Topic:"System Reliability" in M12663

r and the Northeast Power - 24 Coordinating Council, Inc. (NPCC), has established a process of ensuring that - 25 responsibility for compliance with the North American Electric Reliability Corporation - 1 (NERC) and NPCC reliability standa...

AI summary IESO Nova Scotia is advancing Integrated Resource Planning (IRP), selected Dunsky as a consultant, and initiated fast-acting generation projects in Pictou County. It has joined the ISO RTO Council and is transferring reliability responsibilities from NPCC and NERC. Key focus areas include completing the 2026 IRP, procurement processes, and aligning with the Clean Power Plan.

1.1 Project Scope This SOW is part of a binding contract, not a sales or marketing document. To support Client's objective to assume full dispatching, balancing authority, and control centre responsibilities in compliance with the More Acc...

AI summary The Statement of Work (SOW) outlines IBM's obligation to provide a Transition Plan and integrated IT/OT/Cybersecurity Roadmap to the Client, enabling them to assume dispatching, balancing authority, and control centre responsibilities under the More Access to Energy Act (2024) , NERC CIP standards, and NPCC requirements, ensuring system reliability and compliance.

Phase 2 – Dispatching and Control (Target: Q2 2027) - - Transfer of real-time system operations, near-term operational planning, balancing authority (BA), and transmission operator (TOP) functions. - - Implementation of independent control...

AI summary Phase 2 focuses on transferring real-time operations, planning, and transmission functions to IESO Nova Scotia by March 2026, with a 2027 go-live. It includes establishing independent control room capabilities, cybersecurity measures, and inter-organizational interfaces compliant with NERC/NPCC standards.

2.2.1. Stage II - Define Control Center and Operational Strategy Purpose: Build and evaluate a set of 4–5 strategic options for how IESO Nova Scotia can deliver dispatch and control functions independently while maintaining system reliabil...

AI summary This section outlines Stage II of the process, which involves defining the control center and operational strategy for IESO Nova Scotia. The purpose is to develop and evaluate strategic options for delivering dispatch and control functions independently while ensuring system reliability and cost efficiency.

NON-CONFIDENTIAL 1 Request IR - 4 2 Reference: Application, p. 8, lines 10-15 3 Subject to the proclamation of certain provisions of the Act, Phase II involves the transfer of real 4 time dispatch operations. Detailed transition planning i...

AI summary The text outlines a regulatory proceeding related to the implementation of Phase II of the Act, focusing on the transfer of real-time dispatch operations. It requests details on unproclaimed provisions of the Act and IESO NS's progress in assessing technology, regulatory compliance, and space requirements. IESO NS states no formal discussions have occurred regarding the proclamation of these provisions.

Project Work Plan and Schedule Date: March 10, 2026 Project Key activities Estimated Completion MAEA Objects NERC & NPCC Compliance Activities -Completion of compliance activities associated with Transmission Planner, Resource Planner, and...

AI summary The document outlines compliance activities related to NERC and NPCC standards, including ongoing tasks for Transmission Planner, Resource Planner, and Planning Coordinator functions. It also mentions the submission of quarterly IESO reports and the due date for the Annual IESO Report as of September 31, 2026.

- 9 Operations (System Planning) Cost Category Cost category 2025/2026 budget ($) (Millions) Actual 2025/2026 at Dec 31 ($) Annualized 2025/26 based on budget not 2026/2027 Proposed Budget ($) (Millions) Difference ($) (Millions) (increase...

AI summary The document presents a budget and actual spending comparison for the Operations (System Planning) cost category in Nova Scotia, highlighting discrepancies between budgeted and actual figures. It also mentions responses from the Nova Scotia Independent Energy System Operator to information requests by the Nova Scotia Energy Board.

Profile Senior energy-sector leader with over 23 years of experience shaping and delivering mission-critical transformation for Independent System Operators and regulated utilities across North America. Deep expertise in control centre str...

AI summary Profile of a senior energy-sector leader with 23 years of experience in system operators and utilities, specializing in control centre strategy, EMS/SCADA modernization, and market systems transformation. Recognized for leading large-scale initiatives for ISOs and utilities, with expertise in grid modernization and system reliability.

Principal Program Manager Major Canadian Transmission Provider, Canada Jun 2020 - Mar 2021 Provided strategic leadership for analytics and operational modernization programs supporting transmission and system operations environments, enabl...

AI summary The Principal Program Manager at a Major Canadian Transmission Provider (Jun 2020 - Mar 2021) led analytics and operational modernization programs to enhance grid intelligence and operational effectiveness in transmission and system operations.

Key Achievements: - Directed mission-critical modernization of Independent System Operator's market systems, dispatch platforms, and operational support environments across a 3-year transformation program. - Led development and delivery of...

AI summary The document highlights achievements in modernizing the Independent System Operator's market systems, developing real-time electricity market operations, and implementing enterprise integration strategies to enhance operational transparency and system reliability over a 3-year program.

One of Europe's largest Electric System Operators Transformation of the scheduling, dispatch and control operations March 2022, March 2025 Christophe was leading the Value Realisation and Business Change Workstreams for one of the largest...

AI summary Christophe led a major business transformation program (2022-2025) for a European electric system operator, focusing on modernizing scheduling, dispatch, and control operations. The initiative involved over 200 FTEs, aimed to realize £600M in benefits during RIIO2, and emphasized adopting a new operating model through stakeholder engagement and performance drivers.

- 17 Figure 2 GUP guiding principles Theme Description Safety Safety is a foundational element of GUP. Utilities are expected to implement and maintain rigorous safety protocols to protect employees, customers, and the public. This include...

AI summary The document outlines the General Utility Principles (GUP) with a focus on safety, reliability, efficiency, regulatory compliance, cost-effectiveness, and transparency. These principles guide utility operations and regulatory decision-making in Nova Scotia.

Response IR-4 - (a) The referenced excerpt from our report pertains to our review of IESO's response to IG-RIR-1, in which IESO provided actual and historical financial records, and a high-level cash flow modeling exercise. Given that the...

AI summary The response discusses the review of IESO's financial forecasts, noting that while a high-level forecast was provided, there was no identified deficiency. The absence of more robust forecasting did not increase risk, but it is recommended for future use. The response also references the early-stage operations of IESO-NS and asks for an explanation of governance risks related to organizational maturity and staff growth.

Policy Context and Organizational Mandate IESO Nova Scotia was established as a not-for-profit under the More Access to Energy Act in October 2024 to take on long-term system planning, new energy resource procurement, and transmission grid...

AI summary IESO Nova Scotia was established under the More Access to Energy Act to manage long-term system planning and energy procurement. The organization faces urgent challenges, including rising demand, renewable energy transition goals, and reliability risks. A recent peak demand event highlighted the need for immediate action, with an RFP for fast-acting generation planned.

The Application Before the Board The Application before you seeks approval of a total revenue requirement of $14.85 million for the 2026/2027 fiscal year. This amount comprises $13.08 million in ongoing operating, maintenance, and administ...

AI summary The application seeks approval of a $14.85 million revenue requirement for IESO Nova Scotia's 2026/2027 fiscal year, comprising ongoing and transitional costs. The applicant argues the amount is prudent and appropriate, reflecting a carefully developed budget aligned with the organization's statutory mandate and the realities of a phased transition. The filing occurred while the 2025/2026 proceeding was ongoing, limiting the opportunity to incorporate prior feedback.

Conclusion While this Application focuses on the 2026/2027 fiscal year, it is only one step in the broader development of IESO Nova Scotia's regulatory and financial framework. We anticipate further engagement with the Board and intervenor...

AI summary The Application for the 2026/2027 fiscal year outlines IESO Nova Scotia's regulatory and financial framework, emphasizing system reliability, transition to clean energy, and institutional capabilities. It highlights the importance of customer needs and the need for prudent, transparent decision-making, with a focus on aligning with the More Access to Energy Act .

Under the authority of Nova Scotia's More Access to Energy Act (2024) (hereafter called 'the Act'), the newly established IESO Nova Scotia is charged with assuming key system-operator functions currently held by Nova Scotia Power (NSP). Tr...

AI summary The IESO Nova Scotia is transitioning key system-operator functions from Nova Scotia Power (NSP) in two phases. Phase 1, Transmission Planning & Procurement, is set for Winter 2025/26, and Phase 2, Dispatching & Control, is targeted for Spring 2027. The IESO is seeking proposals for Phase 2 transition planning, including IT/OT/Cyber security roadmaps and implementation plans to ensure system reliability and regulatory compliance.

- A. A clear definition of the technology capabilities required by IESO Nova Scotia to deliver the Phase 2 dispatching and control functions enabled by the Act, including near-term operational planning, reliable system operations (includin...

AI summary The document outlines the scope of work for Phase 2 dispatching and control functions under the Act, focusing on technology capabilities, strategic options, and a roadmap for implementation. It emphasizes the need to assess existing NSP assets, identify integration requirements, and evaluate the feasibility of meeting the April 2027 delivery date.

Anticipated Work • Develop 4-5 options for the delivery of Phase 2 dispatching and control functions including near-term operational planning, reliable system operations (real-time monitoring of the power system and contingency analysis) a...

AI summary The anticipated work involves developing 4-5 options for Phase 2 dispatching and control functions, including operational planning, system reliability, and efficient generation dispatch in Nova Scotia. The analysis will compare leveraging existing facilities, building new ones, shared services, and inter-regional collaboration, evaluating each option's pros, cons, timelines, costs, and system reliability.

Expected Deliverables - A report with details of the identified options, pros and cons, timelines, costs, extent to which IESO Nova Scotia processes and systems will be separated from or dependent upon NSP and additional other relevant inf...

AI summary The deliverables include a report on options for IESO Nova Scotia, collaboration with NSP, scalability considerations, back office technology changes, real-time operations, and a transition plan and roadmap for future development stages.

Additional Context Phase 1 Transition (system planning, generation interconnection planning and energy procurement) is planned to take place on December 1, 2025. Phase 1 will focus on the transfer of transmission planning and procurement r...

AI summary The document outlines the transition of electricity system planning and operations from Nova Scotia Power (NSP) to the Independent Electricity System Operator (IESO) in two phases. Phase 1, set for December 2025, involves transmission planning and procurement functions, while Phase 2, planned for Q2 2027, includes real-time dispatch operations. The transition considers Nova Scotia’s unique energy landscape and challenges, including cybersecurity recovery and limited interconnectivity.

Innovation and Fit for Purpose Describe how your proposed solution is right-sized for the Nova Scotia context, emphasizing scalability, cost efficiency, and practical implementation given the province's scale and available resources. Descr...

AI summary The text requests a description of a proposed solution's fit for the Nova Scotia context, emphasizing scalability, cost efficiency, and practical implementation, and how it will help the IESO deliver its desired outcomes and accelerate implementation.

Interregional Transfer Capability Study Canadian Analysis Strengthening Reliability Through the Energy Transformation Final Report

AI summary This document presents the final report of an interregional transfer capability study focused on strengthening reliability through energy transformation in Canada.

Electricity is a key component of the fabric of modern society and the Electric Reliability Organization (ERO) Enterprise serves to strengthen that fabric. The vision for the ERO Enterprise, which is comprised of NERC and the six Regional...

AI summary The Electric Reliability Organization (ERO) Enterprise, composed of NERC and six Regional Entities, aims to ensure a reliable, resilient, and secure North American Bulk Power System (BPS). The ERO's mission is to reduce risks to grid reliability and security, supporting the needs of nearly 400 million North American citizens.

Executive Summary The North American grid is a complex machine that has evolved over many decades; it integrates a network of generation, transmission, and distribution systems across vast geographic areas. As a result of the changing reso...

AI summary The North American grid is a complex system that requires a strong, flexible, and resilient transmission network to meet customer demand, especially with changing resource mixes and extreme weather. Canadian systems are vital to the North American bulk power system, and NERC's analysis supports the reinforcement and expansion of inter-regional transmission to ensure reliability, aligning with Canada's Clean Electricity Strategy.

In Scope - A common modeling approach to study the North American grid independently and transparently - Evaluation of the impact of extreme weather events on hourly energy adequacy using the calculated current transfer capability and 10-y...

AI summary The scope includes modeling the North American grid, evaluating impacts of extreme weather on energy adequacy, identifying transfer capability to address energy deficits, and consulting with industry, with reliability as the sole focus.

A Critical Study: Scope and Focus NERC assessment[s](#page-54-6) 8 identified the need for more transmission throughout North America and a strategically planned resource mix[9](#page-54-7) to address these changes and support the ongoing...

AI summary The text discusses the need for enhanced transmission infrastructure and a strategically planned resource mix to support electrification and address challenges from extreme weather. It emphasizes the importance of energy reliability and adequacy, referencing NERC assessments and the Canadian Analysis.

Executive Summary informed planning at a broad interregional level to support future grid reliability and resilience. A common approach, consistent assumptions, and coordinated results were key elements of the Canadian Analysis. The Canadi...

AI summary The Canadian Analysis evaluates transmission transfer capability and energy margin across Canadian regions, emphasizing the need for interregional coordination to improve grid reliability. It does not provide economic or policy assessments, nor does it endorse specific projects or replace existing transmission planning efforts. The study highlights opportunities for optimizing reserve use and the importance of integrated planning.

Geography, Climate, and System Characteristics Most provinces have few major load centers, most of which are near the southern border, with vast and sparsely populated areas further north. Various options must be carefully weighed before d...

AI summary The text discusses the geographical and climatic challenges faced by Canadian provinces, particularly in relation to extreme cold weather events and the impact on energy systems. It highlights the need for careful consideration when planning new transmission lines and the reliance on hydro resources in certain provinces. References are made to various studies and reports, including those from NERC and the Alberta MSA.

Identified Transfer Capability Additions in the Context of Reliability This study identified additions to transfer capability that could mitigate potential grid reliability risks under the most challenging conditions. These additions will...

AI summary This study identifies transfer capability additions that could mitigate grid reliability risks under extreme conditions. It evaluates the impact of these additions on energy adequacy and reserve optimization, focusing solely on reliability. The analysis uses historical weather data applied to 2033 load and resource conditions and excludes economic modeling. The findings suggest potential improvements to energy adequacy through enhanced transfer capabilities.

Key Findings–Energy Margin Analysis (2033) - Canadian systems were found to be increasingly vulnerable during extreme weather due to anticipated load increases and the changing resource mix. Transmission limitations, and potential for ener...

AI summary Canadian energy systems face increased vulnerability during extreme weather due to load increases and resource mix changes. Transmission limitations and energy shortages were identified across multiple regions, with Nova Scotia and Québec facing significant deficits. Enhancing transfer capability, especially between Nova Scotia and New Brunswick, could address these issues.

Chapter 1: Overview of Scope and Terminology This study, which follows the ITCS,[24](#page-64-2) was requested by Canadian government entities and industry leaders and provides valuable insights regarding potential risks to their systems d...

AI summary This chapter outlines the Canadian Analysis, a comprehensive study requested by Canadian government entities and industry leaders to assess transfer capabilities between TPRs and identify potential energy deficits during extreme events. The study uses historical data and modeling approaches to evaluate reliability and inform future planning.

Transfer Capability Additions to Strengthen Reliability Reliability is a broad concept, and significant aspects of required reliability are defined by NERC Reliability Standards and continually implemented through entity planning, investme...

AI summary The document discusses the importance of transfer capability additions to strengthen system reliability, referencing NERC standards and the Canadian Analysis. It highlights the need to improve energy delivery under extreme conditions and outlines NERC's approach to applying consistent criteria for identifying transfer capability additions.

ts, which may take the form of (but are not limited to) new ac or dc transmission facilities, upgrades to enable higher ratings, grid-enhancing technologies, [34](#page-71-1) or a combination thereof. The Canadian Analysis considered a ran...

AI summary The study focuses on transmission capability analysis, using steady-state power flow and contingency scenarios, while acknowledging limitations such as the exclusion of short-circuit and stability analyses. It also notes that deterministic energy assessments were used for extreme weather conditions rather than probabilistic methods.

Contingencies The transfer analysis simulated contingencies, namely the unplanned outage of system elements, to ensure that the system would remain reliable during the energy transfer. The following NERC Reliability Standard TPL-001-5.1[38...

AI summary The transfer analysis simulated unplanned outages of system elements to ensure system reliability during energy transfer. NERC Reliability Standard TPL-001-5.1 was used, focusing on P1 contingencies such as loss of generators, transmission lines, and transformers operating at 100 kV or above.

Figure 4.1: Two-Pronged Approach for Historical Weather Data Note: The hourly energy margin analysis applied historical weather year data to simulate future grid operations under similar conditions but did not simulate historical operation...

AI summary This section discusses a two-pronged approach using historical weather data to evaluate future grid operations under extreme weather conditions. It highlights the use of 12 weather years to simulate load and resource availability, noting that the selected years do not represent all possible extreme weather scenarios.

Thermal Generator Outage Modeling Thermal generators were aggregated by TPR and fuel type to account for daily fluctuations in available capacity. Thermal capacity was aggregated by up to eight fuel types in each TPR, resulting in 290 uniq...

AI summary Thermal generator outages are modeled by aggregating generators by TPR and fuel type to reflect daily fluctuations in capacity. Data from the GADS system and utility reports are used to analyze forced and planned outages, showing seasonal and daily variations. Unlike the U.S., Canadian systems show no significant correlation between outages and cold temperatures, but some regions face reliability risks with simultaneous outages.

Resource Scheduling Method The hourly energy margin is then used to model the available energy across the entire North American BPS for all 12 weather years. This is done to consider the energy adequacy in each TPR, with and without transf...

AI summary The resource scheduling method models hourly energy margins across North American BPS for 12 weather years, focusing on energy adequacy within and between TPRs. It prioritizes reliability by scheduling resources within a TPR before relying on transfers, and uses scarcity weighting factors to drive dispatch decisions based on surplus or scarcity rather than cost.

Margin Levels Margins were applied to each TPR's hourly load to account for study uncertainty and operational practices. Unlike a Planning Reserve Margin, which is often denoted in terms of peak demand, these margins are applied to all hou...

AI summary Margin levels are applied to each TPR's hourly load to account for uncertainty and operational practices. The tight margin level is set at 10% of the TPR's load to determine when energy imports are needed, while the minimum margin level is set at 3% to determine when load reduction may occur if resources are unavailable. The Advisory Group endorsed these levels after discussions.

Metrics Three important points can be considered in [Figure 5.4](#page-99-0) above: • Point 1 indicates that a TPR, in isolation, is below the tight margin level but there is sufficient transfer capability to import energy from its neighbo...

AI summary The text discusses three key points related to transmission planning regions (TPRs) and their margins. It explains interchange hours, tight margin hours, and resource deficiency hours, highlighting how transfer capability and load management affect system reliability and energy availability.

Criteria The following criteria[75](#page-103-2) were applied when finalizing transfer capability additions: - Additions were made to maintain a 3% minimum margin level[76](#page-103-3) if possible. - Where practical, all resource deficien...

AI summary The criteria for adding transfer capability focus on maintaining a 3% minimum margin level, mitigating resource deficiency hours above 300 MW, and ensuring additions are rounded to the nearest 100 MW. These additions aim to improve reliability by reducing resource deficiency, with specific thresholds for effectiveness.

2024 Energy Margin Analysis Results The results of the energy margin analysis for the 2024 case are summarized in Table 6.1 , which provides an overview of the maximum resource deficiencies observed across various TPRs and weather years. T...

AI summary The 2024 Energy Margin Analysis Results summarize the maximum resource deficiencies observed across various TPRs and weather years, highlighting winter and summer shortfalls. The analysis considers resource sharing between TPRs based on availability and transfer capabilities.

The 2024 case was used for benchmarking, but the simulations did not attempt to recreate actual operations. is largely capable of maintaining energy adequacy across diverse scenarios except under the most challenging conditions. The 2024 c...

AI summary The 2024 case serves as a benchmark for evaluating future energy adequacy, particularly in the 2033 scenario. Simulations applied historical weather conditions to the 2024 resource mix, revealing insights into potential impacts of future changes in resource mixes, load growth, and extreme weather events. Tables 6.2 and 6.3 quantify resource deficiencies in terms of energy (GWh) and hours of deficiency.

2033 Energy Margin Analysis Results The 2033 case analysis mirrors the 2024 analysis but accounts for continued load growth, retirements, and new resource additions. The assumptions for load growth, retirements, and resource additions were...

AI summary The 2033 Energy Margin Analysis builds on the 2024 analysis, factoring in continued load growth, retirements, and new resources. Projections from the 2023 LTRA inform the assumptions. Table 6.4 outlines maximum resource deficiencies across TPRs and weather years, with purple highlighting indicating deficiencies in both summer and winter.

In the 2033 case, six out of eight TPRs are affected by resource deficiencies in at least one weather year and, in many cases, across multiple weather years. Three of these TPRs had no deficiencies in the 2024 case. Similar to the 2024 res...

AI summary In the 2033 case, six out of eight TPRs experience resource deficiencies across multiple weather years, unlike the 2024 case where three TPRs had no deficiencies. Tables 6.5 and 6.6 provide quantitative data on the energy basis (GWh) and duration (hours) of these deficiencies.

6% Minimum Margin Level Sensitivity In this sensitivity analysis, the minimum margin level was increased from 3% to 6%, effectively reducing the surplus energy in all TPRs simultaneously. This adjustment increased the size, frequency, and...

AI summary This sensitivity analysis increases the minimum margin level from 3% to 6%, leading to greater resource deficiencies in six TPRs. The adjustment affects the size, frequency, and duration of deficiencies, as well as the number of TPRs impacted and the magnitude of transfer additions evaluated.

Resource Deficiency Events Section - The summary statistics for each day of resource deficiency in the base 2033 case are provided if applicable. - Daily peak demand represents the day's highest load, regardless of when it occurs. Resource...

AI summary This section discusses resource deficiency events in the base 2033 case, providing summary statistics for each day of resource deficiency. It explains that daily peak demand is the highest load of the day, and resource deficiency hours can occur before or after the peak due to variable renewable and energy-limited resources.

Capacity and Load Data (in MW) MISO-W to Manitoba 0 801 N/A N/A N/A Saskatchewan to Manitoba 106 473 N/A N/A N/A Total Import Interface Limit 1,961 2,483 Total Import Interface Limit + dc-only Interfaces Limit 1,961 2,483 (as % of 2033 Sea...

AI summary The document presents capacity and load data, including import interface limits, energy adequacy by iteration, and resource type details for 2024 and 2033. It outlines thermal, hydro, and variable renewable resources, along with peak demand figures for summer and winter.

Capacity and Load Data (in MW) Total Import Interface Limit 170 100 500 670 600 Total Import Interface Limit + dc-only Interfaces Limit 170 100 500 670 600 (as % of 2033 Seasonal Peak) 12% 4% 45% 22% Energy Adequacy by Iteration Tight Reso...

AI summary The table presents capacity and load data, including import interface limits and energy adequacy by iteration, showing decreasing resource deficiencies across iterations, with the final iteration indicating no deficiency.

While this study represents a pioneering and comprehensive effort to evaluate transfer capability into and within Canada and its impact on energy adequacy, it also had limitations. These factors highlight the need for additional work to bu...

AI summary This study evaluates transfer capability within Canada and its impact on energy adequacy but acknowledges limitations. It outlines future work areas, including exploring resource mixes, expanding weather datasets, and evaluating stability during extreme weather events.

This section provides additional iteration-specific detail for each province with identified resource deficiencies.

AI summary This section provides additional iteration-specific detail for each province with identified resource deficiencies.

Request IR-14: - Reference: Application page 4, "Phase II involves the transfer of real-time dispatch operations. - Due to the complexity of this transition and the direct impact on real-time applications and system - reliability, addition...

AI summary Phase II of the application involves transferring real-time dispatch operations, requiring additional planning due to complexity and impacts on system reliability. IESO Nova Scotia has engaged a third-party consultant via competitive process to deliver a plan, target date, and budget by early 2026.

r functions from NS Power was expected to occur in Q4 2025. On page 4 of the present application, IESO Nova Scotia notes that Phase I has not yet been achieved, but significant progress has been made. 1. Please outline the steps in Phase I...

AI summary The document discusses the progress and delays in the transition of system operator functions from NS Power, referencing Matter M12412 and the current application. It outlines questions regarding the completion of Phase I, the definition of Phase II, and the meaning of the term 'aspirational' in the context of timelines.

A. OVERVIEW Despite the concerns raised by intervenors, the circumstances underlying IESO Nova Scotia's request are clear, urgent, and exceptional. As this rebuttal demonstrates, temporary financial relief is required immediately to ensure...

AI summary IESO Nova Scotia seeks urgent interim financial relief due to lack of approved fees and reliance on a credit line, risking insolvency and operational failures. The request emphasizes temporary FAM use, pending prudency determinations in 2025–2026 and 2026–2027 proceedings, and statutory authority under MAEA. Customer safeguards and transition to independence are highlighted as critical.

ieces accruing to IESO NS could have been resold, IESO NS did not actually [ 41 ](#page-27-1) IESO NS Opening Statement, Exhibit N-16. [ 42 ](#page-27-3) Report of the Auditor General of New Brunswick, Performance Audit, Volume 1, Chapter...

AI summary The IESO NS faced significant financial risks due to its arrangement with the New Brunswick Board, which exposed ratepayers to potential losses. The IESO's history of risk-taking is highlighted by its last-minute request for interim financial relief amid insolvency concerns, which the Board granted to prevent further harm, but criticized as a poor start for the organization.

14 M12633 Transcript, June 25, 2026, pages 120 - 122. 297 Undertaking U-7. 298 299 The not-for-profit nature of IESO Nova Scotia is a significant factor that must be taken into 300 account. If IESO Nova Scotia does not have the funding to...

AI summary The not-for-profit nature of IESO Nova Scotia is highlighted as a critical factor in its ability to carry out its mandate. The document emphasizes the importance of accurate forecasting and the potential consequences if IESO Nova Scotia lacks sufficient funding for energy system planning, resource procurement, and electricity supply reliability.

OPENING STATEMENT 27 IESO NOVA SCOTIA 1 In these roles, I've testified in 13 reaching 80 percent renewable electricity sales by 2030 14 and increasingly pressing energy supply reliability risks. 15 Reliability is a specific area of 16 conc...

AI summary The IESO Nova Scotia highlights growing energy supply reliability risks, citing the latest Long-Term Resource Adequacy Report and a near-crisis event in January 2026. Nova Scotia failed to meet resource adequacy needs and is preparing to launch a request for proposals for fast-acting generation.

IESO NOVA SCOTIA PANEL 45 Cr-ex, (Murphy) 1 to progress a facility that has an extremely long lead 9 the overall risk we deemed to be perhaps quite a bit lower 10 than what you would have noted because there are many 11 other projects that...

AI summary The discussion centers on the risks and benefits of proceeding with a long-lead-time project, noting that other projects could benefit from the equipment. The need for timely action is emphasized to ensure electricity supply reliability, and the involvement of NB Power is highlighted as a key enabler.

IESO NOVA SCOTIA PANEL 487 Questions, (Chair) 1 A. (Johnston) That is correct. 19 that's the expectation. 1 Q. And as far as your audit, I know 2 it's ongoing, has it been going smoothly? 3 A. (Johnston) Yes, I would describe 4 it as smoot...

AI summary The discussion centers on the ongoing audit and a reference to a NERC long-term reliability assessment, highlighting Nova Scotia's electricity supply reliability risks and its failure to meet resource adequacy needs. The conversation includes clarification on the timeline of the NERC report (2026 to 2030).

IESO NOVA SCOTIA PANEL 489 Questions, (Chair) 1 Canadian Analysis that came out in 2025, which was just 2 for Nova Scotia. 3 [1:00:28] Q. Okay. And that was you 4 anticipated my question, where I was going with that. And 5 that study, is t...

AI summary The discussion references a 2025 Canadian Analysis study on interregional transfer capability and addresses the NERC categorization of the NPCC Maritimes area as elevated risk. The study is to be filed as Undertaking U-11, and there is a question about the distinction between elevated and high-risk classifications by NERC.