Topic:"Demand Side Management" in M12551

Application for Annually Adjusted Rates for 2026 Redacted 1 TABLE OF CONTENTS 2 3 1.0 Introduction 7 4 1.1 Prior AAR Proceeding Directives 8 5 1.2 Board Directive regarding Time-varying Pricing Structure for AARs 9 6 2.0 Marginal Cost Anal...

AI summary The document outlines an application for annually adjusted rates for 2026, including sections on marginal cost analysis, tariff structures, and various board directives related to pricing and billing procedures. It covers topics such as load following, real-time pricing, shore power, wholesale market tariffs, and renewable to retail market tariffs.

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.

SALES, GENERATION AND DEMAND ANALYSIS FOR THE YEAR ENDING DECEMBER 31, 2026 ( 1) DOMESTIC ( 2) SMALL GENERAL ( 3) GENERAL ( 4) GENERAL LARGE (1) MWH SALES 5,286,337,241 376,992,742 2,308,034,614 363,766,784 (2) ENERGY LINE 8.2% 8.2% 7.9% 5...

AI summary The document presents a detailed analysis of sales, generation, and demand for the year ending December 31, 2026, including metrics such as energy sales, losses, system demand, and contribution percentages across various customer classes and industrial sectors.

- (2) Demand-related fixed generation cost, coming into effect as a result of a General Rate Application. Demand Charge Components $ per kW of billing demand Demand-related Purchased Power Cost $6.252 Demand-related Fixed Generation Cost $...

AI summary The document outlines the demand-related fixed generation cost, which is part of a General Rate Application. It includes a table showing the demand charge components, such as demand-related purchased power cost and demand-related fixed generation cost, totaling to $11.704 per kW of billing demand.

The Demand Charge is made up of two components: Demand Charge Components dollars per kW Demand Charge from Standby Service Tariff $5.452 Annually Adjusted Demand Savings Credit $0.000 Total $5.452 The Demand Charge is applicable to the LRS...

AI summary The Demand Charge consists of two components: the Demand Charge from Standby Service Tariff and the Annually Adjusted Demand Savings Credit. The charge applies to the LRS' monthly displaced demand on NS Power's system, calculated as the difference between Winter Peak Firm Demand and Monthly Standby Contract Demand under the Standby Service Tariff.

Source Category Demand-related Costs Cost in thousands of $'s 2026 COSS - Exhibit 5, page 1, column 2. $357,621.5 Less FUEL $0 PURCHASES - OTHER THAN BIOMASS AND WIND $8,334 PURCHASES - BIOMASS $5,365 MARITIME LINK $90,413 PURCHASES - WIND...

AI summary The document presents demand-related costs, including fuel purchases, capacity credits, and ancillary service costs, as well as standby demand charge calculations for various service types. It includes data from multiple exhibits and references specific regulatory filings.

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.

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 The tariff applies to PHP's operations at Point Tupper, assuming exclusive service by NS Power. It includes load management via Active Demand Control protocols, specifies voltage requirements, and prohibits combining with other tariffs without NSEB approval.

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.

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.

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.

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.

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 for interrupting load during electricity supply shortfalls, starting with Generation Replacement and Load Following Tariff and ending with the Interruptible Rider to the Large Industrial Tariff. NS Power may adjust the order if needed.

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.

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, plus a CBLA to reduce service costs for other customers, and a credit for system savings from Active Demand Control. The pricing includes CBL Cost, CBL Energy Charge, CBLA, Variable Capital Charge, and an Active Demand Control Credit.

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 interruptibility, specifying that PHP must reduce its load by the amount requested by NS Power within 10 minutes and obtain approval for restoring service. It also requires PHP to provide contact information for individuals capable of managing load interruptions.

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.

Where: "A" is any residual demand (above that required by the interruption request) remaining in the third interval directly following two complete 5-minute intervals after the interruption call was delivered by telephone call. "B" is PHP'...

AI summary This section defines the conditions for penalties related to demand interruption failures by PHP. It outlines how penalties are calculated based on residual demand and average excess demand, limits on interruptions, and the application of penalties for repeated failures.

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 for interrupting load during electricity supply shortfalls, starting with Generation Replacement and Load Following Tariff and ending with the Interruptible Rider to the Large Industrial Tariff. NS Power may adjust the order if needed.

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.

Where: "A" is any residual customer demand (above that required by the interruption notice) remaining in the third interval directly following two complete 5-minute intervals after the interruption call is initiated and sent by NSPI. "B" i...

AI summary The text defines terms related to customer demand during an interruption event and mandates customer responsibility for installing approved metering equipment to monitor generation output, with associated costs borne by the customer.

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 The document outlines special conditions for electricity supply to ships at the port, including responsibilities for equipment maintenance, metering arrangements, and power factor requirements. The Port Authority and NSPI have defined roles, and customers may be required to contribute to capital costs for special metering.

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.

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.

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 document outlines the procedures for load interruption under the Extra Large Industrial Active Demand Control Tariff, including penalties for non-compliance by PHP. The penalty consists of a Threshold Penalty and a Performance Penalty, calculated using specific formulas.

Where: "A" is any residual demand (above that required by the interruption request) remaining in the third interval directly following two complete 5-minute intervals after the interruption call was delivered by telephone call. "B" is PHP'...

AI summary The text outlines the rules for interruptions and penalties related to demand compliance. It defines 'A' and 'B' as metrics for residual demand and excess demand, respectively, and specifies that penalties will not exceed twice the formula amount. Penalties apply for each failure to interrupt, with limitations on interruption duration.

Power Factor Constant Power Factor Constant 90-100% 1.0000 65-70% 1.1255 80-90% 1.0230 60-65% 1.1785 75-80% 1.0500 55-60% 1.2455 70-75% 1.0835 50-55% 1.3335 METERING COSTS

AI summary The table outlines power factor constants for various ranges, which are relevant to metering costs. These constants may be used in calculating energy efficiency or demand-side management-related charges.

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 price PHP pays for electricity based on forecasted incremental costs, with adjustments for system savings and Active Demand Control. Key components include Customer Baseline Energy Cost, Variable Capital Charge, and an Active Demand Control Credit.

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.

Where: "A" is any residual demand (above that required by the interruption request) remaining in the third interval directly following two complete 5-minute intervals after the interruption call was delivered by telephone call. "B" is PHP'...

AI summary The text outlines penalty rules for PHP when failing to respond to interruption calls. Penalties are based on residual demand and average demand exceeding compliance levels. The total penalty cannot exceed twice the formula amount, and interruptions are limited to specific hours per day and week.

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.

REDACTED 1 Response IR-1: 2 3 (a) Demand and energy for 2026 are estimated based on 2024 hourly load shapes and 2018 4 hourly wind production and assume that BUTU is only provided up to the actual hourly 5 demand of the MEUs. The estimates...

AI summary The response estimates demand and energy for 2026 using 2024 hourly load shapes and 2018 hourly wind production data, assuming BUTU is only provided up to the actual hourly demand of the MEUs.

FOR THE YEAR ENDING DECEMBER 31, 2026 (1) (2) ENERGY (3) (4) CLASS NON- SYSTEM (5) (6) (7) (8) SYSTEM DEMAND SYSTEM (9) SYSTEM (10) (11) MWH SALES LINE ENERGY LOSSES REQUIREMENT DMD. (KW) FACTOR COINCIDENT COINCIDENT COINCIDENT LINE COIN....

AI summary The document provides a detailed breakdown of energy sales, losses, and demand across various customer classes for the year ending December 31, 2026, highlighting metrics such as MWH sales, line losses, and demand factors.

DEMAND CLASSIFICATION (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (9) (10) (11) ALLOCATION (30) Streetlights: (31) OPERATING & MAINT. 813 0 0 0 0 0 0 0 0 0 813 EXH 6A (32) GRANTS IN LIEU OF TAXES 327 0 0 0 0...

AI summary The table presents a breakdown of demand classification, including operating and maintenance costs, depreciation, interest, corporate taxes, and return on investment, with various line items and allocations. These figures are categorized under different classifications such as small, general, and large, with specific references to exhibits and pages.

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.

15 The increase of 60.5 percent in the Demand Charge is due to the following causes as reflected in 16 the 2023 and 2026 Cost-of-Service Study (COSS). 17 18 Change in the COSS methodology which resulted in a bigger proportion of generation...

AI summary The 60.5% increase in the Demand Charge is attributed to a change in the COSS methodology, which increased the proportion of generation rate base classified to demand from 35.6% in the 2023 COSS to 45.3% in the 2026 COSS, leading to a 24% increase in non-fuel demand-related costs.

3.3 Interruptible Service Interruptible service has been made available by NS Power as a Bundled Service option to qualifying large industrial customers. Those customers undertake to interrupt their load on demand (or by remote trigger) of...

AI summary Interruptible service is offered by NS Power to qualifying large industrial customers as a Bundled Service option, with penalties for non-compliance. Customers on interruptible service are not counted in firm load, and switching to firm service requires additional capacity development. Stakeholders indicated that interruptibility status remains unchanged when switching between Bundled Service and RtR service.

NON-CONFIDENTIAL 1 Please refer to REI IR-14 for the explanation of the increase in the Demand Charge by 2 Components.

AI summary The document references an increase in the Demand Charge and directs readers to REI IR-14 for an explanation, though no further details are provided in the text.

January 20, 2026 James A. MacDuff Direct +1 (902) 444 8619 [email protected] Purdy's Wharf Tower II 1300-1969 Upper Water Street PO Box 730 Halifax NS Canada B3J 2V1 Tel +1 (902) 425 6500 Fax +1 (902) 425 6350 Ms. Crystal Hen...

AI summary Port Hawkesbury Paper supports the proposed 2026 ELIADC Energy Charge of $75.87/MWh, requesting its effective date be January 1, 2026. They filed for interim approval, which NS Power and others do not oppose, though the Consumer Advocate and Industrial Group question the timing of the effective date.

DEMAND CHARGE $3.397_5.616 per month, per kilowatt (kW) of monthly standby contract demand.

AI summary The document specifies a demand charge of $3.397 to $5.616 per month, per kilowatt (kW) of monthly standby contract demand.

- (2) Demand-related fixed generation cost, coming into effect as a result of a General Rate Application. Demand Charge Components $ per kW of billing demand Demand-related Purchased Power Cost $4.3686.252 Demand-related Fixed Generation C...

AI summary The text outlines a demand-related fixed generation cost introduced through a General Rate Application. It includes a table with demand charge components, specifying costs per kW of billing demand, and defines Contract Demand requirement as the firm demand requested by a wholesale customer and agreed to be supplied by NSPI.

Billing demand is determined based upon the following formula: Billing demand = $$(PR/(1+PR) min(CD, CCF GC)) + (CD - min(CD, CCF GC))$$ Where: PR is Planning Reserve (based on NPCC planning criteria, i.e. 20% or as updated) GC is the thir...

AI summary The document outlines the formula for calculating billing demand, which takes into account factors such as planning reserve, generating capacity, and customer contract demand. It distinguishes between non-dispatchable and dispatchable generation and refers to specific tariffs and conditions for determining generating capacity.

2026 AAR Compliance Filing Appendix A Page 5 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) ONE PART DISTRIBUTION VOLTAGE REAL TIME PRICING TARIFF Page 2 of 3 will be required to make a capital contribution equal to the additional capit...

AI summary The document outlines the terms and conditions of the One-Part Distribution Voltage Real-Time Pricing Tariff, including capital contributions for metering, transformer loss adjustments, service duration, and power factor requirements. It also specifies eligibility and transition rules for customers moving from the Interruptible Rider of the Large Industrial Tariff.

- (2) Demand-related fixed generation cost, coming into effect as a result of a General Rate Application. Demand Charge Components $ per kW of billing demand Demand-related Purchased Power Cost $6.222 Demand-related Fixed Generation Cost $...

AI summary The document outlines the introduction of a demand-related fixed generation cost as part of a General Rate Application. It includes a table showing the cost components, specifically the demand-related purchased power cost and demand-related fixed generation cost, which together total $11.822 per kW of billing demand.

The Demand Charge is made up of two components: Demand Charge Components dollars per kW Demand Charge from Standby Service Tariff $5.601 Annually Adjusted Demand Savings Credit $0.000 Total $5.601 The Demand Charge is applicable to the LRS...

AI summary The Demand Charge consists of two components: the Demand Charge from Standby Service Tariff and the Annually Adjusted Demand Savings Credit. The total Demand Charge is $5.601 per kW, applicable to the LRS' monthly displaced demand determined under the Standby Service Tariff.

ervice by the time the 2027 AAR application is filed, NS Power is directed to provide scenarios for the total amount of energy not realized for periods ranging between one month and 10 months in 2027. The NSUARB directed NS Power to provid...

AI summary NS Power is directed to provide energy not realized scenarios for 2027 and to compare forecasted New Brunswick imports with actual imports from 2021 to 2026. The Board also directed NS Power to update RTP tariffs, with fixed cost adders requiring annual updates and energy charges based on real-time marginal costs.

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.

tion will be supplied either through on-going communication provision such as telemetering (when load fluctuations are involved) or written requests (where application is to a specific level of load). - (2) In the event there is an interru...

AI summary This section outlines the procedures for load interruption under the Generation Replacement Service and Load Following Service, emphasizing customer obligations, the role of NS Power in managing interruptions, and the penalties for non-compliance.

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.

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 The Port Authority and NSPI have defined roles and responsibilities regarding electrical equipment, metering, and operational procedures for port electricity supply. Special conditions include metering responsibilities, staff availability, scheduling, metering costs, transformer losses, and power factor requirements.

SPECIAL CONDITIONS - (1) This tariff is designed for customers supplied and metered at the high side of the transformer at transmission voltage of 69 kV or higher. For customers metered at the low side of the transformer, or at a distribut...

AI summary This section outlines special conditions for a high-voltage transmission tariff, including adjustments for metering locations, requirements for transmission service, service denial criteria, load management obligations, and conditions for billing demand calculations involving third-party generation resources.

The Demand Charge is made up of two components: Demand Charge Components dollars per kW Demand Charge from Standby Service Tariff $5.452 Annually Adjusted Demand Savings Credit $0.000 Total $5.452 The Demand Charge is applicable to the LRS...

AI summary The Demand Charge consists of two components: the Demand Charge from Standby Service Tariff and the Annually Adjusted Demand Savings Credit. The charge applies to the LRS' monthly displaced demand on NS Power's system, calculated based on Winter Peak Firm Demand and Monthly Standby Contract Demand as defined in the Standby Service Tariff.

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.

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.

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.

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.

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.

- (2) Demand-related fixed generation cost, coming into effect as a result of a General Rate Application. Demand Charge Components $ per kW of billing demand Demand-related Purchased Power Cost $6.222 Demand-related Fixed Generation Cost $...

AI summary The text introduces a demand-related fixed generation cost that is part of a General Rate Application. It outlines the components of the demand charge, including purchased power and fixed generation costs, and defines contract demand in the context of wholesale customers and suppliers.

The Demand Charge is made up oftwo components: Demand Charge Components dollars per kW Tariff Demand Charge from Standby Service $5,601 Annually Adjusted Demand Savings Credit $0,000 Total $5,601 The Demand Charge is applicable to the LRS'...

AI summary The Demand Charge consists of two components: the Tariff Demand Charge from Standby Service and the Annually Adjusted Demand Savings Credit. The charge applies to the LRS' monthly displaced demand on NS Power's system, calculated as the difference between Winter Peak Firm Demand and Monthly Standby Contract Demand under the Standby Service Tariff.

NOTICE OF INTERVENTION TO: The Nova Scotia Utility and Review Board ("Board") AND TO: Nova Scotia Power Inc. ("NSPI") - 1. PORT HAWKESBURY PAPER LP ("PHP") conducts its business in Nova Scotia, and is engaged in the manufacture of paper at...

AI summary Port Hawkesbury Paper LP (PHP) is requesting intervenor status in a proceeding before the Nova Scotia Utility and Review Board, as it purchases significant power from Nova Scotia Power Inc. under the ELIADC Tariff and has a vested interest in the matter.

- In Appendix I EO there are Demand Side Management Cost Recovery Rider Charges. Why are - these included as part of the AARs? Document: 325987 Date Filed: 12/01/25 Page 5

AI summary The document asks why Demand Side Management Cost Recovery Rider Charges are included as part of the Annually Adjusted Rates (AARs) in Appendix I EO.

l and Purchased Power Model.17 17 - 2025 PLEXOS AAR F&PP model is based on the 2024 Q3 forecast F&PP model, with updated system assumptions, including commodity pricing update as of 2024-08-16. 1. In stating the above, is NS Power saying i...

AI summary The text discusses the 2025 PLEXOS AAR F&PP model used by NS Power, with assumptions based on August 2024 data. It raises questions about model accuracy, data timeliness, and the identification of highest variable cost generators. The preamble also references economic dispatch and environmental legislation, as well as forecast accuracy assessments via FAM reporting.

capacity in the event the RtR customer returns to NS Power’s service. The Company does not project savings in this cost category and proposes that the current value of zero remain in effect in 2026. 1. Please confirm the assumptions in 202...

AI summary The text requests clarification on assumptions related to load transitioning from NS Power’s service to RtR, firm capacity contributions, and the purpose of certain tariff components. It also asks for a Market Design White Paper and a revised figure showing percentage changes in RTT components compared to 2025 rates.

ing the “adjustment for the projected imbalance” is the SO2 emissions limit issue. 2. Please explain any other reasons that NS Power has for eliminating the “adjustment for the projected imbalance.” In its 2018 AAR application, NS Power st...

AI summary The text discusses NS Power's reasons for eliminating the 'adjustment for the projected imbalance' and the treatment of unit commitment costs under different AAR tariff designs. It also references the Board's requirement for sensitivity analyses regarding potential delays in wind resource in-service dates in the 2026 AAR application.

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.

ORDER On November 7, 2025, NS Power filed its application for approval of the 2026 Annually Adjusted Rates (AARs). On December 12, 2025, Port Hawkesbury Paper requested an interim order approving the 2026 Extra Large Industrial Active Dema...

AI summary NS Power submitted an application for 2026 Annually Adjusted Rates (AARs). Port Hawkesbury Paper requested an interim approval for the 2026 ELIADC tariff, which was granted. The Board approved the 2026 AARs effective April 1, 2026, with the possibility of amendment based on the updated Cost of Service Study.

The Board orders the following. - 1. NS Power's Annually Adjusted Rates, Schedules A to J, are approved for the period April 1, 2026, to December 31, 2026, or until such date as future rates are approved, and are attached as the following...

AI summary The Board has approved NS Power's Annually Adjusted Rates for the period April 1, 2026, to December 31, 2026, or until future rates are approved. The approved rates include multiple tariff schedules, such as Generation Replacement, Transmission Real Time Pricing, and Extra Large Industrial Active Demand Control Tariff.

tion will be supplied either through on-going communication provision such as telemetering (when load fluctuations are involved) or written requests (where application is to a specific level of load). - (2) In the event there is an interru...

AI summary The document outlines procedures for load interruption under the Generation Replacement Service and Load Following Service, specifying customer responsibilities, penalties for non-compliance, and the process for restoring service after an interruption.

The Demand Charge is made up of two components: Demand Charge Components dollars per kW Demand Charge from Standby Service Tariff $5.452 Annually Adjusted Demand Savings Credit $0.000 Total $5.452 The Demand Charge is applicable to the LRS...

AI summary The Demand Charge consists of two components: the Demand Charge from Standby Service Tariff and the Annually Adjusted Demand Savings Credit. The charge applies to the LRS' monthly displaced demand on NS Power's system, calculated as the difference between Winter Peak Firm Demand and Monthly Standby Contract Demand under the Standby Service Tariff.

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 will exclusively serve PHP's electricity needs. It outlines load management requirements, voltage standards, and prohibits combining this tariff with others without NSEB approval.

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.

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.

The Demand Charge is made up oftwo components: Demand Charge Components dollars per kW Tariff Demand Charge from Standby Service $5,601 Annually Adjusted Demand Savings Credit $0,000 Total $5,601 The Demand Charge is applicable to the LRS'...

AI summary The Demand Charge consists of two components: the Tariff Demand Charge from Standby Service and an Annually Adjusted Demand Savings Credit. The charge applies to the LRS' monthly displaced demand on NS Power's system, calculated as the difference between Winter Peak Firm Demand and Monthly Standby Contract Demand, as outlined in the Standby Service Tariff.