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Institutional barriers to DSM (demand side management): Reviewing the regulatory bargain

Description: The paper discusses traditional arguments for utility regulation in the context of the current utility environment. It reviews several DSM delivery options using a matrix of key financial considerations for utilities and consumers. The strengths and weaknesses of each option are discussed and an assessment of current prospects for DSM implementation is provided. The premise of the paper is that adoption of DSM by utilities and consumers has lagged because of technical and behavioral uncertainties. In addition, regulatory practices and DSM delivery mechanisms have not provided adequate means to extract the benefits of DSM and allocate the risks in a way that offers clear advantages over generating options. The paper concludes with a brief discussion of the potential for value of service approaches to resolve these problems.
Date: September 1, 1990
Creator: Warwick, W.M.
Partner: UNT Libraries Government Documents Department

Financial statistics of selected investor-owned electric utilities, 1989

Description: The Financial Statistics of Selected Investor-Owned Electric Utilities publication presents summary and detailed financial accounting data on the investor-owned electric utilities. The objective of the publication is to provide the Federal and State governments, industry, and the general public with current and historical data that can be used for policymaking and decisionmaking purposes related to investor-owned electric utility issues.
Date: January 1, 1991
Partner: UNT Libraries Government Documents Department

Mathematical model of a utility firm. Executive summary

Description: The project was aimed at developing an understanding of the economic and behavioral processes that take place within a utility firm, and without it. This executive summary, one of five documents, gives the project goals and objectives, outlines the subject areas of investigation, discusses the findings and results, and finally considers applications within the electric power industry and future research directions. (DLC)
Date: August 21, 1983
Partner: UNT Libraries Government Documents Department

A good integrated resource plan: Guidelines for electric utilities and regulators

Description: Integrated resource planning helps utilities and state regulatory commissions consistently assess a broad range of demand and supply resources to meet customer energy-service needs cost-effectively. Key characteristics of this planning approach include: explicit consideration and fair treatment of a wide variety of demand and supply options, consideration of the environmental and other social costs of providing energy services, public participation in the development of the resource plan, and analysis of the uncertainties associated with different external factors and resource options. Integrated resource planning differs from traditional planning in the types and scope of resources considered, the owners of the resources, the organizations involved in resource planning, and the criteria for resource selection. This report presents suggestions to utilities on how to conduct such planning and what to include in their resource-planning reports. These suggestions are based on a review of about 50 resource plans as well as discussions with and presentations to regulators and utilities. The suggestions cover four broad topics; the technical competence with which the plan was developed; the adequacy, detail, and consistency (with the long-term plan) of the short-term action plan; the extent to which the interests of various stakeholders was considered, both in public participation in plan development and in the variety of resource plans developedand assessed; and the clarity and comprehensiveness of the utility's report on its plan. Technical competence includes energy and demand forecasts, assessment of supply and demand resources, resource integration, and treatment of uncertainty. Issues associated with forecasts include forecasting approaches; links between the forecasts of energy use and peak demands; and links between the forecasts and the effects of past, present, and future demand-side management programs.
Date: December 1, 1992
Creator: Hirst, E.
Partner: UNT Libraries Government Documents Department

Estimated winter 1980-1981 electric demand and supply, contiguous United States. Staff report

Description: This report summarizes the most recent data available concerning projected electrical peak demands and available power resouces for the 1980-1981 winter peak period, as reported by electric utilities in the contiguous United States. The data, grouped by Regional Reliability Council areas and by Electrical Regions within the Council areas, was obtained from the Form 12E-2 reports filed by utilities with the Department of Energy on October 15, 1980 (data as of September 30). In some instances the data were revised or verified by telephone. Considerations affecting reliability, arising from Nuclear Regulatory Commission actions based on lessons learned from the forced outage of Three Mile Island Nuclear Unit No. 2, were factored into the report. No widespread large-scale reliability problems are foreseen for electric power supply this winter, on the basis of the supply and demand projections furnished by the electric utilities. Reserve margins could drop in some electric regions to levels considered inadequate for reliable service, if historical forced-outage magnitudes recur.
Date: December 1, 1980
Partner: UNT Libraries Government Documents Department

Project-pooled analyses: feasibility of combining data from several electric utility rate demonstration projects

Description: The US-DOE has sponsored projects in numerous locations from Puerto Rico or Rhode Island to California on the effects of time-of-use pricing on electric power use by residential customers. Each project has analyzed its own data with inevitable variations in analysis techniques and interpretation between different projects. The feasibility of either separate but standardized analyses of each project's results and of pooling all the separate project results in order to perform one overall analysis is discussed. It is concluded that the rate structures and experimental designs of the demonstration projects are not sufficiently compatible to warrant pooled analyses. The analyst desiring to use a pooled data base is forced to construct artificial models that can be estimated. Numerous, untestable assumptions are required and little or no gain in overall precision can be expected. It is, therefore, recommended that the project-specific analyses be emphasized and that the future reporting requirements on the project-pooled analyses be eliminated. (LCL)
Date: December 1, 1978
Partner: UNT Libraries Government Documents Department

Analysis of the need for intermediate and peaking technologies in the year 2000. Final report

Description: This analysis was conducted to assess the impact of load management on the future need for intermediate- and peak-generating technologies (IPTs) such as combustion turbines, pumped storage, and cycling coal plants. There would be a reduced need for IPTs if load-management activities such as time-of-use pricing, together with customer-owned energy-storage devices, hot-water-heater controls, and interruptible service can economically remove most of the variation from electric power demands. The objective of this analysis is to assess the need for IPTs in an uncertain future, which will probably include load management and time-differentiated electricity prices. The analysis is exploratory in nature and broad in scope. It does not attempt to predict the future or to model precisely the technical characteristics or economic desirability of load management. Rather, its purpose is to provide research and development planners with some basic insights into the order of magnitude of possible hourly demand shifts on a regional basis and to determine the impact of load management on daily and seasonal variations in electricity demand.
Date: April 1, 1980
Creator: Barrager, S.M. & Campbell, G.L.
Partner: UNT Libraries Government Documents Department

California Marginal-Cost-Pricing Project. [Analysis of methods used to quantify MCP]

Description: This report provides a detailed analysis of methods to quantify the marginal costs of electricity supply. The nine-point criteria used include measurement of marginal costs that are consistent with economic theory, and determination of the applicability of the method and results in regulatory proceedings. The report examines methods which cover a wide range of potential cost-measurement techniques, including linear-programming models of utility systems, production functions, and simple models based on identification of marginal units. These methods were generally found to be unacceptable because they do not calculate marginal costs of a specified demand increment, and do not adequately reflect the utility's planning process. Furthur research is described that will attempt to develop more-acceptable marginal-cost estimates in rate proceedings. 29 references, 21 figures, 28 tables.
Date: September 1, 1979
Partner: UNT Libraries Government Documents Department

Techniques of analyzing the impacts of certain electric-utility ratemaking and regulatory-policy concepts. Bibliography

Description: This bibliography provides documentation for use by state public utility commissions and major nonregulated utilities in evaluating the applicability of a wide range of electric utility rate design and regulatory concepts in light of certain regulatory objectives. Part I, Utility Regulatory Objectives, contains 2084 citations on conservation of energy and capital; efficient use of facilities and resources; and equitable rates to electricity consumers. Part II, Rate Design Concepts, contains 1238 citations on time-of-day rates; seasonally-varying rates; cost-of-service rates; interruptible rates (including the accompanying use of load management techniques); declining block rates; and lifeline rates. Part III, Regulatory Concepts, contains 1282 references on restrictions on master metering; procedures for review of automatic adjustment clauses; prohibitions of rate or regulatory discrimination against solar, wind, or other small energy systems; treatment of advertising expenses; and procedures to protect ratepayers from abrupt termination of service.
Date: August 1, 1980
Partner: UNT Libraries Government Documents Department

Environmental externalities: A survey of state commission actions

Description: Awareness of the environmental consequences of electricity production have led many state public utility commissions (PUC) to consider these externalities formally in their regulation of utilities. At the request of NARUC's Energy Conservation staff subcommittee, the Lawrence Berkeley Laboratory conducted a survey to identify the extent and range of PUC approaches to this issue; responses were obtained from PUC staff in 49 states and the District of Columbia. The study should be viewed as providing a snapshot'' of regulatory developments in an area that is evolving rapidly. 16 refs.
Date: May 1, 1990
Creator: Cohen, S.D.; Eto, J.H. (National Association of Regulatory Utility Commissioners, Washington, DC (United States)); Goldman, C.A. (Lawrence Berkeley Lab., CA (United States)); Beldock, J. (USDOE Assistant Secretary for Conservation and Renewable Energy, Washington, DC (United States). Office of Buildings and Community Systems) & Crandall, G. (MSB Associates, Middleton, WI (United States))
Partner: UNT Libraries Government Documents Department

Capacity-expansion planning under uncertainty in the electric-utility industry

Description: This document basically represents a comparison between theory and practice of capacity-expansion planning in the electric-utility industry. The purpose of the comparison is to provide avenues for further exploration in utility decision making. The focus of the Phase II study is upon the role of uncertainty in the decision-making process. The Phase I effort was directed at modeling the Averch-Johnson theory of the regulated utility. Part I of this report reviews the Anderson study (D. Anderson, Models for Determining Least-Cost Investments in Electricity Supply). The Anderson paper has become a standard reference for capacity-planning studies in the electric-utility industry. Part II examines uncertainty and the behavior of the firm. Part III reviews 5 models of electric-utility capacity planning under uncertainty, and Part IV is concerned with capacity-planning models in practice.
Date: July 25, 1980
Creator: Soyster, A.L.
Partner: UNT Libraries Government Documents Department

Electric-utility DSM programs: 1990 data and forecasts to 2000

Description: In April 1992, the Energy Information Administration (EIA) released data on 1989 and 1990 electric-utility demand-site management (DMS) programs. These data represent a census of US utility DSM programs, with reports of utility expenditures, energy savings, and load reductions caused by these programs. In addition, EIA published utility estimates of the costs and effects of these programs from 1991 to 2000. These data provide the first comprehensive picture of what utilities are spending and accomplishing by utility, state, and region. This report presents, summarizes, and interprets the 1990 data and the utility forecasts of their DSM-program expenditures and impacts to the year 2000. Only utilities with annual sales greater than 120 GWh were required to report data on their DSM programs to EIA. Of the 1194 such utilities, 363 reported having a DSM program that year. These 363 electric utilities spent $1.2 billion on their DSM programs in 1990, up from $0.9 billion in 1989. Estimates of energy savings (17,100 GWh in 1990 and 14,800 GWh in 1989) and potential reductions in peak demand (24,400 MW in 1990 and about 19,400 MW in 1989) also showed substantial increases. Overall, utility DSM expenditures accounted for 0.7% of total US electric revenues, while the reductions in energy and demand accounted for 0.6% and 4.9% of their respective 1990 national totals. The investor-owned utilities accounted for 70 to 90% of the totals for DSM costs, energy savings, and demand reductions. The public utilities reported larger percentage reductions in peak demand and energy smaller percentage DSM expenditures. These averages hide tremendous variations across utilities. Utility forecasts of DSM expenditures and effects show substantial growth in both absolute and relative terms.
Date: June 1, 1992
Creator: Hirst, E.
Partner: UNT Libraries Government Documents Department

The demand-side management program development process: A utility perspective

Description: This report describes an aspect of DSM that has received little attention, namely, how utilities develop DSM programs. The selection of utilities to study purposely was biased in favor of those with reputations for being experienced DSM program developers so as to optimize the chances to obtain detailed information. The DSM planning process is affected by organizational factors and external influences: (1) the location of the demand-side planning department within the utility; (2) the demand-side planning group's functional responsibilities; (3) upper management participation in the DSM program development process; and (4) the organizational relationship between (or, separation of) supply-side and demand-side planning. Organizational factors reflect utilities' views of DSM programs and thus can affect the adoption of a technology- or customer-oriented approach. Despite repeated claims of the uniqueness of the demand- side planning process and its resistance to standardization, two general approaches to program development were discerned, namely technology- or customer-orientation. Although utilities consider customer related and technological factors in their DSM program development process, utilities can be differentiated by their emphasis on one or the other approach. 25 refs.
Date: March 1, 1992
Creator: Wolfe, A.K. (Oak Ridge National Lab., TN (United States)) & Yourstone, N.E. (Yourstone (Evelin), Albuquerque, NM (United States))
Partner: UNT Libraries Government Documents Department

Data requirements for valuing externalities: The role of existing permitting processes

Description: While the assessment of externalities, or residual impacts, will place new demands on regulators, utilities, and developers, existing processes already require certain data and information that may fulfill some of the data needs for externality valuation. This paper examines existing siting, permitting, and other processes and highlights similarities and differences between their data requirements and the data required to value environmental externalities. It specifically considers existing requirements for siting new electricity resources in Oregon and compares them with the information and data needed to value externalities for such resources. This paper also presents several observations about how states can take advantage of data acquired through processes already in place as they move into an era when externalities are considered in utility decision-making. It presents other observations on the similarities and differences between the data requirements under existing processes and those for valuing externalities. This paper also briefly discusses the special case of cumulative impacts. And it presents recommendations on what steps to take in future efforts to value externalities. 35 refs., 2 tabs.
Date: August 1, 1990
Creator: Lee, A.D.; Baechler, M.C. & Callaway, J.M.
Partner: UNT Libraries Government Documents Department

Electric-utility DSM programs: Terminology and reporting formats

Description: The number, scope, effects, and costs of electric-utility demand-site management programs are growing rapidly in the United States. Utilities, their regulators, and energy policy makers need reliable information on the costs of, participation in, and energy and load effects of these programs to make informed decisions. In particular, information is needed on the ability of these programs to cost-effectively provide energy and capacity resources that are alternatives to power plants. This handbook addresses the need for additional and better information in two ways. First, it discusses the key concepts associated with DSM-program types, participation, energy and load effects, and costs. Second, the handbook offers definitions and a sample reporting form for utility DSM programs. The primary purpose in developing these definitions and this form is to encourage consistency in the collection and reporting of data on DSM programs. To ensure that the discussions, reporting formats, and definitions will be useful and used, development of this handbook was managed by a committee, with membership from electric utilities, state regulatory commissions, and the US Department of Energy. Also, this data-collection form was pretested by seven people from six utilities, who completed the form for nine DSM programs.
Date: October 1, 1991
Creator: Hirst, E. (Oak Ridge National Lab., TN (United States)) & Sabo, C. (Barakat and Chamberlin, Inc., Washington, DC (United States))
Partner: UNT Libraries Government Documents Department

Public involvement in integrated resource planning: A study of demand-side management collaboratives

Description: Many utilities and nonutility parties (NUPs) across the country have tried a new approach to reaching agreement on Demand-Side Management (DSM) program design and policy issues. Through this, which is called the DSM collaborative process, parties who have often been adversaries in the past attempt to reach consensus rather than using traditional litigation to resolve differences. We examined nine cases of DSM collaboration involving 24 utilities and approximately 50 NUPs in 10 states. This is the first comprehensive, in-depth review and assessment of collaboratives and it allows conclusions to be drawn about the collaborative process and the factors that contribute to successful efforts of this type. Collaboratives are described in terms of four major contextual and organizational characteristics: regulatory and legal history, parties involved and parties excluded, collaborative scope, and the collaborative process itself.
Date: February 1, 1992
Creator: Raab, J. (Raab (J.), Boston, MA (United States)) & Schweitzer, M. (Oak Ridge National Lab., TN (United States))
Partner: UNT Libraries Government Documents Department

Incentives for demand-side management

Description: This report is the first product of an ongoing project to monitor the efforts of states to remove regulatory barriers to, and provide financial incentives for, utility investment in demand-side management (DSM) resources. The project was commissioned by the National Association of Regulatory Utility Commissioners (NARUC) in response to growing interest among regulators for a comprehensive survey of developments in this area. Each state report beings with an overview of the state's progress toward removing regulatory barriers and providing incentives for DSM. Information is organized under five headings: status; IRP regulations and practice; current treatment of DSM, directions and trends; commission contact person. Where applicable, each overview is followed by one or more sections that report on specific incentive proposals or mechanisms within the state. Information on each proposal or mechanism is organized under eight headings. A notation on each page identifies the utility or other group associated with the proposal or mechanism. The eight headings are as follows: status; background; treatment of cost recovery; treatment of lost revenues/decoupling; treatment of profitability; other features; issues, and additional observations.
Date: January 1, 1992
Creator: Reid, M.W. & Brown, J.B. (Barakat and Chamberlin, Inc., Oakland, CA (United States))
Partner: UNT Libraries Government Documents Department

Consumer's Guide to the economics of electric-utility ratemaking

Description: This guide deals primarily with the economics of electric utilities, although certain legal and organizational aspects of utilities are discussed. Each of the seven chapters addresses a particular facet of public-utility ratemaking. Chapter One contains a discussion of the evolution of the public-utility concept, as well as the legal and economic justification for public utilities. The second chapter sets forth an analytical economic model which provides the basis for the next four chapters. These chapters contain a detailed examination of total operating costs, the rate base, the rate of return, and the rate structure. The final chapter discusses a number of current issues regarding electric utilities, mainly factors related to fuel-adjustment costs, advertising, taxes, construction work in progress, and lifeline rates. Some of the examples used in the Guide are from particular states, such as Illinois and California. These examples are used to illustrate specific points. Consumers in other states can generalize them to their states and not change the meaning or significance of the points. 27 references, 8 tables.
Date: May 1, 1980
Partner: UNT Libraries Government Documents Department

Capital Requirements Estimating Model (CREMOD) for electric utilities. Volume I. Methodology description, model, description, and guide to model applications. [For each year up to 1990]

Description: The Capital Requirements Estimating Model for the Electric Utilities (CREMOD) is a system of programs and data files used to estimate the capital requirements of the electric utility industry for each year between the current one and 1990. CREMOD disaggregates new electric plant capacity levels from the Mid-term Energy Forecasting System (MEFS) Integrating Model solution over time using actual projected commissioning dates. It computes the effect on aggregate capital requirements of dispersal of new plant and capital expenditures over relatively long construction lead times on aggregate capital requirements for each year. Finally, it incorporates the effects of real escalation in the electric utility construction industry on these requirements and computes the necessary transmission and distribution expenditures. This model was used in estimating the capital requirements of the electric utility sector. These results were used in compilation of the aggregate capital requirements for the financing of energy development as published in the 1978 Annual Report to Congress. This volume, Vol. I, explains CREMOD's methodology, functions, and applications.
Date: January 1, 1980
Creator: Collins, D E; Gammon, J & Shaw, M L
Partner: UNT Libraries Government Documents Department

Financial statistics of selected publicly owned electric utilities 1989. [Contains glossary]

Description: The Financial Statistics of Selected Publicly Owned Electric Utilities publication presents summary and detailed financial accounting data on the publicly owned electric utilities. The objective of the publication is to provide the Federal and State governments, industry, and the general public with data that can be used for policymaking and decision making purposes relating to publicly owned electric utility issues. 21 tabs.
Date: February 6, 1991
Partner: UNT Libraries Government Documents Department

Analytical Master Plan for the analysis of the data from the electric utility rate demonstration projects

Description: The Federal Energy Administration (now the US Department of Energy), in cooperation with state public utility commissions and participating utilities, has initiated 16 electric utility rate demonstration projects. The primary purpose of these projects was to evaluate experimentally the effects of time-of-use pricing of electricity for residential customers. The time-of-use rate most frequently employed was a time-of-day (TOD) rate. The method employed by the states to evaluate TOD rates was to select a subset of the residential population, place these people on TOD rates, and with special meters, monitor their temporal use of electricity. As might be expected, with the varying objectives of the states, available resources, and background in load management studies, a variety of approaches were employed, and a variety of data generated by the projects. Also, the received and expected analyses of the data vary considerably among the projects due to the differing interests of the states, available resources, and the composition of the project teams. The three purposes of this Analytical Master Plan (AMP) are: to ensure the data derived from the FEA projects and from related sources are subjected to econometric and statistical analysis that is both rigorous and as highly sophisticated as the state of the art will permit; to ensure that the results of the analysis are organized and displayed in a manner useful to utility and regulatory decision-makers; and to ensure that the analytical effort is conducted on a timely and professional basis. This report identifies the alternative analytical approaches, project specific analyses, project-pooled analyses and organization and management plan for completing the study. Synopses of all the demonstration projects are presented in the appendixes which are bound separately in Volume II.
Date: June 1, 1978
Partner: UNT Libraries Government Documents Department

Sharing the savings to promote energy efficiency

Description: Shared-savings incentives offer a new way for regulated utilities to improve earnings by encouraging customer energy efficiency. Benefits of cost-effective energy efficiency measures can be shared explicitly among customers participating in an utility demand-side management (DSM) program, all utility ratepayers, and the utility itself. For participating customers, electricity bills are lowered directly; for ratepayers, the costs of providing electric services are reduced; and for utility shareholders, they are allowed to retain a fraction of the net benefits as additional earnings. In this study, we define the basic elements of shared-savings arrangements for utility demandside resources. Next, we compare and contrast specific details of the arrangements approved for three different utilities: Pacific Gas and Electric Company (PG E), San Diego Gas and Electric Company (SDG E), and two operating subsidiaries of the New England Electric System (NEES). Our analysis suggests that the percentage share of net benefits on which utilities are allowed to earn is a relatively poor indicator of the incentive mechanism's overall affect on utility earnings. Earnings opportunities and potential are also significantly influenced by particular incentive features. These include the definition and measurement of load reductions, program costs, and program benefits; program cost recovery and the timing of incentive recovery; performance thresholds; program spending and earnings caps; program eligibility criteria; treatment of lost revenues; and for NEES, a complementary, non-shared-savings incentive. We conclude that the collaborative'' processes used to develop incentives for each utility proved extremely useful in allowing parties to negotiate trade-offs inherent between various program design features.
Date: April 1, 1992
Creator: Eto, J.; Destribats, A. & Schultz, D.
Partner: UNT Libraries Government Documents Department