Topic:"Distribution" in M12451

3) Chemical 4) Civil Structures 5) Combustion Turbines 6) Dam Structures 7) Distribution 8) Electrical 9) Heat Exchangers 10) Hydro Mechanical 11) Instrumentation & Controls 12) Ash Residue 13) Rotating Equipment 14) Turbines & Generators...

AI summary The text lists various categories and systems relevant to infrastructure and energy operations, including chemical, civil structures, combustion turbines, distribution, electrical systems, hydro, mechanical, instrumentation, and others related to power generation and transmission.

Whenever the index reaches Extreme in NS: - All cross-country (distribution & transmission) operations will be shut down until such a time as the index drops to a maximum of Very High .

AI summary When the index reaches 'Extreme' in Nova Scotia, all cross-country distribution and transmission operations will be shut down until the index decreases to 'Very High'.

Transmission, Distribution, and General Plant accounts. The historical net salvage data for the years 1976 through 1992 were available only in total for the function and though not considered as the statistical basis for the net salvage es...

AI summary The document discusses net salvage estimates for transmission, distribution, and production plant accounts, based on historical data, management plans, and studies conducted by Stantec and Hatch. The estimates for hydro and steam plants are derived from site-specific decommissioning studies.

59 1 include above included above include above included above 164,385 included above MERSEY Cowie Falls Penstock Unit 1 N include above included above include above included above included above MERSEY Cowie Falls Penstock Unit 2 N includ...

AI summary The text presents data related to infrastructure elements, including Cowie Falls Penstock Units and Jordan Lake Main Outlet Weir, with details on storage capacity, dimensions, and associated costs. The information includes figures such as 295.3 and 301,890, along with some unspecified values marked as 'unknown'.

nd Controls - General 441 Turbine Generator Automatic Run-up and Loading (when separate) 500's ELECTRICAL: 50 & 51 ON SITE DISTRIBUTION LINES REMOVALS 504 Supporting Structures 505 Framing and Hardware 506 Primary and Secondary Overhead Co...

AI summary The document outlines various technical and infrastructure-related items under the 'nd Controls - General' and 'ELECTRICAL' sections, including turbine generator operations, distribution line removals, and components such as conductors, transformers, and metering. It references a redacted document and a page number from a larger report.

4,354 441 Turbine Generator Automatic Run-uP and Loadina /when seParatel 500'5 ELECTRICAL: 50 & 51 ON SITE DISTRIBUTION LINES REMOVALS 504 Sunnnrtina Structures line221 505 Framina and Hardware line221 506 Primary and Secondary Overhead Co...

AI summary The text outlines various electrical infrastructure components and tasks related to turbine generator operations, including distribution line removals, structural support, conductors, and transformers. Specific items such as overhead and underground conductors, conduit, and metering are listed with line numbers and notes on scope.

LOCATION: MARINE TERMINAL POINT TUPPER DATE: 15-Jul-24 Account Estimated Cost: Item Description Assumptions/ Notes:2024 Code July 2024 SOO's ELECTRICAL: 50&51 ON SllE DISlRIBUTION LINES REMOVALS 504 Supporting Structures 505 Framing and Ha...

AI summary The document outlines the estimated costs for the removal of electrical infrastructure at the Marine Terminal Point Tupper location, including distribution lines, power systems, and associated components such as transformers and conduits.

ator Automatic Run-up and Loading (when separate) 500's ELECTRICAL: 50&51 ON SITE DISTRIBUTION LINES REMOVALS NA 504 Supporting Structures 505 Framing and Hardware 506 Primary and Secondary Overhead Conductor 507 Line Protection Equipment...

AI summary The text outlines various electrical infrastructure removal tasks, including distribution lines, supporting structures, conductors, and transformers, with specific reference to the removal of electrical power systems at a cost of 104,550.

up and Loading (Men separate) SOO's ELECTRICAL: 50 &51 ON SITE DISTRIBUTION LINES REMOVALS 35,000 43,050 504 Supporting Structures 505 Framing and Hardware 506 Primary and Secondary Overhead Conductor 507 Line Protection Equipment 508 Unde...

AI summary The text lists various electrical components and systems related to the removal of infrastructure, including distribution lines, supporting structures, conductors, transformers, and power systems, with associated costs provided.

ptions/ Notes:2024 Code SOO's ELECTRICAL: 50&51 ON SITE DISTRIBUTION LINES REMOVALS 153,856 504 Utility poles and cross arms 101,788 Approximately 7.8 km of overhead lines, 200 poles. Cost is for decommissioning and removal of substation e...

AI summary The text outlines the costs associated with the removal of electrical infrastructure, including utility poles, overhead conductors, and substation equipment, as part of a site-specific project. It provides details on the types of equipment being removed and assumptions about what remains in place.

ully assembled / special road restrictions) 500'• ELECTRICAL: 500'• ON SITE DISTRIBUllON LINES REMOVALS 229,314 504 Utilitv nnles and cross arms 152 682 AooroximatelV 12 km of overhead lines 300 ooles. Cost is for decommissionin□ and remov...

AI summary The text outlines the costs associated with the removal of electrical infrastructure, including overhead lines, transformers, and substation equipment, with specific line items detailing labor and equipment expenses for various components of the project.

each - not able to shio fullv assembled / soecial road restrictions\ 500's ON SITE POWER & DISTRIBUTION LINES REMOVALS 273,985 504 Utility poles and cross arms 178,129 Approximately 15.3 km of overhead lines, 350 poles. 506 Primary and Sec...

AI summary The text outlines the costs associated with the removal of utility poles, overhead conductors, and other infrastructure, including the length of lines and number of poles. It also notes that underground cables, conduit, and ductbanks are assumed to remain in place.

ENERGY STORAGE EQUIPMENT - DISTRIBUTED SOLAR 25 - S3 0 1,123,202 64,625 1,058,577 48,536 4.32 21.8 ENERGY STORAGE EQUIPMENT - BATTERIES 10 - S3 0 1,261,438 201,460 1,059,978 141,434 11.21 7.5 POLES, TOWERS AND FIXTURES 43 - R2 (35) 646,990...

AI summary The document presents a detailed breakdown of various energy storage and infrastructure-related costs, including distributed solar, batteries, poles, towers, conductors, and meters. It includes financial figures such as costs, revenues, and percentages for each category, providing a comprehensive overview of expenditures and returns.

Why do this project? As a result of the additional generation associated with the Maritime Link Project, a system impact study noted the potential for system voltage collapse based on the current configuration of the 67N-Onslow Substation...

AI summary The Maritime Link Project necessitated a system impact study due to potential voltage collapse risks at the 67N-Onslow Substation. To mitigate this, Breaker 67N-812 was replaced with Breaker 67N-816, and the nodes for Line L8003 and Transformer 67N-T82 were swapped.

Cost of Service Study Redacted 1 7.0 LINE LOSS STUDY 29 calculated directly for all 174 distribution networks, using a 2023 peak load model. A sensitivity 30 analysis was performed to determine the impact of incremental changes of coincide...

AI summary The document discusses the calculation of line loss in distribution networks, including a sensitivity analysis and the use of industry-standard formulas. A loss factor of 31.6 percent was determined and validated through CYME simulations. Secondary losses were modeled using typical secondary models by customer type and service configuration.

CONFIDENTIAL 1 COSS Model Run #3, Transmission Classified as 100% Demand: 2 The classification of a portion of Transmission as Energy is removed so all rate base and costs are 3 classified as 100% Demand. The sections of the COSS that allo...

AI summary The document outlines various COSS model runs that adjust the classification and allocation of costs related to transmission, grid-scale storage, and distribution. These changes include reclassifying transmission as 100% demand, separating PHP as a class, and adjusting allocators for EHV and HV subfunctions.

CONFIDENTIAL 1 from Ellershouse and top-up energy under the BUTU Tariff. Antigonish and Riverport loads (again 2 net of Ellershouse) is included in distribution primary. 3 4 COSS Model Run #12a, Basic Customer Method (all Demand): 5 Distri...

AI summary The text discusses changes in the COSS model runs related to distribution cost classifications and updated fuel costs. In Model Run #12a, distribution costs are reclassified between demand and customer, with specific adjustments for secondary pole and transformer costs. Model Run #12b further adjusts classifications based on the distribution system load factor. Model Runs #14a and #14b incorporate updated fuel costs from the 2023-2024 GRA proceeding, with adjustments made to reflect original forecast volumes.

2026-2027 GRA Direct Evidence Appendix 12A(1) Page 32 of 46 REDACTED (CONFIDENTIAL INFORMATION REMOVED) CONCENTRIC EVIDENCE: GRA COSS ELEMENTS - the system. The minimum system cost represents the customer-related costs, whereas the total c...

AI summary The text discusses two methods for allocating distribution costs: the Zero Intercept Study and the Minimum Size Selection. The Zero Intercept Study uses regression analysis to estimate customer-related costs, but it is criticized for potential statistical unreliability. The Minimum Size Selection method involves selecting the smallest currently installed assets for cost allocation. These methods are outlined in the NARUC Manual.

COSS CA DR-9 Attachment 1 Page 293 of 627 Start Time End Time ANL_MW 5/1/2021 17:00 5/1/2021 18:00 857.7 5/1/2021 18:00 5/1/2021 19:00 850.8 5/1/2021 19:00 5/1/2021 20:00 906.1 5/1/2021 20:00 5/1/2021 21:00 973.8 5/1/2021 21:00 5/1/2021 22...

AI summary The document provides a table with timestamps and corresponding ANL_MW values, likely representing energy demand or generation data over a specific period in May 2021. The data shows fluctuations in power levels throughout the day, indicating potential variations in energy consumption or production.

Cost of Service Study Process (NSUARB M11475) NSPI Responses to CA Data Requests 1 Request DR-16: 2 3 Please explain how NS Power's substation plant is functionalized between EHV, HV, and 4 distribution, including addressing the following...

AI summary NSPI explains how NS Power's substation plant is functionalized across different voltage levels, including EHV, HV, and distribution. The response categorizes substations into five groups based on their function and voltage levels, such as generation, transmission, hybrid, bulk power, and distribution substations.

NON-CONFIDENTIAL 1 2 (b) NS Power uses either hybrid or bulk power substations to step power down from a primary 3 transmission voltage of either 138 kV or 69 kV to a secondary distribution voltage of 25 4 kV, 12.5 kV or 4.2 kV. NS Power a...

AI summary The document describes the use of hybrid and bulk power substations by NS Power to step down voltage from 138 kV or 69 kV to lower distribution voltages. It also mentions the use of delta tertiary windings in some substations for contingency power supply and the lack of explicit sub-functionalization of substations in the COSS, with a 3:1 investment ratio between EHV and HV levels.

COSS CA DR-27 Attachment 1 Page 2 of 9 Name Section Title C-ED-14M.pdf Section C - Conductors, Sags and Te Hot Line Top Tie on Two Insulators for Existing Double Arm Poles and Double Circuit Poles Only C-ED-15M.pdf Section C - Conductors,...

AI summary The document lists various technical specifications and guidelines related to electrical infrastructure, including conductor configurations, fuse selection charts, and grounding details for distribution lines. These documents are organized by section and title, focusing on specific components and procedures.

COSS CA DR-27 Attachment 1 Page 4 of 9 Name P-ED-10M Section Section P - Poles and Settings Title Pole Marking Details R-ED-37M.pdf Section R - Framing 30 Distribution (RPhase Transition on Tangent Line R-ED-38M.pdf Section R - Framing 30...

AI summary This document outlines various technical specifications and details related to utility infrastructure, including pole marking, distribution framing, and substation duct termination for underground feeders. It includes multiple sections and documents related to different aspects of electrical distribution and substation design.

COSS CA DR-27 Attachment 1 Page 5 of 9 Name Section Title SL-ED-11M.pdf Section SL - Street Lighting LED Streetlight Installation Between Secondary and Communication Attachment SL-ED-12M.pdf Section SL - Street Lighting Street Lighting wit...

AI summary This document lists various technical specifications and installation guidelines for street lighting and related infrastructure, including LED streetlights, floodlights, and festive lighting, under Section SL of the Nova Scotia Power Inc. distribution system.

COSS CA DR-27 Attachment 1 Page 8 of 9 Name Section Title V-ED-14M.pdf Section V - Voltages and Clearances CLEARANCES TO ABOVE GROUND PROPANE OR NATURAL GAS EQUIPMENT V-ED-15M.pdf Section V - Voltages and Clearances Service Conductor Clear...

AI summary This document lists various technical specifications and installation guidelines for electrical equipment, including clearances, capacitor banks, reclosers, and regulators, relevant to distribution systems in Nova Scotia.

COSS CA DR-27 Attachment 1 Page 9 of 9 Name Section Title 4 class, differentiating among (1) customer-classified distribution costs (poles and conductors), 5 (2) customer-classified line transformers, and (3) other customer-classified cost...

AI summary The document requests detailed information on customer-classified distribution costs, including line transformers, hookups, and meter-related expenses, by customer class and year, with specific attention to residential classifications and cost classification accuracy.

NON-CONFIDENTIAL 1 Response DR-28: 2 3 For a breakdown of NS Power's proposal for costs classified as customer, for each class, please refer to the following sections of the 2023 COSS. 1 4 5 6 1. Customer-classified distribution costs 7 a....

AI summary NS Power provides details on how customer-classified distribution costs are broken down in the 2023 COSS, including operating expenses, depreciation expenses, and transformer services. Information on transformer services by rate class is not available, but aggregate data by market segment is provided.

COSS CA DR-39 Attachment 1 Page 1 of 2 Transformer Sub ID Sub Name Region 2016 Peak (MW) 2017 Peak (MW) 2018 Peak (MW) 2019 Peak (MW) 2020 Peak (MW) 2021 Peak (MW) 2022 Peak (MW) 2023 Peak (MW) 1H-T61 1H WATER STREET Halifax 18.89 20.89 16...

AI summary The document presents a table with transformer data, including peak load values for various transformers in Halifax over the years 2016 to 2023. The table includes details such as transformer IDs, substation names, regions, and peak load values for each year.

COSS CA DR-39 Attachment 1 Page 2 of 2 Transformer Sub ID Sub Name Region 2016 Peak (MW) 2017 Peak (MW) 2018 Peak (MW) 2019 Peak (MW) 2020 Peak (MW) 2021 Peak (MW) 2022 Peak (MW) 2023 Peak (MW) 11S-T52 11S KELTIC DRIVE Sydney - 9.42 - 11.7...

AI summary The document presents a table of transformer peak load data across various substations in Sydney and Valley regions from 2016 to 2023, showing fluctuating peak load values over time.

COSS CA DR-40 Attachment 1 Page 1 of 6 Feeder 100C-421 Canso Region 1.47 1.45 1.82 955 963 989 2021 Peak Load (MW) 2022 Peak Load (MW) 2023 Peak Load (MW) 2021 Customer Count 2022 Customers 2023 Customers 2023 Residential Customers 931 202...

AI summary The document presents a table with data on various feeders in Nova Scotia, including peak load (in MW), customer counts, and lengths (in meters) for different years. The data spans multiple regions and years, providing a detailed overview of distribution system metrics.

PARTIALLY CONFIDENTIAL 2026-2027 GRA Direct Evidence Appendix 12A(2) Page 800 of 1218 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 2022-2024 GRA SR-01 Attachment 1a Page 10 of 12 COSS CA DR-53 Attachment 1 Page 10 of 62 Nova Scotia Power Co...

AI summary The document outlines the methodology for the Nova Scotia Power Cost of Service Study, including the classification and allocation of expenses into demand, energy, and customer categories. It details how various costs, such as distribution, service, and communication expenses, are allocated based on factors like rate base, meter investment, and customer numbers.

Description of the MSS - Distribution system costs are incurred to move electricity from generation and transmission facilities - to individual customers that are distributed geographically throughout the service territory of a - utility....

AI summary The document describes the Methodology for System Studies (MSS) used to allocate distribution system costs between demand-related and customer-related components. It explains that distribution costs are influenced by both the number of customers and peak demand, and that the NARUC Manual outlines two methods for this allocation: the Minimum Size Method and the Minimum-Intercept Method. Concentric used the Minimum Size Method in its analysis.

Structures and Improvements Poles, Towers and Fixtures Overhead Conductors and Devices Underground Conduit Underground Conductors and Devices Line Transformers 16 Evidence of CA, at 65. 17 Evidence of CA, at 59.

AI summary The text references evidence from page 65 and 59 of CA's submission, discussing structures, improvements, and technical components related to power distribution systems, including poles, towers, conductors, and transformers.

CONCENTRIC EVIDENCE: GRA COSS ELEMENTS 1 2 3 NSPI uses the "minimum-size method" to classify the customer costs. This method of defining customer costs was approved by the Board in 1977 as an acceptable method of classifying distribution p...

AI summary The document discusses NSPI's use of the 'minimum-size method' to classify customer costs, approved by the Board in 1977. It outlines conclusions regarding the Minimum System Study (MSS), emphasizing that costs are customer-related rather than demand-related and that the NARUC Manual remains a standard industry practice.

1 Request DR-62: 2 3 If NS Power's minimum system method study model relies upon on a survey of selected 4 representative feeder sections to gather information regarding poles, conductors, and other 5 relevant materials contained within ea...

AI summary The document requests detailed information from NS Power regarding its minimum system method study model, specifically focusing on selected feeder sections, their characteristics, and cost and infrastructure details. The request includes data on replacement costs, pole heights, conductor types, and communication equipment.

NON-CONFIDENTIAL 1 Request DR-4: 2 3 How are the costs of primary vs secondary distribution classified, to demand or energy? 4 5 Response DR-4: 6 7 Please refer to page 3 of Exh 5 of 2023 COSS1 for the distribution cost classification resu...

AI summary The response to DR-4 explains that NS Power classifies distribution costs exclusively to demand, customer, or both, but not by primary vs. secondary voltage levels. Classification factors are based on investment in poles and wires, and specific percentages are provided for OM&G costs.

Functionalization - > Approach very standardized in the electricity industry - > NS Power's functions are consistent with industry standard definitions - ➤ Main functions include generation, transmission, distribution and retail - > Costs...

AI summary The document discusses the functionalization approach used by NS Power in the electricity industry, aligning with standard definitions. It outlines main functions such as generation, transmission, distribution, and retail, and explains that costs are assigned to these functions based on the utility's system of accounts. Some allocation between functions is required, such as between transmission and distribution substation costs.

Illustrative List of Sub-Functions 1. Generation 2. Transmission 3. Distribution 4. Retail Steam High Voltage Land Customer Experience and Solutions Hydro Extra High Voltage Easements & Survey Call Centre Wind Other Billing Services & Paym...

AI summary The document presents an illustrative list of sub-functions organized into four main categories: Generation, Transmission, Distribution, and Retail. Each category includes a range of activities and services related to energy and utility operations in Nova Scotia.

System Design by Component - Generation (54% RB, 76% Rev) - 2,336,000 kilowatts Firm Capacity - $2.8B RB, $0.5B FX cost, $0.8B Fuel & Purchased Power - Transmission (19% RB, 8% Rev) - 69 to 345 kV lines, 5175 kilometers - $1.0B RB 19%, $0....

AI summary The document outlines the system design by component, detailing generation, transmission, distribution, and retail segments with their respective rate base (RB) and revenue (Rev) percentages, along with costs and capacities. It provides a breakdown of infrastructure and services for each component.

Minimum System Study Methodology - The Minimum System Study methodology compares the cost of a hypothetical minimum system to the total cost of the distribution system. The cost of the hypothetical minimum system is classified as customer-...

AI summary The Minimum System Study methodology evaluates the cost difference between a hypothetical minimum distribution system and the actual system, classifying costs as either customer-related or demand-related. This approach is used by SaskPower, Hydro Quebec, and NL Power, and similar analyses are used by NB Power and Ontario distributors.

Summary Methodology Arguments in Favour Arguments Against Minimum System Method • A significant portion of distribution system costs are incurred to reach customers, regardless of peak demands. • Aligned with the concept that the distribut...

AI summary The text discusses different methodologies for calculating distribution system costs, including the Minimum System Method, Zero-Intercept Method, and Basic Customer Method. Each method has arguments in favor and against, with considerations related to how costs are attributed to customer demand and energy usage.

Deep dive into NSPI data for - Transmission digital twin PSSe model and 8760 data - Distribution digital twin CYME model and 8760 AMI & MV90 data - Secondary services information within GIS - Customers configuration data

AI summary This section outlines data elements related to NSPI's transmission and distribution systems, including digital twin models, AMI data, GIS information, and customer configuration data.

Activities by NSPI - Testing Distribution Transformer and Secondary Services - Sample configurations - Load and No-Load Losses - Exploring Enhanced Modelling Software - CYME Low Voltage Secondary Network (LVSN) Module - CYME Steady State A...

AI summary NSPI is conducting activities related to testing distribution transformers and secondary services, as well as exploring enhanced modelling software like CYME modules for low voltage secondary networks and steady state analysis. Next steps involve BBA.

Distribution Losses The primary distribution losses were estimated using distribution network simulations in CYME software, combined with : - Load data from AMI (8760) and MV90 meters - Peak–based loss modeling - Transformer load loss eval...

AI summary The primary distribution losses were estimated using CYME software simulations, incorporating load data from AMI and MV90 meters, peak-based loss modeling, transformer load loss evaluation, and a loss factor calculated using a formula based on the 2023 load factor of 52.8%.

Methodology Demand Line Loss

AI summary The document discusses the methodology related to Demand Line Loss, focusing on the analysis and measurement of losses in the electricity distribution system due to demand factors.

2026-2027 GRA Direct Evidence Appendix 12A(5) 1 Page 13 of 31 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Status Quo CTD Referen ce NS Power Position (Pre Resolution Session) NS Power Updated Position (Following Resolution Session) Justifi...

AI summary The document outlines the status quo and positions taken by NS Power regarding the functionalization of interconnections and bulk power substations, with no changes in position following the resolution session. The table highlights key issues and justifications.

P977 IT - Work and Asset 55,225,663.60 Management C0021442 AMI Network Assets 2 30,481,370.92 C0026426 - IT-Customer Energy 6,649,483.97 Management P880 Work & Asset 5,618,091.81 Management In the current COS, these assets were included in...

AI summary The document discusses the classification and functionalization of IT - Work and Asset management assets within the current COS, emphasizing their role in supporting the Distribution function of the business and the criteria for direct functionalization to this area.

4 Table 2 – Summary of NS Power Proposed Methodology Status Quo Change Generation • Allocation except for treatment of purchased power • No initial classification to energy for environmental and fuel conversion reasons • Use system load fa...

AI summary NS Power proposes changes to its methodology for classifying and allocating costs related to generation, transmission, and distribution. Key changes include refunctionalizing radial-to-generation, using system load factors for classification, and creating new storage sub-functions. These changes aim to improve cost allocation and align with updated regulatory practices.

4.2.3.1 NSP CURRENT APPROACH - As explained in section [4.1.3.1,](#page-77-1) NS Power's radial-to-generation costs are currently - included within its general transmission functions. The EHV and HV sub-functions were - classified by the s...

AI summary NS Power's radial-to-generation costs are currently included within its general transmission functions, with EHV and HV sub-functions classified based on system load factor.

5.1.1.1 NSP CURRENT APPROACH - 5 Transmission rate base, depreciation, and OM&A is functionalized between extra high - 6 voltage ("EHV") and high voltage ("HV") sub-functions. As discussed further in this - 7 section, EHV and HV are classi...

AI summary Nova Scotia Power (NSP) classifies and allocates transmission rate base, depreciation, and OM&A costs between extra high voltage (EHV) and high voltage (HV) sub-functions. These are treated as a single Transmission function, with bulk power substations refunctionalized to the Distribution function.

5.1.1.2 NSP PROPOSED APPROACH - NS Power is proposing to maintain the current practice of classifying and allocating EHV - and HV transmission by the same factors. The separation of EHV and HV within the cost - of service study model is no...

AI summary NS Power proposes to maintain current classification practices for EHV and HV transmission, eliminate sub-functionalization in the cost of service study model, and continue refunctionalizing bulk power substations from Transmission to Distribution.

6 6.1.1.2 NSP PROPOSED APPROACH - 7 NS Power is proposing to maintain the same sub-functions, and add an additional sub- - 8 function for storage. Storage assets may serve a distribution function, such as a battery - 9 storage system conne...

AI summary NSP proposes to maintain existing sub-functions and add a new one for storage assets that serve distribution functions, such as battery systems that help avoid capacity-related distribution costs.

1 6.2 CLASSIFICATION - 2 6.2.1 GENERAL DISTRIBUTION - 3 6.2.1.1 NSP CURRENT APPROACH - 4 Distribution sub-functions are classified by a range of methods. A summary of the - 5 classification methodology of each sub-function is summarized be...

AI summary This section discusses the classification methodology for distribution sub-functions, with a focus on NSP's current approach to classifying these sub-functions.

6.2.1.2 NSP PROPOSED APPROACH - NS Power is proposing to maintain the current classification methodologies for its - distribution sub-functions.

AI summary NSP proposes to maintain current classification methodologies for its distribution sub-functions.

2026-2027 GRA Direct Evidence Appendix 12B Page 40 of 55 REDACTED (CONFIDENTIAL INFORMATION REMOVED) -40- NSP COSS Consultation Report Draft April 25, 2025 - 1 considered customer-specific in the basic customer method. Remaining distributi...

AI summary The document discusses the classification of distribution costs in the basic customer method, noting that costs associated with poles, fixtures, and lines are either not classified as customer-related or only partially so, with the remainder classified as demand-related or between demand-related and energy-related using a load factor or alternate methodology.

6.2.2.3 ELENCHUS OPINION - The minimum system method is appropriate for classifying poles & fixtures and overhead - & underground lines between demand and customer. These costs have two clear cost - drivers: the sprawl of the distribution...

AI summary The minimum system method is deemed appropriate for classifying distribution costs related to poles, fixtures, and overhead and underground lines. It accounts for two cost drivers: the sprawl of the distribution system and peak demand. This method is used by multiple utilities and is considered the most common approach in Canada for classifying distribution costs.

7.4.1 UPDATED LINE LOSS STUDY - NS Power retained BBA to conduct a line loss study to allocate NS Power's demand and - energy line losses to rate classes. The study used a range of load data sources, software - simulations, GIS, and indust...

AI summary NS Power commissioned BBA to conduct an updated line loss study to allocate demand and energy line losses to rate classes. The study utilized various data sources, software simulations, GIS, and industry research to estimate losses across different voltage service levels.

1. Introduction Nova Scotia Power Inc. (NS Power) mandated BBA to develop and implement a comprehensive and industry-aligned methodology for conducting line loss studies that are representative of NS Power systems and appropriate for use i...

AI summary Nova Scotia Power Inc. (NS Power) has mandated BBA to develop a standardized methodology for line loss studies using AMI, SCADA, and asset data. The initiative aims to replace manual processes with a more accurate and efficient approach, improving regulatory proceedings and operational efficiency.

3.1 Technical Losses Technical losses refer to the energy dissipated within the electrical system components while delivering power to customers. These losses are inherent to the equipment used for transmission, distribution and secondary...

AI summary Technical losses are the energy lost within electrical system components during power delivery to customers. These losses are inherent to equipment and occur due to conductor resistance and transformer losses, with conductor losses being proportional to resistance and the square of current flow.

REDACTED (CONFIDENTIAL INFORMATION REMOVED) REDACTED 2026-2027 GRA Direct Evidence Appendix 12C Page 9 of 25 Power System Line Loss Study Technical Report Methodology to Compute Loss Allocation Factors

AI summary This document is a technical report titled 'Power System Line Loss Study' that outlines the methodology to compute loss allocation factors. It is part of Appendix 12C of the 2026-2027 GRA Direct Evidence, and it is on page 9 of 25.

Table 1: Transmission monthly simulation results Month Energy (MWh) Peak (MW) Peak Loss (MW) Energy Loss (MWh) January 1,112,409 1,921 82 30,858 February 1,118,927 2,403 102 33,090 March 1,114,369 1,909 58 27,086 April 864,685 1,723 52 18,...

AI summary Table 1 presents monthly transmission simulation results for energy, peak demand, peak loss, and energy loss from January to December. The data includes metrics such as energy in MWh, peak demand in MW, peak loss in MW, and energy loss in MWh, with a total summary provided for the year.

4.2 Distribution losses NS Power relies on a combination of Georeferenced Information System (GIS) data, CYME Power System Engineering software, SCADA monitoring, and metering data from AMI and MV90 systems. A key component of the distribu...

AI summary NS Power uses GIS data, CYME software, SCADA, and metering systems to model distribution losses. The model has limitations, including partial SCADA coverage and lack of secondary cabling data. A load flow study estimated 52.55 MW in distribution losses, or 2.93% of total demand, with a sensitivity analysis adjusting customer demand by ±10% to assess marginal losses.

Table 4: Results of the feeder level loss factor Annual Peak Energy Load Loss Factor Loss Factor Load (PL) in a year Factor (LF) (Feeder Level) (Service Level) (kW) (kWh) % % % 1,794,284 8,291,795,086 52.75% 31.57% 35.31% Using the peak de...

AI summary Table 4 presents the results of the feeder level loss factor, including annual peak load, energy, and load factor. The table shows a loss factor of 31.57% at the feeder level and 35.31% at the service level. The data is used to calculate total annual distribution energy losses using peak demand loss values and the calculated loss factor.

$52.55 \times 0.316 \times 8760 = 145 \, GWh$ This corresponds to 1.75% of total annual energy consumption, providing a quantifiable estimate of the distribution system energy loss. In addition to distribution system load losses, substatio...

AI summary The document calculates annual distribution system energy loss at 145 GWh, representing 1.75% of total annual energy consumption. Additional no-load losses from substation transformers were estimated at 1,780 kW, contributing 0.10% of demand loss and 0.19% of total annual energy loss, though they are relatively small.

4.3 Secondary losses Given limited GIS data and initial software constraints, a structured approach was implemented using GIS data, AMI metering, CYME simulations, and historical load research to improve modelling accuracy with typical con...

AI summary The document discusses the estimation of secondary losses using GIS data, AMI metering, CYME simulations, and historical load research. Typical secondary network configurations were developed based on NS Power's line construction standards, including parameters like customer connections per transformer and conductor characteristics.

Table 6: Secondary energy losses and peak load losses Customer Class Secondary Configuration Annual kWh Sec Non-Coincident Demand Sec (kW) Coincident Demand Sec (kW) Loss Factor % Peak Load Loss % NLL (kW) Demand Losses (kW) Energy Loss %...

AI summary Table 6 presents data on secondary energy losses and peak load losses across different customer classes, including metrics like annual kWh losses, demand losses, and energy loss percentages. The table highlights variations in losses based on secondary configurations such as Padmount, Pole Mounted, and Vault, with different loss factors and percentages for each class.

6. Classification of customers The level at which customers are connected to the network significantly impacts the energy losses associated with electricity delivery. Losses vary depending on the voltage level at which electricity is suppl...

AI summary The classification of customers based on their connection level to the network affects energy losses in electricity delivery. Factors such as voltage level, distribution line length, and the number of transformation stages influence these losses.

2. Primary distribution customers Customers in this category are connected to primary distribution lines operating at voltages ranging from 25 kV to 4.16 kV. At these lower voltage levels, energy losses increase. Customers connected throug...

AI summary Primary distribution customers are connected to lines operating between 25 kV and 4.16 kV, where energy losses increase at lower voltage levels. These customers also experience load and no-load losses through transformers at distribution substations, with primary distribution losses adding to transmission losses.

3. Secondary distribution customers At the lowest-voltage level, secondary distribution customers receive electricity that has passed through several stages of transformation, eventually reaching voltages ranging from 600 V to 240/120 V. E...

AI summary Secondary distribution customers receive electricity at low voltages (600 V to 240/120 V) after multiple transformations. Energy losses are higher in this segment due to transformer inefficiencies at low load factors and longer secondary distribution line distances, which increase current flow and losses.

Table 8: Level of contribution to network losses per customer class Class Secondary Primary Transmission (1) Domestic 100% 0% 0% (5) Small General 100% 0% 0% (8) General 94% 6% 0% (11) General Large 0% 100% 0% (12) Small Industrial 96% 4%...

AI summary Table 8 shows the distribution of network losses among different customer classes, with domestic and small general customers contributing 100% at the secondary level, while large industrial and municipal customers contribute significantly at the transmission level. The text explains that all customers contribute to losses across the entire system, even if their direct contribution is at one level.

7.1 Energy loss allocation factors The calculation of annual energy losses is based on the contribution of each customer class to energy losses across different network segments (Transmission, Distribution, Secondary and Non-Technical). Si...

AI summary The document outlines how energy losses are allocated to different customer classes based on their connection points in the power network. Each class is assigned a portion of losses in specific segments, such as transmission, distribution, and non-technical losses, based on their proportional energy consumption at each voltage level.

A-8 T&D SYSTEM LINE LOSSES ( Non-Confidential ) Total line losses for reporting periods year to date, prior period year to date and forecast next year

AI summary The document presents total line losses for the T&D system for the current year-to-date, prior year-to-date, and forecast for the next year, providing a snapshot of performance metrics related to transmission and distribution losses.

NOVA SCOTIA POWERPeriod: MONTH-YearSubmitted: Date JAN- 16 FEB -16 MAR -16 APR -16 MAY -16 JUN- 16 JUL- 16 AUG -16 SEP- 16 OCT- 16 NOV -16 DEC -16 Total Fair mont Dun vegan Gra nville Ferr y Isle Mad ame Crei gnish Rear Irish Mou ntain Sou...

AI summary The document presents a table with monthly data for various locations in Nova Scotia, likely related to energy production or distribution, though specific details or context for the data are not provided.

Transmission & Distribution Metrics

AI summary The document discusses transmission and distribution metrics, referencing various acronyms and entities involved in the regulatory process. It includes visual elements such as images that may provide further context on the metrics being analyzed.

Summary Observations - ◼ Transmission and Distribution OM&G costs typically include the cost of operating and maintaining utility transmission and distribution substations, overhead lines and structures, underground lines, and line transfo...

AI summary The summary discusses NSPI's Transmission and Distribution OM&G costs, noting that they are in the first quartile of the peer group on various metrics. However, the gap has narrowed since 2021 due to increased expenses from storms, customer growth, and investments in reliability. The document includes images related to these observations.

Transmission and Distribution 2,171 km of transmission 19,916 km of distribution

AI summary The text provides statistics on the length of transmission and distribution lines, indicating 2,171 km of transmission and 19,916 km of distribution infrastructure.

Transmission and Distribution 24,300 km of main lines 13,500 km of service lines

AI summary The text provides statistics on the length of main and service lines in the transmission and distribution network, indicating a total of 24,300 km of main lines and 13,500 km of service lines.

Transmission and Distribution 278 km of transmission 4,459 km of distribution

AI summary The text provides statistics on the length of transmission and distribution lines, indicating 278 km of transmission and 4,459 km of distribution infrastructure.

Transmission and Distribution 2,192 km of transmission 20,299 km of distribution

AI summary The text provides statistics on the length of transmission and distribution networks, indicating 2,192 km of transmission lines and 20,299 km of distribution lines.

Transmission and Distribution 5,000 km of transmission 28,000 km of distribution

AI summary The document provides statistics on the length of transmission and distribution infrastructure, indicating 5,000 km of transmission lines and 28,000 km of distribution lines.

Transmission and Distribution 24,300 km of main lines 13,500 km of service lines

AI summary The document provides statistics on the length of main and service lines in the transmission and distribution network, indicating 24,300 km of main lines and 13,500 km of service lines.

Transmission and Distribution 2,408 km of transmission 17,657 km of distribution

AI summary The text provides statistics on the length of transmission and distribution lines, indicating 2,408 km of transmission and 17,657 km of distribution lines.

Transmission and Distribution 278 km of transmission 4,833 km of distribution

AI summary The document provides statistics on the length of transmission and distribution lines, indicating 278 km of transmission and 4,833 km of distribution lines.

Transmission and Distribution 2,192 km of transmission 20,299 km of distribution

AI summary The document provides statistics on the length of transmission and distribution lines, indicating 2,192 km of transmission and 20,299 km of distribution.

Transmission and Distribution 5,000 km of transmission 28,000 km of distribution

AI summary The document provides statistics on the length of transmission and distribution lines, indicating 5,000 km of transmission and 28,000 km of distribution lines.

Advanced transformer monitoring Supporting reliability and enabling troubleshooting

AI summary The document discusses the importance of advanced transformer monitoring in supporting system reliability and enabling effective troubleshooting within the electricity grid.

Transmission and Distribution ~540.000 Customers - 2,408 km of transmission - 17,657 km of distribution

AI summary The document provides data on the length of transmission and distribution lines, indicating 2,408 km of transmission and 17,657 km of distribution lines. Visual representations are included for further context.

Allocation of $20B 5-Year Capital Plan 55% of capital spend on transmission, distribution and gas infrastructure in support of reliability and customer growth 17% spend on renewable integration reducing volatile fuel cost exposure Capital...

AI summary The document outlines a 5-year, $20B capital plan with 55% allocated to transmission, distribution, and gas infrastructure to ensure reliability and support customer growth, and 17% focused on renewable integration to reduce volatile fuel cost exposure. The plan emphasizes customer-centric investments.

Transmission and Distribution 508,000 Customers - 25,240 km of main lines - 14,530 km of service lines Customers

AI summary The chunk provides statistical data on the transmission and distribution infrastructure, including the number of customers and the total length of main and service lines in Nova Scotia.

Transmission and Distribution • 2,405 km of transmission 550,000 • 17,810 km of distribution

AI summary The text provides statistics on the length of transmission and distribution lines, with 2,405 km of transmission and 17,810 km of distribution. It includes images from page 148 and page 149, but no further details or analysis.

Transmission and Distribution 508,000 Customers - 25,240 km of main lines - 14,530 km of service lines Customers

AI summary The document provides statistics on the transmission and distribution network, including the number of customers and the total length of main and service lines.

Transmission and Distribution 550,000 - 2,405 km of transmission - 17,810 km of distribution

AI summary The document provides statistics on the transmission and distribution infrastructure, including 2,405 km of transmission lines and 17,810 km of distribution lines, along with a visual representation of the data.

Transmission and Distribution - 25,240 km of main lines - 14,530 km of service lines

AI summary The text provides statistics on the length of main lines and service lines in the Transmission and Distribution sector, indicating the scale of infrastructure.

Transmission and Distribution - 2,405 km of transmission - 17,810 km of distribution

AI summary The document provides statistics on the length of transmission and distribution lines, indicating 2,405 km of transmission and 17,810 km of distribution.

8,999.840 % Transmission to Total Assets 19.5% Additional Deferred Chgs. & W/C assigned to Trans. $109.665 NPV - Steam Production 772.3 832.8 802.6 NPV - Hydro 696.3 731.6 713.9 NPV - Wind 158.5 148.8 153.7 NPV - Solar 1.3 1.2 1.2 NPV - Ga...

AI summary The document presents financial and operational data related to transmission plant analysis, including NPV values for various energy production sources and transmission distribution, along with percentages of transmission to total assets. It also references a confidential attachment from Nova Scotia Power Inc. related to the 2026-2027 GRA SR-01.

Notes: - Electrification is a big part of their future, i.e., home heating and EV's. - Is there any legislation on gasoline-powered vehicles? - o There's a federal mandate that says by 2030 or 2035, 50% of sales need to be electric - Accou...

AI summary The document discusses NSPI's distribution pole replacement strategy, focusing on the use of wood poles, the species of trees used, and considerations for upgrading pole classes for reliability and safety. It also touches on the lack of immediate plans to replace wood with fiber-glass, concrete, or steel, and mentions a joint use agreement with Bell-Alliant for managing communication infrastructure on poles.

- Replacing 10 per year doesn't even maintain status quo and leaves fleet risk unacceptably high. - Replacing 15 per year is likely to induce unsustainable financial strain. - Strategy going forward will need to include more life extension...

AI summary The discussion focuses on the replacement and maintenance of transformers, highlighting the need for life extension, increased internal expertise, and infrastructure capacity. It addresses the aging of transformers, replacement timelines, and the impact of new generation sources on substation equipment. The document also touches on voltage levels and the transition from 4kV to 25kV infrastructure.

3.2.2 The Energy Delivery Reliability Team The Energy Delivery Reliability Team included within the Energy Delivery function in Figure 5 is a relatively new organization, focused on the execution of and communication of Reliability initiat...

AI summary The Energy Delivery Reliability Team, a new organization within the Energy Delivery function, focuses on executing and communicating reliability initiatives across the transmission and distribution grid. The team collaborates with the EAM division and engages directly with customer groups to address service challenges and improve performance through innovative methods like satellite imagery for vegetation management.

7.4.4 Energy Delivery Energy Delivery consists of a large volume of assets distributed across the province: - ~27,800 km overhead 4kV to 25kV distribution system - ~400 km underground distribution system - 5,407km 69 kV to 345 kV transmiss...

AI summary Energy Delivery includes extensive electrical infrastructure across Nova Scotia, such as 27,800 km of overhead distribution lines, 400 km of underground distribution, 5,407 km of transmission lines, and approximately 196 substations.

TABLE OF FIGURES Figure 1: Forecast Investment by Reliability Program 2025-2029 ($ million) 5 Figure 2: Contribution to CHI by Outage Cause 2019-2023 (Including all Storms) 9 Figure 3: Highest Priority Distribution Feeders in 2025 12 Figur...

AI summary The document presents a table of figures outlining various investment and infrastructure projects related to grid reliability and vegetation management in Nova Scotia from 2025 to 2029. These figures include investments in distribution feeders, transmission corridors, and vegetation management strategies.

4 The feeders in Figure 3 represent approximately 10 percent of NS Power's distribution feeders 5 across the province. While these are the primary areas of focus in 2025, NS Power will continue 6 to reassess these priorities on an ongoing...

AI summary NS Power is focusing on reliability improvements through investments in approximately 10 percent of its distribution feeders across Nova Scotia in 2025. These priorities will be reassessed throughout the year and the Plan, with NS Power also responding to emerging areas of focus.

Five-Year Reliability Plan – 2025-2029 NON-CONFIDENTIAL 2026-2027 GRA NSEB IR-20 Attachment 1 Page 16 of 40 - As outlined in M11921 New Distribution Rights-of-Way Phase 10,5F 6 1 NS Power uses its Asset - 2 Management Mechanism and Feeder...

AI summary NS Power uses an Asset Management Mechanism and Feeder Risk Profiles to prioritize tree cutting on distribution feeders. Criticality assessments consider factors such as electricity usage, regulatory consequences, customer count, redundancy, and ease of access, with condition ratings from 1 to 5 indicating the vegetative condition of a feeder.

15 2025-2029 Forecast Investment: $66 million 16 - 17 This program will expand the width of distribution corridors that currently have a managed right- - 18 of-way to reduce tree encroachment risks and enhance clearance standards. Over the...

AI summary NS Power plans to invest $66 million from 2025 to 2029 to widen distribution corridors, reducing tree encroachment risks and enhancing clearance standards. The work will focus on 40 communities and prioritize feeders with the poorest performance based on historical outage data and weather analysis.

1 Figure 5: Distribution Vegetation Management Right of Way Widening (2025) 2 3 4 In 2025, NS Power will begin leveraging satellite imagery to further assess vegetation conditions 5 by analyzing the proximity of vegetation to conductors. B...

AI summary In 2025, NS Power plans to use satellite imagery to analyze vegetation near power lines, combining this data with historical outage information to improve vegetation management on poorly performing circuits. This approach will help focus resources on high-risk areas.

Five-Year Reliability Plan – 2025-2029 NON-CONFIDENTIAL 2026-2027 GRA NSEB IR-20 Attachment 1 Page 24 of 40 1 In 2025, $9.2 million is planned to be invested to modernize and replace aging or obsolete 2 equipment such as hydraulic recloser...

AI summary In 2025, NS Power plans to invest $9.2 million to modernize and replace aging equipment, including hydraulic reclosers, PCB-containing devices, and transformers, to improve reliability and environmental compliance. The program also includes the installation of new protective devices such as reclosers to enhance grid resilience.

20 In 2025, NS Power anticipates installing 16 trip saver devices across the province. Trip savers are 21 protective devices installed on smaller sections of the distribution system where fuses would 22 traditionally be used. Similarly to...

AI summary In 2025, NS Power plans to install 16 trip saver devices across Nova Scotia. These devices will replace fuses on smaller sections of the distribution system, helping to quickly detect and isolate faults, restore power to unaffected areas, and reduce outage durations. Fourteen of these devices will be installed on the highest priority feeders.

Five-Year Reliability Plan – 2025-2029 NON-CONFIDENTIAL 2026-2027 GRA NSEB IR-20 Attachment 1 Page 26 of 40 1 54 poles and 10.8 kilometers of primary and neutral conductor, enhancing capacity and 2 reliability in this rapidly expanding are...

AI summary NS Power is implementing infrastructure upgrades, including new poles, conductor installations, and substation feeders, to enhance capacity and reliability in growing areas. Updates to overhead distribution design standards and coastal framing standards are being introduced to improve resilience against severe weather conditions.

1 5.1.1 Distribution System Build-to-Roadside Program 2 3 2025-2029 Forecast Investment: $12 million 4 - 5 The purpose of this program is to bring distribution lines closer to the roadside (re-routing them - 6 from off-road areas where the...

AI summary The Distribution System Build-to-Roadside Program aims to relocate distribution lines closer to roadways to reduce tree contact risks and improve access for maintenance. An estimated $12 million is forecasted for investment between 2025 and 2029, with eight kilometers of line expected to be re-built in 2025.

2 2025-2029 Forecast Investment: $26 million 3 - 4 The Distribution Conductor Upgrades program focuses on the proactive replacement and - 5 modernization of aging infrastructure to reduce the risk of outages and improve reliability and - 6...

AI summary The 2025-2029 forecast investment is $26 million, allocated to the Distribution Conductor Upgrades program. This initiative involves the proactive replacement and modernization of aging infrastructure to reduce outage risks and improve reliability and resilience of the distribution system. In 2025, approximately 39 kilometers of distribution line are expected to be reconductored.

Five-Year Reliability Plan – 2025-2029 NON-CONFIDENTIAL 2026-2027 GRA NSEB IR-20 Attachment 1 Page 30 of 40 1 reliability by enabling the ability to isolate faults to a specific area, reducing outage impacts and 2 enabling faster restorati...

AI summary The document outlines infrastructure investments to enhance grid reliability, including the purchase of a spare substation transformer and the construction of new substations in several locations across the province. These investments aim to improve system capacity, support increased demand, and strengthen grid resilience.

Five-Year Reliability Plan – 2025-2029 NON-CONFIDENTIAL 2026-2027 GRA NSEB IR-20 Attachment 1 Page 33 of 40 - 1 Expanding on Section 6.1, adding a communications path from a downline recloser to the ADMS - 2 environment can provide reliabi...

AI summary NS Power plans to expand connectivity to downline reclosers from 2025 to 2029, aiming to improve reliability through faster fault location, reduced delays, and enhanced asset management. Initial deployments in 2025/2026 will cover up to 28 reclosers, with future scaling based on field learnings and Control Center integration.

NON-CONFIDENTIAL built for developing the new pole class standard, resulting in stronger poles as the standard for Nova Scotia. In addition to increasing the size and strength of wood poles, Nova Scotia Power has increased the usage of cla...

AI summary Nova Scotia Power has upgraded wood pole standards and increased the use of clamp top insulators to improve infrastructure resilience, particularly in high-wind areas like Cheticamp and the Cabot Trail, which have shown greater durability in extreme weather conditions.

TD4 – Distribution OM&G per Retail MWh Sold

AI summary The document presents figures related to Distribution OM&G per Retail MWh Sold, including visual representations from page 159, figures 3 and 4.

CA8 – Distribution Additions as % of Distribution Plant - On a 5-year average basis, NSPI Distribution Additions as a Percent of Distribution Plant is above the peer group median - NSPI Distribution Additions as a Percent of Distribution P...

AI summary NSPI's Distribution Additions as a Percent of Distribution Plant is above the peer group median on a 5-year average basis. While NSPI's Distribution Additions decreased slightly between 2019 and 2023, the peer median increased. NSPI's Distribution Additions and Plant values were higher in 2023 compared to 2019 in nominal terms.

Peer Demographics T - 1 - 1 JPDATED _ Peer Generation Capacity (MW) Distribution Lines Total Electric Revenue Total Electric Plant Number of Customers Thermal Hydro Nuclear Other Renewables Total (km) (km) ($000 CAD ) ($000 CAD ) Gustomers...

AI summary The text presents a table comparing peer utilities, including their generation capacity, distribution lines, total electric revenue, total electric plant value, and number of customers. Nova Scotia Power Inc. is listed alongside other utilities from across North America.

1 Request IR-74: 2 - 3 Reference: Exhibit N-14, OP-03, Attachment 1, ScottMadden Report, p. 28 of 87, - 4 Transmission and Distribution Metrics 5 - 6 The report notes: NSPI widened its positive gap in the Distribution OM&G metrics through...

AI summary The document discusses NSPI's Distribution OM&G expenses, noting that while NSPI widened its positive gap in these metrics through 2021, the gap has narrowed since 2021 due to faster expense growth compared to peers. Factors include increased storm expenses in 2023 and customer growth. ScottMadden does not have similar information on storm costs or reliability investments for peer utilities.

- 19 is the same as customer growth, it shows this information below. Company Percentage Change in Reported Number of Customers 6 depreciation expense basis, and below the peer median in four of the five years studied. 7 8 (v) NS Power's f...

AI summary The text discusses customer growth and compares NS Power's distribution and general plant additions to peer medians, highlighting discrepancies in depreciation expense and investment in system reliability. It also notes higher HR costs per FTE and mentions regulatory processes like the ACE Plan and Five-Year Reliability Plan.

2026-2027 General Rate Application (M12451) NSPI Responses to Synapse Information Requests 1 Request IR-6: 3 (a) Please refer to the 2026 COSS and 2027 COSS tabs included in 2026-2027 GRA SR-01 4 Attachment 2 PCON EO. 5 6 • Exh 3c shows cl...

AI summary NSPI provides responses to Synapse's information requests regarding the 2026-2027 General Rate Application, including references to COSS tabs, classification of voltage investments, and clarification on equipment sizing and distribution line definitions.

NON-CONFIDENTIAL 1 Request IR-1: 2 Tariff, which includes the Distribution Tariff Rates (DTR) as Appendix A. Until recently, 3 the Distribution Tariff has only included provisions for RTR Distribution-connected 4 customers. Within the GRA,...

AI summary The document discusses the need to update the Distribution Tariff to align with proposed revisions, addressing an oversight in the GRA. The changes are due to updates in the Cost-of-Service methodology and increased investment in distribution since the 2023-2024 GRA. References are made to specific attachments and tabs for further details.

Notes: - Electrification is a big part of their future, i.e., home heating and EV's. - Is there any legislation on gasoline-powered vehicles? - o There's a federal mandate that says by 2030 or 2035, 50% of sales need to be electric - Accou...

AI summary The document discusses NSPI's distribution pole replacement strategies, focusing on material and class upgrades for reliability and safety. While wood remains the primary material, alternatives like fiber-glass and concrete are not currently feasible due to cost. The company is using Southern yellow pine and exploring Western red cedar for potential future use.

- Replacing 10 per year doesn't even maintain status quo and leaves fleet risk unacceptably high. - Replacing 15 per year is likely to induce unsustainable financial strain. - Strategy going forward will need to include more life extension...

AI summary The document discusses the aging infrastructure of transformers and the challenges associated with their replacement. It highlights the financial and operational implications of replacing transformers at different rates and the need for life extension strategies. It also covers the impact of new generation sources on substation equipment and the voltage distinctions between transmission and distribution systems.

Item 2c: Electrification Impacts – Transmission and Distribution System Address electrification impacts on the Transmission & Distribution system as additional experience and data become available. This will include an analysis of availabl...

AI summary The document discusses analyzing the impacts of electrification on the Transmission & Distribution system, including assessing T&D capacity and mitigation options, using data from NS Power's AMI implementation as it becomes available.

7.4.4 Energy Delivery Energy Delivery consists of a large volume of assets distributed across the province: - ~27,800 km overhead 4kV to 25kV distribution system - ~400 km underground distribution system - 5,407km 69 kV to 345 kV transmiss...

AI summary The Energy Delivery section outlines the extensive distribution and transmission infrastructure managed by Nova Scotia Power, including overhead and underground systems, and various substations.

Page 1 of 1 Exhibit DMM-4 Acc t oun Nu mb er Ac nt N cou am e Inv estm ent at 31 , 20 23 Dec Per t cen Inv estm ent at 31 , 20 23 Dec NS Po Li fe wer ima Est tes NS Po wer Cu Ty rve pe Lif e P eer Res ult Av era ge Lif e P eer Res ult Ra n...

AI summary The exhibit presents a table detailing investment and salvage estimates for various transmission and distribution assets, including land rights, station equipment, towers, poles, overhead conductors, and distribution assets, with associated percentages, ratings, and average results.

ACCOUNT 540.00 – DISTRIBUTION – SERVICES Investment $ Investment % Previously Approved Curve Concentric Recommended Curve $69,565,394 5.07% 35-R0.5 35-R1 The investment in Distribution – Services is approximately $70 million, representing...

AI summary Account 540.00 – Distribution – Services involves an investment of approximately $70 million, representing over five percent of the total Distribution functional group depreciated and amortized plant. The account includes service lines for residential and commercial customers and uses a T-Cut at age 48 for retirement rate analysis, with retirements of $36,383,019 recorded between 1982 and 2024.

Account No. Account Description ELECTRIC PLANT OTHER PRODUCTION 344 Generators TRANSMISSION 355 356 Poles and Fixtures Overhead Conductors and Devices DISTRIBUTION 362 364 365 368.1 368.2 369.01 370.1 373 Substation Equipment Poles, Towers...

AI summary The document outlines various account numbers and their corresponding descriptions related to electric plant, transmission, and distribution infrastructure, including generators, poles, conductors, and meters.

Account No. Account Description HYDRO PRODUCTION 321 Roads, Trails and Bridges 323 Canals, Penstocks, Surge Tanks and Tailraces 324 Dams and Reservoirs 325 Prime Movers, Generators and Auxiliaries SUBSTATION 341 Buildings and Structures 34...

AI summary The document presents a list of account numbers and their corresponding descriptions related to infrastructure and transportation within the electricity sector, including categories such as roads, transmission lines, distribution systems, and transportation vehicles.

DISTRIBUTION 361.10 Overhead Conductors - Bare Copper 361.11 Overhead Conductors – Weather-Proof Copper 361.12 Overhead Conductors - Bare Aluminum 361.13 Overhead Conductors - Weather-Proof Aluminum 361.14 Overhead Conductors – Aerial Cabl...

AI summary The document outlines various distribution-related accounts, including overhead conductors, poles, transformers, and meters, and discusses the depreciation reserve accounting data compiled from 2000 to 2018 for distribution poles and fixtures. It highlights the methodology used for the study, focusing on retirements, removal costs, and salvage values.

SMOOTH SURVIVOR CURVE NEWFOUNDLAND POWER INC. ACCOUNT 361.40 - DISTRIBUTION - SUBMARINE CABLE NEWFOUNDLAND POWER INC. ACCOUNTS 362.10, 362.20 AND 361.10 - WOOD POLES AND OVERHEAD CONDUCTORS - BARE COPPER ORIGINAL AND SMOOTH SURVIVOR CURVES

AI summary The text references accounts related to distribution infrastructure, including submarine cable and wood poles with smooth survivor curves, and mentions a figure related to these accounts.

72.5 NEWFOUNDLAND POWER INC. ACCOUNT 362.30 - DISTRIBUTION - POLES (CONCRETE AND STEEL) ORIGINAL AND SMOOTH SURVIVOR CURVES

AI summary The text references an account related to distribution poles (concrete and steel) with original and smooth survivor curves, along with a figure from page 171.

NEWFOUNDLAND POWER INC. NEWFOUNDLAND POWER INC. ACCOUNT 363.00 - DISTRIBUTION - STREET LIGHTS ORIGINAL AND SMOOTH SURVIVOR CURVES

AI summary The document presents an account related to distribution, specifically focusing on street lights, with original and survivor curves. The page includes a figure referenced as Figure 1.

ACCOUNT 363.00 - DISTRIBUTION - STREET LIGHTS PLACEMENT BAND 1977-2018 EXPERIENCE BAND 2009-2018 AGE AT BEGIN OF INTERVAL EXPOSURES AT BEGINNING OF AGE INTERVAL RETIREMENTS DURING AGE INTERVAL RETMT RATIO SURV RATIO PCT SURV BEGIN OF INTER...

AI summary The text presents statistical data on the retirement and survival rates of street lights over time, categorized into different age intervals. It includes exposure numbers, retirements, retirement ratios, survival ratios, and percentages of survival at the beginning of each interval. The data spans from 1977 to 2018 and provides a detailed breakdown of the aging and replacement patterns of street lights.

NEWFOUNDLAND POWER INC. ACCOUNT 365.20 - DISTRIBUTION - SERVICES UNDERGROUND ORIGINAL AND SMOOTH SURVIVOR CURVES

AI summary The document references an account related to distribution services, specifically underground original and survivor curves, associated with Newfoundland Power Inc.

ACCOUNT 366.20 - DISTRIBUTION - DEMAND METERS PLACEMENT BAND 1970-2044 EXPERIENCE BAND 2008-2044 AGE AT BEGIN OF INTERVAL EXPOSURES AT BEGINNING OF AGE INTERVAL RETIREMENTS DURING AGE INTERVAL RETMT RATIO SURV RATIO PCT SURV BEGIN OF INTER...

AI summary The document presents a table detailing the aging and retirement rates of demand meters over time, providing exposure numbers, retirements, and survival rates for different age intervals from 0.0 to 38.5 years.

NEWFOUNDLAND POWER INC. ACCOUNT 367.10 - DISTRIBUTION - UNDERGROUND DUCT AND MANHOLES ORIGINAL AND SMOOTH SURVIVOR CURVES

AI summary The document presents original and survivor curves for Account 367.10 - Distribution - Underground Duct and Manholes by NEWFOUNDLAND POWER INC. A figure is included for reference.

ACCOUNT 365.00 - DISTRIBUTION - SERVICES COST OF G R O S S S A L V A G E NET YEAR REGULAR RETIREMENTS REMOVAL AMOUNT PCT REUSE AMOUNT PCT FINAL AMOUNT PCT SALVAGE AMOUNT PCT 2017 322,019 175,088 54 0 8,646 3 166,442 - 52- 2018 352,996 217,...

AI summary The document presents a table detailing distribution services, including costs of removal, reuse, salvage, and net salvage amounts over various years. It shows trends and percentages for different time periods, highlighting the distribution of costs and salvage values.

ACCOUNTS 362.10 AND 362.20 - DISTRIBUTION - POLES AND FIXTURES - WOOD COST OF G R O S S S A L V A G E NET REGULAR REMOVAL REUSE FINAL SALVAGE YEAR RETIREMENTS AMOUNT PCT AMOUNT PCT AMOUNT PCT AMOUNT PCT THREE-YEAR MOVING AVERAGES 15-17 947...

AI summary The text provides data on the cost of retirements and salvage values for wood poles and fixtures in distribution accounts 362.10 and 362.20. It includes three-year and five-year moving averages for the years 2015-2017 and 2014-2018, respectively, with percentages indicating the proportion of costs related to removal and salvage.

21 Q. Please describe your conclusions and recommendations. 20 II. SUMMARY OF CONCLUSIONS AND RECOMMENDATIONS 19 Company") cost of service study. 18 A. The purpose of this evidence is to address Nova Scotia Power's ("NS Power" or "the 17 Q...

AI summary The testimony addresses the misclassification of distribution system costs by NS Power using the minimum size method, which inflates residential customer costs. It recommends adopting the Basic Customer Method instead, aligning costs more accurately with customer numbers and directly related expenses like metering and billing.

g costs. Thus, these costs are primarily driven by demand, rather than by the number of customers. It is only when the distribution system must be expanded to a new geographic area that an incremental 2026-2027 GRA SR-01 Attachment 1a p.4....

AI summary The discussion focuses on whether customer count is a suitable proxy for geographic dispersion in distribution system cost allocation. It argues that geography has a greater influence on distribution costs than the number of customers, and that the minimum size methodology does not account for geographic dispersion.

nsas Public Service Commission). Lazar, J. et al., Electric Cost Allocation for a New Era: A Manual. Montpelier, VT: Regulatory Assistance Project (2020) (Hereafter: "RAP Electric Manual"). at 145 - classification and allocation methodolog...

AI summary The text discusses the classification and allocation methodologies for distribution system costs, referencing the rejection of minimum size studies by the Michigan Public Service Commission and suggesting a hybrid classification method if the Basic Customer Method is not approved. It emphasizes aligning cost methodologies with system cost drivers and differentiating between primary and secondary distribution costs.

only secondary plant, or for primary and secondary distribution plant, should any adjustments be made to recognize that the minimum system also meets all or a portion of customers' maximum demands? Washington Administrative Code 480-85-060...

AI summary The text raises a question about whether adjustments should be made to account for the minimum system meeting customers' maximum demands in the context of primary and secondary distribution plant. It also includes citations to legal codes and regulatory orders from Washington and Michigan.

Ontario Energy Board. Cost Allocation: Board Directions on Cost Allocation Methodology for Electricity Distributors. September 2006. At 53-55. https://www.oeb.ca/documents/cases/EB-2005- 0317/report directions 290906.pdf. Ontario Energy Bo...

AI summary The text references cost allocation methodologies used by other utilities, such as Northern States Power Company (Xcel Energy) and National Grid, in their rate cases. Xcel Energy has assumed a load carrying capacity of 1.5 kW per customer, while National Grid proposed allocating no demand-related costs to residential and small commercial customers.

that "the minimum system would be able to meet the peak load for all or almost all customers in [the relevant classes]; that is, no further investment in higher capacity conductors would be required. Ontario Energy Board. Filing Requiremen...

AI summary The text discusses minimum system studies and zero intercept studies conducted by Xcel Energy, which assess the ability of the distribution system to meet peak load demands without requiring additional investment in higher capacity conductors. These studies are referenced in multiple regulatory filings and dockets.

Table 21: UI Investment Categories Baseline Programs (Maintain Reliability) Modernization Business effectiveness Customer service technology Facilities Fleet Metering Compliance and safety Customer lighting State/municipal projects Third-p...

AI summary Table 21 outlines UI investment categories, divided into baseline and incremental programs, focusing on reliability, modernization, and infrastructure improvements. It includes categories such as modernization, compliance and safety, and resilience projects.

age share of total revenue, less the commodity (such as excluding Generation Services Charge revenue for UI), payroll, and net plant-in-service plus construction work in progress. Ex. UI-RRP-1, p. 36. UI further allocates its costs between...

AI summary The document discusses how UI allocates its costs between distribution and transmission business segments, including the use of FERC-approved allocations for determining revenue requirements and wage allocators. It highlights the inclusion of various rate mechanisms in the distribution wage allocator calculation.

POWER DISTRIBUTION The majority of the distribution system consists of overhead lines supported by wooden poles that crisscross the streets of every town and city in Québec, delivering power to homes, public and commercial buildings, indus...

AI summary The distribution system in Québec primarily uses overhead lines on wooden poles to deliver power across towns and cities, with only a small portion of medium-voltage lines being underground, mainly in urban areas.

DESCRIPTION When a wooden pole is added to the distribution system, it has an expected useful service life of 60 years. However, certain complications—such as rot, woodpeckers making holes in search of food or shelter, and infestations of...

AI summary Wooden poles in the distribution system have a 60-year lifespan, but factors like rot, woodpeckers, carpenter ants, and extreme weather can cause premature failure. Rising temperatures and expanding wildlife populations increase these risks.

Distribution system - More than 270,000 vegetation control actions (pruning, clearing and logging) and 20,000 customer visits are carried out each year. - Distribution lines are currently cleared on average every six years. - From 2016 to...

AI summary The distribution system involves extensive vegetation control actions and customer visits annually. Distribution lines are cleared every six years on average, and from 2016 to 2020, vegetation caused an average of 8,612 power outages per year in medium and low-voltage systems.

12. Adapt vegetation control to the increased growth of certain species ( cont'd ) Action Implementation Progress Other action areas affected Increase budgets and resources to carry out the integrated vegetation control program In progress...

AI summary The document discusses actions related to adapting vegetation control strategies to address the increased growth of certain tree species, including budget increases, scaling up felling programs, and participating in research projects. These measures aim to reduce power outages and improve service continuity.

FURTHER INFORMATION - In 2020, Hydro-Québec had 1,295 employees working on distribution lines. - During this same year, they spent an average of 30% to 35% of their time repairing breakages and resolving power outages.

AI summary In 2020, Hydro-Québec had 1,295 employees working on distribution lines, with 30% to 35% of their time spent on repairs and outage resolution.

Zero–Intercept Method The Zero-Intercept Method assumes that a portion of the upstream distribution system is customer-related rather than entirely demand-related. The Zero-Intercept Method uses a statistical calculation to determine the a...

AI summary The Zero-Intercept Method is a statistical approach used to allocate distribution costs between customer-related and demand-related components. It involves creating a regression curve based on installed costs and demand ratings, extending it to a no-load intercept, and identifying the customer component. While the 2003 Working Group raised concerns about its complexity, some Canadian utilities have successfully applied it.

6.2.1 Background There are several technical factors to consider when allocating the demand-related component of distribution facilities. Some distribution facilities are designed to meet the individual customer's maximum demand, while oth...

AI summary The text discusses technical considerations for allocating demand-related costs in distribution facilities, distinguishing between coincident and non-coincident peak methods. It highlights how different types of facilities use varying demand metrics for design and cost allocation.

Combination of Methodologies It is recommended that all distributors employ the following combination of methodologies in their filings to allocate joint demand-related costs: - CP may be used to allocate the costs of some substations and...

AI summary The document recommends a combination of methodologies for allocating joint demand-related costs in distribution filings. CP is suggested for certain substations and high-voltage conductors, NCPI for secondary conductors and transformers, and NCPC for remaining distribution assets.

Individual Customer NCP vs. Class NCP Class NCP represents the non-coincident demand for each customer class and is determined by considering all of the customers in the class as one service point. Individual customer NCP represents the su...

AI summary The text discusses the difference between individual and class NCP in the context of distribution system planning. It explains that individual NCP, which considers each customer's maximum demand, is more appropriate for secondary line transformers and conductors due to less diversity. Class NCP is more suitable for larger transformers in dense areas.

Distribution Costs The distribution costs that could be functionalized and categorized as being customerrelated costs include the following major categories: - line transformers - primary lines - secondary lines - services The customer-rel...

AI summary The document outlines customer-related distribution costs, including line transformers, primary and secondary lines, and services. Allocation methods are discussed, such as using the number of customers or weighted services to account for varying customer needs.

Appendix 1 – Direct Assignment of Accounts Appendix 1 - Direct Assignment of Accoun its USoA Account # Accounts Direct Assignment Distribution Plant 1875 Street Lighting and Signal Systems х General Plant 1965 Water Heater Rental Units х 1...

AI summary This document outlines the direct assignment of accounts related to distribution plant and customer account expenses, including specific account numbers and their allocations. It also includes a table detailing the functionalization of selected accounts across various categories such as distribution, metering, and customer services.

3.6.3 Filing Questions - 1) Indicate the number of customers in the distributor's service territory that have load displacement generation equipment above 500 kW. - 2) To the extent the distributor has the information available, categorize...

AI summary The filing questions focus on load displacement generation (LDG) equipment, requiring the distributor to report customer numbers, categorize facilities by size and type, assess data representativeness, and explain steps taken to evaluate diversity in Run 3 modeling.

Functional Approach The bulk, primary and secondary sub-accounts relate to assets associated with performing bulk, primary and/or secondary functions within a distribution system. The key objective of the cost allocation is to allocate cos...

AI summary The document discusses the 'functional approach' for allocating distribution costs based on the functions of bulk, primary, and secondary assets. It emphasizes the importance of cost causality and simplicity in the allocation method, noting that a voltage-based test is not universally applicable. The Board concludes that a functional approach best identifies bulk assets.

6.2.2.4 Direction – Definition of Secondary For this function, a voltage-based definition will be adopted: the secondary subaccounts will cover all assets owned by the distributor operating at <750V, whether financed through contributed ca...

AI summary The document defines the secondary subaccounts based on a voltage-based criterion, covering all assets owned by the distributor operating at less than 750V, regardless of whether they are financed through contributed capital or rates.

6.2.2.6 Filing Questions – Supporting Distribution System Information - 1. The Filing Summary should explain how the distributor applied the Board's bulk asset test to its system, and why it concluded it did or did not have bulk assets. -...

AI summary The document outlines requirements for distributors to explain the application of the Board's bulk asset test, include a single line diagram of their distribution system, and identify bulk assets along with the customers they serve.

6.4.2 Direction – Treatment of >50kV Assets Deemed to be Distribution In order to establish a consistent approach in understanding the pure distribution costs associated with each rate classification within a distributor, costs associated...

AI summary The document outlines a directive for the treatment of >50kV assets in distribution cost filings, requiring that costs associated with these assets be identified and shown separately. This ensures clarity in understanding pure distribution costs for each rate classification.

6.5.1 Background A customer that is connected to a distributor's secondary assets will use the distributor's line transformer assets to step-down the voltage to the supply voltage of the secondary assets. Assuming all customers connected t...

AI summary This section explains how line transformer assets are allocated when customers have their own secondary lines but use the distributor's line transformers. Allocation depends on the number of customers and NCP load, which may differ from the allocation method used for secondary assets.

General Service and Large Uses These installations are varied and can include transformation and other distribution plant.

AI summary The text discusses installations related to General Service and Large Uses, which can include transformation and other distribution plant. No specific arguments or entities are mentioned.

Option 1: Zero Intercept Method The zero intercept method uses a statistical calculation to determine the amount of distribution costs that should be categorized as customer-related versus demand related. The zero intercept method seeks to...

AI summary The zero intercept method is a statistical approach to allocate distribution costs between customer-related and demand-related components by analyzing installed costs and capacity ratings. However, due to its complexity and interpretive challenges, it will not be used as the filing methodology for distributors.

7.4.2.1 Background – Past Ontario Studies Past Ontario minimum system results were reviewed in detail. Some of the individual studies examined were undertaken as far back as the mid-1980's. Consultations indicated that the cost causality f...

AI summary Past Ontario studies on minimum system results, dating back to the mid-1980s, are reviewed and considered still useful due to stable cost causality features in distribution system design. Medium and high density results are based on multiple studies, while rural density results come from a single older Ontario Hydro study.

7.4.2.2 Direction – Generic Minimum System Results in Filings The following generic categorization percentages will be built into the filing model: Low-density distributor: line transformers 60% customers/40% demand distribution 60% custom...

AI summary The document outlines the distribution of categorization percentages for low-, medium-, and high-density distributors, specifying the proportion of customers and demand for line transformers and distribution systems.

7.4.3 Filing Questions The Board is interested in understanding certain factors that could impact interpretation of the minimum system results. The following filing questions must be answered: - If the distributor is an urban utility, does...

AI summary The Board is seeking information on the distributor's system characteristics, including the presence of large downtown secondary networks, significant underground systems, and factors affecting the accuracy of low density generic minimum system results.

8.3.2 Direction - Tests for Use of CP in Filings For distribution assets and related O&M accounts that are solely designed to meet the distributor's system demand, CP will be used as the demand allocator. For the filings, this will consist...

AI summary This section outlines the use of Coincident Peak (CP) as a demand allocator for distribution assets and related O&M accounts designed to meet system demand. It specifies that CP will be subdivided into transmission transformation CP (TCP) and distribution CP (DCP), and describes how the choice between 1 CP, 4 CP, or 12 CP will be determined through a test incorporated into the filing model.

Distribution and General Plant Unmetered Scattered Load customers will bear the full allocated costs of distribution facilities (and associated depreciation), with the exclusion of Load Management Controls – Customer Premises (Account 1970...

AI summary Unmetered Scattered Load customers are responsible for the full allocated costs of distribution facilities, excluding Load Management Controls and Meters. Test meters installed on USL as part of a verification program must have their costs allocated to USL.

11.5.2.1 Background The LDG rate classification to be modeled refers to charges imposed by a distributor for distribution services provided to a customer with load displacement generation behind the customer's meter. The load displacement...

AI summary This section discusses the LDG rate classification, which applies to customers with load displacement generation behind their meter. The classification involves allocating distribution costs for both base load and incremental load when the generator is not operating. The section also mentions concerns about load data availability and reliability for these customers.

Future Rate Design Steps The LDG-specific unit costs calculate above will be one of the items of information to be available and considered when designing and implementing new LDG rates. The unit costs calculated here should not be interpr...

AI summary The document discusses future rate design steps for LDG customers, emphasizing that LDG-specific unit costs will inform new rate design. It clarifies that these costs are not proxies for standby distribution rates and mentions a forthcoming Distribution Rate Design Review to examine various rate options.

11.5.5.4 Potential Further Adjustments in Run 3 If any other significant additional distribution system benefits or costs can be identified and quantified at this time by a distributor following its review of Appendix 11.1 (i.e. outside of...

AI summary The text discusses the possibility of including additional distribution system benefits or costs identified during the review of Appendix 11.1 in a Run 3 of the model, provided they are significant and can be quantified. This would be submitted with an explanation in the distributor's Filing Summary.

11.5.8.1 Background A merchant generator is defined to be a generator that provides a significant amount of its generation into the distribution system and also provides the generation required to support its own electricity needs. When th...

AI summary A merchant generator provides power to the distribution system and its own needs. When it is shut down, the distribution system must support its load and provide power to restart it. This should be considered in cost allocation and discussed in the distributor's Filing Summary, though the report will not address distribution rates for merchant generation further.

11.5.9 Hybrid Facilities There is also the situation where a generator is providing load displacement generation but also has significant generation above the customer's load. In this case the generator is performing a "hybrid" role of loa...

AI summary The document discusses hybrid facilities where generators provide both load displacement and merchant generation. It notes that distribution rates for these facilities are not further addressed but suggests that appropriate unit costs for such facilities in the 2006 test year can be modeled using optional Run 3 of the model. Distributors are advised to document their approach and any cost allocation methods used.

Option 3: Basic Connection In this option, the basic customer cost would include the basic connection costs as defined in the Distribution System Code in addition to the customer related costs identified in Option 2. Setting the floor at t...

AI summary Option 3 proposes a basic customer cost that includes connection costs from the Distribution System Code and customer-related costs from Option 2. However, it will not be modeled due to the narrow range of reasonableness it would establish for customer unit costs.

- Newbury Power Inc. Rate Classification - Residential Data Requirements 6. Street Lights Use distributor's OEB approved load profile. 6a. Street Lights TOU It is assumed there is an approved load profile. 7. Sentinel Lights Use distributo...

AI summary The document outlines data requirements for various rate classifications, including street lights and unmetered scattered loads, specifying the use of approved load profiles and special rate design methods.

The following is an example that assumes the distributor has a bulk system that does not provide service equally to all customers and includes the following customer characteristics for Residential, General Service < 50 kW, General Service...

AI summary The text outlines an example scenario involving a distributor with a bulk system that does not provide uniform service to all customers, highlighting different customer classifications such as Residential, General Service < 50 kW, General Service > 50 kW, and Large Use.

The following outlines the resulting numbers of customers using the various asset groupings, for Example 3: Class Bulk Primary Secondary Residential 500 1,000 1,000 General Service <50 kW 250 500 500 General Service >50 kW 50 100 50 Large...

AI summary The text provides a table outlining the number of customers associated with various asset groupings, categorized by class, bulk, primary, and secondary. It includes details on different types of equipment, stations, and infrastructure relevant to distribution and transmission systems.

Filing Question: Load Displacement Customers - Further Potential Distribution Cost Savings or Burdens When completing Run 1 and Run 2 of the filing, all distributors with load displacement customers should review the below list to ascertai...

AI summary The filing question addresses potential distribution cost savings or burdens associated with load displacement customers. It outlines cost reductions and potential burdens, such as deferred asset commissioning, reduced line losses, and increased system flexibility, as well as unknown impacts like voltage stability concerns.

ALLOCATION OF AVERAGE DISTRIBUTION RATE BASE (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL INDUSTRIAL (7) MEDIUM INDUSTRIAL (8) LARGE INDUSTRIAL (9) PHP (10) MUNICIPAL (11) UNMETERED (12) ALLOCATI...

AI summary The document presents a detailed breakdown of the allocation of the average distribution rate base across various categories, including total company, domestic, small general, general, large, small industrial, medium industrial, large industrial, PHP, municipal, and unmetered. Allocation factors are also listed for each category.

ANALYSIS OF AVERAGE OVERHEAD WIRE INVESTMENT (1) TOTAL PLANT (2) PRIMARY DEMAND (3) PRIMARY CUSTOMER (4) SECONDARY DEMAND (5) SECONDARY CUSTOMER (1) FACTORS 1.000 0.493 0.302 0.034 0.171 (2) TOTAL NET WIRE COST $173,434 $85,503 $52,377 $5,...

AI summary The document presents an analysis of average overhead wire investment, including factors and total net wire costs for different categories of plant and customer demand. The table provides numerical data on primary and secondary demand and customer segments.

FOR THE YEAR ENDING DECEMBER 31, 2026 (IN THOUSANDS OF DOLLARS) (1) TOTAL EXPENSES (2) PROD. EXPENSES (3) TRANS. EXPENSES (4) DIST. EXPENSES (5) RETAIL EXPENSES (6) DIRECT EXPENSES (7) ALLOCATION FACTOR (55) Transmission - EHV and HV combi...

AI summary The document presents a detailed breakdown of expenses related to transmission and distribution for the year ending December 31, 2026, categorized into various components such as EHV and HV combined, easements, substations, poles, and line transformers, with allocation factors provided for each category.

FUNCTIONALIZATION OF OPERATING EXPENSES (1) SHORE POWER (2) GEN.REPL LOAD FOLL. (3) ELIADC (4) BUTU (5) SPILL (6) PRICING (6) REAL TIME REAL TIME REAL TIME PRICING (6) PRICING (7) OATT (8) TOTAL BTL (34) COGS - - (35) (36) DSM EXPENSES - -...

AI summary The text presents a table detailing the functionalization of operating expenses, including categories such as COGS, DSM expenses, FCR deferral, and depreciation across various assets like steam, hydro, wind, solar, and transmission and distribution infrastructure.

CLASSIFICATION OF OPERATING EXPENSES (1) TOTAL COMPANY (2) DEMAND EXPENSES (3) ENERGY EXPENSES (4) CUSTOMER EXPENSES DISTRIBUTION FUNCTION (1) Before Streetlights: (2) SUBSTATIONS $2,076 $2,076 $0 - (3) OVERHEAD LINES Before Storm Expense...

AI summary The document presents a detailed breakdown of operating expenses categorized into demand, energy, and customer expenses for a utility company. It includes depreciation, interest, taxes, and other financial figures related to distribution functions, such as substations, overhead lines, and underground lines.

ALLOCATION OF DISTRIBUTION OPERATING EXPENSES (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL INDUSTRIAL (7) MEDIUM INDUSTRIAL (8) LARGE INDUSTRIAL (9) PHP (10) MUNICIPAL (11) UNMETERED (12) ALLOCAT...

AI summary The text presents a detailed table outlining the allocation of distribution operating expenses across various categories and customer segments, including overhead and underground lines, meters, customer service, and substations, with allocation factors and exhibit references provided.

(1) (2) (3) (4) (5) (6) (7) (8) (9) (10) (11) (12) (13) (14) (15) (16) (17) (18) REVENUE TO COST RATIOS STORM COSTS STORM REVENUE NON-FUEL NON-FUEL DISTRIBUTION TRANSMISSION (HV) TRANSMISSION (EHV) GRAND TOTAL GRAND TOTAL COSTS REVENUE(1)...

AI summary The text presents a detailed table showing revenue to cost ratios for various customer classes, including domestic, general, industrial, and municipal, alongside storm costs and revenues. It outlines distribution and transmission costs and revenues, with some entries marked as 'NA' for certain categories.

CLASS : SMALL GENERAL CLASS : SMALL GENERAL RATE BASE COSTS (Source Exh 6) (Source Exh. 3) Variable Fuel Operating Capital Fixed Return Total Total Cost Units Sold Demand Unit Cost Energy Customer Generation (1) Usage (Energy) $51,988 $25,...

AI summary The document presents a detailed breakdown of costs and revenues related to energy generation, transmission, distribution, and retail operations. It includes various cost components such as fuel, operating, capital, and fixed return, along with unit costs and total costs for different segments of the energy system.

CLASS : GENERAL RATE BASE COSTS (Source Exh 6) (Source Exh. 3) Variable Fixed Unit Cost Fuel Operating Capital Return Total Total Cost Units Sold Demand Energy Customer Generation (1) Usage (Energy) $325,478 $157,616 $16,053 $23,257 $11,42...

AI summary The document presents a detailed breakdown of costs associated with energy generation, transmission, distribution, and retail operations. It includes various line items such as fuel, operating, capital, and return costs, along with unit costs and total costs for different segments of the electricity system.

CLASS : LARGE GENERAL CLASS : LARGE GENERAL RATE BASE COSTS (Source Exh 6) (Source Exh. 3) Variable Fixed Unit Cost Fuel Operating Capital Return Total Total Cost Units Sold Demand Energy Customer Generation (1) Usage (Energy) $51,210 $24,...

AI summary The document presents a detailed breakdown of costs associated with energy generation, transmission, distribution, and retail services for a large general class. It includes various cost categories such as fuel, operating, capital, and return, along with unit costs and total expenses for different segments of the energy system.

CLASS : PHP RATE BASE COSTS (Source Exh 6) (Source Exh. 3) Variable Fixed Unit Cost Fuel Operating Capital Return Total Total Cost Units Sold Demand Energy Customer Generation (1) Usage (Energy) $112,866 $54,977 $5,463 $8,065 $3,962 $17,49...

AI summary This table outlines the rate base, costs, and unit costs for various components of the energy system, including generation, transmission, distribution, and retail activities. It provides detailed breakdowns of variable and fixed costs, total costs, and unit costs for different categories such as energy and demand.

FOR THE YEAR ENDING DECEMBER 31, 2026 (1) TOTAL (2) PROD. (3) TRANS. (4) DIST. (5) RETAIL (6) DIRECT (7) (14) PROCUREMENT % RESPONSIBILITY 100.0% 25.0% 25.0% 25.0% 25.0% F - 5 LABOUR-RELATED O&M EXPENSES BY FUNCTIONAL (15) O&M EXPENSES BY...

AI summary The document presents a detailed breakdown of procurement responsibilities and operational expenses by functional areas for the year ending December 31, 2026. It includes percentages of responsibility for procurement, labor-related O&M expenses, and distribution of costs across generation, transmission, distribution, and retail functions.

FOR DECEMBER 2026 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTE...

AI summary The table provides data for December 2026, including energy sales, losses, demand factors, and other metrics related to electricity distribution and system performance.

(IN THOUSANDS OF DOLLARS) FOR THE YEAR ENDING DECEMBER 31, 2026 Calendar Month of System Peak 1 January February March April May June July August September October November December Total (79) PHP INTERRUPTIBLE COINCIDENT DEMAND AT GENERA...

AI summary The document presents a table with financial data in thousands of dollars for the year ending December 31, 2026, covering various demand and loss factor adjustments across different voltage levels and categories, including PHP interruptible coincident demand, domestic, small general, and general demand line loss adjustments.

(IN THOUSANDS OF DOLLARS) (1) TOTAL EXPENSES (2) PROD. EXPENSES (3) TRANS. EXPENSES (4) DIST. EXPENSES (5) RETAIL EXPENSES (6) DIRECT EXPENSES FCR DEFERRAL OTHER EXPENSES 0 0 0 0 0 0 (52) GRANTS IN LIEU OF TAXES DEPRECIATION: 51,549 21,165...

AI summary The table provides a detailed breakdown of expenses across various categories, including depreciation, steam, hydro, wind, solar, and transmission and distribution costs. It includes figures for different types of expenses such as production, transmission, distribution, and retail expenses, with specific amounts listed for each category.

NOVA SCOTIA POWER INC. (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL INDUSTRIAL (7) MEDIUM INDUSTRIAL (8) LARGE INDUSTRIAL (9) PHP (10) MUNICIPAL (11) UNMETERED (12) ALLOCATION FACTOR (29) (30) TO...

AI summary The document provides a table with various categories of generation and transmission data for Nova Scotia Power Inc., including total company generation, domestic generation, and transmission at high voltage. The table includes multiple columns with different classifications of generation and allocation factors.

NOVA SCOTIA POWER INC. DEVELOPMENT OF ALLOCATION FACTORS EXPENSES EXPENSES EXPENSES EXPENSES EXPENSES EXPENSES ALLOCATOR (1) LABOUR O&M excluding HR, IT, PR, OTHER and direct 201,366 87,716 22,048 57,505 34,097 - (2) % RESPONSIBILITY 100.0...

AI summary The document presents a table detailing the allocation of expenses and responsibilities for Nova Scotia Power Inc., including labor, revenue requirements, net plant in service, and procurement percentages across various categories such as production, transmission, and distribution.

FOR DECEMBER 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTE...

AI summary The document presents a table with various energy metrics for December 2027, including energy sales, losses, demand, and system factors. It outlines key parameters related to energy generation, distribution, and system performance.

DETAILED LISTING OF C.O.S.S. INPUT INFORMATION FOR THE YEAR ENDING DECEMBER 31, 2027 (227) POWER PRODUCTION - FUEL (228) POWER PRODUCTION - OPERATING & MAINT. 366,094.3 (277) (278) TRANSMSSION (279) Transmission - HV 0 0.0 0.0 0 0 0 0 (280...

AI summary The document provides a detailed listing of C.O.S.S. input information for the year ending December 31, 2027, including various categories related to power production, transmission, and distribution with associated costs and figures.

FOR THE YEAR ENDING DECEMBER 31, 2027 (IN THOUSANDS OF DOLLARS) Calendar Month of System Peak 1 January February March April May June July August September October November December Total (25) LINE LOSSES - INDUSTRIAL LARGE 2,171 1,951 2,0...

AI summary The document presents line losses data for industrial large customers across calendar months for the year ending December 31, 2027, with values provided in thousands of dollars. The data shows fluctuations in losses throughout the year, peaking in November and reaching a low in December.

JAMES B. YATES, P.ENG. SENIOR STRUCTURAL/CIVIL ENGINEER - x Design of replacement pipeline and penstock for Berwick Electric's hydroelectric generating station. - x Design of remediations and repairs to Middle River dam and sluiceway for t...

AI summary James B. Yates, P.Eng., a senior structural and civil engineer, has extensive experience in designing and overseeing infrastructure projects related to hydroelectric and thermal generation stations, dam remediations, and various civil engineering works across Nova Scotia and beyond.

18 3.10.4 Distribution Tariff 19 Further to the commitment NS Power made in response to Renewall IR-7 (noted in Section 3.9), 16 Attachment 01K (beginning on PDF page 32) and 02K (beginning on PDF page 146). - 20 the main body of the Distr...

AI summary The Distribution Tariff is extended to potential RTR transmission-connected customers, with the main body of the tariff and its rates outlined in specific attachments. This follows NS Power's commitment in response to Renewall IR-7.

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

AI summary Special conditions outline customer responsibilities for metering, service provisions, and load management to maintain power supply integrity. Customers may need to contribute to capital costs for primary metering or own transformers. Load must not negatively impact system reliability or stability.

In this Distribution Tariff, the following terms shall have the following meanings: Act : The Electricity Act , S.N.S. 2004, c. 25, as amended from time to time. Ancillary Services : Services that are necessary to support the transport of...

AI summary This section of the Distribution Tariff defines key terms used throughout the document, including 'Act', 'Ancillary Services', 'Board', 'Bundled Service', 'Customer Information', 'Demand Side Management Recovery Charges', 'Distribution System', 'Distribution System Access', 'Distribution Tariff', 'Distribution Tariff Rate Schedules', 'DT Charges', and 'Good Utility Practice'.

3. SCOPE OF THE DISTRIBUTION TARIFF The Distribution Tariff is applicable to all RtR Customers connected to the Distribution System. This Distribution Tariff is not applicable to RtR Customers directly connected to the Transmission System...

AI summary The Distribution Tariff applies to all RtR Customers connected to the Distribution System, excluding those directly connected to the Transmission System, which must arrange access under the OATT. The tariff outlines terms and conditions for Distribution System Access and retail services.

8. RTR CUSTOMER RESPONSIBILITIES The RtR Customer shall be responsible for: - (a) payment of all fees and charges arising in connection with the Distribution Tariff; - (b) compliance with the terms and conditions of the Distribution Tariff...

AI summary The RtR Customer is responsible for paying fees related to the Distribution Tariff, complying with its terms, obtaining renewable low-impact electricity from an LRS, and managing all contractual arrangements with an LRS.

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

AI summary NS Power is responsible for providing, installing, and sealing revenue class meters for RtR Customers under the Distribution Tariff. The meters must have remote polling capability and comply with the Electricity and Gas Inspection Act regulations. Ownership of the meters and associated equipment remains with NS Power, and metering requirements are detailed in NS Power Regulations Section 4 - Metering.

11.3 Real Power Losses Distribution System Real Power Losses associated with Distribution System Access are incorporated in the Distribution Tariff rates applicable to each RtR Customer's rate class. The RtR Customer is responsible for the...

AI summary Real power losses in the distribution system are included in the distribution tariff rates for each rate class. The responsibility for these costs falls on the RtR Customer.

APPLICABILITY This schedule provides charges for Distribution System Access applicable to distribution-connected Renewable to Retail (RtR) Customers receiving supply of renewable low-impact electricity from a Licenced Retail Supplier as pr...

AI summary This schedule outlines charges for Distribution System Access applicable to Renewable to Retail (RtR) Customers in Nova Scotia, as defined under the Electricity Act.

9. INTERRUPTION OF DISTRIBUTION SYSTEM ACCESS Notwithstanding any term of this Distribution Tariff, NS Power shall have the right to suspend or interrupt, in whole or in part, the provision of Distribution System Access for the purpose of...

AI summary NS Power may suspend or interrupt distribution system access for safety, repairs, or improvements, provided they make reasonable efforts to minimize disruption. Customers remain obligated to pay charges during interruptions and resume service once available.

APPLICABILITY This schedule provides charges for Distribution System Access applicable to distribution-connected Renewable to Retail (RtR) Customers receiving supply of renewable low-impact electricity from a Licenced Retail Supplier as pr...

AI summary This schedule outlines charges for Distribution System Access applicable to Renewable to Retail (RtR) Customers in Nova Scotia, who receive renewable low-impact electricity from a licensed retail supplier under the Electricity Act .

COMPARISON OF REVENUE TO EXPENSE RATIOS 1 FUNCTIONALIZATION OF AVERAGE RATE BASE 2 INITIAL CLASSIFICATION OF AVERAGE RATE BASE 2A FINAL CLASSIFICATION OF AVERAGE RATE BASE 2B ALLOCATION OF AVERAGE RATE BASE 3 ALLOCATION OF AVERAGE DISTRIBU...

AI summary The document outlines various sections related to the analysis of revenue and expense ratios, functionalization of rate bases, classification and allocation of investments in distribution infrastructure, and the breakdown of operating expenses. It includes detailed sections on transmission, distribution, customer service, credit services, depreciation, and storm-related expenses.

953,610 953,610 0 0 (20) (21) TOTAL TRANSMISSION FUNCTION $953,610 $953,610 $0 $0 (22) (23) DISTRIBUTION FUNCTION (24) (25) DISTRIBUTION PLANT: (26) LAND 5,052 2,664 0 2,388 (27) EASEMENTS & SURVEY 177,554 93,631 0 83,922 (28) OTHER 17,970...

AI summary The text presents a detailed breakdown of transmission and distribution costs, including land, easements, substations, poles, lines, and other infrastructure components. It also includes general property plant and working capital figures, reflecting the financial structure of the utility's assets.

19,878 13,425 2,378 2,650 912 513 (33) (34) CUSTOMER OPERATIONS (35) TRANSMISSION & DISTRIBUTION: (36) TRANSMISSION: (37) HV BEFORE STORM EXPENSES (not applicable as a separate item) 0 - 0 - - 0 (38) HV STORM EXPENSES (not applicable as a...

AI summary The text presents a series of line items related to customer operations, transmission, and distribution expenses, including HV and EHV storm expenses, with numerical values and some notes about inapplicability as separate items.

(42) DISTRIBUTION: (43) SUBSTATIONS 1,478 - - 1,444 - 34 (44) OVERHEAD LINES BEFORE STORM EXPENSES 33,736 - - 32,969 - 767 OVERHEAD LINES STORM EXPENSES 22,491 - - 21,979 - 511 (45) UNDERGROUND LINES 579 - - 566 - 13 (46) LINE TRANSFORMERS...

AI summary The document presents a detailed breakdown of distribution and customer operations expenses, including substation costs, overhead and underground line expenses, and street lighting. It also includes generation services and customer service costs, highlighting various line items and their associated figures.

8,575 8,351 - - - 223 (53) RADIAL TO GENERATION TRANS. 3,169 3,086 - - - 83 (54) Transmission - HV (not aplicable as a separate item) 0 - 0 - - 0 (55) Transmission - EHV and HV combined 26,220 - 25,397 - - 823 (56) DISTRIBUTION - Land - -...

AI summary The text presents a detailed breakdown of various costs related to electrical transmission and distribution systems, including radial to generation transfer, high voltage transmission, and various distribution components such as easements, substations, poles, and lines.

2,886 - 67 (63) DISTRIBUTION -Line Transformers 28,382 27,737 - 645 (64) DISTRIBUTION -Services 4,147 4,053 - 94 (65) DISTRIBUTION -Meters 8,124 7,940 - 185 (66) DISTRIBUTION - Streetlight Related 4,585 - - 4,480 - 104 (67) GENERALPROPERTY...

AI summary The text presents a series of line items and financial figures related to distribution, general property, and interest net, including amounts for various categories such as line transformers, meters, and streetlight-related expenses, as well as write-offs and interest net figures.

(42) DISTRIBUTION: (43) SUBSTATIONS 1,444 - - 1,444 - 0.0% 0.0% 0.4% 0.0% (44) OVERHEAD LINES BEFORE STORM EXPENSES 32,969 - - 32,969 - 0.0% 0.0% 10.0% 0.0% OVERHEAD LINES STORM EXPENSES 21,979 - - 21,979 - 0.0% 0.0% 6.7% 0.0% (45) UNDERGR...

AI summary The text presents a detailed breakdown of distribution costs, including substation, overhead lines, underground lines, and street lighting expenses. It shows figures for 2020 and 2021, along with percentages and variances, highlighting a significant increase in overhead line storm expenses.

- 4,053 - 0.0% 0.0% 1.2% 0.0% (65) DISTRIBUTION -Meters 7,940 - - 7,940 - 0.0% 0.0% 2.4% 0.0% (66) DISTRIBUTION - Streetlight Related 4,480 - - 4,480 - 0.0% 0.0% 1.4% 0.0% (67) GENERALPROPERTY:FUNCTIONILIZED 13,267 - 397 6,620 6,251 0.0% 0...

AI summary The document presents a table with various line items related to distribution, general property, and corporate taxes, including figures for different categories and percentages. It includes entries such as meters, streetlight-related costs, and general property classifications, with associated financial data.

(42) DISTRIBUTION: - (43) SUBSTATIONS - 34 (44) OVERHEAD LINES BEFORE STORM EXPENSES - 767 OVERHEAD LINES STORM EXPENSES - 511 (45) UNDERGROUND LINES - 13 (46) LINE TRANSFORMERS - - (47) METERS (Meter Shop Only) - - (48) COMMUNICATIONS - -...

AI summary The text lists various distribution-related line items and their associated costs, including overhead lines, underground lines, and street lighting, with specific monetary values provided for some entries.

0 0 (55) Transmission - EHV and HV combined 81 823 (56) DISTRIBUTION - Land - - (57) DISTRIBUTION - Easements - 70 (58) DISTRIBUTION - Other - 31 (59) DISTRIBUTION - Substations - 206 (60) DISTRIBUTION - Poles and Fixtures - 476 (61) DISTR...

AI summary The text presents a list of line items related to transmission and distribution costs, including categories such as EHV and HV combined, land, easements, substations, poles and fixtures, and overhead and underground lines. Specific cost figures are provided for some categories.

67 (63) DISTRIBUTION -Line Transformers - 645 (64) DISTRIBUTION -Services - 94 (65) DISTRIBUTION -Meters - 185 (66) DISTRIBUTION - Streetlight Related - 104 (67) GENERALPROPERTY:FUNCTIONILIZED 4 273 (68) GENERALPROPERTY:DISTRIBUTION/ TRANS...

AI summary The text lists various categories and associated costs related to distribution, general property, and interest net, including line transformers, meters, and communication systems, with specific numerical values provided for each category.

uirement 382,310 (6) kW 3 CP 222,264 (7) kW 12 NCP 748,952 (8) Unit Cost (cents/kW.h) 8.661 1.351 1.998 0.841 4.190 12.851 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 353,434 0.000 (10) Delivery Trans.(Eng) -...

AI summary The text presents a detailed breakdown of costs related to transmission and distribution, including line items for high voltage (HV) and extra high voltage (EHV) transmission, demand-related delivery, and customer delivery costs. It outlines specific figures for different categories and includes unit costs and totals.

ement 2,393,511 (6) kW 3 CP 1,206,116 (7) kW 12 NCP 4,096,798 (8) Unit Cost (cents/kW.h) 8.445 1.260 1.866 0.795 3.921 12.366 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 2,219,406 0.000 (10) Delivery Trans.(E...

AI summary The text presents a detailed breakdown of costs associated with transmission and distribution systems, including line items such as delivery, transmission, and distribution expenses, with specific figures provided for various categories and subcategories.

ement 376,587 (6) kW 3 CP 137,482 (7) kW 12 NCP 638,846 (8) Unit Cost (cents/kW.h) 7.897 1.060 1.598 0.699 3.356 11.253 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 358,568 0.000 (10) Delivery Trans.(Eng) - EH...

AI summary The text presents a breakdown of costs related to transmission and distribution, including line items such as delivery, demand, and customer costs. It includes figures for various categories like HV and EHV transmission and distribution, with associated monetary values and unit costs provided in cents per kW.h.

uirement 274,652 (6) kW 3 CP 123,550 (7) kW 12 NCP 488,281 (8) Unit Cost (cents/kW.h) 8.320 1.199 1.775 0.764 3.738 12.058 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 255,142 0.000 (10) Delivery Trans.(Eng) -...

AI summary The text provides a detailed breakdown of costs related to transmission and distribution, including line items such as delivery, demand, and customer-related expenses. It includes figures for various voltage levels (HV, EHV) and associated costs in cents per kW.h and dollar amounts.

uirement 467,931 (6) kW 3 CP 158,818 (7) kW 12 NCP 694,524 (8) Unit Cost (cents/kW.h) 7.945 1.050 1.582 0.696 3.327 11.272 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 438,585 0.000 (10) Delivery Trans.(Eng) -...

AI summary The document contains a table with various costs related to transmission and distribution, including delivery costs for different voltage levels and demand categories. The table includes figures for different line items such as transmission, distribution, and demand, with associated monetary values and unit costs.

nt 829,996 (6) kW 3 CP 203,227 (7) kW 12 NCP 2,205,388 (8) Unit Cost (cents/kW.h) 7.371 0.912 0.618 0.617 2.147 9.519 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 810,547 0.000 (10) Delivery Trans.(Eng) - EHV...

AI summary The text provides numerical data related to transmission and distribution costs, including line items for different voltage levels and demand categories. It includes figures for delivery, transmission, and distribution costs, with specific values for various line items and totals.

ement 128,550 (6) kW 3 CP 93,931 (7) kW 12 NCP 288,787 (8) Unit Cost (cents/kW.h) 8.589 1.414 2.139 0.883 4.435 13.024 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 124,528 0.000 (10) Delivery Trans.(Eng) - EHV...

AI summary The text presents a detailed breakdown of costs related to transmission and distribution, including line items such as delivery, transmission, and distribution costs, with specific figures for different categories and time periods.

11,303,785 (6) kW 3 CP 9,225,751 (7) kW 12 NCP 22,327,201 (8) Unit Cost (cents/kW.h) 8.626 1.342 1.845 0.844 4.030 12.656 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 10,548,590 0.000 (10) Delivery Trans.(Eng)...

AI summary The text presents numerical data related to energy delivery, including transmission and distribution costs, unit costs, and various line items categorized under different voltage levels and demand types. It includes figures for delivery, transmission, and distribution costs, as well as unit costs in cents per kW.h.

0 0 0 (25) (26) TOTAL ENERGY 62,503 31,212 2,114 13,235 2,082 1,519 2,587 3,993 4,589 711 460 (27) (28) CUSTOMER CLASSIFICATION (29) (30) DISTRIBUTION FUNCTION (31) DISTRIBUTION - Land 0 0 0 0 0 0 0 0 0 0 0 P-12 (32) DISTRIBUTION - Easemen...

AI summary The text presents a financial table with various categories and subcategories related to energy distribution, including distribution functions, land, easements, poles, and lines. It includes numerical data and references to property-related items such as P-12.

INCIDENT LINE COIN. PEAK COINCIDENT SALES LOSSES REQUIREMENT DMD. (KW) FACTOR DMD. (KW) LOSSES DMD. (KW) L/D FACTOR ( 1) DOMESTIC 319,746 7.69% 344,330 650,001 90.3% 587,067 8.34% 636,042 72.76% ( 2) SMALL GENERAL 26,458 7.64% 28,480 59,02...

AI summary The document presents a detailed breakdown of electricity demand, sales, losses, and requirement factors across various customer categories, including domestic, industrial, and municipal sectors. It includes data on peak demand, coincident sales, and losses, with a sub-total for all categories. Specific programs and systems, such as Shore Power and ELIADC, are also listed.

12.05% REDACTED (CONFIDENTIAL INFORMATION REMOVED) REDACTED 2026-2027 GRA Compliance Filing - SR-01 Attachment 2 Page 86 of 100 EXHIBIT 9D PAGE 3 OF 4 NOVA SCOTIA POWER INC. SUMMARY OF DISTRIBUTION SYSTEM ENERGY LINE LOSSES FOR THE YEAR EN...

AI summary The document provides a summary of distribution system energy line losses for Nova Scotia Power Inc. for the year ending December 31, 2026. It includes a table with monthly data categorized by different customer types and usage levels.

REDACTED (CONFIDENTIAL INFORMATION REMOVED) REDACTED 2026-2027 GRA Compliance Filing - SR-01 Attachment 2 Page 87 of 100 EXHIBIT 9D PAGE 4 OF 4 NOVA SCOTIA POWER INC. SUMMARY OF DISTRIBUTION SYSTEM DEMAND LINE LOSSES FOR THE YEAR ENDING DE...

AI summary The document presents a summary of distribution system demand line losses for Nova Scotia Power Inc. for the year ending December 31, 2026. It includes transmission losses and categorizes demand line losses by different customer classes such as small domestic, general small, medium, large, and industrial.

911 1,021 801 $368,345 350,449 386,240 (54) DIST.PLT.- SERVICES $56,181 $0 139 160 119 $56,042 54,819 57,265 (55) DIST.PLT.- METERS $70,426 $0 176 208 143 $70,250 71,444 69,056 (56) DIST.PLT.- STREET LIGHTING $35,211 87 101 73 $35,124 34,8...

AI summary The text presents a table with financial figures related to distribution and transmission services, including amounts for various categories such as services, meters, and street lighting, along with actuals and percentages for 2024.

E GROUPS 65,731.33 (151) (131) TOTAL LABOUR RELATED 238,872.21 241,048.4 -2,176.2 (132) TRANSMISSION CONTROL CENTER 5,429.9 (133) GENERATION, TRANSMISSION AND DISTRIBUTION (134) TRANSMISSION BEFORE STORM EXPENSES 22,786 99% (135) TRANSMISS...

AI summary The document provides a detailed breakdown of various expenses related to transmission, distribution, and customer service, including pre-storm and storm-related costs, as well as percentages and totals for different line items.

N - Other 1,358.8 0 0.0 1,359 891.3 467 467 0 (251) DISTRIBUTION - Substations 9,065.6 0 0.0 9,066 8,556.5 509 509 0 (252) DISTRIBUTION - Poles and Fixtures 20,950.9 0 0.0 20,951 293.0 20,658 20,658 0 (253) DISTRIBUTION - OH Lines 12,194.0...

AI summary The text presents a table of distribution-related costs and expenses, including substation, poles, overhead lines, underground lines, transformers, services, meters, and streetlights. The data includes figures for various line items and their corresponding allocations.

8,124 8,124 8,124 0 (258) DISTRIBUTION -Streetlights 4,584.6 0 0.0 4,585 4,585 4,585 0 (259) DISTRIBUTION TOTAL 94,824.5 0.000 94,825 (260) (261) GENERAL PROPERTY Adj ,2026 (262) GENERATION 0.0 0 0 0 (263) DISTRIBUTION 6,892.9 0.0 6,893 6,...

AI summary The document presents a series of financial figures and categories related to distribution, generation, and transmission within a regulatory proceeding. The data includes entries for streetlights, general property, and various distribution and transmission costs, with some entries showing zero values and others showing small adjustments.

Calendar Month of System Peak 1 January February March April May June July August September October November December Total (134) EHV - LIR 3.1% (135) HV - LIR 4.2% (136) HV - Municipal 3.8% (137) Distribution BP Substation LIR 4.4% (138)...

AI summary The text presents data on the calendar month of system peak with percentages and values for various distribution and transmission categories, including EHV, HV, and Distribution BP Substation, along with non-coincident demand measurements.

16,511.5 (153) Distribution BP Substation - LIR 4,727.9 (154) Distribution BP Substation - Municipal 14,042.7 (155) Distribution Primary Voltage - LIR 34,200.8 (156) Distribution Primary Voltage - Municipal 14,042.7 (157) (158) Demand Line...

AI summary The text contains a list of line items related to distribution and demand line losses, including various substation and voltage categories, with associated numerical values. It appears to be a financial or operational breakdown from a regulatory proceeding.

15,951.7 (161) Distribution BP Substation - Municipal - (162) Distribution Primary Voltage - LIR 111,061.6 Distribution Primary Voltage - Municipal 45,013.2 ELIADC - MWh Loss Factor 2.5% 2.5% 2.6% 2.4% 2.3% 2.3% 2.2% 2.1% 2.3% 2.3% 2.5% 2....

AI summary The document contains a reference guide for a 2027 Cost of Service Study Analysis by Nova Scotia Power Inc., including a redacted compliance filing related to GRA (Grid Reliability and Availability) for 2026-2027. It includes data on distribution costs and loss factors related to ELIADC (Electric Load and Infrastructure Analysis and Development Corporation).

1,158,946 0 0 (20) (21) TOTAL TRANSMISSION FUNCTION $1,158,946 $1,158,946 $0 $0 (22) (23) DISTRIBUTION FUNCTION (24) (25) DISTRIBUTION PLANT: (26) LAND 5,050 2,624 0 2,426 (27) EASEMENTS & SURVEY 207,143 107,643 0 99,500 (28) OTHER 20,781...

AI summary The text presents a detailed breakdown of transmission and distribution function costs, including land, easements, substations, poles, lines, and other infrastructure components. It outlines the total plant in service and working capital, providing a financial overview of the distribution and transmission systems.

59 20 P-8B (12) DEF. CHG. - Tax 5,171 3,329 176 915 105 96 111 188 156 72 25 P-8B (13) DEF. CHG. - Pension 20,370 13,115 694 3,603 413 377 435 740 613 282 98 O-2B (14) DEF. CHG. - Other 4,177 2,689 142 739 85 77 89 152 126 58 20 P-8B (15)...

AI summary The text presents a series of financial line items related to tax, pension, and other adjustments, along with transmission and distribution costs. These figures are categorized under various line items and include associated matter numbers and classifications.

- - (49) METERS (Meter Shop Only) - - - - - - (50) COMMUNICATIONS - - - - - - (51) STREET LIGHTING 589 - - 570 - 19 (53) TOTAL DISTRIBUTION 58,332.2 - - 56,423 - 1,910 (54) (55) TOTAL CUSTOMER OPERATIONS - T & D 79,764.491 - 20,472 56,423...

AI summary The text presents a table of operational costs and figures related to distribution, customer operations, generation services, and customer service for a utility company. It includes line items such as street lighting, total distribution, customer service experience, and billing services, along with associated costs and variances.

46 (59) DISTRIBUTION - Substations 9,632 9,317 - 315 (60) DISTRIBUTION - Poles and Fixtures 22,210 21,483 - 727 (61) DISTRIBUTION - OH Lines 12,809 12,390 - 419 (62) DISTRIBUTION -UG Lines 2,997 2,899 - 98 (63) DISTRIBUTION -Line Transform...

AI summary The text presents a table of distribution and general property costs, including substation, poles, lines, and transformers, with figures for different years and categories. It also includes entries related to write-offs and interest net.

20,236 - 20,236 - - 0.0% 12.8% 0.0% 0.0% (41) EHV and HV STORM EXPENSES 236 - 236 - - 0.0% 0.1% 0.0% 0.0% (42) (43) DISTRIBUTION: (44) SUBSTATIONS 1,491 - - 1,491 - 0.0% 0.0% 0.4% 0.0% (45) OVERHEAD LINES BEFORE STORM EXPENSES 32,275 - - 3...

AI summary The text presents a detailed breakdown of expenses related to distribution systems, including storm expenses, overhead and underground lines, and street lighting. The data includes numerical figures and percentages, likely from a financial or operational report.

TTERIES 8,551 8,551 - - - 1.9% 0.0% 0.0% 0.0% (53) RADIAL TO GENERATION TRANS. 2,968 2,968 - - - 0.7% 0.0% 0.0% 0.0% (54) Transmission - HV (not aplicable as a separate item) 0 - 0 - - 0.0% 0.0% 0.0% 0.0% (55) Transmission - EHV and HV com...

AI summary The text presents a table of distribution and transmission costs, including line transformers, with various line items such as poles, fixtures, and substations, and their respective percentages and values.

15 753 (33) - (34) CUSTOMER OPERATIONS - (35) TRANSMISSION & DISTRIBUTION: - (36) TRANSMISSION: - HV BEFORE STORM EXPENSES (not applicable (37) as a separate item) 0 0 (38) HV STORM EXPENSES (not applicable as a separ 0 0 (39) (40) EHV and...

AI summary The text lists various expense categories related to customer operations, transmission, and distribution, including high-voltage and extra-high-voltage storm expenses, though some items are marked as not applicable. Specific figures are provided for EHV and HV storm expenses.

- (44) SUBSTATIONS - 50 (45) OVERHEAD LINES BEFORE STORM EXPENSES - 1,092 (46) OVERHEAD LINES STORM EXPENSES - 728 (47) UNDERGROUND LINES - 19 (48) LINE TRANSFORMERS - - (49) METERS (Meter Shop Only) - - (50) COMMUNICATIONS - - (51) STREET...

AI summary The text lists various line items related to distribution and customer operations, including substation costs, overhead and underground line expenses, and total distribution costs. It also mentions generation services, indicating a focus on infrastructure and operational expenditures.

- 46 (59) DISTRIBUTION - Substations - 315 (60) DISTRIBUTION - Poles and Fixtures - 727 (61) DISTRIBUTION - OH Lines - 419 (62) DISTRIBUTION -UG Lines - 98 (63) DISTRIBUTION -Line Transformers - 989 (64) DISTRIBUTION -Services - 115 (65) D...

AI summary The text provides a list of distribution-related categories and their associated costs, including substations, poles, overhead and underground lines, transformers, services, meters, and streetlights, along with some general property classifications.

0 1,834 (55) HYDRO 17,266 16,631 0 0 0 635 (56) WIND 13,334 12,844 0 0 0 491 (57) SOLAR 61 0 0 0 0 61 (57) LM6000 7,372 7,101 0 0 0 271 (58) OTHER GAS TURBINE 3,239 3,120 0 0 0 119 (59) GENERATION BATTERIES 8,877 8,551 0 0 0 327 (60) RADIA...

AI summary The text presents a table with various energy generation and transmission categories, including hydro, wind, solar, and gas turbines, along with associated costs and figures. It also includes data on distribution and transmission costs, such as EHV and HV combined, and distribution easements.

THERMAL O&M D&E SPLIT $151,867 (36) (37) THERMAL O&M DMD. ALLOC. % 48.19% (38) THERMAL O&M ENG. ALLOC. % 51.81% (39) (40) BIOMASS DEMAND ALLOC % 48.19% (41) (42) BIOMASS ENERGY ALLOC % 51.81% (43) (44) NRIS ERIS (45) WIND O&M DMD. ALLOC. %...

AI summary The text presents a breakdown of operational and maintenance costs allocated between demand and energy for various thermal, biomass, and wind assets, as well as pole and wire allocations. It also includes general property allocations across different voltage levels and customer segments, with totals provided.

4,019,140 (8) Unit Cost (cents/kW.h) 8.352 1.336 2.049 0.821 4.205 12.557 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 2,165,416 0.000 (10) Delivery Trans.(Eng) - EHV 0 0 0 0 0 0 0 2,165,416 0.000 (11) Deliver...

AI summary The text presents a detailed breakdown of transmission and distribution costs, including various line items such as delivery, demand, and customer-related expenses. It outlines specific figures for different voltage levels and includes total costs for transmission and distribution. The data provides insights into the financial aspects of power delivery within the region.

y Requirement 273,902 (6) kW 3 CP 125,244 (7) kW 12 NCP 495,495 (8) Unit Cost (cents/kW.h) 8.176 1.270 1.947 0.787 4.003 12.179 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 254,468 0.000 (10) Delivery Trans.(E...

AI summary The text presents data on transmission and distribution costs, including delivery costs for high voltage (HV) and extra high voltage (EHV) lines, demand-related delivery costs, and customer delivery costs. The information includes various line items such as costs for transmission, distribution, and demand management, along with unit costs and totals.

y Requirement 442,241 (6) kW 3 CP 144,442 (7) kW 12 NCP 629,649 (8) Unit Cost (cents/kW.h) 7.630 1.087 1.696 0.703 3.486 11.116 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 414,536 0.000 (10) Delivery Trans.(E...

AI summary The text presents a table with various line items related to transmission and distribution costs, including specific figures for different voltage levels and categories such as demand and customer delivery. It includes monetary values, quantities, and unit costs.

y Requirement 129,552 (6) kW 3 CP 93,701 (7) kW 12 NCP 291,033 (8) Unit Cost (cents/kW.h) 8.658 1.489 2.326 0.906 4.721 13.379 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 125,502 0.000 (10) Delivery Trans.(En...

AI summary The text presents a detailed breakdown of costs related to transmission and distribution, including specific line items for different voltage levels and categories such as demand and customer delivery. The data includes monetary figures and unit costs, highlighting the financial aspects of power delivery infrastructure.

22,698,943 (8) Unit Cost (cents/kW.h) 8.733 1.460 2.085 0.889 4.434 13.167 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 9,923,466 0.000 (10) Delivery Trans.(Eng) - EHV 0 0 0 0 0 0 0 9,923,466 0.000 (11) Delive...

AI summary The document presents a detailed breakdown of transmission and distribution costs, including various line items such as delivery costs for high voltage and extra high voltage systems, along with associated unit costs and totals. These figures are presented in a tabular format with specific monetary values and rates.

0 0 0 0 0 0 (24) STREET LIGHTING 0 0 0 0 0 0 0 0 0 0 0 (25) CUSTOMER SERVICE 0 0 0 0 0 0 0 0 0 0 0 EXHIBIT 6B (26) (27) TOTAL CUSTOMER 58,345 52,707 2,996 1,324 2 253 17 3 0 1 1,042 (28) (29) RETAIL (30) (31) METERS 0 0 0 0 0 0 0 0 0 0 0 N...

AI summary The text presents a table with various categories and numerical data, including street lighting, customer service, meters, substation counts, overhead and underground lines, and associated exhibits and references. It appears to be part of a regulatory proceeding related to utility operations and infrastructure.

85 0 25 339 P-1 (39) UNDERGROUND LINES 831 700 39 57 4 7 6 3 0 1 13 P-1 (40) LINE TRANSFORMERS 0 0 0 0 0 0 0 0 0 0 0 D-1 (41) METERS 11,695 8,873 1,037 973 35 149 61 53 25 1 487 P-6 (42) COMMUNICATIONS 0 0 0 0 0 0 0 0 0 0 0 D-2A (43) STREE...

AI summary The text presents a table with various line items related to distribution costs, including underground lines, line transformers, meters, and street lighting, with associated figures and classifications such as P-1, D-1, and DIRECT. The table also includes a total distribution line item with monetary values and classifications.

0 0 0 0 0 0 0 0 0 0 0 P-9 (28) DISTRIBUTION - Easements 1,796 1,248 68 341 21 39 39 18 0 5 17 P-9 (29) DISTRIBUTION - Other 700 486 27 133 8 15 15 7 0 2 6 P-9 (30) DISTRIBUTION - Substations 9,317 6,471 355 1,771 108 202 204 94 0 26 86 P-9...

AI summary The document outlines various distribution-related costs, including easements, substations, poles, and lines, with specific figures for each category. These costs are categorized under different distribution items and include details such as amounts, percentages, and other numerical data.

0 0 0 0 0 0 0 0 P-9 (36) DISTRIBUTION -Meters 0 0 0 0 0 0 0 0 0 0 0 P-9 (37) DISTRIBUTION PLANT - Streetlight 4,757 0 0 0 0 0 0 0 0 0 4,757 Direct (38) GENERAL PROPERTY 16,886 11,728 644 3,210 196 366 369 170 0 47 157 P-9 (39) (40) TOTAL D...

AI summary The text presents a table with various distribution and demand-related line items, including meters, streetlights, and general property, along with associated costs and classifications such as 'Direct' and 'P-9'. The table includes totals for the distribution function and demand, with figures spanning multiple years.

0 0 0 0 0 (25) (26) TOTAL ENERGY 60,831 31,976 2,200 13,330 2,141 1,564 2,525 4,105 1,777 740 475 (27) (28) CUSTOMER CLASSIFICATION (29) (30) DISTRIBUTION FUNCTION (31) DISTRIBUTION - Land 0 0 0 0 0 0 0 0 0 0 0 P-12 (32) DISTRIBUTION - Eas...

AI summary The text presents a table with various distribution-related costs categorized under different distribution functions, including land, easements, substations, poles and fixtures, overhead lines, underground lines, and line transformers. It provides numerical data for different cost categories across multiple years.

73 0 14 1 0 0 0 33 P-12 (38) DISTRIBUTION - Line Transformers 0 0 0 0 0 0 0 0 0 0 0 P-12 (39) DISTRIBUTION -Services 3,398 3,034 174 115 0 22 2 0 0 0 51 P-12 (40) DISTRIBUTION -Meters 8,124 7,254 416 274 1 53 4 1 0 0 122 P-12 (41) GENERAL...

AI summary The document presents a detailed breakdown of distribution and retail function costs, including line transformers, services, meters, and general property, with figures provided for various categories and periods. The data includes totals and subtotals across multiple line items.

SES EHV TRANSMISSION SERVICE (22) EHV - LIR 217,318 3.1% 224,039 33,243 56.0% 18,609 3.1% 19,185 129.3% 60,987 HV TRANSMISSION SERVICE (23) LARGE INDUSTRIAL 149,381 4.2% 155,636 24,113 83.9% 20,237 4.2% 21,084 80.9% 55,214 (24) MUNICIPAL 6...

AI summary The text presents data on various transmission and distribution services, including EHV transmission, HV transmission, and distribution bulk power substation services, with details on costs, percentages, and other metrics.

- 0.0% 0 (28) SUBTOTAL 32,210 4.45% 33,643 8,310 56.9% 4,728 4.45% 4,938 74.5% 15,952 DISTRIBUTION PRIMARY (BFR BULK POWER SUBST.) (29) LIR 295,673 5.9% 313,068 50,427 67.0% 33,810 4.4% 35,314 95.6% 109,979 (30) MUNICIPAL 56,024 4.2% 56,02...

AI summary The document presents a detailed breakdown of distribution costs and percentages for various categories, including LIR, municipal, and large general, with comparisons between different years. It includes subtotal figures and variance calculations, indicating changes in cost distribution over time.

RIBUTION SYSTEM DEMAND LINE LOSSES COINCIDENT WITH SYSTEM PEAK FOR THE YEAR ENDING DECEMBER 31, 2027 2.43% 4.22% (1) (2) (3) (4) (5) (6) (7) (8) (9) (1) (2) TOTAL SMALL GENERAL SMALL MEDIUM LARGE ENERGY DEMAND MONTH COMPANY DOMESTIC GENERA...

AI summary The document presents data on distribution system demand line losses coincident with system peak for the year ending December 31, 2027, showing percentages for different company categories and months, with overall annual percentages of 2.43% and 4.22%.

0.0 1,393 962.9 431 431 0 (268) DISTRIBUTION - Substations 9,632.0 0 0.0 9,632 9,114.9 517 517 0 (269) DISTRIBUTION - Poles and Fixtures 22,210.0 0 0.0 22,210 317.5 21,893 21,893 0 (270) DISTRIBUTION - OH Lines 12,809.1 0 0.0 12,809 (370.0...

AI summary The text presents a table with financial data categorized under various distribution line items, including substations, poles, overhead lines, underground lines, transformers, services, meters, and streetlights. Each line item includes values for different years and periods, indicating costs and changes over time.

Calendar Month of System Peak 1 January February March April May June July August September October November December Total (117) HV - LIR 149,380.9 (118) HV - Municipal 67,806.0 (119) Distribution BP Substation - LIR 32,210.3 (120) Distri...

AI summary The text provides a table listing the calendar month of system peak for various distribution and transmission systems in Nova Scotia, including values for different voltage levels and locations, as well as energy line losses percentages for specific systems.

4.2% (124) HV - Municipal 3.8% (125) Distribution BP Substation LIR 4.4% (126) Distribution BP Substation - Municipal 4.2% (127) Distribution Primary Voltage - LIR 5.9% (128) Distribution Primary Voltage - Municipal 4.2% (127) (128) Class...

AI summary The text presents a list of percentages and numerical values associated with different categories, likely related to energy distribution and infrastructure, including municipal and LIR (likely Local Independent Retailer) classifications, and various voltage levels and substation types.

ion BP Substation - LIR 8,309.6 (133) Distribution BP Substation - Municipal (134) Distribution Primary Voltage - LIR 50,427.4 (135) Distribution Primary Voltage - Municipal 14,918.0 (136) (137) System Coincident DMD (138) EHV - LIR 18,609...

AI summary The text presents a list of items related to electrical infrastructure, including substation and voltage categories, with associated costs for different entities such as LIR (Local Independent Retailer) and Municipal. These items are likely part of a cost or asset listing in a regulatory proceeding.

FOR THE YEAR ENDING DECEMBER 31, 2027 (IN THOUSANDS OF DOLLARS) ALLOCATION FACTOR INFORMATION Calendar Month of System Peak 1 January February March April May June July August September October November December Total (148) Distribution BP...

AI summary The text presents allocation factor information for the year ending December 31, 2027, including distribution substation and voltage allocations across different months and entities. Specific figures are provided for LIR and Municipal categories, with notable amounts in January and March.

Distribution Primary Voltage - Municipal 44,881.9 PHP - MWh Loss Factor 2.5% 2.5% 2.6% 2.4% 2.3% 2.3% 2.2% 2.1% 2.3% 2.3% 2.5% 2.4% PHP - Peak kW Loss Factor 4.3% 4.0% 3.3% 2.9% 2.7% 2.3% 2.6% 2.6% 2.6% 2.8% 3.6% 4.4% REDACTED (CONFIDENTIA...

AI summary The text presents data on distribution primary voltage and loss factors for PHP (Peak Hour Pricing) over a series of years, highlighting percentages for MWh and Peak kW loss factors. The document is part of a 2026-2027 GRA Compliance Filing and includes a redacted attachment.

s CWIP $ - $ - $ - Total Generation $ 1,888,883 $ 2,065,526 $ 2,165,412 DISTRIBUTION $ 34,037 $ 37,483 $ 30,590 TRANSMISSION $ 2,509 $ 2,708 $ 2,311 DISTRIBUTION/ TRANSMISSION COMMUNICATION $ 39,282 $ 37,252 $ 41,312 DISTRIBUTION/ TRANSMIS...

AI summary The text presents financial data related to generation, distribution, transmission, and general property plant, including capital works in progress (CWIP) and total system plant in service. It includes figures for different years and categories such as retail, non-functionalized, and direct plant in service (solar).

"Overhead line extension" "overhead line extension" means any above ground extension from existing Company distribution facilities required to supply electric power for one or more customers adjacent to a public road, and/or for two or mor...

AI summary The document defines an 'overhead line extension' as an above-ground extension from existing distribution facilities to supply power to customers adjacent to a public road or to multiple customers not adjacent to a public road, terminating where the line is no longer shared by more than one customer.

"Distribution System Access" The services provided by the Company under the Distribution Tariff to provide for the connection of the RtR Customer to the Company's distribution system, but does not include the provision of electricity. Thes...

AI summary The text defines key terms related to distribution system access, meter readings, farming or fishing units, licensed retail suppliers, load definitions, and LRS Participation Agreements, emphasizing compliance with regulations and agreements.

[589] Ms. Palmer agreed that NS Power's use of the minimum system method is not unique and that it is used in other jurisdictions throughout Canada. However, she did not believe this means it is a reasonable method to use for classifying d...

AI summary Ms. Palmer acknowledges the use of the minimum system method in other jurisdictions but argues it is not suitable for NS Power due to its misalignment with customer cost definitions. She explains that distribution costs are primarily driven by demand, not the number of customers, and highlights that customer-related costs are mainly tied to geographic expansion.

[595] As can be seen from the table above, the change to the basic customer method would reduce the proposed increases for the domestic, small general and unmetered rate classes, but increase the rate changes for the rest of NS Power's abo...

AI summary The text discusses the impact of changing the basic customer method on rate classes and highlights the limited number of methods for allocating distribution system costs. It references the Zero Intercept method and notes that the basic customer method allocates the smallest amount of distribution system costs as customer-related.

3.8.3 Primary Distribution System [613] If the basic customer method is not used to allocate distribution system costs between customer and demand, then Ms. Palmer recommends that the primary distribution system be classified 100% to deman...

AI summary Ms. Palmer recommends classifying the primary distribution system 100% to demand, citing concerns with the minimum system methodology used in the cost-of-service study. She argues that primary infrastructure is shared and more likely to peak at the same time as system peaks. An analysis by Concentric in 2022 found that a significant percentage of distribution system poles and conductors are part of the primary distribution system.

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

AI summary This section outlines special conditions related to metering, service provisions, and load management. Customers may be required to contribute to the cost of primary metering, own transformers, and ensure their load does not negatively impact the power supply system's integrity.

GENERAL TIME OF USE TARIFF Page 4 of 4 (4) 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, voltage flicker, unbalan...

AI summary The text outlines considerations for assessing issues that may impact the integrity of the power supply system, including reliability, harmonic voltage and current levels, voltage flicker, unbalance, rate of change in load levels, stability, and fault levels.

The total demand charge in any week, pursuant to a reservation for Daily delivery, shall not exceed the rate specified in Section 2 above times the highest amount in megawatts of Reserved Capacity in any day during such week. The total dem...

AI summary The text outlines rules for demand charges based on reserved capacity for different delivery periods and establishes requirements for discounts in transmission service, emphasizing the use of OASIS for announcements and postings. On-peak days and hours are also defined.

8. RTR CUSTOMER RESPONSIBILITIES The RtR Customer shall be responsible for: - (a) payment of all fees and charges arising in connection with the Distribution Tariff; - (b) compliance with the terms and conditions of the Distribution Tariff...

AI summary The RtR Customer is responsible for paying fees related to the Distribution Tariff, complying with its terms and conditions, obtaining renewable low-impact electricity from an LRS, and managing contractual arrangements with the LRS.

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

AI summary NS Power is responsible for providing, installing, and sealing revenue class meters for RtR Customers under the Distribution Tariff. These meters must meet regulatory requirements and remain NS Power's property. Interval meters with remote polling capabilities are required for all RtR Customers.

11.3 Real Power Losses Distribution System Real Power Losses associated with Distribution System Access are incorporated in the Distribution Tariff rates applicable to each RtR Customer's rate class. The RtR Customer is responsible for the...

AI summary Real power losses in the distribution system are included in the distribution tariff rates for each RtR customer's rate class, and the RtR customer is responsible for these costs.

APPLICABILITY This schedule provides charges for Distribution System Access applicable to distribution-connected Renewable to Retail (RtR) Customers receiving supply of renewable low-impact electricity from a Licenced Retail Supplier as pr...

AI summary This schedule outlines distribution system access charges for Renewable to Retail (RtR) customers in Nova Scotia, who receive renewable low-impact electricity from a licensed retail supplier under the Electricity Act .

Issue Updated Line Loss Study

AI summary The document addresses an updated line loss study, which is relevant to the analysis of energy distribution efficiency and potential cost implications for the utility and regulatory board.

[589] Ms. Palmer agreed that NS Power's use of the minimum system method is not unique and that it is used in other jurisdictions throughout Canada. However, she did not believe this means it is a reasonable method to use for classifying d...

AI summary Ms. Palmer acknowledges that the minimum system method is used elsewhere in Canada but argues it is not appropriate for classifying distribution infrastructure costs, as these are primarily driven by demand rather than the number of customers. She provides an example where adding a new customer with low demand does not significantly increase costs unless the system needs to be expanded to a new area.

[595] As can be seen from the table above, the change to the basic customer method would reduce the proposed increases for the domestic, small general and unmetered rate classes, but increase the rate changes for the rest of NS Power's abo...

AI summary The text discusses the impact of changing the basic customer method on NS Power's rate classes, noting that it would reduce increases for some classes but increase them for others. Mr. Blair explains the Zero Intercept method as a variation of the Minimum System method and confirms that the basic customer method allocates the least distribution system costs to customers, while the minimum system method allocates the most.

3.8.3 Primary Distribution System [613] If the basic customer method is not used to allocate distribution system costs between customer and demand, then Ms. Palmer recommends that the primary distribution system be classified 100% to deman...

AI summary Ms. Palmer recommends classifying the primary distribution system 100% to demand, arguing that the minimum system methodology used in the cost-of-service study incorrectly included primary distribution lines. She notes that primary infrastructure is shared and likely peaks at the same time as the system. An analysis by Concentric in 2022 shows that a significant portion of distribution system poles and conductors are part of the primary distribution system.

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

AI summary Special conditions for metering and service provisions are outlined, including capital contributions for primary metering, customer responsibility for non-standard transformers, and requirements to maintain power supply integrity through reliability and system stability considerations.

GENERAL TIME OF USE TARIFF Page 4 of 4 (4) 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, voltage flicker, unbalan...

AI summary The document discusses factors that could affect the integrity of the power supply system, including reliability, harmonic voltage and current levels, voltage flicker, unbalance, rate of change in load levels, stability, fault levels, and other related conditions.

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

AI summary NS Power is responsible for providing, installing, and sealing revenue class meters for RtR Customers under the Distribution Tariff. The meters must have remote polling capability and comply with the Electricity and Gas Inspection Act. All metering equipment remains the property of NS Power, and requirements are detailed in the NS Power Regulations Section 4 - Metering.

NSP COST OF SERVICE PANEL 141 Cr-ex, (Mahody) 1 in relation to the timing to Goose Harbour, that would 2 3 4 5 6 7 8 9 it is unreasonable to suggest that the cause for installing primary equipment is the presence of a residential customer...

AI summary The discussion revolves around the inclusion of distribution lines serving voltages up to 25,000 volts in Nova Scotia Power's Minimum System Study. The panel questions whether it is reasonable to classify residential customers as the cause for installing primary equipment, given that they likely receive service at a lower voltage. Nova Scotia Power confirms the inclusion and explains that all poles and lines up to that voltage are classified under the primary service level.

customers in the system does not depend on their peak demand. A. That's correct. Q. So a customer located 10 miles away does not become closer or further away from existing infrastructure because their demand is higher or lower. Is that fa...

AI summary The discussion focuses on the relationship between customer location, infrastructure costs, and the Minimum System Study. It highlights that geographic dispersion affects infrastructure costs but is not well correlated with demand or customer account metrics.

dence 16 doesn't contain any Nova Scotia Power-specific 17 analysis showing that a 1.5 kilowatt figure is 18 appropriate, does it? 19 A. No, no. That's some detailed PALMER Cr-ex, (Power) INTERNATIONAL REPORTING INC. CERTIFIED COURT REPORT...

AI summary The discussion involves the lack of Nova Scotia Power-specific analysis regarding a 1.5 kilowatt figure and the consideration of different approaches to allocating Minimum System distribution infrastructure, referencing a table from a Connecticut decision.

onnecticut decision. 16 A. Okay. 17 MS. POWER: And it should be PDF 18 page 203, Mr. Goodine, and it's Table 81, the "Rate 19 Year Load-Carrying Capacity Adjustments." PALMER Cr-ex, (Power) INTERNATIONAL REPORTING INC. CERTIFIED COURT REPO...

AI summary The discussion revolves around the peak load-carrying capacity of distribution assets, excluding line transformers, and the significant variation in load-carrying capacity adjustments, ranging from 0.01 to 1.5. Nova Scotia Power classifies line transformers as 100 percent demand.

INTERNATIONAL REPORTING INC. CERTIFIED COURT REPORTERS Q. And in speaking with my friend concerning the numbers set by Ontario I believe you said that the number was perhaps dated or old. A. Oh, I just mean simply that I understand this wa...

AI summary The witness discusses the Minimum System methodology used by Ontario utilities, noting that it may be outdated and based on current, rather than historical, equipment sizes. The discussion also touches on whether primary distribution costs are classified as customer costs within this methodology.