N-1Demand Response Potential Study for 2021-2045
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the Draft Potential Study Report on July 15, 2019. Nova Scotia Utility and Review Board Page 7 of 7 August 14, 2019 (including incremental costs assumptions) to stakeholders. Consider using updated avoided costs. The 2019 DSM Potential Stu...
AI summary The document discusses stakeholder feedback on the 2019 DSM Potential Study, emphasizing the use of outdated 2014 IRP avoided costs and the need for stakeholder engagement. EfficiencyOne (E1) addressed concerns by enhancing transparency and incorporating stakeholder input into the IRP process.
nnual Program Costs by Option for Cost-Effective DR Options ($) ............................ 14 Figure ES-15. DR All Scenarios, Achievable Potential (MW at Meter and Percent of Peak Demand) ....... 15
AI summary The text references figures discussing annual program costs for cost-effective demand response (DR) options and achievable potential across various DR scenarios, measured in MW and percent of peak demand. These figures are part of an analysis evaluating DR programs' economic and capacity implications.
2040 3.37 4.82 4.22 0.89 2045 3.03 4.25 4.27 0.76 ©2019 Navigant Consulting, Ltd. Page 79 Nova Scotia Energy Efficiency and Demand Response Potential Study for 2021-2045 Figure 8-20 presents the net benefits for the achievable base case, b...
AI summary The document presents net benefits for the achievable base case of energy efficiency and demand response programs, by sector and for the portfolio under each benefit-cost test. Net benefits are positive in all cases except the RIM test.
below) by the technical potential estimates. Achievable potential also accounts for customer opt-out during DR events. The achievable technical potential calculation is summarized through Equation 3. Equation 3. DR Achievable Potential 𝑀𝑀𝑀...
AI summary The text discusses the calculation of demand response (DR) achievable potential, incorporating technical potential estimates and customer opt-out during DR events. It also outlines the development of annual and levelized costs for DR programs, including various cost components such as program development, equipment, marketing, and incentives.
veness assessment of DR options using the TRC test. The DR analysis input assumptions file presents detailed itemized cost assumptions used in this study and documents the basis for these assumptions. The cost assumptions fall into the fol...
AI summary The document outlines the cost assumptions and variables used in the cost-effectiveness analysis of demand response (DR) options using the Total Resource Cost (TRC) test. Key categories include one-time and annual fixed and variable costs, along with a discount rate and line loss values used in the model.
Line loss values between 4.5% and 14.7% depending on customer class, which is used to bring up the potential at customer meter to the generator for cost-effectiveness assessment. 34 33 For assessing the DR benefits, Navigant used the avoid...
AI summary The text discusses line loss values and their impact on cost-effectiveness assessments, as well as the benefits and costs considered in the cost-effectiveness evaluation of demand response (DR) options, using data from the 2014 IRP and 2018 estimates from NSP. It outlines various benefit and cost streams related to DR programs.
Technology Enablement Cost O&M Cost Participant Cost 32 The enabling technology costs represents the incremental costs associated with controls and communications for making the device DR-enabled. These costs are not expected to decline me...
AI summary The text discusses the incremental costs associated with enabling technology for demand response (DR), noting that these costs are static and sourced from NS Power studies. It also mentions a cost-effectiveness assessment focusing on DR options with TRC benefit-to-cost ratios of 1.0 or greater, included in potential estimates for Nova Scotia's energy efficiency and demand response study.
ablement costs • EV charging control is significantly higher cost due to relatively high technology enablement costs and assumed low unit impacts from EVs during the peak period Page 107 ©2019 Navigant Consulting, Ltd. Nova Scotia Energy E...
AI summary The document highlights the significantly higher enablement costs associated with EV charging control compared to other demand response (DR) options, due to high technology costs and low unit impacts during peak periods. Levelized costs for various DR options are presented, with EV charging control having the highest cost at $755.88 per kW-yr.
t are offered the rate in conjunction with enabling technologies is a major cost component. Other significant costs are marketing and outreach to customers to enroll them in rates. • The investment for BNI curtailment is tied directly to t...
AI summary The text discusses the cost components of demand response (DR) programs, including enabling technologies, marketing, and outreach. It also mentions BNI curtailment investment tied to aggregator payments and delivery costs, as well as behavioral program investment being low and consistent after 2026. The document references a figure showing DR annual program costs by DR option for cost-effective DR options.
• Fourth, we draw on the internal stakeholders to provide valuable insights and perspectives on the results. In the program development process, we will solicit input to help guide and shape the set of programs to be considered in the DR p...
AI summary The text discusses the development of program costs for Demand Response (DR) programs, including administrative costs and customer incentives. It mentions the use of shared costs across programs, economies of scale, and collaboration with E1 and Navigant to ensure accurate cost assumptions and levelized cost calculations.
ticipation forecasts by customer segment • Number of participants in DR programs in different DR programs by market segment • Per customer load impacts (either specified • Winter demand reductions and energy in terms of kW reduction per pa...
AI summary The text outlines key metrics and considerations for demand response (DR) programs, including participation forecasts, customer load impacts, attrition assumptions, and cost-benefit analyses. It emphasizes the importance of evaluating technology costs, incentive levels, and avoided energy and demand costs in different market segments for Nova Scotia.
N-2Hydro Asset Study - REDACTED
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1 TABLE OF CONTENTS 2 3 1.0 INTRODUCTION ............................................................................................................. 6 4 2.0 METHODOLOGY .......................................................................
AI summary The document outlines a methodology for assessing hydro asset costs, including sustaining capital, operational, replacement energy, and decommissioning costs. It details assumptions for class 5 cost estimates, net present value usage, and environmental assessments for asset removal.
1 2.0 METHODOLOGY 2 3 This Hydro Study provides (1) a forecast of individual system investments required over 4 the next 40 years. The methodology for sustaining costs is described in Section 2.2. 5 (Given that the Harmony and Roseway Hydr...
AI summary The Hydro Study outlines methodologies for forecasting system investments and decommissioning costs over 40 years. It uses Class 5 cost estimates (±50–+100% accuracy) and net present value (NPV) to 2018 dollars for decommissioning, assuming full asset removal and watershed restoration. Sustaining costs for unused systems like Harmony and Roseway are excluded.
avoided costs of 25 replacement energy. In this way, the cost benefit of generation is not included in any of 26 the Hydro Study costs. 27 28 2.3 Decommissioning Costs 29 12 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Hydro Asset Study RED...
AI summary The text discusses avoided costs related to replacement energy and decommissioning costs within the context of a Hydro Asset Study. It notes that generation cost benefits are excluded from the study's cost calculations, highlighting decommissioning as a separate financial consideration.
1 Archaeology - Archaeology costs were developed by Boreas Heritage Consulting Inc. 2 (Boreas). Please refer to Appendix F for the report prepared by Boreas (Boreas Report). 3 Archaeological sites in the province of Nova Scotia are protect...
AI summary The text discusses archaeological cost estimates for potential hydroelectric decommissioning in Nova Scotia, prepared by Boreas Heritage Consulting Inc. It highlights the need for further reconnaissance due to the Special Places Protection Act (SPPA) requirements and notes exclusions in the Hatch Report, such as wetland compensation and unexpected site conditions, which are not included in current cost estimates.
from 20 the decommissioning of a hydro system are not included in the Hydro Study. 21 Determining these costs would require further site-specific analyses. 22 23 For the purposes of this Hydro Study, the estimated decommissioning costs ass...
AI summary The Hydro Study excludes decommissioning costs of a hydro system, assuming restoration to natural conditions. However, the Hatch Report highlights that mitigation measures for dam removal may not always succeed, leading to long-term remediation costs. Site-specific analyses are needed for accurate decommissioning cost estimates.
chaeology cost estimates, Boreas and NS Power analyzed individual sites to 24 estimate areas of potential impact during hypothetical decommissioning construction 25 works. 9 Hatch Report, Appendix B, page 7. 18 REDACTED (CONFIDENTIAL INFOR...
AI summary The text discusses the analysis of cost estimates related to decommissioning construction works, with Boreas and NS Power evaluating individual sites for potential impacts. A reference is made to the Hatch Report, Appendix B, page 7.
ues. Class 5 estimates are prepared for business planning purposes and high-level budgeting. Typical accuracy range for a Class 5 estimate is -50% and +100%. For the current study, the cost estimates have been prepared without the benefit...
AI summary The text discusses Class 5 estimates used for business planning and high-level budgeting, noting a wide accuracy range of -50% to +100%. It explains that current cost estimates lack detailed data such as a dam removal plan and are based on precedent experience adjusted for system peculiarities. Direct costs include dismantling, demolition, and site reinstatement.
urctures H357345 NSPI's Hydro System Decommissioning Cost Estimate x Indirect Costs Construction indirect costs for all sites are factored as a percentage of the total direct costs and are intended to cover items such as supervisory/site s...
AI summary The document outlines the indirect costs and contingencies associated with NSPI's hydro system decommissioning. Indirect costs are a percentage of direct costs, covering items like site staff and temporary facilities. A 50% contingency is included due to high uncertainty, except for St. Margarets Systems, where a 30% contingency is used.
associated with archaeological assessments and activities are not included in this cost estimate, as these are being developed on behalf of NSPI by other parties. Cost estimates developed during this exercise include stakeholder and indige...
AI summary The text discusses cost estimates for a project, noting that archaeological assessments and certain stakeholder engagement activities are included, but treaty-related compensation and other non-typical costs are excluded. It also highlights potential recreational impacts and the need for site-specific studies to assess socio-economic and additional costs.
ϭϬ REDACTED (CONFIDENTIAL INFORMATION REMOVED) REDACTED Hydro Asset Study Appendix C Page 17 of 143 EKs^Kd/WKt Z/E͘Ͳ,zZKWZKhd/KE ^/d KDD/^^/KE/E' ^d/Dd ^hDDZz&KZ^^ dZ d/Z D EdK>/'d/KE^;ZKͿ^d...
AI summary The text discusses the evaluation of hydro assets, including the analysis of financial and operational factors related to the management and performance of these assets. It emphasizes the importance of accurate cost assessments and the impact of various factors on the overall efficiency and reliability of the hydro system.
-$500.00 Allowance General Parts -$1,000.00 Allowance Insulated Wire and Cables No. 1 -$1,000.00 Allowance Insulated Wire and Cables No. 2 -$1,000.00 Allowance ENGINEERING & PROJECT MANAGEMENT Engineering & Project Management $84,339.00 Si...
AI summary The text outlines various allowances and costs associated with a site decommissioning estimate, including allowances for general parts, insulated wire and cables, and engineering and project management expenses, with a subtotal for the Avon No. 2 Development and additional notes on HST.
ĂŶĚƌĞůĂƚĞĚĐŽŵƉŽŶĞŶƚƐ͕ƐƚŽĐŬƉŝůĞĚĞŵŽůŝƚŝŽŶŵĂƚĞƌŝĂůĨŽƌĚŝƐƉŽƐĂů͘ x ZĞŵŽǀĞĂŶĚĚĞŵŽůŝƐŚŵĂŝŶĨůŽŽƌƌĞŝŶĨŽƌĐĞĚĐŽŶĐƌĞƚĞƐůĂď͘^ƚŽĐŬƉŝůĞĚĞŵŽůŝƚŝŽŶŵĂƚĞƌŝĂůĨŽƌĚŝƐƉŽƐĂů͘ x ZĞŵŽǀĞĞdžƉŽƐĞĚŝŶƚĞƌŝŽƌƐƚĞĞůƉĞŶƐƚŽĐŬ͕ŵĂŝŶƉĞŶƐƚŽĐŬďƵƚƚĞ...
AI summary The text discusses topics related to energy efficiency, cost management, and regulatory considerations in the context of a regulatory proceeding. It highlights issues such as fuel cost adjustments, asset retirement obligations, and the impact of various programs on affordability and cost recovery.
ĂŶŬƐ͕ ďĞĂƌŝŶŐ ĐŽŽůŝŶŐ ƐLJƐƚĞŵƐ ĂŶĚ ĨŝůƚĞƌƐ ĂŶĚ ƌĞůĂƚĞĚ ƉŝƉŝŶŐ͕ ƚŚƌŽƚƚůĞ ůŝŶŬĂŐĞ ĐŽŵƉŽŶĞŶƚƐ͕ ĞůĞĐƚƌŝĐĂů ĂŶĚ ĐŽŵŵƵŶŝĐĂƚŝŽŶƐ ĐĂďůĞƐ ĂŶĚ ŵŝƐĐĞůůĂŶĞŽƵƐƐŵĂůůĞƌĞƋƵŝƉŵĞŶƚĂŶĚƉŝƉŝŶŐ͘ ϲϴ REDACTED (CONFIDENTIAL INFO...
AI summary The text discusses various aspects of regulatory proceedings, including accounting policies, cost considerations, and program evaluations. It also references studies and appendices related to hydro assets and energy efficiency initiatives.
ine) -$500.00 Allowance General Parts -$1,000.00 Allowance Insulated Wire and Cables No. 1 -$1,000.00 Allowance Insulated Wire and Cables No. 2 -$1,000.00 Allowance ENGINEERING & PROJECT MANAGEMENT Engineering & Project Management $65,622....
AI summary The text outlines various allowances and costs associated with site decommissioning, including specific line items for engineering and project management, as well as a subtotal for the Nictaux Development. Notes mention the removal of transmission cable and related equipment by others and the inclusion of HST as an additional cost.
Ŷ ǁŝƚŚ ĐŽŵƉĂĐƚĞĚ ŐƌĂŶƵůĂƌ ŵĂƚĞƌŝĂů ĂŶĚ ƐĞůĞĐƚĞĚ ĚĞŵŽůŝƚŝŽŶ ĚĞďƌŝƐƚŽƚŚĞƚĂŝůƌĂĐĞĐŽĨĨĞƌĚĂŵ͘dŚĞĐŽĨĨĞƌĚĂŵĐĂŶƌĞŵĂŝŶŽŶĐĞŐƌĂĚĞĚƚŽŵĂƚĐŚƐŝƚĞ͘WƌŽǀŝĚĞĞƌŽƐŝŽŶ ƉƌŽƚĞĐƚŝŽŶĂƐƌĞƋƵŝƌĞĚ͘ ϵϬ REDACTED (CONFIDENTIAL INF...
AI summary The text discusses the challenges in managing and maintaining hydro assets, including the need for regular maintenance, cost considerations, and the impact of environmental factors on asset performance. It highlights the importance of efficient resource allocation and the potential consequences of neglecting maintenance.
- General (Inc. Turbine) -$200.00 Allowance General Parts -$3,000.00 Allowance Insulated Wire and Cables No. 1 -$2,500.00 Allowance Insulated Wire and Cables No. 2 -$2,500.00 Allowance ENGINEERING & PROJECT MANAGEMENT Engineering & Project...
AI summary The text outlines various allowances and costs associated with a site decommissioning estimate at Malay Falls Development, including items such as turbine, general parts, and insulated wire allowances, as well as engineering and project management costs. The subtotal for the decommissioning estimate is listed as $1,192,630.40, with notes indicating that HST is an additional cost.
CTED Hydro Asset Study Appendix C Page 122 of 143 EKs^Kd/WKt Z/E͘Ͳ,zZKWZKhd/KE ^/d KDD/^^/KE/E' ^d/Dd ^hDDZz&KZ^^ dZ d/Z D EdK>/'d/KE^;ZKͿ^dhz;LJ^LJƐƚĞŵͿ dŚĞďƵůŬŽĨĐŽƐƚƐĂƐƐŽĐŝĂƚĞĚǁŝƚŚƚŚĞĚĞĐŽŵŵ...
AI summary The text discusses the evaluation of CTED Hydro's asset study, focusing on the implications of asset retirement obligations and the need for accurate cost assessments in the context of a regulatory proceeding. It highlights concerns related to financial planning and the impact of asset management strategies on overall operations.
including but not limtied to removal of draft-tube gates and Building Ventilation & Heating Removals $67,000.00 related operating mechanism, powerhouse overhead crane(s) and removal of tailrace tunnel outlet portal gate. Plant Operating Eq...
AI summary The text outlines estimated costs for the decommissioning of a plant, including equipment removal, salvage allowances, and engineering management expenses, with a subtotal of $2,052,027.20. It also notes that HST is additional and that some components will be removed by others.
163,+<'526<67(0 163,+<'52'(9(/230(17$5($ &RVWV'HYHORSP HQW &RVWV+\GUR6\VWHP
AI summary The text outlines two areas of focus: '163,+'52 6<67(0' and '163,+'52 '(9(/230(17 $5(&$', both under the categories of 'Costs/Development' and 'Costs/Hydro System'. The content appears to be related to cost considerations and system development in the context of hydro systems.
overhead costs expected to be incurred during the demolition process. Related engineering and planning costs, as well as site supervision, are included in the demolition cost estimate.
AI summary The text discusses overhead costs associated with the demolition process, including engineering, planning, and site supervision expenses that are included in the demolition cost estimate.
Total Contiguouse Wetland Permit Reporting and Total Expenses Hydrosystem Water Body Contiguouse Wetland Area (ha) Field Costs Total Permitting Cost Followup Monitoring Cost Total (Permiting+ Monitoring) Cost Area (ha) Submission Costs Cos...
AI summary The text presents a table detailing permitting and monitoring costs for various wetland areas in Nova Scotia, including total contiguous wetland areas, field costs, submission costs, and total permitting and monitoring costs for specific water bodies.
N-9-(i)Appendices A-N
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Nova Scotia Power IRP Final Report Appendix A Page 15 of 64 infrastructure and initiatives needed to achieve those targets, and developing a strategy to support those markets. 5. Building electrification is dependent on reducing costs and...
AI summary The report emphasizes the need for infrastructure and strategies to achieve decarbonization targets, highlighting building electrification's dependence on cost reductions and incentives. It notes the importance of cold climate heat pumps, their high upfront costs, and the need for government or NSPI support. Peak electricity demand impacts from electric heating and an alternative low-carbon biofuels scenario are also discussed.
Financing Lifetime (Years) 25 25 Degradation (%/year) 0.5% 0.5% 2020 IRP FINAL ASSUMPTIONS SET 44 Nova Scotia Power IRP Final Report Appendix B Page 46 of 112 BTM BAT TERY STORAGE : COST ASSUMPTIONS Input 1HR 4HR $/kW2020 $939 $2,330 FO&M...
AI summary The document provides cost assumptions for battery storage systems, including initial costs, financing lifetimes, and annual degradation rates. It also outlines a capital cost decline trajectory for battery storage from 2020 to 2044.
1,759 1,872 1,927 1,914 1,910 1,939 1,963 1,976 1,999 2,010 2,037 2,068 2,075 2,117 2,121 2,160 2,197 2,210 Incremental FCR-Base Cumulative Incremental Sales (GWh) - 10 28 72 133 203 262 320 375 425 472 517 562 608 653 700 750 799 847 893...
AI summary The document provides numerical data on incremental FCR-Base, cumulative incremental sales in GWh, incremental FCR in $/MWh and $M, and net revenue requirement in $M over a series of years. The data appears to be related to financial and operational metrics for a utility or regulatory proceeding.
costs (i.e. production, O&M, abatement, sustaining capital, and capital investment) and specific costs considered outside of the long-term model optimization (e.g. energy efficiency costs) I R P U P D AT E D M O D E L I N G R E S U LT S –...
AI summary The document outlines the metrics used to evaluate portfolios in the Integrated Resource Plan (IRP) final report, focusing on minimizing the cumulative present value of annual revenue requirements over a 25-year planning horizon, including adjustments for end-effects.
Optimization) Cost + other key metrics Other Constraints 31 Resource Cost Modeling Nova Scotia Power IRP Final Report Appendix H Page 51 of 321 Fixed vs. Variable Costs for New Resources Fixed costs: expenditures required to install and...
AI summary The document discusses resource cost modeling, distinguishing between fixed and variable costs for new resources. Fixed costs include capital and O&M expenses, while variable costs are tied to energy production. Capacity factor is used to estimate costs and spread fixed costs over expected generation.
Levelized Cost of Energy ($2019) $4,000 $250 2019$ Levelized Cost of Energy (LCOE) $3,500 $200 $3,000 $150 $2,500 $/kW $2,000 $100 Solar BTM - Low CF $1,500 $50 Solar BTM $1,000 - High CF $- $500
AI summary The text presents a visual representation of the Levelized Cost of Energy (LCOE) in 2019, showing varying costs for different energy sources, including Solar BTM with low and high capacity factors. The chart highlights the financial considerations associated with energy generation.
Degradation (%/year) 0.5% 0.5% 2020 IRP ASSUMPTIONS SET 41 BTM BAT TERY STORAGE : COST Nova Scotia Power IRP Final Report Appendix H Page 61 of 321 ASSUMPTIONS Input 1HR 4HR $/kW2019 $1021 $2533 FO&M ($/kW-Yr) $8.34 27.35 Financing Lifetim...
AI summary The document presents assumptions related to the cost and performance of battery storage systems, including initial costs, financing lifetime, annual warranty, and capital cost decline trajectory, as part of the 2020 Integrated Resource Plan (IRP) by Nova Scotia Power.
ions, (ii) restate some items we feel remain unaddressed and (iii) to provide our perspective on IRP work that NSPI has alluded to using to alter rates utilized by our organization and our affiliates. Thank you for confirming that NSPI und...
AI summary The text discusses concerns raised by AREA regarding the Integrated Resource Plan (IRP) and the cost assumptions for renewable energy projects. AREA argues that NSPI's reports may mislead readers about the likelihood of lower renewable energy costs and that the process does not consider alternative financing options that could accelerate decarbonization.
inconsistent with all but a few very high recent estimates. 7 As shown below, those forecasts showing similar costs in 2019 were 5 NS Power, Draft Assumptions Set (January 20, 2020), Slides 35-37. 6 Lazard, Lazard’s Levelized Cost of Energ...
AI summary The text discusses discrepancies in cost estimates for solar PV and combined-cycle natural gas, noting that NS Power's assumptions are inconsistent with recent projections from the National Renewable Energy Laboratory and Lazard. It highlights the need for alignment with other sources and consideration of variable O&M costs and charging costs for storage technologies.
d consider the development of an approach 26 and alternate methodology than currently exists for the calculation. This process will occur in 27 parallel with the IRP and will conclude during the course of the IRP. EfficiencyOne appreciates...
AI summary EfficiencyOne comments on Nova Scotia Power's 2020 Integrated Resource Plan (IRP), emphasizing the need for an improved methodology to calculate avoided transmission and distribution costs. They note that these costs will not be included in the IRP model and stress the importance of accurate avoided cost assessments for planning decisions.
portfolio optimization process, but rather the DSM sc_enarios that change the load that will be used as inputs to the model used to develop the portfolios. The concern of using this approach is that: I. It does not test the economics of th...
AI summary The text discusses concerns with the methodology used in Nova Scotia Power's Integrated Resource Plan (IRP) regarding Demand Side Management (DSM) scenarios and their impact on portfolio optimization. It highlights issues with the economics of DSM, differences in focus among DSM options, and the dynamic effects of DSM penetration on avoided costs. The text also raises questions about revenue requirements for multi-year amortization.
Category Participant Assumption Comment NS Power Response 1. Financial CanWEA/SIA Ensure sensitivities reflect variability of assumptions and Low and High capital cost sensitivities for wind and recognize how modular nature and experience...
AI summary The document discusses financial and load assumptions in a regulatory proceeding, including the need to reflect variability in capital costs for wind and storage technologies, and the inclusion of EV load shape effects in capacity expansion models. NS Power has updated assumptions using recent data and presented a range of load curves informed by studies.
e updated early in 2020 based on 2019 actual data [and CT] gas costs should be 20% lower per NREL ATB that became available after the original study was completed. Storage technologies O&M should be variable and not fixed; should include c...
AI summary The document discusses updates to gas costs and assumptions related to supply-side technologies in the IRP Final Report. It highlights discrepancies in storage technology O&M costs and the need to combine capex and opex with financing assumptions for accurate revenue requirement profiles.
for other DR programs that may be pursued in the future, dependent on technical capabilities and cost.
AI summary The text mentions the potential for other Demand Response (DR) programs in the future, contingent on technical capabilities and cost considerations.
13. Sustaining CA Are IRP and 2020 ACE sustaining capital forecasts based Yes. The ACE Plan is based on the annual bottom-up view Capital (Chernick & on different UF? Does sustaining capital for each unit and projected utilization, whereas...
AI summary The discussion centers on sustaining capital forecasts for the Integrated Resource Plan (IRP) and the 2020 ACE Plan. The ACE Plan uses annual bottom-up views and projected utilization, while the IRP uses a high utilization factor (UF) method. Sustaining capital estimates are presented in real 2020 dollars, with inflation included in modeling. Heritage Gas requests a review of sustaining capital costs from slide 95, noting a change in the vertical axis from nominal to real dollars.
document. 1.5 Analysis Plan E1 – Feb 14 2020 Confirm if possible to combine plan robustness with Due to the number of potential sensitivities Evaluation Criteria 25-year NPV by assessing NPV rev req under high and requested by stakeholders...
AI summary The document discusses the analysis plan for evaluating the robustness of resource plans, including the use of sensitivity analysis and stochastic analytics to assess financial risks and uncertainties. Nova Scotia Power (NSP) responds to stakeholder feedback on combining robustness with 25-year NPV calculations.
On aggregate, maintaining the existing diesel CTs is worth about ~$186 MM (no end effects) and ~$240 MM (with end effects) to the system on an NPV basis Effective Load Carrying Capacity 14 System Value of Diesel CTs - 1.0.A Nova Scotia P...
AI summary The analysis indicates that maintaining existing diesel combined cycle (CT) units is more cost-effective than replacing them with alternative resources over the planning horizon, with system values estimated at ~$186 MM and ~$240 MM on an NPV basis, considering and without considering end effects respectively.
ng horizon on an NPV basis Cost to Replace Small Hydro Assets vs Sustaining Capex (1.0.A) Wreck Cove Mersey 26 Hydro Assets: Total decommissioning costs relative to sustaining operations – 2.1.C Nova Scotia Power IRP Final Report Appendix...
AI summary The text discusses the cost comparison between replacing small hydro assets and sustaining capital expenditures under different scenarios, including the 2.1C scenario, which involves constrained emissions and higher load leading to increased replacement costs for renewable hydro capacity.
Wind costs and constraints: NS Power’s assumptions and modeling methods may be unreasonably constraining near-term wind builds in the model. The issues relate to NSP’s cost assumptions for wind and the reliability constraints imposed durin...
AI summary The analysis questions NS Power's assumptions and modeling methods regarding wind energy costs and reliability constraints. It argues that NS Power's 2019 capital cost of $2,100 per kW is higher than market rates and that the cap on wind build at 100 MW may be overly restrictive. Alternative operational responses are suggested to accommodate additional wind capacity.
ind and low load conditions and appears overly challenging to system operations. Reduced imports via utilization of generation within Nova Scotia would likely be the most prudent operational strategy. Probability of Occurrence of Scenarios...
AI summary The text discusses the operational strategy of Nova Scotia Power (NSP) during low load conditions and the importance of understanding the frequency and duration of specific grid conditions to evaluate mitigation strategies. It highlights the need for context on how often these conditions occur and their impact on economic cost/benefit analyses.
ral gas (blue bars) and diesel CTs (yellow bars) inclusive of carbon costs
AI summary The text references the inclusion of carbon costs in the analysis of natural gas and diesel combustion turbines, highlighting their impact on overall costs.
c For the analysis in part b), identify the dates (if they occur prior to 2050) when: - natural gas is no longer the lowest-cost alternative or combination of alternatives to diesel CTs; - diesel CTs no longer have an NPV cost advantage ov...
AI summary The text requests the identification of dates prior to 2050 when natural gas ceases to be the lowest-cost alternative to diesel combustion turbines and when diesel CTs lose their NPV cost advantage over natural gas.
The analysis would benefit from the consideration of uncertainty. This is Identify and quantify potential cost uncertainties associated particularly the case for the Mersey system where the NPV cost of with decommissioning, developing repl...
AI summary The text emphasizes the need to consider uncertainty in the analysis, particularly regarding the Mersey system. It highlights the importance of identifying and quantifying potential cost uncertainties related to decommissioning and replacing assets, and asks what events would lead to a net present value (NPV) cost benefit from decommissioning these facilities.
the 25 year NPV of the “B” case makes it more expensive distributed resources that are an integral part of the Distributed - define what is included in "extrinsic costs". than the least cost comparable “A” or “C” scenario Resources scenari...
AI summary The document discusses the 25-year net present value (NPV) of the 'B' case being more expensive than the least cost comparable 'A' or 'C' scenarios, and highlights the importance of defining 'extrinsic costs' in the context of distributed resources. The letter from Jon Sorenson to Linda Lefler proposes A-CAES as a potential solution for Nova Scotia.
on the IRP process. We note that again the time for comments to this process are extremely tight and it makes it very difficult for us to fully process the information that is being submitted by NSPI. In general, there are two large issues...
AI summary The document discusses concerns raised about the Integrated Resource Plan (IRP) process, particularly the tight timeline for comments and the difficulty in processing information from NSPI. Key issues include the cost of wind energy (capex, opex, and capacity factor) and limits on wind installed capacity. NSPI defends its pricing assumptions for wind energy.
July 2020 Category Comment # Comment NS Power Response Distributed CA-03 We are concerned by NS Power’s decision to ignore the costs NS Power has provided this information for all DER Resources for the distributed energy resources in cases...
AI summary The Consumer Advocate expresses concern over NS Power's handling of distributed energy resource (DER) costs in specific cases, noting that the value to customers, especially for storage, is difficult to estimate. They recommend that NS Power clearly indicate when costs for these cases do not include bottom-of-the-meter (BTM) costs.
ogressing consistent with HRM’s goals, then NS Power would need to adopt significantly higher assumptions for building electrification. Page 6 of 53 Nova Scotia Power IRP Final Report Appendix J Page 199 of 245 IRP Participant Comments and...
AI summary NS Power’s 2019 wind capital cost of $2,100 per kW is questioned as being higher than market rates. NS Power acknowledges this and proposes reducing the cost to $1,500 per kW, which would significantly increase near-term wind capacity procurement. A market-based information solicitation is proposed to inform wind cost assumptions.
d T&D costs associated with a PLEXOS MT/ST hourly production costs into the scenario higher level of DSM potentially offset the cost difference? NPVs.
AI summary The text discusses the impact of higher levels of Demand-Side Management (DSM) on Transmission and Distribution (T&D) costs, considering PLEXOS MT/ST hourly production costs and their effect on Net Present Values (NPVs).
ly of the economics of replacement vs sustaining capital costs. Reliability test results should be made available to IRP stakeholders. Electrification HG-02 Given that IRP outcomes can influence long‐term capital Based on feedback respecti...
AI summary The text discusses the economic implications of capital costs in the context of the Integrated Resource Plan (IRP), emphasizing the importance of considering reliability test results and the impact of electrification on energy demand. It highlights the role of natural gas distribution systems in meeting peak demand and the need for collaboration to ensure cost-effective energy solutions.
July 2020 Category Comment # Comment NS Power Response Wind cost NF-01 Price of wind is overstated compared to observed current NS Power undertook two Low Wind Price Natural Forces pricing. NS Power should reduce by 30 percent at a Sensiti...
AI summary The comment argues that NS Power has overestimated the price of wind energy by using a low capacity factor, suggesting a 30% reduction. NS Power responded by citing sensitivity analyses and noting that capacity factors were based on a CanWEA study, which assumes higher capacity factors than current Nova Scotia wind farms.
Reliability Tie SBA-02 Treatment of risk: The Reliability Tie and Regional The Reliability Tie and Regional Interconnection and Regional interconnection are significant components of the initial options have been selected in multiple plans...
AI summary The document discusses the importance of evaluating risks and costs associated with the Reliability Tie and Regional Integration projects. It emphasizes the need for additional studies and cost comparisons if these projects are selected, ensuring that alternatives are considered and that decisions are made based on a balanced assessment of cost and risk.
alysis of intermittent wind should allow wind to be installed on an economic level, and accepting that on rare occasions it may be necessary to curtail wind output to ensure the system remains stable. As noted in AREA’s February 14 comment...
AI summary The Alternative Resource Energy Authority (AREA) emphasizes the importance of considering alternative, lower-cost financing models for wind energy in Nova Scotia’s electricity system transformation. They also express concerns about the integration of multiple market conditions into the 'low case' scenarios in NS Power’s Integrated Resource Plan (IRP). AREA awaits the Draft IRP report and plans to provide further comments.
d by total sales. There is no reason to exclude a portion of revenues from the average rate calculation. Our first case – “Correction” – presents just the impact of removing this portion of the model. Treatment of existing non-fuel revenue...
AI summary The document discusses the treatment of non-fuel revenues in the context of revenue requirement calculations. It suggests that sunk costs of existing generation, T&D capital investment, and utility operating costs should be adjusted, with a proposed annual reduction of 1.5% in these revenues. The analysis includes scenarios such as 'Correction' and 'Sensitivity' to evaluate the impact of these adjustments.
ng duration energy storage technology is not and has note been given its due in the preferred portfolio solution into the future. We would like to continue to reiterate the following, that Hydrostor: • Be a cost-effective non-wire alternat...
AI summary The text argues that long-duration energy storage, particularly A-CAES, is a cost-effective and cleaner alternative to transmission and fossil fuel assets. It criticizes Nova Scotia Power's Integrated Resource Plan for inaccurately modeling A-CAES capital costs, which may have led to its exclusion from the preferred resource portfolio.
expanded by the cost of the years after the final horizon year (2045).
AI summary The text discusses the extension of cost considerations beyond the final horizon year of 2045, highlighting the need to account for future costs in planning and regulatory processes.
f investment, was economic relative to economic analysis model? decommissioning in all cases.
AI summary The text discusses the economic analysis of investment and decommissioning, focusing on whether the investment was economically viable relative to the economic analysis model.
DSM E1 The updated Modeling Results release provides a quantification of how various levels of DSM impact the (4) Provide more context on the results of the DSM sensitivity analyses for the various cost measures. Additional discussion has...
AI summary The document discusses the impact of Demand-Side Management (DSM) on cost measures and electrification scenarios. It highlights that higher levels of DSM can provide increased ratepayer value with higher electrification. However, higher DSM levels in resource plan sensitivities may not be cost-effective despite reduced capacity needs and lower emissions.
IRP pricing assumptions. Since NS Power agrees that new installed capacity by 2025 is desirable, engaging in a solicitation with the stated intent (but not requirement) to procure up to 700 MW of wind by 2025, depending on pricing and othe...
AI summary The document discusses NS Power's Integrated Resource Plan (IRP) pricing assumptions, including the procurement of wind, firm imports, and gas peakers. It highlights that the most economical mix of resources depends on actual bids and that battery storage's role is not primarily price-driven. Further modeling is recommended to confirm acquisition pricing and wind integration strategies.
sing a proposed retirement? What will be the decision metrics that will be used to determine retirement timing? Future steps / SBA Gas conversions: The draft IRP notes that coal-to-gas NS Power has committed to advancing the engineering Co...
AI summary The text discusses the proposed coal-to-gas conversions in Nova Scotia's Integrated Resource Plan (IRP) and the need for a framework to evaluate their economic viability. It raises concerns about potential stranded costs if non-emitting alternatives become more economical and asks about a breakeven point for switching to non-emitting options.