Topic:"Load Management" in M08929

Eligible Customer DR Option Brief Description End Use Classes Electric Furnace 3 Residential Heat Pump 4 Control of electric loads by a thermostat Direct Load Control (DLC) Small Commercial and/or load control switch. HVAC 5 Small Industri...

AI summary The text outlines various demand response (DR) options available to eligible customers, including Direct Load Control (DLC) and BNI Curtailment, detailing their mechanisms, applicable customer classes, and associated costs or benefits.

Page 8 Nova Scotia Energy Efficiency and Demand Response Potential Study for 2021-2045 Figure ES-8 presents market winter peak demand results for four market potential scenarios; (1) maximum achievable, (2) mid case, (3) base case, and (4)...

AI summary The document presents market winter peak demand results for four scenarios (maximum achievable, mid case, base case, low case) ranging between 375 MW and 600 MW over 25 years. It also discusses technical and economic potential savings, which range from 85% to 99% annually, largely due to fuel switching in HVAC systems. Line loss factors differ between the study and system requirement documents.

ype 6. Conduct scenario analysis and present DR potentials, annual costs and cost-effectiveness results by scenario Figure 10-1. DR Potential Assessment Steps •Characterize market for DR potential estimation: Number of customers Step 1: Ma...

AI summary The text outlines the steps for conducting a demand response (DR) potential assessment, starting with market characterization, developing baseline projections, defining DR options, and analyzing scenarios. The process involves estimating DR potentials, costs, and cost-effectiveness across different customer segments and scenarios.

s. Figure 10-2. Market Segmentation for DR Potential Assessment Level Description

AI summary The text presents a figure titled 'Market Segmentation for DR Potential Assessment,' which categorizes different levels of market segmentation relevant to demand response (DR) potential assessment. The figure includes a 'Level' and 'Description' column, though the description is not fully visible in the provided text.

Electric Furnace 22 Residential Control of electric loads by a thermostat Heat Pump 23 DCL Direct Load Control Small Commercial and/or load control switch. HVAC 24 Small Industrial Hot Water Firm capacity reduction commitment. HVAC Large C...

AI summary The text outlines various load management strategies, including direct load control, curtailment, battery control, and EV charging control, aimed at managing electricity demand across residential, commercial, and industrial sectors.

BNI Curtailment- Water Heating Control Water Heating BNI Curtailment- Industrial Total Facility BTM Battery Control BTM Battery Control Batteries EV Charging Control EV Charging Control EV CPP with enabling technology Critical Peak Pricing...

AI summary The text discusses various demand-side management (DSM) options for curtailing energy use, including Direct Load Control (DLC) for residential and small BNI customers, BNI Curtailment for large BNI customers, and BTM battery control for all customer classes. It also mentions EV charging control and Critical Peak Pricing (CPP) with and without enabling technology.

rnaces and heat pumps, the snapback magnitude during evening peak hours may be the same or even greater than the DR evening peak demand reduction as customer demand increases during the evening hours.

AI summary The text discusses the potential for snapback magnitude during evening peak hours to be equal to or greater than the demand response (DR) evening peak demand reduction, as customer demand increases during these hours, particularly in relation to heat pumps and other energy sources.

There are differences in snapback estimates between different types of space heating equipment. For example, for heat pumps, the snapback may be much more pronounced than for central furnaces. For a two-stage heat pump, the compressor oper...

AI summary The text discusses differences in snapback effects for various space heating equipment, particularly heat pumps, during curtailment events. It explains that heat pumps may experience more pronounced snapback due to the activation of heat strips when the compressor is unable to operate at lower temperatures. However, the overall impact may be mitigated due to the short duration of the snapback effect and potential use of supplemental fuels.

cal and economic potential are attributed to HVAC fuel switching measures that completely remove the end-use load from a home. Although still a significant portion of potential, achievable results indicate that efficient electrification te...

AI summary The text discusses the potential of HVAC fuel switching and efficient electrification technologies like heat pumps for reducing energy use, but notes market barriers to adoption. It also highlights that Critical Peak Pricing (CPP) and Direct Load Control (DLC) are the main contributors to demand response savings over a 25-year period.

water heating. control switch. • Load Control Demand Switch C&I Curtailment Firm capacity reduction commitment. Various load types • Manual General including- heating, $/kW payment based on Demand, • Auto-DR ventilation, lighting, contract...

AI summary The text outlines various load control and demand response mechanisms, including manual and automatic demand response, load control switches, and electric vehicle charging control, aimed at managing energy use during peak demand periods. These strategies target different load types across commercial, industrial, and residential sectors.

th winter heating load spikes. Load is lowest during summer evenings but due to air conditioning can also increase during the middle of the day during summer. Figure 20: Month/Hour Average Load (GW) Month/Hour 1 2 3 4 5 6 7 8 9 10 11 12 13...

AI summary The document discusses seasonal variations in electricity load, noting that winter heating load spikes and summer air conditioning increases demand during midday. A table provides monthly and hourly average load data in gigawatts for each month of the year.

electrified heat, transportation, and with greater demand flexibility and dispatchability. This analysis could show a higher (or lower) ELCC for these resources, thus impacting resource planning outcomes. NS Power agrees that different loa...

AI summary NS Power acknowledges electrification and DERs may impact ELCC, planning reserve margins, and resource adequacy. Transmission constraints are excluded from PRM studies due to computational complexity, while DR is modeled as not affecting PRM. NS Power plans to refine the Capacity Study in the IRP Analysis Plan phase.

e level dispatch and load forecasting. x Utility level technologies includes DERMS for facilitating the resource dispatch and program administration 7.14 E1 Did E3 use its own forecast for EV sales in Nova Scotia or was this taken from the...

AI summary The text discusses the use of EV sales forecasts from NS Power's 2019 Load Forecast and requests detailed assumptions for DR program costs, including EV forecasts, event opt-out rates, attrition, recurring costs, and peak shaving calculations. E1 and NSP have met to discuss these questions and refer to Attachment A-5 for further details.

3.1.1 Planning Reserve Margin (PRM) The first step in planning for a reliable grid is load forecasting. Understanding how customer demand may change under different future scenarios is crucial to Nova Scotia Power's planning process. The l...

AI summary The document discusses the Planning Reserve Margin (PRM) as a key component of Nova Scotia Power's grid reliability planning. It outlines the process of load forecasting and the use of a reliability criterion based on a 1-day-in-10-years Loss-of-Load Expectation (LOLE) standard. This standard is translated into a PRM, which is a percentage requirement above expected peak demand to ensure system reliability.

- - - - - - - - - - - - - - - - - - - - Net Revenue Requirement ($M) 1,658 1,665 1,722 1,683 1,706 1,712 1,723 1,741 1,746 1,783 1,796 1,778 1,802 1,818 1,854 1,880 1,893 1,903 1,940 1,974 2,055 2,117 2,103 2,145 2,154 2,194 Load (GWh) 11,...

AI summary The text presents financial and operational data including net revenue requirements, load in gigawatt-hours, and sales figures over a period. It also includes losses calculated at 7% of the load. These metrics are likely used for regulatory proceedings to assess the financial health and operational performance of an electricity provider.

2020 IRP ASSUMPTIONS SET 6 Nova Scotia Power IRP Final Report Appendix H Page 26 of 321 LOAD ASSUMPTIONS OVERVIEW • The underlying data for the “Base Load Forecast” is based on NSP’s annual Load Forecast Report, as filed with the UARB in 2...

AI summary The document outlines the load assumptions used in the 2020 Integrated Resource Plan (IRP) by Nova Scotia Power (NSP), including the base load forecast derived from the 2019 Load Forecast Report and the application of demand-side management (DSM) scenarios. It also discusses the potential impact of electrification driven by the Sustainable Development Goals Act.

t take place during the day. reality, any charging signal based on either a fixed schedule (TOD), or based on some real-time external signal, would only be a sug- 3.2.3. Scenario: Smart charging gestion or a price difference, not a strict...

AI summary The text discusses smart charging scenarios for electric vehicles (EVs), emphasizing that charging signals based on fixed schedules or real-time external signals are suggestions rather than strict commands. It highlights that EVs will charge regardless of grid impacts when needed for imminent trips.

n and Management 109 (2016) 130–139 Fig. 4. Logic diagram for ‘‘TOD Charging” algorithm. Output is load profile of each vehicle, which are then aggregated to become fleet charging loads.

AI summary The text describes a logic diagram for a 'TOD Charging' algorithm, which generates load profiles for individual vehicles and aggregates them to form fleet charging loads. The diagram is part of a study on energy management and vehicle charging strategies.

same week in June, 2014, along These various years are not expected to affect the trending shown with the unmodified export power timeseries from Fig. 9. Charging in Fig. 6. loads for convenience charging (yellow), TOD charging (cyan) and...

AI summary The text discusses seasonal load variations, showing higher winter loads due to heating and lighting needs. It also compares different EV charging scenarios, noting that convenience charging adds about 2 MW of load, TOD charging adds over 4 MW, and smart charging can add up to 6 MW. Digby is identified as a net electricity exporter.

results, because such conditions, when local loads are not at their evening. This is characteristic of areas with electric heat that is minimum, do not negatively impact the export transmission often turned down at night when businesses ar...

AI summary The text discusses variations in electricity generation and load profiles, focusing on the impact of electric vehicles on the grid. It highlights how wind generation is higher at night and lower during the day, and how different EV charging algorithms affect local load profiles and export probabilities.

In Fig. 12, it can be seen that convenience charging (yellow) 60 does modify the L-5533 export. On June 4, it is not helpful, adding load when L-5533 was importing electricity already. On June 5 40 convenience charging happens to reduce re...

AI summary The text discusses the impact of different charging strategies on the export levels of L-5533. Convenience charging, TOD charging, and smart charging are analyzed for their effects on electricity exports on specific dates, showing varying degrees of load modification.

-7 -14 -21 -28 1 2 3 4 5 6 7 June, 2014 (date) Fig. 10. Electricity profiles of convenience, TOD, and smart charging compared with unmodified Transmission L-5533 in June. 12 Existing Load 11 Load with 10% of fleet Convenience Charging Digb...

AI summary The text presents a figure comparing electricity profiles of convenience, Time of Day (TOD), and smart charging with the existing load profile for Transmission L-5533 in June 2014. It shows the impact of different charging strategies on the load profile.

Using the TOD charging strategy, this fraction is improved to 59%, charging (yellow) has very little effect on the most challenging as charging events are pushed to the overnight hours when exports export conditions. In contrast, TOD charg...

AI summary The document discusses the impact of Time of Day (TOD) charging on export conditions, noting that TOD charging improves the fraction to 59% and reduces challenges during peak export times by shifting charging events to overnight hours when exports are more likely.

1 To maintain the fidelity of the DSM Potential Study, EfficiencyOne strongly recommends NS 2 Power consider the above approach. 3 4 On slide 11, NS Power also indicates that the DSM Potential Study cases are assumed to include: 5 • Cost-e...

AI summary EfficiencyOne recommends that NS Power adjust the DSM Potential Study to ensure accuracy, clarifying that it only includes programmatic DSM impacts. Factors like consumer behavior, technology, and energy codes are excluded via net energy savings and sub-models, while other agencies' involvement in DSM is deemed immaterial in Nova Scotia.

1 With this issue in mind, EfficiencyOne recommends that: 2 3 • NS Power select one electrification scenario on the basis of perceived likelihood of 4 each scenario occurring. This determination should be made by NS Power and E3, with 5 op...

AI summary EfficiencyOne recommends that NS Power select an electrification scenario based on likelihood, with input from stakeholders, and then choose a PRP from that scenario. They also request clarification on modifying the 2019 Load Forecast to account for electrification effects and seek confirmation on understanding the E3 Pathways Report.

from baseline forecast [and considered, informed by the Pathways study and E1 DSM why] Potential Study. Could load shape change over time due to changes in load NS Power will work with E3 on potential impact of mix (industry shifts, change...

AI summary The text discusses load shape changes and electrification impacts on peak loads, noting NS Power's collaboration with E3 to model these changes and review assumptions for electrification scenarios. It mentions stakeholder review of these assumptions.

Category Participant Assumption Comment NS Power Response 2. Load Natural DSM scenarios of 17% reduction in low case to 30% in NS Power’s DSM assumptions are informed by the E1 Forces max achievable case appear ambitious Potential Study; a...

AI summary The text discusses load forecasting assumptions and demand-side management (DSM) scenarios, including the need to consider electrification pathways and demand growth. NS Power references the PATHWAYS work and the E1 Potential Study to inform its assumptions.

cell or other derived source) by 2050 and energy requirements. Reasonable to assume 80-100% of space heating via heat pump by 2050 Space heating load aligned with demand peaks and electrification of space heating presents capacity concerns...

AI summary The text discusses the assumption that 80-100% of space heating will be via heat pumps by 2050, raising concerns about capacity due to electrification. It also requests confirmation on modifying the 2019 Load Forecast by removing 40% of future EE and DR from the 'before DSM' scenario while retaining the impacts of previously delivered programs. NS Power plans to use the Pathways report to adjust the forecast for electrification before EE and DR.

ces peak and energy assumptions are significantly different affecting load shape than the 2018 actuals on which the load shape is based. 6. Planning CA Forecast marginal ELCC values may be missing diversity The diversity benefit to ELCC wi...

AI summary The document discusses concerns about load shape assumptions and ELCC values in the Integrated Resource Plan (IRP) analysis. It highlights the need for more detailed methods and diagnostic outputs for the capacity value study, including how hourly loads relate to weather data and long-term weather trends.

Stakeholder input evaluate a broad range of potential outcomes during the IRP process. 2.2 Scenarios Digby Transmission grid (69 kV line) from Tremont to The capacity expansion modeling of the IRP Drivers Yarmouth impedes area’s ability to...

AI summary The document discusses stakeholder input on scenarios for the Integrated Resource Plan (IRP), including transmission grid constraints, electrification of buildings and transportation, and the impact of electrification scenarios on load forecasts and long-term energy requirements.

1. NS Power’s planned reflection of the recession is inadequate. The current economic downturn will reduce NS Power’s load this year. Already, FAM data show that NS Power’s retail sales are down by roughly 5%, which is consistent with impa...

AI summary NS Power's planned reflection of the recession is deemed inadequate due to anticipated load reductions, particularly in commercial and industrial sectors. While residential loads may remain stable, commercial and industrial closures are expected to significantly reduce peak demand, impacting NS Power's planning and operations.

Question Part a,b,c,... Subject Topic IRP Reference Pages Quoted Materials Preamble Information Request / Clarification No. 1 a Demand Load Forecasts NS Power 2020 IRP 5-6 The Mid and High Electrification forecasts are adjusted to The deci...

AI summary The document requests justification for maintaining the endpoints of electrification forecasts in the NS Power 2020 Integrated Resource Plan (IRP), noting that adjustments were made to moderate the initial steep increase in electrification. It also highlights the need to account for historical economic contractions on load forecasts, referencing the impact of the 2008-2010 recession.

NS Power Response conditions. It is critical that this IRP fully assess the import options available to Nova Scotia. Load Forecast Hendriks-01 Detailed historical data requests, additional analyses and The requestor advised that he is a Ph...

AI summary NS Power responds to data requests related to load forecasting and the Integrated Resource Plan (IRP). The requestor, a PhD student, seeks historical load data and analysis of recessionary effects on demand. NS Power notes that much of the requested information is already available to stakeholders and questions the justification for maintaining certain endpoints aligned with SDGA goals.

Covid CA Include impacts of current global economic recession on NS Power’s load and the As requested, NS Power has provided an update on load impacts observed from the effects of the COVID- implications of that recession for the resource...

AI summary The text discusses NS Power's updates to its resource plan in response to the impacts of the global economic recession and the ongoing effects of the COVID-19 pandemic on load. It also mentions adjustments to key inputs for the planning reserve margin (PRM) and the use of updated modeling environments and data, including ELCC contributions calculated via the RESOLVE model.

Analysis of Nova Scotia Power’s 2020 Integrated Resource Plan Recommendations on Key Findings, Action Plan, and Roadmap Elements Prepared for Counsel to Nova Scotia Utility and Review Board December 23, 2020 AUTHORS Bob Fagan Devi Glick Sh...

AI summary This document analyzes Nova Scotia Power’s 2020 Integrated Resource Plan, focusing on scenario planning, modeling assumptions, and results. It addresses load forecasting, demand-side management, and electrification strategies, prepared for the Nova Scotia Utility and Review Board. Key sections include modeling methodologies and outcomes from Synapse Energy’s analysis.

6. Address Effect of PHP Load Explicitly address the effect of PHP load. The LRT requires that NSPI exclude PHP from its planning considerations. NSPI should assess the effect of incorporating PHP load in resource planning to ensure that P...

AI summary NSPI must assess the impact of PHP load on resource planning, ensuring it doesn't burden FAM customers long-term. The LRT was replaced by the ELIADC Tariff, which manages PHP's load as a demand response tool, reducing firm peak load. The Board considers the audit recommendation closed but notes ELIADC's performance remains unproven.

26 Electrification Load Forecasting IRP 4.1 (Load Forecast) Finding (1a), (1b) Action Plan (1), (2) Roadmap (7) As noted earlier the SBA notes that NSPI actions flowing from the

AI summary The text references comments on the IRP Final Report by Bates White, mentioning the SBA's note on NSPI actions related to electrification, load forecasting, and the IRP 4.1 Load Forecast. It also refers to findings, action plans, and a roadmap.