Topic:"Energy Efficiency Resource Assessment Model" in M04265

DETERMINATION OF ENERGY USE (Continued) - (b) The total kilowatt-hour use. - (2) Maintenance Energy Use and Standby Energy Use shall be determined by apportioning the total kilowatthour use less the Supplementary Energy Use in proportion t...

AI summary The document outlines the method for determining maintenance and standby energy use by apportioning total kilowatt-hour use, excluding supplementary energy use, based on the products of power demands and hours of use.

ELIGIBILITY The following customers can apply for this option, provided their demand exceeds 5 M\IV: - New or existing direct indus:rial customers of Ontario Hydro. or - Large customers of a municipai electric utility or a distributing com...

AI summary This section outlines eligibility criteria for the Load Retention and Expansion Price (LREP) program. Customers must meet specific conditions, including demand exceeding 5 MIV, and provide detailed business cases and third-party reviews for load retention or expansion projects, particularly when involving load transfers or self-generation.

EEN II then stores these results and reports them in a choice of four executive smnmary formats. Hundreds of least-cost planning cases can be evaluated without looking at each individual computer run. The Scenario Planning feature of PROSC...

AI summary PROSCREEN II offers enhanced scenario planning and decision analysis capabilities, streamlining study setup, reducing errors, and enabling complex business decisions under uncertainty. It also provides multiple executive summary formats for presenting results.

Introduction PROSCREEN II is available for installation on a wide range of computer systems or for use on EMA's time-sharing computer service. PROSCREEN II will operate on all PRIME, VAX, Data General, IBM CMS, MYS, and MVS/XA systems. PRO...

AI summary PROSCREEN II is a strategic planning tool designed for utility planning, offering ease of use on various computer systems, including mainframes, PCs, and UNIX-based workstations. It is intended for use by analysts with utility planning expertise, not software developers.

Control System Users have two options for interfacing with the modules and the strategic database. One option, the PROSCREEN Il Control System, is a flexible interface which uses a set of English-language line commands to access the system...

AI summary The PROSCREEN II Control System provides users with flexible interfaces to interact with modules and a strategic database. It supports year-by-year output requests, dynamic input adjustments, and features like the Executive Command Facility and Operating System Bridge for enhanced usability.

classes affected by the reallocation of costs. Hourly load shapes could be entered for these classes, and the user need only enter peak, energy, and coincidence factors for any remaining load classes. The analysis of programs which lack hi...

AI summary The text discusses the use of the LFA Module in analyzing demand-side management (DSM) programs, particularly those without historic data. It highlights the module's ability to model energy savings and peak demand reductions, as well as its integration with other modules like GAF and FIR for production costing and financial analysis. The LFA Module is used in three stages of DSM evaluation: screening, integrated optimization, and detailed analysis.

General Capabilities - The module provides a comprehensive demand-side program evaluation capability, with inputs for program cost, load impact, timing, and capital costs. - Load impacts may be input chronologically for each program, or ma...

AI summary The LFA Module provides comprehensive capabilities for demand-side program evaluation, load impact analysis, and load shape data input. It supports detailed or aggregated data modeling, integrates with other modules like GAF and PROMOD, and allows flexible price response and reconciliation of electric price assumptions. The module supports various input formats and reporting by end-use, class, and company.

Introduction The DSVIEW System consists of the DSVIEW Program Design (DSVIEW-DPD) Module and the DSVIEW Cost Effectiveness (DSVIEW -DCE) Module . This section presents an overview of both modules. DSVIEW's advantage as a DSM planning syste...

AI summary The DSVIEW System includes two modules for DSM planning: DSVIEW-DPD and DSVIEW-DCE. It allows utilities to evaluate demand-side measures comprehensively, considering both demand-side and supply-side costs and operations. The system helps identify optimal combinations of demand-side alternatives and supports integrated resource planning.

Introduction The Cost Effectiveness portion of the DSVIEW System (DSVIEW-DCE) has three primary components which run stand-alone or integrated: - Load Forecast Adjustment (LFA) Module models chronological seasonal loads (by end-use and/or...

AI summary The DSVIEW-DCE system includes three modules: Load Forecast Adjustment (LFA), Generation and Fuel (GAF), and DSVIEW-DCE. These modules support load forecasting, production costing simulation, and cost-effectiveness analysis for demand-side management programs. They generate detailed reports and input summaries for documenting assumptions.

RANKii = Ranking of plan i, based on objective j Packages of DSM programs called portfolios are developed based on the initially calculated benefit/cost ratios and user-supplied data on levels of investment and attitudes toward risk. A pac...

AI summary The document describes how DSM portfolios are developed using benefit/cost ratios and investment data, with DSVIEW-DCE evaluating programs to meet portfolio-building criteria. Results include benefit/cost ratios, program rankings, and portfolio reports used in integrated resource planning models like PROVIEW.

Module Methodology PROVIEW's Dynamic Programming calculations are s1lIIl.Jllal'ize as follows: - 1. A capital cost table is constructed. This table contains either the economic carrying charge or in-service date charge for every alternativ...

AI summary The document outlines the methodology of PROVIEW's Dynamic Programming calculations, including the construction of a capital cost table, determination of feasible states, end effects analysis, and selection of the least-cost expansion plan. It also describes the tracing back of optimal plans and their setup for further analysis.

Output Reports The following reports are produced by PROVIEW: - System Cost Repon - Least Cost Plan Smnma:ry Integrated Plan Repon - Demand Side Report Study Period Plan Comparison - Tunnel Repon Planning Period Plan Comparison - Significa...

AI summary The document outlines various reports and diagnostics generated by PROVIEW, including System Cost Reports, Least Cost Plan Summaries, Demand Side Reports, and diagnostics such as Reserve Analysis and Levelized Cost Tables. These tools are used for planning and analysis in the energy sector.

Articles in Technical Journals - "Cloudy Days for DSM." With A. Faruqui and G. Wikler. Electricity Journal, vol. 7, no. 6, July/August 1994, pp. 54-66. - "Efficient Block Rate Structures: Rethinking Conventional Wisdom." With K. Seiden. El...

AI summary The text lists various academic articles published in technical journals, primarily focusing on topics related to demand-side management (DSM), rate structures, forecasting models, and electricity generation costs. These articles were authored by John H. Chamberlin and his colleagues and appeared in journals such as the Electricity Journal, EPRI Journal, and The Engineering Economist.

Export Procedures - 40. As noted in the NSPI Notice of Intervention, the timing and manner of approval of gas exports is relevant to this proceeding because, to the extent that the projects are dependent on export sales and shipments, it i...

AI summary NSPI argues that the export approval procedures used for Western Canada's gas markets are not suitable for Nova Scotia's Sable Island gas projects, which lack a competitive market. NSPI emphasizes the need to apply the Market-Based Procedure under the National Energy Board Act to ensure public interest and equitable access to gas resources.

Coal Demand Drops Assuming no Electricity Exports In the absence of very detailed information about export markets, it is difficult to determine how realistic the export case is. For purposes of assessing the impact on coal, we take a cons...

AI summary The document discusses the impact of assuming zero electricity exports on coal demand in Nova Scotia. It estimates a reduction in coal demand by about 400,000 tonnes as the Tuft's Cove conversion comes online in 2000, assuming maximum use of natural gas.

Recommendations: - 1) The Steering Committee.accepts and endorses the recommendations which are set forth and more fully amplifi_ed in the attached report of the consultants, Gardner/Pinfold and Hillary and Associates. In summary, the reco...

AI summary The Steering Committee recommends actions to support the CBRM region, including early access to natural gas, resource pooling for offshore projects, training programs for natural gas jobs, and a review of provincial energy policy. A lateral natural gas pipeline is also recommended to mitigate the impact of the SOEP on the region.

Regional SOEP & M&NP Impacts ' SOEP and M&NP are having a generally positive impact on the Nova Scotia economy, though the main employment and income impacts are concentrated in the areas of project activity. This is the triangle bounded b...

AI summary The Sable Offshore Energy Project (SOEP) and the Maritime and Northern Power (M&NP) project are positively impacting Nova Scotia's economy, primarily through employment and income in the Halifax, Strait of Canso, and Amherst region. However, participation from the CBRM is limited due to industrial capacity constraints, and Nova Scotia's content in these projects is expected to be between 20-25% for SOEP and 40-45% for M&NP, mainly from construction activities.

Future Offshore Projects Proposed exploration in the Sydney and Laurentian Basins should lead to positive impacts on adjacent coastal areas, in this case, the CBRM. The scale of the impact depends on the type and level of exploration activ...

AI summary Future offshore projects in the Sydney and Laurentian Basins may bring economic benefits to the CBRM through supply base development and support services. Exploration and development on the Scotian Shelf are anticipated to have positive impacts centered in the Halifax area.

RECOMMEND A TIO NS - 1. In light of the on-going weakness of the CBRM economy and the implications of the closure of CBDC, a framework for ensuring the CBRM gains early access to natural gas should be given careful consideration by governm...

AI summary The recommendations focus on addressing economic challenges in the CBRM due to CBDC's closure, promoting participation in offshore energy projects, developing training programs for natural gas jobs, and reviewing provincial energy policy to better align with supply and demand conditions.

3. APPROACH To meet these objectives, several tasks are carried out: - ) We start with SOEP and M&NP, tracing project spending within Nova Scotia and the CBRM. This forms the basis for determining so-called "Project Impacts". Of interest i...

AI summary The analysis outlines an approach to assess the energy and project impacts of the SOEP and M&NP. It focuses on tracing spending, evaluating energy demand impacts, and comparing scenarios with and without natural gas. Key factors include energy prices and environmental standards, with conclusions on gas's impact on coal and its competitiveness in the CBRM.

4. OUTLINE The report is presented in five chapters plus several appendices. This introduction is followed by an overview of the CBRM economy. Chapter II provides a detailed description of the natural gas projects, and the opportunities an...

AI summary The report outlines five chapters and appendices, covering the CBRM economy, natural gas projects, offshore exploration opportunities, natural gas market potential in Nova Scotia, and the impact of natural gas availability on coal demand.

Going back to look at Table II-2 (Chapter II), we see that Nova Scotia content during SOEP Phase I stands at about 30%. This Table reflects a pattern of participation not unlike that experienced elsewhere, and not unlike that with the CBRM...

AI summary The text discusses the participation of Nova Scotia in the Sable Offshore Energy Project (SOEP) Phase I, noting a 30% local content. It highlights that local firms may participate in project management and engineering through joint ventures or subcontracting, as these activities are typically handled by multinational EPC firms.

2. FACTORS AFFECTING NATURAL GAS DEMAND It is important to note that the mere availability of natural gas in Nova Scotia does not in itself guarantee a market. It must compete with existing fuels whose suppliers, including CBDC, would like...

AI summary The availability of natural gas in Nova Scotia does not ensure market success, as it must compete with existing fuels like those supplied by CBDC. Factors influencing natural gas demand include inter-fuel economics, gas distribution policies, environmental considerations, CBDC production capabilities, and potential electricity deregulation.

Cases The objective is to identify and measure the impacts (eg, changes in energy expenditures, employment, etc)-.arising from access to natural gas. An alternative Case approach is used as the basis for the analysis of change. Two cases a...

AI summary The analysis compares two cases—'Gas on Mainland Nova Scotia' and 'Gas in CBRM'—to measure the impacts of natural gas availability on energy expenditures and employment. These cases are evaluated against a 'No Gas' base case to assess changes in energy demand and supply patterns up to 2010.

Assumptions The analysis rests on several key assumptions: );,, Price: Relative prices of energy forms now available are assumed to remain constant in real terms at today's levels. Natural gas is assumed to be distributed to consumers at a...

AI summary The analysis assumes constant energy prices, with natural gas priced 10% below oil. It uses a low gas price case to estimate delivered costs, considering lateral and distribution tariffs. Gas demand is projected based on displacement of competing fuels, with 35% of residential energy demand expected to be met by gas by year ten. Feasibility of gas distribution is not fully assessed beyond the Gas in CBRM Case.

4. BASE CASE: NO GAS - ENERGY DEMAND TO 2010 The demand estimates in Table IV-1 form the starting point for the assessment of impacts natural gas is expected to have on final demand for energy. Total annual expenditure levels by energy sou...

AI summary This section outlines the Base Case scenario without natural gas, projecting energy expenditures from 1998 to 2010. Total annual energy expenditures are expected to rise from $1,066 million to $1,332 million over the study period.

A Basis for Comparison In light of these factors, several projections are possible: coal-fired expansion, oil-fired expansion, import-based expansion, or some combination of these three. From the perspective of the impact on coal, we would...

AI summary The text discusses potential energy expansion scenarios, emphasizing coal demand projections. It argues that coal demand should be measured based on CBDC's production capacity rather than hypothetical demand increases. A projection shows coal demand increasing from 3.2 million tonnes in 1998 to 3.9 million tonnes in 2010.

Combustion Efficiency and Operating Characteristics Combustion efficiency determines the actual cost of energy once it is converted to the user's needs. A shift to natural gas would cut the total amount of energy consurn.ed, where the shif...

AI summary The text discusses combustion efficiency across different sectors, noting that residential and industrial sectors may see efficiency gains or losses depending on fuel type and system design. Natural gas can improve efficiency in residential and power generation sectors, while industrial conversions may result in a slight efficiency loss but offset by other benefits.

TABLE B-1 BASE CASE: NO NATURAL GAS IN NOVA SCOTIA RESIDENTIAL ENERGY DEMAND Electricity Petroleum Wood Natural Gas Total Energy gwh LFO (mega 1) Prop (mega 1) tonnes ('000 mmbtu) ('000 mmbtu) 1996 3,730 530 25 17,500 0 34,394 1997 3,788 5...

AI summary This table presents residential energy demand in Nova Scotia from 1996 to 2010, showing data for electricity, petroleum, wood, and natural gas consumption. The data is segmented into various energy sources and measured in gigawatt-hours and million British thermal units. The table highlights the absence of natural gas usage during the period.

TABLE B-7 CASE A: NATURAL GAS ON MAINLAND NOVA SCOTIA AND STRAIT OF CAN SO COMMERCIAL-INSTITUTIONAL ENERGY DEMAND (000s MMBtu) Electricity Petroleum Natural Gas Total Energy LFO HFO Propane 1996 9,389 6,425 1,386 790 0 17,991 1997 10,277 6...

AI summary The table presents energy demand data for commercial-institutional sectors in Mainland Nova Scotia and the Strait of Canso from 1996 to 2010, showing the consumption of electricity, petroleum products, and natural gas. Natural gas enters the market in 2000, with usage increasing over time.

CASE A: NATURAL GAS ON MAINLAND NOVA SCOTIA AND STRAIT OF CANSO INDUSTRIAL ENERGY DEMAND (000s MMBtu) ł Electricity Petroleum Natural Gas Total Energy LFO HFO Propane 1006 0.574 1 550 7.000 7/7 0 17.0/2 1996 8,574 1,559 7,062 767 0 17,962...

AI summary The document provides data on energy demand in Nova Scotia from 1996 to 2010, showing the usage of electricity, petroleum, and natural gas. Natural gas enters the market in 2000, and there is a gradual increase in its consumption over time.

TABLEC-2 CASE B: NATURAL GAS IN THE CAPE BRETON REGIONAL MUNICIPALITY COMMERCIAL-INSTITUTIONAL ENERGY DEMAND (OOOs MMBtu) Electricity Petroleum Natural Gas Total Energy LFO HFO Propane 1996 1,328 909 196 1997 1,454 923 199 112 114 0 2,546...

AI summary The table presents energy demand data for the Cape Breton Regional Municipality from 1996 to 2010, showing trends in electricity, petroleum, and natural gas consumption. Natural gas begins entering the Nova Scotia market in 2000, as indicated in the text.

TABLEC-4 CASE B: NATURAL GAS IN THE CAPE BRETON REGIONAL MUNICIPALITY TOT AL ENERGY DEMAND (OOOs MMBtu) Electricity Petroleum Wood Natural Gas Energy LFO HFO Propane 1996 4,419 3,595 1,443 327 40 0 9,823 1997 4,632 3,648 1,464 332 40 0 10,...

AI summary The table presents energy demand data for the Cape Breton Regional Municipality from 1996 to 2010, detailing energy consumption by fuel type, including electricity, petroleum, wood, and natural gas. Natural gas usage increases significantly starting in 2001, while petroleum and wood usage decline over the period.

TOTAL ENERGY EXPENDITURES ($ 000s) I Electricity Petroleum Wood Natural Gas Total LFO HFO Propane - Andrews 1996 103,625 27,507 4,059 4,136 213 0 139,541 1997 108,623 27,920 4,120 4,199 213 0 145,075 1998 108,091 28,339 4,182 4,261 213 0 1...

AI summary The table presents total energy expenditures from 1996 to 2010, categorized by energy type and year. It includes expenditures on electricity, petroleum, wood, and natural gas. The electricity price is also provided as $23.45/mmbtu.

lear capacity has a marked impact on the electricity outlook after 2010. Forty seven percent of the new CCGT and 58 percent of the new coal capacity is expected to be introduced between 2010 and 2020. - Regional Differences in Relative Pri...

AI summary The text discusses regional differences in the relative prices of fuels for electricity suppliers, highlighting the geographical distribution of capacity by energy source. It notes that the West South Central region has seen increased reliance on natural gas due to coal transportation issues and higher coal prices.

Wide Distribution of Coal in Alberta Alberta's total coal resources are estimated at 2,600 gigatonnes, of which 800 gigatonnes are considered to be recoverable. These include 790 gigatonnes of sub-bituminous coal and 10 gigatonnes of bitum...

AI summary Alberta holds vast coal reserves, with 800 gigatonnes recoverable, including sub-bituminous and bituminous coals. Sub-bituminous coal meets most of Alberta's electricity needs, while metallurgical and thermal coals are exported. Coal is distributed across three distinct regions, each with unique characteristics and uses.

SUS energy charge does not constitute a legal impediment to implementation of Schedule SUS. 39. Schedule SUS would cause no significant disadvantage to members of any nonindustrial CSU rate classes. 40. Use of cogeneration potential as a b...

AI summary The document discusses the implementation of Schedule SUS, noting it does not hinder its adoption and benefits CSU and ratepayers by retaining industrial load. Concerns about potential load loss due to rising rates and the justification of Schedule SUS based on cogeneration viability are highlighted. Mr. Hughes' recommendations are rejected due to incomplete calculations.

DISCUSSION [I, 2) AP&L and Mid-America support approval of the Agreement. As a result of the August 19, 1988, amendment to the Agreement, the Staff now recommends approval of the Agreement. Also as a result of the amendment, AEEC, the othe...

AI summary AP&L and Mid-America support the approval of an agreement, which would allow Mid-America to reduce its electricity purchases from AP&L through co-generation. The Commission must determine if the agreement is just and reasonable. Experts testified that co-generation is a viable alternative for Mid-America, which currently does not generate its own electricity.