Topic:"Transmission Planning" in M13007

Note: (1) The AESO also has specific service charges, charged on a per service basis and do not vary by market participant/TO; (2) The number of charges refers to the number of separate tariffs used to recover costs applicable to IESO Nova...

AI summary The text discusses grid charges and incentive-based regulation of Transmission Network Service Providers (TNSPs) in Australia, referencing a 2022 determination by the Australian Energy Regulator (AER) that aims to minimize costs passed on to consumers through AEMO's participant fees.

Types of Charges - Charges that also recover non-Core Costs are marked ( ) Load Generation Intertie traders Transmission owner consumption (MWh); and a tiered, MW-based proportion of substation costs. Other Transmission Service Charges : a...

AI summary The document outlines various types of charges related to transmission services, including those that recover non-Core Costs. These include Demand Opportunity Service (DOS), Export Opportunity Service (XOS), Export Opportunity Merchant Service (XOM), Energy Market Trading Charge, and Balancing Services Use of System (BSUoS), among others. Each charge is associated with specific cost recovery mechanisms and customer classes.

mes, any reduction in exports would simply shift recovery of the revenue requirement to other market participants, creating a potential welfare loss through a distortion of efficient trading patterns. that the billing determinant should re...

AI summary The text discusses how billing determinants should reflect the underlying cost drivers of activities or assets for which costs are being recovered. It highlights that coincident peak load charges are used to recover transmission costs, linking who pays to who causes the cost, promoting economic efficiency. However, for inseparable Core Costs of an ISO, there is no clear cost driver, making it difficult to establish a similar billing determinant.

1.b. Integrated into transmission revenue requirement MPs: A charge levied via the OATT schedule for transmission service would charge the same MPs as the existing OATT schedule, which are domestic (network integration) and export (point-t...

AI summary The document discusses the integration of transmission revenue requirements into the OATT schedule, affecting MPs such as NSP, OATT MEUs, and intertie traders. Billing determinants are based on firm reservation quantity and peak load, with potential for over- or under-recovery of revenue. Adjustments and true-up considerations align with Option 1.a.

Response IR - 9 a)-c) Please refer to NSEB IR-8. It is too early to speculate on the details of a potential OATT and/or peak-load based fee recovery mechanism. IESO Nova Scotia will complete a fulsome evaluation of the suitability of an OA...

AI summary The response discusses the timing of evaluating an Open Access Transmission Tariff (OATT) and peak-load based fee recovery mechanism, noting that it is premature to speculate on details. It also mentions that IRP and long-term planning costs are included in Transmission O&M costs and that OATT rates are set on a $/MW-month basis.

NON-CONFIDENTIAL 97 d) As shown in the FTI Jurisdictional Scan, many of the benchmarked ISOs (including ISO 98 NE, CAISO, IESO Ontario and the AESO) charge ISO Core Costs to intertie traders.6 For 99 more detail, see Table 4 of Appendix 1,...

AI summary The text discusses how ISOs in various jurisdictions, including IESO Ontario and AESO, charge intertie traders for ISO Core Costs. It suggests that not charging these traders may shift costs to domestic load and could be politically less acceptable. The text also speculates that if export volumes increase or IESO Nova Scotia takes on additional functions, charging intertie traders could become more relevant.

- Inconsistent with method IESO allocates costs to MPs Energy % (SLF) Demand % 51.81% 48.19% Transmission ansmission Generation 80.4% 19.6% (To be Determined) Pros

AI summary The text discusses inconsistencies in the method used by the IESO to allocate costs to MPs, highlighting a discrepancy in the distribution of energy and demand percentages, as well as transmission and generation costs.

Option 5: SLF for Gen , Demand for Tx Options Summary ¢/kWh Base cost of fuel Non-fuel Subtotal FAM AA FAM BA Subtotal DSM PCR DSM BA Subtotal SCRR IESO RR Fuel-related in aggregate ¢/kWh ¢/kWh ¢/kWh ¢/kWh ¢/kWh ¢/kWh 9.864 18.919 0.000 0....

AI summary The document presents a detailed breakdown of costs and rates associated with Option 5, focusing on the SLF for Generation and Demand for Transmission. It includes various components such as base fuel costs, non-fuel costs, and adjustments related to DSM, SCRR, and IESO.

pi Power Company 2024 Integrated Resource Plan," with Michael Goggin, Grid Strategies LLC, prepared for Southern Renewable Energy Association, for submission in MPSC Docket No. 2019-UA-231, June 2024. "Unlocking America's Energy: How to Ef...

AI summary The document lists several reports prepared by Grid Strategies LLC and other organizations, focusing on energy planning, grid integration, power demand forecasts, and transmission policies. These reports were submitted to various regulatory bodies and industry groups in the United States.

10 Request IR-4: - 11 Reference: Application, s. 3.3, p.13 Identification of Market Participants, and - 12 Reference: Appendix 2, p. 7, footnote 5. - 13 (a) Please confirm whether any large industrial customer in Nova Scotia is, or 14 in t...

AI summary The request asks whether large industrial customers in Nova Scotia may be directly connected to the transmission system instead of being served through NSPI or an MEU, and if so, how their share of IESO-NS's revenue requirement would be recovered under the Proposed Mechanism.