N-1Application - Redacted
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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.
14 stakeholders on developing on-peak and off-peak AARs following the completion of the TVP pilot evaluation.[13](#page-9-1) 15 [emphasis added] 16 17 Subsequently, in April 2025, NS Power experienced a cybersecurity incident, which led to...
AI summary The document discusses the development of on-peak and off-peak Annual Adjusted Rates (AARs) following the completion of the TVP pilot evaluation. A cybersecurity incident in April 2025 caused delays in filing the 2024/25 TVP Evaluation Report and a temporary suspension of TVP Tariffs for 2025/26. NS Power plans to re-initiate stakeholder engagement once systems are restored and evaluations are complete.
1 3.0 LOAD FOLLOWING PORTION OF THE GRLF TARIFF 2 3 The GRLF Tariff is available to customers who have their own generation of continuous capability, 4 normally used to support the customer's own load, where the customer has signed an oper...
AI summary The GRLF Tariff provides services for customers with continuous generation capabilities, including Generation Replacement, Optional Load Following, and Spill. The GR service acts as a backup, the LF service is an energy-only charge, and Spill Service handles surplus generation. The 2026 LF rate is proposed to decrease by 2.183 cents per kWh compared to 2025.
1 Figure 2: GRLF Tariff Energy Charge in Cents per kWh 2025 2026 Variance Incremental Cost of Generation Fuel Cost 8.919 6.736 (2.183) Additional O&M costs 0.500 0.500 0.000 Energy Charge (cents per kWh) 9.419 7.236 (2.183) Application for...
AI summary The text presents a table showing the incremental cost of generation and energy charge per kWh for 2025 and 2026, highlighting a significant decrease in fuel costs and energy charges. It also mentions an application for Annually Adjusted Rates for 2026.
1 4.0 ONE PART REAL-TIME PRICING TARIFFS 2 3 Consistent with its October 15, 2025 memorandum to AAR Stakeholders (Appendix J) on NS 4 Power's Proposal for Methodological Changes to 1P-RTP Tariff, the Company proposes that 5 starting in 202...
AI summary The document discusses NS Power's proposal to implement two One Part Real-Time Pricing (1P-RTP) Tariffs starting in 2026, eliminating the avoided fuel cost adjustment. The proposal includes a Transmission RTP Tariff and a Distribution Voltage RTP Tariff, with fixed cost adders designed to recover non-fuel-related costs. The change is driven by the new Cost of Service Study (COSS) filed in the 2026-2027 GRA, which no longer separates environmental and non-environmental costs.
1 Figure 3: 1P-RTP Tariff Charges by Voltage and Cost Components in Cents per kWh 2025 2026 Variance On-Peak Off-Peak On-Peak Off-Peak On-Peak Off-Peak EHV Fixed Cost Adder 5.721 0.539 n/a n/a n/a n/a Fuel Cost Adjustment 2.704 0.253 n/a n...
AI summary Figure 3 presents the 1P-RTP Tariff Charges by voltage and cost components in cents per kWh for 2025 and 2026, including fixed cost adders and fuel cost adjustments for EHV, HV, Transmission, and Distribution. Variance between years is also shown.
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 adders, and proposed future 1P-RTP adjustments be reviewed as part of GRAs. No stakeholder 2 comments on the October 15 memorandum were received in regard to NS Power's proposed 3...
AI summary NS Power is proposing to adjust its 1P-RTP tariffs based on hourly marginal costs and non-fuel fixed costs, citing volatility in cost estimation due to emissions constraints and non-dispatchable resources. The application aligns with the 2025 AARs proceeding and suggests future tariff adjustments should be handled through General Rate Applications rather than the AAR process.
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.
Application for Annually Adjusted Rates for 2026 Redacted 1 As approved by the Board in the original proceeding to set these rates,32 the BUTU Tariff and the 2 Spill Tariff were each assigned 50 percent of the associated administration cos...
AI summary The document discusses the application for annually adjusted rates for 2026, including the use of an inflation rate to adjust administration costs and the proposed increase in customer charges. It references past Board decisions and the methodology used to calculate energy charges.
12 6.1.3 BUTU Demand Charge 8 not be provided in future applications. 14 The proposed Demand Charge of $11.704 per kilowatt (kW) of billing demand reflects a sum of 15 two components: 16 • the 2026[35](#page-25-2) 17 FAM-based component of...
AI summary The proposed BUTU Demand Charge of $11.704 per kW is composed of two components: a FAM-based component of $6.252 per kW from the 2026 Base Cost of Fuel calculations and a non-FAM-based component of $5.452 per kW from Appendix F3.
8 Figure 6: BUTU Demand Charge Components in Dollars per kW of Billing Demand 2026 Demand Charge Components Marginal Cost Based Methodology Embedded Cost Methodology Proposed Rates Demand-related Purchased Power Cost $0.000 $6.252 $6.252 D...
AI summary Figure 6 outlines the demand charge components for BUTU in 2026, comparing marginal cost-based methodology, embedded cost methodology, and proposed rates. The table highlights the costs associated with demand-related purchased power and fixed generation costs under different methodologies.
18 Figure 7: BUTU Tariff Charges 2025 2026 Variance Customer Charge ($/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.
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.
3 8.1.1 CBL Cost and CBL Energy Charge 4 - 5 As defined in Section 8.1, the CBL Energy Charge represents the average annual incremental non- - 6 capital cost (in $/MWh), net of FCR, to serve PHP's forecast load. For the 2026 Tariff year, t...
AI summary The CBL Cost and CBL Energy Charge for the 2026 Tariff year are defined and calculated, with the CBL Cost being $73.60/MWh and the CBL Energy Charge being $69.85/MWh. The FCR of $3.75/MWh is transferred to the CBLA under the ELIADC Tariff provisions. Modeling assumptions are detailed in Confidential Appendix G2.
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) CBL Cost 73.60 Minus FCR 3.75 CBL Energy Charge 69.85 Constant (CBLA) 1.25 Plus FCR transferred from CBL Cost 3.75 Total CBLA 5.00 8.1.3 Variable Capital Charge 2 The ELIADC Energy Charge includes a Var...
AI summary This section discusses the CBL Adder and Variable Capital Charge (VCC) in the context of NS Power's 2021 AAR application. The CBL Adder is calculated by subtracting FCR from CBL Cost and adding back FCR transferred from CBL Cost, resulting in a total CBLA. The VCC is part of the ELIADC Energy Charge and is used to account for the incremental generation and delivery costs of electricity for PHP.
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.
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.
GENERATION REPLACEMENT AND LOAD FOLLOWING TARIFF Page 4 of 5 Specific requirements shall be stipulated by way of a written operating agreement. - (3) In assessing issues which might unduly affect the integrity of the power supply system th...
AI summary The Generation Replacement and Load Following Tariff outlines specific requirements for service, including reliability standards, customer responsibilities for special metering, transformer losses adjustments, and power factor requirements. The Company retains control over metering locations and applies adjustments for non-compliance with power factor standards.
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 This section outlines the criteria for load following services, requiring customer-generators and the Company to establish net operating capability for billing purposes. It also mandates the Company to apply to the Nova Scotia Energy Board for approval of its forecasted incremental generation costs, which will be used in determining load following rates.
2026 AAR Application Appendix B1 Page 1 of 6 REDACTED (CONFIDENTIAL INFORMATION REMOVED) ONE PART TRANSMISSION REAL TIME PRICING TARIFF Page 1 of 3
AI summary The document is a redacted page from the 2026 Annual Application Report (AAR) Appendix B1, focusing on the One Part Transmission Real Time Pricing Tariff. It is part of a regulatory proceeding and contains confidential information that has been removed.
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.
SPECIAL CONDITIONS - (1) Projections of the anticipated hourly energy price (week ahead and day ahead) will be provided to the customer according to the following schedule: - o By midnight each business day, hourly price forecasts for each...
AI summary The document outlines special conditions for energy pricing and metering. Hourly energy price forecasts are to be provided to customers regularly, with final prices determined 20 minutes before each hour. Metering is typically at the low voltage side of the transformer, but primary metering may be required based on customer needs.
ONE PART TRANSMISSION REAL TIME PRICING TARIFF Page 2 of 3 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. - (3) The cost of any special...
AI summary The ONE PART TRANSMISSION REAL TIME PRICING TARIFF outlines requirements for customers, including capital contributions for metering, transformer loss adjustments, service terms, and power factor maintenance. Customers must maintain a minimum power factor or face billing adjustments.
2026 AAR Application Appendix B1 Page 4 of 6 REDACTED (CONFIDENTIAL INFORMATION REMOVED) ONE PART DISTRIBUTION VOLTAGE REAL TIME PRICING TARIFF Page 1 of 3
AI summary This document is a page from the 2026 AAR Application Appendix B1, which outlines a One Part Distribution Voltage Real Time Pricing Tariff. The content is partially redacted due to confidentiality, and it appears to be part of a regulatory proceeding related to electricity rates and tariff design.
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.
SPECIAL CONDITIONS - (1) Projections of the anticipated hourly energy price (week ahead and day ahead) will be provided to the customer according to the following schedule: - o By midnight each business day, hourly price forecasts for each...
AI summary The document outlines special conditions for energy pricing and metering. Hourly energy price forecasts are to be provided to customers on a regular schedule, with final prices determined 20 minutes before each hour. Metering is typically at the low voltage side of the transformer, but primary metering may be required based on customer needs.
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.
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 (8) The Company reserves the right to have a separate service agreement, if in the...
AI summary The document provides a table with power factor constants and a statement reserving the Company's right to establish separate service agreements for specific issues that may arise for the benefit of the Company and its customers.
2026 AAR Application Appendix B1 Page 6 of 6 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 ensurin...
AI summary The document outlines requirements for customers participating in a distribution voltage real-time pricing tariff, emphasizing their responsibility to maintain power system integrity through proper load management and adherence to a written operating agreement. Key considerations include reliability, harmonic levels, voltage flicker, and system stability.
REDACTED 2026 AAR Application Appendix B2 Page 1 of 19 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 1P-RTP ADDER CALCULATION Avoided Costs less: MC Revenue Fuel Cost Adj $0.18982 $0.02395 $0.16130 $0.02036 $0.02852 $0.00360 -100.0% -100.0%...
AI summary The document presents a table outlining various cost components and percentages related to the 1P-RTP Adder calculation, including avoided costs, customer costs, distribution voltage, O&M, capital, ROE, and transmission costs. The percentages indicate changes or adjustments to these costs.
REDACTED 2026 AAR Application Appendix B2 Page 6 of 19 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Approved Year 2025 Proposed Year 2026 Exclude the GRLF, LRT and Shore Power rate classes. Exclude the following rate classes: the GRLF, OATT...
AI summary The table compares average hourly KW requirements across different voltage classes for 2025 and 2026, highlighting significant variance percentages, including a 95.9% increase in EHV and a -100.0% change in HV. The GRLF, LRT, and OATT rate classes are excluded in 2026, affecting the data representation.
2026 Annually Adjusted Rates Method Used to Calculate 1P-RTP Tariffs
AI summary The document discusses the use of the 2026 annually adjusted rates method in calculating 1P-RTP tariffs, indicating a focus on rate design and the implementation of updated tariff structures.
19 Rate Design: 20 The two[1](#page-84-0) 21 rates allow customers to buy energy at a price that varies on an hourly basis. That price 22 is the sum of the marginal cost of producing the energy in that hour, plus a fixed cost adder. These...
AI summary The document discusses rate design, where customers pay hourly variable energy rates based on marginal production costs and fixed cost adders. Fixed costs are recovered during on-peak hours for generation, and during all hours for transmission, distribution, and customer costs. There is no demand charge.
34 Method Used to Calculate 1P-RTP Tariffs: 35
AI summary This section of the document discusses the method used to calculate 1P-RTP tariffs, though no detailed explanation is provided in the text snippet.
36 The Fixed Cost Adders 37 38 The fixed cost rate components are designed to recover fully embedded fixed Generation cost of 39 services. 1 Currently there are three One Part RTP Tariffs in effect: (a) two transmission-based tariffs: 1P-R...
AI summary The text discusses fixed cost rate components designed to recover embedded generation costs, referencing the current One Part RTP Tariffs and the 2026-2027 GRA (M12451) Cost of Service Study, which no longer breaks down transmission costs by EHV and HV components.
2026 AAR Application Appendix B3 Page 2 of 11 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 2026 Annually Adjusted Rates Method Used to Calculate 1P-RTP Tariffs
AI summary This document discusses the use of the 2026 Annually Adjusted Rates Method in calculating 1P-RTP Tariffs, highlighting the approach used for rate adjustments.
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 4 of 11 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 2026 Annually Adjusted Rates Method Used to Calculate 1P-RTP Tariffs
AI summary The 2026 AAR Application Appendix B3 outlines the use of the 2026 Annually Adjusted Rates Method in calculating the 1P-RTP Tariffs, indicating a regulatory process involving rate calculation and tariff design.
NON-CONFIDENTIAL 4 9 10 1 (ii) The Distribution cost amounts by service voltage level are then segregated by the 2 relative into On and off-peak category by using the relative share of time of use 3 sales. 5 (iii) The Distribution cost fix...
AI summary The text outlines the process of segregating distribution costs by service voltage level into on-peak and off-peak categories based on the relative share of time-of-use sales. Fixed cost rates for each voltage level are derived by dividing the distribution cost by on- and off-peak sales in kWh.
2026 AAR Application Appendix B3 Page 6 of 11 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 2026 On peak rates in Cents/ kWh Fig 3 rates in Cents/ kWh Variance Transmission 196,618,713 211,929,809 408,548,522 48% 52% 0% 145.32 2.11% $9,004 $...
AI summary The document presents a cost breakdown for 2026 on-peak and off-peak rates in cents per kWh, including transmission, distribution, and customer classes. It includes figures for variance, costing determinants, and apportioned amounts. The data highlights the distribution of costs across different customer classes and service levels.
ENERGY CHARGE Energy charges will vary by voltage level of the point of delivery and will be made up of two components. - (1) Annually adjusted fuel cost component which shall be the Company's forecast average annual marginal energy cost a...
AI summary Energy charges are determined based on voltage levels and consist of an annually adjusted fuel cost component, which is the Company's forecast average annual marginal energy cost, approved for use with the GR&LF tariff and adjusted for line losses at the point of delivery voltage level.
- (2) A fixed cost adder adjusted concurrent with changes in base cost rates coming into effect as a result of a General Rate Case application. Base Energy Charge Components Transmission Voltage of 69 kV or Higher (cents per kWh) Distribut...
AI summary The text describes a fixed cost adder that is adjusted in tandem with changes in base cost rates resulting from a General Rate Case application. A table provides details on base energy charge components, including fuel cost and fixed cost adder for different voltage levels.
2026 AAR Application Appendix C1 Page 3 of 4 REDACTED (CONFIDENTIAL INFORMATION REMOVED) SHORE POWER TARIFF Page 3 of 4 - metering transformers supplied by NSPI. NSPI owns and is responsible for the maintenance of meters and metering trans...
AI summary The Shore Power Tariff outlines responsibilities and requirements for the Port Authority and NSPI regarding metering, operational procedures, and billing adjustments. The Port Authority must provide trained staff and submit vessel schedules, while NSPI manages metering equipment. Customers may be required to cover additional capital costs for primary metering and special systems. Adjustments for transformer losses and power factor requirements are also specified.
2026 AAR Application Appendix C2 Page 1 of 1 REDACTED (CONFIDENTIAL INFORMATION REMOVED) SHORE POWER CALCULATION 2026 MWh Requirement Unit Revenue Unit Production Total non-demand Cost at Total at Generator's related fixed cost Generator's...
AI summary This table outlines the shore power calculation for 2026, including MWh requirements, unit fuel costs, and revenue by voltage class. It details line losses, generation, transmission, and distribution costs, as well as unit fixed costs and rates. A footnote directs readers to the 'Usage Statistics' tab in Appendix D for further information on energy requirements.
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 data on energy sales, losses, system demand, and load factors across different customer classes and voltage-based service levels.
DEMAND CHARGE The demand charge for this service is made up of the following two components: - (1) Annually adjusted demand-related purchased power cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism, or...
AI summary The demand charge for the service comprises two components, with the first being an annually adjusted demand-related purchased power cost, influenced by factors such as Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
ENERGY CHARGE The energy charge is made up of the following two components: - (1) Annually adjusted energy-related purchased power and fuel cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism or General R...
AI summary The energy charge consists of two components, one of which is annually adjusted energy-related purchased power and fuel cost, influenced by mechanisms such as the Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
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 The tariff outlines special conditions for customers supplied at high voltage levels, specifying adjustments for meter readings, separate service agreements, reliability requirements, and conditions for attributing capacity credit factor (CCF) values. These provisions ensure system integrity and address resource adequacy needs.
Proposed Annual Inflation Rate 3.25% 2025 2026 Variance COLUMN A B C D E F G H I J K L M N O P Cost Allocation Factors 3 CP Demands Energy Requirement Purchased Power- Biomass Maritime Link Purchased Po Relative Shares Relative Shares of I...
AI summary The document outlines a proposed annual inflation rate of 3.25% and presents a detailed table with cost allocation factors for various rate classes and energy-related metrics for the years 2025 and 2026, including energy requirements, fuel costs, and purchased power details.
Monthly Energy Allocators Rate Class Jan-26 Feb-26 Mar-26 Apr-26 May-26 Jun-26 Jul-26 Aug-26 Sep-26 Oct-26 Nov-26 Dec-26 Total Medium Industrial 3.27545% 3.22% 3.48% 3.94% 4.72% 5.43% 4.96% 4.66% 5.05% 4.64% 4.29% 3.38% 4.13% Large Industr...
AI summary The document presents monthly energy allocators for different rate classes in Nova Scotia, showing percentage allocations from January 2026 to December 2026. The data includes Medium Industrial, Large Industrial, PHP, and Municipal categories, with percentages varying across months.
DETERMINATION OF MONTHLY STANDBY CONTRACT DEMAND Monthly Standby Contract Demand (MSCD) in kW is determined using the following formula: $$MSCD = LWPFD - min (LWPFD, (\sum_{ii=1}^{nn} CCi GCi)/(1+PR))$$
AI summary The Monthly Standby Contract Demand (MSCD) in kW is calculated using a specific formula that involves Load Without Power Factor Demand (LWPFD), a summation of components, and a power factor (PR). This formula helps determine the standby demand for contracts.
Where: - o "k" is the number of otherwise applicable bundled service rate classes to RtR customers of an LRS. - o "CMPFDi" is hourly kW Class Monthly Peak Firm Demand of the LRS firm load in each tariff class at the time of system coincide...
AI summary The document defines technical terms related to load replacement service (LRS) and customer rate classes, including CMPFDi and CMDAFi, which are used to calculate peak firm demand and adjustment factors for different customer classes.
The Energy Charge is made up of the following components: Energy Charge Components cents per kWh Fixed Cost Adder from Energy Balancing Service Tariff 2.166 Annually Adjusted Energy Savings Credit 0.000 Annual Energy Cost Adjustment 2.198...
AI summary The Energy Charge consists of components such as the Fixed Cost Adder from the Energy Balancing Service Tariff and the Annual Energy Cost Adjustment, totaling 4.363 cents per kWh. It applies to the LRS' monthly displaced energy on NS Power's generation system, calculated as total monthly LRS load minus the top-up quantity determined under the Energy Balancing Service Tariff.
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.
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 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.
POWER FACTOR CORRECTION Under normal operating conditions, an average power factor over the entire billing period, calculated for kWh consumed and lagging kVAR-h, as recorded, of not less than 90% lagging for the total Mill load (under all...
AI summary The text outlines the requirement for maintaining a minimum power factor of 90% lagging for the total Mill load under normal operating conditions. If this requirement is not met, adjustment factors will be applied to the CBL Energy Charge.
VCC CALCULATION Description Units Value Variable capital cost impact $ $787,508 PHP load forecast-2026 GWh 774.46 VCC Rate $/MWh $1.02 2026 AAR Application Appendix H Page 1 of 37 REDACTED (CONFIDENTIAL INFORMATION REMOVED)
AI summary The document provides a table detailing the variable capital cost impact, PHP load forecast for 2026, and the VCC rate. These figures are part of an AAR application appendix, which includes confidential information that has been redacted.
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.
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 PHP required to forecast energy usage accurately. If significant changes occur, such as delays in NS Block energy import, NS Power may request a recalculation of the CBL Energy Charge with Board approval.
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.
GENERATION REPLACEMENT AND LOAD FOLLOWING TARIFF Page 4 of 5 - (3) In assessing issues which might unduly affect the integrity of the power supply system the following would be considered: reliability, harmonic voltage and current levels,...
AI summary The Generation Replacement and Load Following Tariff outlines conditions for maintaining power supply integrity, customer responsibilities for special service requirements, transformer loss adjustments, and power factor maintenance requirements to ensure system reliability and proper billing.
SPECIAL CONDITIONS - (1) Projections of the anticipated hourly energy price (week ahead and day ahead) will be provided to the customer according to the following schedule: - o By midnight each business day, hourly price forecasts for each...
AI summary The document outlines special conditions related to energy pricing projections and metering requirements. Hourly energy price forecasts are to be provided to customers on a specific schedule, and final prices are determined twenty minutes before the hour begins. Metering is typically at the low voltage side of the transformer, with exceptions based on customer requirements.
ONE PART DISTRIBUTION VOLTAGE REAL TIME PRICING TARIFF Page 2 of 3 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. - (3) The cost of any...
AI summary The document outlines the terms 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 addresses eligibility for firm service and the conditions under which customers may transition between service types.
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 ensuring that its load does not unduly deteriorate the integrity of the power supply system, b...
AI summary The tariff outlines customer responsibilities to maintain power supply integrity through load management and compliance with written operating agreements. Factors affecting system integrity, such as reliability and voltage stability, are identified for assessment.
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.
STANDBY SERVICE TARIFF Page 1 of 4 Renewable to Retail
AI summary The document introduces the Standby Service Tariff, focusing on the 'Renewable to Retail' section, which likely outlines how renewable energy sources are integrated into retail energy services.
APPLICABILITY - (1) An LRS taking service under this Standby Service Tariff shall also take service under the Open Access Transmission Tariff (OATT), the Energy Balancing Service Tariff, and the Renewable to Retail Market Transition Tariff...
AI summary This section outlines the applicability of the Standby Service Tariff, specifying that it applies in conjunction with other tariffs such as OATT and the Energy Balancing Service Tariff, and is limited to firm load only.
STANDBY SERVICE TARIFF Renewable to Retail Page 2 of 4
AI summary The document discusses the Standby Service Tariff under the Renewable to Retail program, focusing on the structure and implementation of the tariff. It outlines the terms and conditions for standby service, which is a critical component of the energy distribution framework.
Where: - "k" is the number of otherwise applicable bundled service rate classes to RtR customers of an LRS. - o "CMPFDi" is hourly kW Class Monthly Peak Firm Demand of the LRS firm load in each tariff class at the time of system coincident...
AI summary The text defines key terms related to bundled service rate classes for LRS customers, including CMPFDi and CMDAFi, and references an effective date and page number from an appendix in the 2026 AAR Application.
DEMAND CHARGE The demand charge for this service is made up of the following two components: - (1) Annually adjusted demand-related purchased power cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism, or...
AI summary The demand charge for the service consists of two components, with the first being an annually adjusted demand-related purchased power cost influenced by factors such as the Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
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, mandatory OATT service, service denial criteria, service agreements, load integrity requirements, and conditions for attributing capacity credit factor (CCF) values to wholesale customers.
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.
2026 AAR Application Appendix J Page 2 of 3 REDACTED (CONFIDENTIAL INFORMATION REMOVED) - 1. The growing complexity of the air emission market makes the continued application of the current avoided fuel cost methodology increasingly diffic...
AI summary The text discusses the challenges with the current avoided fuel cost methodology in the context of the 1P-RTP service, arguing that it leads to volatility and unreliability. It notes the shift from this methodology to a marginal fuel cost approach as directed by the Board in its 2017 decision. This change aligns the 1P-RTP tariffs with the costing approach used for other AARs, using an annual average of forecasted hourly marginal costs.
Background on 1P-RTP Tariff Design and Operation There are currently three 1P-RTP Tariffs in effect; one for each of the three voltage levels at which RTP customers may be served. The tariffs are: - 1. One Part Extra High Voltage (EHV) RTP...
AI summary The document outlines the structure of three 1P-RTP Tariffs in Nova Scotia, each corresponding to different voltage levels. These tariffs include energy charges based on hourly marginal costs and fixed cost adders that recover non-fuel related costs and adjust for fuel cost imbalances. The adders are updated annually and help stabilize overall tariff costs.
N-6NSPI (REI) RIR 1 to 20 - Redacted
44 passages
(b) Please provide the missing information required to evaluate historical forecast accuracy regarding natural gas, diesel, import purchases, and Maritime Link. Α В С D E F G H 17 to market participants, including LRSs, and better reflect...
AI summary The text requests missing information to evaluate historical forecast accuracy for natural gas, diesel, import purchases, and Maritime Link. It also asks whether NS Power agrees with monthly marginal cost pricing to better align costs with system conditions and reduce cross-subsidization.
NON-CONFIDENTIAL 1 of key system assumptions, some of which, such as quantification of monthly air emissions, 2 cannot be produced and updated in time to continuously execute monthly updates. 3 Additionally, because marginal costs are calc...
AI summary NS Power argues that monthly marginal cost updates are not practical or useful due to limitations in data availability and the design of the annually adjusted rates process. They also state that monthly marginal cost pricing would not significantly improve price signals for AAR customers.
REDACTED 50%, 75%, 125% and 150% of forecasted Surplus Energy to better understand the range of potential impacts on forecasted marginal and average costs? If not, why not? (g) Regarding the updated 2026 PHP CBL load, please confirm whethe...
AI summary The document includes a series of questions regarding the impact of various scenarios on marginal and average costs, the updated 2026 PHP CBL load, and the inclusion of new wind generation data in models. It also references a regulatory emission limit and model results for 2026. A response mentions the annual regulatory SO2 emission limit and model results.
NOVA SCOTIA POWER INC. CAPACITY BASED ANCILLARY SERVICES 2026 REVENUE REQUIREMENT AND RATE DESIGN (1) (2) (3) (4) (5) (6) (7) (8) (9) Revenue Requirement ($/kW-yr) Services Required (MW) Revenue Requirement ($000/yr) Usage (MW) Rate for Ne...
AI summary The document presents a table outlining the revenue requirement and rate design for Nova Scotia Power Inc.'s capacity-based ancillary services in 2026, including various services such as regulation, load following, and operating reserves, along with their associated costs and rates.
NOVA SCOTIA POWER INC. 2026 REACTIVE SUPPLY AND VOLTAGE CONTROL RATE DESIGN (1) Revenue Requirement ($000/yr) (2) Billing Determinants (MW) (3) Yearly ($/MW-yr) (4) Monthly ($/MW-mo) (5) Weekly ($/MW-wk) (6) On-Peak Daily ($/MW-dy) (7) Off...
AI summary The document presents a revenue requirement and billing determinants table for Nova Scotia Power Inc.'s 2026 reactive supply and voltage control rate design. It outlines various revenue and cost figures across different time intervals, including yearly, monthly, weekly, and hourly rates for on-peak and off-peak periods.
NON-CONFIDENTIAL Energy Balancing Service Tariff Charges Variance 2025 2026 Amount Percent (%) Administration Charge ($/customer/month) $401.58 $414.63 $13.05 3.25 Energy Charge (cents per kWh) - - - - Fuel Cost (cents per kWh) 8.919 6.736...
AI summary The table outlines Energy Balancing Service Tariff Charges for 2025 and 2026, showing increases in administration charges and decreases in fuel cost and fixed cost adder, leading to a reduction in total charges and energy credits.
5 8 13 17 2 The double percent digit reduction in the fuel cost components are due to the overall lower 3 cost of energy generation as provided in Figure 1: Cost of Energy Generation in the 4 evidence of the Application. 6 The reduction of...
AI summary The text discusses a 33.66% reduction in the Fixed Cost Adder, attributed to changes in the Cost of Service (COS) methodology and increased energy requirements in the above-the-line rate classes. It references the 2023 and 2026 Cost of Service Studies (COSS) and refers to an application related to the Annually Adjusted Rates for 2026 (M12551).
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to REI Information Requests 1 Request IR-16: 2 3 Reference: RtR Transition Tariff (RTT) – Annual Energy Cost Adjustment, page 35 and 4 Appendix F4, page 138. 5 6 Preamble: This porti...
AI summary The document outlines information requests related to the Annual Energy Cost Adjustment in the RtR Transition Tariff, focusing on NS Power's consideration of REI's forecasted load migration and the methodology used to calculate average and marginal fuel costs for 2026.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to REI Information Requests 1 Request IR-18: 27 bundled service to RtR, including the MW amount, customer class, load profile, and 28 timing of transition. 29 30 (b) What specific as...
AI summary The document discusses responses to information requests regarding annually adjusted rates for 2026, including assumptions about load served under RTR, firm capacity contributions from third-party generators, and the validity of savings credits under specific circumstances.
Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 8 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) from those currently in effect, with the exception of modification of the hourly imbalance service in schedule 4 to avoid doub...
AI summary The document outlines the proposed distribution tariff for 2026, specifying how distribution-connected RtR customers will be billed by NS Power and how LRSs will pass on these charges. It also notes that transmission-connected RtR customers will not be subject to the distribution tariff but will maintain a relationship with NS Power via an operating agreement.
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.
2.3 Customer Relationship with NS Power As noted below, customers connected at distribution voltage will become distribution customers. The request to switch to RtR service will trigger a change from being a Bundled Service customer to dis...
AI summary This section discusses the customer relationship with NS Power, distinguishing between distribution and transmission voltage customers. Customers connected at distribution voltage will become distribution customers, while those connected at transmission voltage will maintain a direct relationship with NS Power through an operating agreement.
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.
3.4 Full / partial service Some stakeholders provided design feedback indicating a preference that large customers should have the option to take partial RtR service from NS Power. This was understood by the Company to mean that a portion...
AI summary Stakeholders suggested that large customers should have the option to take partial Real Time Retail (RtR) service from NS Power. The concept of partial service was discussed, with two forms: unrestricted and restricted. Unrestricted partial service was excluded due to potential distortions in load shape and cost transfer to other customers.
Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 13 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) seasonal variability. Costs of such revision would need to be borne by the applicant for such type of service. And such devel...
AI summary The document discusses considerations for enabling large customers to choose a restricted partial Real Time Retail (RtR) service, but notes that no precedents exist for this at the retail level. NS Power decided not to include partial service provisions in the design framework, citing added complexity and the need to leverage existing tariffs. Full service models apply separately to each customer account.
• Secondary metering: - o Secondary metering would be installed at individual customer premises and would be used as the basis for determining charges under all RtR tariffs including charges to the LRS in respect of distribution access[7](...
AI summary The text discusses the implementation of secondary metering for determining charges under RtR tariffs, including requirements for hourly recording and remote polling by NS Power. It also outlines the role of secondary metering in B-t-M arrangements and the LRS Participation Agreement to avoid stranding of distribution costs.
3.6 Meter Ownership and Related Issues In accordance with NS Power's initial proposal, which was generally supported by stakeholders[8](#page-74-1) , NS Power will continue to own and to read the meters. In requesting RtR service, RtR cust...
AI summary NS Power proposes to retain ownership of meters and use existing cumulative energy metering to infer hourly consumption data, despite administrative complexities. Stakeholders generally support this approach, though one requested LRS meter ownership for interval meters, which is now redundant given NS Power's plans.
Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 16 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) - The use of inferred data adds two months to the settlement cycle for the relevant NS Power services to each LRS. - Existing...
AI summary NS Power proposes transitioning all RtR customers to remote polled interval metering at the start of the RtR market, citing existing infrastructure capacity and the need to upgrade meters upon service requests. Inferred data will be used to estimate load profiles for unmetered classes.
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.
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 18 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) The financial market option as presented would have left NS Power Bundled Service tariffs in place for all customers. Under t...
AI summary The document discusses the adoption of a disaggregated tariff approach for the Real Time Retail (RtR) market by NS Power, which provides greater transparency compared to other alternatives. The approach involves two categories of tariffs: the Distribution Tariff based on individual customer meter readings, and LRS tariffs based on aggregated data. The existing OATT is generally applicable, except for Schedule 4, which is replaced by Schedule 4A for RtR Market Participants.
4.2 Avoiding Negative Impacts on Other Customers The tariff design was strongly driven by the Electricity Act requirement that other remaining customers of NS Power are not to be negatively affected if some retail customers choose to purch...
AI summary The tariff design ensures that other customers of NS Power are not negatively impacted if some retail customers opt to buy renewable electricity from an LRS. This is achieved through a disaggregated tariff approach that uses the same Cost of Service model and cost allocation as the Bundled Service rate setting, ensuring NS Power bears the same aggregate risk for RtR load as for Bundled Service load.
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.
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.
Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 23 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) While option 2 foregoes the potential benefit of delivery point load forecasts, these forecasts would be onerous to produce a...
AI summary Option 2 is chosen for its simplicity, consistency, and better incentive structure despite the loss of potential benefits from delivery point load forecasts, which are deemed too burdensome and of questionable value. NS Power has proceeded with this option.
5.5.1 Overview The structure of top-up and spill services is driven largely by the cost allocation process summarised in section 5.2 above. On the basis of that discussion the proposed EBS tariff comprises: - Top-up incremental cost charge...
AI summary The proposed EBS tariff includes top-up incremental cost charges, spill incremental cost credits with annual excess spill discounts, and fixed cost rates for top-up energy allocated, based on the cost allocation process outlined in section 5.2.
5.5.2 Incremental Cost Element of Top-up and Spill Charges The incremental costs of top-up and the avoided costs for spill vary according to the demand-supply balance on the system, and the type of generation that will be capable and most...
AI summary The incremental cost element of top-up and spill charges is discussed in the context of demand-supply balance and generation efficiency. Two modes of variability—load patterns and generation patterns—are considered in the design of the EBS tariff, affecting when top-up and spill occur based on load and generation correlations.
Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 25 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) systematically when other variable generation production is high and system marginal cost is low. Given the unpredictable nat...
AI summary The document discusses the challenges of incorporating variable generation into rate structures, proposing a mid-point rate with a spread to reflect incremental costs. It suggests avoiding time-based rates due to complexity and instead using a spread between top-up and spill rates to account for variability in generation patterns.
5.5.3 Allocated Cost Element In order to recover the appropriate allocation of fixed generation costs to the production for top-up, the selected tariff structure adds the fixed generation cost allocated to energy to the incremental top-up...
AI summary The allocated cost element in the tariff structure is designed to recover fixed generation costs by adding them to the incremental top-up rate, aligning with the energy-based charge used in the Bundled Service Cost of Service analysis.
5.6 Standby Service Tariff; Design Principles Standby Service fulfills two functions: - It provides to each LRS any firm dependable capacity required (in excess of the LRS's selfsupplied firm dependable capacity) to support the share of to...
AI summary The Standby Service Tariff ensures that Local Resource Suppliers (LRS) have access to firm dependable capacity and demand-based capacity to meet system adequacy requirements. This is a mandatory obligation for LRS, unlike voluntary backup service for Wholesale Market customers. The tariff is designed to provide reliability equivalent to Bundled Service customers.
Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 27 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) The quantity of capacity that must be purchased by any LRS from NS Power should therefore be determined as follows: 1.20 x LR...
AI summary The document outlines a method for determining the capacity that LRS must purchase from NS Power, using a formula based on annual system coincident peak demand. It contrasts this with the current billing demand calculation under the Wholesale Market Backup / Top-up Service tariff and suggests a different charge determinant for the RtR Standby Service tariff to better reflect system needs.
5.7.2 Charge Determinant Details It is expected that customers can and will migrate between bundled service and RtR supply, and among LRSs, at any time of year. This presents a challenge in properly allocating costs for recovery from each...
AI summary The document discusses the allocation of costs among Local Resource Suppliers (LRS) and the challenge of accurately reflecting customer portfolios over time. A proposed method involves recalculating annual coincident demand based on monthly data to ensure fair billing for large industrial customers.
Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 28 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) - o Aggregate the class equivalent annual contributions to determine the LRS total equivalent annual peak firm demand. - The...
AI summary The document outlines the methodology for calculating the standby charge billing demand for a Local Resource Supplier (LRS) based on their firm dependable capacity contribution and total equivalent annual peak demand, factoring in a 20% reserve margin.
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.
Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 29 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) determinant that will reflect a virtual delivery point for the aggregated of each LRS's hourly load at customer meters as adj...
AI summary The document discusses the implementation of annually adjusted rates for 2026, including the replacement of Schedule 4 with Schedule 4A for each LRS, and references the application of specific OATT schedules.
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.
6.3 Relief in Respect of Generation and Load Connected in the Same Distribution Zone Consideration has been given to the transmission tariff treatment where RtR generation and load are connected to the same distribution zone, and thus behi...
AI summary The document discusses the treatment of transmission tariffs for Real Time Retail (RtR) generation and load connected to the same distribution zone. It suggests that if a generator-to-LRS-to-customer system operates entirely within a single distribution network, the LRS payment for transmission services should be calculated as the net of load minus same-zone generation.
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.
7 Tariff Design Specifics: Distribution & Retail Charges The Distribution Access Tariff provides for the recovery of costs classified in the Bundled Service Cost of Service analysis as distribution costs and as retail costs. The Distributi...
AI summary The Distribution Access Tariff is designed to recover distribution and retail costs, using the same charge determinants as the applicable Bundled Service tariff. It incorporates amended NS Power Regulations to account for the RtR market opening.
Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 32 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) - The foregone amounts under the energy-based charge for fixed generation costs under the Bundled Service tariffs, less that...
AI summary The text discusses the calculation of stranded amounts related to energy-based charges and fuel cost recovery, focusing on the impact of load supplied by LRS and the nature of generation resources. It also explains how differences in fuel costs between bundled service tariffs and RtR supply affect the RTT energy charge.
Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 33 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) fee would be based on each customer's historic load and class, using a rate that might be adjusted from time to time but with...
AI summary The text discusses the method for calculating fees based on a customer's historic load and class, with the rate potentially adjusted over time but without retroactive changes.
8.2.2 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.
NON-CONFIDENTIAL 1 Request IR-19: 2 - 3 With respect to Figure 11, page 37, please add a column to show the percentage change for - 4 each component of the RTT compared to 2025 rates. Where the change is greater than 10% - 5 for a particul...
AI summary The request asks for a column showing percentage changes in the RTT compared to 2025 rates, with explanations for changes over 10%. The response directs to a figure for the requested information.
Annually Adjusted Rates for 2026 (M12551) NSPI Responses to REI Information Requests 1 Tariff Design: Interruptible service terms must be incorporated into tariffs and 2 aligned with regulatory requirements. 3 Compliance Obligations: N...
AI summary The document outlines challenges related to tariff design, compliance obligations, cost recovery, and mitigation steps for the Annually Adjusted Rates for 2026 proceeding. NSPI acknowledges these challenges and commits to addressing them proactively while providing updates to REI.
N-14Compliance Filing - Redacted
31 passages
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.
SPECIAL CONDITIONS - (1) Projections of the anticipated hourly energy price (week ahead and day ahead) will be provided to the customer according to the following schedule: - o By midnight each business day, hourly price forecasts for each...
AI summary The special conditions outline requirements for providing hourly energy price forecasts and specify metering arrangements. Hourly price forecasts are to be provided to customers regularly, with major changes communicated promptly. The final price for each hour is determined twenty minutes before the hour begins. Metering is typically at the low voltage side of the transformer, but primary metering may be required based on customer needs.
ONE PART TRANSMISSION REAL TIME PRICING TARIFF Page 2 of 3 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. - (3) The cost of any special...
AI summary The One-Part Transmission Real-Time Pricing Tariff outlines requirements for customers, including capital contributions for metering, transformer loss adjustments, service terms, and power factor maintenance. It also addresses eligibility and conditions for transitioning between service types.
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 (8) The Company reserves the right to have a separate service agreement, if in the...
AI summary The document presents a table outlining power factor constants for different ranges, which are likely used in utility rate calculations. It also includes a statement from the Company reserving the right to establish separate service agreements for specific issues not covered in the document.
2026 AAR Compliance Filing Appendix A Page 3 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) ONE PART TRANSMISSION REAL TIME PRICING TARIFF Page 3 of 3 - (9) The customer will make all necessary arrangements and bear all costs of ensurin...
AI summary The document outlines customer responsibilities regarding load management and system integrity under the One Part Transmission Real Time Pricing Tariff. Customers must ensure their load does not negatively impact the power supply system and must comply with written operating agreements. Factors considered in assessing system integrity include reliability, harmonic levels, voltage flicker, and stability.
2026 AAR Compliance Filing Appendix A Page 4 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) ONE PART DISTRIBUTION VOLTAGE REAL TIME PRICING TARIFF Page 1 of 3
AI summary The document outlines a section of the 2026 AAR Compliance Filing, specifically Appendix A, Page 4 of 25, which has been redacted due to the inclusion of confidential information. The text references a 'One Part Distribution Voltage Real Time Pricing Tariff' on Page 1 of 3.
SPECIAL CONDITIONS - (1) Projections of the anticipated hourly energy price (week ahead and day ahead) will be provided to the customer according to the following schedule: - o By midnight each business day, hourly price forecasts for each...
AI summary The special conditions outline requirements for providing hourly energy price forecasts and specify metering arrangements. Hourly price forecasts are to be provided to customers regularly, with major changes communicated promptly. The final price for each hour is determined twenty minutes before the hour begins. Metering is typically at the low voltage side of the transformer, but primary metering may be required based on customer needs.
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.
2026 AAR Compliance Filing Appendix A 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 under the One Part Distribution Voltage Real Time Pricing Tariff, including ensuring load does not compromise power supply integrity and adherence to specific operational requirements outlined in a written agreement.
- (2) A fixed cost adder adjusted concurrent with changes in base cost rates coming into effect as a result of a General Rate Case application. Base Energy Charge Components Transmission Voltage of 69 kV or Higher (cents per kWh) Distribut...
AI summary The text outlines a fixed cost adder that is adjusted in tandem with changes in base cost rates resulting from a General Rate Case application. A table provides base energy charge components, including fuel cost and fixed cost adder at different voltage levels.
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 for customers with transformers owned by them and served at transmission voltage levels.
2026 AAR Compliance Filing Appendix A 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, including requirements for load management and specific operating agreements. Factors affecting system integrity, such as reliability and harmonic levels, are also addressed.
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 The document outlines the terms and conditions for the Wholesale Market Backup/Top-Up Service Tariff, including requirements for customer applications, service duration, and metering equipment installation. Applications must be submitted annually by specific deadlines, and service is renewable on a minimum 12-month basis or three-year forward basis under certain conditions.
ENERGY CHARGE Effective: April 1, 2026 Energy charge for top-up service is made up of the following two components: - (1) Annually adjusted fuel cost component based on NS Power's incremental cost of serving the LRS' forecasted incremental...
AI summary The energy charge for top-up service is composed of an annually adjusted fuel cost component, determined by NS Power's incremental cost of serving the LRS' forecasted incremental top-up load, effective April 1, 2026.
- (2) Fixed cost adder reflective of fixed cost energy-related generation costs. Energy Charge Components cents per kWh Fuel Cost 6.736 Fixed Cost Adder 2.155 Total 8.891 The charge is applicable to top-up energy consumed in each hour.
AI summary The text outlines a fixed cost adder of 2.155 cents per kWh, which reflects fixed cost energy-related generation costs. This adder is applied to top-up energy consumed in each hour, contributing to the total energy charge of 8.891 cents per kWh, which includes fuel cost and the fixed cost adder.
DEMAND CHARGE $5.601 per month, per kilowatt (kW) of monthly standby contract demand.
AI summary The demand charge is set at $5.601 per month per kilowatt of monthly standby contract demand.
DETERMINATION OF MONTHLY STANDBY CONTRACT DEMAND Monthly Standby Contract Demand (MSCD) in kW is determined using the following formula: $$MSCD = LWPFD - min (LWPFD, (\sum_{ii=1}^{nn} CCi GCi)/(1+PR))$$
AI summary The Monthly Standby Contract Demand (MSCD) is calculated using a formula that involves Load Without Power Factor Demand (LWPFD), Capacity Credit Factors (CCi), Generation Capacity (GCi), and a Performance Ratio (PR).
Where: • "LWPFD" is LRS Winter Peak Firm Demand in respect of each billing month calculated as follows: $$LWPFD = \sum_{i=1}^{k} (CMPFDi CMDAFi)$$
AI summary The document defines 'LWPFD' (LRS Winter Peak Firm Demand) as calculated using a formula that sums the product of CMPFDi and CMDAFi for each billing month.
Renewable to Retail Classes Jan, Feb, Dec Mar, Apr May, Jun Jul, Aug, Sep Oct, Nov Domestic 1.00 1.34 2.13 2.26 1.65 Small General 1.00 1.24 1.62 1.59 1.35 General 1.00 1.21 1.47 1.36 1.20 Large General 1.00 0.99 0.93 0.86 0.99 Small Indus...
AI summary The table presents rate classes and associated multipliers for different customer categories under the Renewable to Retail initiative. The Planning Reserve (PR) is defined as a percentage based on the Northeast Power Coordinating Council's planning criteria, currently set at 20%.
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.
COLUMN A B C D E F G H I J K L M N O P Q R S T U V X Cost Allocation Fact tors Fuel-re lated Cos ts from COS 3 CP De mands Energy Requ uirement Purchased Powe r- Biomass Maritime Link Purchased Po wer other than B Wind Biomass and ı Purcha...
AI summary The text presents a table outlining cost allocation factors and energy requirements across various rate classes and embedded cost categories, including fuel-related costs, purchased power, and energy-related and demand-related costs. It includes columns for different types of energy sources and cost allocations.
ONE PART TRANSMISSION REAL TIME PRICING TARIFF Page 2 of 3 - 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. - (3) The cost of any speci...
AI summary The document outlines the terms and conditions for the One Part Transmission Real Time Pricing Tariff, including capital contributions for metering, transformer loss adjustments, service duration, and power factor requirements. It also discusses eligibility for firm service and conditions for returning to interruptible service.
2026 AAR Compliance Filing Appendix H Page 4 of 25 REDACTED (CONFIDENTIAL INFORMATION REMOVED) ONE PART DISTRIBUTION VOLTAGE REAL TIME PRICING TARIFF Page 1 of 3
AI summary This document outlines a one-part distribution voltage real-time pricing tariff, which is part of a compliance filing for 2026. The content is redacted, indicating that confidential information has been removed.
SPECIAL CONDITIONS - (1) Projections of the anticipated hourly energy price (week ahead and day ahead) will be provided to the customer according to the following schedule: - o By midnight each business day, hourly price forecasts for each...
AI summary The special conditions outline requirements for providing hourly energy price forecasts and specify metering arrangements. Hourly price forecasts are to be provided to customers regularly, with major changes communicated promptly. The final price for each hour is determined twenty minutes before the hour begins. Metering is typically at the low voltage side of the transformer, but primary metering may be required based on customer needs.
ONE PART DISTRIBUTION VOLTAGE REAL TIME PRICING TARIFF Page 2 of 3 - 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. - (3) The cost of a...
AI summary The document outlines the terms and conditions for 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 details provisions for transitioning between service types and penalties for non-compliance with power factor standards.
ENERGY CHARGE Energy charges will vary by voltage level of the point of delivery and will be made up of two components. - (1) Annually adjusted fuel cost component which shall be the Company's forecast average annual marginal energy cost a...
AI summary Energy charges are determined by voltage level and consist of an annually adjusted fuel cost component, which is based on the Company's forecast average annual marginal energy cost, approved for use with the GR&LF tariff and adjusted for line losses at the voltage level of the point of delivery.
DEMAND CHARGE The demand charge for this service is made up of the following two components: - (1) Annually adjusted demand-related purchased power cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism, or...
AI summary The demand charge for the service consists of two components, one being an annually adjusted demand-related purchased power cost, which is influenced by factors such as the Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
ENERGY CHARGE The energy charge is made up of the following two components: - (1) Annually adjusted energy-related purchased power and fuel cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism or General R...
AI summary The energy charge consists of two components, one of which is annually adjusted energy-related purchased power and fuel cost, influenced by factors such as the Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
ENERGY CHARGE Effective: April 1, 2026 Energy charge for top-up service is made up of the following two components: - (1) Annually adjusted fuel cost component based on NS Power's incremental cost of serving the LRS' forecasted incremental...
AI summary The energy charge for top-up service, effective April 1, 2026, consists of an annually adjusted fuel cost component based on NS Power's incremental cost of serving the LRS' forecasted incremental top-up load.
DETERMINATION OF MONTHLY STANDBY CONTRACT DEMAND Monthly Standby Contract Demand (MSCD) in kW is determined using the following formula: $$MSCD = LWPFD - min (LWPFD, (\sum_{ii=1}^{nn} CCi GCi)/(1+PR))$$
AI summary The Monthly Standby Contract Demand (MSCD) is calculated using a formula that involves Load Without Power Factor Demand (LWPFD), Capacity Credit Factors (CCi), Generation Capacity (GCi), and a Performance Ratio (PR).
Where: - o "k" is the number of otherwise applicable bundled service rate classes to RtR customers of an LRS. - o "CMPFDi" is hourly kW Class Monthly Peak Firm Demand of the LRS firm load in each tariff class at the time of system coincide...
AI summary The text defines key terms used in the regulatory proceeding, including 'k', 'CMPFDi', and 'CMDAFi', which are related to bundled service rate classes, peak firm demand, and demand adjustment factors for load serving resources.
101197Board Order
19 passages
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.
, a Threshold Penalty and a Performance Penalty. The Threshold Penalty charge shall be the cost of the appropriate firm billing effective at that time for the consumption used in that billing period. The Performance Penalty which is based...
AI summary The text outlines penalty charges for customers during an interruption event, including a Threshold Penalty based on firm billing costs and a Performance Penalty calculated using a formula involving residual demand and average demand. It also mandates the installation of approved metering equipment by customers to monitor generation output.
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 document outlines special conditions for service agreements, including the company's right to establish separate agreements, customer responsibilities for maintaining power system integrity, and specific requirements related to metering, transformer losses, and power factor adjustments.
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.
DEMAND CHARGE The demand charge for this service is made up of the following two components: - (1) Annually adjusted demand-related purchased power cost, coming into effect as a result of a Base Cost of Fuel, Fuel Adjustment Mechanism, or...
AI summary The demand charge for the service comprises two components, with the first being an annually adjusted demand-related purchased power cost influenced by factors such as the Base Cost of Fuel, Fuel Adjustment Mechanism, or General Rate Application.
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, incorporating variables such as Planning Reserve (PR), Contract Demand (CD), and Capacity Contribution Factor (CCF). It distinguishes between non-dispatchable and dispatchable generation, referencing specific supplier capacities and NSPI's planning studies.
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.
ENERGY CREDIT Compensation for spill energy delivered to NSPI will be at the Company's forecast average annual marginal energy costs of 6.736 cents per kilowatt hour as approved for use with the GRLF rate.
AI summary The Energy Credit section outlines that compensation for spill energy delivered to NSPI will be based on the Company's forecast average annual marginal energy costs of 6.736 cents per kilowatt hour, as approved for use with the GRLF rate.
ENERGY CHARGE Energy charge for top-up service is made up of the following two components: - (1) Annually adjusted fuel cost component based on NS Power's incremental cost of serving the LRS' forecasted incremental top-up load.
AI summary The energy charge for top-up service consists of an annually adjusted fuel cost component based on NS Power's incremental cost of serving the LRS' forecasted incremental top-up load.
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).
Where: - o "k" is the number of otherwise applicable bundled service rate classes to RtR customers of an LRS. - o "CMPFDi" is hourly kW Class Monthly Peak Firm Demand of the LRS firm load in each tariff class at the time of system coincide...
AI summary The text defines several terms related to the calculation of bundled service rate classes and demand factors for LRS customers, including definitions for 'k', 'CMPFDi', and 'CMDAFi', with specific considerations for unmetered customer classes.
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.
The Energy Charge is made up of the following components: Energy Charge Components cents per kWh Fixed Cost Adder from Energy Balancing Service Tariff 2.166 Annually Adjusted Energy Savings Credit 0.000 Annual Energy Cost Adjustment 2.198...
AI summary The Energy Charge comprises fixed cost adders, energy savings credits, and annual adjustments, totaling 4.363 cents per kWh. It applies to the Load Serving Retailer's monthly displaced energy on NS Power's generation system, calculated after accounting for distribution losses and top-up quantities.
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.
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.
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.
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 adjust the CBL Energy Charge based on significant changes in circumstances, such as delays in energy imports or unexpected changes in generation costs or consumption. These adjustments require Board approval and do not affect the Minimum Payment by PHP.
POWER FACTOR CORRECTION Under normal operating conditions, an average power factor over the entire billing period, calculated for kWh consumed and lagging kVAR-h, as recorded, of not less than 90% lagging for the total Mill load (under all...
AI summary The document outlines a power factor correction requirement, mandating a minimum average power factor of 90% lagging for the total Mill load under normal operating conditions. If this requirement is not met, adjustment factors will be applied to the CBL Energy Charge.
101197Board Order
23 passages
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.
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: Generation Replacement Service, Optional Load Following Service, and Spill Service. It specifies how power is delivered to partial requirement customers with their own generation equipment. Customers taking this service are referred to as 'customergenerators.'
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 document outlines special conditions for service agreements, specifying that customers must ensure their load does not negatively impact the power supply system. It also addresses transformer losses, power factor requirements, and the financial responsibility for special metering and communication systems.
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): 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, with weekend and holiday rates aligned to off-peak. Annual approval from the Nova Scotia Energy Board is required, and a credit is applied for customer-owned transformers based on peak demand.
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 (8) The Company reserves the right to have a separate service agreement, if in the...
AI summary The document provides a table showing power factor constants for different ranges and states that the Company may establish separate service agreements for issues not covered in the current document for the benefit of the Company and its customers.
- (2) A fixed cost adder adjusted concurrent with changes in base cost rates coming into effect as a result of a General Rate Case application. Base Energy Charge Components Transmission Voltage of 69 kV or Higher (cents per kWh) Distribut...
AI summary This section describes a fixed cost adder that is adjusted in line with changes in base cost rates resulting from a General Rate Case application. The table provides breakdowns of base energy charges, including fuel cost and fixed cost adder components for different voltage levels.
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.
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 used to calculate billing demand for customers, incorporating factors such as planning reserve, customer contract demand, and the capacity contribution factor of a third-party supplier's generation. This calculation is based on whether the generation is dispatchable or non-dispatchable.
ENERGY CREDIT Compensation for spill energy delivered to NSPI will be at the Company's forecast average annual marginal energy costs of 6.736 cents per kilowatt hour as approved for use with the GRLF rate.
AI summary The document specifies that compensation for spill energy delivered to NSPI will be based on the Company's forecast average annual marginal energy costs of 6.736 cents per kilowatt hour, as approved for use with the GRLF rate.
ENERGY CHARGE Energy charge for top-up service is made up of the following two components: - (1) Annually adjusted fuel cost component based on NS Power's incremental cost of serving the LRS' forecasted incremental top-up load.
AI summary The energy charge for top-up service consists of an annually adjusted fuel cost component based on NS Power's incremental cost of serving the LRS' forecasted incremental top-up load.
- (2) Fixed cost adder reflective of fixed cost energy-related generation costs. Energy Charge Components cents per kWh Fuel Cost 6.736 Fixed Cost Adder 2.166 Total 8.902 The charge is applicable to top-up energy consumed in each hour.
AI summary The document outlines a fixed cost adder of 2.166 cents per kWh, applicable to top-up energy consumed hourly, as part of energy charge components that include fuel cost and total charges.
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 involves Load Replacement Service (LRS) and Capacity Credit Factor (CCF) values, adjusted by a factor related to the Capacity Credit Factor (PR).
Where: - o "k" is the number of otherwise applicable bundled service rate classes to RtR customers of an LRS. - o "CMPFDi" is hourly kW Class Monthly Peak Firm Demand of the LRS firm load in each tariff class at the time of system coincide...
AI summary The text defines key variables used in determining rates for LRS customers, including 'k', 'CMPFDi', and 'CMDAFi', which are used to calculate monthly peak firm demand and demand adjustment factors for different customer classes.
Classes Jan, Feb, Dec Mar, Apr May, Jun Jul, Aug, Sep Oct, Nov Domestic 1.00 1.34 2.13 2.26 1.65 Small General 1.00 1.24 1.62 1.59 1.35 General 1.00 1.21 1.47 1.36 1.20 Large General 1.00 0.99 0.93 0.86 0.99 Small Industrial 1.00 1.25 1.23...
AI summary The text presents a table showing different rate classes and their corresponding multipliers for various months. The table includes Domestic, General, Industrial, and Unmetered classes, with multipliers varying by month. The term 'PR' is defined as Planning Reserve based on Northeast Power Coordinating Council criteria.
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.
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, an adder for reducing service costs for other customers, and a credit for system savings from Active Demand Control. The tariff includes components like CBL Cost, CBL Energy Charge, and a credit to incentivize PHP's participation in demand control.
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.
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.
POWER FACTOR CORRECTION Under normal operating conditions, an average power factor over the entire billing period, calculated for kWh consumed and lagging kVAR-h, as recorded, of not less than 90% lagging for the total Mill load (under all...
AI summary The document outlines power factor correction requirements, specifying that a minimum average power factor of 90% lagging must be maintained over the billing period. If this is not met, adjustment factors will be applied to the CBL Energy Charge.
Effective: April 1, 2026 Metering will normally be at the low voltage side of the transformer and, for measurement and, where applicable, billing purposes, meter readings will be increased by 1.1%. Should the Mill's requirements make it ne...
AI summary The document outlines metering requirements under the tariff, specifying that metering is typically at the low voltage side of the transformer. If primary metering is required by the Mill, PHP must cover the additional cost as a capital contribution. Any special metering or communication systems required by PHP must also be funded by PHP as a capital contribution.