Topic:"System Reliability" in M08059

ovision Constraints ........................................... 17 Emission Constraints ............................................................................................................... 17 Available Resource New Build Costs ....

AI summary The document outlines sections of a modeling analysis covering emission constraints, resource costs, wind capacity credits, transmission infrastructure, coal plant retirement timelines, and sensitivity analyses. It references a final report by Synapse Energy Economics, Inc. on thermal generation utilization and optimization for Nova Scotia Power.

nd assumptions in a memo dated October 16, 2017. Additional updates to these assumptions, also based on stakeholder comments, were provided in December 2017 memo. The key aspects are described below. 2.1. Modeling Methodology Plexos Synaps...

AI summary The document outlines Synapse's use of the Plexos Integrated Energy Model to simulate Nova Scotia's energy futures through long-term (LT) capacity expansion and short-term (ST) production cost modeling. Key factors include capital/production costs, system constraints (emissions limits, transmission), and resource optimization under NSPI's planning framework.

ractual quantities (NS Block and Supplemental Energy) and allows for both Maritime Link Surplus Energy to be available for purchase and for incremental non‐firm imports (and exports) to New Brunswick. Synapse developed a modeling plan and...

AI summary Synapse Energy Economics collaborated with NSPI to model thermal generation optimization using Plexos, incorporating updated fuel costs, sustaining capital estimates, and renewable energy sources (wind, solar, battery storage). The analysis included reserve margin requirements aligned with NPCC reliability criteria and scenarios for new capacity additions.

napse set the Plexos model to maintain a 20 percent reserve margin in all years when making build/retire decisions, in accordance with Northeast Power Coordinating Council (NPCC) reliability criteria. Additional modeling scenarios were des...

AI summary The analysis uses the Plexos model with a 20% reserve margin per NPCC reliability criteria, exploring scenarios involving peak load, wind capacity credit, transmission expansion, capital expenditures, battery storage costs, gas prices, and coal plant retirements. Post-processing of model outputs standardizes data and calculates revenue requirements to compare NPV of scenarios.

ze the format of the data to facilitate analysis, and, second, to build a revenue requirement calculation in order to compare the overall net present values of the various scenarios and sensitivities. As a first step, Synapse takes the raw...

AI summary Synapse Energy Economics processes Plexos modeling outputs into Excel for revenue requirement calculations and NPV comparisons. The analysis highlights Plexos' inability to model Tufts Cove unit retirements due to software limitations, recommending system constraint evaluations prior to the next IRP process.

Sust Wind NB HardCode Scen. # Scenario Name Load Capital CapCredit Trans RetirePath 1 Ref Ref Ref Ref No No 2 Med DSM Med DSM Ref Ref No No 4 Ref/HighSusCap Ref High Ref No No 5 Med DSM/HighSusCap Med DSM High Ref No No 7 Ref/HighWindCapCr...

AI summary The table outlines various scenarios with different combinations of demand-side management (DSM), capacity credits, and transmission (NB Trans) options. The note highlights 'RetirePath1,' which includes forced retirements of coal plants beyond Lingan 2 in 2020/21, specifically Lingan 4 (2023) and Lingan 3 (2024), modeled in Plexos.

Link to flow energy to Newfoundland in winter prior to Muskrat Falls completion, if needed, and with Newfoundland’s agreement to allow recall energy to flow to Nova Scotia during non‐winter months.19 Transmission/Unit Commitment/Reserve Pr...

AI summary The document discusses the constraints related to transmission, unit commitment, and emission limits in NSPI's energy system, including the use of Plexos modeling to ensure compliance with reserve margin requirements and emission standards.

capital costs incurred a range of 6.5% to 10.4% of total NPVRR costs in our main scenarios. It is critical to continue to assess the pattern of these costs and project future costs. 5. Establish requirements to allow increased levels of wi...

AI summary The document discusses capital costs and the need to assess their future impact. It also outlines requirements for increasing wind energy on the NSPI system, including infrastructure improvements and coordination with neighboring provinces for reliability with increased wind resource utilization.

s of resources. Our aim is to provide a modeling analysis that shows the costs of retention versus the costs of alternative resource plans that use a different mix of resources to meet capacity needs. The analysis proceeds in an electric s...

AI summary The analysis compares the costs of retaining coal resources versus alternative resource plans, considering declining renewable energy costs, increasing coal costs, infrastructure changes like the Maritime Link, and carbon emission reductions. It evaluates economic viability of coal amid aging plants and uncertain gas prices.

See NSPI 2017 Declining cap per regulations 2030-2042 Steeper Cap Carbon / CO2 emissions NSPI 2017 10-Yr. System through 2030, and continuing Decline (5%/year) Outlook p. 34 @ ~2.5%/yr thereafter. See NSPI 2017 Declining cap per regs. thru...

AI summary The text outlines NSPI's 2017 carbon and pollutant emission caps, detailing declining limits for CO2 through 2030 and beyond, with specific reductions for SO2, NOx, and Hg. It references gas-fired combined cycle (CC) and combustion turbine (CT) costs, noting capital expenditures and operational metrics from Table 5.

llions of dollars of projected sustaining capital on those facilities still remains outstanding. In addition, analysis of storage options and wind capacity contributions deserve greater consideration. In order to move forward with these ma...

AI summary The Board engages Synapse Energy Economics Inc. to analyze generation resource utilization and cost-effective options for Nova Scotia ratepayers. A reclassification of thermal units is deferred until after the 2017-2019 rate stabilization period. Stakeholders will review Terms of Reference, and NSPI will provide technical data for analysis.

g resource adequacy requirements), or they affect the capacity contributions available from existing and potentially new alternative capacity resources. The eight action items are characterized below: 1. Optimize the level of sustaining ca...

AI summary The text outlines eight action items addressing resource adequacy, including optimizing fossil fuel capital expenditures, conducting wind penetration studies, regional coordination, evaluating wind capacity value, monitoring market opportunities, assessing demand response, securing DSM commitments, and evaluating Mersey Development. These focus on reliability, transmission, and renewable integration.

through programmatic efforts to achieve peak demand reduction through demand response options beyond those currently obtained via interruptible industrial load. 2 – Conduct Additional System Studies NSPI has not yet conducted any updates t...

AI summary NSPI proposes demand response beyond interruptible industrial load for peak reduction but lacks updated studies on wind penetration and transmission support. Storage options are deemed non-competitive based on Levelized Electricity Cost to Grid, though broader system reliability and coal plant retirement scenarios require further analysis.

% to 46% of capacity and Quebec’s use of 30%.9 The contribution of wind resources to capacity requirements must continue to be carefully examined; if Nova Scotia was to use a capacity credit of 20% 8 EPRI, Energy Storage Cost Summary for U...

AI summary The text examines Nova Scotia's capacity requirements, emphasizing the need to assess wind resource capacity credits and explore import capacity via the Maritime Link and New Brunswick. It highlights the potential of demand response and energy efficiency programs to address resource adequacy gaps, particularly under different coal plant retirement scenarios.

t paths. Additional firm capacity could also be available across the Maritime Link to meet resource adequacy needs. 6 – Demand Response and DSM Resource Commitments through Energy Efficiency Programs NSPI’s need for capacity resources is p...

AI summary NSPI's capacity needs are based on meeting peak load, which occurs infrequently. Demand response mechanisms could reduce the need for up to 300 MW of capacity. The 2016 load duration curve illustrates that peak loads are brief, suggesting demand response could address most capacity requirements.

7009 7885 8761 Hours per Year Load Greater than Indicated Value Source: NSPI OASIS, Hourly Load Data, 2016. 10 Based on 600 MW (20% ‐ 12%). 7 In the most recent load forecast, NSPI projects increasing peak load. In response to the Board’s...

AI summary NSPI's load forecast projects increasing peak demand, citing Synapse's report as justification. However, Synapse recommends refining peak load calculations due to historically flat historical peaks. The text argues for urgent analysis of alternatives to coal plant investments, emphasizing a portfolio approach over single substitutions to ensure cost-effective, reliable service.

Peak Season Demand, Resources, and Reserve Margins Demand (MW) 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 Total Internal Demand 5,584 5,608 5,627 5,623 5,622 5,608 5,580 5,552 5,509 5,518 Demand Response 272 272 272 272 271 271 271...

AI summary The table presents historical and projected data on peak season demand, available resources, reserve margins, and resource excess/shortfall in Nova Scotia from 2017 to 2026, highlighting trends in energy system reliability and planning.

240 257 290 324 375 357 Prospective 361 218 309 314 315 332 365 398 450 426 NPCC CP-8 Working Group 46 Approved by the RCC - December 6, 2016 NPCC 2016 LONG RANGE ADEQUACY OVERVIEW Peak Season Reserve Margins 10-Year On-Peak Generation Ant...

AI summary The document presents a 2016 long-range adequacy overview by the NPCC CP-8 Working Group, focusing on peak season reserve margins and 10-year on-peak generation additions. It was approved by the RCC on December 6, 2016, highlighting infrastructure planning and system reliability considerations.

Probabilistic Assessment Overview  General Overview – The Maritimes Area is a winter peaking area with separate jurisdictions and regulators in New Brunswick, Nova Scotia, Prince Edward Island (PEI), and Northern Maine. The GE MARS model...

AI summary The Maritimes Area probabilistic assessment uses the NPCC's GE MARS model to evaluate resource adequacy, showing minimal changes in LOLH and EUE despite increased demand from electric heating. Capacity resources and operating procedures mitigate reliability risks, aligning with a 20% reserve margin criterion.

reserve criterion of 20% to the NPCC resource adequacy criterion, LOLE was evaluated with the Maritimes Area firm load scaled so that the reserve was equal to 20%. The results showed that a Maritimes Area reserve of 20% corresponds to an L...

AI summary The analysis evaluates the Maritimes Area's resource adequacy using a 20% reserve criterion aligned with NPCC standards, resulting in an LOLE of 0.086 days/year. Modeling assumptions align with the NPCC 2016 Long Range Adequacy Overview and NERC RAS assessments, emphasizing probabilistic resource adequacy frameworks.

Base Case Study Summary of Results  No significant LOLH is observed. EUE Reserve Margin (RM) % is 0.005 in 2018 and negligible in 2020. Base Case Sensitivity Case Anticipated Reserve Margins are well above 20% in both years. The greatest...

AI summary The analysis shows no significant Loss of Load Hours (LOLH) or Expected Unserved Energy (EUE) in both the Base and Sensitivity Case Studies. Reserve Margins (RM) remain well above 20% in 2018 and 2020, indicating strong system reliability. Anticipated RM values are 26.42% in 2018 and 24.37% in 2020 under the Base Case, with similar trends in the Sensitivity Case.

0.000 0.000 0.001 0.000 Margins remain above 20% in 2018 and LOLH (hours/year) 0.000 0.000 0.000 0.000 near 20% in 2020. Summary The Maritimes Area is comprised of four sub-areas, New Brunswick (NB), Nova Scotia (NS), Prince Edward Island...

AI summary The Maritimes Area (NB, NS, PEI, NM) uses a 20% reserve margin target aligned with NPCC's 0.1 days/year loss of load expectation. Resource adequacy reviews confirm this correlation. Load growth is flat (0.2% summer, -0.13% winter annually), though NB's southeast outpaces others. DSM programs aim to manage peak demand, and NB Power has upgraded infrastructure.

mands and potential NPCC CP-8 Working Group 48 Approved by the RCC - December 6, 2016 NPCC 2016 LONG RANGE ADEQUACY OVERVIEW imports to NB from NS that may begin after the completion of the HVDC interconnection to the Canadian province of...

AI summary The document discusses energy efficiency program growth in New Brunswick, Nova Scotia's planned renewable capacity additions (wind, solar, biomass), and potential impacts of retiring a coal plant. It notes that HVDC interconnection to Newfoundland may offset coal retirement, with reliability concerns if hydro capacity delays occur.

ith the Canadian province of Newfoundland and Labrador. Should a delay occur in the introduction of energy from the new hydro capacity, the retirement of the coal unit will be correspondingly delayed? Renewable Energy Standards (RESs) have...

AI summary The text discusses renewable energy developments in New Brunswick and Nova Scotia, including wind generation capacity deratings, the Maritimes Link project's role in providing hydro resources, and a planned coal unit retirement in Nova Scotia offset by hydro capacity via an HVDC cable to Newfoundland and Labrador. It highlights challenges with frequency response from wind generation and regional differences in capacity derating methodologies.

the unit retirement are comparable and are planned to coincide in timing so that the overall resource adequacy is unaffected by these changes. This HVDC cable project is currently under construction. Transmission development in the Maritim...

AI summary The document outlines transmission developments in the Maritimes, including HVDC cable projects and upgrades to mitigate contingencies and improve resource adequacy. Key projects include a 345 kV breaker installation, undersea cables between NB and PEI, and the Maritime Link HVDC cable between Newfoundland and Labrador and NS, planned for completion by 2018.

a second 345/138 kV NPCC CP-8 Working Group 49 Approved by the RCC - December 6, 2016 NPCC 2016 LONG RANGE ADEQUACY OVERVIEW transformer will be added in parallel with an existing unit at the Keswick terminal in NB to mitigate the effects...

AI summary A 345/138 kV transformer will be added at Keswick terminal in NB to address contingencies. The Maritimes hydro system (1330 MW, run-of-the-river) relies on thermal units for storage and spinning reserves to ensure reliability during extreme weather or wind disruptions, without modifying planning assumptions.

nning reserve is available to cover the loss of the largest base loaded generator in the area. The latter situation is mitigated further by wide geographic dispersal of wind resources across the Area. The Maritimes Area has a diversified m...

AI summary The Maritimes Area maintains resource adequacy through diversified capacity resources (nuclear, oil, coal, natural gas, hydro, wind, biomass) and geographic wind dispersal. Fuel diversity reduces reliance on single sources, with no anticipated disruptions. Ramp rate variability analysis shows minimal changes expected during the LTRA assessment period, though historical data is limited.

File No: SM002557-00003 Nancy G. Rubin, Q.C. Direct Dial: 902.420-3337 [email protected] April 27, 2017 Delivered by E-mail Doreen Friis Regulatory Affairs Officer/Clerk Nova Scotia Utility and Review Board 3rd Floor 1601 Lower Wa...

AI summary NSPI responds to the Nova Scotia Utility and Review Board's concerns regarding its 10-Year System Outlook Report, noting increased peak demand despite declining energy sales. It explains that variable renewable integration has altered steam unit utilization, requiring low-capacity thermal units to meet capacity needs and maintain reserve margins.

ed to serve firm peak demand and maintain the system’s planning reserve margin.2 (emphasis added) 1 NSPI 10-year System Outlook Report, p.18 2 NSPI 10-year System Outlook Report, p. 25 3090853 v1 Doreen Friis April 27, 2017 Page 2 In other...

AI summary The text discusses NSPI's capacity factors for power plants, discrepancies in data provided, and planning challenges due to federal policies like carbon pricing. It highlights the need for accurate information and flexibility in planning amid regulatory uncertainty.

Multeese Consulting Incorporated 163 Parkerest Drive. Lawrencetown. N.S. B27, 1M1 April 26, 2017 Doreen Friis, Regulatory Affairs Officer/Clerk Nova Scotia Utility and Review Board 1601 Lower Water Street Halifax NS B3J 3P6 Dear Ms. Friis:...

AI summary NSPI argues for maintaining its thermal generators until end-of-life, except Lingan 2, which would retire with Newfoundland power availability. Key reasons include meeting 1% annual firm load growth, 20% reserve margin needs, economic efficiency of existing units over replacement, and limited wind firm capacity (17% NRIS). Wind requires load-following capacity from thermal units.

es with respect to environmental concerns in both the short and long term, and technological developments with respect to renewables and storage. This option typically takes about a year to complete. With respect to the second option, this...

AI summary The text outlines two options for addressing environmental and technological considerations: a comprehensive one-year plan and a six-month screening exercise to evaluate alternatives to NSPI’s coal plant operations. The author recommends the latter, suggesting it could identify more cost-effective solutions or necessitate adjustments to NSPI’s plan or further IRP work.

echnical Conference, NS Power discussed its intention to improve its engagement process. 1 NSUARB Letter, 10‐Year System Outlook Report, February 9, 2017, M07540. April 27, 2017 D. Friis Stakeholders brought to the Company’s attention more...

AI summary NS Power aims to improve stakeholder engagement following feedback on its thermal unit utilization and investment strategy. Key discussion topics include reserve margin requirements, federal coal legislation impacts, gas consumption outlook, and regional transmission interconnections. Stakeholders emphasized the need for transparency on resource adequacy planning and potential alternatives to NS Power's existing investment strategy for fossil fuel units.

g resource adequacy requirements), or they affect the capacity contributions available from existing and potentially new alternative capacity resources. The eight action items are characterized below: 1. Optimize the level of sustaining ca...

AI summary The document outlines eight action items addressing resource adequacy, including optimizing capital expenditures for fossil-fueled plants, conducting system studies for higher wind penetration, regional coordination with Newfoundland and New Brunswick, evaluating wind capacity value, exploring market opportunities, assessing demand response, securing DSM commitments, and evaluating Mersey Development's 30 MW capacity addition.

stated at the 4/13/2017 technical conference, is not well-supported. It is not at all clear that lengthy retention of the coal units was the most economic option arising from the 2014 IRP analysis. 5 5 A truer optimization, given the model...

AI summary The text critiques the 2014 Integrated Resource Plan (IRP) for inadequately evaluating alternatives to retaining coal units, emphasizing the need for iterative analysis to compare resource plans. It highlights demand-side management (DSM) and alternative capacity options (e.g., wind, storage, demand response) as more economical solutions and recommends additional system studies.

through programmatic efforts to achieve peak demand reduction through demand response options beyond those currently obtained via interruptible industrial load. 2 – Conduct Additional System Studies NSPI has not yet conducted any updates t...

AI summary NSPI has not conducted updated studies on wind penetration or transmission system support needs for higher wind integration. It acknowledges reduced steam unit requirements by 2020 but emphasizes the need for further analysis on coal plant retirement scenarios. Storage alternatives were discussed but deemed 'not cost competitive' based on Levelized Electricity Cost to Grid assessments.

options “are not cost competitive” compared to traditional solutions. 9 However, this conclusion was based on an assessment of the Levelized Electricity Cost to Grid, 10 and did not capture the value analysis (e.g., during the 2020s). An i...

AI summary The text discusses the cost competitiveness of energy solutions, noting that some options are not cost-effective based on Levelized Electricity Cost to Grid assessments. It highlights the potential of iterative modeling to reduce costs and references studies on synthetic inertia and energy storage. The GE 2013 wind integration study and Lazard's LCOS 2.0 analysis are cited as key resources.

NSPI’s projected requirements. Any analysis must first rigorously explore the cost and capability of demand side options, and accurately represent their attributes in any capacity expansion exercise. 14 NSPI response to NS UARB IR-2 (b-c)....

AI summary NSPI argues that its example of substituting a combustion turbine for a coal plant oversimplifies capacity expansion considerations, emphasizing variable factors like capital costs and locational economics. The analysis must rigorously evaluate demand-side options and include updated assumptions for supply-side alternatives, addressing system ramping and ancillary service needs under varying renewable penetration scenarios.

. As a general observation, the Industrial Group recommends one base set run with the current forecast of load and capital and then sensitivity runs with a high and a low scenario. ATL and BTL Loads The structure of the “Below-the-Line” (B...

AI summary The Industrial Group recommends analyzing load scenarios with and without Below-the-Line (BTL) loads, noting that serving BTL may be cheaper than serving Above-the-Line (ATL) due to NSPI's high-cost generation portfolio. Synapse highlights that demand response could reduce peak load needs but warns that increased interruptions from a smaller thermal fleet may push customers toward firm load.

pital assumptions will be included for new resources, both fueled and renewable?  How will the declining capacity value of new incremental wind resources be accounted for? NS Power has reviewed the example assumptions provided in the Term...

AI summary NS Power discusses challenges in system stability analysis for new resources, emphasizing the need for independent studies due to changing transmission and system conditions. It highlights reliability risks with the 150 MW and 800 MW import options from New Brunswick, citing potential mismatches with the NS Power system's scale and reliability requirements.

tem and could present reliability risks without additional system resources to respond to contingencies. Rescaling of this assumption or consideration of reliability implications would be required. Regarding the “medium” and “high” cases f...

AI summary The text discusses reliability risks from wind capacity assumptions and critiques the GE study's methodology for wind generation. NS Power advocates using multi-year data for accurate wind capacity value ranges, while Synapse highlights uncertainties in capital expenditure projections for aging plants, citing specific large capital injection needs.

roach and input assumption sets after review of comments by stakeholders and discussion with NS UARB staff. 5) Allow for another round of modeling after the technical conference, if needed. The overall timeframe for the analysis and the in...

AI summary Synapse Energy Economics outlines a planning exercise to assess the cost-effectiveness of retaining NSPI's thermal resources through 2030, acknowledging limitations in modeling due to timeframe constraints and the need for stakeholder input. The analysis prioritizes major power system constraints like reserve margins and transmission limits.

ts illustrated below. Due to time limitations, we will not define scenarios for all possible permutations of input assumptions. Illustrative Matrix: Example of key parameters and range of assumptions Alternative assumptions: Set 1 Set 2 Se...

AI summary The text presents a matrix of alternative assumptions for energy planning parameters, including load, capital requirements, gas prices, transmission, wind resource costs, demand response, storage, carbon costs, and balancing areas. Scenarios explore varying levels of energy efficiency, capital needs, and resource availability.

Maritimes coordination coordination M&N: Maritimes and Northeast gas availability / Nova Scotia delivery Synapse will refine the above approach, developing and documenting the sets of input assumptions to use during July and August. 3 A “c...

AI summary The document outlines Synapse's process for refining gas availability and delivery models in Nova Scotia, including steps for capacity expansion modeling. It references the 2014 'candidate resource plan' terminology and details parameters for load forecasts, resource costs, system stability, and model execution.

e minimum number of generation units online, system stability or voltage, operating reserves, or related parameters. h. Execute model runs, iterate as necessary, post-processing of results. Scope The scope of work will encompass refining a...

AI summary The scope involves refining a modeling plan for system stability, voltage, and operating reserves, with stakeholder input, Plexos model execution, and potential 2018 hearings. The process includes iterative modeling, reporting, and finalizing outcomes subject to regulatory review.

uns. e. Specify balancing area constructs to model. Research and develop alternatives to model balancing area constructs over the longer-term (e.g., NS alone, with import paths from NB and NL; or 3 combined Maritime provincial balancing re...

AI summary The text outlines steps for modeling balancing area constructs, incorporating technical constraints, and conducting stakeholder reviews using Plexos software. It emphasizes collaboration with NSPI, iterative modeling, and stakeholder feedback through conferences and hearings.

568,125 $ 505,625 $ 8,912,500 TUC3 $ 824,375 $ 793,125 $ 3,280,625 $ 868,125 $ 1,255,625 $ 524,375 $ 768,125 $ 543,125 $ 868,125 $ 505,625 $ 10,231,250 TUC6 $ 1,822,500 $ 1,997,500 $ 4,847,500 $ 2,297,500 $ 4,747,500 $ 1,822,500 $ 2,197,50...

AI summary The 2014 Integrated Resource Plan (IRP) Action Plan's eight action items influence Nova Scotia Power Inc.'s (NSPI) thermal fleet economics by affecting peak demand and capacity contributions from existing and new resources, impacting resource adequacy requirements and capital investment decisions.

g resource adequacy requirements), or they affect the capacity contributions available from existing and potentially new alternative capacity resources. The eight action items are characterized below: 1. Optimize the level of sustaining ca...

AI summary The document outlines eight action items addressing resource adequacy, including optimizing capital expenditures, studying wind penetration impacts, regional coordination, evaluating wind resources, monitoring market opportunities, assessing demand response, securing DSM commitments, and evaluating Mersey Development. These steps aim to ensure system reliability and capacity contributions.

ain energy storage technologies and use cases are currently in the midst of rapid cost declines that will likely persist.” (Executive Summary, page 3, emphasis added) 3- Regional Coordination Options Continuing regional coordination has sy...

AI summary The text highlights rapid energy storage cost declines, advocates for regional grid coordination among Nova Scotia, New Brunswick, and Newfoundland to enhance wind integration, and critiques NSPI's low wind capacity credit (12%) compared to higher regional benchmarks (20-46%). It emphasizes technical cooperation and operational efficiency gains from shared grid planning.

for the IG provided comments respecting specific considerations for the modeling plan runs and scope of work and milestones. Finally, PHP’s comments focused on opportunities for stakeholder input. While Synapse has adjusted the timeline to...

AI summary NS Power expresses concerns about Synapse's lack of response to stakeholder comments on the modeling plan, emphasizing the need for transparency, technical feasibility, and alignment with customer interests. It stresses the importance of a clear process for evaluating grid transitions from coal to alternative solutions while balancing affordability and reliability.

cant reduction in natural gas use for energy generation, making its availability and price for winter use in the Maritimes potentially more economical than is currently considered. The future availability and security of natural gas supply...

AI summary NS Power highlights uncertainties in natural gas supply security in Nova Scotia, emphasizing the need for infrastructure improvements to support gas generation. Additional wind generation requires system upgrades for stability, with NS Power urging Synapse to address these in its Final Report. Both issues impact long-term planning and resource assumptions in the Integrated Resource Plan (IRP).

~ Blackburn Law June 21, 2018 VIA EMAIL Ms. Doreen Friis Regulatory Affairs Officer/Clerk Nova Scotia Utility and Review Board 1601 Lower Water Street, 3rd Floor Halifax NS B3J 3S3 Dear Ms. Friis: Re: M08059 - Generation Utilization and Op...

AI summary The Small Business Advocate (SBA) highlights concerns about Nova Scotia Power's (NSPI) continued capital expenditures on fossil fuel generation, arguing that without analysis of economic obsolescence, small businesses may face unnecessary costs and stranded assets. The SBA emphasizes sector transformation, including renewable energy adoption and the Maritime Link transmission line, which may render older fossil fuel plants obsolete.

ot indicate it should be part of this matter. Synapse concurs with NS Power, the Industrial Group, the Small Business Advocate, and PHP that no further process is necessary in respect to this matter. Synapse’s primary reply comment in this...

AI summary Synapse agrees with NS Power and other stakeholders that no further process is needed for this matter. Synapse emphasizes the interpretation of its findings, noting that under reference scenarios, thermal fleet retention is indicated through 2030, though this is not a final determination on long-term utilization.

es in the province (gas, oil, imports) and the IRP must fully reflect this resource option. [Note that EfficiencyOne has been directed to file a DSM Potential Study by July 31,2019.] 2. Determine costs and achievable potential for peak-loa...

AI summary The text outlines requirements for the Integrated Resource Plan (IRP) to include fossil fuel and import resources, mandates a DSM Potential Study by EfficiencyOne, and emphasizes analyzing demand response costs, battery storage economics, and sustaining capital costs for thermal generation. The IRP must reflect diverse resource options and quantify costs for peak-load reduction and energy storage.

capital costs incurred a range of 6.5% to 10.4% of total NPVRR costs in our main scenarios. It is critical to continue to assess the pattern of these costs and project future costs. 5. Establish requirements to allow increased levels of wi...

AI summary The text discusses capital costs (6.5–10.4% of NPVRR) and outlines requirements for integrating wind energy into NSPI's system, including transmission upgrades and intertie completion. It emphasizes joint dispatch coordination with Maritime Provinces and analysis of Tufts Cove thermal units for economic retirement modeling.