Topic:"Transmission Planning" in M12551

NON-CONFIDENTIAL Α В С D E F G Н I J K L M Formular A/C B/C G/G11 H I ı J-I J/A K/B Costir ng Deter minants i Catego amount in Adders i n$/kWh Customer Class Sa les On Off 3 C PS Amount in Millions On Off Off Line Relative % Apportion to S...

AI summary The table presents cost breakdowns for transmission and distribution, including on-peak and off-peak figures, percentages, and monetary values. It also includes a section for non-eligible customers and total costs. The text mentions 'Transmission Cost Fixed Cost' as a subheading, indicating a focus on fixed costs related to transmission.

2026 AAR Application Appendix B3 Page 10 of 11 REDACTED (CONFIDENTIAL INFORMATION REMOVED) A B C D E F G H I J K L Formular A/C B/C D H E H I/A 100 I/A 100 Costing Determinants F G 12 Off On Adders Cents/ kWh Average Cost per Cost per Cust...

AI summary The document presents financial and cost data related to transmission and distribution for different customer classes, including sales, cost determinants, and allocation percentages. It includes tables with figures for total generation, transmission, and distribution costs, as well as percentages of on and off-peak sales.

Annual Peak of ATL 2,356,954 Annual Energy Requirement of ATL 11,303,785,142 System Coincident Load Factor 54.748044% ECEI Batteries CWIP $ 15,185 $ 30,370 $ (0) Generation-related Trans Assets Plant $ 58,575 $ 58,575 $ 58,575 Generation-r...

AI summary The text presents data on the Annual Peak and Annual Energy Requirement of ATL, along with detailed tables outlining various costs and assets related to generation, distribution, transmission, and general property plant. It includes figures for different categories such as Generation-related Trans Assets Plant, Distribution, Transmission, and General Property Plant, as well as the Total System Plant in Service and Generation Rate Base classifications.

CONFIDENTIAL (Attachment Only) 1 Request IR-6: 2 3 On page 13 of the application, Nova Scotia Power (NS Power) states that since Q4 2024, the 4 reliability of energy flowing through the Labrador Island Link (LIL) and Maritime Link 5 (ML) h...

AI summary The document includes a request for a table detailing monthly energy data from the Maritime Link (ML) from Q4 2024 to October 2025, in response to concerns about reliability improvements. The response refers to a confidential attachment that has been removed.

NON-CONFIDENTIAL 1 Request IR-10: 2 - 3 In Appendix F4, please explain the increase in Average Unit Cost at the Transmission Level - 4 from 7.688 to 7.835. How does it align with Appendix D in the Costs by Functional Area tab - 5 for the u...

AI summary The request asks for an explanation of the increase in Average Unit Cost at the Transmission Level from 7.688 to 7.835 and how it aligns with Appendix D for Total Transmission unit costs. A response directs the reader to a table for further details.

10 2025 2026 Variance Var (%) MWh Energy Requirement at Generator 10,100,338 11,303,785 1,203,448 11.9 Transmission Line Losses (%) 3.0 2.4 -6.0 -20.0 MWh Load at Transmission Level 9,806,153 11,038,853 1,232,700 12.6 Total Fuel Cost of FA...

AI summary The table presents energy and cost data for 2025 and 2026, showing an increase in MWh energy requirements, a decrease in transmission line losses, and rising fuel costs. These figures highlight changes in energy demand, efficiency, and expenses over the two-year period.

Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 24 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) - Class aggregate hourly load at transmission delivery points will be further aggregated to determine the system aggregate ho...

AI summary The document outlines a process for calculating net hourly spill and net hourly top-up by aggregating load and supply data at transmission delivery points for each LRS, after accounting for transmission losses.

6.3 Relief in Respect of Generation and Load Connected in the Same Distribution Zone Consideration has been given to the transmission tariff treatment where RtR generation and load are connected to the same distribution zone, and thus behi...

AI summary The document discusses the treatment of transmission tariffs for Real Time Retail (RtR) generation and load connected to the same distribution zone. It suggests that if a generator-to-LRS-to-customer system operates entirely within a single distribution network, the LRS payment for transmission services should be calculated as the net of load minus same-zone generation.

• Use of Transmission for Delivery of Services The delivery to the LRS for its customers of Standby Service, Top-up Service and potentially the acceptance of spill all rely on the use of the transmission system. Absent assured 100% reliabl...

AI summary The delivery of Standby Service, Top-up Service, and spill acceptance by the LRS depends on the transmission system. During RtR generator outages, the top-up requirement may reach 100% of the load, necessitating full transmission capacity to the delivery point.

• Congestion Relief Transmission congestion does not generally arise in the last kilometers of transmission delivery, but at a few locations on the Province's bulk transmission system. While there may be differences in impact between RtR g...

AI summary The text discusses transmission congestion, noting that it occurs primarily on the bulk transmission system rather than in the last kilometers of delivery. It also mentions that the impact of RtR generation differs between Cape Breton and the Halifax area, but this difference remains regardless of whether the generation is connected to transmission or distribution systems.

Summarized Rate base from Schedule 2a in 2026 COSS INITIAL CLASSIFICATION AS PER 2026 GRA Application Filing OM&G - Other CTs 2,999 2,999 - 0% - DSM Amortization - - - 0% - FCR Deferral - - - 0% - Reg. Affairs -Advocay Expenses 1,364 617 7...

AI summary The document presents a summarized rate base from Schedule 2a in the 2026 COSS, detailing various classifications such as OM&G, DSM amortization, FCR deferral, and expenses related to generation, transmission, and distribution. It includes figures for different asset categories, depreciation, and revenue components.

Annual Peak of ATL 2,356,954 Annual Energy Requirement of ATL 11,303,785,142 O- 4 0-! 4 1 1 F4 LM6000 Environmental & Fuel Conversion $ - $ - $ - LM6000 Environmental & Fuel Conversion - CWIP ECEI Batteries Plant $ $ - 145,582 $ $ - 119,31...

AI summary The document presents financial and operational data related to energy generation, distribution, and transmission, including figures for annual peak and energy requirements, capital works in progress (CWIP), and various plant and asset costs.

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

AI summary This section outlines special conditions for a high-voltage transmission tariff, including adjustments for metering locations, mandatory use of the Open Access Transmission Tariff (OATT), service denial criteria, service agreements, load integrity requirements, and conditions for attributing capacity credit factor (CCF) values.

Request IR-10: - In Appendix F4, please explain the increase in Average Unit Cost at the Transmission Level from - 7.688 to 7.835. How does it align with Appendix D in the Costs by Functional Area tab for the unit - costs for Total Transmi...

AI summary The document requests an explanation for the increase in Average Unit Cost at the Transmission Level from 7.688 to 7.835 and how it aligns with the Total Transmission unit costs in Appendix D, row (13).