Topic:"Transmission Planning" in M12451

- (6) Discounts: Three principal requirements apply to discounts for transmission service as follows: - (i) any offer of a discount made by the Transmission Provider must be announced to all Eligible Customers solely by posting on the OASI...

AI summary The text outlines the rules for discounts on transmission service, requiring that all offers and requests for discounts be posted on the OASIS. Once a discount is negotiated, it must be made available to all eligible customers on unconstrained transmission paths. On-peak days are defined as Monday to Friday.

SCHEDULE 10: NETWORK INTEGRATION TRANSMISSION SERVICE RATE (1) The rate charged for Network Integration Transmission Service is: For 20236: $4,888.134,317.55/MW-month For 20247: $5,658.784,317.55/MW-month based on the Transmission Customer...

AI summary Schedule 10 outlines the Network Integration Transmission Service rate for 2023 and 2024, based on the Transmission Customer's Net Non-coincident Monthly Peak Demand. A formula is provided for calculating transmission congestion charges based on redispatch costs and load factors.

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.

357.00 UNDERGROUND CONDUIT 65 - S3 0 1,736,139 611,263 1,124,876 27,127 1.56 41.5 358.00 UNDERGROUND CONDUCTORS AND DEVICES 45 - S3 (10) 7,345,546 853,459 7,226,642 194,359 2.65 37.2 359.00 ROADS, TRAILS AND BRIDGES 60 - S3 0 344,183 110,1...

AI summary The text presents financial data related to underground conduit, underground conductors and devices, and roads, trails, and bridges, including costs and other metrics. It also includes a total for transmission plant and details about distribution plant, specifically land rights and related expenses.

RAILS AND BRIDGES 60 - S3 0 344,183 110,123 234,060 6,260 1.82 37.4 TOTAL TRANSMISSION PLANT 1,254,616,801 513,076,344 971,188,679 33,825,592 2.70

AI summary The text presents numerical data related to rail and bridge costs and total transmission plant expenses, including figures such as 344,183, 110,123, and 234,060, along with percentages and other metrics.

.4 TOTAL TRANSMISSION PLANT 1,254,616,801 513,076,344 971,188,679 33,825,592 2.70 DISTRIBUTION PLANT LAND RIGHTS - EASEMENTS, SURVEYS AND CLEARING 65 - R5 0 118,136,716 15,711,852 102,424,864 1,860,352 1.57 55.1 STRUCTURES AND IMPROVEMENTS...

AI summary The text presents financial data related to total transmission and distribution plant costs, including land rights, structures, station equipment, and energy storage equipment, with various line items and percentages provided for the years 2026-2027. The data is part of a confidential appendix in a regulatory proceeding.

Summary of Related CIs +/- 2 years Pursuant to Section 11.2 of the CEJC, related CIs for Transmission projects include "Work completed on the same asset class (Padmount transformers, Breakers, etc.) or in the same location (feeder, Transmi...

AI summary The document outlines related Cost Items (CIs) for Transmission projects under Section 11.2 of the CEJC, including specific projects like the Canso Crossing Double Circuit Tower upgrade and 345 KV Node Swap. It details depreciation classes and an estimated useful life of 45 years for transmission assets.

JUSTIFICATION: Justification Criteria: Transmission

AI summary The document section outlines the Justification Criteria under the Transmission category, indicating the focus area for the proceeding.

Why do this project? This project was required for a 330 MW Firm Point-to-Point transmission service request and a 170 MW Network Service request as part of the new Maritime Link HVDC interconnection between Nova Scotia Power and Newfoundl...

AI summary This project supports a 330 MW Firm Point-to-Point transmission service and a 170 MW Network Service as part of the Maritime Link HVDC interconnection between Nova Scotia Power and Newfoundland and Labrador Hydro. It enables NS to export 330 MW and provide 170 MW of operating reserve to NB, facilitating economic energy transactions between NS, NB, and NL.

Why do this project now? The System Impact Study Report TSR400-SIS2-R1 prepared by the Nova Scotia Power System Operator dated 2013- 03 identified six actual, or potential, system upgrades required to prevent NS Power transmission related...

AI summary The 2013 System Impact Study identified system upgrades to prevent thermal overloads and voltage collapses. The project was implemented before the ML Project's interconnection, eliminating constraints and ensuring reliability when receiving energy from the Maritime Link.

Title: Separate L8004/L7005 on Canso Crossing Double Circuit Tower (DCT) Start Date: 2014/01 In-Service Date: 2018/07 Final Cost Date: 2021/11 Function: Transmission Forecast Amount: $20,387,278

AI summary The document details a transmission project involving the separation of lines L8004/L7005 on the Canso Crossing Double Circuit Tower (DCT), with a forecasted cost of $20.4 million. The project started in 2014, became operational in 2018, and reached final cost in 2021, highlighting capital expenditures for transmission infrastructure.

DESCRIPTION: This project consisted of building a second transmission line tower crossing over the Strait of Canso to physically separate two existing transmission lines that shared common towers. As a result of the increased capacity and...

AI summary The project involved constructing a second transmission line tower over the Strait of Canso to separate shared 345kV and 230kV lines. Initially planned in ACE 2014-2017, it was referenced in the 2018 ACE Plan with a $19.25M budget. Now submitted for approval via the General Rate Application, the project is complete with final costs.

Why do this Project? L8004 is a 345kV line between 101S-Woodbine and 79N-Hopewell. L7005 is a 230kV line between 3C-Port Hastings and 67N-Onslow. The Transmission Service Request and associated System Impact Study (Report TSR400-SIS2-R1 pr...

AI summary The document describes the reconfiguration of two transmission lines (L8004 and L7005) across the Strait of Canso to address risks of overload and instability. A 2013 study identified that a single tower failure on shared lines could cause instability, prompting separation from a double circuit tower (DCT) at Auld's Cove to ensure reliable transmission for the Maritime Link Project.

Why do this Project Now? The System Impact Study Report TSR400-SIS2-R1 prepared by the Nova Scotia Power System Operator dated 2013- 03 identified six actual, or potential, system upgrades required to prevent NS Power transmission related...

AI summary The 2013 System Impact Study Report identified necessary system upgrades to prevent thermal overloads and voltage collapses. This project, part of the Maritime Link initiative, was implemented before the project's interconnection to NS Power's grid. Originally scheduled for Q3 2017, the project aimed to align with design timelines, minimize outages, and reduce environmental impacts.

Asset Location : - Budget Version UARB Submissions 1455 1455 Transmission Plant General Capital Item Accounts Exp. Type Utility Account Forecast Amount Additions 0200 - TP - Land Rights 672,151 Additions 0300 - TP - Bldg.,Struct.Grnd. 24,5...

AI summary The document outlines capital item accounts related to the Transmission Plant General under the Budget Version UARB Submissions. It includes details on additions and retirements for various items, such as land rights, buildings, wood poles, and overhead conductors, along with cost estimates and references for the Canso Crossing Double Circuit Tower project executed between 2014 and 2019.

Why do this project? This project was undertaken to avoid thermal overloads on transmission line L6511 and line L7019due to increased energy flow onto these transmission lines from the Maritime Link. In addition, these system upgrades also...

AI summary This project was initiated to prevent thermal overloads on transmission lines L6511 and L7019 caused by increased energy flow from the Maritime Link. The upgrades also address line clearance violations and safety concerns associated with additional generation flow on these corridors.

Why do this project now? This project was completed in advance of the Maritime Link Project to eliminate the thermal overload constraints as identified. To complete this work, transmissionline outages were taken that were coordinated with...

AI summary This project was completed in 2018 to eliminate thermal overload constraints before the Maritime Link Project. Transmission line outages were coordinated with system constraints and the shutdown of the Trenton Generation plant. Energy from the Maritime Link is now being received by NS Power.

Why do this project this way? Completing the project this way had the least impact to NS Power customers and the NS Power transmission system. The alternative wasthe construction of additional transmission capacity (the construction of a n...

AI summary The project was completed with minimal impact on NS Power customers and the transmission system. An alternative would have involved constructing new transmission lines, but rebuilding existing lines during planned maintenance periods resulted in lower capital costs.

UARB APPROVAL SHEET Project Title: 67N Onslow 345 kV Node Swap

AI summary The document presents an approval sheet for the 67N Onslow 345 kV Node Swap project, indicating that it is under consideration by the Nova Scotia Utility and Review Board (NSUARB).

67N Onslow 345 kV Node Swap Title: Description Unit Quantity Unit Estimate Total Estimate Cost Support Reference Completed Similar Projects (FP#'s) 530050 Regular Labour Administrative Support Staff Lot 1 $ 5,902 $ 5,902 Environmental Staf...

AI summary The document outlines the estimated costs for various labor and material components involved in the 67N Onslow 345 kV Node Swap project, including administrative support, engineering, travel, and construction materials.

Cost of Service Study Redacted 1 COSS treatment that is applicable to generation assets, while also recognizing that non-firm PPAs 2 provide energy only. 3 4 5.3 Classification of Transmission Costs – Transmission 100 Percent to Demand 5 6...

AI summary The document discusses NS Power's use of the Service Life Factor (SLF) to classify transmission costs since the 1995 NSEB decision (NSPI864), aligning transmission with generation's energy and demand classification. It notes that transmission costs are demand-driven and that the SLF's relevance is diminishing due to coal phase-out and increased renewable energy adoption. The Elenchus Report is referenced for further details.

Cost of Service Study Redacted the COSS design should provide for battery sub-functions within each service area of generation, transmission and distribution. Battery storage units would then be looked at on a case-by-case basis and their...

AI summary The text discusses the design of the Cost of Service Study (COSS) and the need to align transmission rates between the OATT and COSS frameworks. It highlights methodological differences in how transmission costs are calculated and classified in these two systems, leading to inequities in customer pricing and inefficient market design.

19 6.3 Transmission Links to Other Systems – Maritime Link 9 at a number of system peaks rather than a single peak event. 20 21 The current approach to functionalization of the Maritime Link (ML) between transmission and 22 generation is t...

AI summary NS Power's analysis supports the current approach of fully functionalizing all Maritime Link costs to generation, as transmission costs are minor and not explicitly included in purchase prices. Separating transmission components from generation costs is deemed impractical due to their secondary nature.

6 COSS Model Run #3, Transmission Classified as 100% Demand: - 7 The classification of a portion of Transmission as Energy is removed so all rate base and costs are - 8 classified as 100% Demand. The sections of the COSS that allocate Ener...

AI summary In COSS Model Run #3, Transmission is reclassified as 100% Demand, removing its classification as Energy. This adjustment zeros out sections of the COSS that allocate Energy-related Transmission to rate classes to avoid cell reference errors.

1 COSS Model Run #15 Transmission clean import-enabling assets classified by SLF: - 2 This model functionalizes transmission costs associated with enabling clean imports and classifies - 3 these costs by the SLF, with remaining transmissio...

AI summary This section describes COSS Model Run #15, which categorizes transmission costs related to enabling clean imports by SLF, with remaining costs classified as demand. The model includes tabs showing variances between the scenario and the current COSS and Model #3.

CONFIDENTIAL Exhibit Reference Cells Modification 104, 115-116, 179-180 Exh 9a Annual Columns M-V Calculate primary and secondary distribution MWh and load factor 14. a. Updated Fuel Costs BCF File – Data Inputs Rows 8-47 Update fuel cost...

AI summary The document outlines updates to fuel cost inputs and modifications to transmission classifications for renewable energy assets. These changes are part of a regulatory proceeding involving Nova Scotia Power and the NSUARB, with references to various exhibits and data inputs.

Under-frequency Load Shedding occurred twice with loss of transmission due to line icing from freezing rain. Start Restored Event 29-Nov-18 8:58 29-Nov-18 16:52 Icing event. Tripping of the transmission lines in the Cape Breton Export Corr...

AI summary Under-frequency Load Shedding occurred twice due to loss of transmission caused by line icing from freezing rain. The first incident occurred on 29-Nov-18, and the second on 16-Jan-23, both involving tripping of transmission lines in the Cape Breton Export Corridor and the NS-NB Tie line, respectively.

COSS CA DR-9 Attachment 1 Page 45 of 627 Start Time End Time ANL_MW 5/9/2019 9:00 5/9/2019 10:00 5/9/2019 10:00 5/9/2019 11:00 883.2 889.2 5/9/2019 11:00 5/9/2019 12:00 880.5 5/9/2019 12:00 5/9/2019 13:00 874.0 5/9/2019 13:00 5/9/2019 14:0...

AI summary The document provides a table of apparent energy load (ANL_MW) data recorded over multiple time intervals on May 9th to May 12th, 2019. This data appears to be related to energy usage and may be used for analysis in a regulatory proceeding.

COSS CA DR-9 Attachment 1 Page 274 of 627 Start Time End Time ANL_MW 3/7/2021 6:00 3/7/2021 7:00 1431.0 3/7/2021 7:00 3/7/2021 8:00 3/7/2021 8:00 3/7/2021 9:00 1483.1 1507.1 3/7/2021 9:00 3/7/2021 10:00 1470.2 3/7/2021 10:00 3/7/2021 11:00...

AI summary This document presents a table of energy demand data for a specific period, showing the start and end times along with corresponding ANL_MW values. The data spans multiple days in March 2021 and appears to be part of a regulatory proceeding related to energy usage and planning.

COSS CA DR-9 Attachment 1 Page 311 of 627 Start Time 6/23/2021 5:00 End Time 6/23/2021 6:00 ANL_MW 664.1 6/23/2021 6:00 6/23/2021 7:00 765.6 6/23/2021 7:00 6/23/2021 8:00 862.9 6/23/2021 8:00 6/23/2021 9:00 879.5 6/23/2021 9:00 6/23/2021 1...

AI summary This document contains a table of load data (in ANL_MW) for specific time intervals on June 23, 2021, through June 26, 2021. It appears to be part of a regulatory proceeding related to energy load management and planning.

COSS CA DR-9 Attachment 1 Page 438 of 627 Start Time End Time ANL_MW 6/28/2022 15:00 6/28/2022 16:00 1102.1 6/28/2022 16:00 6/28/2022 17:00 6/28/2022 17:00 6/28/2022 18:00 1066.0 1110.1 6/28/2022 18:00 6/28/2022 19:00 1102.2 6/28/2022 19:0...

AI summary This document presents a table with timestamps and corresponding ANL_MW values, likely representing energy demand or generation data over a period from June 28, 2022, to July 1, 2022. The data appears to be technical and related to grid operations or resource planning.

COSS CA DR-9 Attachment 1 Page 570 of 627 Start Time End Time ANL_MW 7/18/2023 15:00 7/18/2023 16:00 7/18/2023 16:00 7/18/2023 17:00 1349.1 1380.7 7/18/2023 17:00 7/18/2023 18:00 1359.6 7/18/2023 18:00 7/18/2023 19:00 1329.8 7/18/2023 19:0...

AI summary This document presents a table showing the ANL_MW (Apparent Net Load in Megawatts) for various time intervals between July 18, 2023, and July 21, 2023. These data points represent the net electricity demand during specific hours, which is likely relevant to grid operations and resource planning.

NON-CONFIDENTIAL model dispatches into the highest net load hours.2 2 3 4 The NS Block of energy delivered to NS over the Maritime Link is a firm energy import and 5 treated as such for ELCC. The ELCC for the basic block is mainly influenc...

AI summary The document discusses the Effective Load-Carrying Capacity (ELCC) of energy imports delivered to Nova Scotia via the Maritime Link. Firm energy imports are treated differently from non-firm imports, with the latter having an ELCC of zero due to timing and reliability factors.

Cost of Service Study Process (NSUARB M11475) NSPI Responses to CA Data Requests 1 Request DR-14: 2 3 Please provide current transmission costs associated with the extra-high voltage 4 transmission system (EHV, 138 kV and greater) and the...

AI summary NSPI responded to a data request regarding transmission costs for EHV and HV systems in Nova Scotia. The response included spending figures for 2023 and details about the system configuration, noting that both mesh and radial structures are present, with HV lines supplying approximately 25% of the load capacity.

10 2.1.1 Transmission Revenue Requirement 11 12 The first step in calculating the transmission tariff is to determine the appropriate revenue 13 requirement that must be recovered from the sale of Transmission Services. Refer to [Figure 2]...

AI summary The first step in calculating the transmission tariff involves determining the appropriate revenue requirement to be recovered from the sale of Transmission Services, with reference to Figure 2.2.

4 The revenue requirement shown in Figure 2-2 includes the costs of all transmission lines at 5 voltages of 69 kV or higher and th[e terminal sta](#page-101-1)tions associated with those transmission lines. It 6 also includes the revenue r...

AI summary The revenue requirement in Figure 2-2 includes costs for transmission lines at 69 kV or higher and associated terminal stations, as well as generation step-up transformers of NS Power, which are excluded from OATT revenue requirements. Details are provided in Figure 2-.

this service. 1 2. Definition of the basic functions of the Transmission System 2 3. Allocation of transmission revenue requirements to the different functional uses of the 3 system 4 4. Determination of system usage by service 5 5. Alloca...

AI summary The document outlines the basic functions of the Transmission System, including Point-to-Point and Network Services, as well as Ancillary Services such as Scheduling, System Control, and Dispatch. These services are defined within the OATT and are essential for the operation of the transmission system in Nova Scotia.

2.1.4 Transmission Functions - 3 The services defined in the OATT and described in the previous section use different parts of the - 4 Transmission System. To ensure appropriate cost allocation, it is necessary to break down the - 5 revenu...

AI summary This section discusses the breakdown of revenue requirements into component pieces to ensure appropriate cost allocation for different services provided by the Transmission System, grouping assets into three main functional groups for the NS Power OATT.

1. Generation Related Transmission Assets Direct Assignment Facilities are generation-related transmission assets (GRTA) that serve the function of connecting generation units to the shared Transmission System. They consist of generator st...

AI summary Generation-related transmission assets (GRTA), including transformers and transmission lines, connect generation units to the Transmission System. Revenue requirements for these assets are recovered directly from generation owners, not through the transmission tariff rate.

3. Radial-to-Load Assets Radial-to-Load Assets are those parts of the Transmission System that are not a part of the integrated network and are used only to serve in-province loads. However, because the impact of including radial-to-load a...

AI summary The text discusses radial-to-load assets, which are parts of the transmission system serving in-province loads and are included in the bulk power network for ratemaking purposes. It references various attachments and documents related to the topic.

4 2.1.5 Functional Allocation of Costs 5 - 6 The allocation of the Transmission Services revenue requirement of $126.5 million in 2022, - 7 $153.8 in 2023 and $183.4 million in 2024 to the functional uses of the system is summarized in - 8...

AI summary The document outlines the allocation of Transmission Services revenue requirements for 2022, 2023, and 2024, with figures provided for each year. The allocation details are summarized in Figure 2-4 and further elaborated in Figure 2-8.

11 Functional Allocation of Revenue Requirements Revenue Requirement Functional Use Share ($millions) 2022 2023 2024 Generator Related Transmission Assets (GRTA) $7.0 $8.3 $9.3 Bulk Network In Province (Transmission OATT) 110.4 136.0 164.7...

AI summary The table outlines the functional allocation of revenue requirements for various components of the energy system in Nova Scotia for the years 2022, 2023, and 2024. It includes allocations for Generator Related Transmission Assets (GRTA), Bulk Network In Province (Transmission OATT), and the Energy Control Centre, with total revenue requirements increasing over the years.

13 2.1.6 Determination of System Usage 14 - 15 The transmission revenue requirement is allocated between Point-to-Point and Network - 16 Integration Services based on the monthly coincident peak system load. There is a single long- - 17 te...

AI summary The document discusses the allocation of transmission revenue requirement between Point-to-Point and Network Integration Services based on monthly coincident peak system load, with a specific 330 MW reservation used in the analysis. A figure is referenced to illustrate the resulting system usage.

1 Figure 2-3 Transmission System Usage Transmission System Usage Usage Quantity (MW) Allocation 2022 2023 2024 Factors (%) Average export usage over 5 years 330 330 330 16.79% Forecasted average of Network Loads at the time of the 12 month...

AI summary Figure 2-3 presents transmission system usage data, including average export usage and forecasted network loads for the years 2022 to 2024. The data shows that average export usage is 330 MW, while forecasted network loads at the time of the 12 monthly system peaks are 1,635 MW, accounting for 83.21% of total usage.

14 Figure 2-4 Transmission Services Revenue Requirements Transmission Services Revenue Requirements Percent Service Share Revenue Requirement ($ millions) 2022 2023 2024 Point-to-Point 16.79% 18.5 22.8 27.7 91.9 113.1 137.1 Network 83.21%...

AI summary Figure 2-4 presents the transmission services revenue requirements for different service shares over the years 2022 to 2024, showing increasing figures for Point-to-Point and Network services, with total revenue requirements rising from 110.4 to 164.7 million dollars.

1 Figure 2-5 Per Unit Transmission Services Revenue Requirements Per Unit Transmission Services Revenue Requirements Service Revenue Requirement ($ millions) Usage (MW) Per Unit Revenue Requirement ($/MW-year) 2022 Point-to-Point 18.5 330...

AI summary Figure 2-5 presents the per unit transmission services revenue requirements for the years 2022, 2023, and 2024. It includes revenue requirements, usage in MW, and per unit revenue requirements in dollars per MW-year for both Point-to-Point and Network services.

17 Tariff in effect. 1 4 6 10 PARTIALLY CONFIDENTIAL 2026-2027 GRA Direct Evidence Appendix 12A(2) Page 836 of 1218 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 2022-2024 GRA SR-01 Attachment 1e Page 16 of 32 COSS CA DR-53 Attachment 1 Page...

AI summary The document discusses ancillary services required for the reliable operation of the Transmission System, categorizing them into capacity-based and non-capacity-based services. It references the Nova Scotia Power Open Access Transmission Update from February 2022 and mentions the calculation of rates for these services.

PARTIALLY CONFIDENTIAL 2026-2027 GRA Direct Evidence Appendix 12A(2) Page 851 of 1218 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 2022-2024 GRA SR-01 Attachment 1e Page 31 of 32 COSS CA DR-53 Attachment 1 Page 61 of 62 Nova Scotia Power Op...

AI summary The document discusses changes in NS Power's transmission costs and operational factors from 2014 to 2024, including increased investment in transmission assets, changes in depreciation rates, and the impact of wind generation on ancillary services. Operating costs have decreased, but the overall system usage has increased, affecting OATT service rates.

NON-CONFIDENTIAL 1 Request DR-72: 2 3 Please provide an update on the status of the powerflow modeling that would provide some 4 clarity regarding the use of HV transmission by EHV-connected loads. (6/3 meeting) 5 6 Response DR-72: 7 8 NSP...

AI summary NSPI has not initiated powerflow modeling for the Nova Scotia transmission system, noting that many areas rely on 69kV sub-transmission lines rather than 138kV transmission lines. Expanding 138kV infrastructure would reduce operating costs but would require significant capital investment.

Cost of Service Study Process (NSUARB M11475) NSPI Responses to IG Data Requests 1 Request DR-20: 2 3 Reference: November 4, 2024 and November 5, 2024 Cost of Service Study Resolution 4 Sessions verbal request. 5 6 Clarify how Generation R...

AI summary The document discusses the determination of Generation Related Transmission Assets (GRTA) in the OATT calculations and their relationship to the transmission rate base. NSPI explains that GRTA includes assets connecting generation units to the Transmission System and are recovered directly from generation owners, not through the transmission tariff.

(a) (b) (d) (c) Duration (days, hours) Description Start time End time Cause 5, 20 Hurricane Dorian 7-Sep-19 10:30 13-Sep-19 7:26 Numerous trips to transmission elements caused by high winds Outage to line L-8001 to NB due to ice build-up,...

AI summary The document details two outages: one caused by Hurricane Dorian in September 2019, and another due to transmission line icing in January 2021. Both events led to disruptions in energy imports and customer interruptions. The text is part of a partially confidential GRA Direct Evidence Appendix.

Cost of Service Study Process (NSUARB M11475) NSPI Responses to PHP Data Requests 1 Request DR-29: 2 3 Reference: Email from David MacDougall on October 22, 2024 titled "COSS - Models and 4 DRs." 5 6 It is PHP's understanding that NSPI is...

AI summary NSPI is not reviewing its position on the Maritime Link's treatment as transmission. It advocates maintaining the current costing methodology for the Maritime Link. The only significant change in the near-term is the termination of Supplemental energy by March 2027, which will not affect the costing treatment of the NS Block and Surplus energy.

COSS SBA DR-6 Attachment 1 Page 17 of 24 011 SOLID FUEL 012 NATURAL GAS 013 OIL 019 THERMAL GENERAL 021 WIND 022 HYDRO 023 TIDAL 024 BIOMASS 025 SOLAR 029 RENEWABLES GENERAL 091 BY PRODUCT SERVICES 099 POWER GENERATION GENERAL 111 SUBSTATI...

AI summary The document contains a list of fuel types, location segments, and other operational categories used in the regulatory proceeding. It includes information on power generation, transmission, distribution, and corporate segments, as well as location-based classifications.

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.

Long Term Resource Planning - o 1 to 25 year planning horizon. - o Used for Integrated Resource Plans (IRP), 10 Year System Outlook, Northeast Power Coordinating Council (NPCC) regional studies, and generation and transmission investment d...

AI summary The text outlines the Long Term Resource Planning process, which spans a 1 to 25 year planning horizon and is used for Integrated Resource Plans (IRP), 10 Year System Outlook, Northeast Power Coordinating Council (NPCC) regional studies, and generation and transmission investment decisions.

Common Themes and Action Plan - There are significant common elements across the 24 scenarios modeled: - Regular, structured renewable generation additions to achieve i dentified wind/solar capacity buildout. - Near-term investments in ene...

AI summary The text outlines common elements across 24 modeled scenarios, including renewable generation additions, energy storage and transmission investments, firm capacity resources, and fuel conversions at existing NS Power sites. It emphasizes the need for a collaborative 2030 Resource Development Plan based on the Integrated Resource Plan (IRP) analysis to achieve system reliability and meet 2030 goals.

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.

Agenda - Classification of Generation - o Historic Perspective behind Current Approach - o Future Challenges - Classification of Transmission - o Historic Perspective behind Current Approach - o Future Challenges - Questions

AI summary The agenda item focuses on the classification of generation and transmission, including a review of historical perspectives and future challenges related to these classifications.

Instead of collecting generation costs, collect generation and transmission costs • California couldn't use this method for transmission costs due to federal

AI summary The text discusses the consideration of collecting both generation and transmission costs, referencing California's inability to use this method for transmission costs due to federal constraints.

Comments on NB Power COSS Filings (April 11, 2024) Page 3 of 4 General Service II Secondary Distribution 1.59% 1.60% Small Industrial Small Industrial Transmission 0.14% 0.14% Small Industrial Primary Distribution 2.42% 2.41% Small Industr...

AI summary The document presents a table of distribution and transmission sales percentages and raises a question about whether the Probability of Dispatch (POD) method is equivalent to the Hybrid Cost Model (HCM) method.

Transmission Allocator - Functional Classification - Demand is the appropriate allocation for transmission. - Transmission facilities are sized to handle peak electricity demand. - The majority of NS Power's transmission system is networke...

AI summary The document discusses the functional classification of transmission facilities based on demand and the need for further investigation into 3-CP versus 12-CP allocation methods to align cost with causation. It also notes that winter peaks influence system demand and that the majority of NS Power's transmission system is networked.

Issue 2 Transmission Issue 2a - Functionalization of 'transmission' assets between transmission and generation (Maritime Link and Reliability Tie)? SBA View - The SBA refers to the discussion of Issue 1 a(i) above for this. A fresh look is...

AI summary Issue 2a concerns the functionalization of 'transmission' assets between transmission and generation, specifically the Maritime Link and Reliability Tie. The SBA suggests a fresh look is needed as the existing methodology does not adequately address allocating some transmission costs as energy-related.

Issue 2b - Functionalization of 'transmission' assets between transmission and generation (bulk Power Substation, BESS)? SBA View - The SBA refers to the discussion of Issue 1 a(i) above for this. A fresh look is needed, especially since t...

AI summary The SBA suggests that a fresh look is needed for the functionalization of transmission assets, such as bulk power substations and BESS, between transmission and generation. It notes that the existing methodology does not adequately address allocating some transmission costs as energy-related.

Issue 2d - New Transmission Resources (including grid scale battery, ancillary service technologies)? SBA View-The SBA refers to the discussion oflssue la(i) above for Grid Scale Batteries. Regarding Ancillary Services, the SBA agrees with...

AI summary The SBA references a prior discussion on grid scale batteries and agrees that ancillary service costs should be fully demand-related, but emphasizes the need to examine the cost allocation factor in comparison to resource adequacy cost causation.

- In the 2023-2024 GRA the test year usage under the Point-to-Point reflected the prospective Long-term firm reservation as provided in Trans – Fig 5-10. Service Long-Term Firm Reservations Transmission System 12 CP Allocation Factors (%)...

AI summary The 2023-2024 GRA details test year usage under the Point-to-Point service, reflecting long-term firm reservations as shown in Trans – Fig 5-10. The table outlines service allocations and billing determinants for different transmission systems.

Transmission Costs Compared: Unbundled Municipal Tariff vs OATT in context of total service costs

AI summary The document compares transmission costs between the Unbundled Municipal Tariff and OATT within the context of total service costs, illustrated through a figure referenced in the text.

Transmission Cost and Rate Design Processes Compared

AI summary The document compares transmission cost and rate design processes, likely discussing methodologies, cost allocation, and regulatory considerations involved in setting rates for transmission services.

Transmission Losses The Annual Transmission losses were determined through a detailed simulation process PSS/E software. This modeling approach incorporates : - Hourly (8760) SCADA data, capturing real-time system conditions

AI summary Annual transmission losses are calculated using PSS/E software through a detailed simulation process that incorporates hourly SCADA data to capture real-time system conditions.

- Predefined transformer losses, integrated into the overall transmission loss calculation Month Energy (MWh) Peak (MW) Peak Loss (MW) Energy Loss (MWh) Energy Loss (%) January 1,112,409 1,921 82 30,858 2.77% February 1,118,927 2,403 102 3...

AI summary The text discusses predefined transformer losses integrated into the overall transmission loss calculation. A table provides monthly data on energy, peak demand, and loss metrics from January to December, with a total annual loss of 252,511 MWh, representing 2.27% of total energy.

Total Energy Losses = ∑ Segment Losses (1) kWH SALES (2) ANNUAL ENERGY PER CUSTOMER (GWh) (3) LOSS ALLOCATION FACTOR (%) (4) TRANSMISSION ENERGY LOSS (GWh) (5) TRANSMISSION ENERGY LOSS (%) (6) DISTRIBUTION ENERGY LOSS (GWh) (7) DISTRIBUTIO...

AI summary The document presents a detailed breakdown of total energy losses across various customer segments, including domestic, industrial, and municipal, with percentages of losses attributed to transmission, distribution, secondary systems, and non-technical factors. It highlights the allocation of losses and their impact on different customer groups.

Memorandum To: NS Power From: Andrew Blair & John Todd Date: December 18, 2024 Re: Transmission Classification Jurisdiction Review

AI summary This memorandum from Andrew Blair and John Todd to NS Power addresses the Transmission Classification Jurisdiction Review. It is part of a regulatory proceeding and outlines considerations related to transmission classification and jurisdiction.

Transmission costs, excluding from generation radial and interconnections, are classified 100% as demand in all jurisdictions except Alberta. Province Utility Transmission Classification (excluding generation radial and interconnections) B...

AI summary Transmission costs, excluding generation radial and interconnections, are classified as 100% demand in all provinces except Alberta, where ENMAX classifies approximately 80% as demand with certain charges billed on energy.

2026-2027 GRA Direct Evidence Appendix 12A(4) Page 11 of 18 REDACTED (CONFIDENTIAL INFORMATION REMOVED) - 2- Transmission Classification December 18, 2024

AI summary The document is a page from a 2026-2027 GRA Direct Evidence Appendix 12A(4) that includes a section titled 'Transmission Classification December 18, 2024.' The content is partially redacted due to confidential information being removed.

2026-2027 GRA Direct Evidence Appendix 12A(4) Page 12 of 18 REDACTED (CONFIDENTIAL INFORMATION REMOVED) - 3- Transmission Classification December 18, 2024

AI summary This document is a redacted page from a regulatory proceeding related to transmission classification as of December 18, 2024. It appears to be part of a larger appendix in the 2026-2027 GRA Direct Evidence.

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 discusses the refunctionalization of transmission systems, with NS Power maintaining its position to refunctionalize a portion of transmission related to radial to generation based on OATT calculations. No changes were made to the position following the resolution session.

2026-2027 GRA Direct Evidence Appendix 12A(6) Page 3 of 6 REDACTED (CONFIDENTIAL INFORMATION REMOVED) functionalization between EHV and HV categories; classification of transmission based on SLF and allocation of demand related costs based...

AI summary The text discusses the functionalization of EHV and HV categories, classification of transmission based on SLF, allocation of demand-related costs using 3CP, and the inclusion of new transmission resources such as grid-scale batteries and ancillary service technologies, as well as transmission links to other systems.

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.

5.1.1.3 ELENCHUS OPINION - Elenchus supports NS Power's proposed methodology for functionalizing general - Transmission rate base and revenue requirement. - The distinction that NS Power makes between EHV and HV transmission assets is not...

AI summary Elenchus supports NS Power's methodology for functionalizing general transmission rate base and revenue requirement, but questions the distinction between EHV and HV transmission assets, arguing that the evidence does not justify excluding HV cost responsibility from EHV customers.

5.2.1.3 ELENCHUS OPINION - NS Power's current classification methodology of applying the system load factor to the - transmission system is unique in Canada. Aside from radial-to-generation and

AI summary NS Power's current classification methodology of applying the system load factor to the transmission system is unique in Canada, differing from other approaches such as radial-to-generation.

4.1 Transmission losses The calculation of transmission system losses relies on a detailed modelling approach using PSS/E software. This process incorporates hourly (8760) SCADA data, allowing for a comprehensive assessment of real-time sy...

AI summary The calculation of transmission system losses uses PSS/E software with hourly SCADA data to assess real-time system conditions. Monthly simulations are used to determine annual losses, with the highest monthly peak loss representing total annual energy dissipation in the transmission network based on 2023 models.

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.

1. Transmission system customers Customers connected at the transmission level receive electricity at higher voltages, typically between 345 kV and 69 kV. At these voltage levels, energy losses are relatively lower. Because electricity is...

AI summary Transmission system customers are connected at high voltage levels (345 kV to 69 kV), resulting in lower energy losses due to reduced current flow for the same power delivery compared to lower voltage systems.

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.

4.8.1 Transmission System Configuration NS Power has developed a condensed transmission system model allowing for accurate representation of NS Power transmission system constraints. The number of nodes and interconnecting corridors by whi...

AI summary NS Power has developed a condensed transmission system model to accurately represent transmission system constraints. The model's configuration, including the number of nodes and corridors, will be determined by the Planning and Performance department and continuously reviewed for accuracy and detail. All adjustments to the model will be documented and stated in assumptions.

4.8.2 Transmission Corridor energy transfer limits Transmission corridor energy transfer limits as per the data published on OASIS – Open Access Same-time Information System. All necessary adjustments due to transmission corridor upgrades...

AI summary The document discusses transmission corridor energy transfer limits as published on OASIS, noting that any adjustments due to upgrades or reconfigurations will be documented in assumptions, including their magnitude and reasons.

4.8.3 Transmission System Restrictions Transmission system energy transfer restrictions as they affect generating unit dispatch: - Cape Breton Export energy transfer levels required to trigger arming of the group SPS targeting generating u...

AI summary This section discusses transmission system energy transfer restrictions and their impact on generating unit dispatch, including specific energy transfer levels that trigger actions such as arming SPS and committing generating units. The PLEXOS model is used to capture these transmission limits, and the system planning group will request updates from the system operator and FERM before each forecast.

7.0 Import Power The methodology used to forecast the price of power imports into Nova Scotia from New Brunswick for the 2020-2022 Rate Stability Period assumes that all NB to NS imports are purchased from ISO New England, including transm...

AI summary The methodology for forecasting power imports from New Brunswick to Nova Scotia during the 2020-2022 Rate Stability Period assumes purchases from ISO New England, including transmission and losses. Import prices are based on on-peak and off-peak forward prices from the New England Power Pool, with adjustments made for system constraints and known changes.

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.

CA6 – Transmission Additions as % of Transmission Plant - ◼ On a 5-year average basis, NSPI Transmission Additions as a Percent of Transmission Plant is below the peer group median and is fourth lowest - ◼ NSPI Transmission Additions as a...

AI summary NSPI's Transmission Additions as a Percent of Transmission Plant have decreased by over 1 percentage point between 2019 and 2023, placing it below the peer group median and fourth lowest. Meanwhile, the peer median Transmission Additions increased by 29% over the same period, while NSPI's Transmission Plant increased by 15% in nominal terms.

Nova Scotia's 2030 Clean Power Plan In October 2023, the Nova Scotia provincial government announced its Clean Power Plan The plan outlines how the province will phase out coal and reach 80% renewable energy by 2030 The Province's plan inc...

AI summary Nova Scotia's 2030 Clean Power Plan aims to phase out coal and achieve 80% renewable energy by 2030. Key elements include increasing wind and solar energy, importing hydroelectricity from Muskrat Falls, incorporating grid-scale batteries, adding natural gas generation, and building a new transmission line to New Brunswick.

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.

Atlantic Reliability Tie – NS Power • In December 2023, the provincial government approved the NS portion of the Reliability Tie Project, a 345kV transmission line between NS and NB, targeting in-service in 2028

AI summary In December 2023, the provincial government approved the Nova Scotia portion of the Atlantic Reliability Tie Project, a 345kV transmission line connecting Nova Scotia and New Brunswick, with an expected in-service date of 2028.

The Province's plan includes: - 30% more wind power and 5% more solar energy; - Continued imports of hydro electricity from Muskrat Falls via the Maritime Link; - The incorporation of grid-scale batteries - Efficiency investments to reduce...

AI summary The Province's plan includes increasing wind and solar energy, importing hydro electricity from Muskrat Falls, incorporating grid-scale batteries, investing in efficiency to manage peak load growth, adding fast-acting natural gas generation, and building a new transmission line between Nova Scotia and New Brunswick.

Atlantic Reliability Tie – NS Power • In December 2023, the provincial government approved the NS portion of the Reliability Tie Project, a 345kV transmission line between NS and NB, targeting in-service in 2028

AI summary In December 2023, the provincial government approved the Nova Scotia portion of the Reliability Tie Project, a 345kV transmission line connecting Nova Scotia and New Brunswick, with an expected in-service date of 2028.

Major Decarbonization Projects - Added ~600 MW of wind (~150 MW rate base and ~450 MW through IPPs) - Completed Maritime Link ($1.8 billion) project which is capable of transmitting 500 MW of hydro capacity - Battery Energy Storage Systems...

AI summary The document outlines major decarbonization projects, including the addition of 600 MW of wind energy, completion of the Maritime Link transmission project, and development of three 50 MW battery energy storage systems. These initiatives aim to enhance renewable energy capacity and grid reliability.

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.

Utility Type Transmission - ~500 km

AI summary The document mentions that the utility type is Transmission with a length of approximately 500 kilometers.

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 24,300 km of main lines 13,500 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 a total of 24,300 km of main lines and 13,500 km of service 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 lines, indicating 5,000 km of transmission and 28,000 km of distribution lines.

The Province's plan includes: - 30% more wind power and 5% more solar energy; - Continued imports of hydro electricity from Muskrat Falls via the Maritime Link; - The incorporation of grid-scale batteries - Efficiency investments to reduce...

AI summary The Province's plan includes increasing wind and solar energy, importing hydroelectricity, incorporating grid-scale batteries, investing in efficiency to manage peak load, adding natural gas generation, and constructing a new transmission line between Nova Scotia and New Brunswick.

Atlantic Reliability Tie – NS Power • In December 2023, the provincial government approved the NS portion of the Reliability Tie Project, a 345kV transmission line between NS and NB, targeting in-service in 2028

AI summary In December 2023, the provincial government approved the Nova Scotia portion of the Reliability Tie Project, a 345kV transmission line connecting Nova Scotia and New Brunswick, with an expected in-service date of 2028.

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 - 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.

Major Decarbonization Projects - Added ~600 MW of wind (~150 MW rate base and ~450 MW through IPPs) - Completed Maritime Link ($1.8 billion) project which is capable of transmitting 500 MW of hydro capacity - Refurbishment of Nova Scotia P...

AI summary The document outlines major decarbonization projects including the addition of wind capacity, completion of the Maritime Link transmission project, refurbishment of hydro facilities, and investments in grid-scale battery storage and transmission to support renewable energy and phase out coal by 2030.

Enabling Renewable Generation Nova Scotia Power continues to work collaboratively with the Provincial Government to implement the 2030 Clean Power Plan to phase out coal and increase renewable generation to 80% of sales by 2030. Updates si...

AI summary Nova Scotia Power is advancing renewable generation initiatives, including grid-scale battery installations and transmission line projects, in alignment with the 2030 Clean Power Plan. The creation of an Independent System Operator and partnerships with the Canada Infrastructure Bank and WMA are key aspects of these efforts.

TOTAL MW 330 1,785 100.00% NOTES: 1. There is currenly one Long-Term Firm Point-to-Point Transmission Reservation (TSR400) 2.The 1,785 MW is the average of the 12 monthly Test Year Coincident Peaks. system load data resulting in a coincide...

AI summary The document presents transmission revenue requirement allocation for Nova Scotia Power Inc. in 2027, detailing unit costs for bulk transmission services, point-to-point service, and network service, with total costs and usage by service in dollars and megawatts.

- o Larger investment on the transmission side of things PART TIALLY CONFIDENTIAL CI C0053316 Appendix A Page 3 o CI Number : ( C0053316 - Transmission Customer Performance Regulations Compliance Projet Michelin Waterville Dynamic Voltage...

AI summary The text discusses a larger investment on the transmission side of things, highlighting a project related to transmission customer performance regulations compliance. It includes details about various capital item accounts and their associated forecast amounts for a project with the CI number C0053316.

Integration Assets - The reliability [ti](#page-12-3)e1 is required in all scenarios to support the integration of variable renewable generation (wind and solar) and to serve as the first leg of the Atlantic Loop (the latter in the with At...

AI summary The document discusses the need for reliability infrastructure to support variable renewable generation integration and the Atlantic Loop. It outlines the Reliability Tie, synchronous condensers, and future capacity additions by 2030, 2035, and 2050.

Item 1b: Regional Integration Continue working with neighboring jurisdictions in support of the Atlantic Loop and other opportunities for regional integration, conducting detailed engineering and economic studies for firm import options re...

AI summary The document emphasizes the need to continue collaboration with neighboring jurisdictions to support the Atlantic Loop and other regional integration opportunities. It calls for detailed engineering and economic studies to evaluate firm import options that may require new transmission investments and stronger regional interconnections, considering factors such as supply security, emission intensity, and dispatch flexibility.

ITEM 10: FIRM IMPORTS Continue to monitor opportunities for near-term firm imports over existing transmission infrastructure.

AI summary The document suggests continuing to monitor opportunities for near-term firm imports over existing transmission 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.

For Energy Delivery, major assets include: - Major Substation Equipment\ (e.g. Breakers, Transformers) - Transmission Conductor and Structures\ - Distribution Conductor, Poles, and other attachments\ - Telecommunication and Teleprotection...

AI summary The text lists major energy delivery assets, including substation equipment, transmission and distribution infrastructure, and telecommunication systems, noting that reliability teams are responsible for these asset groupings.

DATE FILED: December 9, 2024 Page 31 of 54 1 Developed a procurement approach for the synchronous condenser equipment. 2 Initiated substation design activities to accommodate the synchronous condensers. 3 4 This project has been included i...

AI summary The document outlines progress on two key projects: the procurement of synchronous condensers and the development of the Reliability Tie transmission line. Both projects are part of broader efforts to enhance grid reliability and integrate renewable energy, aligning with the 2030 Clean Power Plan.

1 work related to land easements and rights of way for the New Brunswick portion of the 2 line in late 2024. 3 4 Key preliminary engineering activities continue on the Project and NS Power anticipates bringing 5 forward a capital applicati...

AI summary The text discusses ongoing work related to land easements and rights of way for the New Brunswick portion of a project, with key engineering activities continuing and a capital application anticipated in Q1 2025. Stage 2 of the 2030 Clean Power Plan includes transmission upgrades and regional integration efforts, such as the conversion of a 230 kV line to 345 kV and additional transformation capacity in Nova Scotia.

DATE FILED: December 9, 2024 Page 45 of 54 1 8.0 PROJECT ACCOUNTABILITIES, COORDINATION, AND RISK 2 MANAGEMENT 3 4 NS Power believes that the Nova Scotia 2030 Clean Power Plan is a comprehensive and 5 appropriate clean energy transition pl...

AI summary NS Power supports the Nova Scotia 2030 Clean Power Plan, which it describes as comprehensive and based on stakeholder engagement. The plan outlines roles for the NS Government and NS Power in meeting renewable energy targets, with the NSIESO taking on responsibility for future battery storage and fast-acting generation projects.

Transmission Geographic location of the Line L-6511 Between New Glasgow and Glen Dhu L-7003 Between Onslow and Port Hastings L-7004 Between Dalhousie Mountain and Port Hastings L-7005 Between Onslow and Port Hastings L-7008 Between Brushy...

AI summary The document lists several transmission lines with their respective geographic locations, including lines between New Glasgow and Glen Dhu, Onslow and Port Hastings, Dalhousie Mountain and Port Hastings, and others.

8 2025-2029 Forecast Investment: $196 million 9 - 10 In 2025, a targeted transmission investment of $33 million will fund a range of initiatives aimed 11 at improving reliability and making the transmission system more resilient. These ini...

AI summary The 2025-2029 forecast investment of $196 million includes a $33 million transmission investment in 2025 to improve reliability and resilience, with funds allocated for infrastructure upgrades, site-specific projects, and maintenance programs. Details are outlined in the 2025 ACE Plan.

4 (a) Please find a version of Figure 3 from the 2024 Load Forecast, modified to reflect the 5 updated forecast used for the 2026-2027 GRA, below: Year NSR (GWh) Growth (%) System Peak (MW) Growth (%) 2014 11,037 -1.4 2,118 4.2 2015 11,099...

AI summary The text presents a modified version of Figure 3 from the 2024 Load Forecast, updated to reflect the 5 updated forecast used for the 2026-2027 GRA. It includes tables with data on Net System Requirement (NSR) and System Peak (MW) from 2014 to 2034, showing growth percentages for each year.

Transmission & Distribution Metrics

AI summary The document discusses transmission and distribution metrics, including the role of entities like Nova Scotia Power and Emera Inc., and references various acronyms and technical terms related to energy infrastructure and operations.

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 transform...

AI summary The document discusses NSPI's Transmission and Distribution OM&G costs, highlighting that they are in the first quartile compared to peers on various metrics. However, since 2021, NSPI's expenses have grown faster than its peers, influenced by factors such as increased storm expenses, customer growth, and investment in reliability.

CA6 – Transmission Additions as % of Transmission Plant - On a 5-year average basis, NSPI Transmission Additions as a Percent of Transmission Plant is below the peer group median and is fourth lowest - NSPI Transmission Additions as a Perc...

AI summary NSPI's Transmission Additions as a Percent of Transmission Plant have decreased by over 1 percentage point between 2019 and 2023, placing it below the peer group median. While NSPI's additions dropped by 9%, the peer median increased by 29%. NSPI's Transmission Plant grew by 15% in nominal terms, whereas the peer median declined by 6%.

CA7 – Transmission Additions as % of Depreciation Expense

AI summary The document presents figures related to transmission additions as a percentage of depreciation expense, with visual representations on pages 185, including Figure 3 and Figure 4.

REDACTED 1 Request IR-96: 2 3 Reference: Exhibit N-3 GRA Direct Evidence, 9.3 Maritime Link Capital Applications 4 5 On page 60, NS Power addresses the Board's directive from the 2023-2024 GRA Decision 6 regarding inclusion of four Maritim...

AI summary The document discusses a request for detailed breakdowns of benefits and costs related to the Maritime Link transmission projects, including depreciation, financing costs, and energy purchases. It also asks for estimated costs of energy generation without using Maritime Link energy and capital costs for the projects.

NON-CONFIDENTIAL 1 Request IR-97: 2 3 Reference: Exhibit N-3, GRA Direct Evidence 4 5 On page 61 of the application, NS Power states that since the Maritime Link transmission 6 projects have met the Board's threshold test, the transmission...

AI summary NS Power refers to the Maritime Link transmission projects meeting the Board's threshold test, with transmission assets forecast at their net book value. A request is made for a continuity schedule showing the opening rate base amount for the GRA forecast starting January 1, 2026.

CONFIDENTIAL (Attachment Only) 1 Request IR-4: 2 3 Refer to GRA Appendix 12A, Cost of Service Study Process, section 5.3. 4 5 6 (a) Provide the Board's Decision on the Cost of Service proceeding in 1995 (NSPI864). 7 (b) Explain why reduced...

AI summary The text outlines several requests related to the Cost of Service Study and transmission system design by NSPI. It asks for the Board's 1995 decision, explains the relevance of coal generation reduction to transmission classification, and seeks clarification on transmission cost definitions, wind generation's impact on system design, and the factors driving system costs with increased renewable energy.

CONFIDENTIAL (Attachment Only) 1 (i) Is NSPI's transmission system designed to function over extended hours of high 2 loading? Explain why or why not. 3 4 (j) In live, unlocked Excel file format with all links and formula intact, please pr...

AI summary NSPI is asked whether its transmission system can function under high loading and to provide an alternate version of the COSS using SLF to classify transmission costs. NSPI explains that the transmission system will transition from radial to network-based, affecting cost classification.

NON-CONFIDENTIAL 1 in transmission costs paid for by customers in the bundled and unbundled markets of Nova 2 Scotia. Date Filed: November 5, 2025 NSPI (Synapse) IR-5 Page 2 of 2

AI summary The text references transmission costs in Nova Scotia, distinguishing between bundled and unbundled markets. It is part of a document filed by NSPI (Synapse) on November 5, 2025.

NON-CONFIDENTIAL 1 Request IR-8: 2 3 What is NS Power's transmission loss factor in each of 2026 and 2027. If that differs from 4 prior years, please explain why. 5 6 Response IR-8: 7 8 The System Average Loss Factor (SALF) applicable to N...

AI summary The document discusses NS Power's response to requests regarding transmission loss factors for 2026 and 2027, the filing of 2026 Annually Adjusted Rates, and options for addressing FAM balances related to load migrations. The SALF is calculated annually based on historical data, and the 2026 rates application was filed in November 2025.

- o Larger investment on the transmission side of things PA RTIALLY CONFIL DENTIAL CI C0053316 Appendix A Page 3 of CI Number : C0053316 Transmission Customer Performance Regulations Compliance Project Michelin Waterville Dynamic Voltage R...

AI summary The text discusses a transmission customer performance regulations compliance project involving a dynamic voltage restorer at the Michelin Waterville site. It outlines various capital item accounts and associated forecast amounts for different transmission-related additions, totaling $31,170,675.

- 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.

Integration Assets - The reliability [ti](#page-113-3)e1 is required in all scenarios to support the integration of variable renewable generation (wind and solar) and to serve as the first leg of the Atlantic Loop (the latter in the with A...

AI summary The document discusses the need for reliability infrastructure, including the Reliability Tie and synchronous condensers, to support the integration of variable renewable energy sources like wind and solar. These assets are crucial for maintaining grid stability, especially in scenarios involving the Atlantic Loop and by 2030.

Item 1b: Regional Integration Continue working with neighboring jurisdictions in support of the Atlantic Loop and other opportunities for regional integration, conducting detailed engineering and economic studies for firm import options re...

AI summary The document emphasizes the need to continue regional integration efforts, particularly with the Atlantic Loop, by conducting detailed engineering and economic studies for new transmission investments and interconnections. These studies should evaluate supply security, emission intensity, and dispatch flexibility.

ITEM 10: FIRM IMPORTS Continue to monitor opportunities for near-term firm imports over existing transmission infrastructure.

AI summary The document suggests continuing to monitor opportunities for near-term firm imports over existing transmission infrastructure.

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.

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.

NEWFOUNDLAND POWER INC. ACCOUNT 350.02 - TRANSMISSION - ROADS, TRAILS AND BRIDGES ORIGINAL AND SMOOTH SURVIVOR CURVES

AI summary The document presents original and survivor curves related to transmission infrastructure, specifically roads, trails, and bridges under Account 350.02 for Newfoundland Power Inc.

ACCOUNTS 355.10 AND 355.20 - TRANSMISSION - POLES AND FIXTURES ORIGINAL LIFE TABLE, CONT. PLACEMENT BAND 1928-2018 EXPERIENCE BAND 1948-2018 AGE AT BEGIN OF INTERVAL EXPOSURES AT BEGINNING OF AGE INTERVAL RETIREMENTS DURING AGE INTERVAL RE...

AI summary This document presents a table detailing the original life table for poles and fixtures in transmission accounts 355.10 and 355.20, covering placement and experience bands from 1928 to 2018. It includes data on exposures, retirements, retirement ratios, survival ratios, and percentage survival at the beginning of each interval.

UTILITY RATE PROCEEDINGS IN WHICH TESTIMONY HAS BEEN PRESENTED BY JACOB POUS ALASKA 172 Judicial District Court of Texas Franchise Fees United States Bankruptcy Court 93-10408S Level of Harm, Ratemaking, Equity for Eastern District of Texa...

AI summary The document lists utility rate proceedings in which Jacob Pous has provided testimony, including cases involving depreciation, excess reserve, rate base, and transmission access across various jurisdictions such as Texas, Florida, and others.

- "Avoiding Debates—Aligning Planning with Procurement." Presentation at the EUCI 2019 Hawai'i Power Summit, Post-Conference Workshop, Honolulu, HI (January 2019). - "Assessing Available Carbon-Free/Renewable Generation Resources." Present...

AI summary The text lists various presentations and panels related to energy planning, procurement, and strategic issues in the electricity sector, with a focus on topics such as renewable generation, competitive procurement, and transmission planning. Presentations were delivered at events like the EUCI Power Summit and Southwest Power Pool meetings.

EXAMPLE OF ADAPTATION: TRANSMISSION LINES Heat causes power lines to expand and sag. Safety standards dictate the minimum distance that must be maintained between power lines and the ground. There are three main sources of heat that cause...

AI summary This section discusses how rising temperatures due to climate change affect power line expansion and sagging, leading Hydro-Québec to adapt its transmission line design practices. The focus is on increasing thermal ranges and modifying infrastructure to meet long-term needs while considering future operating conditions.

CHALLENGES TO OVERCOME - Given the vast scale of the transmission system, any adaptation measure requires a massive effort.

AI summary The text highlights the significant challenge posed by the scale of the transmission system, emphasizing that any adaptation measure would require a substantial effort.

EXHIBIT 3 PAGE 2 OF 5 (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (10) (11) (12) ALLOCATION (16) DEF. CR ARO Trans -52 -33 -2 -9 -1 -1 -1 -2 -2 -1 -0 D-3A (17) SUB-TOTAL 48,119 30,913 1,578 8,564 976 877 1,12...

AI summary The document presents a detailed table of various financial and operational allocations, including distribution plant costs, transmission functions, and general property plant expenses. It includes allocations across different categories and sizes, with some entries referencing exhibits and other documents.

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) PROD. WEIGHTS (7) TRANS. WEIGHTS (8) DIST. WEIGHTS (9) RETAIL WEIGHTS (47)...

AI summary The document presents a detailed breakdown of expenses for the year ending December 31, 2026, categorized by different energy generation and distribution components, including hydro, wind, solar, and various transmission and distribution expenses. It also includes weight percentages 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.

(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 : 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 : 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.

EXHIBIT 3 PAGE 3 OF 5 (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL INDUSTRIAL (7) MEDIUM INDUSTRIAL (8) INDUSTRIAL LARGE (9) PHP (10) MUNICIPAL (11) UNMETERED (12) ALLOCATION FACTOR (52) DEF. CHG...

AI summary The table presents various financial and cost-related data categorized by different company segments and allocation factors. It includes entries such as deferred charges, asset retirement obligations, and transmission costs, with some cells containing zero values and others referencing specific line items.

(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.

EXHIBIT 8B PAGE 1 OF 3 (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (10) (11) (12) ALLOCATION (21) DEMAND - DIST. PLANT (22) % RESPONSIBILITY $36,113 100.00% $0 0.00% $0 0.00% $0 0.00% $0 0.00% $0 0.00% $0 0.0...

AI summary The table presents financial responsibility allocations across various categories, including demand, energy generation, transmission, and customer distribution, with percentages and dollar amounts for different sizes and types of plants. Each entry includes a reference to a specific allocation matter.

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.

Summary Unnamed: 0 NOVA SCOTIA POWER, INC. Unnamed: 2 Unnamed: 3 Unnamed: 4 Unnamed: 5 Unnamed: 6 Unnamed: 7 Unnamed: 8 Unnamed: 9 Unnamed: 10 Unnamed: 11 Unnamed: 12 Unnamed: 13 Unnamed: 14 Unnamed: 15 Unnamed: 16 Unnamed: 17 Unnamed: 18...

AI summary The table provides detailed financial data on overhead and underground conductors, devices, and infrastructure related to transmission and distribution plants, including costs, quantities, and other metrics.

This service is required to schedule the movement of power through, out of, within, or into an Operating Area. This service can be provided only by the operator of the Operating Area in which the transmission facilities used for transmissi...

AI summary The text outlines the requirements for scheduling, system control, and dispatch services within an Operating Area. These services must be provided by the operator of the Operating Area or through arrangements with the Transmission Provider. Charges for these services are passed through to the Transmission Customer.

Network Integration Transmission Service For 2026, $319.06/MW of Network Integration Transmission Service per month. For 2027, $217.15/MW of Network Integration Transmission Service per month.

AI summary The document outlines the Network Integration Transmission Service rates for 2026 and 2027, specifying $319.06/MW and $217.15/MW per month, respectively, with a visual reference to a chart or image on page 67.

SCHEDULE 2: REACTIVE SUPPLY AND VOLTAGE CONTROL FROM GENERATION SOURCES SERVICE In order to maintain transmission voltages on the Transmission Provider's transmission facilities within acceptable limits, generation facilities (in the Opera...

AI summary This schedule outlines the provision of Reactive Supply and Voltage Control from Generation Sources Service to maintain acceptable transmission voltages. The service is provided by the Transmission Provider or an Operating Area operator, with charges based on set rates and passed through to the Transmission Customer.

Customer Obligations for Self-Supply and Third-Party Supply The customer obligation for self-supply or third-party supply of Operating Reserve – Spinning Reserve is equal to 2.0 percent of the Transmission Customer's reserved capacity for...

AI summary The document outlines the customer obligation for self-supply or third-party supply of Operating Reserve – Spinning Reserve, setting it at 2.0 percent of the Transmission Customer's reserved capacity for Point-to-Point Transmission Service and 2.0 percent of the Network Load for Network Integration Transmission Service.

SCHEDULE 6: OPERATING RESERVE – SUPPLEMENTAL RESERVE SERVICE Supplemental Reserve Service (also referred to as Contingency Reserve – Supplemental) is needed to serve load in the event of a system contingency; however, it is not available i...

AI summary Schedule 6 outlines the requirements for Supplemental Reserve Service, which is used to serve load during system contingencies. The service can be provided by on-line but unloaded generating units, quick-start generation, or interruptible load. The Transmission Provider must offer this service, and the Transmission Customer must either purchase it or make alternative arrangements.

- (6) Discounts: Three principal requirements apply to discounts for transmission service as follows: - (i) any offer of a discount made by the Transmission Provider must be announced to all Eligible Customers solely by posting on the OASI...

AI summary The document outlines requirements for discounts in transmission service, emphasizing that all discounts must be posted on the OASIS for transparency. It also defines on-peak days as Monday to Friday for the service.

SCHEDULE 9: REAL POWER LOSS FACTORS For Point-to-Point service, the Transmission Provider will seasonally calculate loss factors to be used on a path-by-path basis. For each season, winter and summer, the power flow models used to calculat...

AI summary This document outlines the methodology for calculating real power loss factors for both Point-to-Point and Network Service by the Transmission Provider, including seasonal calculations, annual reviews, and the application of locational loss factors. It also details the rate for Network Integration Transmission Service and the formula for transmission congestion charges.

SCHEDULE 3: REGULATION AND FREQUENCY RESPONSE SERVICE Regulation and Frequency Response Service is necessary to provide for the continuous balancing of resources (generation and interchange) with load and for maintaining scheduled Intercon...

AI summary Regulation and Frequency Response Service is essential for maintaining balance between generation and load, ensuring stable 60 Hz frequency. The Transmission Provider is responsible for providing this service, and the Transmission Customer must either purchase it or arrange alternatives. Monthly charges are outlined, with costs passed through if an Operating Area operator performs the service.

Customer Obligations for Self-Supply and Third-Party Supply The customer obligation for self-supply or third-party supply of Operating Reserve – Spinning Reserve is equal to 2.0 percent of the Transmission Customer's reserved capacity for...

AI summary The document outlines that the customer obligation for self-supply or third-party supply of Operating Reserve – Spinning Reserve is set at 2.0 percent of the Transmission Customer's reserved capacity for Point-to-Point Transmission Service and 2.0 percent of the Network Load for Network Integration Transmission Service.

SCHEDULE 6: OPERATING RESERVE – SUPPLEMENTAL RESERVE SERVICE Supplemental Reserve Service (also referred to as Contingency Reserve – Supplemental) is needed to serve load in the event of a system contingency; however, it is not available i...

AI summary Schedule 6 outlines the requirements for Supplemental Reserve Service, which is used to serve load during system contingencies. The service can be provided by on-line but unloaded generating units, quick-start generation, or interruptible load. The Transmission Provider must offer this service, and the Transmission Customer must either purchase it or make alternative arrangements.

0 0 0 0 0 0 0 0 0 0 0 P-11B (13) DEF. CHG. - Pension 0 0 0 0 0 0 0 0 0 0 0 O-5B (14) DEF. CHG. - Other 0 0 0 0 0 0 0 0 0 0 0 P-11B (15) DEF. CHG. - FCR 0 0 0 0 0 0 0 0 0 0 0 P-11B (16) DEF. CR. - ARO Trans 0 0 0 0 0 0 0 0 0 0 0 E-1A (17) S...

AI summary The document presents a table with financial data related to various line items, including pension, other defined charges, fuel cost recovery, and asset retirement obligation transactions. The table includes totals for transmission functions and energy costs, though much of the content is redacted due to confidentiality.

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.

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.

16,145 16,145 - - - 3.7% 0.0% 0.0% 0.0% (48) WIND 12,948 12,948 - - - 3.0% 0.0% 0.0% 0.0% (49) SOLAR - - - - - 0.0% 0.0% 0.0% 0.0% (50) LM6000 6,832 6,832 - - - 1.6% 0.0% 0.0% 0.0% (51) GAS TURBINE - OTHER 2,805 2,805 - - - 0.6% 0.0% 0.0%...

AI summary The document presents a table with various energy generation and transmission categories, including wind, solar, and gas turbine data, along with percentages and monetary values. The table includes items such as LM6000, Generation Batteries, and Transmission - EHV and HV combined, with some entries having zero values or missing data.

(36) TRANSMISSION: - (37) HV BEFORE STORM EXPENSES (not applicable as a separate item) 0 0 (38) HV STORM EXPENSES (not applicable as a separate item) 0 0 (39) (40) EHV and HV BEFORE STORM EXPENSES 70 715 (41) EHV and HV STORM EXPENSES 1 8

AI summary The text lists various transmission-related expenses, including HV and EHV storm expenses, with specific figures provided. These items are categorized under transmission and include before and after storm costs, though some are marked as not applicable as separate items.

22 1,249 (47) HYDRO 8 432 (48) WIND 6 346 (49) SOLAR - - (50) LM6000 3 183 (51) GAS TURBINE - OTHER 1 75 (52) GENERATION BATTERIES 4 223 (53) RADIAL TO GENERATION TRANS. 1 83 (54) Transmission - HV (not aplicable as a separate item) 0 0 (5...

AI summary The text lists various energy generation and transmission categories along with numerical values, including hydro, wind, solar, gas turbines, and transmission systems. Some entries have zero or missing data, indicating incomplete or non-applicable information.

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.

TRANSMISSION OPERATING EXPENSES FOR THE YEAR ENDING DECEMBER 31, 2026 (IN THOUSANDS OF DOLLARS)

AI summary The document presents transmission operating expenses for the year ending December 31, 2026, with figures provided in thousands of dollars. It outlines the financial details related to the transmission operations during that period.

COMPANY EXPENSES EXPENSES EXPENSES TRANSMISSION FUNCTION (1) Transmission - HV (not aplicable as a separate item)

AI summary The document discusses transmission expenses, specifically highlighting that transmission at high voltage (HV) is not applicable as a separate item. This suggests that HV transmission costs may be consolidated or not separately accounted for in the expense breakdown.

0 0 -5,558 0 0 DIRECT (31) ALLOC. OF ELI 2P-RTP DMD. ADJ. 5,558 3,571 182 989 113 101 130 202 167 77 26 D-4 (32) ELI 2P-RTP PRIORITY DMD ADJ. -556 0 0 0 0 0 0 0 -556 0 0 DIRECT (33) ALLOC. OF ELI 2P-RTP PRI. DMD. ADJ. 556 357 18 99 11 10 1...

AI summary The document presents a detailed financial breakdown of various allocation and adjustment items, including ELI 2P-RTP demand adjustments and total generation figures. It includes operating and maintenance costs, transmission expenses, and regulatory affairs expenses, with some line items marked as direct or related to specific categories.

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 722,194 (6) kW 3 CP 246,525 (7) kW 12 NCP 1,151,424 (8) Unit Cost (cents/kW.h) 7.713 1.020 -0.063 0.676 1.634 9.346 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 697,603 0.000 (10) Delivery Trans.(Eng) - EHV...

AI summary The text provides numerical data related to energy costs and transmission/distribution expenses, including kW values and unit costs in cents per kW.h. It includes line items for transmission and distribution costs, with specific figures for different voltage levels and demand categories.

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.

70 P-10 (12) (13) TOTAL GENERATION FUNCTION 62,503 31,212 2,114 13,235 2,082 1,519 2,587 3,993 4,589 711 460 (14) (15) TRANSMISSION FUNCTION Transmission - HV (not aplicable as a (16) separate item) 0 0 0 0 0 0 0 0 0 0 0 E-1B (17) GENERAL...

AI summary The text presents a table with various financial and operational figures related to generation and transmission functions, including specific line items such as total generation function, transmission - HV, and general property. The data includes numerical values across multiple categories, but no explicit discussion or argument is made.

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.

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.

0 0 0 (17) (18) TRANSMISSION PLANT 1,000,894 0 1,000,894 0 0 0 (19) (20) DISTRIBUTION PLANT (21) (22) LAND 5,050 0 0 5,050 0 0 (23) EASEMENTS & SURVEY 207,143 0 0 207,143 0 0 (24) OTHER 20,781 0 0 20,781 0 0 (25) SUBSTATIONS 192,024 0 0 19...

AI summary The document presents a detailed breakdown of costs associated with various components of the transmission and distribution plant, including land, easements, substations, poles, lines, transformers, and meters. These figures are likely part of a regulatory proceeding related to infrastructure costs.

280,086 -76,712 356,798 0 (35) (36) TOTAL GENERATION FUNCTION 2,539,311 2,182,513 356,798 0 (37) (38) TRANSMISSION FUNCTION (39) Transmission - HV (not aplicable as a separate (40) item) 0 0 0 0 (41) (42) GENERAL PROPERTY PLANT 0 0 0 0 (43...

AI summary The text presents a series of financial figures and line items related to generation, transmission, and working capital, with most values listed as zero. It includes categories such as transmission, general property plant, and deferred charges, but does not provide specific details or analysis.

4,177 0 0 0 0 0 4,177 0 0 (15) DEF. CHG. - FCR 5,240 0 0 0 0 0 5,240 0 0 (16) DEF. CR. - ARO Trans -7 0 0 0 0 0 -7 0 0 (17) SUB-TOTAL 54,778 0 0 0 0 0 54,778 0 0 (18) (19) Transmission - EHV 1,158,946 0 0 0 0 0 1,158,946 0 0 (20) (21) TOTA...

AI summary The document presents a classification of average rate base for Nova Scotia Power Inc. for the year ending December 31, 2027, including various financial line items such as deferred charges, asset retirement obligations, and transmission costs.

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.

UNCTION 1,467,999 771,645 53,095 321,681 51,657 37,733 60,923 99,055 42,892 17,847 11,471 (38) (39) TRANSMISSION FUNCTION (40) Transmission - HV (not aplicable as a separate item) 0 0 0 0 0 0 0 0 0 0 0 E-1B (41) (42) GENERAL PROPERTY PLANT...

AI summary The document presents a table with financial figures and line items related to transmission function, general property plant, and working capital. It includes entries for cash, materials and supplies, and deferred charges, with some line items marked as not applicable or zero.

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.

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.

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 374,976 (6) kW 3 CP 136,936 (7) kW 12 NCP 637,230 (8) Unit Cost (cents/kW.h) 7.651 1.113 1.738 0.714 3.565 11.216 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 357,053 0.000 (10) Delivery Trans.(E...

AI summary The text provides a breakdown of costs related to transmission and distribution, including line items such as delivery for transmission and distribution, with associated figures in dollars and cents per kilowatt-hour. It lists various components like demand, customer delivery, and total transmission costs.

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 719,039 (6) kW 3 CP 245,492 (7) kW 12 NCP 1,148,007 (8) Unit Cost (cents/kW.h) 7.447 1.071 0.058 0.690 1.819 9.267 Transmission/Distribution (9) Delivery Trans.(Eng) - HV 0 0 $0 $0 $0 $0 $0 694,582 0.000 (10) Delivery Trans.(...

AI summary The text provides a breakdown of costs related to transmission and distribution, including delivery costs for high voltage and extra high voltage systems, as well as demand and customer-related delivery costs. It outlines various line items such as transmission costs, demand-related delivery costs, and customer delivery costs with corresponding figures and totals.

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.

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.

eration 2,116,693 2,066,780 2,166,605 Average RB before (23) T&D Adj. T&D Adj. (24) TRANSMISSION PLANT 817,951 ($187,906) 1,005,858 966,664 1,045,051 (25) TRANSMISSION PLANT - CWIP 182,943 182,943 141,193 224,692 (26) Total Transmission 1,...

AI summary The text provides financial data related to transmission plant costs and adjustments, including figures for transmission plant, CWIP, and total transmission over various periods.

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.

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).

isks. Morrison Park highlighted that "concrete steps to solve problems at NSPI – such as the securitization of the stranded FAM balances – was rewarded by the markets with lower yields on NSPI bonds". [319] NS Power has been in a precariou...

AI summary Morrison Park highlighted that securitization of stranded FAM balances helped NSPI lower bond yields. NS Power's credit rating downgrade to BBB- in late 2022 has led to increased debt costs, with potential additional annual interest costs of $25 million or more. This includes higher rates on new debt, refinanced debt, and penalties on government-backed financing arrangements for renewable and transmission projects.

This service is required to schedule the movement of power through, out of, within, or into an Operating Area. This service can be provided only by the operator of the Operating Area in which the transmission facilities used for transmissi...

AI summary The document outlines the requirements for scheduling, system control, and dispatch services within an Operating Area, specifying that these services must be provided by the Operating Area operator or arranged by the Transmission Provider. Charges for these services are passed through to the Transmission Customer based on costs incurred by the Operating Area operator.

Network Integration Transmission Service For 2026, $319.06/MW of Network Integration Transmission Service per month. For 2027, $217.15/MW of Network Integration Transmission Service per month.

AI summary The document outlines the Network Integration Transmission Service rates for 2026 and 2027, specifying $319.06/MW per month for 2026 and $217.15/MW per month for 2027.

SCHEDULE 2: REACTIVE SUPPLY AND VOLTAGE CONTROL FROM GENERATION SOURCES SERVICE In order to maintain transmission voltages on the Transmission Provider's transmission facilities within acceptable limits, generation facilities (in the Opera...

AI summary Schedule 2 outlines the provision of Reactive Supply and Voltage Control from Generation Sources Service to maintain transmission voltages within acceptable limits. The service is provided by the Transmission Provider or an Operating Area operator, with charges based on established rates and passed through to the Transmission Customer.

Customer Obligations for Self-Supply and Third-Party Supply The customer obligation for self-supply or third-party supply of Operating Reserve – Spinning Reserve is equal to 2.0 percent of the Transmission Customer's reserved capacity for...

AI summary The document outlines the customer obligation for self-supply or third-party supply of Operating Reserve – Spinning Reserve, which is set at 2.0 percent of the Transmission Customer's reserved capacity for Point-to-Point Transmission Service and 2.0 percent of the Network Load for Network Integration Transmission Service.

- (6) Discounts: Three principal requirements apply to discounts for transmission service as follows: - (i) any offer of a discount made by the Transmission Provider must be announced to all Eligible Customers solely by posting on the OASI...

AI summary The text outlines the requirements for discounts in transmission service, emphasizing that all discount offers and requests must be posted on the OASIS. Additionally, it specifies that once a discount is negotiated, it must be uniformly applied to all eligible customers on unconstrained transmission paths. On-peak days are defined as Monday to Friday.

SCHEDULE 9: REAL POWER LOSS FACTORS For Point-to-Point service, the Transmission Provider will seasonally calculate loss factors to be used on a path-by-path basis. For each season, winter and summer, the power flow models used to calculat...

AI summary Schedule 9 outlines the methodology for calculating real power loss factors for Point-to-Point and Network Service, including seasonal and annual loss factors, and the application of locational loss factors for new generation. It also describes the rate for Network Integration Transmission Service and the formula for transmission congestion charges.

This service is required to schedule the movement of power through, out of, within, or into an Operating Area. This service can be provided only by the operator of the Operating Area in which the transmission facilities used for transmissi...

AI summary The document outlines the requirements for scheduling, system control, and dispatch services within an Operating Area, specifying that these services must be provided by the operator of the Operating Area. It also details the cost structure for these services and how charges are passed through to the Transmission Customer.

SCHEDULE 2: REACTIVE SUPPLY AND VOLTAGE CONTROL FROM GENERATION SOURCES SERVICE In order to maintain transmission voltages on the Transmission Provider's transmission facilities within acceptable limits, generation facilities (in the Opera...

AI summary Schedule 2 outlines the provision of Reactive Supply and Voltage Control from Generation Sources Service to maintain transmission voltages within acceptable limits. This service is provided by the Transmission Provider or through arrangements with the Operating Area operator, with charges passed through to the Transmission Customer based on set rates.

SCHEDULE 3: REGULATION AND FREQUENCY RESPONSE SERVICE Regulation and Frequency Response Service is necessary to provide for the continuous balancing of resources (generation and interchange) with load and for maintaining scheduled Intercon...

AI summary This schedule outlines the necessity of Regulation and Frequency Response Service to balance generation and load, ensuring a stable 60 Hz frequency. The Transmission Provider is responsible for providing this service, and the Transmission Customer must either purchase it or arrange an alternative. Costs are passed through monthly.

SCHEDULE 5: OPERATING RESERVE – SPINNING RESERVE SERVICE Spinning Reserve Service is needed to serve load immediately in the event of a system contingency. Spinning Reserve Service may be provided by generating units that are on-line and l...

AI summary Spinning Reserve Service is required to address system contingencies and must be provided by online generating units operating below maximum output. The Transmission Provider must offer this service, and the Transmission Customer must either purchase it or make alternative arrangements. Monthly charges for the service are outlined, with costs passed through if the Operating Area operator provides the service.

Customer Obligations for Self-Supply and Third-Party Supply The customer obligation for self-supply or third-party supply of Operating Reserve – Spinning Reserve is equal to 2.0 percent of the Transmission Customer's reserved capacity for...

AI summary The document outlines the customer obligation for self-supply or third-party supply of Operating Reserve – Spinning Reserve, specifying it as 2.0 percent of the Transmission Customer's reserved capacity for Point-to-Point Transmission Service and 2.0 percent of the Network Load for Network Integration Transmission Service.

SCHEDULE 6: OPERATING RESERVE – SUPPLEMENTAL RESERVE SERVICE Supplemental Reserve Service (also referred to as Contingency Reserve – Supplemental) is needed to serve load in the event of a system contingency; however, it is not available i...

AI summary This section outlines the requirements for Supplemental Reserve Service, which is used to serve load during system contingencies. It specifies that the Transmission Provider must offer this service, and the Transmission Customer must either purchase it or make alternative arrangements. Charges for the service are outlined and are based on costs passed through by the Operating Area operator.

- (6) Discounts: Three principal requirements apply to discounts for transmission service as follows: - (i) any offer of a discount made by the Transmission Provider must be announced to all Eligible Customers solely by posting on the OASI...

AI summary The text outlines requirements for discounts on transmission service, specifying that all offers and requests for discounts must be posted on the OASIS. Once a discount is negotiated, it must be applied uniformly to all eligible customers on unconstrained transmission paths. On-peak days are defined as Monday to Friday.

SCHEDULE 9: REAL POWER LOSS FACTORS For Point-to-Point service, the Transmission Provider will seasonally calculate loss factors to be used on a path-by-path basis. For each season, winter and summer, the power flow models used to calculat...

AI summary Schedule 9 outlines the calculation and application of real power loss factors for Point-to-Point and Network Service by the Transmission Provider. Loss factors are determined seasonally and annually, with specific rates and formulas provided for Network Integration Transmission Service and congestion charges.

1 and transmission. 2 (Willett) Yeah, and it's all A. 3 generation. 4 Okay. Thank you. Q. 5 And then lastly 6 (Willett) And, sorry, I just want A. 7 to clarify as well, but there are assets within Nova 8 Scotia not related to the Maritime...

AI summary The text discusses a regulatory proceeding involving Nova Scotia Power (NSP) and the Nova Scotia Energy Board (NSEB), focusing on transmission assets, the Maritime Link assessment, and the functionalization of storage assets. It references the Minimum System Study (MSS) and mentions a Settlement Agreement executed on August 29, 2025.

1 A. (Coyne) I'm with you, Mr. Deveau. 2 Q. Okay. So turning to page 61 you 3 starting around line 5 there we'll, first of all, 4 you mention, obviously, the renewable goal and the 5 retirement of coal-fired generation in the first few 6 s...

AI summary The text discusses the Province of Nova Scotia's 2030 Clean Power Plan, which includes adding renewable energy capacity and abandoning the Atlantic Loop project. It also references a Morningstar DBRS report from January 2024, which is positive about the plan for achieving renewable generation targets.

1 I realize it's not a huge amount, but 2 the I understand from the IRs that I think the issue 3 here was that they were not projected in 2024 because you 4 thought they'd be charged at capital. I think you might 5 have just mentioned that...

AI summary The discussion centers on the ECEI initiative and an increase of 700,000 in the 2022 GRA, referencing multiple projects including a transmission project, a large wind project, and battery storage under the ACE Plans.