing arrangements and contract demand levels for MEUs.

Application for Annually Adjusted Rates for 2026 Redacted 1 • the non-FAM-based component of 2.166 per kWh, as provided in Appendix F2 . 2 3 With the 2026 BUTU rate representing the last of the four-year phase-in, the non-FAM rate 4 compon...

AI summary The document outlines the completion of the non-FAM-based rate phase-in for 2026, indicating that no further adjustments are required as the final year of the phase-in has been reached. Reference is made to Appendix F2 and Figure 5 for details on the rate components and methodology.

18 Figure 7: BUTU Tariff Charges 2025 2026 Variance Customer Charge ($/customer/month) 401.58 414.63 13.05 Energy Charge (cents per kWh) 10.577 9.150 (1.428) Demand Charge ($/kW) 7.160 11.704 4.544 Application for Annually Adjusted Rates f...

AI summary Figure 7 presents BUTU Tariff Charges for 2025 and 2026, showing increases in customer and demand charges, and a decrease in energy charges. The document also references an application for Annually Adjusted Rates for 2026.

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.

21 Figure 8: Spill Tariff Charges 2025 2026 Variance Administration Charge ($/supplier/month) 2,409.46 2,487.77 78.31 Energy Credit (cents per kWh) 8.919 6.736 (2.183) 22

AI summary Figure 8 presents spill tariff charges for 2025 and 2026, showing an increase in the administration charge and a decrease in the energy credit per kWh.

1 7.0 RENEWABLE TO RETAIL MARKET TARIFFS 2 - 3 This AAR Application includes three Renewable to Retail (RtR) tariffs: the Energy Balancing - 4 Service (EBS) Tariff, Standby Service (SS) Tariff, and Renewable to Retail Market Transition - 5...

AI summary This section discusses the Renewable to Retail (RtR) tariffs, including the Energy Balancing Service (EBS) Tariff, Standby Service (SS) Tariff, and Renewable to Retail Market Transition (RTT) Tariff. It also outlines Renewall Energy Inc.'s efforts to obtain a license to sell renewable low-impact electricity, including extensions granted by the Board and a conditional Power Purchase Agreement for the Mersey River Wind project.

40 M11874, RTR Implementation Cost – Board IR 01. 41 M11874: RTR Implementation Cost – Board IR-01.

AI summary The text references two instances of matter number M11874, which pertains to the RTR Implementation Cost and is associated with Board IR 01.

7 7.2 Standby Service Tariff 8 6 9 The Standy Service (SS) Tariff is a mandatory tariff applicable to LRSs for supplemental standby 10 generation capacity service provided in combination with EBS under the EBS Tariff. The SS Tariff 11 has...

AI summary The Standby Service (SS) Tariff includes an Administration Charge and a Demand Charge. The Administration Charge is set annually and is aligned with the EBS Tariff. The Demand Charge is based on the 2026 Cost of Service Study, proposing a rate of $5.452 per month per kilowatt of monthly standby contract demand.

16 7.3.1 RTT Energy Charge 17 - 18 The RTT Energy Charge has three components: Fixed Cost Adder, Annually Adjusted Energy - 19 Savings Credit and Annual Energy Cost Adjustment. - 21 The charge is designed to only apply to the LRS' monthly...

AI summary The RTT Energy Charge consists of three components: Fixed Cost Adder, Annually Adjusted Energy Savings Credit, and Annual Energy Cost Adjustment. It applies to the LRS' monthly displaced energy on NS Power's generation system, with 50% of RtR Market energy assumed to be displaced energy from direct deliveries by third-party suppliers.

1 Figure 11: Renewable to Retail Transition Tariff Charges by Cost Components Energy Charge by Components (cents per kWh) 2025 2026 Variance Fixed Cost Adder from EBS Tariff 3.264 2.166 (1.099) Annually Adjusted Energy Savings Credit 0.000...

AI summary Figure 11 presents the Renewable to Retail Transition Tariff Charges by Cost Components for 2025 and 2026, showing changes in energy and demand charges. Energy charges include a Fixed Cost Adder from EBS Tariff, an Annual Energy Cost Adjustment, and a total energy charge. Demand charges include a Demand Charge from Standby Service Tariff and a total demand charge.

4 7.4 Board Directive regarding Interruptible Service in the RTR Market 5 6 The Board provided the following directive in its Order, dated March 20, 2024, approving the 2024 7 AARs: 8 9 NS Power and Roswall are directed to explore ways in...

AI summary The Board directed NS Power and Roswall to explore interruptible service under the RtR Tariff and provide recommendations in the 2025 AAR application. NS Power proposed Terms of Reference for a pilot to Renewall, but has not yet received a response. The pilot, once approved, aims to provide insights into the interruptible process within the RtR market.

1 Figure 12: Calculation of ELIADC Energy Charge Item Description 2026 ($/MWh) A CBL Cost 73.60 B FCR 3.75 C=A–B CBL Energy Charge 69.85 D CBL Adder 5.00 E Variable Capital Cost 1.02 F=C+D+E ELIADC Energy Charge 75.87 2

AI summary Figure 12 outlines the calculation of the ELIADC Energy Charge for 2026, breaking down components such as the Customer Baseline Cost, Fixed Cost Recovery, and Variable Capital Cost to arrive at the final energy charge of $75.87 per MWh.

Application for Annually Adjusted Rates for 2026 Redacted • If CBL Cost ≤ $56.75/MWh : CBLA = 75% × (61.75 – CBL Cost)[49](#page-40-1) 1 2 3 • If CBL Cost > $56.75/MWh and < $61.75/MWh : CBLA = [75% × (61.75 – CBL Cost)] + [FCR – (75% × (6...

AI summary The document outlines the calculation of the Customer Baseline Adder (CBLA) for 2026, based on the Customer Baseline (CBL) Cost and Fixed Cost Recovery (FCR). The CBLA is set at $5.00/MWh for 2026, reflecting the full recovery of the minimum FCR under the revised tariff, an increase from $1.00/MWh in 2025.

14 Figure 13: CBL Adder 2026 ($/MWh) annually, instead of setting it once for the term of the ELIADC tariff as originally designed. 9 In its Decision on the 2021 AARs, the Board provided: 11 The Board accepts NS Power's proposal to update...

AI summary The document discusses the Board's decision regarding the annual adjustment of the Variable Capital Charge (VCC) in the ELIADC tariff. The Board accepted NS Power's proposal to update the VCC annually but noted inconsistencies in the Utilization Factor (UF) applied to the 'with PHP' scenario for Lingan-3, disallowing the application of the Sustaining Capital Delta.

5 8.2 ELIADC Energy Charge Calculation 6 7 The ELIADC Energy Charge is composed of the CBL Energy Charge (i.e. CBL Cost net of FCR 8 which is transferred to the CBLA, as described in Section 8.1), CBLA, and VCC. 9 - 10 Figure 15 presents t...

AI summary The ELIADC Energy Charge is calculated using the CBL Energy Charge, CBLA, and VCC. The 2026 ELIADC Energy Charge is set at $75.87/MWh, with the proposed tariff detailed in Appendix G1 and a redline version in Appendix H. The amendments to the ELIADC Tariff are based on the Company's October 31, 2025 Compliance Filing under M12184.

16 Figure 15: ELIADC Energy Charge Energy Charge by Component 2026 ($/MWh) CBL Energy Charge 69.85 CBLA 5.00 Variable Capital Cost 1.02 Total $75.87 Application for Annually Adjusted Rates for 2026 Redacted 1 9.0 RELIEF SOUGHT 2 3 NS Power...

AI summary The document presents the ELIADC Energy Charge for 2026, including various components such as CBL Energy Charge, CBLA, and Variable Capital Cost. It also includes an application for Annually Adjusted Rates for 2026, requesting the removal of a specific sensitivity analysis and approval of proposed tariff changes.

SERVICE DEFINITION Service under this tariff consists in delivery of supplemental power to partial requirement customers who operate their own dispatchable generation equipment, as approved to be connected to the grid by the Company. The S...

AI summary The Service under this tariff provides supplemental power to partial requirement customers with their own dispatchable generation equipment. It includes Generation Replacement, Optional Load Following, and Spill Service, with specific definitions for each component and billing under full requirement tariffs for supplementary power.

AVAILABILITY This tariff is available to: - (a) Customers who have their own qualifying generating facility of not less than 2,000 kW of aggregate capacity, as defined under Special Condition 8, normally used to support their own load; - (...

AI summary The tariff is available to customers with qualifying generating facilities or those supplying energy to Non-Utility Owned Generation sites. It outlines conditions for energy supply, pricing based on notification timelines, and load reduction requirements in case of supply interruptions. Customers must maintain communication systems for load interruption notices.

GENERATION REPLACEMENT AND LOAD FOLLOWING TARIFF Page 3 of 5 Company will exercise the automated control of the customer's load to interrupt the customer load. - (4) Following interruption, service may only be restored by the customer with...

AI summary The Generation Replacement and Load Following Tariff outlines procedures for load interruption, penalties for non-compliance, and requirements for metering equipment. The Performance Penalty formula is based on residual demand and average demand during the interruption event, with penalties capped at twice the firm billing cost for the period.

SPECIAL CONDITIONS - (1) The Company reserves the right to have a separate service agreement, if in the opinion of the Company issues not specifically set out herein, must be addressed for the ongoing benefit of the Company and its custome...

AI summary The special conditions outlined include the company's right to establish separate service agreements and the customer's responsibility to maintain power supply system integrity through proper design and operation.

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 hourly marginal costs and fixed cost adders for on-peak and off-peak usage. On-peak adders are significantly higher than off-peak, and weekend and holiday rates use the off-peak price. Fixed cost adders are updated annually and submitted for approval. A credit is applied for customer-owned transformers based on peak demand.

AVAILABILITY - (1) Customers must make a written request to take service under this tariff. - (2) This tariff is available to customers who are served at transmission voltage of 69 kV or higher and have loads of 2,000 KVA or 1,800 kW, and...

AI summary The tariff is available to customers served at 69 kV or higher with loads of 2,000 KVA or 1,800 kW and over, who must make a written request to take service under this tariff.

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): 10.008 ¢/kWh Off-peak (11:00 pm – 7:00am, non-holiday weekday...

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 determined annually and submitted for approval to the Nova Scotia Energy Board. A credit is also applied for customer-owned transformers based on peak demand.

AVAILABILITY - (1) Customers must make a written request to take service under this tariff. - (2) This tariff is available to customers who are served at voltage less than 69 kV and have loads of 2,000 KVA or 1,800 kW, and over.

AI summary The tariff is available to customers with voltage less than 69 kV and loads of 2,000 KVA or 1,800 kW or more, who must make a written request to take service under this tariff.

2026 AAR Application Appendix B1 Page 5 of 6 REDACTED (CONFIDENTIAL INFORMATION REMOVED) will be required to make a capital contribution equal to the additional capital cost of primary metering as opposed to the cost of secondary metering....

AI summary The document outlines the terms and conditions for customers taking service under a specific tariff, including capital contribution requirements, transformer loss adjustments, service duration, and power factor maintenance. It also details transition rules for customers moving from interruptible to firm service and vice versa.

NON-CONFIDENTIAL 1 NS Power utilizes the Partially Confidential electronic Excel file, Appendix B2, to calculate the 2 1P-RTP rates by using the following method. 3 4 • The costing determinants such as Monthly Energy requirement, Monthly s...

AI summary NS Power uses a Partially Confidential Excel file to calculate 1P-RTP rates by inputting costing determinants, fixed costs from the 2026 Cost of Service Study, and breaking down fixed costs by expense type and customer service level. The company no longer includes fuel cost adjustments in the Adders, as per its October 2025 memorandum.

22 Cost of Service Fixed Cost Riders 23 24 (a) Generation Cost Fixed Cost. 25 26 (i) The generation total cost of $426.9 million broken down into expense type 27 (operating, capital, and Return) in the 2026 Cost of service is apportioned t...

AI summary The document discusses the allocation of generation costs in the 2026 Cost of Service Study, including the apportionment of costs based on coincident peaks and the derivation of fixed cost rates by service level. The methodology involves dividing generation costs by on-peak sales in kWh and references Appendix B for detailed rider calculations.

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.

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, applying from April 1 to November 30, and outlines the order in which rate classes are called upon during supply shortfalls.

2026 AAR Application Appendix C1 Page 2 of 4 REDACTED (CONFIDENTIAL INFORMATION REMOVED) SHORE POWER TARIFF Page 2 of 4 A credit equal to 32 cents per peak kilovolt-ampere of monthly peak demand will be applied where the transformer is own...

AI summary The document outlines a credit mechanism of 32 cents per peak kilovolt-ampere for customers with transformers owned by them and served at transmission voltage levels, as part of the Shore Power Tariff.

SUPPLY INTERRUPTIONS This is an interruptible service. Before connecting the ship to the shore supply the port authority will request permission from NSPI indicating the expected load and duration for which the power is needed. The custome...

AI summary This section outlines the requirements for interruptible service under the tariff, including customer obligations to provide notice, reduce load promptly, maintain communication systems, and comply with interruption requests to avoid penalties.

BUTU Capacity Credit Calc. Approved Net Demand Installed Capacity Capacity Credit Contract Demands (kWs) FAM-related Demand Charge Gross Demand Payment payment bfr Credits Capacity Credit Ellershouse Imports 23,500 20.5% 0% 7,549 $6.252 $6...

AI summary This document presents a capacity credit calculation table related to Ellershouse Imports, including installed capacity, capacity credit, contract demands, and financial figures. The table includes a total capacity credit of -301,764, which may relate to a 2026 AAR Application Appendix E4.

REDACTED 2026 AAR Application Appendix E5 Page 1 of 1 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 2026 BUTU (NSPI-P-889) Updated for change in Interruptible Rider 2009 BUTU (NSPI-P-889) Three Winter Season Average Coincident Factor Wnter S...

AI summary The document contains redacted information from a 2026 AAR Application Appendix, including a table related to the BUTU (NSPI-P-889) and updated Interruptible Rider details. It includes data on winter season average coincident factors and annual levelized capacity costs for transmission losses and monthly charges.

ENERGY BALANCING SERVICE The Energy Balancing Service is a supplemental generation service provided to Licenced Retail Suppliers (LRS) in respect of the Licenced Retail Supplier's Renewable to Retail (RtR) Customers utilizing the productio...

AI summary The Energy Balancing Service is a supplemental generation service provided to Licensed Retail Suppliers (LRS) for their Renewable to Retail (RtR) Customers. It ensures service reliability by delivering complementary energy and receiving surplus generation, and must be used with Standby Service under the Standby Service Tariff.

ENERGY BALANCING SERVICE TARIFF Page 2 of 3 Renewable to Retail generation adjusted by the deduction of transmission locational losses, as applicable to the geographic zone in which the generating facility is interconnected, over its aggre...

AI summary The Energy Balancing Service Tariff outlines requirements for renewable energy generation and load balancing, including locational loss adjustments, compliance with regulations, and spill capacity approvals by NS Power. The LRS must ensure renewable generation aligns with consumption over a compliance period.

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 establish separate service agreements when necessary for the benefit of its customers and the power supply system. Specific operating agreements are required to ensure that generation and load do not compromise system integrity. NS Power also retains the right to apply for changes in rates or service terms through the Nova Scotia Energy Board.

APPLICABILITY - (1) The RTT is applicable to the LRS, and is in addition to (and not in substitution of) any charges owing by the LRS to NS Power under the Open Access Transmission Tariff (OATT), the Standby Service Tariff, or the Energy B...

AI summary The Renewable to Retail Market Transition Tariff (RTT) applies to Licensed Retail Suppliers (LRS) and operates alongside other tariffs such as the Open Access Transmission Tariff (OATT), Standby Service Tariff, and Energy Balancing Service Tariff. The RTT includes energy and demand charges with annual adjustments based on forecasted differences between NS Power's avoided costs and system fuel costs.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 1 of 8 The Extra Large Industrial Active Demand Control Tariff (ELIADC) provides a mechanism whereby Port Hawkesbury Paper LP (PHP, the Mill, the Customer) pays the forecast incremen...

AI summary The ELIADC tariff allows Port Hawkesbury Paper LP to pay forecast incremental costs and contribute to utility costs, while granting Nova Scotia Power control over the customer's load to reduce system costs and improve reliability for all customers.

COST OF ELECTRICITY UNDER THE ELIADC TARIFF The price paid by PHP for electricity under this Tariff will be based on the forecast incremental cost to serve PHP at an assumed levelized baseline load level, plus an adder to contribute to the...

AI summary The ELIADC Tariff sets the price PHP pays for electricity based on forecast incremental costs, with adjustments for system savings and incentives for Active Demand Control. Key elements include baseline energy costs, adders, and credits for demand control contributions.

Minimum Payment The ELIADC Tariff requires that a minimum payment shall be made by PHP in respect of each tariff year, which shall not be less than the sum of: - (a) NS Power's actual total incremental cost of serving PHP during the year (...

AI summary The ELIADC Tariff mandates a minimum payment by PHP, calculated as the sum of NS Power's actual incremental costs and a fixed cost recovery component based on MWh supplied. Adjustments to meet this minimum are determined and charged after the year ends.

Customer Baseline Energy Charge, Customer Baseline Energy Cost, and Contribution to Utility Costs In advance of each tariff year, PHP shall advise NS Power of its forecast annual and monthly energy requirements for the subsequent calendar...

AI summary PHP is required to provide NS Power with its forecasted energy requirements, and NS Power calculates a Customer Baseline Load (CBL) Cost, which includes incremental non-capital costs. The CBL Adder (CBLA) is calculated based on the CBL Cost and is used to determine the ELIADC Energy Charge. The CBLA increases as the CBL Cost decreases, with specific formulas outlined for different CBL Cost ranges.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 3 of 8 $61.75/MWh. The FCR transferred from the CBL Cost is then added to the calculated CBLA to equal $5/MWh FCR. • When the forecast CBL Cost is at or over $61.75/MWh, the FCR to b...

AI summary The ELIADC Tariff outlines how the Energy Load Incentive and Demand Control Tariff energy charge is calculated, including the Fixed Cost Recovery (FCR) transfer from the Customer Baseline (CBL) Cost to the CBL Adder (CBLA), and the addition of a Variable Capital Charge (VCC) to determine the final energy charge per MWh.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 4 of 8 - (b) Material and unexpected change in the cost of generation as compared to the CBL Energy Charge calculation; - (c) Material and unexpected increased electricity consumptio...

AI summary The document outlines conditions under which changes to the Customer Baseline Energy Charge (CBL Energy Charge) may be required for PHP, including unexpected changes in generation costs, increased or decreased electricity consumption due to specific events. If PHP and NS Power cannot agree, the matter may be submitted to the Board for expedited adjudication, with the Minimum Payment remaining unchanged.

ACTIVE DEMAND CONTROL AND SCHEDULE VARIANCE NS Power shall be entitled to actively manage PHP's load in accordance with the terms and conditions set out in the Active Demand Control – Energy Supply Protocol attached as Schedule 1 to this T...

AI summary NS Power is allowed to manage PHP's load under the Active Demand Control protocol. Annual reports are required to the Board, detailing system savings and schedule variances. PHP is entitled to a 25% credit based on the difference between the Customer Baseline Cost and the actual annual cost to serve them.

TERM The third term of this Tariff is 2026, unless revised per a Decision of the NSEB (Term). Prior to the end of the third term, NS Power or PHP may apply to the Board for approval of a subsequent term for this Tariff, including the appro...

AI summary The third term of the Tariff is set for 2026, subject to revision by a decision from the NSEB. NS Power or PHP can request the Board's approval for a subsequent term, including adjustments to pricing elements or PHP's transition to an alternative tariff.

REOPENER If, at any time during the Term, NS Power or PHP determines that the ELIADC Tariff is not working effectively, the parties shall work together to try to resolve any such concerns. If the parties cannot resolve such concerns, eithe...

AI summary The reopener clause allows NS Power or PHP to request adjustments to the ELIADC Tariff if it is not functioning effectively, with the Board having the authority to make expedited adjustments to protect customers. PHP would then have the option to remain on the adjusted Tariff.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 6 of 8 Load interruption calls will be made to PHP in advance of all such calls to NS Power's Large Industrial Interruptible Rider customers. Where the customer has provided NS Power...

AI summary The Extra Large Industrial Active Demand Control Tariff outlines procedures for load interruption, including penalties for non-compliance. PHP is required to comply with interruption calls, and failure to do so results in Threshold and Performance Penalties. Penalties are calculated based on residual demand and performance during interruptions, with limits on the total penalty amount and interruption duration.

Conversion of Interruptible Load to Firm Should PHP desire to be served under any applicable firm service tariff, a five-year advance written notice must be given to NS Power so as to ensure adequate capacity availability. Requests for a c...

AI summary The document outlines the process for converting interruptible load to firm service, requiring a five-year advance written notice to NS Power to ensure adequate capacity availability. Such requests are treated like all other firm service requests.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 7 of 8 received by NS Power. NS Power may, however, permit an earlier conversion. If PHP desires to return to interruptible service in the future, PHP may convert to an interruptible...

AI summary The document outlines the conditions under which PHP can convert between firm and interruptible service tariffs under the ELIADC tariff, with NS Power having the authority to permit earlier conversions.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 1 of 8 The Extra Large Industrial Active Demand Control Tariff (ELIADC) provides a mechanism whereby Port Hawkesbury Paper LP (PHP, the Mill, the Customer) pays the forecast incremen...

AI summary The ELIADC tariff allows Port Hawkesbury Paper LP to pay forecasted incremental costs and contribute to utility costs while granting NS Power control over the customer's load to reduce system costs and improve reliability for all customers.

Customer Baseline Energy Charge, Customer Baseline Energy Cost, and Contribution to Utility Costs In advance of each tariff year, PHP shall advise NS Power of its forecast annual and monthly energy requirements for the subsequent calendar...

AI summary PHP is required to provide NS Power with its forecast energy requirements and maintenance schedules to calculate the Customer Baseline Load (CBL) Cost, which includes fuel, purchased power, line losses, and variable operating costs. The CBL Adder (CBLA) is calculated based on the CBL Cost and includes the Fixed Cost Recovery (FCR) when the CBL Cost is below a certain threshold.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 3 of 8 $61.75/MWh. The FCR transferred from the CBL Cost is then added to the calculated CBLA to equal $5/MWh FCR. When the forecast CBL Cost is at or over $61.75/MWh, the FCR to be...

AI summary The ELIADC tariff structure includes a CBL Energy Charge, CBLA, and VCC. When the forecast CBL Cost is over $61.75/MWh, the FCR transferred is capped at $3.75/MWh, and the CBLA is set to $5/MWh. These charges are submitted annually for Board approval as part of NS Power's rate adjustments.

ELIADC ENERGY CHARGE Information on the CBL Energy Charge and VCC for 2026 will be provided to the Board by November 7, 2025.The ELIADC Energy Charge is $75.87 per Megawatt- hour

AI summary The ELIADC Energy Charge is set at $75.87 per Megawatt-hour for 2026. Information on the CBL Energy Charge and VCC will be submitted to the Board by November 7, 2025.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 4 of 8 (a) It becomes apparent that the CBL Energy Charge plus the CBLA plus the Variable Capital Charge will not result in the recovery of the actual incremental cost to serve plus...

AI summary The text outlines conditions under which the CBL Energy Charge, CBLA, and Variable Capital Charge may not recover the actual incremental cost to serve plus $5/MWh FCR. It also describes scenarios that could lead to a submission to the Board for expedited adjudication if PHP and NS Power cannot agree on necessary changes.

ACTIVE DEMAND CONTROL AND SCHEDULE VARIANCE NS Power shall be entitled to actively manage PHP's load in accordance with the terms and conditions set out in the Active Demand Control – Energy Supply Protocol attached as Schedule 1 to this T...

AI summary NS Power is permitted to manage PHP's load under the Active Demand Control – Energy Supply Protocol. NS Power must annually report system savings and load shifting benefits to the Board, including impacts of schedule variances. PHP is entitled to a 25% credit based on the cost differential between the Customer Baseline Load and actual annual costs to serve PHP.

TERM The third term of this Tariff is 2026, unless revised per a Decision of the NSEB (Term). Prior to the end of the third term, NS Power or PHP may apply to the Board for approval of a subsequent term for this Tariff, including the appro...

AI summary The third term of the Tariff is set for 2026, subject to potential revision by a decision from the NSEB (Term). Either NS Power or PHP can request the Board's approval for a subsequent term, including adjustments to the Tariff's pricing elements or PHP's transition to an alternative tariff.

REOPENER If, at any time during the Term, NS Power or PHP determines that the ELIADC Tariff is not working effectively, the parties shall work together to try to resolve any such concerns. If the parties cannot resolve such concerns, eithe...

AI summary The document outlines the process for adjusting the ELIADC Tariff if it is not working effectively. If NS Power or PHP determines this, they must attempt to resolve the issue together. If unresolved, either party may request the Board to adjust the tariff, with the possibility of expedited approval to protect customers. PHP would then decide whether to remain on the adjusted tariff.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 6 of 8 Load interruption calls will be made to PHP in advance of all such calls to NS Power's Large Industrial Interruptible Rider customers. Where the customer has provided NS Power...

AI summary This section of the ELIADC Tariff outlines the process for load interruption calls made to PHP, the conditions under which NS Power may hold PHP's load as Operating Reserve, and the penalty charges for non-compliance. Penalties include a Threshold Penalty and a Performance Penalty based on specific formulas.

Conversion of Interruptible Load to Firm Should PHP desire to be served under any applicable firm service tariff, a five-year advance written notice must be given to NS Power so as to ensure adequate capacity availability. Requests for a c...

AI summary PHP must provide five years' written notice to NS Power if it wishes to convert from interruptible load to firm service, ensuring capacity availability. Conversion requests are handled like all other firm service requests.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 7 of 8 received by NS Power. NS Power may, however, permit an earlier conversion. If PHP desires to return to interruptible service in the future, PHP may convert to an interruptible...

AI summary The document outlines the conditions under which Port Hawkesbury Paper LP (PHP) can convert between firm and interruptible service tariffs under the ELIADC tariff. PHP can request an earlier conversion to firm service if needed, and may return to interruptible service after two years under the firm tariff, with NS Power's approval.

AVAILABILITY This Energy Balancing Service Tariff is applicable to the LRS in order to facilitate the purchase of renewable low-impact electricity by RtR Customers. This Energy Balancing Service Tariff is provided under the following terms...

AI summary The Energy Balancing Service Tariff applies to the LRS to enable the purchase of renewable low-impact electricity by RtR Customers, subject to a valid LRS Participation Agreement with NS Power and service provision to RtR Customers.

APPLICABILITY - (1) An LRS taking service under this Energy Balancing Service Tariff shall also take service under the Open Access Transmission Tariff (OATT), the Standby Service Tariff, and the Renewable to Retail Market Transition Tariff...

AI summary This section outlines the applicability of the Energy Balancing Service Tariff, specifying that LRS must also take service under other tariffs, and clarifies how service is based on metered energy quantities and independent of forecasts. It also defines how hourly top-up and spill quantities are calculated.

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 establish separate service agreements when necessary for the benefit of its customers and the power supply system. The LRS' RtR Customers and generators must ensure their operations do not compromise system integrity, with specific requirements outlined in written agreements. NS Power retains the authority to apply for changes in rates and terms through the Nova Scotia Utility and Review Energy Board.

SERVICE DEFINITION Service under this tariff consists in delivery of supplemental power to partial requirement customers who operate their own dispatchable generation equipment, as approved to be connected to the grid by the Company. The S...

AI summary The service definition outlines three components of power delivery for partial requirement customers with dispatchable generation equipment: Generation Replacement Service, Optional Load Following Service, and Spill Service. These services address backup power, load imbalances, and excess generation, respectively, with specific billing arrangements under applicable tariffs.

GENERATION REPLACEMENT AND LOAD FOLLOWING TARIFF Page 2 of 5 This tariff is available to: - (a) Customers who have their own qualifying generating facility of not less than 2,000 kW of aggregate capacity, as defined under Special Condition...

AI summary This tariff outlines the Generation Replacement and Load Following Service available to customers with qualifying generating facilities or those supplying energy to Non-Utility Owned Generation sites. It details how energy will be supplied, pricing mechanisms, and customer responsibilities in cases of supply interruptions, including the requirement for customers to reduce load promptly when notified.

GENERATION REPLACEMENT AND LOAD FOLLOWING TARIFF Page 3 of 5 - (4) Following interruption, service may only be restored by the customer with approval of the Company. - (5) Failure to comply in whole or in part with a requirement to interru...

AI summary The document outlines the rules for restoring service after a load interruption, requiring customer approval from the Company. It also specifies penalty charges for non-compliance, including a Threshold Penalty based on billing costs and a Performance Penalty calculated using a formula involving kVA values.

SPECIAL CONDITIONS - (1) The Company reserves the right to have a separate service agreement, if in the opinion of the Company issues not specifically set out herein, must be addressed for the ongoing benefit of the Company and its custome...

AI summary The Company reserves the right to establish separate service agreements for specific issues, and customers are required to ensure their load does not negatively impact the power supply system. Specific requirements will be outlined in a written operating agreement.

GENERATION LOAD FOLLOWING CRITERIA - (1) Two months preceding each tariff year the customer-generator, in conjunction with the Company, shall establish the aggregate net operating capability of its generation equipment for the billing purp...

AI summary The document outlines criteria for load following services, requiring customer-generators to establish their generation equipment's net operating capability with the Company. Adjustments are made if generation levels drop significantly, and the Company must seek approval from the Nova Scotia Utility and Review Energy Board for forecasted incremental generation costs.

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, and operational expenses, and are to be recovered through Bundled Service, not through other applicable tariffs.

APPLICABILITY - (1) The RTT is applicable to the LRS, and is in addition to (and not in substitution of) any charges owing by the LRS to NS Power under the Open Access Transmission Tariff (OATT), the Standby Service Tariff, or the Energy B...

AI summary The RTT applies to the LRS and is in addition to charges under other tariffs. It includes energy and demand charges with provisions for savings credits and annual adjustments based on forecasted costs. The LRS must also take service under the OATT and other tariffs.

SHORE POWER TARIFF Page 2 of 4 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 Shore Power Tariff provides a credit of 32 cents per peak kilovolt-ampere of monthly peak demand for customers who own the transformer and are served at a transmission voltage level.

SUPPLY INTERRUPTIONS This is an interruptible service. Before connecting the ship to the shore supply the port authority will request permission from NSPI indicating the expected load and duration for which the power is needed. The custome...

AI summary This section outlines the conditions for interruptible service under the tariff, requiring customers to provide notice, maintain communication systems, and comply with load reduction requests from NSPI. Failure to comply may result in penalty charges.

SHORE POWER TARIFF Page 4 of 4 (9) The customer will make all necessary arrangements and bear all costs of ensuring that its load does not unduly deteriorate the integrity of the power supply system, by reason of its design and/or operatio...

AI summary The Shore Power Tariff outlines customer responsibilities to maintain power supply integrity through design and operation. Specific requirements are to be outlined in a written operating agreement, and factors affecting system integrity, such as reliability and harmonic levels, are identified for assessment.

AVAILABILITY This Standby Service Tariff is applicable to the LRS in order to facilitate the purchase of renewable low-impact electricity by Renewable to Retail (RtR) Customers. This Standby Service Tariff is provided under the following t...

AI summary The Standby Service Tariff applies to the Local Retail Service (LRS) to enable Renewable to Retail (RtR) Customers to purchase renewable low-impact electricity. The tariff is subject to two conditions: a valid LRS Participation Agreement with NS Power and the provision of service to RtR Customers.

WHOLESALE MARKET BACKUP/TOP-UP SERVICE TARIFF Page 3 of 6 The tariff is applicable to the scheduled backup/top-up load of participating customers under the following terms and conditions: - (1) The wholesale customer has provided written n...

AI summary This section outlines the terms and conditions for the Wholesale Market Backup/Top-Up Service Tariff. Key requirements include written notice from the wholesale customer, minimum subscription periods, and the need for adequate metering equipment. Applications must be submitted by specific deadlines, and NSPI must respond within set timelines.

WHOLESALE MARKET NON-DISPATCHABLE SUPPLIER SPILL TARIFF Page 2 of 2 - (2) The Company reserves the right to have a separate service agreement, if in the opinion of the Company issues not specifically set out herein, must be addressed for t...

AI summary The document outlines the Company's right to establish separate service agreements for non-dispatchable suppliers to address issues affecting the power supply system's integrity. It emphasizes the need for suppliers to ensure their generation output does not compromise system reliability and mentions the filing of the 2026 Annually Adjusted Rates Confidential Appendix I.

NS Power's Proposal - 1. The adjustment for the projected imbalance in the recovery of the avoided fuel costs should be eliminated. The energy charges under these tariffs should be made of hourly marginal costs. The fixed cost adders shoul...

AI summary NS Power proposes eliminating the adjustment for the projected imbalance in the recovery of avoided fuel costs in the 1P-RTP tariff and instead using hourly marginal costs for energy charges. It also suggests that future adjustments to the 1P-RTP tariffs should be made as part of General Rate Applications, similar to the OATT. These changes aim to address forecasting challenges related to emissions and non-dispatchable generation sources.

18 (b) The Company has not performed this analysis. Until such time as the Board renders a 19 Decision on an application for an ATL tariff applicable to PHP, uncertainty regarding the 20 final form of the tariff and PHP's participation rem...

AI summary The Company has not performed a specific analysis regarding the ATL tariff for PHP, creating uncertainty until the Board makes a decision. There is also a note about an overestimated Energy Sales forecast in NS Power's Q3 2025 Load forecast, which slightly affects the marginal cost forecast.

AVAILABILITY - (a) This Tariff is applicable to operations at PHP's mill site at Point Tupper, and is premised upon PHP's electricity requirements being exclusively served by NS Power. - (b) In addition to the priority interruptible servic...

AI summary This tariff applies to PHP's operations at Point Tupper, specifying that NS Power must exclusively serve PHP's electricity needs. It includes load management protocols, voltage requirements, and restrictions on combining this tariff with others without NSEB approval.

Customer Baseline Energy Charge, Customer Baseline Energy Cost, and Contribution to Utility Costs In advance of each tariff year, PHP shall advise NS Power of its forecast annual and monthly energy requirements for the subsequent calendar...

AI summary The document outlines the process for calculating the Customer Baseline Energy Charge (CBL Cost) and its relationship with the CBL Adder (CBLA) and Fixed Cost Recovery (FCR). NS Power uses PHP's forecast energy requirements to determine the CBL Cost, which includes fuel, purchased power, line losses, and variable operating costs. The CBLA is calculated based on the forecast CBL Cost and interacts with the FCR.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 3 of 8 $61.75/MWh. The FCR transferred from the CBL Cost is then added to the calculated CBLA to equal $5/MWh FCR. x When the forecast CBL Cost is at or over $61.75/MWh, the FCR to b...

AI summary The ELIADC Energy Charge is calculated by summing the CBL Energy Charge, CBLA, and VCC. When the forecast CBL Cost exceeds $61.75/MWh, the FCR transferred is capped at $3.75/MWh, with the difference assigned a value of zero. These charges are submitted for Board approval annually as part of the Annual Adjusted Rates proceeding.

INTRA-YEAR MODIFICATIONS TO THE CBL ENERGY CHARGE NS Power will utilize its established forecasting methodology to determine the CBL Energy Charge. PHP will undertake commercially reasonable efforts to accurately forecast its energy usage....

AI summary NS Power will use its forecasting methodology to determine the CBL Energy Charge, with the possibility of revision if significant changes occur. PHP is expected to forecast its energy usage accurately. Delays in NS Block energy import could impact the CBL Energy Charge for 2020, potentially requiring recalculation.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 4 of 8 - (a) It becomes apparent that the CBL Energy Charge plus the CBLA plus the Variable Capital Charge will not result in the recovery of the actual incremental cost to serve plu...

AI summary The document outlines conditions under which adjustments to the CBL Energy Charge may be necessary, including changes in generation costs, unexpected consumption shifts, and capital expenditures. If NS Power and PHP cannot agree, the issue can be referred to the Board for expedited adjudication, with the Minimum Payment remaining unchanged.

ACTIVE DEMAND CONTROL AND SCHEDULE VARIANCE NS Power shall be entitled to actively manage PHP's load in accordance with the terms and conditions set out in the Active Demand Control – Energy Supply Protocol attached as Schedule 1 to this T...

AI summary NS Power is allowed to manage PHP's load under the Active Demand Control Protocol. NS Power must annually report system savings and load shifting benefits to the Board, including impacts of schedule variances. PHP receives a 25% credit based on the cost differential between CBL Cost and actual annual cost to serve. The report must be submitted within 60 days of the tariff year end.

TERM The third term of this Tariff is 2026, unless revised per a Decision of the NSEB (Term). Prior to the end of the third term, NS Power or PHP may apply to the Board for approval of a subsequent term for this Tariff, including the appro...

AI summary The third term of the Tariff is set for 2026, subject to potential revision by the NSEB. NS Power or PHP may request approval for a subsequent term, including adjustments to pricing elements or a transition to an alternative tariff.

REOPENER If, at any time during the Term, NS Power or PHP determines that the ELIADC Tariff is not working effectively, the parties shall work together to try to resolve any such concerns. If the parties cannot resolve such concerns, eithe...

AI summary The document outlines the process for adjusting the ELIADC Tariff if it is deemed ineffective. If NS Power or PHP cannot resolve concerns, either may request the Board to adjust the Tariff. The Board may act expedited to protect customers, and PHP would have the opportunity to decide whether to remain on the adjusted Tariff.

MINIMUM LOAD REQUIREMENT NS Power will withdraw the availability of this tariff, if, on a consistent basis, PHP is not maintaining a regular demand of 25,000 kVA.

AI summary NS Power will withdraw a tariff if PHP fails to maintain a consistent minimum demand of 25,000 kVA.

INTERRUPTIBILITY The Mill will reduce its load by, at a minimum, the amount requested by NS Power within 10 minutes of such request by NS Power. Following such interruption, service may only be restored by the Mill with the approval of NS...

AI summary The document outlines requirements for interruptibility, specifying that PHP must reduce load within 10 minutes of NS Power's request and provide contact information for load interruption. It also references annually adjusted rates for 2026.

Conversion of Interruptible Load to Firm Should PHP desire to be served under any applicable firm service tariff, a five-year advance written notice must be given to NS Power so as to ensure adequate capacity availability. Requests for a c...

AI summary The document outlines the process for PHP to convert from interruptible load service to firm service, requiring a five-year advance notice to NS Power. This ensures adequate capacity availability and that such requests are treated like all other firm service requests.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 7 of 8 received by NS Power. NS Power may, however, permit an earlier conversion. If PHP desires to return to interruptible service in the future, PHP may convert to an interruptible...

AI summary The document outlines the conditions under which Port Hawkesbury Paper LP (PHP) can convert between firm and interruptible service tariffs with Nova Scotia Power (NS Power). PHP may request an earlier conversion to interruptible service, and NS Power may allow an earlier conversion from firm to interruptible service after two years of service under the firm tariff.

Order of Interruptibility In the event an interruption call is required in order to avoid shortfalls in system electricity supply, interruptible load will be called upon to provide capacity to NS Power in the following order: - (1) Generat...

AI summary The Order of Interruptibility outlines the sequence in which interruptible load will be called upon during electricity supply shortages, prioritizing certain tariffs over others. NS Power may adjust the order if necessary, particularly when managing operating reserves.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 5 of 8 The third term of this Tariff is 2026, unless revised per a Decision of the NSEB (Term). Prior to the end of the third term, NS Power or PHP may apply to the Board for approva...

AI summary The third term of the Extra Large Industrial Active Demand Control Tariff is set for 2026, subject to potential revision by the NSEB. NS Power or PHP may seek approval for a subsequent term or transition to an alternative tariff before the third term ends.

MINIMUM LOAD REQUIREMENT NS Power will withdraw the availability of this tariff, if, on a consistent basis, PHP is not maintaining a regular demand of 25,000 kVA.

AI summary NS Power will withdraw a tariff if PHP fails to maintain a consistent minimum demand of 25,000 kVA.

INTERRUPTIBILITY The Mill will reduce its load by, at a minimum, the amount requested by NS Power within 10 minutes of such request by NS Power. Following such interruption, service may only be restored by the Mill with the approval of NS...

AI summary The document outlines the requirements for load interruption by PHP in response to requests from NS Power, including the need for timely load reduction and the provision of contact information for load interruption. It also mentions the Annual Adjusted Rates for 2026 related to the IG IR-5 Attachment 2.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 6 of 8 load as Operating Reserve as required by system conditions. When interruptions are required, NS Power will exercise the automated control of the customer's load to interrupt t...

AI summary The document outlines the Extra Large Industrial Active Demand Control Tariff, detailing how NS Power may interrupt PHP's load during system emergencies and the penalties for non-compliance. Penalties include a Threshold Penalty and a Performance Penalty based on specific formulas.

Conversion of Interruptible Load to Firm Should PHP desire to be served under any applicable firm service tariff, a five-year advance written notice must be given to NS Power so as to ensure adequate capacity availability. Requests for a c...

AI summary The document outlines the process for PHP to convert from interruptible load to firm service, requiring a five-year advance notice to NS Power. It also mentions the treatment of such requests and the possibility of an earlier conversion. The text includes a reference to 'Annually Adjusted Rates for 2026 IG IR-5 Attachment 2 Page 7 of 8'.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 7 of 8 years of service under the firm tariff schedule. NS Power may permit an earlier conversion from firm to interruptible service.

AI summary The document discusses the possibility of converting from firm to interruptible service under the Extra Large Industrial Active Demand Control Tariff, with NS Power having the authority to allow such a conversion before the typical years of service under the firm tariff schedule.

Order of Interruptibility In the event an interruption call is required in order to avoid shortfalls in system electricity supply, interruptible load will be called upon to provide capacity to NS Power in the following order: - (1) Generat...

AI summary The Order of Interruptibility outlines the priority sequence in which interruptible load customers will be called upon during electricity supply shortages. It specifies the order of priority for different tariffs, including Generation Replacement and Load Following, Extra Large Industrial Active Demand Control, Shore Power, and the Large Industrial Interruptible Rider Tariff.

POWER FACTOR CORRECTION Annually Adjusted Rates for 2026 IG IR-5 Attachment 2 Page 8 of 8

AI summary The document discusses annually adjusted rates for 2026, specifically referencing an attachment related to power factor correction. It includes a reference to a visual element, likely a chart or graph, though the content is minimal.

NON-CONFIDENTIAL 1 Request IR-9: 2 3 In Appendix F3, why is the Interruptible Credit Cost now included in the monthly rate for 4 the Standby Demand Charge Calculation? 5 6 Response IR-9: 7 8 The monthly standby rate applied for in this App...

AI summary The response to Request IR-9 explains that the interruptible credit cost is not included in the monthly standby rate of $5.452 per kW, but is instead a separate credit of $14.053 per kW for interruptible customers. This credit is provided for informational purposes to assist in pricing decisions within the RtR market.

NON-CONFIDENTIAL 1 Request IR-10: 2 3 (a) Without commenting on the merits, please outline in detail the steps required to 4 calculate and implement an annual true-up mechanism under which a credit or debit 5 is calculated and applied to t...

AI summary The document outlines Request IR-10, which asks for details on implementing an annual true-up mechanism based on Marginal Cost differences. The response indicates that NS Power has existing true-up mechanisms for FAM, DSM, and Storm Riders, but no specific methodology for a new annual true-up has been evaluated. A regulatory process involving the NSEB is required for any changes.

PARTIALLY CONFIDENTIAL (Attachment Only) 1 Request IR-12: 2 3 Reference: Appendix F2, F3 and F4. 4 5 (a) For each cross-referenced document from the GRA, please provide the assigned 6 NSEB exhibit number. 7 8 (b) Please provide a pdf versi...

AI summary The request (IR-12) asks for exhibit numbers, PDFs of cross-referenced documents, and an explanation of why NS Power refused access to confidential information. The response refers to a table and mentions the 2024 AARs and confidentiality undertakings.

FOR THE YEAR ENDING DECEMBER 31, 2026 (IN THOUSANDS OF DOLLARS) (1) INTERR. RIDER DMD ADJ. (2) (3) (4) Peak Dmd. in KWs (at Generator) Int Credit Amount 69,594 11,165 (5) (6) PHP DEMAND ADJUSTMENT CALCULATION (7) (8) Demand Usage Annual Cr...

AI summary The table outlines calculations related to demand adjustments and interruption credits for the year ending December 31, 2026. It includes metrics such as peak demand, power factor, and annual credit amounts, with a focus on Priority Interruption Demand Adjustments and the PHP (Peak Hour Pricing) demand adjustment calculation.

NON-CONFIDENTIAL 1 Decrease in ancillary generation related costs of 19 percent between the submitted OATT 2 applications in the 2023-2024 GRA and the 2026-2027 GRA. 3 4 Exclusion of the interruptible credit amount of $11.2 million from th...

AI summary The submitted OATT applications show a 19% decrease in ancillary generation costs between the 2023-2024 and 2026-2027 GRA periods. However, the exclusion of $11.2 million in interruptible credit from standby demand charges caused a 76% increase in demand charge costs, partially offset by a 6% rise in demand usage. A 60.5% residual imbalance is attributed to the cross-over effect.

Annually Adjusted Rates for 2026 (M12551) NSPI Responses to REI Information Requests 1 Request IR-18: capability (ELCC) of ten percent of the total installed capacity. This is in reference to the potential system benefit on the supply side...

AI summary The document discusses the Annually Adjusted Energy Savings Credit (AAESC) and Annually Adjusted Demand Savings Credit (AADSC) mechanisms, developed as part of the original RtR Tariff proceeding (M06214) and approved in 2016. It also references the 2026-2027 GRA (M12451) and the impact of the RtR market on system requirements.

Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 5 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Following discussions with NS Power, RCAI prepared a report[1](#page-64-1) and made a related presentation to stakeholders on...

AI summary RCAI collaborated with NS Power to develop the framework and tariff instruments for the Renewable to Retail (RtR) Market, including distribution tariffs, energy balancing service tariffs, and market rule amendments, based on stakeholder feedback and discussions from 2014 to 2015.

1.5 Conclusions and Opinion This report describes the proposed RtR Market framework and the instruments to be used by NS Power for its implementation. It outlines the consultations with stakeholders. And it includes discussion of the issue...

AI summary This section outlines the proposed Renewable to Retail (RtR) Market framework by NS Power, emphasizing its alignment with the Electricity Act and stakeholder input. It highlights the framework's rational approach, use of existing tariff structures, and its ability to provide fair rates and cost recovery for RtR customers.

2.1 LRS Participation Agreements Each LRS will be required to execute an LRS Participation Agreement with NS Power. The proposed form of the LRS Participation Agreement is attached as Appendix B to the LRS Terms and Conditions, and will bi...

AI summary This section outlines the requirements for LRS Participation Agreements with NS Power, detailing the terms and conditions that bind LRS to specific tariffed services and market participation rules. It also describes the obligations for both LRS and non-LRS RtR generators to become Market Participants.

2.2.1 Selected Option; LRS Participation Agreement The selected option of the LRS Participation Agreement has the benefit of clarity. It has been drafted specifically for this purpose and has embedded all necessary provisions in a single d...

AI summary The LRS Participation Agreement is selected for its clarity and comprehensive provisions, creating a clear contractual relationship between LRS and NS Power, allowing for unified administration and settlement of tariffs and payment security.

3.2 Service Duration NS Power's Bundled Service tariffs are designed to provide appropriate cost recovery over each calendar year, subject to certain specific deferred cost recovery provisions. RtR tariffs are all designed on the same basi...

AI summary NS Power's Bundled Service and RtR tariffs are structured to ensure cost recovery over each calendar year, with provisions to address frequent customer switching. Controls may be added if frequent switching is observed, except in cases of special or unplanned circumstances.

Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 12 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) interruptibility would be independent of bundled / RtR status, and would be independent of whether RtR generation was operati...

AI summary The document discusses the complexities of implementing interruptible service for RtR (Real Time Retail) customers, noting that current systems and tariffs are not in place for such service. NS Power would need to address several issues, including contractual arrangements and tariff amendments, if interruptible RtR service is requested.

• In either configuration: - o the amount corresponding to the RtR distribution charge on the B-t-M generation quantity; - o the amount corresponding to the OATT charges on the B-t-M generation quantity; - o the amount corresponding to the...

AI summary The text outlines various components that may be included in either configuration, including distribution charges, OATT charges, generation reserve margins, market transition tariffs, and changes in customer load shapes.

Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 15 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) - Enhanced recovery of embedded costs: - o As noted above, without secondary metering for use in RtR tariff settlement, a B-t...

AI summary The document discusses the need for secondary metering to recover embedded costs associated with a B-t-M arrangement. Without secondary metering, costs could be stranded and passed on to remaining NS Power customers. NS Power has opted for secondary metering as a simpler solution to avoid creating a special B-t-M Transition Tariff.

3.7.1 Customer-specific Billings to the LRS or Customers For service under the Distribution Tariff, NS Power will invoice the LRS monthly for each individual customer charge.

AI summary NS Power invoices the LRS monthly for individual customer charges under the Distribution Tariff.

Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 17 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) - Energy Balancing Service, comprising: - o Top-up service; - o Spill, including at a discounted rate for the annual excess o...

AI summary The document outlines the Energy Balancing Service, including top-up and spill services, and the RtR Market Transition Tariff for embedded cost recovery. NS Power will bill LRS for these services monthly after implementing remote polled interval metering for all RtR customers.

3.7.3 Fuel Adjustment Mechanism (FAM), DSM Cost Recovery, and Miscellaneous Charges The FAM tariff includes a provision that outstanding FAM balances in respect of customers migrating to non-FAM be charged to those customers. NS Power will...

AI summary The FAM tariff includes provisions for charging outstanding balances to customers migrating to non-FAM. DSM cost recovery is expected to apply to both Bundled Service and RtR customers. Interval meter installation and other miscellaneous charges will be recovered at cost, billed to the LRS as they are necessary for load aggregation.

4.1 Disaggregated Tariff Approach RCAI's October, 2014 Market Design White Paper identified a range of RtR design options to stakeholders, and sought stakeholder feedback. 9 Approved NS Power Rates and Regulations can be found at http://ww...

AI summary The document discusses the Disaggregated Tariff Approach, referencing a 2014 Market Design White Paper by RCAI that presented Real Time Retail (RtR) design options to stakeholders and sought their feedback. It also provides a link to approved NS Power Rates and Regulations.

Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 19 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) RtR rates are therefore expected to be adjusted, if required, in parallel with Bundled Service rates, including where applica...

AI summary The document indicates that RtR rates will be adjusted in parallel with Bundled Service rates, including the annually adjusted rate processes where applicable.

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.

5.2 Cost Allocation Principles The Energy Balancing Service, Standby Service, and RtR Market Transition tariffs have been designed to incorporate the same fixed cost classification and allocation principles as in the Cost of Service analys...

AI summary The document outlines the cost allocation principles for the Energy Balancing Service, Standby Service, and RtR Market Transition tariffs, aligning them with the Bundled Service Cost of Service analysis. Fixed generation costs are classified and allocated based on demand and energy use, with aggregated rates applied for RtR customers.

5.3.1 Purpose The purposes of the top-up and spill services are essentially the time-shifting of the RtR generation supply so that it will match the needs of the RtR load. Each LRS will effectively use the NS Power system as an energy stor...

AI summary The purpose of the top-up and spill services is to time-shift RtR generation supply to match RtR load, using the NS Power system as energy storage. The tariff arrangement compensates NS Power and LRS for incremental costs and savings, and covers fixed generation costs classified as energy-related in the CoS model.

• Incentives: - o Under option 1, the imbalance top-up rate under schedule 4 represents the incremental NS Power generation cost only, excluding the recovery of fixed generation costs allocated to energy. An LRS could gain by over-forecast...

AI summary The text discusses two options for imbalance top-up rates. Option 1 creates perverse incentives for LRS to misforecast supply and load, while Option 2 eliminates these incentives by making top-up and spill quantities independent of forecasts, encouraging accurate generation forecasting to minimize costs.

5.3.3 Self-supply of Top-up Consideration has been given to the potential for an LRS to self-supply top-up service from a generator other than its normal supplier(s) of renewable low impact electricity, as is permitted under the OATT. Thre...

AI summary The document evaluates three scenarios for self-supply of top-up energy by an LRS under the OATT. All scenarios are deemed impractical, with the third option of importing energy for top-up being unviable in the near term due to increased costs and complexity.

5.5.4 Annual Excess Spill Discount The top-up and spill incremental rates discussed above are designed to recover the costs of providing annually balanced top-up and spill services. Any sustained bias towards top-up service quantity would...

AI summary The Annual Excess Spill Discount addresses situations where there is a sustained bias towards spill service, potentially reducing costs avoided by NS Power. In such cases, the rate payable to the LRS for extra spill should be discounted from the rate applicable to balanced spill.

5.7.1 Concern with Existing Backup Service Charge Determinant The demand charge portion of NS Power's present Wholesale Market Backup and Top-up Service tariff was reviewed for its applicability in the RtR Market. Based on NS Power's NPCC...

AI summary The document discusses concerns with the existing backup service charge determinant in NS Power's Wholesale Market Backup and Top-up Service tariff, particularly in the RtR Market. It outlines calculations for determining firm dependable capacity and the LRS responsibility based on annual system coincident peak demand.

5.8 Standby Service; Rate The rate applied is the rate per unit of winter peak demand, spread over 12 monthly payments, required to recover the demand-based fixed supply cost under the Bundled Service Cost of Service analysis, after exclud...

AI summary The rate for standby service is calculated based on winter peak demand, spread over 12 monthly payments, to recover demand-based fixed supply costs after excluding those recoverable under OATT Ancillary Service rate Schedules 2 to 6.

6.1.1 Concepts NS Power has considered two conceptual options for the transmission tariff in the RtR Market Context: - aggregated approach; and - customer-specific approach. These are described below. NS Power has selected the aggregate ap...

AI summary NS Power has evaluated two conceptual options for transmission tariffs in the RtR Market Context: an aggregated approach and a customer-specific approach. NS Power has opted for the aggregated approach, with transmission charges billed to the LRS in both cases.

6.1.3 Customer-specific Approach (not selected) Under a customer-specific approach, the tariff Network Service terms and conditions would remain broadly applicable, but the service-specific schedules of rates would be replaced by class-spe...

AI summary A customer-specific approach would replace service-specific rate schedules with class-specific ones based on individual metering results. This approach would use the same charge determinants as the new RtR Distribution Access Service rates and include transmission costs plus fixed generation demand amounts under OATT Schedules 2 to 6. Proposed OATT Schedule 4A would be separately billable to the LRS.

6.2 Treatment of Imbalance, OATT Schedule 4 Under the proposed EBS tariff approach, OATT Schedule 4 will not apply to RtR service. It will be replaced by Schedule 4A which would provide for payments at 10% of marginal cost in respect of ea...

AI summary The proposed EBS tariff approach replaces OATT Schedule 4 with Schedule 4A for RtR service, which provides for payments at 10% of marginal cost for imbalances exceeding 2.0 MWh, excluding curtailment by NS Power. This is discussed in section 5.3.2.

Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 30 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) While such an approach would address the situation where 100% of an LRS's activity is in a single zone, the principles are ap...

AI summary The text discusses the application of principles to scenarios involving Local Resource Suppliers (LRS) where their generation and load are located in the same zone, addressing issues related to annually adjusted rates for 2026.

• Embedded Cost Recovery To the extent that an LRS was to be relieved of transmission charges for generation located in the same zone as load, and this loss of NS Power revenue could not be recovered from Bundled Service customers, this wo...

AI summary The text discusses the potential need to add a transmission cost element to the RtR Market Transition Tariff to recover embedded costs from LRS if they are relieved of transmission charges for generation in the same zone as load, which could negate benefits for LRS.

8.1 Purpose of the RtR Market Transition Tariff The proposed RtR Market Transition Tariff (RTT) is designed to recover embedded costs not otherwise recovered thought the tariffs described above. The amounts to be recovered under the RTT in...

AI summary The RtR Market Transition Tariff (RTT) is intended to recover embedded costs not covered by existing tariffs. It accounts for the difference between the Standby Service charge and potential benefits from avoided or deferred generation capacity investments, which are expected to be minimal in the near term.

8.2.1 Options Two potential recovery mechanisms were presented to stakeholders: - A Retail Access Adjustment based on the extent of the embedded cost recovery required in each year as a result of each LRS's activity, using rates that could...

AI summary Two potential recovery mechanisms were presented to stakeholders: a Retail Access Adjustment based on embedded cost recovery requirements and an exit fee associated with each exiting customer to recover estimated embedded costs.

8.2.2 Retail Access Adjustment Characteristics of the retail access adjustment as proposed in the RtR Market Transition Tariff are: - Charges per unit of stranded demand and energy set in advance and capable of annual adjustment; - Charge...

AI summary The retail access adjustment, as proposed in the RtR Market Transition Tariff, includes features such as adjustable charges per unit of stranded demand and energy, indifference to generation technology, and cost responsibility moving with customers during migration between LRSs. The adjustment aims to ensure stable cost recovery and can continue as long as embedded cost recovery is required.

8.2.4 Stakeholder input One stakeholder indicated a preference for an Exit Fee, determined on customer exit but payable over a five year period. This preference was recognised and considered in selecting the solution, but did not outweigh...

AI summary A stakeholder expressed a preference for an Exit Fee structure, to be paid over five years upon customer exit. This preference was acknowledged but did not influence the decision to adopt the RTT approach, as explained in the following section.

8.2.5 Basis for selection The amount of embedded cost recovery depends in large part on the amounts of NS Power fixed costs recovered by other mechanisms. As noted in the discussion of the EBS and Standby Service tariffs, the amounts recov...

AI summary The selection of the RtR Market Transition Tariff over Exit Fees is based on its ability to achieve full and fair embedded cost recovery with less risk and uncertainty, considering the complexity and variability of Exit Fee estimates.

8.3 Interaction with Other Tariffs and Retailers Regulations In the event that NS Power's recoveries under other proposed tariffs are varied from those proposed, the proposed RTT would need to be revised to reflect any such changes in thos...

AI summary The document discusses the need to revise the proposed Real Time Retail (RtR) tariff if other tariffs are varied, to ensure compliance with the 'no harm' requirements of the Electricity Act. It also mentions the preferred approach using secondary metering for B-t-M settlement and the potential need for a Behind-the-Meter Transition Tariff if this approach is rejected.

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.

bject to the application as filed, but wishes to make some limited comments regarding modelling of power imports, as well as NS Power's justification for the change in the 1P-RTP method. Specifically: Modelling of Power Imports: The Consum...

AI summary The Consumer Advocate notes inconsistencies in NS Power's modelling of power imports and the change in the 1P-RTP method. They highlight discrepancies between historical average deliveries and model outputs and suggest avoiding resetting import limits. They also reference NS Power's 2018 AAR Application regarding 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.

Submissions In conclusion, the SBA respectfully submits that the Board should consider risk allocation of the proposed AARs in the presence of volatile marginal costs, ensure administrative costs are welljustified, and acknowledge the need...

AI summary The SBA submits that the Board should consider risk allocation of proposed AARs in light of volatile marginal costs, ensure administrative costs are well-justified, and provide clarity on deferred RtR costs to ensure fairness across customer classes.

") submitted comments that do not challenge the appropriateness of the ELIADC Energy Charge as filed by NS Power. Rather, the comments appear to raise questions about the timing of the effective date. The CA's submission states that: "Give...

AI summary The Consumer Advocate (CA) and Industrial Group (IG) have submitted comments regarding the ELIADC Energy Charge and the timing of interim relief. The CA suggests delaying the effective date of interim relief to align with the 2026 Annually Adjusted Rates, while the IG argues against granting relief to PHP alone, as other rate classes also have rate changes and have not sought interim relief.

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.

2026 COSS Methodology Disproportionately impacts RtR Customers The RtR tariffs were developed and approved under a different cost allocation model and therefore do not reflect the substantial shifts in demand-related allocations now propos...

AI summary The 2026 COSS methodology disproportionately impacts RtR customers by shifting costs from energy to demand, increasing demand charges and misaligning cost allocation with the current framework. This could undermine competition in the RtR market and contradict legislative objectives, requiring a tariff review before Q4 2026.

Updated RtR Tariffs are needed to Improve Cost Causation REI acknowledges that the AAR process is not necessarily the proper venue for revising tariff structures.[5](#page-3-0) However, NSPI's 2026 AAR filing reveals that the current RtR t...

AI summary REI argues that the current RtR tariffs are misaligned with cost causation principles and require revision to reflect monthly variability of marginal costs, ensure appropriate annual energy cost adjustment methodology, and implement a true-up mechanism to minimize risk and volatility.

(a) No Evidence of Forecast Accuracy or Historical Validation Through the Information Request Process, REI asked a series of questions to test the validity of the marginal cost forecasting for 2026. In response, however, NSPI did not provi...

AI summary REI questioned the accuracy of NSPI's marginal cost forecasting for 2026. NSPI could not provide historical data due to a cybersecurity breach and only offered limited comparisons, such as a single-quarter forecast discrepancy for solid fuel plants and diesel combustion turbines. These discrepancies raise concerns about the reliability of forecasting methods.

A True-Up Mechanism Should Be Considered for the RtR Tariffs A true up mechanism is essential for the RtR tariffs, particularly the RTT. A one-year swing of over 444% in 2026 for the RTT Energy Charge delta is significant and demonstrates...

AI summary A true-up mechanism is recommended for the RtR tariffs, especially the RTT, due to extreme volatility in energy charge deltas, such as a 444% swing in 2026. NSPI argues that the fuel imbalance has low materiality, but REI contends that the analysis is incomplete and does not account for the significant cost impact on RtR customers. A true-up is seen as fair and necessary for cost causation and competition.

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.

stands that the information in Appendix A4 is incorrect, and the information in Exhibit N-2 is correct, and wished to bring this discrepancy to the Board's attention.[6](#page-4-3) NS Power Response: - NS Power adjusts NB Import volumes us...

AI summary The Consumer Advocate points out discrepancies in Appendix A4 and Exhibit N-2, which NS Power acknowledges and corrects. NS Power explains its use of a three-year average in the Fuel Adjustment Mechanism (FAM) for forecasting NB import volumes, and agrees with the CA regarding the Maritime Link on-peak surplus energy limits. The CA also discusses changes to the 1P-RTP methodology.

NS Power Response: Currently there is one customer taking service under the 1P-RTP Tariffs and that customer takes this service in concert with an above-the-line (ATL) tariff, with the 1P-RTP service being applied to the customer's top ene...

AI summary NS Power explains that only one customer currently uses the 1P-RTP Tariff, which is applied to the top energy block in conjunction with an above-the-line tariff. The company confirms that changes in the LF rate calculation method in 2018 did not affect the 1P-RTP Tariff rates, which are calculated independently. The fuel cost adjustment for 1P-RTP customers is based on varying eligible loads rather than a fixed 25 MW decrement.

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.

ribed in Section 7.0 of the Application, the existing RtR tariffs The Board's Interim Order in the 2026 DCRR proceeding (M12521) approved the continuation of the 2025 DCRR "until further order of the Board in this matter, or as part of NS...

AI summary The document references the Board's Interim Order in the 2026 DCRR proceeding (M12521), which approved the continuation of the 2025 DCRR until further order of the Board or as part of NS Power's ongoing general rate application. REI acknowledges that the AAR process is not the proper venue for revising tariff structures.

026 Page 15 of 22 At page 4 of its Submissions, REI provided "REI acknowledges that the AAR process is not necessarily the proper venue for revising tariff structures."

AI summary REI acknowledges that the AAR process may not be the appropriate venue for revising tariff structures, as noted in its submissions on page 4.

STANDBY SERVICE Standby Service is a supplemental generation capacity service provided to Licensed Retail Suppliers (LRS). The service is provided in combination with Energy Balancing Service under the Energy Balancing Service Tariff. The...

AI summary Standby Service is a supplemental generation capacity service offered to Licensed Retail Suppliers (LRS) in Nova Scotia. It includes capacity adequacy service to meet system adequacy standards and top-up capacity service to support energy delivery through the Energy Balancing Service Tariff.

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 for Load Replacement Service (LRS) is calculated annually using forecasted costs and the number of LRS subscribers, resulting in a fixed monthly charge of $414.63.

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 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 Renewable to Retail Market Transition Tariff.

Requested Relief The Company respectfully requests Board approval of the revised 2026 AARs, provided as Appendix A, and as listed herein: - One-Time Transmission Real-Time Pricing Tariff; - One-Time Distribution Voltage Real-Time Pricing T...

AI summary Nova Scotia Power is requesting approval for revised 2026 AARs, including several new tariffs. The company will file the 2027 AAR Application by November 6, 2026, including updates on directives from previous proceedings. The approved rates will be implemented as per the Board's decision.

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 order in which rate classes will be called upon during supply shortfalls.

SUPPLY INTERRUPTIONS This is an interruptible service. Before connecting the ship to the shore supply the port authority will request permission from NSPI indicating the expected load and duration for which the power is needed. The custome...

AI summary This section outlines the conditions for interruptible service under the tariff, requiring customers to provide notice, reduce load promptly upon request, and comply with restoration procedures. Non-compliance may result in penalty charges.

APPLICABILITY - (1) The RTT is applicable to the LRS, and is in addition to (and not in substitution of) any charges owing by the LRS to NS Power under the Open Access Transmission Tariff (OATT), the Standby Service Tariff, or the Energy B...

AI summary The RTT applies to LRS and is in addition to charges under other tariffs. It includes energy and demand charges with annual adjustments based on forecasted avoided costs and system fuel costs. Savings credits are also applied annually for NS Power's forecasted savings from LRS's electricity supply.

2026 AAR Compliance Filing Appendix H Page 1 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) ONE PART TRANSMISSION REAL TIME PRICING TARIFF Page 1 of 3

AI summary The document is a redacted page from a 2026 AAR Compliance Filing Appendix H, related to the One Part Transmission Real Time Pricing Tariff. It indicates that the content is confidential and has been redacted.

2026 AAR Compliance Filing Appendix H Page 6 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) ONE PART DISTRIBUTION VOLTAGE REAL TIME PRICING TARIFF Page 3 of 3 - (9) The customer will make all necessary arrangements and bear all costs of...

AI summary The document outlines customer responsibilities in maintaining power supply system integrity under a real-time pricing tariff. Customers must ensure their load does not negatively impact the system, with specific requirements outlined in a written operating agreement. Factors considered in assessing system integrity include reliability, harmonic levels, voltage flicker, and stability.

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 order in which rate classes will be called upon during supply shortfalls.

SHORE POWER TARIFF Page 2 of 4 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 Shore Power Tariff provides a credit of 32 cents per peak kilovolt-ampere of monthly peak demand for customers who own the transformer and are served at a transmission voltage level.

2026 AAR Compliance Filing Appendix H Page 10 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) SHORE POWER TARIFF Page 4 of 4 - (9) The customer will make all necessary arrangements and bear all costs of ensuring that its load does not un...

AI summary The Shore Power Tariff outlines customer responsibilities to maintain power supply integrity through proper load management and adherence to operating agreements. Specific factors affecting system reliability, such as harmonic levels and voltage flicker, are considered in assessments.

CUSTOMER CHARGE The monthly customer charge under this tariff is calculated according to the following formula: Monthly customer charge = forecast annual administration costs forecast number of customers subscribed \ 12 This charge will be...

AI summary The monthly customer charge under the tariff is calculated using forecasted annual administration costs and the number of subscribed customers, resulting in a charge of $414.63 per month.

APPLICABILITY - (1) The RTT is applicable to the LRS, and is in addition to (and not in substitution of) any charges owing by the LRS to NS Power under the Open Access Transmission Tariff (OATT), the Standby Service Tariff, or the Energy B...

AI summary The RTT applies to the LRS in addition to other tariffs, with adjustments for energy and demand charges based on forecasted savings and avoided costs. Credits and adjustments are calculated annually and applied prospectively. The LRS must also take service under the OATT and other related tariffs.

ed in the 2024/25 TVP Evaluation Report being extended, and the pilot for 2025/26 was suspended. NS Power intends to provide an update in its 2027 AAR application. The Board directs NS Power to do so. The NSUARB directed NS Power to perfor...

AI summary The NSUARB directed NS Power to provide a sensitivity analysis on delayed wind resources in its 2026 AAR application, but NS Power only provided one unrealistic scenario. The Board accepts the modeling but directs NS Power to update the 2027 AAR with actual in-service dates and energy impacts of any delays.

Renewall Energy Inc. REI's submission was concentrated on the use of the proposed Cost of Service Study methodology, the RtR tariff review and design, RTRSS tariff calculation and the forecasted marginal cost used in the application. Notab...

AI summary Renewall Energy Inc. (REI) raised concerns about the proposed Cost of Service Study methodology, RtR tariff design, and RTRSS tariff calculations, requesting recalculations and a Board order to revise tariffs by March 31, 2026. NS Power responded by suggesting that changes to tariffs may be premature due to ongoing regulatory proceedings and proposed a draft Terms of Reference for an interruptible service pilot with REI.

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.

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.

2. 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...

AI summary The Board directs NS Power to adjust AARs if the Cost of Service Study is not approved, update the 2027 AAR with information on wind resources and Maritime Link sensitivity, compare forecasted and actual New Brunswick imports, and engage stakeholders on tariff amendments by April 30, 2026. The 2027 AAR must be filed by November 6, 2026.

SERVICE DEFINITION Service under this tariff consists in delivery of supplemental power to partial requirement customers who operate their own dispatchable generation equipment, as approved to be connected to the grid by the Company. The S...

AI summary The Service under this tariff provides supplemental power to customers with dispatchable generation equipment. It includes Generation Replacement, Optional Load Following, and Spill Services, each defined based on specific operational conditions. Customers receiving this service are termed 'customergenerators,' and supplementary power is billed under full requirement tariffs.

AVAILABILITY This tariff is available to: - (a) Customers who have their own qualifying generating facility of not less than 2,000 kW of aggregate capacity, as defined under Special Condition 8, normally used to support their own load; - (...

AI summary The tariff is available to customers with qualifying generating facilities and those needing energy for Non-Utility Owned Generation sites. Energy supply is managed based on customer requests, with pricing determined by estimated or actual costs depending on notice given by the customer.

GENERATION LOAD FOLLOWING CRITERIA Effective: April 1, 2026 - (1) Two months preceding each tariff year the customer-generator, in conjunction with the Company, shall establish the aggregate net operating capability of its generation equip...

AI summary This document outlines the Generation Load Following Criteria effective April 1, 2026. It specifies that customer-generators must establish their net operating capability with NS Power for billing purposes and that the Company must seek approval from the Nova Scotia Energy Board for its forecasted incremental generation costs, which will influence the load following rate for the next tariff year.

AVAILABILITY - (1) Customers must make a written request to take service under this tariff. - (2) This tariff is available to customers who are served at transmission voltage of 69 kV or higher and have loads of 2,000 KVA or 1,800 kW, and...

AI summary The ELIADC tariff is available to customers with transmission voltage of 69 kV or higher and loads of 2,000 KVA or 1,800 kW and over. Customers must submit a written request to take service under this tariff.

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 states that a credit of 32 cents per peak kilovolt-ampere of monthly peak demand will be applied to customers who own their transformers and are served at a transmission voltage level.

SUPPLY INTERRUPTIONS This is an interruptible service. Before connecting the ship to the shore supply the port authority will request permission from NSPI indicating the expected load and duration for which the power is needed. The custome...

AI summary This section outlines the terms of an interruptible service tariff, requiring customers to provide notice, maintain communication systems, and comply with load reduction requests from NSPI. Non-compliance may result in penalties.

WHOLESALE MARKET BACKUP/TOP-UP SERVICE TARIFF Page 1 of 6 CUSTOMER CHARGE The monthly customer charge under this tariff is calculated according to the following formula: Monthly customer charge = forecast annual administration costs foreca...

AI summary The monthly customer charge under the Wholesale Market Backup/Top-Up Service Tariff is calculated using forecasted annual administration costs and the number of subscribed customers, resulting in a fixed monthly charge of $414.63.

ENERGY BALANCING SERVICE The Energy Balancing Service is a supplemental generation service provided to Licenced Retail Suppliers (LRS) in respect of the Licenced Retail Supplier's Renewable to Retail (RtR) Customers utilizing the productio...

AI summary The Energy Balancing Service is a supplemental generation service provided to Licensed Retail Suppliers (LRS) for their Renewable to Retail (RtR) Customers. It ensures service reliability by delivering complementary energy and receiving surplus generation, and must be used with Standby Service under the Standby Service Tariff.

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.

DETERMINATION OF MONTHLY STANDBY CONTRACT DEMAND Monthly Standby Contract Demand (MSCD) in kW is determined using the following formula: $$MSCD = LWPFD - min (LWPFD, (\sum_{iiii=1}^{nnnn} CCi GCi)/(1+PR))$$

AI summary The Monthly Standby Contract Demand (MSCD) is calculated using a formula that subtracts a value derived from customer contributions and generation costs, adjusted by a percentage rate, from the Load Without Power Factor Demand (LWPFD).

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 establish 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, as outlined in written operating agreements. NS Power may apply to the Nova Scotia Energy Board for changes to rates or terms.

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 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 generation-related fixed costs and those approved by the Nova Scotia Energy Board for future recovery.

APPLICABILITY - (1) The RTT is applicable to the LRS, and is in addition to (and not in substitution of) any charges owing by the LRS to NS Power under the Open Access Transmission Tariff (OATT), the Standby Service Tariff, or the Energy B...

AI summary The RTT applies to LRS and is in addition to charges under the OATT, Standby Service Tariff, and Energy Balancing Service Tariff. Energy and Demand Charges under the RTT include provisions for mitigation credits and annual adjustments based on forecasted avoided costs and system fuel costs.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 1 of 8 The Extra Large Industrial Active Demand Control Tariff (ELIADC) provides a mechanism whereby Port Hawkesbury Paper LP (PHP, the Mill, the Customer) pays the forecast incremen...

AI summary The ELIADC tariff allows Port Hawkesbury Paper LP to pay forecasted incremental costs and contribute to utility costs, while granting Nova Scotia Power control over the customer's load to reduce system costs and improve reliability for all customers.

COST OF ELECTRICITY UNDER THE ELIADC TARIFF The price paid by PHP for electricity under this Tariff will be based on the forecast incremental cost to serve PHP at an assumed levelized baseline load level, plus an adder to contribute to the...

AI summary The ELIADC Tariff determines the cost of electricity for PHP based on forecast incremental costs, adders, and credits for system savings from Active Demand Control. This includes components like Customer Baseline Energy Cost, Variable Capital Charge, and an Active Demand Control Credit.

Minimum Payment Effective: April 1, 2026 The ELIADC Tariff requires that a minimum payment shall be made by PHP in respect of each tariff year, which shall not be less than the sum of: - (a) NS Power's actual total incremental cost of serv...

AI summary The ELIADC Tariff requires PHP to make a minimum payment each year, calculated as the sum of NS Power's incremental serving costs and a fixed cost recovery component based on MWh supplied. Adjustments to meet this minimum are determined and charged after year end.

Customer Baseline Energy Charge, Customer Baseline Energy Cost, and Contribution to Utility Costs In advance of each tariff year, PHP shall advise NS Power of its forecast annual and monthly energy requirements for the subsequent calendar...

AI summary The document outlines the methodology for calculating the Customer Baseline Energy Charge (CBL Energy Charge) and related components, including the CBL Adder (CBLA) and Variable Capital Charge (VCC), for PHP. These charges are based on forecasted costs and are submitted for Board approval as part of the annual rate-setting process.

ELIADC ENERGY CHARGE Effective: April 1, 2026 The ELIADC Energy Charge is $75.87 per Megawatt- hour

AI summary The ELIADC Energy Charge, effective April 1, 2026, is set at $75.87 per Megawatt-hour. This charge applies to the Extra Large Industrial Active Demand Control program.

ACTIVE DEMAND CONTROL AND SCHEDULE VARIANCE NS Power shall be entitled to actively manage PHP's load in accordance with the terms and conditions set out in the Active Demand Control – Energy Supply Protocol attached as Schedule 1 to this T...

AI summary NS Power is allowed to manage PHP's load under the Active Demand Control protocol. NS Power must report system savings and schedule variances annually to the Board, including load shifting benefits and improvements. PHP receives a 25% credit based on cost differentials. The report is due within 60 days of the tariff year's end, as outlined in the Board's decision M12184.

REOPENER If, at any time during the Term, NS Power or PHP determines that the ELIADC Tariff is not working effectively, the parties shall work together to try to resolve any such concerns. If the parties cannot resolve such concerns, eithe...

AI summary The document outlines the process for adjusting the ELIADC Tariff if it is determined to be ineffective. If NS Power or PHP cannot resolve concerns about the tariff, either party may request the Board to adjust it, with the possibility of an expedited decision to protect customers. PHP would then have the opportunity to decide whether to remain on the adjusted tariff.

MINIMUM LOAD REQUIREMENT NS Power will withdraw the availability of this tariff, if, on a consistent basis, PHP is not maintaining a regular demand of 25,000 kVA.

AI summary NS Power will withdraw the availability of a tariff if PHP does not maintain a regular demand of 25,000 kVA on a consistent basis.

INTERRUPTIBILITY The Mill will reduce its load by, at a minimum, the amount requested by NS Power within 10 minutes of such request by NS Power. Following such interruption, service may only be restored by the Mill with the approval of NS...

AI summary The document outlines the requirements for load interruption by PHP under the Large Industrial Interruptible Rider. PHP must reduce its load within 10 minutes of NS Power's request, with penalties for non-compliance. Penalties include a Threshold Penalty and a Performance Penalty, calculated based on residual demand and compliance levels. Interruptions are limited to 16 hours per day and 5 days per week.

Conversion of Interruptible Load to Firm Should PHP desire to be served under any applicable firm service tariff, a five-year advance written notice must be given to NS Power so as to ensure adequate capacity availability. Requests for a c...

AI summary PHP must provide five years' notice to NS Power to convert from interruptible to firm service, with NS Power having the option to allow an earlier conversion. PHP may return to interruptible service after two years under the firm tariff, with NS Power also able to permit an earlier return.

Order of Interruptibility In the event an interruption call is required in order to avoid shortfalls in system electricity supply, interruptible load will be called upon to provide capacity to NS Power in the following order: - (1) Generat...

AI summary The document outlines the order in which interruptible load will be called upon during system electricity supply shortfalls, prioritizing Generation Replacement and Load Following (GRLF) Tariff, followed by Extra Large Industrial Active Demand Control (ELIADC) Tariff, Shore Power Tariff, and finally the Interruptible Rider to the Large Industrial Tariff. NS Power may adjust the order if needed.

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 provides port electricity to cruise ships in Nova Scotia, applicable for demands of 2,000 kVA or 1,800 kW and above. It is seasonal, from April 1 to November 30, and customers must accept supply interruptions. In such cases, rate classes are called upon in a specified order to provide capacity to NSPI.

SUPPLY INTERRUPTIONS This is an interruptible service. Before connecting the ship to the shore supply the port authority will request permission from NSPI indicating the expected load and duration for which the power is needed. The custome...

AI summary The document outlines the terms of an interruptible service tariff, specifying that customers must provide notice, maintain communication systems, and comply with load reduction requests from NSPI. Non-compliance may result in penalty charges.

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 metering transformers s...

AI summary This section outlines the special conditions for port electricity supply, including ownership responsibilities, operational requirements, metering arrangements, and power factor maintenance. The Port Authority and NSPI have defined roles, and customers are required to cover additional costs for specialized metering and communication systems.

APPLICABILITY - (1) The RTT is applicable to the LRS, and is in addition to (and not in substitution of) any charges owing by the LRS to NS Power under the Open Access Transmission Tariff (OATT), the Standby Service Tariff, or the Energy B...

AI summary The RTT applies to Load Serving Retailers (LRS) in addition to other tariffs. It includes energy and demand charges with adjustments based on forecasted savings and avoided costs. The LRS must also take service under the OATT and other tariffs. The RTT includes annual adjustments and credits based on forecasted performance.

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-3: Refer to M12551, Exhibit N-1, the Application, page 9 of 45, at lines 26 – 31 and continuing through page 10 of 45, at lines 1 - 22, which states: Following the Board's 2024 AAR Decision, the Company filed (on July 31, 2024)...

AI summary Following the Board's 2024 AAR Decision, NS Power filed and received acceptance of the Year Three (2023/24) TVP Pilot Evaluation Report. The Board directed NS Power to develop on-peak and off-peak AARs after the TVP pilot evaluation is complete. A cybersecurity incident in April 2025 led to an extension for filing the 2024/25 TVP Evaluation Report and a temporary suspension of TVP Tariffs. NS Power plans to re-initiate stakeholder engagement once systems are restored and evaluations are complete.

Request IR-4: Refer to M12551, Exhibit N-1, the Application, Section 7.0 Renewable to Retail Market (RtR) Tariffs and the proposed RtR Tariff Administration Charge , which states: The Company has calculated the RtR Tariff Administration Ch...

AI summary The document discusses NS Power's proposed RtR Tariff Administration Charge, including the deferral of costs incurred in 2026 and anticipated recovery starting in 2027. Questions are raised about current estimated costs, whether interest costs will be applied, and the expected interest rate.

n addition to the BUTU and Spill Tariffs, has NS Power used this 3.25 percent escalation factor in any other application for approval of revised tariff rates for 2026 or in the proposed GRA in M12451? Refer to M12551, Exhibit N-1, the Appl...

AI summary The text inquires whether NS Power applied a 3.25 percent escalation factor in any other applications for revised tariff rates in 2026 or in the proposed GRA in M12451, referencing a specific increase in the Spill Tariff and an appendix for supporting calculations.

ection 4.1). The Company received feedback on the TVP aspects of the letter in February 2025. On March 25, 2025, the Board issued its Decision on the 2025 AARs, which provided the following directive: In the 2023 AAR decision, the Board no...

AI summary The Board directed NS Power to develop on-peak and off-peak AARs after the TVP pilot evaluation is complete, and to engage with stakeholders. A cybersecurity incident in April 2025 delayed the TVP Evaluation Report and temporarily suspended TVP Tariffs. NS Power plans to re-initiate stakeholder engagement once systems are restored and evaluations are complete.

ffering a TVP structure for AARs? Refer to M12551, Exhibit N-1, the Application, Section 7.0 Renewable to Retail Market (RtR) Tariffs and the proposed RtR Tariff Administration Charge , which states: The Company has calculated the RtR Tari...

AI summary The document discusses NS Power's proposed RtR Tariff Administration Charge and associated costs, including deferred costs and future recovery plans. It also references standby service tariff charges for 2025 and 2026 and asks about estimated costs, interest rates, and supporting documentation.

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 2026.[[5]](#footnote-6) 1. Does the proposed higher 2026 Admini...

AI summary The document discusses the proposed increase in the 2026 Administration Charge for standby service tariffs, asking whether the 3.25% increase aligns with other AAR tariffs. It also addresses the Annually Adjusted Energy Savings Credit, noting that NS Power does not project savings in this category for 2026 and requests an explanation and supporting information.

1 Request IR-14: - 2 Reference: Standby Service, page 34. - 3 With respect to Figure 10, please add a column to show the percentage change for each - 4 component of the Standby Service Tariff compared to 2025 rates. Where the change is gre...

AI summary The request asks for an updated Figure 10 with a new column showing percentage changes in Standby Service Tariff components compared to 2025 rates, and detailed explanations for changes exceeding 10%.

7 Request IR-15: - 8 Reference: Appendix F3, page 137 Standby Demand Charge Calculation. - 9 (a) Please explain in detail the source and derivation of the Interruptible 10 Service Credit, including the methodology, assumptions, and calcula...

AI summary Request IR-15 asks for detailed information on the Interruptible Service Credit, including its source, derivation, methodology, and assumptions, as well as its relation to the Pilot Interruptible Service in the RtR market and the Board order or tariff provision authorizing it.

16 Request IR-17: - 17 (a) Under the current RTT framework, please confirm whether the Annual 18 Energy Cost Adjustment would require NS Power to provide a credit to the 19 RtR customer in circumstances where the Average Marginal Cost (or...

AI summary The request seeks clarification on the Annual Energy Cost Adjustment under the RTT framework, specifically regarding whether credits are required when avoided costs exceed system fuel costs, the amount of such credits, and any limitations or constraints on the credit magnitude.

16 Request IR-19: 17 With respect to Figure 11, page 37, please add a column to show the percentage change for each 18 component of the RTT compared to 2025 rates. Where the change is greater than 10% for a 19 particular component, please...

AI summary The request asks for the addition of a column in Figure 11, page 37, showing the percentage change for each component of the RTT compared to 2025 rates. If the change exceeds 10%, a detailed explanation of the drivers is required.

1. Please confirm that NS Power considered REI’s forecasted market uptake in its load forecast and calculation of average and marginal costs for 2026. If not, please explain why REI's forecast was not considered and what load migration ass...

AI summary The text outlines a series of questions directed at NS Power regarding its load forecasting, cost calculations, and tariff provisions related to the RTT Annual Energy Cost Adjustment. It asks whether REI's forecast was considered, how load migration impacts cost calculations, and whether credits are provided under certain conditions.

tations, offsets, or adjustments that would reduce the credit amount? Please explain with reference to specific tariff provisions. 7. Please indicate whether NS Power believes that any cap, limit, floor, or other constraint applies to the...

AI summary The document addresses questions about the Annual Energy Cost Adjustment and related credits, including whether caps or constraints apply. NS Power explains that the Annually Adjusted Energy Savings Credit is designed to account for non-fuel cost savings from freed-up capacity, but no savings are projected in 2026. The current value of zero remains in effect.

ce. The Company does not project savings in this cost category and proposes that the current value of zero remains in effect in 2026. Reference: RTT Demand Savings Credit, page 36, lines 17-23. The Annually Adjusted Demand Savings Credit i...

AI summary The Company does not project savings in the Annually Adjusted Demand Savings Credit cost category and proposes maintaining the current value of zero for 2026. This credit is intended to pass non-fuel demand-related cost savings to the LRS due to freed up capacity from RtR market participation, but the Company's ability to mitigate costs is limited by its need to maintain generation capacity.

Request IR-3: In its letter of January 31, 2025, NS Power stated that it would "prepare a proposal outlining the change in methodology for the calculation of the FCA component of 1P-RTP Tariffs for distribution to stakeholders in Q2 2025,...

AI summary NS Power committed to prepare a proposal outlining changes to the FCA component of 1P-RTP Tariffs for stakeholder review in Q2 2025. The request seeks clarification on whether this proposal was completed and, if not, the reason for the delay.

ed under the proposed 1P-RTP and the alternate 1P-RTP (as provided in response to part (c) above) rates, and explain any material differences in the total cost recovery. - (e) NS Power further states, In view of the foregoing [referencing...

AI summary NS Power has eliminated the adjustment for the projected imbalance in the recovery of the avoided fuel in response to the SO2 emissions limit. Energy charges are now based on hourly marginal costs, and fixed cost adders include only non-fuel costs.

nsitivity analyses.[[10]](#footnote-11) In its application, NS Power states that it “does not believe the ‘no new wind’ scenario to be indicative of a plausible outcome for 2026.”[[11]](#footnote-12) 1. Please explain why NS Power submitte...

AI summary The document includes questions directed at NS Power regarding its submission of a sensitivity analysis it considers not plausible, the Q3 2025 wind site forecast, and alternate scenarios for wind project delays. It also requests clarification on the implications of Sensitivity 4 results for rate setting.

December 12, 2025 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 He...

AI summary NS Power applied for interim approval of the 2026 ELIADC Tariff, which was previously approved in Matter M12184. The Board granted approval but required amendments, including increasing the minimum payment, adjusting cost structures, and improving reporting requirements.

sition in Matter M11989, NS Power has indicated to PHP it does not oppose the Board granting interim approval of the 2026 ELIADC Energy Charge effective January 1, 2026 if the Board deems appropriate. Accordingly, PHP submits this request...

AI summary PHP requests interim approval for the 2026 ELIADC Energy Charge to be effective January 1, 2026, with the possibility of amendment by the Board in its final decision. NS Power does not oppose this request.

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.

January 14, 2026 Crystal Henwood Clerk of the Board Nova Scotia Energy Board 1601 Lower Water Street, 3rd Floor Halifax, NS B3J 3S3 Re: M12551 2026 AAR Application – NS Power Comments on PHP's Request for Interim Approval of the 2026 ELIAD...

AI summary NS Power does not oppose the interim approval of the 2026 ELIADC Energy Charge, aligning with its previous position in Matter M11989. The request was submitted by Port Hawkesbury Paper LP (PHP) for the Nova Scotia Energy Board's approval.

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.

Multiple Moving Variables The ELIADC is a below-the-line ("BTL") rate. The ongoing General Rate Application ("GRA " ), Matter M12451, assumes PHP takes above-the-line ("ATL") service, as of January 1, 2026 – the same timeline in which PHP...

AI summary The document discusses the ELIADC rate and the GRA application, highlighting the uncertainty around PHP's transition to ATL service and the potential cost implications. NSPI seeks to defer risks through a deferral account, while concerns are raised about the fairness of granting PHP interim relief without similar measures for other customer classes.

m of the ELIADC Tariff in another matter (M12184) and relying on Section 69(1) of the Public Utilities Act, which permits the Board to grant interim approval of rates in the following circumstances: When a public utility has submitted for...

AI summary The document discusses the interim approval of the ELIADC Tariff under Section 69(1) of the Public Utilities Act, noting that the change may represent a rate reduction for the sole customer, PHP, and thus qualifies for interim approval.

f the ELIADC Tariff, it would appear that the first option is applicable, as PHP is the only customer within the ELIADC rate class and the change does appear to represent a reduction is costs for PHP. However, as noted, the section offers...

AI summary The text discusses the ELIADC Tariff and the interim approval process for PHP, noting that the Board's previous approval in M11989 set the rate effective from February 1, 2025, avoiding a true-up for January 2025. It suggests that applying the interim rate retroactively could lead to multiple readjustments and recommends setting the rate effective from February 1, 2026.

tory Boards Act , S.N.S. 2024, c. 2, Sch. A, the Nova Scotia Utility and Review Board (NSUARB) was succeeded by the Nova Scotia Energy Board (Board) for all applications related to electric utilities. NS Power filed its 2026 AAR applicatio...

AI summary NS Power submitted its 2026 AAR application with proposed updates to tariff methodologies and rates. The application includes changes to transmission rate structures and fixed cost adders for specific tariffs. The NSUARB was replaced by the Board, and NS Power faced delays due to a cyber attack affecting the TVP pilot evaluation. The Board directs NS Power to provide an update in its 2027 AAR.

Other Issues raised by the CA and SBA The CA's submission did not object to NS Power's AAR application, however, comments about the modeling of imports were provided. Specifically, the CA noted that there were inconsistencies between the h...

AI summary The CA raised concerns about inconsistencies in NS Power's modeling of NB imports and surplus energy volumes, while the SBA expressed concerns about risk transfer and cross-subsidization related to AAR rates. NS Power explained its methodology for adjusting NB import volumes and clarified that AAR customers bear greater risk than Above the Line customers. The Board found the methodology reasonable and agreed with NS Power's explanation.

Renewall Energy Inc. REI's submission was concentrated on the use of the proposed Cost of Service Study methodology, the RtR tariff review and design, RTRSS tariff calculation and the forecasted marginal cost used in the application. Notab...

AI summary Renewall Energy Inc. (REI) submitted concerns regarding the proposed Cost of Service Study methodology, RtR tariff design, and RTRSS tariff calculation, noting changes to the RTRSS formula. REI requested recalculations and regulatory action by March 31, 2026. NS Power responded by suggesting that addressing these issues may be premature and that changes should occur after the RtR begins service.

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 conditions, including interim approval of the ELIADC tariff. It issues several directives to NS Power, including revising sensitivity analyses, providing data on administration charges, and initiating stakeholder engagement. The final approval of AAR rates is pending the outcome of the COSS review.

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.

2. 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...

AI summary The Board has directed NS Power to make various adjustments to its AARs, including updates on wind resource deployment, sensitivity analysis of the Maritime Link, and stakeholder engagement on tariff amendments. NS Power must also submit data on administration charge inflation adjustments and file the 2027 AAR application by a specific deadline.

AVAILABILITY This tariff is available to: - (a) Customers who have their own qualifying generating facility of not less than 2,000 kW of aggregate capacity, as defined under Special Condition 8, normally used to support their own load; - (...

AI summary The tariff is available to customers with qualifying generating facilities and those needing energy for non-utility generation sites. Energy supply is contingent on customer requests, with pricing based on estimated or actual costs depending on the situation.

GENERATION LOAD FOLLOWING CRITERIA Effective: April 1, 2026 - (1) Two months preceding each tariff year the customer-generator, in conjunction with the Company, shall establish the aggregate net operating capability of its generation equip...

AI summary This document outlines the generation load following criteria effective April 1, 2026. It specifies procedures for determining net operating capability and the process for the Company to apply for approval of its forecasted incremental generation costs with the Nova Scotia Energy Board.

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): 10.008 ¢/kWh Off-peak (11:00 pm – 7:00am, non-holiday weekday...

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 applied for customer-owned transformers based on monthly peak demand.

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-genera...

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, applying from April 1 to November 30, and outlines the priority order for capacity contributions during supply shortfalls.

SUPPLY INTERRUPTIONS This is an interruptible service. Before connecting the ship to the shore supply the port authority will request permission from NSPI indicating the expected load and duration for which the power is needed. The custome...

AI summary This section outlines the conditions for interruptible service under the tariff, requiring customers to provide notice, maintain communication systems, and comply with load reduction requests from NSPI. Failure to comply may result in penalties.

WHOLESALE MARKET BACKUP/TOP-UP SERVICE TARIFF Page 1 of 6 CUSTOMER CHARGE The monthly customer charge under this tariff is calculated according to the following formula: Monthly customer charge = forecast annual administration costs foreca...

AI summary The monthly customer charge under the Wholesale Market Backup/Top-Up Service Tariff is calculated using forecasted annual administration costs and the number of subscribed customers, resulting in a fixed charge of $414.63 per month.

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 using forecast annual administration costs and the number of suppliers supplying wholesale customers, resulting in a charge of $2,487.77 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 The document outlines special conditions for energy balancing services, including NS Power's right to establish separate service agreements, requirements for LRS' RtR customers and generators to maintain power supply integrity, and factors considered in assessing system integrity. NS Power also retains the right to apply for changes in rates or terms through the Nova Scotia Energy Board.

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 based on forecasted administration costs and the number of LRS subscriptions, amounting to $414.63 per month.

APPLICABILITY - (1) The RTT is applicable to the LRS, and is in addition to (and not in substitution of) any charges owing by the LRS to NS Power under the Open Access Transmission Tariff (OATT), the Standby Service Tariff, or the Energy B...

AI summary The RTT applies to the LRS in addition to other tariffs, with energy and demand charges adjusted annually based on forecasted savings and cost differences. The LRS must also take service under the OATT and other tariffs.

Customer Baseline Energy Charge, Customer Baseline Energy Cost, and Contribution to Utility Costs In advance of each tariff year, PHP shall advise NS Power of its forecast annual and monthly energy requirements for the subsequent calendar...

AI summary The document outlines the calculation method for the Customer Baseline Energy Charge (CBL Energy Charge) and related components, including the CBL Adder (CBLA) and Variable Capital Charge (VCC), which are used to determine the ELIADC Energy Charge. The process involves forecasting energy requirements, calculating incremental costs, and applying specific formulas based on forecasted CBL Cost levels.

ACTIVE DEMAND CONTROL AND SCHEDULE VARIANCE NS Power shall be entitled to actively manage PHP's load in accordance with the terms and conditions set out in the Active Demand Control – Energy Supply Protocol attached as Schedule 1 to this T...

AI summary NS Power is allowed to manage PHP's load under the Active Demand Control – Energy Supply Protocol. NS Power must report system savings and schedule variances annually to the Board, including load shifting benefits and improvements to the ELIADC Tariff. PHP receives a 25% credit based on the cost differential between CBL Cost and actual annual serving costs.

REOPENER If, at any time during the Term, NS Power or PHP determines that the ELIADC Tariff is not working effectively, the parties shall work together to try to resolve any such concerns. If the parties cannot resolve such concerns, eithe...

AI summary The document outlines the process for adjusting the ELIADC Tariff if it is deemed ineffective. If NS Power or PHP cannot resolve concerns, either may request the Board to adjust the tariff, potentially on an expedited basis. PHP would then have the opportunity to decide whether to remain on the adjusted tariff.

MINIMUM LOAD REQUIREMENT NS Power will withdraw the availability of this tariff, if, on a consistent basis, PHP is not maintaining a regular demand of 25,000 kVA.

AI summary NS Power will withdraw the availability of the tariff if PHP consistently fails to maintain a regular demand of 25,000 kVA.

INTERRUPTIBILITY The Mill will reduce its load by, at a minimum, the amount requested by NS Power within 10 minutes of such request by NS Power. Following such interruption, service may only be restored by the Mill with the approval of NS...

AI summary The document outlines the requirements for load interruption under the Large Industrial Interruptible Rider, including the obligation of PHP to reduce load within 10 minutes of NS Power's request, the penalties for non-compliance, and the calculation of Threshold and Performance Penalties based on residual demand and average demand during interruptions.

Conversion of Interruptible Load to Firm Should PHP desire to be served under any applicable firm service tariff, a five-year advance written notice must be given to NS Power so as to ensure adequate capacity availability. Requests for a c...

AI summary PHP must provide five years' written notice to NS Power to convert from interruptible to firm service, with possible exceptions for earlier conversion. PHP may revert to interruptible service after two years under the firm tariff, with potential for earlier reversion.

ra. 737. March 25, 2026. 4 At para. 737, the Board provided: "[…] Intervenors will have one week from the date that NS Power files its March 27, 2026 C. Henwood NS Power is in the process of compiling its 2026-2027 GRA Compliance Filing; h...

AI summary NS Power requests an extension for the 2026 AAR Compliance Filing due to overlapping personnel commitments with the 2026-2027 GRA Compliance Filing. The request is to extend the due date by two weeks following 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.

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 applies to port authorities in Nova Scotia 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 order in which rate classes will be called upon during supply shortfalls.

SUPPLY INTERRUPTIONS This is an interruptible service. Before connecting the ship to the shore supply the port authority will request permission from NSPI indicating the expected load and duration for which the power is needed. The custome...

AI summary This section outlines the conditions for interruptible service under the tariff, including customer responsibilities such as providing notice, reducing load within 10 minutes, maintaining a dedicated phone line, and potential penalties for non-compliance with load interruption requests from NSPI.

SPECIAL CONDITIONS - (1) NS Power reserves the right to have a separate service agreement, ifin the opinion ofNS Power issues not specifically set out herein, must be addressed for the ongoing benefit ofNS Power and its customers. - (2) Th...

AI summary NS Power reserves the right to establish separate service agreements for issues not covered in the current terms, ensuring the integrity of the power supply system through specific operating agreements and considerations such as reliability and stability. NS Power may also apply for changes to rates or terms with the Nova Scotia Energy Board.

ard notes that any impacted party, including REI, can apply to the Board for relief, with supporting materials, if the parties cannot agree on a reasonable timeline.[1](#page-0-0) [ emphasis added ] By email dated April 30, 2026, Nova Scot...

AI summary Nova Scotia Power Inc. (NS Power) has been engaging with REI regarding tariff amendments, including monthly marginal cost pricing and a true-up mechanism for RtR tariffs. The Board directed NS Power to provide updates, and NS Power has shared marginal cost data with REI but has not yet received a response. NS Power is also working on other Board-directed proceedings that may impact the outcome of M12551.

COMMENTS ON STATUS AND PATH FORWARD REI agrees with the Board's observation that a number of proceedings — including M11422 (Large Industrial Interruptible Rider (LIIR) Pilot), M12339 (Development of RtR Tariff Amendments), and M12588 (Ren...

AI summary REI agrees with the Board's observation that several ongoing proceedings impact the Renewable to Retail (RtR) framework and REI's market entry. REI is collaborating with NS Power on these matters and supports the need for a new process to establish a cost recovery mechanism for RtR implementation costs.

Renewall responded, in part: REI confirms that it has received and reviewed the actual hourly marginal cost data for 2024 and 2025 provided by NS Power. REI notes that it had requested a broader range of historical years in order to assess...

AI summary REI has reviewed marginal cost data for 2024 and 2025 but requests additional historical data for a more comprehensive analysis of a potential true-up mechanism. REI also acknowledges the importance of the RtR tariff framework and is working with NS Power on related proceedings, including the development of a cost recovery mechanism for RtR implementation.