Topic:"Capacity Market Participation" in M12451

Power Production OM&G expense was forecast at $98.7 million in the 2024 GRA compliance forecast. Actual 2024 Power Production OM&G expense was $104.5 million. Figure 7A-2: Power Production 2024 Compliance vs. 2024 Actuals ($ Millions) REDA...

AI summary The 2024 Power Production OM&G expense was higher than forecasted, driven by increased unit utilization and delays in retiring coal units. These increases were partially offset by reduced expenses in renewable energy sources. OM&G expense is expected to rise further in 2025.

water increase due to pricing increases, change in Trenton Unit 5 and Lingari 2 Unit retirement assumptions and increased running nours. 231

AI summary The text discusses an increase in water due to pricing increases, changes in retirement assumptions for Trenton Unit 5 and Lingari 2 Unit, and increased running hours, resulting in a value of 231.

NON-CONFIDENTIAL 1 Request DR-4: 2 3 Please explain whether NS Power views run-of-river hydro (e.g., all but Wreck Cove) to 4 function more like an intermittent resource (ELCC classification) or like a 5 thermal/dispatchable resource (SLF...

AI summary NS Power classifies run-of-river hydro (except Wreck Cove) as dispatchable resources based on their pondage and reliability, while Wreck Cove is treated as a dispatch-limited resource assessed using the ELCC approach.

COSS CA DR-9 Attachment 1 Page 470 of 627 Start Time End Time ANL_MW 9/29/2022 23:00 9/30/2022 0:00 9/30/2022 0:00 9/30/2022 1:00 911.5 869.7 9/30/2022 1:00 9/30/2022 2:00 835.1 9/30/2022 2:00 9/30/2022 3:00 820.9 9/30/2022 3:00 9/30/2022...

AI summary The text provides a table showing the start and end times of an event along with the corresponding ANL_MW values, which likely represent some form of energy or capacity measurement. The data spans from September 29, 2022, to October 2, 2022, and appears to be part of a larger regulatory proceeding document.

COSS IG DR-2 Attachment 1 Page 4 of 4 Capacity Factor Jan-24 Feb-24 Mar-24 Apr-24 May-24 Jun-24 Jul-24 Aug-24 Sep-24 Oct-24 Nov-24 Dec-24 To Date Lingan 1 (oil) 0% 7% 0% 0% 0% 0% 0% 0% 0% 0% 0% 6% 1% Lingan 2 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%...

AI summary The document presents a table showing the capacity factors of various power generation units in Nova Scotia from January to December 2024. The data highlights the performance of oil, natural gas, and other thermal generation facilities, with some units showing higher capacity factors, such as Tufts Cove 3, while others show minimal or no output.

NON-CONFIDENTIAL 2 3 In regards to request number 1 please indicate whether NS Power believes ELCC factor 4 would be preferable to the use of capacity factor for classification of intermediate generation, 5 and if not please provide an exp...

AI summary The document addresses a request regarding whether NS Power believes the Effective Load-Carrying Capacity (ELCC) factor is preferable to the capacity factor for classifying intermediate generation, and if not, an explanation is requested.

15 Revised Table 18 ‐ E3 PRM Study (Section Resource Nameplate Capacity Net Capacity ELCC % Coal 1081 976 90% HFO/Gas 318 232 73% Gas CTs 144 133 93% LFO CTs 231 178 77% Biomass 43 41 95% Hydro 374 355 95% Wind 596 113 19% Maritime Link Ba...

AI summary The table presents the ELCC percentages for various energy resources in Nova Scotia, including coal, gas, hydro, and wind. The Maritime Link base energy imports have an ELCC of 95%, which was adjusted by NS Power in 2022 due to high forced outage rates associated with the Labrador Island Link.

Cost of Service Study Process (NSUARB M11475) NSPI Responses to PHP Data Requests 1 Request DR-14: 2 3 Please provide the following data for any reliability/emergency events called due to limited 4 supply of generating capacity over the pa...

AI summary The document outlines a data request (DR-14) from the NSUARB to NSPI regarding reliability/emergency events due to limited generating capacity between 2019 and 2023. NSPI responds by referring to a table containing information on 20 industrial load interruption events, with details on the Large Industrial – Interruptible Rider (LIIR) tariff.

Agenda - Introduction - COSS from an infrastructure planning perspective - Walk through 2023 COSS calculations - Questions

AI summary The agenda item discusses the Capacity and Operating Service Standards (COSS) from an infrastructure planning perspective, including a walk through of 2023 COSS calculations and an opportunity for questions.

4.9 IPPs IPP contracts will be forecast using the pricing structure and volumes set out in the contract. If the volume is not fixed, the simple average of the last three years of production will be used where available. If discrete changes...

AI summary IPP contracts will be forecast based on the pricing structure and volumes outlined in the contract. If volume is not fixed, the simple average of the last three years of production will be used. Adjustments will be made for changes in IPP capability, and if insufficient data exists, estimates will be based on available information and similar projects.

A-5 IPP CONTRACT SUMMARY ( Confidential ) Summary of IPP contracts including installed capacity and annual energy for the year ended. A-6 PLANT PERFORMANCE ( Confidential/Non-Confidential ) - Summary of capacity factor (non-confidential),...

AI summary The document provides a summary of IPP contracts, including installed capacity and annual energy production for the year ended, as well as details on plant performance metrics such as capacity factor, availability factor, and DAFOR, with some data marked as confidential.

Standardized Filing Requirements for Fuel - Generating Units by Type Year 2026 Net Avg. Heat Rate Thermal Units Fuel Type In Service Year Firm Capacity (MW) (Btu/kwh) Energy (GWh) Tufts Cove 1 Oil / Natural Gas 1965 78.0 32.1 Tufts Cove 2...

AI summary The document outlines standardized filing requirements for fuel generating units in Nova Scotia for the year 2026, providing detailed data on various power generation sources, including thermal units, combustion turbines, hydro systems, wind systems, independent power producers, and imported/exported power, with energy outputs and capacities listed.

Definition: Availability is not a reported CEA measure. It is comparable to the Capability Factor CbF (%), which is the complement of the Incapability Factor. CEA Availability is calculated here as (100% - ICbF). Availability is now a CEA...

AI summary The document defines 'Availability' as a new CEA measure, calculated as (operating hours + available hours) / unit hours for 2016 onwards. It is derived from the complement of the Incapability Factor (ICbF), expressed as (100% - ICbF).

2025 Load Forecast Report Redacted - 1 energy under the Wholesale Market Backup/Top-Up (BUTU) Tariff in cases where their third- - 2 party supply is unavailable or interrupted. Their load is assumed to be served by a third party after - 3...

AI summary The 2025 Load Forecast Report includes the full peak demand of municipal electric utilities taking third-party supply, as NS Power is required to provide backup capacity and must plan for long-term service to these customers.

12 The capacity factors were based on the historical performance of the nearest geographical 13 wind farms to each location. The commercial operation dates were based on contract terms 14 and the best available information at the time of t...

AI summary The capacity factors for wind farms were determined based on historical performance of nearby wind farms, and commercial operation dates were based on contract terms and available information at the time of the forecast. A table is referenced for pricing details of the Rate Base Procurement wind projects.

(1) Unfavourable generation mix As a result of the current generation mix, NSPI is dependent on international suppliers for its fuel supply, exposing the Company to volatile global pricing. This exposure, combined with continued investment...

AI summary NSPI's reliance on international fuel suppliers and coal-based generation has led to higher electricity rates. While the Muskrat Falls project will reduce coal use, coal-based assets will still contribute to the generation mix beyond 2029. Federal and provincial regulations require coal plant closures by 2030, necessitating significant investment in replacements.

2. Unfavourable generation mix As a result of the current generation mix, NSPI is dependent on international suppliers for its fuel supply, exposing the Company to volatile global pricing. This exposure, combined with continued investment...

AI summary NSPI's reliance on international fuel suppliers and higher electricity rates due to its current generation mix pose challenges in passing on costs to ratepayers. While the Muskrat Falls Hydroelectric Project will reduce coal-based generation, coal plants will remain in the mix until 2030, requiring significant investments for replacement.

Page 13 of 16 Nova Scotia Power Inc. January 12, 2024 Operating Statistics For the year ended December 31 Electricity Sold (GWh) % 2022 2021 2020 2019 2018 Residential 46 4,822 4,661 4,652 4,664 4,581 Commercial 29 3,006 2,902 2,850 3,068...

AI summary The document presents operating statistics for Nova Scotia Power Inc. for the years 2018 to 2022, including electricity sold, energy sales growth, installed generation capacity, long-term IPP contracts, energy generated, and total energy production after accounting for transmission losses and internal use.

MODELING APPROACH Capacity expansion and production cost optimization modeling developed least-cost portfolios for each scenario. The scenarios are compliant with current legislation, including the 2030 environmental policy targets of coal...

AI summary The modeling approach outlines capacity expansion and production cost optimization to develop least-cost portfolios aligned with 2030 environmental targets and net zero scenarios. The results include minimized system costs, emissions, reserve margins, and generation profiles.

CAPACITY ADDITIONS The optimized capacity additions highlight the transition of the power system to an increased penetration of variable renewable energy, backed by fast acting firm capacity resources (Battery and Combustion Turbine) as th...

AI summary The document discusses optimized capacity additions in the power system, emphasizing the transition to variable renewable energy supported by fast-acting firm capacity resources like batteries and combustion turbines. Fuel conversions and primary fuel switching, such as coal-to-gas and coal-to-oil, are highlighted as low-cost firm capacity options that ensure reliability during peak demand and resource unavailability.

Item 3a: Thermal Plant Retirement Proceed with Trenton 5 retirement plan based on the updated evergreen IRP projections (2027/2028). NS Power will manage operating restrictions of the thermal fleet to meetfirm capacity requirements are met...

AI summary The document discusses the retirement of the Trenton 5 thermal plant based on updated IRP projections and outlines NS Power's plan to manage the thermal fleet's operating restrictions to meet capacity requirements while minimizing utilization and sustaining capital investment. It also mentions the development of a coal retirement plan with consideration of cold reserve operating modes.

NON-CONFIDENTIAL - 1 Conditions for the projects above to be successfully developed include: - 2 Timely procurement, completion and commissioning of renewable and new fast-acting 3 generation projects. - 4 Successful regulatory approvals a...

AI summary The text outlines conditions for the successful development of renewable and fast-acting generation projects, emphasizing regulatory approvals, stakeholder support, supply chain reliability, and talent availability. NS Power is also considering fuel switching of coal units to meet capacity needs and reduce SO2 emissions post-2030.

Point Aconi - 1 Unit 165 MW, CFB Boiler, In-Service 3/94, Fuel Coal / Pet Coke. - Unit 1 Expected retirement 2029. - o Will be retired by December 31, 2029 - Dates are subject to change - o Can't retire this unit without the new proposed C...

AI summary Point Aconi's Unit 1, a 165 MW CFB boiler fueled by coal and pet coke, is expected to retire by 2029, contingent on new CTs. Mine operations at Point Aconi hold sole resource extraction rights, with uncertainty about their future post-retirement. The limestone quarry at Kelly Rock is tied to the operational life of Point Aconi.

MODELING APPROACH Capacity expansion and production cost optimization modeling developed least-cost portfolios for each scenario. The scenarios are compliant with current legislation, including the 2030 environmental policy targets of coal...

AI summary The modeling approach outlines scenarios for capacity expansion and production cost optimization, aligning with 2030 environmental policy targets and net zero goals. Each scenario considers factors like electrification pace, resource strategy, and the Atlantic Loop, with results focusing on minimizing total system costs through Net Present Value of Revenue Requirement (NPVRR).

Item 3a: Thermal Plant Retirement Proceed with Trenton 5 retirement plan based on the updated evergreen IRP projections (2027/2028). NS Power will manage operating restrictions of the thermal fleet to meetfirm capacity requirements are met...

AI summary The document outlines the retirement plan for the Trenton 5 thermal plant based on updated IRP projections and discusses the management of the thermal fleet to meet capacity requirements while minimizing utilization. It also mentions the development of a coal retirement plan for remaining units, including cold reserve operating modes.

- explanation of the primary factors for the $14.2 million increase from 2024CR to 2027F have been provided by the Company and are detailed below: - Thermal Plants The increase of approximately $10.9 million from 2024CR to 2027F relates pr...

AI summary The $14.2 million increase in operating costs from 2024CR to 2027F is primarily due to increased labour, contracts, and materials costs, driven by changes in the retirement assumptions for Trenton Unit 5 and Lingan Unit 2, as well as increased running hours.

Selected experience - Served as Consulting Expert on behalf of the Public Utilities Commission of Texas in assessing a proposed acquisition of Texas New Mexico Power by Blackstone, Inc. - Led efforts as Procurement Monitor on behalf of the...

AI summary The text outlines the professional experience of an individual who has worked as a consulting expert and auditor in various regulatory and energy-related proceedings across North America, including assessments of utility acquisitions, procurement monitoring, and market design analysis.

This capital item was included in the 2025 ACE Plan for Subsequent Approval as a project with an estimated cost of $1,08 3,801. NS Power indicated that the increase of $173,326 was primarily attributed to the project scope being undefined...

AI summary The document discusses the refurbishment and continued use of LIN2, a thermal power plant, as part of the 2025 ACE Plan. NS Power explains that LIN2 is necessary for winter capacity and system reliability, and its retirement date has been extended to 2027 due to delays in procuring replacement generation. Refurbishment costs have increased due to the need for inspections and necessary work.

ects like it treated projects on other generating units where projects with different scopes of work on different assets are separated, including for Trenton 5 which has a similar retirement forecast. The Board considers LIN2 to present a...

AI summary The Board acknowledges the unique circumstances surrounding the LIN2 generating unit, noting its planned retirement and the need for cold reserve capacity due to forced outages and project schedules. It directs NS Power to submit LIN2 capital improvement projects as a Winter Capacity Requirement application until further notice.

Supplier Obligations Transmission Customers that self-supply this service, and third-party suppliers, shall provide between 100 and 110 percent of the stated MW amount within 30 minutes of notification by the Transmission Provider to activ...

AI summary Supplier obligations require transmission customers and third-party suppliers to provide 100-110% of stated MW reserves within 30 minutes of notification by the Transmission Provider, with penalties for failure to meet these obligations, including a one-month charge for each deficiency.

Customer Obligations for Self-Supply and Third-Party Supply The customer obligation for self-supply or third-party supply of Operating Reserve – Supplemental Reserve will be equal to 8.3 percent of Reserved Capacity for Point-to-Point Tran...

AI summary The document outlines the customer obligation for self-supply or third-party supply of Operating Reserve – Supplemental Reserve, setting it at 8.3 percent of Reserved Capacity for Point-to-Point Transmission Service and 8.3 percent of Network Load for Network Integration Transmission Service.

Request IR-17: - 2026-2027 GRA OE-01A Att 1 CONF, tab "Output 2"; 2026-2027 GRA OE-01A Att 1 CONF, tab "Output 2." a) Please provide assumed equivalent forced outage rate for the Labrador Island Link during - b) Please provide the data in...

AI summary Request IR-17 and IR-18 seek detailed information on energy generation assumptions, contractual arrangements, and financial obligations related to wind farms and the Labrador Island Link. The requests include data on forced outage rates, capacity factors, pricing terms, and how wind farm output interacts with load forecasts and costs.

Supplier Obligations Transmission Customers that self-supply this service, and third-party suppliers, shall provide between 100 and 110 percent of the stated MW amount within eight minutes of notification by the Transmission Provider to ac...

AI summary Suppliers providing Operating Reserve must deliver 100-110% of the required MW within eight minutes of notification and maintain it for 50 minutes. Failure to meet this obligation incurs a penalty equal to one month's charge for the deficient reserves.

1 of possibilities as to exactly where the Control Centre 14 page. Note 6. There's an increase of 49 employees there 15 and it refers to Note 6. And let's go on the next page 16 for Note 6. And Note 6 says: 17 18 19 20 21 22 23 Primarily d...

AI summary The text discusses the retention of two thermal units, Trenton 5 and Lingan 2, due to their importance in serving customer load and providing system capacity. It references past Board decisions requiring approval for operating costs and mentions ongoing requests for operating costs in winter capacity applications.

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

AI summary The Technical Advisory Team reviewed past Canadian studies and found that peak load carrying capability adjustments ranged from 0.2 to 1.0 kilowatts per customer/connection. The Board approved a generic adjustment of 0.4 kilowatts per customer or connection as a reasonable figure.