Cost and quality of fuels for electric utility plants, 1994

Energy Technology Data Exchange (ETDEWEB)

NONE

1995-07-14

This document presents an annual summary of statistics at the national, Census division, State, electric utility, and plant levels regarding the quantity, quality, and cost of fossil fuels used to produce electricity. Purpose of this publication is to provide energy decision-makers with accurate, timely information that may be used in forming various perspectives on issues regarding electric power.

Least cost planning as a regulatory concept in the Federal Republic of Germany

International Nuclear Information System (INIS)

Leprich, U.

1994-01-01

The least cost planning concept is a result of the traditional planning of business activities on the part of public utilities developed further. In the light of operating efficiency it certainly makes sense for public utilities to limit or at least shift power demand in certain situations (''load management''), thereby enlarging the scope for entrepreneurial action. LCP as a regulatory concept, by contrast, discards this view, judging the efforts of utilities to ensure efficient use of electrical energy exclusively from an overall economic angle. The relevant question is then no longer ''When does LCP make sense for public utilities, given current boundary conditions?'' but rather, ''To what extent are LCP activities desirable in national economic terms, and in what way must the regulatory system be adapted to permit utilities to launch such activities?'' What LCP as a ''competitive concept'' is about, is foremost, the substitution competition between the energy source electric power and the respective application technology that produces the desired ''service''. (orig./UA) [de

Least-cost network evaluation of centralized and decentralized contributions to global electrification

International Nuclear Information System (INIS)

Levin, Todd; Thomas, Valerie M.

2012-01-01

The choice between centralized and decentralized electricity generation is examined for 150 countries as a function of population distribution, electricity consumption, transmission cost, and the cost difference between decentralized and centralized electricity generation. A network algorithm is developed to find the shortest centralized transmission network that spans a given fraction of the population in a country. The least-cost combination of centralized and decentralized electricity that serves the country is determined. Case studies of Botswana, Uganda, and Bangladesh illustrate situations that are more and less suited for decentralized electrification. Specific maps for centralized and decentralized generation are presented to show how the least-cost option varies with the relative costs of centralized and decentralized generation and transmission cost. Centralized and decentralized fractions are calculated for 150 countries. For most of the world's population, centralized electricity is the least-cost option. For a number of countries, particularly in Africa, substantial populations and regions may be most cost-effectively served by decentralized electricity. - Highlights: ► Centralized and decentralized electrification are compared for 150 countries. ► A cost-optimized network algorithm finds the least-cost electrification system. ► Least-cost infrastructures combine centralized and decentralized portions. ► For most people, centralized electricity is cheapest option. ► In much of Africa, decentralized electricity may be cheaper than centralized.

Trends in transmission, distribution, and administration costs for U.S. investor-owned electric utilities

International Nuclear Information System (INIS)

Fares, Robert L.; King, Carey W.

2017-01-01

This paper analyzes the cost of transmission, distribution, and administration for U.S. investor-owned electric utilities. We analyze data reported to the Federal Energy Regulatory Commission (FERC) from 1994 to 2014 using linear regression to understand how the number of customers in a utility's territory, annual peak demand, and annual energy sales affect annual TD&A spending. Then, we use Edison Electric Institute data for 1960 to 1992 to show trends in TD&A spending between 1960 and 2014. We find that the number of customers in a utility's territory is the single best predictor for annual TD&A costs. Between 1994 and 2014, the average cost per customer was $119/Customer-Year for transmission, $291/Customer-Year for distribution, and $333/Customer-Year for utility administration. Total TD&A costs per customer have been approximately $700–$800/Customer-Year since 1960, but the cost per kWh of energy sold was significantly higher in the 1960s because the average customer used less than half as much energy annually versus 2014. Thus, TD&A costs per kWh are likely to increase if kWh energy sales decline in the future unless cost recovery is transitioned to a mechanism not based solely on kWh sales. - Highlights: • U.S. investor-owned electric utility delivery costs from 1960? 2014 are investigated. • Transmission, distribution, and utility administrative costs are analyzed separately. • The number of utility customers is the best predictor for annual delivery costs. • Delivery costs per kWh are likely to increase if kWh sales decrease in the future.

Evaluation of actual costs of power sources and effects on balance sheets of electric utilities

International Nuclear Information System (INIS)

Matsuo, Yuji; Yamaguchi, Yuji; Murakami, Tomoko

2013-01-01

After the Fukushima nuclear accident, almost all nuclear power stations continued to stop operation and sharp increase of purchase costs of fossil fuels forced some electric utilities to suffer a deficit. This article presented quantitative analysis of effects of present state on power costs and balance sheets of electric utilities. Levelized costs of electricity increased from 8.6 ¥/kWh (2010) to 11.6 ¥/kWh (2011) and 12.6 ¥/kWh (2012). Total power costs increased from 7.5 Trillion¥(2010) to 9.5 Trillion¥(2011). Due to increase of cost of fossil fuel compensated for nuclear power, electric utilities suffered a net loss of 0.8 Trillion¥ and decreased surplus to 2.5 Trillion¥ in 2011. Net loss of 1.3 Trillion¥ and surplus of 1.2 Trillion¥ was estimated for 2012. This state was beyond the limit of utilities' efforts to reduce costs and uncertain share of power sources became a great risk. Future share of power sources should be judged appropriately from various standpoints (costs, stable supply, energy security and national economic growth) and early public dissemination of new philosophy on share of power sources was highly required. (T. Tanaka)

State Regulatory responses to acid rain: Implications for electric utility operations

International Nuclear Information System (INIS)

Nagelhout, M.

1990-01-01

This article discusses the state regulatory responses to acid rain legislation and how this will affect electric utility operations. Topics discusses include planning and fuel procurement practices, least-cost planning, long-term supply contracts, fuel mix, cogeneration and small power production, qualifying facility contracts, avoided costs, environmental impact, lobbying expense, bill inserts, and forecasting models

Cost of energy from utility-owned solar electric systems. A required revenue method for ERDA/EPRI evaluations

Energy Technology Data Exchange (ETDEWEB)

1976-06-01

This methodology calculates the electric energy busbar cost from a utility-owned solar electric system. This approach is applicable to both publicly- and privately-owned utilities. Busbar cost represents the minimum price per unit of energy consistent with producing system-resultant revenues equal to the sum of system-resultant costs. This equality is expressed in present value terms, where the discount rate used reflects the rate of return required on invested capital. Major input variables describe the output capabilities and capital cost of the energy system, the cash flows required for system operation and maintenance, and the financial structure and tax environment of the utility.

The impact of cost recovery on electric utilities' Clean Air Act compliance strategies

International Nuclear Information System (INIS)

Bensinger, D.L.

1993-01-01

By 1995, over 200 electric power plant units in twenty one states must comply with Phase I of the acid rain requirements in Title IV of the 1990 Clean Air Act Amendments (CAAA). By the year 2000, an additional 2200 units must comply with the Title IV. Compliance costs are expected to necessitate significant electricity rate increases. In order to recover their compliance costs, utilities must file rate increase requests with state public utility commissions (PUC's), and undergo a rate proceeding involving public heatings. Because of the magnitude of cost and the complexity of compliance options, including interaction with Titles I and III of the CAAA, extensive PUC reviews of compliance strategies are likely. These reviews could become as adversarial as the nuclear prudence reviews of the 1980's. A lack of understanding of air pollution and the CAA by much of the general public and the flexibility of compliance options creates an environment conducive to adverse public reaction to the cost of complying with the Clean Air Act. Public attitudes toward pollution control technologies will be greatly affected by these hearings, and the early plant hearings will shape the utility rate making process under the Clean Air Act. Inadequate cost recovery due to constrained compliance strategies or adverse hearings could significantly inhibit industry willingness to invest in certain control technologies or advanced combustion technologies. There are already signs that Clean Air Act compliance will be the prudence issue of the 1990's for utilities, even where state statutes mandate particular compliance approaches. Specific actions should be undertaken now by the utility industry to improve the probability of sound cost recovery decisions, preserve compliance options, including multimedia strategies, and avoid the social- and cost-acceptance problems of nuclear power

User's guide to SERICPAC: A computer program for calculating electric-utility avoided costs rates

Energy Technology Data Exchange (ETDEWEB)

Wirtshafter, R.; Abrash, M.; Koved, M.; Feldman, S.

1982-05-01

SERICPAC is a computer program developed to calculate average avoided cost rates for decentralized power producers and cogenerators that sell electricity to electric utilities. SERICPAC works in tandem with SERICOST, a program to calculate avoided costs, and determines the appropriate rates for buying and selling of electricity from electric utilities to qualifying facilities (QF) as stipulated under Section 210 of PURA. SERICPAC contains simulation models for eight technologies including wind, hydro, biogas, and cogeneration. The simulations are converted in a diversified utility production which can be either gross production or net production, which accounts for an internal electricity usage by the QF. The program allows for adjustments to the production to be made for scheduled and forced outages. The final output of the model is a technology-specific average annual rate. The report contains a description of the technologies and the simulations as well as complete user's guide to SERICPAC.

Measuring the costs of photovoltaics in an electric utility planning framework

International Nuclear Information System (INIS)

Awerbuch, Shimon

1993-01-01

Utility planning models evaluate alternative generating options using the revenue requirements method-an engineering-oriented, discounted cash-flow (DCF) methodology that has been widely used for over three decades. Discounted cash-flow techniques were conceived in the context of active expense-intensive technologies, such as conventional, fuel-intensive power generation. Photovoltaic (PV) technology, by contrast, is passive and capital intensive-attributes that are similar to those of other new process technologies, such as computer-integrated manufacturing. Discounted cash-flow techniques have a dismal record for correctly valuing new technologies with these attributes, in part because their benefits cannot be easily measured using traditional accounting concepts. This paper examines how these issues affect cost measurement in both conventional and PV-based electricity, and presents kWh-cost estimates for three technologies (coal, gas and PV) using risk-adjusted approaches, which suggest that PV costs are generally equivalent to the gas/combined cycle and about twice the cost of base-load coal (environmental externalities are ignored). Finally, the paper evaluates independent power purchases for a typical US utility and finds that in such a setting the cost of PV-based power is comparable to the firm's published avoided costs. (author)

Recovery of Utility Fixed Costs: Utility, Consumer, Environmental and Economist Perspectives

Energy Technology Data Exchange (ETDEWEB)

Wood, Lisa [Inst. for Electric Innovation and The Edison Foundation, Washington DC (United States); Hemphill, Ross [RCHemphill Solutions, Columbus, OH (United States); Howat, John [National Consumer Law Center, Boston, MA (United States); Cavanagh, Ralph [Natural Resources Defense Council, New York, NY (United States); Borenstein, Severin [Univ. of California, Berkeley, CA (United States); Deason, Jeff [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States); Schwartz, Lisa [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States); Schwartz, Lisa [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States)

2016-06-14

Utilities recover costs for providing electric service to retail customers through a combination of rate components that together comprise customers’ monthly electric bills. Rates and rate designs are set by state regulators and vary by jurisdiction, utility and customer class. In addition to the fundamental tenet of setting fair and reasonable rates, rate design balances economic efficiency, equity and fairness, customer satisfaction, utility revenue stability, and customer price and bill stability.1 At the most basic level, retail electricity bills in the United States typically include a fixed monthly customer charge — a set dollar amount regardless of energy usage — and a volumetric energy charge for each kilowatt-hour consumed.2 The energy charge may be flat across all hours, vary by usage level (for example, higher rates at higher levels of usage), or vary based on time of consumption.3 While some utility costs, such as fuel costs, clearly vary according to electricity usage, other costs are “fixed” over the short run — generally, those that do not vary over the course of a year. Depending on your point of view, and whether the state’s electricity industry has been restructured or remains vertically integrated, the set of costs that are “fixed” may be quite limited. Or the set may extend to all capacity costs for generation, transmission and distribution. In the long run, all costs are variable. In the context of flat or declining loads in some regions, utilities are proposing a variety of changes to retail rate designs, particularly for residential customers, to recover fixed costs. In this report, authors representing utility (Chapter 1), consumer (Chapter 2), environmentalist (Chapter 3) and economist (Chapter 4) perspectives discuss fixed costs for electric utilities and set out their principles for recovering those costs. The table on the next page summarizes each author’s relative preferences for various options for fixed cost

Least-cost electrical services as an alternative to the braidwood project

International Nuclear Information System (INIS)

Lovins, A.

1985-01-01

This book is a summary of testimony before the Illinois Commerce Commission. The author argues that even if it cost nothing to build the Braidwood plant, it would cost less to write it off and buy electricity-saving measures instead

Inter-utility trade in electricity

International Nuclear Information System (INIS)

Penman, A.

1992-01-01

Enhanced inter-utility cooperation could have a profound effect on the future of the electricity supply industry. Coordinated planning, development, and operations of electric power systems have the potential to reduce the cost of electricity to consumers and to lessen the impact of electricity supply on the environment. These effects could be achieved by being able to supply electricity from lower cost and more environmentally benign sources located over wider geographic areas, and having to install less new generating capacity. Access to transmission and wheeling services would be an important factor in allowing increased inter-utility cooperation to occur. Canada's National Energy Board conducted a review to identify measures that can be taken to enhance interprovincial trade in electricity, to encourage greater cooperation between electric utilities in the areas of systems planning and development, and to enable buyers and sellers of electricity to obtain access to available transmission capacity through intervening provinces for wheeling purposes. The work undertaken by the Board during that review is described. A total estimated economic benefit of $23-32.5 billion was identified, mainly from long-term firm sales and from seasonal diversity exchanges. Four options were developed that appear to be available to encourage and achieve enhanced inter-utility cooperation. These are continuation of voluntary cooperation, voluntary cooperation with federal monitoring, establishing voluntary regional planning entities, and establishing regional planning entities with mandated federal power

Methods for Analyzing the Benefits and Costs of Distributed Photovoltaic Generation to the U.S. Electric Utility System

Energy Technology Data Exchange (ETDEWEB)

Denholm, P.; Margolis, R.; Palmintier, B.; Barrows, C.; Ibanez, E.; Bird, L.; Zuboy, J.

2014-09-01

This report outlines the methods, data, and tools that could be used at different levels of sophistication and effort to estimate the benefits and costs of DGPV. In so doing, we identify the gaps in current benefit-cost-analysis methods, which we hope will inform the ongoing research agenda in this area. The focus of this report is primarily on benefits and costs from the utility or electricity generation system perspective. It is intended to provide useful background information to utility and regulatory decision makers and their staff, who are often being asked to use or evaluate estimates of the benefits and cost of DGPV in regulatory proceedings. Understanding the technical rigor of the range of methods and how they might need to evolve as DGPV becomes a more significant contributor of energy to the electricity system will help them be better consumers of this type of information. This report is also intended to provide information to utilities, policy makers, PV technology developers, and other stakeholders, which might help them maximize the benefits and minimize the costs of integrating DGPV into a changing electricity system.

DSM and electric utility competitiveness: An Illinois perspective

Energy Technology Data Exchange (ETDEWEB)

Jackson, P.W.

1994-12-31

A predominant theme in the current electric utility industry literature is that competitive forces have emerged and may become more prominent. The wholesale bulk power market is alreadly competitive, as non-utility energy service providers already have had a significant impact on that market; this trend was accelerated by the Energy Policy Act of 1992. Although competition at the retail level is much less pervasive, electric utility customers increasingly have greater choice in selecting energy services. These choices may include, depending on the customer, the ability to self-generate, switch fuels, move to a new location, or rely more heavily on demand-side management as a means of controlling electric energy use. This paper explores the subject of how demand-side management (DSM) programs, which are often developed by a utility to satisfy resource requirements as a part of its least-cost planning process, can affect the utility`s ability to compete in the energy services marketplace. In this context, the term `DSM` is used in this paper to refer to those demand-side services and programs which provide resources to the utility`s system. Depending on one`s perspective, DSM programs (so defined) can be viewed either as an enhancement to the competitive position of a utility by enabling it to provide its customers with a broader menu of energy services, simultaneously satisfying the objectives of the utility as well as those of the customers, or as a detractor to a utility`s ability to compete. In the latter case, the concern is with respect to the potential for adverse rate impacts on customers who are not participants in DSM programs. The paper consists of an identification of the pros and cons of DSM as a competitive strategy, the tradeoff which can occur between the cost impacts and rate impacts of DSM, and an examination of alternative strategies for maximizing the utilization of DSM both as a resource and as a competitive strategy.

DSM and electric utility competitiveness: An Illinois perspective

International Nuclear Information System (INIS)

Jackson, P.W.

1994-01-01

A predominant theme in the current electric utility industry literature is that competitive forces have emerged and may become more prominent. The wholesale bulk power market is alreadly competitive, as non-utility energy service providers already have had a significant impact on that market; this trend was accelerated by the Energy Policy Act of 1992. Although competition at the retail level is much less pervasive, electric utility customers increasingly have greater choice in selecting energy services. These choices may include, depending on the customer, the ability to self-generate, switch fuels, move to a new location, or rely more heavily on demand-side management as a means of controlling electric energy use. This paper explores the subject of how demand-side management (DSM) programs, which are often developed by a utility to satisfy resource requirements as a part of its least-cost planning process, can affect the utility's ability to compete in the energy services marketplace. In this context, the term 'DSM' is used in this paper to refer to those demand-side services and programs which provide resources to the utility's system. Depending on one's perspective, DSM programs (so defined) can be viewed either as an enhancement to the competitive position of a utility by enabling it to provide its customers with a broader menu of energy services, simultaneously satisfying the objectives of the utility as well as those of the customers, or as a detractor to a utility's ability to compete. In the latter case, the concern is with respect to the potential for adverse rate impacts on customers who are not participants in DSM programs. The paper consists of an identification of the pros and cons of DSM as a competitive strategy, the tradeoff which can occur between the cost impacts and rate impacts of DSM, and an examination of alternative strategies for maximizing the utilization of DSM both as a resource and as a competitive strategy

Managing electricity procurement cost and risk by a local distribution company

International Nuclear Information System (INIS)

Woo, C.-K.; Karimov, R.I.; Horowitz, Ira

2004-01-01

A local electricity distribution company (LDC) can satisfy some of its future electricity requirements through self-generation and volatile spot markets, and the remainder through fixed-price forward contracts that will reduce its exposure to the inherent risk of spot-price volatility. A theoretical framework is developed for determining the forward-contract purchase that minimizes the LDCs expected procurement cost, subject to a cost-exposure constraint. The answers to the questions of 'What to buy?' and 'How to buy?' are illustrated using an example of a hypothetical LDC that is based on a municipal utility in Florida. It is shown that the LDCs procurement decision is consistent with least-cost procurement subject to a cost-exposure constraint, and that an internet-based multi-round auction can produce competitive price quotes for its desired forward purchase

Impact of Federal tax policy and electric utility rate schedules upon the solar building/electric utility interface. Executive summary

Energy Technology Data Exchange (ETDEWEB)

Feldman, S.L.; Wirtshafter, R.M.; Abrash, M.; Anderson, B.; Sullivan, P.; Kohler, J.

1978-10-01

An analysis is performed to show that a utility solar-passive strategy can be used rather effectively in aiding the utility to obtain more efficient load factors and lower costs. The objectives are to determine the impact of active and passive solar energy designs for space conditioning and hot water heating for the residential sector upon the diurnal and annual load curves for several utilities, to assess the effect of present utility pricing policies, and to examine alternative pricing schemes, as well as Federal and state tax credits, as they may affect the optimal sizing and configuration of active solar and passive solar building components. The methodology, the systems model, an overall building design, building cost determination, and a description of TRNSYS are presented. The major parameters discussed that distinguish variation in the cost-effectiveness of particular building design fall into 5 categories: the weather, building configurations, building costs, utility costs and rates, and financial parameters (inclusive of tax credits for solar and energy conservation investment). Five utilities are studied: Colorado Springs Department of Public Utilities; Public Service Co. of New Mexico; New England Electric System; Pacific Gas and Electric; and Georgia Power Co.

Willingness to Pay for Renewable Electricity: A Review of Utility Market Research

Energy Technology Data Exchange (ETDEWEB)

Farhar, B. C.

1999-09-09

As competition in the electric utility industry has become more widespread and federal legislation deregulating the utility industry more likely, utilities have become more concerned about actions they can take to help ensure the loyalty of their customers. National polls have, for 20 years, found majority preferences for renewable energy over other energy sources. This issue brief compiles and analyzes recent market research conducted by utility companies on customer interest in and willingness to pay for renewable electricity. Findings in the areas examined in this review are: Customers are favorable toward renewable sources of electricity, although they know little about them; Solar and wind are the most favored sources of electricity generation; Majorities of 52% to nearly 100% of residential customers said they were willing to pay at least a modest amount more per month on their electric bills for green power; their responses follow a predictable curve showing that percentages willing to pay more decline as cost increases. The residential market for green pricing is approximately 2% near program rollout at a $5/month price increment, and should increase slowly but steadily over time; Customers may view with favor, and be more willing to purchase electricity from, utilities that provide green power.

Estimating the cost of saving electricity through U.S. utility customer-funded energy efficiency programs

International Nuclear Information System (INIS)

Hoffman, Ian M.; Goldman, Charles A.; Rybka, Gregory; Leventis, Greg; Schwartz, Lisa; Sanstad, Alan H.; Schiller, Steven

2017-01-01

The program administrator and total cost of saved energy allow comparison of the cost of efficiency across utilities, states, and program types, and can identify potential performance improvements. Comparing program administrator cost with the total cost of saved energy can indicate the degree to which programs leverage investment by participants. Based on reported total costs and savings information for U.S. utility efficiency programs from 2009 to 2013, we estimate the savings-weighted average total cost of saved electricity across 20 states at $0.046 per kilowatt-hour (kW h), comparing favorably with energy supply costs and retail rates. Programs targeted on the residential market averaged $0.030 per kW h compared to $0.053 per kW h for non-residential programs. Lighting programs, with an average total cost of $0.018 per kW h, drove lower savings costs in the residential market. We provide estimates for the most common program types and find that program administrators and participants on average are splitting the costs of efficiency in half. More consistent, standardized and complete reporting on efficiency programs is needed. Differing definitions and quantification of costs, savings and savings lifetimes pose challenges for comparing program results. Reducing these uncertainties could increase confidence in efficiency as a resource among planners and policymakers. - Highlights: • The cost of saved energy allows comparisons among energy resource investments. • Findings from the most expansive collection yet of total energy efficiency program costs. • The weighted average total cost of saved electricity was $0.046 for 20 states in 2009–2013. • Averages in the residential and non-residential sectors were $0.030 and $0.053 per kW h, respectively. • Results strongly indicate need for more consistent, reliable and complete reporting on efficiency programs.

Managing electricity procurement cost and risk by a local distribution company

International Nuclear Information System (INIS)

Chikeung Woo; Karimov, R.I.; Horowitz, I.

2004-01-01

A local electricity distribution company (LDC) can satisfy some of its future electricity requirements through self-generation and volatile spot markets, and the remainder through fixed-price forward contracts that will reduce its exposure to the inherent risk of spot-price volatility. A theoretical framework is developed for determining the forward-contract purchase that minimizes the LDCs expected procurement cost, subject to a cost-exposure constraint. The answers to the questions of ''What to buy?'' and ''How to buy?'' are illustrated using an example of a hypothetical LDC that is based on a municipal utility in Florida. It is shown that the LDCs procurement decision is consistent with least-cost procurement subject to a cost-exposure constraint, and that an internet-based multi-round auction can produce competitive price quotes for its desired forward purchase. (author)

A methodology to identify stranded generation facilities and estimate stranded costs for Louisiana's electric utility industry

Science.gov (United States)

Cope, Robert Frank, III

1998-12-01

The electric utility industry in the United States is currently experiencing a new and different type of growing pain. It is the pain of having to restructure itself into a competitive business. Many industry experts are trying to explain how the nation as a whole, as well as individual states, will implement restructuring and handle its numerous "transition problems." One significant transition problem for federal and state regulators rests with determining a utility's stranded costs. Stranded generation facilities are assets which would be uneconomic in a competitive environment or costs for assets whose regulated book value is greater than market value. At issue is the methodology which will be used to estimate stranded costs. The two primary methods are known as "Top-Down" and "Bottom-Up." The "Top-Down" approach simply determines the present value of the losses in revenue as the market price for electricity changes over a period of time into the future. The problem with this approach is that it does not take into account technical issues associated with the generation and wheeling of electricity. The "Bottom-Up" approach computes the present value of specific strandable generation facilities and compares the resulting valuations with their historical costs. It is regarded as a detailed and difficult, but more precise, approach to identifying stranded assets and their associated costs. This dissertation develops a "Bottom-Up" quantitative, optimization-based approach to electric power wheeling within the state of Louisiana. It optimally evaluates all production capabilities and coordinates the movement of bulk power through transmission interconnections of competing companies in and around the state. Sensitivity analysis to this approach is performed by varying seasonal consumer demand, electric power imports, and transmission inter-connection cost parameters. Generation facility economic dispatch and transmission interconnection bulk power transfers, specific

Electric utility power plant construction costs, 1st Edition

International Nuclear Information System (INIS)

Anon.

1993-01-01

New UDI report combines historical construction costs for more than 1,000 coal, oil, gas, nuclear and geothermal units that have entered commercial operation since 1966 and projected power plant construction costs for about 400 utility-owned generating units scheduled to enter commercial operation during the next 20 years. Key design characteristics and equipment suppliers, A/E, constructor and original installed cost data. Direct construction costs without AFUDC are provided where known. Historical construction cost data are also provided for about 130 utility-owned hydroelectric, gas turbine, combined-cycle and diesel units (these data are generally for units entering service after 1980)

Estimation of cost-effectiveness of the Finnish electricity distribution utilities

International Nuclear Information System (INIS)

Kopsakangas-Savolainen, Maria; Svento, Rauli

2008-01-01

This paper examines the cost-effectiveness of Finnish electricity distribution utilities. We estimate several panel data stochastic frontier specifications using both Cobb-Douglas and Translog model specifications. The conventional models are extended in order to model observed heterogeneity explicitly in the cost frontier models. The true fixed effects model has been used as a representative of the models which account for unobserved heterogeneity and extended conventional random effect models have been used in analysing the impact of observed heterogeneity. A comparison between the conventional random effects model and models where heterogeneity component is entered either into the mean or into the variance of the inefficiency term shows that relative efficiency scores diminish when heterogeneity is added to the analysis. The true fixed effects model on the other hand gives clearly smaller inefficiency scores than random effects models. In the paper we also show that the relative inefficiency scores and rankings are not sensitive to the cost function specification. Our analysis points out the importance of the efficient use of the existing distribution network. The economies of scale results suggest that firms could reduce their operating costs by using networks more efficiently. According to our results average size firms which have high load factors are the most efficient ones. All firms have unused capacities so that they can improve cost-effectiveness rather by increasing the average distributed volumes than by mergers

Estimation of cost-effectiveness of the Finnish electricity distribution utilities

Energy Technology Data Exchange (ETDEWEB)

Kopsakangas-Savolainen, Maria; Svento, Rauli [Department of Economics, University of Oulu (Finland)

2008-03-15

This paper examines the cost-effectiveness of Finnish electricity distribution utilities. We estimate several panel data stochastic frontier specifications using both Cobb-Douglas and Translog model specifications. The conventional models are extended in order to model observed heterogeneity explicitly in the cost frontier models. The true fixed effects model has been used as a representative of the models which account for unobserved heterogeneity and extended conventional random effect models have been used in analysing the impact of observed heterogeneity. A comparison between the conventional random effects model and models where heterogeneity component is entered either into the mean or into the variance of the inefficiency term shows that relative efficiency scores diminish when heterogeneity is added to the analysis. The true fixed effects model on the other hand gives clearly smaller inefficiency scores than random effects models. In the paper we also show that the relative inefficiency scores and rankings are not sensitive to the cost function specification. Our analysis points out the importance of the efficient use of the existing distribution network. The economies of scale results suggest that firms could reduce their operating costs by using networks more efficiently. According to our results average size firms which have high load factors are the most efficient ones. All firms have unused capacities so that they can improve cost-effectiveness rather by increasing the average distributed volumes than by mergers. (author)

Cost structure analysis of commercial nuclear power plants in Japan based on corporate financial statements of electric utility companies

International Nuclear Information System (INIS)

Kunitake, Norifumi; Nagano, Koji; Suzuki, Tatsujiro

1998-01-01

In this paper, we analyze past and current cost structure of commercial nuclear power plants in Japan based on annual corporate financial statements published by the Japanese electric utility companies, instead of employing the conventional methodology of evaluating the generation cost for a newly constructed model plant. The result of our study on existing commercial nuclear plants reveals the increasing significance of O and M and fuel cycle costs in total generation cost. Thus, it is suggested that electric power companies should take more efforts to reduce these costs in order to maintain the competitiveness of nuclear power in Japan. (author)

An economic and legal perspective on electric utility transition costs

Energy Technology Data Exchange (ETDEWEB)

Rose, K.

1996-07-01

The issue of possibly unrecoverable cost incurred by a utility, or `stranded costs,` has emerged as a major obstacle to developing a competitive generation market. Stranded or transition costs are defined as costs incurred by a utility to serve its customers that were being recovered in rates but are no longer due to availability of lower-priced alternative suppliers. The idea of `stranded cost,` and more importantly arguments for its recovery, is a concept with little basis in economic theory, legal precedence, or precedence in other deregulated industries. The main argument recovery is that the ``regulatory compact`` requires it. This is based on the misconception that the regulator compact is simply: the utility incurs costs on behalf of its customers because of the ``obligation to serve`` so, therefore, customers are obligated to pay. This is a mischaracterization of what the compact was and how it developed. Another argument is that recovery is required for economic efficiency. This presumes, however, a very narrow definition of efficiency based on preventing ``uneconomic`` bypass of the utility and that utilities minimize costs. A broader definition of efficiency and the likelihood of cost inefficiencies in the industry suggest that the cost imposed on customers from inhibiting competition could exceed the gains from preventing uneconomic bypass. Both these issues are examined in this paper.

The Ursern electricity utility - Positive and negative aspects

International Nuclear Information System (INIS)

Niederhaeusern, A.

2008-01-01

In this interview with Markus Russi, head of an electricity utility in the Swiss Alps, recent Swiss legislation such as the Energy law and the cost-covering remuneration of power from renewable energy sources is discussed. The production of the power generation facilities belonging to the utility - hydropower and wind energy - is discussed and future refurbishment and expansion work noted. The situation in the electricity market and co-operation with other local electricity utilities are also discussed and various disadvantages of the new Swiss electricity market legislation are noted. Future partnerships with other utilities with similar business strategies are discussed.

Superconducting magnetic energy storage for electric utility load leveling: A study of cost vs. stored energy

International Nuclear Information System (INIS)

Luongo, C.A.; Loyd, R.J.

1987-01-01

Superconducting Magnetic Energy Storage (SMES) is a promising technology for electric utility load leveling. This paper presents the results of a study to establish the capital cost of SMES as a function of stored energy. Energy-related coil cost and total installed plant cost are given for construction in nominal soil and in competent rock. Economic comparisons are made between SMES and other storage technologies and peaking gas turbines. SMES is projected to be competitive at stored energies as low as 1000 MWh

Electric utility deregulation - A nuclear opportunity

International Nuclear Information System (INIS)

DeMella, J.R.

2002-01-01

The implications of electric deregulation are and will continue to be pervasive and significant. Not only will the fundamental monopoly regulatory concepts of managing electric utilities change but deregulation will have a profound and dramatic impact on the way electric generating plants are managed and operated. In the past, under the various approaches to financial regulation, the economic benefits normally attributed to competition or that would have otherwise been derived from competitive or open market forces, were assumed to be embodied in and inherent to the various processes, methods and principles of financial oversight of utility companies by regional, state and municipal regulatory authorities. Traditionally, under the various forms of regulated monopolies, a utility company, in exchange for an exclusive franchise to produce and sell electricity in a particular region, was obligated to provide an adequate supply to all consumers wanting it, at a price that was 'just and reasonable'. The determination of adequate supply and reasonable price was a matter of interpretation by utility companies and their regulators. In essence, the ultimate economic benefits, normally attributed to price equilibrium, in balance with supply, demand and other market forces, were expected to be achieved through a complex, political process of financial regulatory oversight, in which utility companies were usually reimbursed for all annual expenses or their 'cost of service' and additionally allowed to earn a 'reasonable' rate of return on plant investments. The result was often escalating electric prices, over supplies of electric capacity, by justifying unnecessarily high reserve margins based on long planning horizons (typically 20 years or greater) with extrapolated demand requirements that were generally in excess of what actually occurred over time. Although the regulatory process varied from country or country and region-to-region, the fundamental principles, which

Electric plant cost and power production expenses 1991

International Nuclear Information System (INIS)

1993-01-01

Electric Plant Cost and Power Production Expenses is prepared by the Survey Management Division; Office of Coal, Nuclear, Electric and Alternate Fuels (CNEAF); Energy Information Administration (EIA); US Department of Energy. This publication presents electric utility statistics on power production expenses and construction costs of electric generating plants. Data presented here are intended to provide information to the electric utility industry, educational institutions, Federal, State, and local governments, and the general public. These data are collected and published to fulfill data collection and dissemination responsibilities of the Energy Information Administration (EIA), as specified in the Federal Energy Administration Act (Public Law 93-275), as amended

Electric plant cost and power production expenses 1990

International Nuclear Information System (INIS)

1992-06-01

Electric Plant Cost and Power Production Expenses is prepared by the Survey Management Division; Office of Coal, Nuclear, Electric and Alternate Fuels, Energy Information Administration (EIA); US Department of Energy. This publication presents electric utility statistics on power production expenses and construction costs of electric generating plants. Data presented here are intended to provide information to the electric utility industry, educational institutions, Federal, State, and local governments, and the general public. These data are collected and published to fulfill data collection and dissemination responsibilities of the Energy Information Administration (EIA), as specified in the Federal Energy Administration Act (Public Law 93-275), as amended

Concepts for reducing nuclear utility inventory carrying costs

International Nuclear Information System (INIS)

Graybill, R.E.; DiCola, F.E.; Solanas, C.H.

1985-01-01

Nuclear utilities are under pressure to reduce their operating and maintenance expenses such that the total cost of generating electricity through nuclear power remains an economically attractive option. One area in which expenses may be reduced is total inventory carrying cost. The total inventory carrying cost consists of financing an inventory, managing the inventory, assuring quality, engineering of acceptable parts specifications, and procuring initial and replenishment stock. Concepts and methodology must be developed to reduce the remaining expenses of a utility's total inventory carrying cost. Currently, two concepts exist: pooled inventory management system (PIMS), originally established by General Electric Company and a group of boiling water reactor owners, and Nuclear Parts Associates' (NUPA) shared inventory management program (SIMP). Both concepts share or pool parts and components among utilities. The SIMP program objectives and technical activities are summarized

Total life cycle cost model for electric power stations

International Nuclear Information System (INIS)

Cardullo, M.W.

1995-01-01

The Total Life Cycle Cost (TLCC) model for electric power stations was developed to provide a technology screening model. The TLCC analysis involves normalizing cost estimates with respect to performance standards and financial assumptions and preparing a profile of all costs over the service life of the power station. These costs when levelized present a value in terms of a utility electricity rate. Comparison of cost and the pricing of the electricity for a utility shows if a valid project exists. Cost components include both internal and external costs. Internal costs are direct costs associated with the purchase, and operation of the power station and include initial capital costs, operating and maintenance costs. External costs result from societal and/or environmental impacts that are external to the marketplace and can include air quality impacts due to emissions, infrastructure costs, and other impacts. The cost stream is summed (current dollars) or discounted (constant dollars) to some base year to yield a overall TLCC of each power station technology on a common basis. While minimizing life cycle cost is an important consideration, it may not always be a preferred method for some utilities who may prefer minimizing capital costs. Such consideration does not always result in technology penetration in a marketplace such as the utility sector. Under various regulatory climates, the utility is likely to heavily weigh initial capital costs while giving limited consideration to other costs such as societal costs. Policy makers considering external costs, such as those resulting from environmental impacts, may reach significantly different conclusions about which technologies are most advantageous to society. The TLCC analysis model for power stations was developed to facilitate consideration of all perspectives

Strategies to address transition costs in the electricity industry

Energy Technology Data Exchange (ETDEWEB)

Baxter, L.; Hadley, S.; Hirst, E.

1996-07-01

Transition costs are the potential monetary losses that electric- utility shareholders, ratepayers, or other parties might experience because of structural changes in the electricity industry. Regulators, policy analysts, utilities, and consumer groups have proposed a number of strategies to address transition costs, such as immediately opening retail electricity markets or delaying retail competition. This report has 3 objectives: identify a wide range of strategies available to regulators and utilities; systematically examine effects of strategies; and identify potentially promising strategies that may provide benefits to more than one set of stakeholders. The many individual strategies are grouped into 6 major categories: market actions, depreciation options, rate-making actions, utility cost reductions, tax measures, and other options. Of the 34 individual strategies, retail ratepayers have primary or secondary responsibility for paying transition costs in 19 of the strategies, shareholders in 12, wheeling customers in 11, taxpayers in 8, and nonutility suppliers in 4. Most of the strategies shift costs among different segments of the economy, although utility cost reductions can be used to offset transition costs. Most of the strategies require cooperation of other parties, including regulators, to be implemented successfully; financial stakeholders must be engages in negotiations that hold the promise of shared benefits. Only by rejecting ``winner-take-all`` strategies will the transition-cost issue be expeditiously resolved.

Decreased Opioid Utilization and Cost at One Year in Chronic Low Back Pain Patients Treated with Transcutaneous Electric Nerve Stimulation (TENS).

Science.gov (United States)

Pivec, Robert; Minshall, Michael E; Mistry, Jaydev B; Chughtai, Morad; Elmallah, Randa K; Mont, Michael A

2015-11-01

Chronic low back pain (CLBP) may be treated without opioids through the use of transcutaneous electrical nerve stimulation (TENS). However, no study has evaluated its clinical effect and economic impact as measured by opioid utilization and costs. The purpose of this study was to evaluate patients who were given TENS for CLBP compared to a matched group without TENS at one-year follow-up, to determine differences between opioid consumption. Opioid utilization and costs in patients who did and did not receive TENS were extracted from a Medicare supplemental administrative claims database. Patients were selected if they had at least two ICD-9-CM coded claims for low back pain in a three-month period and were then propensity score matched at a 1:1 ratio between patients who received TENS and those who did not. There were 22,913 patients in each group who had a minimum follow-up of one year. There were no significant demographic or comorbidity differences with the exception that TENS patients had more episodes of back pain. Significantly fewer patients in the TENS group required opioids at final follow-up (57.7 vs. 60.3%). TENS patients also had significantly fewer annual per-patient opioid costs compared to non-TENS patients ($169 vs. $192). There were significantly lower event rates in TENS patients compared to non-TENS patients when measured by opioid utilization (characterized by frequency of prescription refills) (3.82 vs. 4.08, respectively) or pharmacy utilization (31.67 vs. 32.25). The TENS group also demonstrated a significantly lower cost of these utilization events ($44 vs. $49) and avoided more opioid events (20.4 events fewer per 100 patients annually). Treatment of CLBP with TENS demonstrated significantly fewer patients requiring opioids, fewer events where a patient required an opioid prescription, and lower per-patient costs. Since TENS is both non-invasive and a non-narcotic, it may potentially allow physicians to be more aggressive in treating CLBP

Power Sales to Electric Utilities

Energy Technology Data Exchange (ETDEWEB)

None

1989-02-01

The Public Utilities Regulatory Policies Act (PURPA) of 1979 requires that electrical utilities interconnect with qualifying facilities and purchase electricity at a rate based upon their full avoided costs (i.e., costs of providing both capacity and energy). Qualifying facilities (QF) include solar or geothermal electric units, hydropower, municipal solid waste or biomass-fired power plants, and cogeneration projects that satisfy maximum size, fuel use, ownership, location, and/or efficiency criteria. In Washington State, neither standard power purchase prices based upon a proxy ''avoided plant'', standard contracts, or a standard offer process have been used. Instead, a variety of power purchase contracts have been negotiated by developers of qualifying facilities with investor-owned utilities, public utility districts, and municipally-owned and operated utilities. With a hydro-based system, benefits associated with resource acquisition are determined in large part by how compatible the resource is with a utility's existing generation mix. Power purchase rates are negotiated and vary according to firm energy production, guarantees, ability to schedule maintenance or downtime, rights of refusal, power plant purchase options, project start date and length of contract; front-loading or levelization provisions; and the ability of the project to provide ''demonstrated'' capacity. Legislation was also enacted which allows PURPA to work effectively. Initial laws established ownership rights and provided irrigation districts, PUDs, and municipalities with expanded enabling powers. Financial processes were streamlined and, in some cases, simplified. Finally, laws were passed which are designed to ensure that development proceeds in an environmentally acceptable manner. In retrospect, PURPA has worked well within Washington. In the state of Washington, 20 small-scale hydroelectric projects with a combined generating capacity of

Wind turbine cost of electricity and capacity factor

International Nuclear Information System (INIS)

Cavallo, A.J.

1995-01-01

Wind turbines are currently designed to minimize the cost of electricity at the wind turbine (the busbar cost) in a given wind regime, ignoring constraints on the capacitor factor (the ratio of the average power output to the maximum power output). The trade-off between these two quantities can be examined in a straightforward fashion; it is found that the capacitor factor can be increased by a factor of 1.3 above its value at the cost minimum for a 10 percent increase in the cost of electricity. This has important implications for the large scale integration of wind electricity on utility grids where the cost of transmission and storage may be a significant fraction of the cost of delivered electricity. (Author)

A framework and review of customer outage costs: Integration and analysis of electric utility outage cost surveys

Energy Technology Data Exchange (ETDEWEB)

Lawton, Leora; Sullivan, Michael; Van Liere, Kent; Katz, Aaron; Eto, Joseph

2003-11-01

A clear understanding of the monetary value that customers place on reliability and the factors that give rise to higher and lower values is an essential tool in determining investment in the grid. The recent National Transmission Grid Study recognizes the need for this information as one of growing importance for both public and private decision makers. In response, the U.S. Department of Energy has undertaken this study, as a first step toward addressing the current absence of consistent data needed to support better estimates of the economic value of electricity reliability. Twenty-four studies, conducted by eight electric utilities between 1989 and 2002 representing residential and commercial/industrial (small, medium and large) customer groups, were chosen for analysis. The studies cover virtually all of the Southeast, most of the western United States, including California, rural Washington and Oregon, and the Midwest south and east of Chicago. All variables were standardized to a consistent metric and dollar amounts were adjusted to the 2002 CPI. The data were then incorporated into a meta-database in which each outage scenario (e.g., the lost of electric service for one hour on a weekday summer afternoon) is treated as an independent case or record both to permit comparisons between outage characteristics and to increase the statistical power of analysis results. Unadjusted average outage costs and Tobit models that estimate customer damage functions are presented. The customer damage functions express customer outage costs for a given outage scenario and customer class as a function of location, time of day, consumption, and business type. One can use the damage functions to calculate outage costs for specific customer types. For example, using the customer damage functions, the cost experienced by an ''average'' customer resulting from a 1 hour summer afternoon outage is estimated to be approximately $3 for a residential customer, $1

Estimating potential stranded commitments for U.S. investor-owned electric utilities

International Nuclear Information System (INIS)

Baxter, L.; Hirst, E.

1995-01-01

New technologies, low natural gas prices, and federal and state utility regions are restructuring the electricity industry. Yesterday's vertically integrated utility with a retail monopoly franchise may be a very different organization in a few years. Conferences, regulatory-commission hearings, and other industry fora are dominated by debates over the extent and form of utility deintegration, wholesale competition, and retail wheeling. A key obstacle to restructuring the electricity industry is stranded commitments. Past investments, power-purchase contracts, and public-policy-driven programs that made sense in an era of cost-of-service regulation may not be cost-effective in a competitive power market. Regulators, utilities, and other parties face tough decisions concerning the mitigation and allocation of these stranded commitments. The authors developed and applied a simple method to calculate the amount of stranded commitments facing US investor-owned electric utilities. The results obtained with this method depend strongly on a few key assumptions: (1) the fraction of utility sales that is at risk with respect to competition, (2) the market price of electric generation, and (3) the number of years during which the utility would lose money because of differences between its embedded cost of production and the market price

The comparative costs of nuclear and fossil fuelled power plants in an American electricity utility

International Nuclear Information System (INIS)

Corey, G.R.

1984-01-01

This chapter compares the current and historic operating performances of twelve large nuclear and coal-fired units now operated by Commonwealth Edison Company, and provides specific comparison of bus-bar costs of electricity generated by those units in recent years. It also provides cost comparisons for future nuclear and coal-fired units and attempts to deal realistically with the effect of future inflation upon these comparisons. The chapter attempts to deal responsibly with the problem of uncertainty - how present-day comparisons may be affected by future developments and how my own published comparisons have varied over the past four or five years. The conclusion is reached that, given the uncertain world in which we live, no electric power supplier can afford to put all its eggs in one basket. Utility managers have a strong incentive to diversify their sources of power generation, and society as a whole would do well to encourage such diversification. (author)

Results from the OECD report on international projections of electricity generating costs

International Nuclear Information System (INIS)

Paffenbarger, J.A.; Bertel, E.

1998-01-01

The International Energy Agency and Nuclear Energy Agency of the OECD have periodically undertaken a joint study on electricity generating costs in OECD Member countries and selected non-Member countries. This paper presents key results from the 1998 update of this study. Experts from 19 countries drawn from electric utility companies and government provided data on capital costs, operating and maintenance costs, and fuel costs from which levelized electricity generating costs (US cents/kWh) for baseload power plants were estimated in each country using a common set of economic assumptions. Light water nuclear power plants, pulverized coal plants, and natural gas-fired combined cycle gas turbines were the principal options evaluated. five and 10% discount rates, 40-year operating lifetime, and 75% annual load factor were the base assumptions, with sensitivity analyses on operating lifetime and load factor. Fuel costs and fuel escalation were provided individually by country, with a sensitivity case to evaluate costs assuming no real fuel price escalation over plant lifetimes. Of the three principal fuel/technology options, none is predominantly the cheapest option for all economic assumptions. However, fossil-fueled options are generally estimated to be the least expensive option. The study confirms that gas-fired combined cycles have improved their economic performance in most countries in recent years and are strong competitors to nuclear and coal-fired plants. Eleven out of the 18 countries with two or more options show gas-fired plants to be the cheapest option at 10% discount rate. Coal remains a strong competitor to gas when lower discount rates are used. Nuclear is the least expensive at both 5 and 10% discount rate in only two countries. Generally, with gas prices above 5 US$/GJ, nuclear plants constructed at overnight capital costs below 1 650 $/kWe have the potential to be competitive only at lower discount rates

Repeated regulatory failures: British electric utilities, 1919--1937

Science.gov (United States)

van der Werf, Ysbrand John

This dissertation uses previously unexamined firm-level data to look at British electric utilities during the 1919--1937 period. The persistent influence of the 1882 and 1888 Electric Lighting Acts had a significant role in perpetuating the inefficient market structure and high costs of the industry. First, I examine factors that influence costs in 1919 and compare the relative cost efficiency of municipally-owned and investor-owned utilities (munis and IOUs). Scale and load factor are found to be more important than ownership in influencing costs, although IOUs enjoy a scale advantage. Given costs, there is no difference in prices between IOUs and munis, and on average prices were 20 percent below monopoly prices. Looking at the 1919--1928 period and examining changes in the industry as measured by the firms' choices in frequency, current, and interconnections with other utilities shows evidence for a great deal of change, which occurred in statistically predictable ways. Utilities are standardizing the type of current produced, and the eventual localized standard frequencies were selected by 1907. There is little in the way of market rivalry between mum's and IOUs but large munis are less likely to build networks and sell in the wholesale market. Finally, I compare the changes that occurred during the 1919--1928 period, under the weak intervention of the Electricity Commissioners, with those of the 1928--1937 period, under the strong intervention of the Central Electricity Board. Without the CEB localized frequency standards would likely have remained in place. The CEB intervened directly in the wholesale market, but contrary to common perceptions, this strong intervention had relatively little impact on trends observed in the industry under the weak intervention of the 1919--1928 period: the CEB reduced prices and costs by no more than about 15 percent and was responsible for at most a quarter of their decline during the 1928--37 period.

U.S. electric utility demand-side management 1995

International Nuclear Information System (INIS)

1997-01-01

The US Electric Utility Demand-Side Management report is prepared by the Coal and Electric Data and Renewables Division; Office of Coal, Nuclear, Electric and Alternative Fuels; Energy Information Administration (EIA); US Department of Energy. The report presents comprehensive information on electric power industry demand-side management (DSM) activities in the US at the national, regional, and utility levels. The objective of the publication is to provide industry decision makers, government policy makers, analysts, and the general public with historical data that may be used in understanding DSM as it relates to the US electric power industry. The first chapter, ''Profile: US Electric Utility Demand-Side Management'', presents a general discussion of DSM, its history, current issues, and a review of key statistics for the year. Subsequent chapters present discussions and more detailed data on energy savings, peak load reductions and costs attributable to DSM. 9 figs., 24 tabs

Transmission pricing and stranded costs in the electric power industry

International Nuclear Information System (INIS)

Baumol, W.J.; Sidak, J.G.

1995-09-01

Stranded costs are those costs that electric utilities are currently permitted to recover through their rates but whose recovery may be impeded or prevented by the advent of competition in the industry. Estimates of these costs run from the tens to the hundreds of billions of dollars. Should regulators permit utilities to recover stranded costs while they take steps to promote competition in the electric power industry. William Baumol and J. Gregory Sidak argue that answer to that question should be yes.The authors show that a transmission price, the price for sending electricity over the transmission grid, can be determined in a manner that is compatible with economic efficiency and clearly neutral in its effects upon all competitors in electricity generation. A correctly constructed regime of transmission pricing may in fact achieve the efficiency and equity goals that justify the recovery of stranded costs

Review of inter-utility trade in electricity

International Nuclear Information System (INIS)

1994-01-01

In 1992, Canada's National Energy Board released two discussion papers on inter-utility trade. Responses to the papers were received from utilities, government agencies, and other interested parties with regard to questions concerning measures that could be taken to enhance interprovincial trade in electricity and to enable buyers and sellers of electricity to obtain commercial access to available transmission capacity through intermediate provinces for wheeling purposes. The Board's review had estimated long-term net benefits from enhanced inter-utility cooperation at $23-32.5 billion by the year 2000 from such types of transactions as seasonal diversity exchanges and long-term firm sales. Seven types of options to achieve enhanced inter-utility trade were identified. Most of the respondent utilities and provinces that have direct access to external markets tended to prefer the status quo, opposing mandated solutions but supporting (or at least not opposing) federal monitoring of progress on enhanced inter-utility cooperation. Provinces and utilities without direct access to external markets tended to support (as a last resort) mandated solutions to disputes concerning electricity trade. Since the Board review, important events in the North American electricity supply industry have occurred; these are described, focusing on the US Energy Policy Act that gives powers to order transmission access. The formation by US utilities of regional transmission groups (RTGs) with federal encouragement is discussed, along with the implications for Canadian utilities that may want to become members of particular RTGs. The advantages and drawbacks of selecting the various options for enhancing inter-utility trade are then summarized. 1 tab

Analysis on the cost performance and its impact to Japanese electric utilities and vision of the power portfolio

International Nuclear Information System (INIS)

Yamaguchi, Yuji; Matsuo, Yuji; Murakami, Tomoko

2013-01-01

Most of the nuclear power plants in Japan have been shut down since the Fukushima accident in March 2011, without being permitted to restart after periodical inspections. Accordingly, thermal power generation significantly increased in FY 2011. In this paper the authors made a quantitative analysis on the unit costs of power generation and on the financial performance based on the financial reports of electric utilities. The average unit cost in FY 2011 rose to 11.6 JPY/kWh, 3 JPY/kWh higher than that in FY 2010, and will rise further to 12.6 JPY/kWh in FY 2012. The total retained profit of 8 utilities decreased by some 1 trillion JPY from FY 2010 to FY 2011 and will decrease further to 1 trillion JPY by the end of FY 2012, which is the lowest level in history. Clear decisions on energy policies and future power portfolio, as well as the restructuring of the electricity system in line with the rapid change in the power portfolio will be highly required for policy planners in Japan. (author)

Electrical equipment distributors assuming greater role as suppliers to electric utilities

International Nuclear Information System (INIS)

Anon.

1990-01-01

A survey was conducted of Canada's largest distributors of electrical equipment to the utility market. Summaries are presented of the views of the major respondents concerning market trends and future challenges. Distributors have emerged as a supply source to utilities over the past two decades. Before then, electric utilities did virtually all their business directly with the manufacturers and rarely with distributors. One reason for this situation was that direct dealing with manufacturers was perceived by the utilites as providing better access to technical advice. Distributors have grown significantly since then and many have their own expert technical staff and provide full support for their products. Various advantages for utilities in dealing with distributors are noted: ability to supply most needs relatively rapidly from stock, simplification of ordering, improved inventory management, and savings in brokerage and other costs associated with imported equipment

Economical electricity supply and utilization

Energy Technology Data Exchange (ETDEWEB)

Madsen, K

1980-05-01

During the first oil crisis in 1973, hundreds of millions of D-marks have been wasted by medium-sized businesses in the FRG due to avoidable losses and increased electricity costs. Serious attempts towards excluding such losses have to be initiated by an analysis of the individual technical conditions of an enterprise and by consultations 'on site'. Problems relating to an economical electricity supply and utilization in medium-sized industrial enterprises are discussed in this article from the point of view of an industrial consultant being an expert in this field. Practical examples are also given.

12 CFR 360.1 - Least-cost resolution.

Science.gov (United States)

2010-01-01

... 12 Banks and Banking 4 2010-01-01 2010-01-01 false Least-cost resolution. 360.1 Section 360.1 Banks and Banking FEDERAL DEPOSIT INSURANCE CORPORATION REGULATIONS AND STATEMENTS OF GENERAL POLICY RESOLUTION AND RECEIVERSHIP RULES § 360.1 Least-cost resolution. (a) General rule. Except as provided in...

Challenges in sensor development for the electric utility industry

Science.gov (United States)

Ward, Barry H.

1999-01-01

The electric utility industry is reducing operating costs in order to prepare for deregulation. The reduction in operating cost has meant a reduction in manpower. The ability to utilize remaining maintenance staff more effectively and to stay competitive in a deregulated environment has therefore become critical. In recent years, the industry has moved away from routine or periodic maintenance to predictive or condition based maintenance. This requires the assessment of equipment condition by frequent testing and inspection; a requirement that is incompatible with cost reduction. To overcome this dilemma, industry trends are toward condition monitoring, whereby the health of apparatus is monitored continuously. This requires the installation of sensors hr transducers on power equipment and the data taken forwarded to an intelligent device for further processing. These devices then analyze the data and make evaluations based on parameter levels or trends, in an attempt to predict possible deterioration. This continuous monitoring allows the electric utility to schedule maintenance on an as needed basis. The industry has been faced with many challenges in sensor design. The measurement of physical, chemical and electrical parameters under extreme conditions of electric fields, magnetic fields, temperature, corrosion, etc. is extensive. This paper will give an overview of these challenges and the solutions adopted for apparatus such as power transformers, circuit breakers, boilers, cables, batteries, and rotating machinery.

Determining the Cost of Capital for Turkish Electricity Distribution Utilities: Analysis and Recommendations

OpenAIRE

Gözen, Mustafa

2012-01-01

Turkey has been transforming her electricity market to a competitive one since the electricity market law was approved by the parliament in 2001. As part of the new regime, electricity distribution activities are subject to incentive-based regulation by the energy regulator - EMRA. At the beginning of each implementation period, initial revenue is allowed by EMRA for a distribution utility in which a rate of return for investments in the utility is added. Setting a fair rate is relatively eas...

Financial impact of energy efficiency under a federal combined efficiency and renewable electricity standard: Case study of a Kansas 'super-utility'

International Nuclear Information System (INIS)

Cappers, Peter; Goldman, Charles

2010-01-01

Historically, local, state and federal policies have separately promoted the generation of electricity from renewable technologies and the pursuit of energy efficiency to help mitigate the detrimental effects of global climate change and foster energy independence. Federal policymakers are currently considering and several states have enacted a combined efficiency and renewable electricity standard which proponents argue provides a comprehensive approach with greater flexibility and at lower cost. We examine the financial impacts on various stakeholders from alternative compliance strategies with a Combined Efficiency and Renewable Electricity Standard (CERES) using a case study approach for utilities in Kansas. Our results suggest that an investor-owned utility is likely to pursue the most lucrative compliance strategy for its shareholders-one that under-invests in energy efficiency resources. If a business model for energy efficiency inclusive of both a lost fixed cost recovery mechanism and a shareholder incentive mechanism is implemented, our analysis indicates that an investor-owned utility would be more willing to pursue energy efficiency as a lower-cost CERES compliance strategy. Absent implementing such a regulatory mechanism, separate energy efficiency and renewable portfolio standards would improve the likelihood of reducing reliance on fossil fuels at least-cost through the increased pursuit of energy efficiency.

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

Energy Technology Data Exchange (ETDEWEB)

1980-05-01

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.

Abatement cost of GHG emissions for wood-based electricity and ethanol at production and consumption levels.

Directory of Open Access Journals (Sweden)

Puneet Dwivedi

Full Text Available Woody feedstocks will play a critical role in meeting the demand for biomass-based energy products in the US. We developed an integrated model using comparable system boundaries and common set of assumptions to ascertain unit cost and greenhouse gas (GHG intensity of electricity and ethanol derived from slash pine (Pinus elliottii at the production and consumption levels by considering existing automobile technologies. We also calculated abatement cost of greenhouse gas (GHG emissions with respect to comparable energy products derived from fossil fuels. The production cost of electricity derived using wood chips was at least cheaper by 1 ¢ MJ-1 over electricity derived from wood pellets. The production cost of ethanol without any income from cogenerated electricity was costlier by about 0.7 ¢ MJ-1 than ethanol with income from cogenerated electricity. The production cost of electricity derived from wood chips was cheaper by at least 0.7 ¢ MJ-1 than the energy equivalent cost of ethanol produced in presence of cogenerated electricity. The cost of using ethanol as a fuel in a flex-fuel vehicle was at least higher by 6 ¢ km-1 than a comparable electric vehicle. The GHG intensity of per km distance traveled in a flex-fuel vehicle was greater or lower than an electric vehicle running on electricity derived from wood chips depending on presence and absence of GHG credits related with co-generated electricity. A carbon tax of at least $7 Mg CO2e-1 and $30 Mg CO2e-1 is needed to promote wood-based electricity and ethanol production in the US, respectively. The range of abatement cost of GHG emissions is significantly dependent on the harvest age and selected baseline especially for electricity generation.

Electric-utility DSM programs in a competitive market

Energy Technology Data Exchange (ETDEWEB)

Hirst, E.

1994-04-01

During the past few years, the costs and effects of utility demand-side management (DSM) programs have grown sharply. In 1989, US electric utilities spent 0.5% of revenues on such programs and cut total electricity consumption by 0.6%. By 1992, these numbers had increased to 1.3% and 1.2%, respectively. Utility projections, as of early 1993, of DSM expenditures and energy savings for 1997 were 1.7% and 2.5%, respectively. Whether this projected growth comes to pass may depend on current debates about deregulation of, and increased competition in, the electric-utility industry. This report examines the factors likely to affect utility DSM programs in a more competitive environment. The electric-utility industry faces two forces that may conflict with each other. One is the pressure to open up both wholesale and retail markets for competition. The net effect of such competition, especially at the retail level, would have much greater emphasis on electricity prices and less emphasis on energy services. Such an outcome would force a sharp reduction in the scale of DSM programs that are funded by customers in general. The second force is increased concern about environmental quality and global warming. Because utilities are major contributors to US carbon dioxide emissions, the Administration`s Climate Change Action Plan calls on utilities to reduce such emissions. DSM programs are one key way to do that and, in the process, to cut customer electric bills and improve economic productivity. This report discusses the forms of competition and how they might affect DSM programs. It examines the important roles that state regulatory commissions could play to affect retail competition and utility DSM programs. The report also considers the effects of DSM programs on retail electricity prices.

Modelling the impact of EVs on electricity generation, costs and CO2 emissions

International Nuclear Information System (INIS)

Calnan, P.; Deane, J.P.; Ó Gallachóir, B.P.

2013-01-01

This paper focuses on the impact of electric vehicles on electricity generation in Ireland in 2025 based on five alternative generation portfolios. The year 2025 was selected for assessment due to the information on the composition of the five generation portfolios from Eirgrid the system operator in Ireland being provided. Detailed market simulations were undertaken on the five possible generation portfolios to assess the impact of the Government targets for electric vehicles on the generation costs, emissions, generation stack and the cost to load of this additional demand. This paper also studied the impact between a standard and least cost electric vehicle loading regime to ascertain the benefits that could be achieved. The results show that gas will be the dominant source of electricity generation to load electric vehicles and that wind as an electricity source will experience a minor reduction in curtailment, with the least cost charging profile showing a more pronounced reduction. The capital benefits of the Standard and Least Cost EV load are found to be negligible. The portfolios studied generated CO 2 emissions per kilometre between 52 and 70 gCO 2 /km. All portfolios with the exception of coal were found to comply with EU regulation 443/2009. - Highlights: • This paper focuses on the impact of electric vehicles on electricity generation in Ireland in 2025. • It uses the PLEXOS software package by Energy Exemplar to model the Irish electricity market. • Government targets for electric vehicle penetration have a limited impact on the power system. • Electric vehicles will meet EU requirements in terms of emissions created per kilometre

Turmoil and transition: Electric utility industry trends

International Nuclear Information System (INIS)

1994-06-01

In a review of electric utility industry trends, focusing on North America, it is noted that four critical influences are dominant: competition in the electricity supply business; technological advances; the recognized need for environmental protection; and a favoring of market economics and customer choice. As energy costs rose in the 1970s and 1980s, electricity usage growth rates decreased and demand side management became an accepted alternative to building new power plants. In large areas of Canada and the USA, substantial surplus generation capacity arose, transmission linkages improved, and regional electricity markets developed. Privatization measures in the British electric sector were closely studied in North America and electric markets in the USA were pushed toward more competition with the 1992 Energy Policy Act. Non-utility generators have entered the market, including industrial companies, pipeline companies, independent renewable-energy providers, and power companies set up by the utilities themselves. Power pools may evolve into regional transmission grids in which the transmission owning utilities would exchange their lines for an interest in the grid. California is likely to lead in opening access to transmission on a regional scale. Distribution systems are likely to remain a regulated monopoly as before. Substantial change is expected in customer services as functions such as power purchase and conservation are being performed by independent companies. Other possible developments in the industry include emissions trading and spot markets for power. The implications of these trends for British Columbia Hydro are discussed

18 CFR 141.100 - Original cost statement of utility property.

Science.gov (United States)

2010-04-01

... 18 Conservation of Power and Water Resources 1 2010-04-01 2010-04-01 false Original cost statement... POLICIES ACT OF 1978 STATEMENTS AND REPORTS (SCHEDULES) § 141.100 Original cost statement of utility... predecessors of an electric operating unit or system, the original cost, estimated, if not known, the cost of...

Calculating the marginal costs of a district-heating utility

International Nuclear Information System (INIS)

Sjoedin, Joergen; Henning, Dag

2004-01-01

District heating plays an important role in the Swedish heat-market. At the same time, the price of district heating varies considerably among different district-heating utilities. A case study is performed here in which a Swedish utility is analysed using three different methods for calculating the marginal costs of heat supply: a manual spreadsheet method, an optimising linear-programming model, and a least-cost dispatch simulation model. Calculated marginal-costs, obtained with the three methods, turn out to be similar. The calculated marginal-costs are also compared to the actual heat tariff in use by the utility. Using prices based on marginal costs should be able to bring about an efficient resource-allocation. It is found that the fixed rate the utility uses today should be replaced by a time-of-use rate, which would give a more accurate signal for customers to change their heat consumptions. (Author)

Reference costs of the electric power production

International Nuclear Information System (INIS)

2003-06-01

This study periodically realized by the DGEMP aims to compare the competitiveness of the different channels of electric power production, for different utilization conditions. The first part ''reference costs of the 2003 electric power production'' examines the prices of the electric power produced by different channels in particular in the framework of the industrial implementing in 2015. The nuclear and thermal power plants are concerned. The second part is devoted to the decentralized production channels (wind energy, photovoltaic, cogeneration heat-electricity) is under construction and will be presented next year. (A.L.B.)

Waste utilization in electric energy industry

International Nuclear Information System (INIS)

Parate, N.S.; Harris, E.

1991-01-01

This paper reports that electric energy is an integral element of today's economy and the standard quality of life. The availability of energy at an affordable cost has always been of basic concern because of the intimate relationship of energy to our societal development and progress. Coal and Uranium are the primary alternative energy sources for large electric power plants. Coal remains the dominant fuel for electric generation. The pressurized fluidized bed combustion technology has the potential of utilizing all types of coal, including coal with high ash, high sulphur, and high moisture content. Fluidized bed combustion is a firing technique which fulfills today's pollution control requirements without downstream flue gas cleaning plants like scrubbers, baghouses, and precipitators

Trends in Japan's power generation costs after the Fukushima Daiichi Nuclear Power Plant accident and their influence on finance of electric utilities

International Nuclear Information System (INIS)

Matsuo, Yuhji; Yamaguchi, Yuhji; Murakami, Tomoko

2013-01-01

Following the Fukushima Daiichi nuclear power plant accident, the nuclear reactors that were suspended for periodic inspections after the Fukushima accident were not permitted to resume operation, and nuclear power generation in Japan continued to decline. In this article, the authors quantitatively evaluated the effects on power generation costs of Japan's situation, using electric utilities financial reports up to FY 2011. We also analyzed the profitability of the Japanese electric industry, using the financial statements included in the reports, and quantitatively evaluated the effects of changes in power generation costs. The total cost of power generation has increased from 7.5 trillion yen in FY 2010 before the Fukushima accident to 9.6 trillion yen in FY 2011 and to 10.6 trillion yen in FY 2012. In particular, the fuel cost for thermal power generation rose sharply from 3.7 trillion yen in FY 2010 to 6.1 trillion yen in FY 2011 and 7.3 trillion yen in FY 2012, almost doubling in the two years from FY 2010 to 2012. The unit cost of power generation rose sharply from 8.6 yen/kWh in FY 2010 to 11.8 yen/kWh in FY 2011 and 13.5 yen/kWh in FY 2012. The unit cost is expected to rise even further in FY 2013 due to the weak yen. As the result not only Tokyo Electric Power Company, but also the other general electric utilities registered huge net losses. Their retained earnings (total of eight utilities) dropped by 2 trillion yen between FY 2010 and 2012. With increased thermal power generation, the risk of rising costs associated with changes in primary energy prices and exchange rates has increased drastically. For the stability of the electricity industry and the development of the Japanese economy, the government should clearly formulate a basic policy regarding the composition of power sources, and an effective plan both at home and abroad, and should develop a system that will be also to handle sudden changes in the composition of power sources. (author)

International perspectives on the importance of electric tariff transitioning to cost-based levels in Bulgaria

International Nuclear Information System (INIS)

Simpson, T.; Davis, F.; Dilovska, I.

1996-01-01

The traditional cost-of-service approach to power pricing has been replaced in many countries by market pricing mechanisms that compensate power producers at the marginal cost of production established collectively in the marketplace. The paper stresses the importance of cost-based tariff setting pointing out two main pricing principles of utility services: 1) Revenues must meet or exceed the utility average cost of production; 2) Marginal cost pricing for incremental consumption must ensure efficient allocation of resources. Examples describing the factors encouraging transition to economically efficient tariffs at a small utility are given for: Northwest U.S., MINENERGO in Belarus, Pacific Gas and Electric Co in California and the National Electric Co (NEK) in Bulgaria.The analysis of the Bulgarian electric sector is based on ongoing work being funded by the U.S. Agency for International Development. Each of the four utilities described faces a different challenge for transitioning tariffs to cost- based levels. However, one and the same broad conclusion applies in all cases: utility pricing must take into account the underlying average and marginal cost structures of the regional power industry. Bulgaria needs transition to cost-based tariffs to recover the electricity cost-of-service and to ensure that the electric sector operates efficiently and consumers are treated fairly. Measures that facilitate the process of tariff transitioning include: 1) Developing a transparent process of tariff setting with clear objectives, a plan and timetable, and roles of organizations; 2) Establishing of independent regulation to ensure that tariff setting objectives are achieved; 3) Instituting mechanisms to reward organizations for performance that achieves electric sector objectives. 3 figs

Competition in the electric utility sector?

International Nuclear Information System (INIS)

Olsen, O.J.; Fristrup, P.; Munksgaard, J.; Skytte, K.

2000-01-01

The book analyses some important problems for the liberaliaction of the electricity market in Denmark and its neighbouring countries. Will the competition and its potential for a more cost-effective electric supply be prevented by the electric companies' many possibilities to utilize market power? Can competition be combined with ambitious energy policy aims about reducing the environmental impacts of the electric supply? Does the Danish tradition for consumer ownership constitute an important supplement to the protection of the smaller consumers in a world of international competition? The intention with the book is not to take concrete position to the many topical problems in the Danish political discussion of restructurns of the electric sector, but to give a theoretical analysis to understand and analyse the development. On this basis the conclusion is, that the competition will work even in combination with ambitious environmental aims. (EHS)

Thermal burn and electrical injuries among electric utility workers, 1995-2004.

Science.gov (United States)

Fordyce, Tiffani A; Kelsh, Michael; Lu, Elizabeth T; Sahl, Jack D; Yager, Janice W

2007-03-01

This study describes the occurrence of work-related injuries from thermal-, electrical- and chemical-burns among electric utility workers. We describe injury trends by occupation, body part injured, age, sex, and circumstances surrounding the injury. This analysis includes all thermal, electric, and chemical injuries included in the Electric Power Research Institute (EPRI) Occupational Health and Safety Database (OHSD). There were a total of 872 thermal burn and electric shock injuries representing 3.7% of all injuries, but accounting for nearly 13% of all medical claim costs, second only to the medical costs associated with sprain- and strain-related injuries (38% of all injuries). The majority of burns involved less than 1 day off of work. The head, hands, and other upper extremities were the body parts most frequently injured by burns or electric shocks. For this industry, electric-related burns accounted for the largest percentage of burn injuries, 399 injuries (45.8%), followed by thermal/heat burns, 345 injuries (39.6%), and chemical burns, 51 injuries (5.8%). These injuries also represented a disproportionate number of fatalities; of the 24 deaths recorded in the database, contact with electric current or with temperature extremes was the source of seven of the fatalities. High-risk occupations included welders, line workers, electricians, meter readers, mechanics, maintenance workers, and plant and equipment operators.

Planning uncertainties, market risks and new environmental choices: Winning least cost planning combinations

International Nuclear Information System (INIS)

Violette, D.; Lang, C.

1990-01-01

Utility demand and supply-side planners will face new challenges from environmental regulations. Under current proposals, every ton of pollutant will have a cost to utilities, not just the tons that put them over the allowable limit. Planners will have to account for these new costs. To do this, planners need to start tracking emissions implementation actions today, and begin strategies for future regulatory changes. Current legislative proposals include a tax on the carbon content of fuels to curb emissions of greenhouse gases and substantial reductions in sulfur dioxide and nitrogen oxide emissions. The important issue for planners is the flexible compliance requirements within these regulatory changes. The acid rain proposals, for example, include a market-based emissions trading system for emissions allowances. Whenever there is a competitive market, there are market risks, and potential winners and losers. Utilities need to be prepared to analyze and mitigate these risks. Integrated least cost planing is one way a utility will have to meet this challenge. Planning involves uncertainty and risk. The wide array of compliance choices create countless combinations of strategies for utilities to comply with the new emissions regulations. This paper discusses new compliance strategies, demand-side management (DSM) as a compliance strategy, solutions to DSM traps, and the compliance strategy game

Electric utility load management: rational use of energy program pilot study

Energy Technology Data Exchange (ETDEWEB)

1977-08-01

In recognition of the role that load management can play in ensuring that the growing demand for electricity is met in a cost- and energy-efficient manner, in mid-1974, the NATO Committee on the Challenges of Modern Society sponsored all three meetings to provide a forum for representatives of U.S. and European utilities to exchange views and experiences on the various aspects of load management. It was the consensus of representatives at the meetings that three overall approaches offer significant opportunities for achieving improved load management: development of marginal-cost rate structures; power pooling and energy storage by utilities; and efforts by consumers. Industrial consumers can assist electric utilities in their efforts to level system loads through three important methods: interruptible power and deferred load control; peak self-generation; and shifts in operating schedules. Residential/commercial consumers also have an important role to play by managing both their electric heating load (through the interruption of direct-resistance heating and the storage of heat) and their air conditioning load. In response to the interest expressed by the participants in the CCMS conferences, the U.S. and several European governments, national electric utility industry organizations, state public utility commissions, and many individual utilities have undertaken R and D projects to investigate and test various aspects of these three approaches to load management. This report describes the projects that were presented by the utility representatives.

Cost functions and the electric utility industry. A contribution to the debate on deregulation

International Nuclear Information System (INIS)

Ramos-Real, F.J.

2005-01-01

This study analyses the main articles that estimate cost functions in the electricity utility industry with a view to studying of the initial arguments for proposing competition and vertical disintegration. The works reviewed here, in general terms, confirm the initial arguments in favour of the deregulation process, mainly, the exhaustion of scale economies for moderate size firms in generation and the condition of natural monopoly for transmission and distribution. However, the savings obtained from undertaking different activities together should be kept in mind when restructuring the sector. On the other hand, the improvements in productivity deriving from the reforms have not translated into reductions in the price of electricity in many countries. These last two results suggest the need for appropriate market regulation for the deregulation process to translate into an improvement in how the sector works and into benefits for consumers. There is still insufficient empirical literature on these issues due to the fact that the process is still ongoing in many countries and more time will have to transpire before sufficient data is available

Privatization of municipal electrical utilities

International Nuclear Information System (INIS)

Carr, J.

1998-01-01

The challenges and special issues which arise through the sale of a municipal electric utility were discussed. The recent sales of two utilities, the Kentville Electric Commission in Nova Scotia and Cornwall Electric in Ontario, were used as examples to show how the sale of an electric utility differs from the sale of most business enterprises. Municipal utilities are integral parts of the communities they serve which introduces several complexities into the sale. Factors that require special attention in the sale of the utilities, including electricity rates, local accountability, treatment of employees and local economic development, and the need for a comprehensive communication program to deal with the substantial public interest that sale of a municipal utility will engender, were reviewed

Value-Added Electricity Services: New Roles for Utilities and Third-Party Providers

Energy Technology Data Exchange (ETDEWEB)

Blansfield, J. [Inst. for Electric Innovations, Washington, DC (United States); Wood, L. [Inst. for Electric Innovations, Washington, DC (United States); Katofsky, R. [Advanced Energy Economy, Washington, DC (United States); Stafford, B. [Advanced Energy Economy, Washington, DC (United States); Waggoner, D. [Advanced Energy Economy, Washington, DC (United States); Schwartz, L. C. [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States)

2017-10-30

New energy generation, storage, delivery, and end-use technologies support a broad range of value-added electricity services for retail electricity customers. Sophisticated energy management services, distributed generation coupled with storage, and electric vehicle charging are just a few examples of emerging offerings. Who should provide value-added services — utilities or third parties, or both, and under what conditions? What policy and regulatory changes may be needed to promote competition and innovation, to account for utility costs to enable these services, and to protect consumers? The report approaches the issues from three perspectives: utilities, third-party service providers, and consumers: -Jonathan Blansfield and Lisa Wood, Institute for Electric Innovation -Ryan Katofsky, Benjamin Stafford and Danny Waggoner, Advanced Energy Economy -National Association of State Utility Consumer Advocates

Management of busbar costs and spending tradeoffs for the transition to competitive markets in electricity

Energy Technology Data Exchange (ETDEWEB)

Corio, M.R.; Boyd, G. [Applied Economic Research Co., Inc., New York, NY (United States)

1995-09-01

Competition is changing the fundamental basis for doing business in the electricity generation market. As the market moves toward competitive market conditions, electricity will be viewed increasingly as a commodity--not only supplied to customers within a utility`s service area, but brokered and marketed outside its area as well. With movement toward retail wheeling being considered in California, Michigan, and New York, it may soon become a reality as well. This means that a utility can no longer feel secure as the monopoly supplier of electricity within its own franchise area. To remain the main supplier in its current service area and compete for customers in other service areas, utilities will need to understand and examine all the components of ``busbar costs`` at its generating units. As competition drives the market to marginal costs, generating units with costs exceeding the market clearing price for electricity may soon have a limited role in the generation market. As the industry evolves, competition in the marketplace will force uneconomic plants to reduce costs or go out of business. This paper discusses results of studies addressing the evaluation of cost effectiveness, benchmarking of cost-efficiency, and development of marginal cost curves for busbar costs based on the development and aggregation of the three key measures which determine the cost and level of output (generation): (1) reliability; (2) heat rate; and (3) planned outage factor.

Positioning the electric utility to build information infrastructure

Energy Technology Data Exchange (ETDEWEB)

1994-11-01

In two particular respects (briefly investigated in this study from a lawyer`s perspective), electric utilities appear uniquely well-positioned to contribute to the National Information Infrastructure (NII). First of all, utilities have legal powers derived from their charters and operating authorities, confirmed in their rights-of-way, to carry out activities and functions necessary for delivering electric service. These activities and functions include building telecommunications facilities and undertaking information services that have become essential to managing electricity demand and supply. The economic value of the efficiencies made possible by telecommunications and information could be substantial. How great remains to be established, but by many estimates electric utility applications could fund a significant share of the capital costs of building the NII. Though utilities` legal powers to pursue such efficiencies through telecommunications and information appear beyond dispute, it is likely that the effort to do so will produce substantial excess capacity. Who will benefit from this excess capacity is a potentially contentious political question that demands early resolution. Will this windfall go to the utility, the customer, or no one (because of political paralysis), or will there be some equitable and practical split? A second aspect of inquiry here points to another contemporary issue of very great societal importance that could very well become the platform on which the first question can be resolved fortuitously-how to achieve universal telecommunications service. In the effort to fashion the NII that will now continue, ways and means to maximize the unique potential contribution of electric utilities to meeting important social and economic needs--in particular, universal service--merit priority attention.

Efficiency-bonds as a means to competitive least-cost solutions

International Nuclear Information System (INIS)

Nilsson, Hans; Rode, Hans.

1992-01-01

The new view on the energy system is that it delivers energy service to end-users instead of only energy. The new view calls for least-cost solutions with regard also to the use of energy-efficient equipment. These solutions are, however, not realized automatically on the market since this is arranged for delivery of energy instead of energy service. There is a need to invent new ways to organize the market. This could be done with new sets of incentives for the traditional actors, mainly the utilities. A stock-market solution seems to have such qualities. (author)

Electricity prices in a competitive environment: Marginal cost pricing of generation services and financial status of electric utilities. A preliminary analysis through 2015

International Nuclear Information System (INIS)

1997-08-01

The emergence of competitive markets for electricity generation services is changing the way that electricity is and will be priced in the United States. This report presents the results of an analysis that focuses on two questions: (1) How are prices for competitive generation services likely to differ from regulated prices if competitive prices are based on marginal costs rather than regulated open-quotes cost-of-serviceclose quotes pricing? (2) What impacts will the competitive pricing of generation services (based on marginal costs) have on electricity consumption patterns, production costs, and the financial integrity patterns, production costs, and the financial integrity of electricity suppliers? This study is not intended to be a cost-benefit analysis of wholesale or retail competition, nor does this report include an analysis of the macroeconomic impacts of competitive electricity prices

Rent dissipation through electricity prices of publicly owned utilities

International Nuclear Information System (INIS)

Bernard, J-T.; Roland, M.

1997-01-01

Pricing policies of Canadian public utilities were examined. It was shown that under the existing set of rules the prices established are frequently below the marginal cost. This appears to be particularly true in the case of provinces that rely principally on hydroelectric resources. Study recommendations to bring electricity prices in line with marginal costs have had little success to date despite overwhelming evidence of large economic losses associated with the current institutional arrangements. This situation remains at the same time that governments apply high tax rates on incomes. By putting together two strands of economic literature, public choice and the theory of public utility pricing, this paper develops a simple model that explains why the median consumer prefers a low electricity price and a high tax rate. Hydro-Quebec survey data is used to confirm that these conditions are satisfied in Quebec. 17 refs., 1 tab

How to develop a world class electrical utility for the free markets of electrical energy?

International Nuclear Information System (INIS)

Aaltonen, J.E.; Takala, J.A.

1995-01-01

The electricity distribution in Finland is going to the new stage where the electrical energy market will be gradually free from competition. The purpose of this study is to analyze the concept of the world class utility. A feasibility study was made to research the condition in logistics and suitable methods for the implementation. Some ideas have been piloted to verify and find acceptable approaches of the implementation to practice. Utilities improved the cost efficiency and strategical business logistics in a customer oriented and flexible way. The methods and findings can be used on other public and industrial areas, too

Electricity prices in a competitive environment: Marginal cost pricing of generation services and financial status of electric utilities. A preliminary analysis through 2015

Energy Technology Data Exchange (ETDEWEB)

NONE

1997-08-01

The emergence of competitive markets for electricity generation services is changing the way that electricity is and will be priced in the United States. This report presents the results of an analysis that focuses on two questions: (1) How are prices for competitive generation services likely to differ from regulated prices if competitive prices are based on marginal costs rather than regulated {open_quotes}cost-of-service{close_quotes} pricing? (2) What impacts will the competitive pricing of generation services (based on marginal costs) have on electricity consumption patterns, production costs, and the financial integrity patterns, production costs, and the financial integrity of electricity suppliers? This study is not intended to be a cost-benefit analysis of wholesale or retail competition, nor does this report include an analysis of the macroeconomic impacts of competitive electricity prices.

R and D options for demand side management in Japanese electric utilities

International Nuclear Information System (INIS)

Yamamoto, Takahiko

1996-01-01

Japanese electric demand has been steadily increasing in accordance with the economic growth. However, Japanese electric utilities are facing several problems; increasing construction cost of power facilities, siting constraints and the environmental issue of greenhouse gas emissions. To overcome these problems, electric utilities have been promoting demand-side-management (DSM) activities as well as supplier-side measures, with some presently being carried out through promoting energy conservation technologies and introducing electric tariff options of specific contracts for residential/commercial and industrial consumers. Japanese electric utilities have been carrying out R and D for the future, in particular, energy storage and heat storage which contribute to the improvement of load factor. In this paper, I would like to outline the R and D options for DSM in Japan. (author)

IRP methods for Environmental Impact Statements of utility expansion plans

International Nuclear Information System (INIS)

Cavallo, J.D.; Hemphill, R.C.; Veselka, T.D.

1992-01-01

Most large electric utilities and a growing number of gas utilities in the United States are using a planning method -- Integrated Resource Planning (IRP) - which incorporates demand-side management (DSM) programs whenever the marginal cost of the DSM programs are lower than the marginal cost of supply-side expansion options. Argonne National Laboratory has applied the IRP method in its socio-economic analysis of an Environmental Impact Statement (EIS) of power marketing for a system of electric utilities in the mountain and western regions of the United States. Applying the IRP methods provides valuable information to the participants in an EIS process involving capacity expansion of an electric or gas utility. The major challenges of applying the IRP method within an EIS are the time consuming and costly task of developing a least cost expansion path for each altemative, the detailed quantification of environmental damages associated with capacity expansion, and the explicit inclusion of societal-impacts to the region

International comparison of electricity generating costs

International Nuclear Information System (INIS)

Jones, P.M.S.; Stevens, G.H.; Wigley, K.

1989-01-01

The paper reviews the principal findings of successive studies of projected comparative generation costs for base-load electricity production conducted by Nuclear Energy Agency working groups, including a current study jointly sponsored by the International Energy Agency. It concludes that over the six years 1983-1989 nuclear generation costs have remained steady or slightly declined in the majority of OECD countries. This represents an excellent result in view of the difficulties that have arisen in many countries during the period. Nuclear power is projected to maintain a significant advantage in most OECD countries on an assessment basis reflecting utility experience and discount rates employed by the majority of participants. However, nuclear's projected advantage has declined due to a significant fall in projected coal prices which have decreased by 50% since 1983. This decline is only slightly offset by increased capital and operating costs for coal-fired plant. If rates of return sought by utilities were higher or if coal prices prove lower than utilities project then the economic balance between nuclear and coal-fired power would be further reduced and could in some instances be reversed. To improve on its competitiveness nuclear power will have to continue to control capital costs through replication and reduced construction schedules and to improve plant availability to maximise output

Economies of scale and vertical integration in the investor-owed electric utility industry

International Nuclear Information System (INIS)

Thompson, H.G.; Islam, M.; Rose, K.

1996-01-01

This report analyzes the nature of costs in a vertically integrated electric utility. Findings provide new insights into the operations of the vertically integrated electric utility and supports earlier research on economics of scale and density; results also provide insights for policy makers dealing with electric industry restructuring issues such as competitive structure and mergers. Overall, results indicate that for most firms in the industry, average costs would not be reduced through expansion of generation, numbers of customers, or the delivery system. Evidently, the combination of benefits from large-scale technologies, managerial experience, coordination, or load diversity have been exhausted by the larger firms in the industry; however many firms would benefit from reducing their generation-to-sales ratio and by increasing sales to their existing customer base. Three cost models were used in the analysis

Data warehousing for electric utilities; Data Warehousing fuer Stromerzeuger im Strommarkt

Energy Technology Data Exchange (ETDEWEB)

Rappenecker, G.; Wolff, G.; Gross, P.

2000-07-01

Deregulation of the electricity market has changed the business processes of electric utilities profoundly. The paradigm of availability was replaced by economic efficiency. Four requirements are decisive: Implementation of unbundling as required by law - cost reduction to enhance competitive strength - marketing of the utilities' own products - positioning in the new electricity market. [German] Die Deregulierung des Strommarktes hat die Geschaeftsprozesse der Stromerzeuger grundlegend gewandelt. Das Paradigma der Versorgungssicherheit wurde ersetzt durch das der Wirtschaftlichkeit. Die Veraenderung der Geschaeftsprozesse der Stromerzeuger sind massiv gepraegt von vier Anforderungen: - Umsetzung des gesetzlich vorgeschriebenen 'Unbundling' - Erhalt der Konkurrenzfaehigkeit durch Kostensenkung - Vermarktung der eigenen Produkte - Positionierung im neu entstehenden Strommarkt. (orig.)

Management of busbar costs and spending tradeoffs for the transition to competitive markets in electricity

International Nuclear Information System (INIS)

Corio, M.R.; Boyd, G.

1995-01-01

Competition is changing the fundamental basis for doing business in the electricity generation market. As the market moves toward competitive market conditions, electricity will be viewed increasingly as a commodity--not only supplied to customers within a utility's service area, but brokered and marketed outside its area as well. With movement toward retail wheeling being considered in California, Michigan, and New York, it may soon become a reality as well. This means that a utility can no longer feel secure as the monopoly supplier of electricity within its own franchise area. To remain the main supplier in its current service area and compete for customers in other service areas, utilities will need to understand and examine all the components of ''busbar costs'' at its generating units. As competition drives the market to marginal costs, generating units with costs exceeding the market clearing price for electricity may soon have a limited role in the generation market. As the industry evolves, competition in the marketplace will force uneconomic plants to reduce costs or go out of business. This paper discusses results of studies addressing the evaluation of cost effectiveness, benchmarking of cost-efficiency, and development of marginal cost curves for busbar costs based on the development and aggregation of the three key measures which determine the cost and level of output (generation): (1) reliability; (2) heat rate; and (3) planned outage factor

Electricity transmission pricing. How contracts must reflect costs

International Nuclear Information System (INIS)

Shuttleworth, G.

1996-01-01

Two basic structures of transmission systems are distinguished: transmission channels offered through an integrated electric utility and open access offered over an independent network. The first structure allows the application of 'top-down pricing', where transmission prices are derived from customer tariffs less avoidable generation costs. Transmission prices in the second structure must be derived from a 'bottom-up' analysis of transmission costs, including building capacity, marginal losses, and congestion. 5 refs

Low-Income Community Solar: Utility Return Considerations for Electric Cooperatives

Energy Technology Data Exchange (ETDEWEB)

Aznar, Alexandra Y [National Renewable Energy Laboratory (NREL), Golden, CO (United States); Gagne, Douglas A [National Renewable Energy Laboratory (NREL), Golden, CO (United States)

2018-04-05

The objective of this short report is to identify project structures that make low-income community solar projects more cost-effective, replicable, and scalable, for electric cooperative and municipal utilities. This report explores the tradeoffs between providing energy bill savings for low-income subscribers and utility project returns, as well as some of the key lessons learned from existing successful low-income community solar pilot projects.

Secured electrical supply at least cost: Coal, gas, nuclear, hydro

Energy Technology Data Exchange (ETDEWEB)

Gavor, J. [ENA Ltd., Prague (Czechoslovakia); Stary, O.; Vasicek, J. [Czech Technical Univ., Prague (Czechoslovakia)

1995-12-01

Electric power sector in East Central European countries finds in a difficult period. In the situation of demand stagnation, enormous investments must be realized in a very short time. Today`s decisions in the development strategy will influence the long term future of the industry. The optimal structure of the sources is one of the most important problem to be solved. Paper describes the current structure of the sources in electric power sector in the Czech Republic. The importance of coal, oil and gas, nuclear and hydro in electric power generation is compared. Taking into account the different position in the load coverage, economy of individual sources is evaluated and basic results of discounted cash flow calculations are presented. Information on specific investment programs and projects are included and further trends are estimated.

The least-cost hydrogen for Southern California

International Nuclear Information System (INIS)

Lin, Zhenhong; Chen, Chien-Wei; Ogden, Joan; Fan, Yueyue

2008-01-01

Optimization is applied to identify the least-cost sequence of hydrogen infrastructure build-up in Southern California during 2010-2060. Given an exogenous demand, the model generates temporal and spatial decisions for building a hydrogen infrastructure, in terms of when, where, at what sizes and by what technologies, that minimize the net present value of technology, environment, and fuel accessibility costs. The least-cost sequence is then analyzed with respect to technology deployment, delivered hydrogen cost, capital requirements, subsidy need, subsidy capacity, and CO 2 mitigation. It is found that industrial hydrogen could play a critical role in initiating hydrogen transition, temporally bridged by onsite SMR to central production dominated at first by biomass gasification and later by coal gasification with carbon dioxide capture and storage (CCS). While a non-discounted capital investment of $24.43 billion is needed for the 50-year build-up, a hydrogen price below 3$/kg could pay back the costs in 20 years earning a 10% IRR. If hydrogen is purchased at the current equivalent gasoline price (2.517 $/gallon), the hydrogen industry could potentially provide $4715 as subsidy for each new FCV purchase. With CCS, 50% of 50-year CO 2 emissions could be avoided. (author)

Least cost analysis of renewable energy projects

International Nuclear Information System (INIS)

Cosgrove-Davies, M.; Cabraal, A.

1994-01-01

This paper describes the methodology for evaluating dispersed and centralized rural energy options on a least cost basis. In defining the load to be served, each supply alternative must provide equivalent levels of service. The village to be served is defined by the number of loads, load density, distance from the nearest power distribution line, and load growth. Appropriate rural energy alternatives are identified and sized to satisfy the defined load. Lastly, a net present value analysis (including capital, installation, O and M, fuel, and replacement costs, etc.) is performed to identify the least cost option. A spreadsheet-based analytical tool developed by the World Bank's Asia Alternative Energy Unit (ASTAE) incorporates this approach and has been applied to compare photovoltaic solar home systems with other rural energy supply options in Indonesia. Load size and load density are found to be the critical factors in choosing between a grid and off-grid solution

An Assessment Model for Energy Efficiency Program Planning in Electric Utilities: Case of the Pacific of Northwest U.S.A

Science.gov (United States)

Iskin, Ibrahim

Energy efficiency stands out with its potential to address a number of challenges that today's electric utilities face, including increasing and changing electricity demand, shrinking operating capacity, and decreasing system reliability and flexibility. Being the least cost and least risky alternative, the share of energy efficiency programs in utilities' energy portfolios has been on the rise since the 1980s, and their increasing importance is expected to continue in the future. Despite holding great promise, the ability to determine and invest in only the most promising program alternatives plays a key role in the successful use of energy efficiency as a utility-wide resource. This issue becomes even more significant considering the availability of a vast number of potential energy efficiency programs, the rapidly changing business environment, and the existence of multiple stakeholders. This dissertation introduces hierarchical decision modeling as the framework for energy efficiency program planning in electric utilities. The model focuses on the assessment of emerging energy efficiency programs and proposes to bridge the gap between technology screening and cost/benefit evaluation practices. This approach is expected to identify emerging technology alternatives which have the highest potential to pass cost/benefit ratio testing procedures and contribute to the effectiveness of decision practices in energy efficiency program planning. The model also incorporates rank order analysis and sensitivity analysis for testing the robustness of results from different stakeholder perspectives and future uncertainties in an attempt to enable more informed decision-making practices. The model was applied to the case of 13 high priority emerging energy efficiency program alternatives identified in the Pacific Northwest, U.S.A. The results of this study reveal that energy savings potential is the most important program management consideration in selecting emerging energy

State Performance-Based Regulation Using Multiyear Rate Plans for U.S. Electric Utilities

Energy Technology Data Exchange (ETDEWEB)

Lowry, Mark Newton [Pacific Economics Group Research LLC (United States); Makos, Matt [Pacific Economics Group Research LLC (United States); Deason, Jeff [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States); Schwartz, Lisa [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States)

2017-07-31

Electric utilities today must contain costs at a time when many need to modernize aging systems and all face major changes in technologies, customer preferences and competitive pressures.Most U.S. electric utility facilities are investor-owned, subject to rate and service regulation by state public utility commissions. Regulatory systems under which these utilities operate affect their performance and ability to meet these challenges. In this business environment, multiyear rate plans have some advantages over traditional rate regulation.The report focuses on key design issues and provides case studies of the multiyear rate plan approach, applicable to both vertically integrated and restructured states. Mark Newton Lowry and Matt Makos of Pacific Energy Group Research and Jeff Deason of Berkeley Lab authored the report; Lisa Schwartz, Berkeley Lab, was project manager and technical editor.The report is aimed primarily at state utility regulators and stakeholders in the state regulatory process. The multiyear rate approach also provides ideas on how to streamline oversight of public power utilities and rural electric cooperatives for their governing boards.Two key provisions of multiyear rate plans strengthen cost containment incentives and streamline regulation: 1. Reducing frequency of rate cases, typically to every four or five years 2. Using an attrition relief mechanism to escalate rates or revenue between rate cases to address cost pressures such as inflation and growth in number of customers, independently of the utility’s own cost Better utility performance can be achieved under well-designed multiyear rate plans while achieving lower regulatory costs. Benefits can be shared between utilities and their customers. But plans can be complex and involve significant changes in the regulatory system. Designing plans that stimulate utility performance without undue risk and share benefits fairly can be challenging.This report discusses the rationale for multiyear

Electricity costs in liberalized market

International Nuclear Information System (INIS)

Barkans, J.; Junghans, G.

2006-01-01

In the liberalized electricity market the flexible demand determines the operation of power plants. Under market conditions the producers are forced to compete, and their power plants are normally loaded in order of increasing prices. The electricity costs consist of fixed and variable components, and the competition among producers simulates minimization of both the components. Considering the fixed costs (including maintenance, depreciation, capital costs and other permanent costs not depending on production) to be known, the total electricity costs in different operating conditions are based on the economic characteristics and the equipment load of a power plant. The paper describes the method for determination of electricity costs for condensing thermal power plants with permanent steam take-off for regeneration purposes and adjustable steam take-off for the needs of local heat energy consumers. The marginal costs for CHP plants are determined considering a number of different steam take-off from a turbine. At the electricity cost determination, auxiliary services also are taken into account. These can be reduced by adjusting the rotational speed of electric motors. The paper also shows how to determine the electricity costs for gas turbines, combined cycle gas turbines, and nuclear power plants. The position of hydro power plants among other PPs in the free market is also analysed. (authors)

Transition costs in the electricity industry: A summary of issues

Energy Technology Data Exchange (ETDEWEB)

Baxter, L.; Hirst, E.; Hadley, S.

1996-10-01

Progress is evident as the restructuring debate in the U.S. electricity industry completes its third year. The Federal Energy Regulatory Commission released a final rule on transmission open access-a key element to facilitate more efficient wholesale markets. The majority of states have initiated investigations or discussions on restructuring retail markets. Yet hurdles remain in formulating and implementing state-level restructuring proposals. Perhaps foremost among these hurdles is the issue of transition costs (the potential monetary losses experienced by utilities, consumers, and other economic actors as a result of government initiatives to transform electricity generation from a regulated to a competitive market). Transition costs are approximately equal to the difference between the embedded cost for generation services under traditional cost-of-service regulation and the competitive-market price for power. When government takes action to open current monopoly franchises to multiple generation providers and the competitive-market price falls below embedded generation costs, then transition costs will arise. Transition costs will include one or more of the following four classes of costs: (1) assets, primarily utility-owned power plants; (2) liabilities, primarily long-term power-purchase and fuel-supply contracts; (3) regulatory assets, including deferred expenses and costs that regulators allow utilities to place on their balance sheets; and (4) public-policy programs, such as energy efficiency, low-income programs, and research and development. What is at issue in the transition-cost debate? The debate turns on four questions: (1) How large are the potential transition costs from restructuring? (2) How are these costs estimated? (3) What, if anything, might be done to address these costs? (4) Who will ultimately pay for any remaining costs and how? This paper summarizes some of the key results from a project at ORNL that addresses these four questions.

Market research for electric utilities

International Nuclear Information System (INIS)

Shippee, G.

1999-01-01

Marketing research is increasing in importance as utilities become more marketing oriented. Marketing research managers need to maintain autonomy from the marketing director or ad agency and make sure their work is relevant to the utility's operation. This article will outline a model marketing research program for an electric utility. While a utility may not conduct each and every type of research described, the programs presented offer a smorgasbord of activities which successful electric utility marketers often use or have access to

The cost of nuclear electricity: France after Fukushima

International Nuclear Information System (INIS)

Boccard, Nicolas

2014-01-01

The Fukushima disaster has lead the French government to release novel cost information relative to its nuclear electricity program allowing us to compute a levelized cost. We identify a modest escalation of capital cost and a larger than expected operational cost. Under the best scenario, the cost of French nuclear power over the last four decades is 59€/MWh (at 2010 prices) while in the worst case it is 83€/MWh. On the basis of these findings, we estimate the future cost of nuclear power in France to be at least 76€/MWh and possibly 117€/MWh. A comparison with the US confirms that French nuclear electricity nevertheless remains cheaper. Comparisons with coal, natural gas and wind power are carried out to find the advantage of these. - Highlights: • We compute the levelized cost of French nuclear power over 40 years using a novel court of audit report. • We include R and D, technology development, fissile fuel, financing cost, decommissioning and the back-end cycle. • We find a mild capital cost escalation and a high operation cost driven by a low fleet availability. • The levelized cost ranges between 59 and 83€/MWh (at 2010 prices) and compares favorably to the US. • A tentative cost for future nuclear power ranges between 76 and 117€/MWh and compares unfavorably against alternative fuels

Market research for electric utilities

Energy Technology Data Exchange (ETDEWEB)

Shippee, G.

1999-12-01

Marketing research is increasing in importance as utilities become more marketing oriented. Marketing research managers need to maintain autonomy from the marketing director or ad agency and make sure their work is relevant to the utility's operation. This article will outline a model marketing research program for an electric utility. While a utility may not conduct each and every type of research described, the programs presented offer a smorgasbord of activities which successful electric utility marketers often use or have access to.

Electric utility report '80

International Nuclear Information System (INIS)

Anon.

1980-01-01

A collection of brief atricles describes the trends and developments in Canada's electric utilities for the 1980's. Generating stations planned or under construction are listed. The trends in technology discused at a recent Canadian Electrical Association meeting are summarized in such areas as turbine stability control, power line vibration control, system reliability, substations and transformer specifications. Developments in nuclear generation are discussed and compared on the world scale where Japan, for example, has the world's largest nuclear program. Progress on fusion is discussed. In Canada the electric utilities are receiving the support of the comprehensive nuclear R and D program of Atomic Energy of Canada Ltd. New innovations in utility technology such as street lighting contactors, superconductive fault limiters and demand profile analyzers are discussed. (T.I.)

Efficiency evaluation of the state owned electric utilities in India

International Nuclear Information System (INIS)

Thakur, Tripta; Deshmukh, S.G.; Kaushik, S.C.

2006-01-01

This paper presents a framework for accessing comparative efficiencies of Indian State Owned Electric Utilities (SOEU), which have been mainly responsible for the generation, distribution and transmission of electricity in India. Performance of 26 utilities was evaluated using the non-parametric technique of Data Envelopment Analysis (DEA), and the impact of scale on the efficiency scores was also evaluated. The results indicate that the performance of several SOEUs is sub-optimal, suggesting the potential for significant cost reductions. Separate benchmarks were derived for possible reductions in employees' number, and the results indicate that several utilities deploy a much larger number of employees than that required by a best practice utility, and significant savings are possible on this account. It was also found that the bigger utilities display greater inefficiencies and have distinct scale inefficiencies. Exploiting scale efficiencies by suitable restructuring and unbundling of SOEUs are therefore crucial measures that may foster efficiencies in the SOEUs. The paper discusses these results in the context of related policy issues

Stranded cost recovery in electricity market reforms in the US

International Nuclear Information System (INIS)

Woo, C.K.; Lloyd, D.; Karimov, R.; Tishler, A.

2003-01-01

An important element of an electricity market reform is stranded cost recovery. This paper explains the cause of stranded costs, describes four recovery mechanisms, evaluates these mechanisms using the criteria of recovery certainty, economic efficiency and equity, reviews the financial performance of 12 utilities in the US in connection to stranded cost recovery, and shows why the mechanism used in California has contributed to the reform failure in that state. (Author)

The impact of financing schemes and income taxes on electricity generation costs

International Nuclear Information System (INIS)

Bertel, E.; Plante, J.

2007-01-01

Electricity generation cost estimates reported in many national and international studies provide a wealth of data to support economic assessments, and eventually to guide choices on generation sources and technologies. However, although the electricity generating cost is the criterion generally selected to present results, it is calculated by various means in different studies because the chosen approach must be relevant to the context of the specific project (private vs. stated-owned investor, regional differences...). The traditional constant-money levelized generation cost methodology is widely used by utilities, government agencies and international organisations to provide economic assessments of alternative generation options. It gives transparent and robust results, especially suitable for screening studies and international comparisons. However, the method, which is strictly economic, does not take into account all the factors influencing the choice of investors in liberalized electricity markets. In particular, it does not take into account financing schemes and income taxes which may hate a significant impact on the capital cost to be supported by the investor. The approach described below is based on the overall framework of average levelized lifetime cost evaluation, but it takes into account the financing scheme adopted by the investor and the income taxes supported by the plant operator/utility. It is similar to models which are used to analyse the economics of competing electricity generation sources in liberalized electricity markets, such as the merchant plant cash flow model adopted in the MIT study. (authors)

Quality electric motor repair: A guidebook for electric utilities

Energy Technology Data Exchange (ETDEWEB)

Schueler, V.; Douglass, J.

1995-08-01

This guidebook provides utilities with a resource for better understanding and developing their roles in relation to electric motor repair shops and the industrial and commercial utility customers that use them. The guidebook includes information and tools that utilities can use to raise the quality of electric motor repair practices in their service territories.

Least cost energy planning in Thailand:A case of biogas upgrading in palm oil industry

Directory of Open Access Journals (Sweden)

Artite Pattanapongchai

2011-12-01

Full Text Available Thailand is currently the world’s fourth largest producer of crude palm oil. The palm oil mill effluent is proposed to beused for biogas production. A value added option is then proposed by increasing thermal efficiency of the biogas by removingCO2 content and increasing the percentage of methane, consequently turning the biogas in to green gas. In this study, thebiogas and upgrading process for electricity generation with the subsidy or adder in the long term planning is presented. Thisanalysis uses the MARKAL-based least-cost energy system as an analytical tool. The objective of this study is to investigateupgrading biogas with a selected water scrubbing technique featuring least-cost energy planning. The co-benefit aspect ofbiogas and biogas upgrading project is analyzed by given an adder of 0.3 Baht/kWh. The target of total electricity generationfrom biogas is 60 MW in 2012. The result shows that green gas will account for approximately 44.91 million m3 in 2012 andincrease to 238.89 million m3 in 2030. The cumulative CO2 emission during 2012-2030 is 2,354.92 thousand tonnes of CO2.Results show that under the given adders the upgrading project is competitive with the conventional technologies in electricitygeneration planning.

A Canadian case study : the value of real time electricity monitoring : a real-time cost utility management solution

International Nuclear Information System (INIS)

Rouse, S.; Dittburner, D.

2006-01-01

Energy prices can vary significantly over the course of a single day in response to changing levels in energy demand and availability of supply. The impacts of varying energy prices on business and industry means that hourly electricity costs can fluctuate widely over the course of a day even though energy use remains stable. This presentation gave details of an energy efficiency initiative at Unilever's Rexdale site which has resulted in $4 million saved through reductions in energy consumption and equipment retrofits. The Rexdale plant won an energy efficiency award in 2005, and the success of the initiative was attributed to the use of Utility 3 + , an energy management software tool. A turn key system with integrated software and hardware, Utility 3 + is capable of measuring how much energy is being used and can provide details of costs using a combination of historical and forecast prices. The tool is equipped with alarms with pre-set thresholds to match real-time rises in energy prices. Real-time prices are relayed from the Internet along with a 2 way data communication system. It was concluded that use of the tool has resulted in improved cash flow management and greater control of energy costs. A system description of the tool was provided, as well as details of various equipment retrofits. refs.., tabs., figs

A Canadian case study : the value of real time electricity monitoring : a real-time cost utility management solution

Energy Technology Data Exchange (ETDEWEB)

Rouse, S. [Energy at Work, Toronto, ON (Canada); Dittburner, D. [Unilever Canada, Toronto, ON (Canada)

2006-07-01

Energy prices can vary significantly over the course of a single day in response to changing levels in energy demand and availability of supply. The impacts of varying energy prices on business and industry means that hourly electricity costs can fluctuate widely over the course of a day even though energy use remains stable. This presentation gave details of an energy efficiency initiative at Unilever's Rexdale site which has resulted in $4 million saved through reductions in energy consumption and equipment retrofits. The Rexdale plant won an energy efficiency award in 2005, and the success of the initiative was attributed to the use of Utility 3{sup +}, an energy management software tool. A turn key system with integrated software and hardware, Utility 3{sup +} is capable of measuring how much energy is being used and can provide details of costs using a combination of historical and forecast prices. The tool is equipped with alarms with pre-set thresholds to match real-time rises in energy prices. Real-time prices are relayed from the Internet along with a 2 way data communication system. It was concluded that use of the tool has resulted in improved cash flow management and greater control of energy costs. A system description of the tool was provided, as well as details of various equipment retrofits. refs.., tabs., figs.

Historical plant cost and annual production expenses for selected electric plants, 1982

International Nuclear Information System (INIS)

1984-01-01

This publication is a composite of the two prior publications, Hydroelectric Plant Construction Cost and Annual Production Expenses and Thermal-Electric Plant Construction Cost and Annual Production Expenses. Beginning in 1979, Thermal-Electric Plant Construction Cost and Annual Production Expenses contained information on both steam-electric and gas-turbine electric plant construction cost and annual production expenses. The summarized historical plant cost described under Historical Plant Cost in this report is the net cumulative-to-date actual outlays or expenditures for land, structures, and equipment to the utility. Historical plant cost is the initial investment in plant (cumulative to the date of initial commercial operation) plus the costs of all additions to the plant, less the value of retirements. Thus, historical plant cost includes expenditures made over several years, as modifications are made to the plant. Power Production Expenses is the reporting year's plant operation and maintenance expenses, including fuel expenses. These expenses do not include annual fixed charges on plant cost (capital costs) such as interest on debt, depreciation or amortization expenses, and taxes. Consequently, total production expenses and the derived unit costs are not the total cost of producing electric power at the various plants. This publication contains data on installed generating capacity, net generation, net capability, historical plant cost, production expenses, fuel consumption, physical and operating plant characteristics, and other relevant statistical information for selected plants

The case for indexed price caps for U.S. electric utilities

International Nuclear Information System (INIS)

Lowry, M.N.

1991-01-01

Indexed price caps are a promising alternative to traditional, cost-of-service utility rate regulation. In just a decade, they have sprung from the drawing boards of economists to use by major utilities in a number of industries. Several authors have discussed the merits of indexed price caps for U.S. electric utilities. Despite their efforts, many parties to electric utility policy making are unfamiliar with the subject. This is unsurprising given the policy controversies that already embroil the industry. It is also unfortunate, since indexed price caps may help solve some of the problems that prompt these controversies. Indexed price caps can improve electric utility rate regulation in two ways. Utilities would have strong incentives to improve performance without the micromanagement that increasingly characterizes state-level regulation. Utilities could also be granted more extensive marketing freedoms, since indexes can protect customers from cross-subsidization. Two areas of concern about indexed price cap plans have emerged in recent discussions that the author has held with officials of electric utilities, intervenor groups, and regulatory agencies. Officials are often unclear on plan details, and therefore may not appreciate the degree of flexibility that is possible in plan design. Confusion over the available options in price cap adjustment indexes and the logic behind them is especially widespread. Officials also desire a clearer expression of how indexed price caps can coexist with current regulatory initiatives. This article details the major attributes of index plans, provides a brief history of indexing, discusses index design options in depth, and concludes with a vision of how indexed price caps can be made operational in today's electric utility industry

Least-cost Paths - Some Methodological Issues

Directory of Open Access Journals (Sweden)

Irmela Herzog

2014-06-01

Full Text Available This article deals with methodological issues connected with least-cost path (LCP calculations in archaeology. The number of LCP studies in archaeology has increased rapidly during the last couple of years, but not all of the approaches applied are based on an appropriate model and implementation. Many archaeologists rely on standard GIS software with default settings for calculating LCPs and are not aware of possible alternatives and the pitfalls that are described in this article. After briefly introducing the aims and applications of LCP methods in archaeology, LCP algorithms are discussed. The outcome of the LCP calculations depends not only on the algorithm but also on the cost model, which often includes several cost components. The discussion of the cost components has a focus on slope, because nearly all archaeological LCP studies take this cost component into account and because several methodological issues are connected with slope-based cost models. Other possible cost components are: the load of the walker, vegetation cover, wetlands or other soil properties, travelling and transport on water, water as barrier and as attractor, aspect, altitude, and social or cultural cost components. Eventually, advantages and disadvantages of different ways of combining cost components are presented. Based on the methodological issues I conclude that both validation checks and variations of the model are necessary to analyse the reliability of archaeological LCP results.

Environmental exposures in the US electric utility industry

International Nuclear Information System (INIS)

Repetto, R.; Henderson, J.

2003-01-01

Quantitative analysis of 47 US investor-owned electric utilities' environmental exposures to impending air quality and climate policies shows potentially material and highly differentiated financial impacts. For many companies the minimized compliance costs of a four-pollutant cap-and-trade regulatory regime would be less than those of a three-pollutant regime that omitted controls on carbon dioxide emissions. Fragmented regulatory requirements would have the highest compliance costs. The companies studied vary considerably in the adequacy of their financial reporting of these potential impacts. Greater transparency would benefit investors and the most favorably positioned companies. (author)

Utilization of oil wells for electricity generation: Performance and economics

International Nuclear Information System (INIS)

Kharseh, Mohamad; Al-Khawaja, Mohammed; Hassani, Ferri

2015-01-01

There is a general agreement that the climate change, which is the most important challenge facing humanity, is anthropogenic and attributed to fossil fuel consumption. Therefore, deploying more renewable energy resources is an urgent issue to be addressed. Geothermal refers to existing heat energy in deep rock and sedimentary basins. Traditionally, geothermal energy has been exploited in places with plentiful hot water at relatively shallow depth. Unfortunately, the high exploration and drilling costs of boreholes is the main barrier to the commerciality of geothermal worldwide. In oil producing countries, such problems can be overcome by utilizing oil or gas wells. The current study presents thermodynamic and economic analyses of a binary geothermal power generation system for commercial electricity generation. Two different source temperatures (100 and 120 °C) and constant sink temperature (29 °C) were considered. The optimal working fluid and optimal design that improve the performance of the plant are determined. For the current costs in Qatar, the economical analysis of 5 MW geothermal plant shows that the levelized cost of electricity for the plant varies from 5.6 to 5.2 ¢/kW. Whereas, the payback period of such plants lies between 5.8 and 4.8 years. - Highlights: • Utilizing oil well makes geothermal plant competitive with other resources. • R32 seems to be the best working fluid. • The levelized cost of electricity for geothermal plant is less than 5.6 ¢/kWh. • The payback time of geothermal plant is less than 6 years.

R and D options for demand side management in Japanese electric utilities

International Nuclear Information System (INIS)

Yamamoto, T.

1995-01-01

Japanese electric utilities are facing several problems: increasing construction cost of power facilities, siting constraints and the environmental issue of greenhouse gas emissions. To overcome these problems, electric utilities have been promoting demand-side-management (DSM) activities as well as supplier-side measures, with some presently being carried out through promoting energy conservation technologies and introducing tariff options for residential/commercial and industrial consumers. R and D works have been carried out on various fields such as energy storage and heat storage which contribute to the improvement of the load factor. 5 figs., 2 tabs

Electric portfolio modeling with stochastic water - climate interactions: Implications for co-management of water and electric utilities

Science.gov (United States)

Woldeyesus, Tibebe Argaw

Water supply constraints can significantly restrict electric power generation, and such constraints are expected to worsen with future climate change. The overarching goal of this thesis is to incorporate stochastic water-climate interactions into electricity portfolio models and evaluate various pathways for water savings in co-managed water-electric utilities. Colorado Springs Utilities (CSU) is used as a case study to explore the above issues. The thesis consists of three objectives: Characterize seasonality of water withdrawal intensity factors (WWIF) for electric power generation and develop a risk assessment framework due to water shortages; Incorporate water constraints into electricity portfolio models and evaluate the impact of varying capital investments (both power generation and cooling technologies) on water use and greenhouse gas emissions; Compare the unit cost and overall water savings from both water and electric sectors in co-managed utilities to facilitate overall water management. This thesis provided the first discovery and characterization of seasonality of WWIF with distinct summertime and wintertime variations of +/-17% compared to the power plant average (0.64gal/kwh) which itself is found to be significantly higher than the literature average (0.53gal/kwh). Both the streamflow and WWIF are found to be highly correlated with monthly average temperature (r-sq = 89%) and monthly precipitation (r-sq of 38%) enabling stochastic simulation of future WWIF under moderate climate change scenario. Future risk to electric power generation also showed the risk to be underestimated significantly when using either the literature average or the power plant average WWIF. Seasonal variation in WWIF along with seasonality in streamflow, electricity demand and other municipal water demands along with storage are shown to be important factors for more realistic risk estimation. The unlimited investment in power generation and/or cooling technologies is also

Cost-reflective electricity pricing: Consumer preferences and perceptions

International Nuclear Information System (INIS)

Hall, Nina L.; Jeanneret, Talia D.; Rai, Alan

2016-01-01

In Australia, residential electricity peak demand has risen steeply in recent decades, leading to higher prices as new infrastructure was needed to satisfy demand. One way of limiting further infrastructure-induced retail price rises is via ‘cost-reflective’ electricity network pricing that incentivises users to shift their demand to non-peak periods. Empowering consumers with knowledge of their energy usage is critical to maximise the potential benefits of cost-reflective pricing. This research consulted residential electricity consumers in three Australian states on their perceptions and acceptance of two cost-reflective pricing scenarios (Time-of-Use and Peak Capacity pricing) and associated technologies to support such pricing (smart meters, in-home displays and direct load control devices). An energy economist presented information to focus groups on the merits and limitations of each scenario, and participants’ views were captured. Almost half of the 53 participants were agreeable to Time-of-Use pricing, but did not have a clear preference for Peak Capacity pricing, where the price was based on the daily maximum demand. Participants recommended further information to both understand and justify the potential benefits, and for technologies to be introduced to enhance the pricing options. The results have implications for utilities and providers who seek to reduce peak demand. - Highlights: •Electricity price rises can be limited by ‘cost-reflective’ pricing. •We consulted residential electricity consumers on Time-of-Use and Peak Capacity pricing. •Understanding of peak electricity demand must increase to enable demand shift. •Interactive website could enable consumers to evaluate pricing options. •Smart meter adoption may increase if voluntary and includes an in-home display.

Why do electricity utilities cooperate with coal suppliers? A theoretical and empirical analysis from China

International Nuclear Information System (INIS)

Zhao Xiaoli; Lyon, Thomas P.; Wang Feng; Song Cui

2012-01-01

The asymmetry of Chinese coal and electricity pricing reforms leads to serious conflict between coal suppliers and electricity utilities. Electricity utilities experience significant losses as a result of conflict: severe coal price fluctuations, and uncertainty in the quantity and quality of coal supplies. This paper explores whether establishing cooperative relationships between coal suppliers and electricity utilities can resolve conflicts. We begin with a discussion of the history of coal and electricity pricing reforms, and then conduct a theoretical analysis of relational contracting to provide a new perspective on the drivers behind the establishment of cooperative relationships between the two parties. Finally, we empirically investigate the role of cooperative relationships and the establishment of mine-mouth power plants on the performance of electricity utilities. The results show that relational contracting between electricity utilities and coal suppliers improves the market performance of electricity utilities; meanwhile, the transportation cost savings derived from mine-mouth power plants are of importance in improving the performance of electricity utilities. - Highlights: ► We discuss the history of coal and electricity pricing reforms. ► The roots of conflicts between electricity and coal firms are presented. ► We conduct a theoretical analysis of relational contracting. ► The role of mine-mouth power plants on the performance of power firms is examined.

Electric utilities in 2007

Energy Technology Data Exchange (ETDEWEB)

Hyman, L.S. [Smith Barney Inc., New York, NY (United States)

1998-10-01

A century ago--in the year J.J. Thomson discovered the electron--electricity, gas and traction companies battled for markets, and corrupt city councils demanded their fair share of the take. One tycoon became so disgusted with the confusion and dishonesty that he decided to bribe the legislature to set up an honest, state-run regulatory agency that would bring order to chaos. But he was found out. The scandal set back the cause of regulation until 1907, the year in which the electric washing machine and the vacuum cleaner were invented. By then, electricity sales had septupled from 1897 levels, and three states had established utility regulation. In the coming decade, 1997 to 2007, the utility business could undergo similar dramatic change, but it will move toward less regulation and more competition during a period of slow growth. Management will have to work harder to achieve success, however, because much of the profits will have to come not from a growing market but from the pockets of competitors. By 2007, electricity will constitute a component of a larger energy and utility services industry that sells electricity, natural gas and possibly water, propane and telecommunications. Customized service will meet the needs of consumers of all sizes. The dominant firm in the industry, the virtual utility, may look more like a financial organization or a mass marketer than the traditional converter of raw material to energy. Emphasis on market-based pricing should lead to more efficient use of resources. If the process works right, the consumer wins.

Beyond free electricity: the costs of electric cooking in poor households and a market-friendly alternative

International Nuclear Information System (INIS)

Howells, M.; Alfstad, T.; Victor, D.G.; Elias, R.J.; Gaunt, T.

2006-01-01

The South African government is introducing a poverty-reduction policy that will supply households with a monthly 50 kWh free basic electricity (FBE) subsidy. We show that FBE distorts the energy choices of poor households by encouraging them to cook with electricity, whereas alternatives such as liquefied petroleum gas (LPG) can deliver a similar cooking service at a much lower cost to society. An alternative energy scheme, such as providing households with clean energy credits equivalent in value to the FBE's cost, could deliver additional energy services worth at least 6% of total household welfare (and probably much more) at no additional public cost; those benefits are so large that they would cover the entire cost of LPG fuel needed to implement the scheme. The analysis is extremely sensitive to the coincidence of electric cooking with peak power demand on the South African grid and to assumptions regarding how South Africa will meet its looming shortfall in peak power capacity. One danger of FBE is that actual peak coincidence and the costs of supplying peak power could be much less favorable than we assume, and such uncertainties expose the South African power system to potentially very high costs of service. (author)

Beyond free electricity: The costs of electric cooking in poor households and a market-friendly alternative

International Nuclear Information System (INIS)

Howells, Mark; Victor, David G.; Gaunt, Trevor; Elias, Rebecca J.; Alfstad, Thomas

2006-01-01

The South African government is introducing a poverty-reduction policy that will supply households with a monthly 50 kWh free basic electricity (FBE) subsidy. We show that FBE distorts the energy choices of poor households by encouraging them to cook with electricity, whereas alternatives such as liquefied petroleum gas (LPG) can deliver a similar cooking service at a much lower cost to society. An alternative energy scheme, such as providing households with clean energy credits equivalent in value to the FBE's cost, could deliver additional energy services worth at least 6% of total household welfare (and probably much more) at no additional public cost; those benefits are so large that they would cover the entire cost of LPG fuel needed to implement the scheme. The analysis is extremely sensitive to the coincidence of electric cooking with peak power demand on the South African grid and to assumptions regarding how South Africa will meet its looming shortfall in peak power capacity. One danger of FBE is that actual peak coincidence and the costs of supplying peak power could be much less favorable than we assume, and such uncertainties expose the South African power system to potentially very high costs of service

Comparative costs of coal and nuclear-generated electricity in the united states

International Nuclear Information System (INIS)

Brandfon, W.W.

1987-01-01

This paper compares the future first-year operating costs and lifetime levelized costs of producing baseload coal- and nuclear-generated electricity under schedules shorter than those recently experienced at U.S. plants. Nuclear appears to have a clear economic advantage. Coal is favorable only when it is assumed that the units will operate at very low capacity factors and/or when the capital cost differential between nuclear and coal is increased far above the recent historical level. Nuclear is therefore a cost-competitive electric energy option for utilities and should be considered as an alternative to coal when large baseload capacity is required. (author)

Energy use, cost and CO2 emissions of electric cars

International Nuclear Information System (INIS)

van Vliet, Oscar; Brouwer, Anne Sjoerd; Kuramochi, Takeshi; van den Broek, Machteld; Faaij, Andre

2011-01-01

We examine efficiency, costs and greenhouse gas emissions of current and future electric cars (EV), including the impact from charging EV on electricity demand and infrastructure for generation and distribution. Uncoordinated charging would increase national peak load by 7% at 30% penetration rate of EV and household peak load by 54%, which may exceed the capacity of existing electricity distribution infrastructure. At 30% penetration of EV, off-peak charging would result in a 20% higher, more stable base load and no additional peak load at the national level and up to 7% higher peak load at the household level. Therefore, if off-peak charging is successfully introduced, electric driving need not require additional generation capacity, even in case of 100% switch to electric vehicles. GHG emissions from electric driving depend most on the fuel type (coal or natural gas) used in the generation of electricity for charging, and range between 0 g km -1 (using renewables) and 155 g km -1 (using electricity from an old coal-based plant). Based on the generation capacity projected for the Netherlands in 2015, electricity for EV charging would largely be generated using natural gas, emitting 35-77 g CO 2 eq km -1 . We find that total cost of ownership (TCO) of current EV are uncompetitive with regular cars and series hybrid cars by more than 800 EUR year -1 . TCO of future wheel motor PHEV may become competitive when batteries cost 400 EUR kWh -1 , even without tax incentives, as long as one battery pack can last for the lifespan of the vehicle. However, TCO of future battery powered cars is at least 25% higher than of series hybrid or regular cars. This cost gap remains unless cost of batteries drops to 150 EUR kWh -1 in the future. Variations in driving cost from charging patterns have negligible influence on TCO. GHG abatement costs using plug-in hybrid cars are currently 400-1400 EUR tonne -1 CO 2eq and may come down to -100 to 300 EUR tonne -1 . Abatement cost using

Cost/benefit assessment in electric power systems

International Nuclear Information System (INIS)

Oteng-Adjei, J.

1990-01-01

The basic function of a modern power system is to satisfy the system load requirements as economically as possible and with a reasonable assurance of continuity and quality. The question of what is reasonable can be examined in terms of the costs and the worth to the consumer associated with providing an adequate supply. The process of preparing reliability worth estimates based on customer cost-of-interruption data is presented. These data can be derived for a particular utility service area and are used to determine appropriate customer damage functions. These indicators can be used with the basic loss of energy expectation (LOEE) index to obtain a factor that can be utilized to relate the customer losses to the worth of electric service reliability. This factor is designated as the interrupted energy assessment rate (IEAR). The developed IEAR values can be utilized in both generating capacity and composite generation and transmission system assessment. Methods for using these estimates in power system optimization at the planning stages are described and examples are used to illustrate the procedures. 106 refs., 77 figs., 64 tabs

The Full Costs of Electricity Provision

International Nuclear Information System (INIS)

Horst Keppler, Jan; Rothwell, Geoffrey; Cometto, Marco; Deffrennes, Marc; Iracane, Daniel; Ha, Jaejoo; Paillere, Henri; ); Aspelund, Karl; Aydil, Ismail; ); Berthelemy, Michel; Devezeaux De Lavergne, Jean-Guy; Burtin, Alain; Crozat, Matthew P.; D'Haeseleer, William; Friedrich, Reiner; Gonzalez Jimenez, Antonio; Hirschberg, Stefan; Kiso, Jan-Ole; ); Lee, Manki; Le Masne, Dominique; ); Lundmark, Roger J.; Neumann, Doris; ); Politis, Savvas; ); Prin, Coralie; Skonieczny, Olgierd; Voss, Alfred

2018-01-01

Electricity provision touches upon every facet of life in OECD and non-OECD countries alike, and choosing how this electricity is generated - whether from fossil fuels, nuclear energy or renewables - affects not only economic outcomes but individual and social well-being in the broader sense. Research on the overall costs of electricity is an ongoing effort, as only certain costs of electricity provision are perceived directly by producers and consumers. Other costs, such as the health impacts of air pollution, damage from climate change or the effects on the electricity system of small-scale variable production are not reflected in market prices and thus diminish well-being in unaccounted for ways. Accounting for these social costs in order to establish the full costs of electricity provision is difficult, yet such costs are too important to be disregarded in the context of the energy transitions currently under way in OECD and NEA countries. This report draws on evidence from a large number of studies concerning the social costs of electricity and identifies proven instruments for internalising them so as to improve overall welfare. The results outlined in the report should lead to new and more comprehensive research on the full costs of electricity, which in turn would allow policy makers and the public to make better informed decisions along the path towards fully sustainable electricity systems

$35 billion habit: will nuclear cost overruns bankrupt the utilities

International Nuclear Information System (INIS)

Morgan, R.E.

1980-01-01

The Nuclear Regulatory Commission (NRC) has proposed some 150 modifications in the design and operation of nuclear power plants as a result of the accident at Three Mile Island. The Atomic Industrial Forum estimates the total cost of the NRC's proposed rule changes at $35.5 billion ($3.5 billion in capital costs for the entire industry, and $32 billion in outage and construction-delay costs to the utilities) for existing facilities and for those with construction well underway. The changes range from improved training for reactor workers to a major overhaul of the reactor-containment design. The nuclear industry is asking the NRC to modify the proposals citing excessive costs (like the $100 million changes needed for a plant that cost $17 million to build) and safety (some of the complex regulations may interfere with safety). Financing the changes has become a major problem for the utilities. If the regulators allow all the costs to be passed along to the consumer, the author feels electricity will be too expensive for the consumer

Performance-based ratemaking for electric utilities: Review of plans and analysis of economic and resource-planning issues. Volume 1

Energy Technology Data Exchange (ETDEWEB)

Comnes, G.A.; Stoft, S.; Greene, N. [Lawrence Berkeley Lab., CA (United States). Energy and Environment Div.; Hill, L.J. [Lawrence Berkeley Lab., CA (United States). Energy and Environment Div.]|[Oak Ridge National Lab., TN (United States). Energy Div.

1995-11-01

Performance-Based Ratemaking (PBR) is a form of utility regulation that strengthens the financial incentives to lower rates, lower costs, or improve nonprice performance relative traditional regulation, which the authors call cost-of-service, rate-of-return (COS/ROR) regulation. Although the electric utility industry has considerable experience with incentive mechanisms that target specific areas of performance, implementation of mechanisms that cover a comprehensive set of utility costs or services is relatively rare. In recent years, interest in PBR has increased as a result of growing dissatisfaction with COS/ROR and as a result of economic and technological trends that are leading to more competition in certain segments of the electricity industry. In addition, incentive regulation has been used with some success in other public utility industries, most notably telecommunications in the US and telecommunications, energy, and water in the United Kingdom. In this report, the authors analyze comprehensive PBR mechanisms for electric utilities in four ways: (1) they describe different types of PBR mechanisms, (2) they review a sample of actual PBR plans, (3) they consider the interaction of PBR and utility-funded energy efficiency programs, and (4) they examine how PBR interacts with electric utility resource planning and industry restructuring. The report should be of interest to technical staff of utilities and regulatory commissions that are actively considering or designing PBR mechanisms. 16 figs., 17 tabs.

Comparative costs of electricity generation: a Canadian perspective

International Nuclear Information System (INIS)

Moore, B.; Guindon, S.

1998-01-01

The cost of generation will be a critical factor in the decision making process for electric power utilities in the years ahead as plans for new capacity are made under the pressures of a more competitive, deregulated market. Technologies with low capital, fuel and operating costs, short construction schedules, capacity closely matched to load growth and minimal regulatory/public acceptance problems are generally more attractive. As the Levelized Unit Energy Cost (LUEC) studies show, natural gas plants require ready access to low-cost supply of natural gas in order to compete. In areas with access to large supplies of low cost natural gas, it is therefore quite likely that natural gas turbines will be chosen, perhaps in combined cycles, for the next round of capacity increases in order to minimize financial risks. From a cost perspective, the challenge for the nuclear industry in Canada is to ensure, in the short to medium term, that the existing plants reach their full operating life and that they operate consistently at high capacity factors. In the longer term, improvements which lower the capital costs of nuclear plants, decrease construction times and increase capacity utilization factors will enhance the competitiveness of the nuclear option

Electric energy utilization and conservation

International Nuclear Information System (INIS)

Tripathy, S.C.

1991-01-01

Various aspects of electric energy utilization and conservation are discussed. First chapter reviews thermodynamic aspects of energy conservation. Subsequent chapters describe possibilities and methods of energy conservation in thermal power plants, airconditioning and ventilation systems, electric lighting systems, electric heating systems in industries, and railway electrification. Chapter 8 describes various modes of energy storage and compares their economies. The next chapter discusses various facets of energy economics and the last chapter discusses the practical aspects of energy conservation in different industries and power utilities. (M.G.B.). 100 refs

Equity, tariffing, regulation: analysis of the cost allocation policies of an electric utility industry

International Nuclear Information System (INIS)

Bezzina, J.

1998-01-01

In this work, an analysis in terms of equity of policies of tariffing regulation and cost allocation of a multi-products electric company (organized as a natural monopoly) is proposed. The goal is double. In a standard point of view, the first goal is to show that today's literature in the domains of public economy, industrial organization and regulation (traditionally based on efficiency considerations) is able to supply reading keys for the analysis of moral philosophy problems. In a positive point of view, the second goal is to demonstrate that the equity criterion is operational enough to judge tariffing management practices in a particular industrial environment and can be used as a regulatory instrument by an ethics-concerned authority. The document is organized in two parts. An ethical and economical analysis of the equity concepts between allocation efficiency, production efficiency and tariffing practices of companies is proposed first. A particular equity concept is considered which is ready to be implemented for the regulation of a public utility, and the ins and outs expected with an equity theory of tariffing practices are evoked. In a second part, an analysis of goal conflicts between the authority and the regulated company is made in a point of view of equity regulation and cost allocation. An improved equity criterion is defined first, from which a measure is built and becomes a tool for the regulatory authority. Then, its use by a regulatory authority fully informed or encountering information asymmetry problems are analyzed in order to show its stakes on the cost allocation and tariffing policies of the company. (J.S.)

Do Canadian electricity prices reflect costs?

International Nuclear Information System (INIS)

Jaccard, M.

1993-01-01

In an article by Cairns and Heyes (1993), it is argued that electricity pricing in Canada diverges from cost due to inter-class rate design that results in cross-subsidies, subsidized cost of capital, intra-class rate design that lacks time-of-use pricing, and failure to collect differential rent. Some problems with the key components of the initial assumption that prices diverge from cost are examined. The premise that inter-class rate design results in cross-subsidies may be correct, but is difficult to test since unregulated crown utilities are not required to make the necessary information public. Cairns and Heyes are on firmer ground in their assertion that provincial government backing of utility debts leads to lower costs of capital than would otherwise occur. Quebec and British Columbia governments have recently undertaken revenue collection initiatives justified under the rationale of addressing this situation. However, there are problems with the assumption that lack of time-of-use pricing indicates cost/price divergence, since such pricing is especially relevant in capacity-critical systems. Most hydroelectric systems are energy-critical and time-of-use differentials are not appropriate. Finally, recent evidence suggests reassessing the differential rent assumptions of the 1980s. The economic rents estimated in that period may be more accurately described as windfall rents existing in the short term while markets adjust to erratic fuel prices and cost changes in nuclear and hydro energy. There may be good economic efficiency arguments against short-term rent collection strategies involving erratic price adjustments. 1 ref

Economic evaluations of fusion-based energy storage systems in an electric utility

International Nuclear Information System (INIS)

Hwang, W.G.

1977-01-01

The feasibility of introducing a fusion energy storage system, which consists of a fusion-fission reactor and a water-splitting process, in an electric utility was investigated. The fusion energy storage system was assumed to be run during off-peak periods in order to make use of unused, low fuel cost capacity of an electric utility. The fusion energy storage system produces both fissile fuel and hydrogen. The produced hydrogen was assumed to be transmitted through and stored in existing natural gas trunklines for later use during peak-load hours. The peaking units in the utility were assumed to burn the hydrogen. Reserve power is usually cheap on systems with heavy nuclear fission reactor installation. The system studied utilizes this cheap energy for producing expensive fuel. The thermochemical water-splitting process was employed to recover thermal energy from the fusion-fission reactor system. The cost of fusion energy storage systems as well as the value of produced fuel were calculated. In order to simulate the operations of the fusion energy storage system for a multi-year planning period, a computer program, FESUT (Fusion Energy Simulation at the University of Texas), was developed for the present study. Two year utility simulations with the fusion energy storage system were performed

All Electric Passenger Vehicle Sales in India by 2030: Value proposition to Electric Utilities, Government, and Vehicle Owners

Energy Technology Data Exchange (ETDEWEB)

Abhyankar, Nikit [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States); Gopal, Anand R. [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States); Sheppard, Colin [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States); Park, Won Young [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States); Phadke, Amol A. [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States)

2017-06-20

In India, there is growing interest among policymakers, planners, and regulators for aggressive electrification of passenger vehicles. For example, Piyush Goyal, the Minister of State for India’s Ministry of Coal, Power, New and Renewable Energy, announced an aspirational goal of converting all vehicle sales in India to battery electric vehicles (BEVs) by 2030 (Economic Times, 2016). In 2012, India has already announced the National Mission on Electric Mobility (NMEM) sets a countrywide goal of deploying 6 to 7 million hybrid and electric vehicles (EVs) by 2020 (DHI, 2012). A major policy motivation for transport electrification is to reduce India’s oil import dependency. The objective of this paper is to assess the effect of full electrification of vehicle sales in India by 2030 on the key stakeholders such as BEV owners, electric utilities, and the government. Specifically, we attempt to answer the following questions: (a) How does the total vehicle ownership cost of BEVs compare with the conventional vehicles? (b) What is the additional load due BEV charging? (c) What is the impact on the power sector investments, costs, and utility revenue? (d) How can smart BEV charging help renewable energy grid integration? (e) What is the impact on the crude oil imports? (f) What is the impact on the greenhouse gas (GHG) emissions?

External costs of nuclear-generated electricity

International Nuclear Information System (INIS)

Rotaru, I.; Glodeanu, F.; Popescu, D.; Andrei, V.

2004-01-01

in market prices, such as security of supply, cost stability and broad economic impacts on employment and balance of trade. If such externalities would be internalized, the effect would be positive for nuclear energy in Romania. In conclusion, like other energy sources, nuclear energy has risks and benefits that need to be fully recognized and assessed to evaluate its external costs. Both internalized (direct) costs and externalities vary from country to country, and from technology to technology. For fossil fuels and biomass, external costs may be of the same order of magnitude as direct cost. Nuclear electricity, solar photovoltaic and wind power have external costs at least one order of magnitude lower than the direct cost. Beyond the competitive generation costs of existing nuclear power plants in most markets, benefits of nuclear power, that are not reflected currently in prices, include: security of supply, cost stability and the quasi absence of atmospheric emissions of greenhouse gases, other pollutant gases and particulates. The capital and operating costs of nuclear power plants and fuel cycle facilities already internalize a major portion of the potential external costs, and these are reflected in the prices paid by consumers of nuclear-generated electricity. The internalization of external costs for all electricity generating technologies will help nuclear energy to be more competitive. (authors)

Energy technologies for distributed utility applications: Cost and performance trends, and implications for photovoltaics

International Nuclear Information System (INIS)

Eyer, J.M.

1994-01-01

Utilities are evaluating several electric generation and storage (G ampersand S) technologies for distributed utility (DU) applications. Attributes of leading DU technologies and implications for photovoltaics (PV) are described. Included is a survey of present and projected cost and performance for: (1) small, advanced combustion turbines (CTs); (2) advanced, natural gas-fired, diesel engines (diesel engines); and (3) advanced lead-acid battery systems (batteries). Technology drivers and relative qualitative benefits are described. A levelized energy cost-based cost target for PV for DU applications is provided. The analysis addresses only relative cost, for PV and for three selected alternative DU technologies. Comparable size, utility, and benefits are assumed, although relative value is application-specific and often technology- and site-specific

Electric infrastructure failures in Nigeria: a survey-based analysis of the costs and adjustment responses

International Nuclear Information System (INIS)

Adenikinju, A.F.

2003-01-01

This paper examines the cost of electricity shortages on the Nigerian manufacturing sector. Utilizing the data obtained from a 1998 nationwide survey, the paper details the various costs from power outages and examines the response of manufacturers to the infrastructure problem. The findings of the study confirm that the cost of electricity failures on the Nigerian manufacturing sector is quite high. Firms incur huge costs on the provision of expensive back-up to minimise the expected outage costs. The average costs of this back-up are on the average 3 times the cost of publicly supplied electricity. The marginal cost estimates also indicate that the cost of kWh of unserved electricity in Nigeria is very high. Small-scale firms bear the greater proportion of the cost of the power failure. A situation where firms spend as much as 20-30% of initial investment on the acquisition of facilities to enhance electricity supply reliability has a significant negative impact on costs competitiveness of the manufacturing sector. Thus, the study supports current government efforts to privatise the public monopoly and liberalizes the electricity market. These hopefully will mitigate the burden of poor power supply as well as introduce the needed competition into the electricity market in the country

Balancing Cost and Risk: The Treatment of Renewable Energy inWestern Utility Resource Plans

Energy Technology Data Exchange (ETDEWEB)

Wiser, Ryan; Bolinger, Mark

2005-09-01

Markets for renewable electricity have grown significantly in recent years, motivated in part by federal tax incentives and in part by state renewables portfolio standards and renewable energy funds. State renewables portfolio standards, for example, motivated approximately 45% of the 4,300 MW of wind power installed in the U.S. from 2001 through 2004, while renewable energy funds supported an additional 15% of these installations. Despite the importance of these state policies, a less widely recognized driver for renewable energy market growth is poised to also play an important role in the coming years: utility integrated resource planning (IRP). Formal resource planning processes have re-emerged in recent years as an important tool for utilities and regulators, particularly in regions where retail competition has failed to take root. In the western United States, recent resource plans contemplate a significant amount of renewable energy additions. These planned additions - primarily coming from wind power - are motivated by the improved economics of wind power, a growing acceptance of wind by electric utilities, and an increasing recognition of the inherent risks (e.g., natural gas price risk, environmental compliance risk) in fossil-based generation portfolios. The treatment of renewable energy in utility resource plans is not uniform, however. Assumptions about the direct and indirect costs of renewable resources, as well as resource availability, differ, as do approaches to incorporating such resources into the candidate portfolios that are analyzed in utility IRPs. The treatment of natural gas price risk, as well as the risk of future environmental regulations, also varies substantially. How utilities balance expected portfolio cost versus risk in selecting a preferred portfolio also differs. Each of these variables may have a substantial effect on the degree to which renewable energy contributes to the preferred portfolio of each utility IRP. This article

The effect of costs and regulation on electricity prices

International Nuclear Information System (INIS)

Schlaf, E.P.

1991-01-01

Two distinct econometric tests were performed to determine if state price regulation of public utilities has had a measurable impact on retail electricity prices. The results of both tests agree that, during the 1971-1985 period, average national electricity prices in each of the three major consuming sectors and the four Census regions were below the level which would have been preferred by profit-maximizing monopolists. Electricity consumers received price benefits during the sample period as a result of regulation. The first test of the effectiveness of state price regulation used a 'revealed preference' approach by comparing the actual prices set by regulatory commissioners with prices and outcomes predicted by three competing theories of regulatory motivation. The second test of the effectiveness of price regulation combined traditional cost function inputs with regulatory variables in reduced-form price equations to determine whether the amount of regulatory intensity, as measured by the number of staff members per regulated utility, is associated with declining electricity prices and whether appointed commissioners allow higher prices than elected commissioners

A bid solicitation and selection method for developing a competitive spot priced electric market

International Nuclear Information System (INIS)

Ancona, J.J.

1997-01-01

The electric utility industry is in the beginning throes of a transformation from a cost-based regulated structure to a more market based less regulated system. Traditional unit commitment and economic dispatch methodologies can continue to provide reliable least-cost solutions, providing they are modified to accommodate a larger sphere of market participants. This paper offers a method for an entity such as an Independent System Operator (ISO) to solicit and evaluate bids for developing a spot priced electric market by replicating existing utility practices that are effective and efficient, while creating an open and equitable competitive marketplace for electricity

Do acquisitions by electric utility companies create value? Evidence from deregulated markets

International Nuclear Information System (INIS)

Kishimoto, Jo; Goto, Mika; Inoue, Kotaro

2017-01-01

In the early 1990s, the United Kingdom (the UK) initiated widespread reforms in the electricity industry through a series of market liberalization policies. Several other countries have subsequently followed the lead and restructured their electricity industry. A major outcome of the deregulation effort is the spate of takeovers, both domestic and global, by electric utility companies. With the entry of new players and increasing competition, the business environment of the electricity industry has changed dramatically. This study analyzes the economic impact of mergers and acquisitions (M&As) in the electric utility industry after deregulation. We have examined acquisitions that took place between 1998 and 2013 in the United States, Canada, the UK, Germany, and France. Although previous studies showed no evidence of a positive effect on acquiring firms through M&As, we find that acquisitions by electric utility companies increased the acquiring firms’ share value and improved their operating performance, primarily through efficiency gains after the deregulation. These results are consistent with the empirical evidence and implications presented by Andrade et al. (2001) that M&A created value for the shareholders of the acquiring and target combined firms. - Highlights: • This study examined mergers and acquisitions (M&A) in electric utility industry. • The sample covered M&A between 1998 and 2013 in North America and Europe. • We found M&A significantly increased acquiring firms’ share value and operating performance. • Deregulation policy realized gains for shareholders without incurring costs for consumers.

Decreasing fuel cost weight in electric utility business. ; Urged peak measures and management constitution improvement. Denki jigyo no nenryohi weight wa gensho. ; Isogareru peak taisaku to keiei taishitsu kaizen

Energy Technology Data Exchange (ETDEWEB)

1993-09-01

The electric power industry has made stable and economic power supply possible by advancing diversification in power sources and shifting the petroleum supply sources to southern countries and China. The cost constitution of the electric utility business in the fiscal year 1992 was such that the ratio of fuel cost is 15.9% against the total cost amount of 13 trillion 399.3 billion yen. As opposed, the fuel cost percent in the fiscal 1980 was 37.7%. This means that the effect of the fuel cost on the total cost has become smaller even if the fuel cost varies as a result of external factors including fluctuation in foreign exchange rates. Peaks in the power demand have been recorded in day time in high summer when air conditioning demand increases, which have been growing year after year. Expenses to maintain facilities and functions to deal with this demand increase have been increasing. The owned capital ratio in the electric power business was 15.7% in the fiscal 1992, which is by far lower than the average of whole industry of 28%. Execution of measures against the power peaks and improvement of the management constitution are the problems posed on the electric power industry. 4 figs., 1 tab.

Electric vehicle utilization for ancillary grid services

Science.gov (United States)

Aziz, Muhammad

2018-02-01

Electric vehicle has been developed through several decades as transportation mean, without paying sufficient attention of its utilization for other purposes. Recently, the utilization of electric vehicle to support the grid electricity has been proposed and studied intensively. This utilization covers several possible services including electricity storage, spinning reserve, frequency and voltage regulation, and emergency energy supply. This study focuses on theoretical and experimental analysis of utilization of electric vehicles and their used batteries to support a small-scale energy management system. Charging rate of electric vehicle under different ambient temperature (seasonal condition) is initially analyzed to measure the correlation of charging rate, charging time, and state-of-charge. It is confirmed that charging under warmer condition (such as in summer or warmer region) shows higher charging rate than one in colder condition, therefore, shorter charging time can be achieved. In addition, in the demonstration test, each five electric vehicles and used batteries from the same electric vehicles are employed and controlled to support the electricity of the office building. The performance of the system is evaluated throughout a year to measure the load leveling effect during peak-load time. The results show that the targeted peak-load can be shaved well under certain calculated peak-shaving threshold. The finding confirms that the utilization of electric vehicle for supporting the electricity of grid or certain energy management system is feasible and deployable in the future.

Potential for increased wind-generated electricity utilization using heat pumps in urban areas

International Nuclear Information System (INIS)

Waite, Michael; Modi, Vijay

2014-01-01

Highlights: • Large-scale wind power and increased electric heat pumps were evaluated. • A deterministic model of wind power and electricity demand was developed. • Sub-models for space heating and domestic hot water demand were developed. • Increased use of heat pumps can improve the viability of large-scale wind power. • Larger wind power capacity can meet a target utilization rate with more heat pumps. - Abstract: The U.S. has substantial wind power potential, but given wind’s intermittent availability and misalignment with electricity demand profiles, large-scale deployment of wind turbines could result in high electricity costs due to energy storage requirements or low utilization rates. While fuel switching and heat pumps have been proposed as greenhouse gas (GHG) emissions and energy reduction strategies at the building scale, this paper shows that heat pump adoption could have additional system-wide benefits by increasing the utilization of wind-generated electricity. A model was developed to evaluate the effects of coupling large-scale wind power installations in New York State with increased use of electric heat pumps to meet a portion of space heating and domestic hot water (DHW) demands in New York City. The analysis showed significant increases in wind-generated electricity utilization with increased use of heat pumps, allowing for higher installed capacity of wind power. One scenario indicates that 78.5% annual wind-generated electricity utilization can be achieved with 3 GW of installed wind power capacity generated electricity equal to 20% of existing NYC annual electricity demand; if 20% of space heating and DHW demands are provided by heat pumps, the 78.5% utilization rate can be achieved with an increase of total wind power capacity to 5 GW. Therefore, this integrated supply–demand approach could provide additional system-wide emissions reductions

Calculating utility prudency issue costs

International Nuclear Information System (INIS)

Nielsen, K.R.

1985-01-01

The nuclear industry, particularly utilities and their construction, engineering and vendor agents, is faced with a surging increase in prudency management audits. What started as primarily a nuclear project-oriented requirement has spread to encompass most significant utility capital construction projects. Such audits are often a precedent condition to commencement of rate hearings. The cost engineer, a primary major capital construction project participant, is required to develop or critique ''prudency issue'' costs as part of such audits. Although utility costs in the broadest sense are potentially at issue, this paper concentrates on the typical project/construction management costs. The costs of design, procurement and construction are all subject to the calculation process

Growth strategies of electric utilities in context of deregulation and liberalization of electricity market

Directory of Open Access Journals (Sweden)

Maria Đogić

2017-01-01

Full Text Available This paper identifies the growth strategies adopted by the electric utilities sector in the context of changes resulting from the deregulation and liberalization of the electricity market. Strategies pursued by the electric utilities sector were rarely the subject of research in the field of strategic management despite the fact that electricity is an indispensable element of everyday life and the economy as a whole. Therefore, a case study of the largest incumbent electric utilities in the Republic of Croatia, Slovenia, Bosnia and Herzegovina, Serbia, Montenegro, and Macedonia has been conducted, and differences in the degree of market liberalization and core features of these companies have been noted. Research findings have shown that the degree of deregulation can affect the growth strategies of electric utilities. In those countries where the degree of deregulation is lower, electric utilities focus on the domestic market. On the other hand, a higher level of deregulation enables electric utilities to achieve their growth through diversification or innovation. Given the fact that the analyzed electric utilities are operating within relatively small economies, they cannot compete with electric utilities in developed countries, and, apart from international electricity trading, are mostly focused on their domestic markets.

Operating and impact of the compensation mechanism of the electric utility charges on the energy offer in non connected areas

International Nuclear Information System (INIS)

Levratto, N.

2005-01-01

Since the law of the 10 february 2000 relative to the modernization and the development of the electric utility, the France adopted a mechanism aiming to compensate the costs subjected by EDF and other suppliers providing a public utility mission in the domain of the electricity production and distribution. This document takes stock on the organization, the evaluation and the economical and environmental consequences of the implementing of a compensation system of costs bond to the electricity production in non connected areas. (A.L.B.)

Realistic generation cost of solar photovoltaic electricity

International Nuclear Information System (INIS)

Singh, Parm Pal; Singh, Sukhmeet

2010-01-01

Solar photovoltaic (SPV) power plants have long working life with zero fuel cost and negligible maintenance cost but requires huge initial investment. The generation cost of the solar electricity is mainly the cost of financing the initial investment. Therefore, the generation cost of solar electricity in different years depends on the method of returning the loan. Currently levelized cost based on equated payment loan is being used. The static levelized generation cost of solar electricity is compared with the current value of variable generation cost of grid electricity. This improper cost comparison is inhibiting the growth of SPV electricity by creating wrong perception that solar electricity is very expensive. In this paper a new method of loan repayment has been developed resulting in generation cost of SPV electricity that increases with time like that of grid electricity. A generalized capital recovery factor has been developed for graduated payment loan in which capital and interest payment in each installment are calculated by treating each loan installment as an independent loan for the relevant years. Generalized results have been calculated which can be used to determine the cost of SPV electricity for a given system at different places. Results show that for SPV system with specific initial investment of 5.00 cents /kWh/year, loan period of 30 years and loan interest rate of 4% the levelized generation cost of SPV electricity with equated payment loan turns out to be 28.92 cents /kWh, while the corresponding generation cost with graduated payment loan with escalation in annual installment of 8% varies from 9.51 cents /kWh in base year to 88.63 cents /kWh in 30th year. So, in this case, the realistic current generation cost of SPV electricity is 9.51 cents /kWh and not 28.92 cents /kWh. Further, with graduated payment loan, extension in loan period results in sharp decline in cost of SPV electricity in base year. Hence, a policy change is required

Greenhouse gas abatement in Senegal. A case study of least-cost options

International Nuclear Information System (INIS)

Amous, S.; Revet, D.; Sokona, Y.

1994-01-01

The first stage of the study was to make a preliminary inventory of greenhouse gas (GHG) emissions for the base year 1988. Following this seven no regret technical options for emission reduction were investigated and the costs calculated, allowing the identification of three least-cost options. The three least-cost options must be implemented first because of their negative costs. The economic benefits of both abatement scenarios are characterized by a negative global cost whatever the discount rate is. (author)

Regional projections of nuclear and fossil electric power generation costs

International Nuclear Information System (INIS)

Smolen, G.R.; Delene, J.G.; Fuller, L.C.; Bowers, H.I.

1983-12-01

The total busbar electric generating costs were estimated for locations in ten regions of the United States for base load nuclear and coal-fired power plants with a startup date of January 1995. A complete data set is supplied which specifies each parameter used to obtain the comparative results. When the comparison is based on reference cost parameters, nuclear- and coal-fired generation costs are found to be very close in most regions of the country. Nuclear power is favored in the South Atlantic region where coal must be transported over long distances, while coal-fired generation is favored in the Central and North Central regions where large reserves of cheaply mineable coal exist. The reference data set reflects recent electric utility construction experience. Significantly lower nuclear capital investment costs would result if regulatory reform and improved construction practices were instituted. The electric power generation costs for base load oil- and natural gas-fired plants were also estimated. These plants were found to be noncompetitive in all regions for those scenarios most likely to develop. Generation cost sensitivity to changes in various parameters was examined at a reference location. The sensitivity parameters included capital investment costs, lead times, capacity factors, costs of money, and coal and uranium prices. In addition to the levelized lifetime costs, year-by-year cash flows and revenue requirements are presented. The report concludes with an analysis of the economic merits of recycling spent fuel in light-water reactors

Cost utility analysis of diagnostic method of syphilis

Directory of Open Access Journals (Sweden)

Viroj Wiwanitkit

2008-04-01

Full Text Available Presently, the diagnosis of syphilis is dependent mainly on serological tests. The most widely used screening tests for syphilis are the VDRL and the rapid plasma reagin (RPR and for confirmation, the fluorescent treponemal antibody (FTA and the treponema pallidum hemagglutination (TPHA tests. The four alternative modes for diagnosis of syphilis can be a VDRL + FTA, b VDRL + TPHA, c RPR + FTA and d RPR + TPHA. Here the author reports an evaluation of cost utility of these tests in medical practice. It is shown that the cost per accurate diagnosis with VDRL + TPH is the least expensive choice. Therefore, this alternative is the best method for serological diagnosis for syphilis, based on medical laboratory economics principles

Exploring the relationship between planning and procurement in Western U.S. electric utilities

Energy Technology Data Exchange (ETDEWEB)

Carvallo Bodelon, Juan Pablo [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States). Energy Analysis and Environmental Impacts Division; Sanstad, Alan H. [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States). Energy Analysis and Environmental Impacts Division; Larsen, Peter H. [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States). Energy Analysis and Environmental Impacts Division

2017-06-01

Integrated resource planning (IRP) is an important regulatory process used in many U.S. states to formulate and evaluate least-cost and risk-assessed portfolios to meet future load requirements for electric utilities. In principle, effective implementation of IRP seeks to assure regulators and the public that utility investment decisions, given uncertainty, are as cost-effective as possible. However, to date, there is no empirical assessment on the effectiveness of IRP implementation. In this analysis, we compare planning, procurement processes and actual decisions for a sample of twelve load serving entities (LSEs) across the Western U. S. from 2003-2014. The 2008/2009 recession provides a unique “stress test” to the planning process and offers an excellent opportunity to trace how procurement decisions responded to this largely unforeseen event. In aggregate, there is a general alignment between planned and procured supply-side capacity. However, there are significant differences in the choice of supply-side resources and type of ownership for individual LSEs. We develop case studies for three LSEs and find that subsequent plans differ significantly due to changes in the planning environment and that procurement decisions in some cases are impacted by factors that are not accounted for in the planning process. Our results reveal that a limited amount of information produced during the long-term planning process (e.g., forecasts, methods, and least cost/risk portfolios) are ultimately used during the procurement process, and that the latter process relies extensively on the most recent information available for decision making. These findings suggest that states' IRP rules and regulations mandating long-term planning horizons with the same analytical complexity throughout the planning period may not create useful information for the procurement process. The social value of a long-term planning process that departs from procurement and the balance between

Transition-cost issues for a restructuring US electricity industry

Energy Technology Data Exchange (ETDEWEB)

NONE

1997-03-01

Utilities regulators can use a variety of approaches to calculate transition costs. We categorized these approaches along three dimensions. The first dimension is the use of administrative vs. market procedures to value the assets in question. Administrative approaches use analytical techniques to estimate transition costs. Market valuation relies on the purchase price of particular assets to determine their market values. The second dimension concerns when the valuation is done, either before or after the restructuring of the electricity industry. The third dimension concerns the level of detail involved in the valuation, what is often called top-down vs. bottom-up valuation. This paper discusses estimation approaches, criteria to assess estimation methods, specific approaches to estimating transition costs, factors that affect transition-cost estimates, strategies to address transition costs, who should pay transition costs, and the integration of cost recovery with competitive markets.

Time-of-Use Rates and Electricity Costs of Representative New York Dairy Farms

OpenAIRE

Boisvert, Richard N.; Bills, Nelson L.; Middagh, Mark C.; Schenkel, Mark

1992-01-01

Electric utilities throughout the Nation are experimenting with strategies to reduce total electricity consumption or to alter the timing of electrical power use by their customers. This report focuses on one such strategy, time-of-use (TaU) electric rates, and the likely effect of this pricing option on the New York dairy sector. The purpose of the study is to assess the change in farm electrical energy costs when power is sold to dairymen at higher rates for periods of peak power demand and...

Electric utilities look back on 1998

International Nuclear Information System (INIS)

Anon.

1999-01-01

A review of activities in the electric power industry in Canada during 1998 is presented. In general, the principal preoccupation of Canadian electric utilities in 1998 was preparation for competition in a deregulated energy market. Utilities worked with provincial and national legislatures to redraw the rules of power supply. US FERC order 888 was central to many debates. FERC order 888 stipulates the unbundling of the retail aspects of operations from those that will remain regulated. Electric utilities also continued to prepare for the Y2K phenomenon and to work towards achieving ISO 14001 environmental management accreditation. They also explored alternative means of power generation. The year began with utilities across Canada sharing expertise and manpower to mitigate the impact of the ice storm which devastated parts of Quebec, Ontario and New Brunswick. It is believed that as a result of the ice storm of 1998, the Canadian utility industry is much better prepared to deal with weather-related emergencies than ever before. 1 fig

Cost effects of international trade in meeting EU renewable electricity targets

International Nuclear Information System (INIS)

Voogt, M.H.; Uyterlinde, M.A.

2006-01-01

The European market for renewable electricity received a major stimulus from the adoption of the Directive on the Promotion of Renewable Electricity. The Directive specifies the indicative targets for electricity supply from renewable energy sources (RES-E) to be reached in European Union (EU) Member States in the year 2010. It also requires Member States to certify the origin of their renewable electricity production. This article presents a first EU-wide quantitative evaluation of the effects of meeting the targets, using an EU-wide system for tradable green certificates (TGC). We calculate the equilibrium price of green certificates and identify which countries are likely to export or import certificates. Cost advantages of participating in such an EU-wide trading scheme are determined for each of the Member States. Moreover, we identify which choice of technologies results in meeting targets at least costs. Results are obtained from a model that quantifies the effects of achieving the RES-E targets in the EU with and without trade. The article provides a brief insight in this model as well as the methodology that was used to specify cost potential curves for renewable electricity in each of the 15 EU Member States. Model calculations show that within the EU-wide TGC system, the total production costs of the last option needed to satisfy the overall EU RES-E target equals 9.2 eurocent/kWh. Assuming that the production price of electricity on the European power market would equal 3 eurocent/kWh in the year 2010, the indicative green certificate price equals 6.2 eurocent/kWh. We conclude that implementation of an EU-wide TGC system is a cost-efficient way of stimulating renewable electricity supply

Assessing the full costs of electricity

International Nuclear Information System (INIS)

Keppler, Jan Horst

2016-01-01

For decades, economists, energy specialists and policy-makers have been satisfied with assessing the comparative costs of electricity generation on the basis of discounted average costs over the lifetime and the total output of a generating plant. As a standardised form of cost-benefit accounting (CBA), these levelised costs of electricity (LCOE) indicate the required expenditures in terms of capital, fuel, and operations and management (O and M), adjusted for their incidence in time or the different technology options per unit of output (i.e. a MWh of electricity). This straightforward, transparent and comparatively simple metric worked well in a context of regulated markets where generators were centrally dispatched according to system requirements, tariffs were set by regulators and load factors could be predicted with confidence. In order to satisfy a given demand for electricity, the technology with the lowest LCOE was usually chosen, thus minimising the costs of the electricity system. Nuclear energy thus competed with hydro, where available, and coal and gas on the basis of their respective capital, labour and fuel costs at the level of the individual plant. (author)

IT use in electric utilities - today and tomorrow

International Nuclear Information System (INIS)

Persson, Maria

1998-01-01

A survey of the present and future use of IT-systems in British electric utilities is presented. Systems for Asset Management, Reliability Centered Maintenance, Customer Databases etc are discussed. A few utilities are studied more closely (Eastern Electricity, London Electricity, Scottish Power and Yorkshire Electricity)

Joint Costs in Electricity and Natural Gas Distribution Infrastructures: The Role of Urban Factors

Directory of Open Access Journals (Sweden)

Muzeyyen Anil Senyel

2018-04-01

Full Text Available This paper analyzes the joint cost structure of electricity and natural gas distribution investments. Assessing the joint costs is critical for urban development and public policy regarding competition at the local level. The paper accounts for the urban and geographic factors at the local level, while the previous literature primarily used company-level data with a few or no site-specific variables in joint cost analyses. An empirical analysis of the multi-utility capital costs suggests that the local urban and geographic conditions affect such costs, with economies of scope present in electricity and natural gas both in terms of total costs and underground investment costs. Hence, the joint service provision makes economic and environmental sense for urban policy makers.

Cost-benefit analysis of reforming Israel's electricity industry

International Nuclear Information System (INIS)

Tishler, A.; Newman, J.; Spekterman, I.; Woo, C.K.

2006-01-01

In June 2003, the Israeli government decided to reform the Israeli electricity industry, which is currently dominated by Israel electric corporation (IEC), a government-owned vertically integrated electric utility. The first step of the planned reform will be taken in 2006, when IEC will be functionally separated into generation, transmission, local distribution, and customer services. Immediately thereafter will be the second step, which by 2012 will result in the deregulation and privatization of the wholesale generation and customer services. Transmission and distribution (T and D) services will remain regulated but will be available to all T and D users under mandatory open access. This paper summarizes a cost-benefit analysis of the government's reform plan. Relative to a regulated regime, the government's plan, even if carried out flawlessly, may only yield a small net benefit. However, it entails a large increase in electricity producer profit and government tax receipt, at the expense of electricity consumers. A less-than-perfect transition to competition can easily wipe out the potential gain of the government plan. Market reform experience to date shows that electricity market reform can easily fail, and the factors for success do not exist in Israel. Since the outcome of a failing reform can be disastrous, it will be imprudent to implement the government's plan in 2006, when the current electricity law expires. Hence, we recommend performance-based regulation for the period of 2006-2010. Subject to an updated cost-benefit analysis, possible decentralization, privatization and competition may follow

Electric utility companies and geothermal power

Science.gov (United States)

Pivirotto, D. S.

1976-01-01

The requirements of the electric utility industry as the primary potential market for geothermal energy are analyzed, based on a series of structured interviews with utility companies and financial institution executives. The interviews were designed to determine what information and technologies would be required before utilities would make investment decisions in favor of geothermal energy, the time frame in which the information and technologies would have to be available, and the influence of the governmental politics. The paper describes the geothermal resources, electric utility industry, its structure, the forces influencing utility companies, and their relationship to geothermal energy. A strategy for federal stimulation of utility investment in geothermal energy is suggested. Possibilities are discussed for stimulating utility investment through financial incentives, amelioration of institutional barriers, and technological improvements.

Energy economics: impacts on electric utilities' future decisions

International Nuclear Information System (INIS)

Smith, S.H.

1983-01-01

Despite financial and regulatory pressures that have led electric utilities to slow construction and minimize capital expenditures, Carolina Power and Light Company is proceeding with two new nuclear and two new coal facilities because it believes the commitment to expand must be made in the 1980s. The economic slowdown has given utilities a breathing period, but not enough to allow a complete stop in expansion if the utilities are to be ready for the expected economic growth of the 1990s. Financing this expansion is a slower process for regulated industries and leads to strained relations between customers and suppliers. The two can work together to promote conservation and load management, but higher rates must finance new construction to avoid a shortfall later. The costs of environmentally sound coal combustion and nuclear plant construction must both be reduced to help keep the recovery from being inflationary

LIFE Cost of Electricity, Capital and Operating Costs

International Nuclear Information System (INIS)

Anklam, T.

2011-01-01

Successful commercialization of fusion energy requires economic viability as well as technical and scientific feasibility. To assess economic viability, we have conducted a pre-conceptual level evaluation of LIFE economics. Unit costs are estimated from a combination of bottom-up costs estimates, working with representative vendors, and scaled results from previous studies of fission and fusion plants. An integrated process model of a LIFE power plant was developed to integrate and optimize unit costs and calculate top level metrics such as cost of electricity and power plant capital cost. The scope of this activity was the entire power plant site. Separately, a development program to deliver the required specialized equipment has been assembled. Results show that LIFE power plant cost of electricity and plant capital cost compare favorably to estimates for new-build LWR's, coal and gas - particularly if indicative costs of carbon capture and sequestration are accounted for.

Levelised cost of electricity 2015

International Nuclear Information System (INIS)

Stolzenberger, Christian; Then, Oliver

2015-01-01

The electricity business is currently subject to dynamic and permanent change that is driven by innovation, learning curves and modifications of the electricity generation mix. A new edition of the ''Levelised Cost of Electricity (LCOE)'' was drafted under these circumstances. The fundamental idea behind the LCOE is to calculate the yearly average costs of building and operating plants and to compare these with the average energy generated each year.

Levelised cost of electricity 2015

Energy Technology Data Exchange (ETDEWEB)

Stolzenberger, Christian; Then, Oliver [VGB PowerTech e.V., Essen (Germany)

2015-07-01

The electricity business is currently subject to dynamic and permanent change that is driven by innovation, learning curves and modifications of the electricity generation mix. A new edition of the ''Levelised Cost of Electricity (LCOE)'' was drafted under these circumstances. The fundamental idea behind the LCOE is to calculate the yearly average costs of building and operating plants and to compare these with the average energy generated each year.

The effect of utility time-varying pricing and load control strategies on residential summer peak electricity use. A review

International Nuclear Information System (INIS)

Newsham, Guy R.; Bowker, Brent G.

2010-01-01

Peak demand for electricity in North America is expected to grow, challenging electrical utilities to supply this demand in a cost-effective, reliable manner. Therefore, there is growing interest in strategies to reduce peak demand by eliminating electricity use, or shifting it to non-peak times. This strategy is commonly called 'demand response'. In households, common strategies are time-varying pricing, which charge more for energy use on peak, or direct load control, which allows utilities to curtail certain loads during high demand periods. We reviewed recent North American studies of these strategies. The data suggest that the most effective strategy is a critical peak price (CPP) program with enabling technology to automatically curtail loads on event days. There is little evidence that this causes substantial hardship for occupants, particularly if they have input into which loads are controlled and how, and have an override option. In such cases, a peak load reduction of at least 30% is a reasonable expectation. It might be possible to attain such load reductions without enabling technology by focusing on household types more likely to respond, and providing them with excellent support. A simple time-of-use (TOU) program can only expect to realise on-peak reductions of 5%. (author)

Financial impacts of nonutility power purchases on investor-owned electric utilities

Energy Technology Data Exchange (ETDEWEB)

1994-06-01

To assist in its these responsibilities in the area of electric power, EIA has prepared this report, Financial Impacts of Nonutility Power Purchases on Investor-Owned Electric Utilities. The primary purpose of this report is to provide an overview of the issues surrounding the financial impacts of nonutility generation contracts (since the passage of the Public Utility Regulatory Policies Act of 1978) on investor-owned utilities. The existing concern in this area is manifest in the provisions of Section 712 of the Energy Policy Act of 1992, which required State regulatory commissions to evaluate various aspects of long-term power purchase contracts, including their impact on investor-owned utilities` cost of capital and rates charged to customers. The EIA does not take positions on policy questions. The EIA`s responsibility is to provide timely, high quality information and to perform objective, credible analyses in support of the deliberations by both public and private decision-makers. Accordingly, this report does not purport to represent the policy positions of the US Department of Energy or the Administration.

Financial impacts of nonutility power purchases on investor-owned electric utilities

International Nuclear Information System (INIS)

1994-01-01

To assist in its these responsibilities in the area of electric power, EIA has prepared this report, Financial Impacts of Nonutility Power Purchases on Investor-Owned Electric Utilities. The primary purpose of this report is to provide an overview of the issues surrounding the financial impacts of nonutility generation contracts (since the passage of the Public Utility Regulatory Policies Act of 1978) on investor-owned utilities. The existing concern in this area is manifest in the provisions of Section 712 of the Energy Policy Act of 1992, which required State regulatory commissions to evaluate various aspects of long-term power purchase contracts, including their impact on investor-owned utilities' cost of capital and rates charged to customers. The EIA does not take positions on policy questions. The EIA's responsibility is to provide timely, high quality information and to perform objective, credible analyses in support of the deliberations by both public and private decision-makers. Accordingly, this report does not purport to represent the policy positions of the US Department of Energy or the Administration

A comparison of costs associated with utility management options for dry active waste

Energy Technology Data Exchange (ETDEWEB)

Hornibrook, C. [EPRI, Palo Alto, CA (United States)

1995-12-31

The economics of low level waste management is receiving more attention today than ever before. This is due to four factors: (1) the increases in the cost of processing of these wastes; (2) increases in the cost of disposal; (3) the addition of storage costs for those without access to disposal; and (4) the increasing competitive nature of the electric generation industry. These pressures are forcing the industry to update it`s evaluation of the mix of processing that will afford it the best long term economics and minimize it`s risks for unforeseen costs. Whether disposal is available or not, all utilities face the same challenge of minimizing the costs associated with the management of these wastes. There are a number of variables that will impact how a utility manages their wastes but the problem is the uncertainty of what will actually happen, i.e., will disposal be available, when and at what cost. Using the EPRI-developed WASTECOST: DAW code, this paper explores a variety of LLW management options available to utilities. Along with providing the costs and benefits, other technical considerations which play an important part in the management of these wastes are also addressed.

The projected costs of electricity generation

International Nuclear Information System (INIS)

Cameron, R.; Keppler, J. H.

2010-10-01

This paper describes the outcomes from the joint report between the Nuclear Energy Agency and the International Energy Agency of the OECD on the projected costs of generating electricity. The study contains data on electricity generating costs for almost 200 power plants provided by 17 OECD member countries, 4 non-OECD countries and 4 industrial companies or industry organisations. The paper presents the projected costs of generating electricity calculated according to common methodological rules on the basis of the data provided by participating countries and organisations. Data were received for a wide variety of fuels and technologies, including coal, gas, nuclear, hydro, onshore and offshore wind, biomass, solar, wave and tidal. Cost estimates were also provided for combined heat and power plants, as well as for coal plants that include carbon capture. As in previous studies of the same series, all costs and benefits were discounted or capitalised to the date of commissioning in order to calculate the state of the electricity costs per MWh, based on plant operating lifetime data. In addition, the paper contains a discussion of a number of factors affecting the cost of capital, the outlook for carbon capture and storage and the working of electricity markets. (Author)

A Cost-Utility Analysis of 5 Strategies for the Management of Acute Otitis Media in Children.

Science.gov (United States)

Shaikh, Nader; Dando, Emily E; Dunleavy, Mark L; Curran, Dorothy L; Martin, Judith M; Hoberman, Alejandro; Smith, Kenneth J

2017-10-01

To assess whether antimicrobial therapy in young children with acute otitis media reduces time to resolution of symptoms, overall symptom burden, and persistence of otoscopic evidence of infection. We used a cost-utility model to evaluate whether immediate antimicrobial treatment seems to be worthwhile, and if so, which antimicrobial agent is most cost effective. We compared the cost per quality-adjusted life-day of 5 treatment regimens in children younger than 2 years of age with acute otitis media: immediate amoxicillin/clavulanate, immediate amoxicillin, immediate cefdinir, watchful waiting, and delayed prescription (DP) for antibiotic. The 5 treatment regimens, listed in order from least effective to most effective were DP, watchful waiting, immediate cefdinir, immediate amoxicillin, and immediate amoxicillin/clavulanate. Listed in order from least costly to most costly, the regimens were DP, immediate amoxicillin, watchful waiting, immediate amoxicillin/clavulanate, and immediate cefdinir. The incremental cost-utility ratio of immediate amoxicillin compared with DP was $101.07 per quality-adjusted life-day gained. The incremental cost-utility ratio of immediate amoxicillin/clavulanate compared with amoxicillin was $2331.28 per quality-adjusted life-day gained. In children younger than 2 years of age with acute otitis media and no recent antibiotic exposure, immediate amoxicillin seems to be the most cost-effective initial treatment. Copyright © 2017 Elsevier Inc. All rights reserved.

Financial statistics of major U.S. investor-owned electric utilities 1996

Energy Technology Data Exchange (ETDEWEB)

NONE

1997-12-01

The Financial Statistics of Major US 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 Federal and State governments, industry, and the general public with current and historical data that can be used for making policy and decisions relating to investor-owned electric utility issues. The US electric power industry is a combination of electric utilities (investor-owned, publicly owned, Federal, and cooperatives) and nonutility power producers. Investor-owned electric utilities account for over three-fourths of electric sales and revenue. Historically, the investor-owned electric utilities have served the large consolidated markets. There is substantial diversity among the investor-owned electric utilities in terms of services, size, fuel usage, and prices charged. Most investor-owned electric utilities generate, transmit, and distribute electric power. Investor-owned electric utilities operate in all States except Nebraska; Hawaii is the only State in which all electricity is supplied by investor-owned electric utilities. 5 figs., 57 tabs.

External costs of electricity

International Nuclear Information System (INIS)

Rabl, A.; Spadaro, J.V.

2005-01-01

This article presents a synthesis of the ExternE project (External costs of Energy) of the European community about the external costs of power generation. Pollution impacts are calculated using an 'impact pathways' analysis, i.e. an analysis of the emission - dispersion - dose-response function - cost evaluation chain. Results are presented for different fuel cycles (with several technological variants) with their confidence intervals. The environmental impact costs are particularly high for coal: for instance, in France, for coal-fired power plants it is of the same order as the electricity retail price. For natural gas, this cost is about a third of the one for coal. On the contrary, the environmental impact costs for nuclear and renewable energies are low, typically of few per cent of the electricity price. The main part of these costs corresponds to the sanitary impacts, in particular the untimely mortality. In order to avoid any controversy about the cost evaluation of mortality, the reduction of the expectation of life due to the different fuel cycles is also indicated and the risks linked with nuclear energy are presented using several comparisons. (J.S.)

Peak shifting and cross-class subsidization: The impacts of solar PV on changes in electricity costs

International Nuclear Information System (INIS)

Johnson, Erik; Beppler, Ross; Blackburn, Chris; Staver, Benjamin; Brown, Marilyn; Matisoff, Daniel

2017-01-01

The expansion of distributed solar necessitates additional research into the impacts on both utilities and their customers. In this paper we use New Jersey solar data, PJM market data, and demand profiles from a PJM utility to investigate rate and bill impacts of large-scale solar penetration. In addition to the subsidization of solar adopters by non-participants, we highlight the channels through which cross-subsidization of rate classes can arise in practice. The results of our study indicate that the fear of a utility “death spiral” may be exaggerated. Significant solar can be incorporated with only a 2% increase in non-participant bills. At high levels of penetration, distributed solar has the potential to alter the system peak hour which affects the allocation of costs across rate-classes. As the peak hour shifts to the evening when solar production diminishes, residential customers face higher distribution costs. Policy makers and utilities need to be aware of these challenges in designing the next generation of rates that are better aligned with cost causality. - Highlights: • We develop a model of electricity costs with large amounts of solar adoption. • Solar adoption leads to cost redistribution across customer classes. • Costs are redistributed partially because peak utility load shifts later in the day. • Residential distributed solar generation affects electricity bills the most. • We confirm the subsidy of participants by non-participants in net metering programs.

How EPRI [Electric Power Research Institute] helps utilities save money

International Nuclear Information System (INIS)

Anon.

1996-01-01

A number of case studies are presented which illustrate how the work of the Electric Power Research Institute in the USA has enabled nuclear utilities to save money. The areas covered by the examples are: steam generator tube repair; streamlining of reliability centred maintenance; cost effective instrumentation and control maintenance; reducing the frequency of instrument calibration; optimising the engineering change process; detecting and reducing fuel failure; extending the qualified life of equipment. (U.K.)

Probabilistic Analysis of Electrical Energy Costs: Comparing Production Costs for Gas, Coal and Nuclear Power Plants. Annex III

Energy Technology Data Exchange (ETDEWEB)

NONE

2013-12-15

The increase in electricity demand is linked to the development of the economy and living standards in each country. This is especially true in those developing countries in which electricity consumption is far below the average of industrialized countries. To satisfy the increased demand for electricity, it is necessary to build new electrical power plants that could, in an optimum way, meet the imposed acceptability criteria. The main criteria are the potential to supply the required energy and to supply it with minimum or, at least, acceptable costs and environmental impacts, to satisfy the licensing requirements and be acceptable to the public. The main competitors for electricity production in the next few decades are fossil fuel power plants (coal and gas) and nuclear power plants. Power plants making use of renewables (solar, wind, biomass) are also important, but due to limited energy supply potential and high costs, can only be a supplement to the main generating units. Large hydropower plants would be competitive under the condition that suitable sites for the construction of such plants exist. Unfortunately, both in Croatia and in the rest of central Europe, such sites are scarce.

Weighted least-squares criteria for electrical impedance tomography

International Nuclear Information System (INIS)

Kallman, J.S.; Berryman, J.G.

1992-01-01

Methods are developed for design of electrical impedance tomographic reconstruction algorithms with specified properties. Assuming a starting model with constant conductivity or some other specified background distribution, an algorithm with the following properties is found: (1) the optimum constant for the starting model is determined automatically; (2) the weighted least-squares error between the predicted and measured power dissipation data is as small as possible; (3) the variance of the reconstructed conductivity from the starting model is minimized; (4) potential distributions with the largest volume integral of gradient squared have the least influence on the reconstructed conductivity, and therefore distributions most likely to be corrupted by contact impedance effects are deemphasized; (5) cells that dissipate the most power during the current injection tests tend to deviate least from the background value. The resulting algorithm maps the reconstruction problem into a vector space where the contribution to the inversion from the background conductivity remains invariant, while the optimum contributions in orthogonal directions are found. For a starting model with nonconstant conductivity, the reconstruction algorithm has analogous properties

10 CFR 490.307 - Option for Electric Utilities.

Science.gov (United States)

2010-01-01

... 10 Energy 3 2010-01-01 2010-01-01 false Option for Electric Utilities. 490.307 Section 490.307... Provider Vehicle Acquisition Mandate § 490.307 Option for Electric Utilities. (a) A covered person or its... selling, at wholesale or retail, electricity has the option of delaying the vehicle acquisition mandate...

Comparison of costs of electricity generation based on nuclear energy and pit coal

International Nuclear Information System (INIS)

1981-01-01

Despite of a meanwhile considerable increase in costs of installation, especially of nuclear power stations, the differences in costs have increased in favour of nuclear electricity generation. The cost advantages are estimated 4 German Pfennig per kilowatt-hour in the base-load field for plants coming into operation at the end of this decade compared with the most profitable variant of pit coal utilization on which this investigation is based; compared to the use of German hard coal, assuming a relatively optimistic development of prices for domestic hard coal in the future, the cost advantage is estimated 8 German Pfennig per kilowatt-hour. The main reason is that in the past years the price for German hard coal as well as for imported coal considerably rose and for the future further increases have to be expected whereas the largest share of the costs of nuclear electricity generation doesn't increase, after the plant is completed. Considering the importance of the fuel costs within the total costs of electricity generation in coal power stations this must have its effects on the total result. These results also prove to be valid for a variation of important cost parameters. Only if the unlikely assumption that considerable variations of influences on costs - each unfavourable effecting nuclear electricity generation - would come together would prove to be true the economic efficiency of nuclear energy would be reduced or questioned. (UA) [de

Cost and quality gains from diversification and vertical integration in the electricity industry: A DEA approach

International Nuclear Information System (INIS)

Arocena, Pablo

2008-01-01

This paper analyzes the degree of economies of vertical integration, diversification and scale in the electricity industry by means of Data Envelopment Analysis. We estimate the impact that alternative forms of unbundling would have on the cost and quality of supply, measured as the number and duration of supply interruptions, in a group of Spanish electric utilities. We find evidence of the existence of cost and quality gains from integrating power generation and distribution in the range of 1.1 to 4.9%, whereas diversifying the source of power generation saves between 1.3 and 4.3% of costs and quality. Finally, the scale efficiency of the largest utilities could be improved by dividing them into smaller units, provided that their current vertical scope and generation-mix are preserved. (author)

Cost and quality gains from diversification and vertical integration in the electricity industry: A DEA approach

Energy Technology Data Exchange (ETDEWEB)

Arocena, Pablo [Universidad Publica de Navarra, Dpto. Gestion de Empresas, Campus de Arrosadia, 31006 Pamplona (Spain)

2008-01-15

This paper analyzes the degree of economies of vertical integration, diversification and scale in the electricity industry by means of Data Envelopment Analysis. We estimate the impact that alternative forms of unbundling would have on the cost and quality of supply, measured as the number and duration of supply interruptions, in a group of Spanish electric utilities. We find evidence of the existence of cost and quality gains from integrating power generation and distribution in the range of 1.1 to 4.9%, whereas diversifying the source of power generation saves between 1.3 and 4.3% of costs and quality. Finally, the scale efficiency of the largest utilities could be improved by dividing them into smaller units, provided that their current vertical scope and generation-mix are preserved. (author)

Shaping the future of electric utilities

International Nuclear Information System (INIS)

Byus, L.C.

1993-01-01

On December 14, 1992, Cincinnati Gas ampersand Electric Company (CG ampersand E) and PSI Resources, Inc. announced an agreement to merge the two companies into a newly formed company, CINergy Corp. In announcing the proposed merger, James E. Rogers Jr., chairman, president, and chief executive officer of PSI said, Our companies have chosen to shape our future and our industry. This is an ideal partnership, since our strengths complement each other and our vision of the future is the same. Will this merger be the first of many that will shape the future of the electric utility in the United States? What is the vision of the future for the industry? About five years ago, a well-known Wall Street utility analyst traveled around the country talking about the anticipated consolidation of electric utility companies in the US His motto was Fifty in Five, meaning widespread consolidation that would reduce the number of independent investor-owned utilities from more than 100 to 50 within a five-year period. He even developed a map showing the mergers/consolidations he looked for and actually named names. More than five years have passed, and only a handful of utility mergers have taken place. But, looking forward from 1992, restructuring of the utility industry is very much a vision of the future. What is the driving force? The National Energy Policy Act of 1992 provides the legislative framework for the electric utility industry in the US in future years. While the specific rules that will govern the industry are yet to be promulgated, the intent to allow (even promote) competition is evident in the Act itself. But it appears the vision of the future is market driven

ASSESSMENT OF CONTROL TECHNOLOGIES FOR REDUCING EMISSIONS OF SO2 AND NOX FROM EXISTING COAL-FIRED UTILITY BOILERS

Science.gov (United States)

The report reviews information and estimated costs on 15 emissioncontrol technology categories applicable to existing coal-fired electric utility boilers. he categories include passive controls such as least emission dispatching, conventional processes, and emerging technologies ...

Financial statistics of major US investor-owned electric utilities 1992

Energy Technology Data Exchange (ETDEWEB)

1993-12-28

The Financial Statistics of Major US 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 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. The Financial Statistics of Major US Investor-Owned Electric Utilities publication provides information about the financial results of operations of investor-owned electric utilities for use by government, industry, electric utilities, financial organizations and educational institutions in energy planning. In the private sector, the readers of this publication are researchers and analysts associated with the financial markets, the policymaking and decisionmaking members of electric utility companies, and economic development organizations. Other organizations that may be interested in the data presented in this publication include manufacturers of electric power equipment and marketing organizations. In the public sector, the readers of this publication include analysts, researchers, statisticians, and other professionals engaged in regulatory, policy, and program areas. These individuals are generally associated with the Congress, other legislative bodies, State public utility commissions, universities, and national strategic planning organizations.

Electrolysis: Information and Opportunities for Electric Power Utilities

Energy Technology Data Exchange (ETDEWEB)

Kroposki, B.; Levene, J.; Harrison, K.; Sen, P.K.; Novachek, F.

2006-09-01

Recent advancements in hydrogen technologies and renewable energy applications show promise for economical near- to mid-term conversion to a hydrogen-based economy. As the use of hydrogen for the electric utility and transportation sectors of the U.S. economy unfolds, electric power utilities need to understand the potential benefits and impacts. This report provides a historical perspective of hydrogen, discusses the process of electrolysis for hydrogen production (especially from solar and wind technologies), and describes the opportunities for electric power utilities.

Load Forecasting in Electric Utility Integrated Resource Planning

Energy Technology Data Exchange (ETDEWEB)

Carvallo, Juan Pablo [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States); Larsen, Peter H. [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States); Sanstad, Alan H [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States); Goldman, Charles A. [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States)

2017-07-19

Integrated resource planning (IRP) is a process used by many vertically-integrated U.S. electric utilities to determine least-cost/risk supply and demand-side resources that meet government policy objectives and future obligations to customers and, in many cases, shareholders. Forecasts of energy and peak demand are a critical component of the IRP process. There have been few, if any, quantitative studies of IRP long-run (planning horizons of two decades) load forecast performance and its relationship to resource planning and actual procurement decisions. In this paper, we evaluate load forecasting methods, assumptions, and outcomes for 12 Western U.S. utilities by examining and comparing plans filed in the early 2000s against recent plans, up to year 2014. We find a convergence in the methods and data sources used. We also find that forecasts in more recent IRPs generally took account of new information, but that there continued to be a systematic over-estimation of load growth rates during the period studied. We compare planned and procured resource expansion against customer load and year-to-year load growth rates, but do not find a direct relationship. Load sensitivities performed in resource plans do not appear to be related to later procurement strategies even in the presence of large forecast errors. These findings suggest that resource procurement decisions may be driven by other factors than customer load growth. Our results have important implications for the integrated resource planning process, namely that load forecast accuracy may not be as important for resource procurement as is generally believed, that load forecast sensitivities could be used to improve the procurement process, and that management of load uncertainty should be prioritized over more complex forecasting techniques.

Financial statistics of major publicly owned electric utilities, 1991

International Nuclear Information System (INIS)

1993-01-01

The Financial Statistics of Major 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 Federal and State governments, industry, and the general public with data that can be used for policymaking and decisionmaking purposes relating to publicly owned electric utility issues

Financial statistics of major publicly owned electric utilities, 1991

Energy Technology Data Exchange (ETDEWEB)

1993-03-31

The Financial Statistics of Major 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 Federal and State governments, industry, and the general public with data that can be used for policymaking and decisionmaking purposes relating to publicly owned electric utility issues.

Calculating cost savings in utilization management.

Science.gov (United States)

MacMillan, Donna

2014-01-01

A major motivation for managing the utilization of laboratory testing is to reduce the cost of medical care. For this reason it is important to understand the basic principles of cost accounting in the clinical laboratory. The process of laboratory testing includes three distinct components termed the pre-analytic, analytic and post-analytic phases. Utilization management efforts may impact the cost structure of these three phases in different ways depending on the specific details of the initiative. Estimates of cost savings resulting from utilization management programs reported in the literature have often been fundamentally flawed due to a failure to understand basic concepts such as the difference between laboratory costs versus charges and the impact of reducing laboratory test volumes on the average versus marginal cost structure in the laboratory. This article will provide an overview of basic cost accounting principles in the clinical laboratory including both job order and process cost accounting. Specific examples will be presented to illustrate these concepts in various different scenarios. © 2013.

The prospects for cost competitive solar PV power

International Nuclear Information System (INIS)

Reichelstein, Stefan; Yorston, Michael

2013-01-01

New solar Photovoltaic (PV) installations have grown globally at a rapid pace in recent years. We provide a comprehensive assessment of the cost competitiveness of this electric power source. Based on data available for the second half of 2011, we conclude that utility-scale PV installations are not yet cost competitive with fossil fuel power plants. In contrast, commercial-scale installations have already attained cost parity in the sense that the generating cost of power from solar PV is comparable to the retail electricity prices that commercial users pay, at least in certain parts of the U.S. This conclusion is shown to depend crucially on both the current federal tax subsidies for solar power and an ideal geographic location for the solar installation. Projecting recent industry trends into the future, we estimate that utility-scale solar PV facilities are on track to become cost competitive by the end of this decade. Furthermore, commercial-scale installations could reach “grid parity” in about ten years, if the current federal tax incentives for solar power were to expire at that point. - Highlights: ► Assessment of the cost competitiveness of new solar Photovoltaic (PV) installations. ► Utility-scale PV installations are not yet cost competitive with fossil fuel power plants. ► Commercial-scale installations have already attained cost parity in certain parts of the U.S. ► Utility-scale solar PV facilities are on track to become cost competitive by the end of this decade

The Characteristic of Molten Heat Salt Storage System Utilizing Solar Energy Combined with Valley Electric

Directory of Open Access Journals (Sweden)

LI .Jiu-ru

2017-02-01

Full Text Available With the environmental pollution and energy consumption clue to the large difference between peak and valley of power grid，the molten salt heat storage system(MSHSS utilizing solar Energy combined with valley electric is presented for good energy saving and low emissions. The costs of MSHSS utilizing solar Energy combined with valley electric are greatly reduced. The law of heat transfer in molten salt heat storage technology is studied with the method of grey correlation analysis. The results show the effect of elbow sizes on surface convective heat transfer coefficient with different flow velocities.

ROMI 3.1 Least-cost lumber grade mix solver using open source statistical software

Science.gov (United States)

Rebecca A. Buck; Urs Buehlmann; R. Edward. Thomas

2010-01-01

The least-cost lumber grade mix solution has been a topic of interest to both industry and academia for many years due to its potential to help wood processing operations reduce costs. A least-cost lumber grade mix solver is a rough mill decision support system that describes the lumber grade or grade mix needed to minimize raw material or total production cost (raw...

Levelized cost of electricity (LCOE) of renewable energies and required subsidies in China

International Nuclear Information System (INIS)

Ouyang, Xiaoling; Lin, Boqiang

2014-01-01

The development and utilization of renewable energy (RE), a strategic choice for energy structural adjustment, is an important measure of carbon emissions reduction in China. High cost is a main restriction element for large-scale development of RE, and accurate cost estimation of renewable power generation is urgently necessary. This is the first systemic study on the levelized cost of electricity (LCOE) of RE in China. Results indicate that feed-in-tariff (FIT) of RE should be improved and dynamically adjusted based on the LCOE to provide a better support of the development of RE. The current FIT in China can only cover the LCOE of wind (onshore) and solar photovoltaic energy (PV) at a discount rate of 5%. Subsidies to renewables-based electricity generation, except biomass energy, still need to be increased at higher discount rates. Main conclusions are drawn as follows: (1) Government policy should focus on solving the financing problem of RE projects because fixed capital investment exerts considerable influence over the LCOE; and (2) the problem of high cost could be solved by providing subsidies in the short term and more importantly, by reforming electricity price in the mid-and long-term to make the RE competitive. - Highlights: • Levelized cost of electricity (LCOE) of renewable energies is systemically studied. • Renewable power generation costs are estimated based on data of 17 power plants. • Required subsidies for renewable power generation are calculated. • Electricity price reform is the long-term strategy for solving problem of high cost

Homeless Veterans' Use of Peer Mentors and Effects on Costs and Utilization in VA Clinics.

Science.gov (United States)

Yoon, Jean; Lo, Jeanie; Gehlert, Elizabeth; Johnson, Erin E; O'Toole, Thomas P

2017-06-01

The study compared health care utilization and costs among homeless veterans randomly assigned to peer mentors or usual care and described contacts with peer mentors. Homeless patients at four Department of Veterans Affairs clinics were randomly assigned to a peer mentor (N=195) or to usual care (N=180). Administrative data on utilization and costs over a six-month follow-up were combined with peer mentors' reports of patient contacts. Most patients (87%) in the peer mentor group had at least one peer contact. Patients in this group spent the largest proportions of time discussing housing and health issues with peer mentors and had more outpatient encounters than those in usual care, although differences were not significant. No other between-group differences were found in utilization or costs. Although significant impacts of peer mentors on health care patterns or costs were not detected, some patients had frequent contact with peer mentors.

Financial statistics of major investor-owned electric utilities, 1991

International Nuclear Information System (INIS)

1993-01-01

The Financial Statistics of major 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 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

Financial statistics of selected investor-owned electric utilities, 1989

Energy Technology Data Exchange (ETDEWEB)

1991-01-01

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.

The Impact of Utility Tariff Evolution on Behind-the-Meter PV Adoption

Energy Technology Data Exchange (ETDEWEB)

Cole, Wesley J [National Renewable Energy Laboratory (NREL), Golden, CO (United States); Gagnon, Pieter J [National Renewable Energy Laboratory (NREL), Golden, CO (United States); Frew, Bethany A [National Renewable Energy Laboratory (NREL), Golden, CO (United States); Margolis, Robert M [National Renewable Energy Laboratory (NREL), Golden, CO (United States)

2017-09-18

This analysis uses a new method to link the NREL Regional Energy Deployment System (ReEDS) capacity expansion model with the NREL distributed generation market demand model (dGen) to explore the impact that the evolution of retail electricity tariffs can have on the adoption of distributed photovoltaics (DPV). The evolution most notably takes the form of decreased mid-day electricity costs, as low-cost PV reduces the marginal cost of electricity during those hours and the changes are subsequently communicated to electricity consumers through tariffs. We find that even under the low PV prices of the new SunShot targets the financial performance of DPV under evolved tariffs still motivates behind-the-meter adoption, despite significant reduction in the costs of electricity during afternoon periods driven by deployment of cheap utility-scale PV. The amount of DPV in 2050 in these low-cost futures ranged from 206 GW to 263 GW, a 13-fold and 16-fold increase over 2016 adoption levels respectively. From a utility planner's perspective, the representation of tariff evolution has noteworthy impacts on forecasted DPV adoption in scenarios with widespread time-of-use tariffs. Scenarios that projected adoption under a portfolio of time-of-use tariffs, but did not represent the evolution of those tariffs, predicted up to 36 percent more DPV in 2050, compared to scenarios that did not represent that evolution. Lastly, we find that a reduction in DPV deployment resulting from evolved tariffs had a negligible impact on the total generation from PV - both utility-scale and distributed - in the scenarios we examined. Any reduction in DPV generation was replaced with utility-scale PV generation, to arrive at the quantity that makes up the least-cost portfolio.

Factors influencing electric utility expansion. Volume II

Energy Technology Data Exchange (ETDEWEB)

Masud, E. [ed.

1977-01-01

This report, Vol. 2, submitted by the General Electric Co., identifies factors that should be considered in planning interconnected systems and discusses how these factors relate to one another. The objective is to identify all the factors and classify them by their use and importance in arriving at a decision. Chapter 2 discusses the utility system and its system behavior characteristics, emphasizing behavior that affects the planning of the bulk-power generation and transmission system. Chapter 3 introduces interconnection planning by discussing the new system characteristics brought to operation and planning. Forty-two factors associated with cost, reliability, constraints, and coordination are related to each other by factor trees. Factor trees display the relationship of one factor such as reliability to more-detailed factors which in turn are further related to individual characteristics of facilities. These factor trees provide a structure to the presentation. A questionnaire including the 42 factors was completed by 52 system planners from utility companies and government authorities. The results of these questionnaires are tabulated and presented with pertinent discussion of each factor. Chapter 4 deals with generation planning, recognizing the existence of interconnections. Chapter 5 addresses transmission planning, questions related to reliability and cost measures and constraints, and factors related to both analytical techniques and planning procedures. The chapter ends with a discussion of combined generation-transmission planning. (MCW)

Impacts of Western Area Power Administration's power marketing alternatives on electric utility systems

International Nuclear Information System (INIS)

Veselka, T.D.; Portante, E.C.; Koritarov, V.

1995-03-01

This technical memorandum estimates the effects of alternative contractual commitments that may be initiated by the Western Area Power Administration's Salt Lake City Area Office. It also studies hydropower operational restrictions at the Salt Lake City Area Integrated Projects in combination with these alternatives. Power marketing and hydropower operational effects are estimated in support of Western's Electric Power Marketing Environmental Impact Statement (EIS). Electricity production and capacity expansion for utility systems that will be directly affected by alternatives specified in the EIS are simulated. Cost estimates are presented by utility type and for various activities such as capacity expansion, generation, long-term firm purchases and sales, fixed operation and maintenance expenses, and spot market activities. Operational changes at hydropower facilities are also investigated

Technology choice in a least-cost expansion analysis framework

International Nuclear Information System (INIS)

Guziel, K.A.; South, D.W.

1990-01-01

This paper reports that the current outlook for new capacity additions by electric utilities is uncertain and tenuous. Regardless of the amount, it is inevitable that new capacity will be needed in the 1990s and beyond. The fundamental question about the additional capacity requirements centers on technology choice and the factors influencing the decision process. Under current market conditions, utilities have become capital aversive due to rate base disallowances by state regulatory commissions, difficulties in funding long-term capital-intensive projects, uncertainties about future demand, and the ability to purchase power from sources such as independent power producers (IPPs) and cogenerators. Instead of building capital-intensive power plants, utilities have begun relying on natural gas technologies, which permit rapid construction/deployment and low capital investment

Capture and corruption in public utilities. The cases of water and electricity in Sub-Saharan Africa

Energy Technology Data Exchange (ETDEWEB)

Auriol, Emmanuelle [Toulouse School of Economics, 21 Allees de Brienne, 31000 Toulouse (France); Blanc, Aymeric [Agence Francaise de Developpement, 5 rue Roland Barthes, 75598 Paris Cedex 12 (France)

2009-06-15

The paper focuses on public utilities services located in poor countries with a special attention to capture and corruption issues. It confronts the optimal policy of Auriol and Picard [Privatization in Developing Countries and the Government Budget Constraint, Nota di Lavoro 75.2002. Fondazione Eni Enrico Mattei, Milan, Italy] regarding private sector involvement in public utilities with empirical evidence on water and electricity in Sub-Saharan Africa (SSA). As predicted by the theory, the participation of private unregulated firms in the supply of services for the middle class and poor people is fairly common in SSA. By contrast, services for rich people are provided by public utilities. Theory suggests that their prices should be high so that the public firms make a profit. Yet piped water and electricity are subsidized. This suggests that there is a problem of capture by the ruling elite. Since ruling elites design privatization programs, there is concern about their optimality. The paper shows that the social cost of corrupted privatization is non-monotone in the opportunity cost of public funds. Because of the fiscal loss it represents, privatizing profit centers of public firms entails huge social costs in very poor countries. (author)

Capture and corruption in public utilities. The cases of water and electricity in Sub-Saharan Africa

International Nuclear Information System (INIS)

Auriol, Emmanuelle; Blanc, Aymeric

2009-01-01

The paper focuses on public utilities services located in poor countries with a special attention to capture and corruption issues. It confronts the optimal policy of Auriol and Picard [Privatization in Developing Countries and the Government Budget Constraint, Nota di Lavoro 75.2002. Fondazione Eni Enrico Mattei, Milan, Italy] regarding private sector involvement in public utilities with empirical evidence on water and electricity in Sub-Saharan Africa (SSA). As predicted by the theory, the participation of private unregulated firms in the supply of services for the middle class and poor people is fairly common in SSA. By contrast, services for rich people are provided by public utilities. Theory suggests that their prices should be high so that the public firms make a profit. Yet piped water and electricity are subsidized. This suggests that there is a problem of capture by the ruling elite. Since ruling elites design privatization programs, there is concern about their optimality. The paper shows that the social cost of corrupted privatization is non-monotone in the opportunity cost of public funds. Because of the fiscal loss it represents, privatizing profit centers of public firms entails huge social costs in very poor countries. (author)

Economic costs of electricity production in Poland

International Nuclear Information System (INIS)

Beeldman, M.; Solinski, J.

1994-02-01

This study presents a methodology for the calculation of the economic costs of the production of electricity. This methodology is applied to assess electricity production cost in Poland by type of power station for the years 1995 and 2000. In addition, an overview is presented of the methods used by the OECD countries, particularly in the Netherlands. The main conclusions of the study are: 1) the real economic costs to generate electricity in Poland are about two times higher compared with the traditional book-keeping data; 2) the investment costs will become the most important cost component in the near future; and 3) there are considerables differences in production cost per kWh for the different types of power plants in Poland. 4 appendices, 14 refs

Survey and analysis of selected jointly owned large-scale electric utility storage projects

Energy Technology Data Exchange (ETDEWEB)

1982-05-01

The objective of this study was to examine and document the issues surrounding the curtailment in commercialization of large-scale electric storage projects. It was sensed that if these issues could be uncovered, then efforts might be directed toward clearing away these barriers and allowing these technologies to penetrate the market to their maximum potential. Joint-ownership of these projects was seen as a possible solution to overcoming the major barriers, particularly economic barriers, of commercializaton. Therefore, discussions with partners involved in four pumped storage projects took place to identify the difficulties and advantages of joint-ownership agreements. The four plants surveyed included Yards Creek (Public Service Electric and Gas and Jersey Central Power and Light); Seneca (Pennsylvania Electric and Cleveland Electric Illuminating Company); Ludington (Consumers Power and Detroit Edison, and Bath County (Virginia Electric Power Company and Allegheny Power System, Inc.). Also investigated were several pumped storage projects which were never completed. These included Blue Ridge (American Electric Power); Cornwall (Consolidated Edison); Davis (Allegheny Power System, Inc.) and Kttatiny Mountain (General Public Utilities). Institutional, regulatory, technical, environmental, economic, and special issues at each project were investgated, and the conclusions relative to each issue are presented. The major barriers preventing the growth of energy storage are the high cost of these systems in times of extremely high cost of capital, diminishing load growth and regulatory influences which will not allow the building of large-scale storage systems due to environmental objections or other reasons. However, the future for energy storage looks viable despite difficult economic times for the utility industry. Joint-ownership can ease some of the economic hardships for utilites which demonstrate a need for energy storage.

Projected costs of generating electricity

International Nuclear Information System (INIS)

2005-01-01

Previous editions of Projected Costs of Generating Electricity have served as the reference in this field for energy policy makers, electricity system analysts and energy economists. The study is particularly timely in the light of current discussions of energy policy in many countries. The joint IEA/NEA study provides generation cost estimates for over a hundred power plants that use a variety of fuels and technologies. These include coal-fired, gas-fired, nuclear, hydro, solar and wind plants. Cost estimates are also given for combined heat and power plants that use coal, gas and combustible renewables. Data and information for this study were provided by experts from 19 OECD member countries and 3 non-member countries. The power plants examined in the study use technologies available today and considered by participating countries as candidates for commissioning by 2010-2015 or earlier. Investors and other decision makers will also need to take the full range of other factors into account (such as security of supply, risks and carbon emissions) when selecting an electricity generation technology. The study shows that the competitiveness of alternative generation sources and technologies ultimately depends on many parameters: there is no clear-cut ''winner''. Major issues related to generation costs addressed in the report include: descriptions of state-of-the-art generation technologies; the methodologies for incorporating risk in cost assessments; the impact of carbon emission trading; and how to integrate wind power into the electricity grid. An appendix to the report provides country statements on generation technologies and costs. Previous studies in the series were published in 1983, 1986, 1990, 1993 and 1998. (author)

Impact of power purchases from non-utilities on the utility cost of capital

International Nuclear Information System (INIS)

Kahn, E.; Stoft, S.; Belden, T.

1995-01-01

The bond rating agencies in the USA have asserted that long-term power purchase contracts between non-utility generators and utilities are the equivalent of debt to the utilities, and therefore raise the cost of capital to the purchaser. Non-Utility generators claim that these contracts reduce risk to the utilities. This debate is reflected in the 1992 Energy Policy Act. This paper investigates this controversy from the perspective of the equity markets. Using a CAPM framework, various specifications of the cost of equity capital are estimated, to shed light on this question. No evidence is found for the hypothesis that non-utility generation contracts raise the cost of capital. There does appear to be a slight increase in this cost for those utilities seeking to build their own generation capacity as opposed to purchasing it from non-utility suppliers. (author)

Real business of electrical skill

International Nuclear Information System (INIS)

1981-03-01

This book introduces electrical structure and duty of electric security officials with definition, kinds, safe system for electrical structure and position, mission, duty, license and revocation of one's license of officials. It also deals with plan for non utility electric installation such as condition control, the cost of materials and the cost of construction, important equipment and materials, supervisory control, design on non utility power substation, construction of non utility power substation, high voltage substation by cubicle interior wiring, utilization equipment, communication installation and safe work and safe education of electricity and related regulations.

The marginal costs like reference for the decision of electric energy cogeneration in Brazil

International Nuclear Information System (INIS)

Silva, D.B. da; Eduardo, J.H.B.P.

1987-01-01

The electric cogeneration question, in a form of optimal utilization of high quality chemical energy in some industrial processes, or a form of employment of any others feedstocks, can be discussed on economics view, with the marginal costs reference, actually in implantation in Brazilian Electrical Sector. In this article, some ideas are presented about the mentioned discussion, in the Brazilian Electric Sector ambient, including analysis of laws and proposed directions for its modifications, looking for the cogeneration activity development in Brazil. (author)

Cost-optimal electricity systems with increasing renewable energy penetration for islands across the globe

NARCIS (Netherlands)

Blok, K.; van Velzen, Leonore

2018-01-01

Cost-optimal electricity system configurations with increasing renewable energy penetration were determined in this article for six islands of different geographies, sizes and contexts, utilizing photovoltaic energy, wind energy, pumped hydro storage and battery storage. The results of the

VT Electric Utility Franchise Areas

Data.gov (United States)

Vermont Center for Geographic Information — (Link to Metadata) ELCFRANCHISE includes Vermont's Electric Utility Franchise boundaries. It is a compilation of many data sources. The boundaries are approximate...

Projected cost comparison of nuclear electricity

International Nuclear Information System (INIS)

Juhn, P.E.; Hu, C.W.

2000-01-01

Comparison of electricity generation costs has been done in the late years through a large co-operation between several organisations. The studies are aiming to provide reliable comparison of electricity generating costs of nuclear and conventional base load power plants. This paper includes the result of the joint IAEA/OECD study published in 1997. (author)

Spot markets vs. long-term contracts - modelling tools for regional electricity generating utilities

International Nuclear Information System (INIS)

Grohnheit, P.E.

1999-01-01

A properly organised market for electricity requires that some information will be available for all market participants. Also a range of generally available modelling tools are necessary. This paper describes a set of simple models based on published data for analyses of the long-term revenues of regional utilities with combined heat and power generation (CHP), who will operate a competitive international electricity market and a local heat market. The future revenues from trade on the spot market is analysed using a load curve model, in which marginal costs are calculated on the basis of short-term costs of the available units and chronological hourly variations in the demands for electricity and heat. Assumptions on prices, marginal costs and electricity generation by the different types of generating units are studied for selected types of local electricity generators. The long-term revenue requirements to be met by long-term contracts are analysed using a traditional techno-economic optimisation model focusing on technology choice and competition among technologies over 20.30 years. A possible conclusion from this discussion is that it is important for the economic and environmental efficiency of the electricity market that local or regional generators of CHP, who are able to react on price signals, do not conclude long-term contracts that include fixed time-of-day tariff for sale of electricity. Optimisation results for a CHP region (represented by the structure of the Danish electricity and CHP market in 1995) also indicates that a market for CO 2 tradable permits is unlikely to attract major non-fossil fuel technologies for electricity generation, e.g. wind power. (au)

The external costs of electricity

International Nuclear Information System (INIS)

Rabl, A.; Spadaro, J.V.

2001-01-01

This article presents an overview of the ExtrenE project (external costs of electricity) of the European Commission (EC). The damage caused by pollution has been calculated through analyses of the impact pathways which involve an analysis of the emission - dispersion - dose-response function - monetary estimation chain. The results are introduced for various cycles of combustible fuels (with several technological variants), indicating the confidence intervals. The cost of the damage is particularly high for coal. For example, for the coal-fired power stations in France (with the emission levels of 1995) it is approximately equal to the sales price of electricity. For natural gas, the cost of damage is approximately one-third that of coal. On the other hand, the damage costs for nuclear fuel and most forms of renewable energy are low, at a maximum just a few percent of the electricity price. The greatest part of these costs arises from health impact, particularly premature death. In order to avoid the controversy inherent in making a monetary assessment of mortality, especially if this is imposed upon future generations, the reduction in life expectancy due to the various combustible cycles is also indicated and the risks of nuclear energy are put into perspective via several comparisons. (authors)

Modelling the transition from cost-based to bid-based pricing in a deregulated electricity-market

International Nuclear Information System (INIS)

Druce, Donald J.

2007-01-01

Alberta is a province in western Canada with a deregulated electricity-market. Market clearing prices for most hours reflect the cost of either coal-fired or gas-fired thermal generation. Whenever there is a chronic shortage of generation or even a temporary one due to an outage, prices can be bid much higher than fuel costs would suggest. The province of British Columbia borders Alberta to the west and its electric utility, BC Hydro, has a history of trade with the utilities in Alberta. BC Hydro has predominantly hydroelectric resources and large storage reservoirs. Prior to Alberta's deregulation in 1996, BC Hydro was able to enter into mutually beneficial load-factoring contracts with the Alberta utilities. Now, as long as the transmission is available, BC Hydro can buy low priced off-peak coal-fired energy and sell into the high priced periods without having to share the benefits. BC Hydro uses a combination of econometric and Monte Carlo modelling to simulate hourly price-duration curves for Alberta that capture both cost-based and bid-based characteristics. This approach provides a good fit with the stochastic dynamic programming model that BC Hydro has developed for its mid-term hydro scheduling

Health economic studies: an introduction to cost-benefit, cost-effectiveness, and cost-utility analyses.

Science.gov (United States)

Angevine, Peter D; Berven, Sigurd

2014-10-15

Narrative overview. To provide clinicians with a basic understanding of economic studies, including cost-benefit, cost-effectiveness, and cost-utility analyses. As decisions regarding public health policy, insurance reimbursement, and patient care incorporate factors other than traditional outcomes such as satisfaction or symptom resolution, health economic studies are increasingly prominent in the literature. This trend will likely continue, and it is therefore important for clinicians to have a fundamental understanding of the common types of economic studies and be able to read them critically. In this brief article, the basic concepts of economic studies and the differences between cost-benefit, cost-effectiveness, and cost-utility studies are discussed. An overview of the field of health economic analysis is presented. Cost-benefit, cost-effectiveness, and cost-utility studies all integrate cost and outcome data into a decision analysis model. These different types of studies are distinguished mainly by the way in which outcomes are valued. Obtaining accurate cost data is often difficult and can limit the generalizability of a study. With a basic understanding of health economic analysis, clinicians can be informed consumers of these important studies.

Financial statistics major US publicly owned electric utilities 1996

Energy Technology Data Exchange (ETDEWEB)

NONE

1998-03-01

The 1996 edition of The Financial Statistics of Major US Publicly Owned Electric Utilities publication presents 5 years (1992 through 1996) of summary financial data and current year detailed financial data on the major publicly owned electric utilities. The objective of the publication is to provide Federal and State governments, industry, and the general public with current and historical data that can be used for policymaking and decision making purposes related to publicly owned electric utility issues. Generator and nongenerator summaries are presented in this publication. Five years of summary financial data are provided. Summaries of generators for fiscal years ending June 30 and December 31, nongenerators for fiscal years ending June 30 and December 31, and summaries of all respondents are provided. The composite tables present aggregates of income statement and balance sheet data, as well as financial indicators. Composite tables also display electric operation and maintenance expenses, electric utility plant, number of consumers, sales of electricity, and operating revenue, and electric energy account data. 2 figs., 32 tabs.

X - FACTOR EVALUATION UNDER RPI-X REGULATION FOR INDIAN ELECTRICITY DISTRIBUTION UTILITIES

Directory of Open Access Journals (Sweden)

PAVAN KHETRAPAL

2017-07-01

Full Text Available With regulators’ growing interest in improving operational efficiency and quality supply, the time is nearing when performance based regulation will become norm for regulating the distribution tariff in Indian electricity distribution sector. In this context, the State Electricity Regulatory Commissions proposed replacing rate-of-return regulation with most commonly used performance based regulatory regime, i.e., Price Cap regulation also known as RPI-X (Retail Price Index - Productivity Offset regulatory framework. However, the potential problem associated with applying price cap regulation scheme in practice is the determination of productivity offset or X factor used in price caps setting. This paper proposed an approach to calculate the X-factor for 58 government-owned and privately-owned electricity distribution utilities in India during a five year period from 2007/08 to 2011/12. A Stochastic Frontier model through an input distance function is first applied to compute the Malmquist Total Factor Productivity (TFP and the estimated TFP is then used to calculate the utility-specific X-factor. With rely on calculated X-factor, the distribution utilities would be able to cap either on prices or revenues thus accounting the inflation in the tariff determination. This will be more realistic approach as compared to cost plus approach.

The role of utilities in developing low carbon, electric megacities

International Nuclear Information System (INIS)

Kennedy, Chris; Stewart, Iain D.; Facchini, Angelo; Mele, Renata

2017-01-01

Development of electric cities, with low carbon power supply, is a key strategy for reducing global CO2 emissions. We analyze the role of electric utilities as important actors to catalyze the transition to electric cites, drawing upon data for the world's 27 megacities. Progress towards the ideal electric city is most advanced for Paris, Rio de Janeiro, Sao Paulo and Buenos Aires for low carbon electricity, while Indian megacities have relatively high use of carbon-intensive electricity as a percentage of total energy use. There is wide variety in the structure of markets for electricity provision in megacities, with a dominant, public utility being the most common model. We review literature on electricity sector business models and broadly propose future models dependent on the predominance of locally dispersed generation and the nature of the ownership of the electric grid within the city. Where a high proportion of electricity can be provided by locally distributed supply within a city, the role of utilities could predominantly become that of enabler of exchange with the grid, but new pricing structures are required. A further challenge for utilities in enabling the electric city is to provide a higher level of resilience to events that disrupt power supply. - Highlights: • Amongst 27 megacities, Paris, Rio, Sao Paulo and Buenos Aires are most progressed low carbon electric cities. • Indian megacities have relatively high use of electricity as a percentage of total energy use. • Wide variety in electricity market structure in megacities; dominant, public utility the most common model. • Utilities could become enablers of exchange with the grid, but new pricing models required.

Electrical energy market management in deregulated power system

International Nuclear Information System (INIS)

Abady, A. F.; Niknam, T.

2003-01-01

For many decades, vertically integrated electric utilities monopolized the way they control, sell and distribute electricity to customers in their service territories. In this monopoly, each utility managed three main components of the system: generation, transmission and distribution. Analogous to perceived competitions in airline, communication and natural gas industries which demonstrated that vertically integrated monopolies could not provide services as efficiently as competitive firms, the electric power industry plans to improve its efficiency by providing a more reliable energy at least cost to customers. A competition is guaranteed by establishing a restructured environment in which customers could choose to buy from different suppliers and change suppliers as they wish in order to pay market base rates. This paper is dealing with progressive approach of restructuring in power and introduce ISO, its functions and model of electrical energy markets

Impact of Neuromuscular Electrical Stimulation (NMES) on 90-Day Episode Costs and Post-Acute Care Utilization in Total Knee Replacement Patients with Disuse Atrophy.

Science.gov (United States)

Pal, Sarmistha; Chughtai, Morad; Sultan, Assem A; Khlopas, Anton; Sodhi, Nipun; George, Nicole E; Etcheson, Jennifer I; Gwam, Chukwuweike U; Newman, Jared M; Samuel, Linsen T; Bhave, Anil; DaVanzo, Joan E; Mont, Michael A

2017-12-22

This study evaluated differences in: 1) total episode payments, 2) probability of hospital readmission, 3) probability of inpatient rehab facility (IRF) and utilization, and 4) probability of skilled nursing care facility (SNF) utilization in patients who had disuse atrophy and underwent a total knee arthroplasty (TKA) and either did, or did not, receive preoperative home-based neuromuscular electrical stimulation (NMES) therapy. We used the Medicare limited dataset for a 5% sample of beneficiaries from 2014 and 2015 to construct episodes-of-care for TKA (DRG-470) patients with disuse atrophy who underwent a TKA during the 30 days prior to hospital admission and 90 days post-discharge. Patients were stratified into those who either did or did not receive pre- and postoperative NMES therapy. An ordinary least square (OLS) model was used to estimate the impact of NMES on total episode. Linear probability models were used to estimate the impact of NMES on SNF or IRF utilization and readmission. A $3,274 reduction in episode payments for patients who used preoperative NMES versus those who did not (ptotal episode payments and SNF utilization for TKA patients with disuse atrophy who had NMES therapy was demonstrated.

Least cost pathways to a low carbon electricity system for Australia: impacts of transmission augmentation and extension

Science.gov (United States)

Dargaville, R. J.

2016-12-01

Designing the pathway to a low carbon energy system is complex, requiring consideration of the variable nature of renewables at the hourly timescale, emission intensity and ramp rate constraints of dispatchable technologies (both fossil and renewable) and transmission and distribution network limitations. In this work, an optimization framework taking into account these considerations has been applied to find the lowest cost ways to reduce carbon emissions by either 80% or 100% in 2050 while keeping the system operating reliably along the way. Technologies included are existing and advanced coal and gas technologies (with and without carbon capture and storage), rooftop PV, utility scale PV, concentrating solar thermal, hydro with and without pumped storage, bioenergy, and nuclear. In this study we also also the optimisation to increase transmission capacity along existing lines, and to extend key trunk lines into currently unserved areas. These augementations and extensions come at a cost. The otpimisation chooses these options when the benefits of accessing high quality renewable energy resources outweights the costs. Results show that for the 80% emission reduction case, there is limited need for transmission capacity increase, and that the existing grid copes well with the increased flows due to conversion to distrubuted renewable energy resources. However, in the 100% case the increased reliance on renewables means that signficant transmission augmentation is beneficial to the overall cost. This strongly suggests that it is important to understand the long term emission target early so that infrastructure investments can be optimised.

Reference costs of the electric power production; Couts de reference de la production electrique

Energy Technology Data Exchange (ETDEWEB)

NONE

2003-06-01

This study periodically realized by the DGEMP aims to compare the competitiveness of the different channels of electric power production, for different utilization conditions. The first part ''reference costs of the 2003 electric power production'' examines the prices of the electric power produced by different channels in particular in the framework of the industrial implementing in 2015. The nuclear and thermal power plants are concerned. The second part is devoted to the decentralized production channels (wind energy, photovoltaic, cogeneration heat-electricity) is under construction and will be presented next year. (A.L.B.)

Controllable and affordable utility-scale electricity from intermittent wind resources and compressed air energy storage (CAES)

International Nuclear Information System (INIS)

Cavallo, Alfred

2007-01-01

World wind energy resources are substantial, and in many areas, such as the US and northern Europe, could in theory supply all of the electricity demand. However, the remote or challenging location (i.e. offshore) and especially the intermittent character of the wind resources present formidable barriers to utilization on the scale required by a modern industrial economy. All of these technical challenges can be overcome. Long distance transmission is well understood, while offshore wind technology is being developed rapidly. Intermittent wind power can be transformed to a controllable power source with hybrid wind/compressed air energy storage (CAES) systems. The cost of electricity from such hybrid systems (including transmission) is affordable, and comparable to what users in some modern industrial economies already pay for electricity. This approach to intermittent energy integration has many advantages compared to the current strategy of forcing utilities to cope with supply uncertainty and transmission costs. Above all, it places intermittent wind on an equal technical footing with every other generation technology, including nuclear power, its most important long-term competitor

Business case for implementing two ergonomic interventions at an electric power utility.

Science.gov (United States)

Seeley, Patricia A; Marklin, Richard W

2003-09-01

Ergonomics analysis of line workers in the electric power industry who work overhead on utility poles revealed some tasks for which less than 1% of the general population had sufficient strength to perform. During a 2-year study, a large Midwestern US electric utility provided a university with a team of represented workers and management. They evaluated, recommended, and monitored interventions for 32 common line worker tasks that were rated at medium to high magnitude of risk factors for musculoskeletal disorders (MSDs). Two of the recommended ergonomic interventions-the battery-operated press and cutter-were selected by the team as having the greatest potential for reducing risk factors of MSDs. Only overhead distribution line worker tasks were evaluated. A business case was formulated that took into account medical injury and illness statistics, workers' compensation, replacement worker and retraining costs. An outline of a business case formulation and a sample intervention payback calculation is shown. Based on the business case, the utility committed over US dollars 300000 to purchase battery-operated presses and cutters for their overhead distribution line crews.

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

Energy Technology Data Exchange (ETDEWEB)

None

1980-08-01

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.

Financial statistics of major US publicly owned electric utilities 1992

Energy Technology Data Exchange (ETDEWEB)

1994-01-01

The 1992 edition of the Financial Statistics of Major US Publicly Owned Electric Utilities publication presents 4 years (1989 through 1992) of summary financial data and current year detailed financial data on the major publicly owned electric utilities. The objective of the publication is to provide 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 publicly owned electric utility issues. Generator and nongenerator summaries are presented in this publication. Four years of summary financial data are provided. Summaries of generators for fiscal years ending June 30 and December 31, nongenerators for fiscal years ending June 30 and December 31, and summaries of all respondents are provided. The composite tables present aggregates of income statement and balance sheet data, as well as financial indicators. Composite tables also display electric operation and maintenance expenses, electric utility plant, number of consumers, sales of electricity, and operating revenue, and electric energy account data. The primary source of publicly owned financial data is the Form EIA-412, {open_quotes}Annual Report of Public Electric Utilities.{close_quotes} Public electric utilities file this survey on a fiscal year, rather than a calendar year basis, in conformance with their recordkeeping practices. In previous editions of this publication, data were aggregated by the two most commonly reported fiscal years, June 30 and December 31. This omitted approximately 20 percent of the respondents who operate on fiscal years ending in other months. Accordingly, the EIA undertook a review of the Form EIA-412 submissions to determine if alternative classifications of publicly owned electric utilities would permit the inclusion of all respondents.

A minimum achievable PV electrical generating cost

International Nuclear Information System (INIS)

Sabisky, E.S.

1996-01-01

The role and share of photovoltaic (PV) generated electricity in our nation's future energy arsenal is primarily dependent on its future production cost. This paper provides a framework for obtaining a minimum achievable electrical generating cost (a lower bound) for fixed, flat-plate photovoltaic systems. A cost of 2.8 $cent/kWh (1990$) was derived for a plant located in Southwestern USA sunshine using a cost of money of 8%. In addition, a value of 22 $cent/Wp (1990$) was estimated as a minimum module manufacturing cost/price

Outlook for California's electric utility industry

International Nuclear Information System (INIS)

Frank, S.E.

1996-01-01

This article describes how the Southern California Edison Company deals with revolutionary change as the state's electricity industry reinvents itself. The topics of the article include how competition has make things better for SCEC's employees, customers, and shareholders, and an outline of the principal features of the electric utility industry in California

Perspectives on the future of the electric utility industry

International Nuclear Information System (INIS)

Tonn, B.; Schaffhauser, A.

1994-04-01

This report offers perspectives on the future of the electric utility industry. These perspectives will be used in further research to assess the prospects for Integrated Resource Planning (IRP). The perspectives are developed first by examining economic, political and regulatory, societal, technological, and environmental trends that are (1) national and global in scope and (2) directly related to the electric utility industry. Major national and global trends include increasing global economic competition, increasing political and ethnic strife, rapidly changing technologies, and increasing worldwide concern about the environment. Major trends in the utility industry include increasing competition in generation; changing patterns of electricity demand; increasing use of information technology to control power systems; and increasing implementation of environmental controls. Ways in which the national and global trends may directly affect the utility industry are also explored. The trends are used to construct three global and national scenarios- ''business as usual,'' ''technotopia future,'' and ''fortress state'' -and three electric utility scenarios- ''frozen in headlights,'' ''megaelectric,'' and ''discomania.'' The scenarios are designed to be thought provoking descriptions of potential futures, not predictions of the future, although three key variables are identified that will have significant impacts on which future evolves-global climate change, utility technologies, and competition. While emphasis needs to be placed on understanding the electric utility scenarios, the interactions between the two sets of scenarios is also of interest

Perspectives on the future of the electric utility industry

Energy Technology Data Exchange (ETDEWEB)

Tonn, B. [Oak Ridge National Lab., TN (United States); Schaffhauser, A. [Tennessee Univ., Knoxville, TN (United States)

1994-04-01

This report offers perspectives on the future of the electric utility industry. These perspectives will be used in further research to assess the prospects for Integrated Resource Planning (IRP). The perspectives are developed first by examining economic, political and regulatory, societal, technological, and environmental trends that are (1) national and global in scope and (2) directly related to the electric utility industry. Major national and global trends include increasing global economic competition, increasing political and ethnic strife, rapidly changing technologies, and increasing worldwide concern about the environment. Major trends in the utility industry include increasing competition in generation; changing patterns of electricity demand; increasing use of information technology to control power systems; and increasing implementation of environmental controls. Ways in which the national and global trends may directly affect the utility industry are also explored. The trends are used to construct three global and national scenarios- ``business as usual,`` ``technotopia future,`` and ``fortress state`` -and three electric utility scenarios- ``frozen in headlights,`` ``megaelectric,`` and ``discomania.`` The scenarios are designed to be thought provoking descriptions of potential futures, not predictions of the future, although three key variables are identified that will have significant impacts on which future evolves-global climate change, utility technologies, and competition. While emphasis needs to be placed on understanding the electric utility scenarios, the interactions between the two sets of scenarios is also of interest.

Cost evolution of electric energy in Brazil

International Nuclear Information System (INIS)

Oliveira, A. de; Contreras, E.C.A.

1981-01-01

An analysis of electric energy costs in Brazil is presented. Hydro, coal and nuclear costs are analysed and the final conclusion seems to indicate that nuclear power plants are not economically interesting untill the Brazilian electric capacity attains 110 GW average power. (Author) [pt

Balancing Cost and Risk: The Treatment of Renewable Energy in Western Utility Resource Plans

Energy Technology Data Exchange (ETDEWEB)

Bolinger, Mark; Wiser, Ryan

2005-08-10

Markets for renewable energy have historically been motivated primarily by policy efforts, but a less widely recognized driver is poised to also play a major role in the coming years: utility integrated resource planning (IRP). Resource planning has re-emerged in recent years as an important tool for utilities and regulators, particularly in regions where retail competition has failed to take root. In the western United States, the most recent resource plans contemplate a significant amount of renewable energy additions. These planned additions--primarily coming from wind power--are motivated by the improved economics of wind power, a growing acceptance of wind by electric utilities, and an increasing recognition of the inherent risks (e.g., natural gas price risk, environmental compliance risk) in fossil-based generation portfolios. This report examines how twelve western utilities treat renewable energy in their recent resource plans. In aggregate, these utilities supply approximately half of all electricity demand in the western United States. Our purpose is twofold: (1) to highlight the growing importance of utility IRP as a current and future driver of renewable energy, and (2) to identify methodological/modeling issues, and suggest possible improvements to methods used to evaluate renewable energy as a resource option. Here we summarize the key findings of the report, beginning with a discussion of the planned renewable energy additions called for by the twelve utilities, an overview of how these plans incorporated renewables into candidate portfolios, and a review of the specific technology cost and performance assumptions they made, primarily for wind power. We then turn to the utilities' analysis of natural gas price and environmental compliance risks, and examine how the utilities traded off portfolio cost and risk in selecting a preferred portfolio.

The Effects of Rising Interest Rates on Electric Utility Stock Prices: Regulatory Considerations and Approaches

Energy Technology Data Exchange (ETDEWEB)

Kihm, Steve [Seventhwave, Madison, WI (United States); Satchwell, Andrew [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States); Cappers, Peter [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States)

2017-07-26

This technical brief identifies conditions under which utility regulators should consider implementing policy approaches that seek to mitigate negative outcomes due to an increase in interest rates. Interest rates are a key factor in determining a utility’s cost of equity and investors find value when returns exceed the cost of equity. Through historical observations of periods of rising and falling interest rates and application of a pro forma financial tool, we identify the key drivers of utility stock valuations and estimate the degree to which those valuations might be affected by increasing interest rates.3 We also analyze the efficacy of responses by utility regulators to mitigate potential negative financial impacts. We find that regulators have several possible approaches to mitigate a decline in value in an environment of increasing interest rates, though regulators must weigh the tradeoffs of improving investor value with potential increases in customer costs. Furthermore, the range of approaches reflects today’s many different electric utility regulatory models and regulatory responses to a decline in investor value will fit within state-specific models.

Financial statistics of major US investor-owned electric utilities 1994

Energy Technology Data Exchange (ETDEWEB)

NONE

1995-12-01

The Financial Statistics of Major U.S. 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 Federal and State Governments, industry, and the general public with current and historical data that can be used for making policy and decisions relating to investor-owned electric utility issues.

Overview of U.S. electric utilities: Transmission and distribution systems

International Nuclear Information System (INIS)

Brown, R.D.

1994-01-01

I hope this brief description of the US electric utility industry has been interesting and informative. No doubt many characteristics, concerns, and research efforts mirror those of the electric utility industry in South Korea. It is hoped that through workshops such as this that electric utilities, manufacturers and consultants may learn from each other for the mutual benefit of all

Utility-Scale Solar 2014. An Empirical Analysis of Project Cost, Performance, and Pricing Trends in the United States

Energy Technology Data Exchange (ETDEWEB)

Bolinger, Mark [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States); Seel, Joachim [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States)

2015-09-01

Other than the nine Solar Energy Generation Systems (“SEGS”) parabolic trough projects built in the 1980s, virtually no large-scale or “utility-scale” solar projects – defined here to include any groundmounted photovoltaic (“PV”), concentrating photovoltaic (“CPV”), or concentrating solar thermal power (“CSP”) project larger than 5 MW_AC – existed in the United States prior to 2007. By 2012 – just five years later – utility-scale had become the largest sector of the overall PV market in the United States, a distinction that was repeated in both 2013 and 2014 and that is expected to continue for at least the next few years. Over this same short period, CSP also experienced a bit of a renaissance in the United States, with a number of large new parabolic trough and power tower systems – some including thermal storage – achieving commercial operation. With this critical mass of new utility-scale projects now online and in some cases having operated for a number of years (generating not only electricity, but also empirical data that can be mined), the rapidly growing utility-scale sector is ripe for analysis. This report, the third edition in an ongoing annual series, meets this need through in-depth, annually updated, data-driven analysis of not just installed project costs or prices – i.e., the traditional realm of solar economics analyses – but also operating costs, capacity factors, and power purchase agreement (“PPA”) prices from a large sample of utility-scale solar projects in the United States. Given its current dominance in the market, utility-scale PV also dominates much of this report, though data from CPV and CSP projects are presented where appropriate.

Projected costs of electricity generation

International Nuclear Information System (INIS)

Cameron, R.

2010-01-01

This paper describes the outcomes of a study on the projected costs of generating electricity. It presents the latest data available on electricity generating costs for a wide variety of fuels and technologies, including coal, gas, nuclear, hydro, onshore and offshore wind, biomass, solar, wave and tidal. The study reaches 2 key conclusions. First, at a 5% real interest rate, nuclear energy is the most competitive solution for base-load electricity generation followed by coal-fired plants without carbon capture and natural gas-fired combined plants. It should be noted that coal with carbon capture has not reached a commercial phase. Second, at a 10% interest rate, nuclear remains the most competitive in Asia and North America but in Europe, coal without carbon capture equipment, followed by coal with carbon capture equipment, and gas-fired combined cycle turbines are overall more competitive than nuclear energy. The results highlight the paramount importance of interest rates (this dependence is a direct consequence of the nuclear energy's high capital costs) and of the carbon price. For instance if we assume a 10% interest rate and a cost of 50 dollar per tonne of CO 2 , nuclear energy would become competitive against both coal and gas. (A.C.)

Estimated Value of Service Reliability for Electric Utility Customers in the United States

Energy Technology Data Exchange (ETDEWEB)

Sullivan, M.J.; Mercurio, Matthew; Schellenberg, Josh

2009-06-01

Information on the value of reliable electricity service can be used to assess the economic efficiency of investments in generation, transmission and distribution systems, to strategically target investments to customer segments that receive the most benefit from system improvements, and to numerically quantify the risk associated with different operating, planning and investment strategies. This paper summarizes research designed to provide estimates of the value of service reliability for electricity customers in the US. These estimates were obtained by analyzing the results from 28 customer value of service reliability studies conducted by 10 major US electric utilities over the 16 year period from 1989 to 2005. Because these studies used nearly identical interruption cost estimation or willingness-to-pay/accept methods it was possible to integrate their results into a single meta-database describing the value of electric service reliability observed in all of them. Once the datasets from the various studies were combined, a two-part regression model was used to estimate customer damage functions that can be generally applied to calculate customer interruption costs per event by season, time of day, day of week, and geographical regions within the US for industrial, commercial, and residential customers. Estimated interruption costs for different types of customers and of different duration are provided. Finally, additional research and development designed to expand the usefulness of this powerful database and analysis are suggested.

Cost estimate of electricity produced by TPV

Science.gov (United States)

Palfinger, Günther; Bitnar, Bernd; Durisch, Wilhelm; Mayor, Jean-Claude; Grützmacher, Detlev; Gobrecht, Jens

2003-05-01

A crucial parameter for the market penetration of TPV is its electricity production cost. In this work a detailed cost estimate is performed for a Si photocell based TPV system, which was developed for electrically self-powered operation of a domestic heating system. The results are compared to a rough estimate of cost of electricity for a projected GaSb based system. For the calculation of the price of electricity, a lifetime of 20 years, an interest rate of 4.25% per year and maintenance costs of 1% of the investment are presumed. To determine the production cost of TPV systems with a power of 12-20 kW, the costs of the TPV components and 100 EUR kW-1el,peak for assembly and miscellaneous were estimated. Alternatively, the system cost for the GaSb system was derived from the cost of the photocells and from the assumption that they account for 35% of the total system cost. The calculation was done for four different TPV scenarios which include a Si based prototype system with existing technology (etasys = 1.0%), leading to 3000 EUR kW-1el,peak, an optimized Si based system using conventional, available technology (etasys = 1.5%), leading to 900 EUR kW-1el,peak, a further improved system with future technology (etasys = 5%), leading to 340 EUR kW-1el,peak and a GaSb based system (etasys = 12.3% with recuperator), leading to 1900 EUR kW-1el,peak. Thus, prices of electricity from 6 to 25 EURcents kWh-1el (including gas of about 3.5 EURcents kWh-1) were calculated and compared with those of fuel cells (31 EURcents kWh-1) and gas engines (23 EURcents kWh-1).

A cost-effectiveness and cost-utility analysis of radiosurgery vs. resection for single-brain metastases

International Nuclear Information System (INIS)

Mehta, Minesh; Noyes, William; Craig, Bruce; Lamond, John; Auchter, Richard; French, Molly; Johnson, Mark; Levin, Allan; Badie, Behnam; Robbins, Ian; Kinsella, Timothy

1997-01-01

Purpose: The median survival of well-selected patients with single-brain metastases treated with whole-brain irradiation and resection or radiosurgery is comparable, although a randomized trial of these two modalities has not been performed. In this era of cost containment, it is imperative that health-care professionals make fiscally prudent decisions. The present environment necessitates a critical appraisal of apparently equi-efficacious therapeutic modalities, and it is within this context that we present a comparison of the actual costs of resection and radiosurgery for brain metastases. Methods and Materials: Survival and quality of life outcome data for radiation alone or with surgery were obtained from two randomized trials, and radiosurgical results were obtained from a multiinstitutional analysis that specifically evaluated patients meeting surgical criteria. Only linear accelerator radiosurgery data were considered. Cost analysis was performed from a societal view point, and the following parameters were evaluated: actual cost, cost ratios, cost effectiveness, incremental cost effectiveness, cost utility, incremental cost utility, and national cost burden. The computerized billing records for all patients undergoing resection or radiosurgery for single-brain metastases from January 1989 to July 1994 were reviewed. A total of 46 resections and 135 radiosurgery procedures were performed. During the same time period, 454 patients underwent whole-brain radiation alone. An analysis of the entire bill was performed for each procedure, and each itemized cost was assigned a proportionate figure. The relative cost ratios of resection and radiosurgery were compared using the Wilcoxon rank sum test. Cost effectiveness of each modality, defined as the cost per year of median survival, was evaluated. Incremental cost effectiveness, defined as the additional cost per year of incremental gain in median survival, compared to the next least expensive modality, was also

Financial statistics of major US publicly owned electric utilities 1994

Energy Technology Data Exchange (ETDEWEB)

NONE

1995-12-15

This publication presents 5 years (1990--94) of summary financial data and current year detailed financial data on the major publicly owned electric utilities. Generator and nongenerator summaries are presented. Composite tables present: Aggregates of income statement and balance sheet data, financial indicators, electric operation and maintenance expenses, electric utility plant, number of consumers, sales of electricity, and operating revenue, and electric energy account data.

Financial statistics of major US publicly owned electric utilities 1994

International Nuclear Information System (INIS)

1995-01-01

This publication presents 5 years (1990--94) of summary financial data and current year detailed financial data on the major publicly owned electric utilities. Generator and nongenerator summaries are presented. Composite tables present: Aggregates of income statement and balance sheet data, financial indicators, electric operation and maintenance expenses, electric utility plant, number of consumers, sales of electricity, and operating revenue, and electric energy account data

Modelling the transition from cost-based to bid-based pricing in a deregulated electricity-market

Energy Technology Data Exchange (ETDEWEB)

Druce, Donald J. [BC Hydro, 6911 Southpoint Drive, Burnaby, British Columbia (Canada)

2007-12-15

Alberta is a province in western Canada with a deregulated electricity-market. Market clearing prices for most hours reflect the cost of either coal-fired or gas-fired thermal generation. Whenever there is a chronic shortage of generation or even a temporary one due to an outage, prices can be bid much higher than fuel costs would suggest. The province of British Columbia borders Alberta to the west and its electric utility, BC Hydro, has a history of trade with the utilities in Alberta. BC Hydro has predominantly hydroelectric resources and large storage reservoirs. Prior to Alberta's deregulation in 1996, BC Hydro was able to enter into mutually beneficial load-factoring contracts with the Alberta utilities. Now, as long as the transmission is available, BC Hydro can buy low priced off-peak coal-fired energy and sell into the high priced periods without having to share the benefits. BC Hydro uses a combination of econometric and Monte Carlo modelling to simulate hourly price-duration curves for Alberta that capture both cost-based and bid-based characteristics. This approach provides a good fit with the stochastic dynamic programming model that BC Hydro has developed for its mid-term hydro scheduling. (author)

Electric utilities in Illinois

Energy Technology Data Exchange (ETDEWEB)

1978-01-01

Although the conference dealt specifically with concerns of the electric utilities in Illinois, the issues were dealt with in the national context as well. A separate abstract was prepared for each of the 5 sections of this proceeding. A total of 25 papers were presented. Section titles are: Forecasting, Planning and Siting, Reliability, Rates and Financing, and Future Developments.

Laboratory cost and utilization containment.

Science.gov (United States)

Steiner, J W; Root, J M; White, D C

1991-01-01

The authors analyzed laboratory costs and utilization in 3,771 cases of Medicare inpatients admitted to a New England academic medical center ("the Hospital") from October 1, 1989 to September 30, 1990. The data were derived from the Hospital's Decision Resource System comprehensive data base. The authors established a historical reference point for laboratory costs as a percentage of total inpatient costs using 1981-82 Medicare claims data and cost report information. Inpatient laboratory costs were estimated at 9.5% of total inpatient costs for pre-Diagnostic Related Groups (DRGs) Medicare discharges. Using this reference point and adjusting for the Hospital's 1990 case mix, the "expected" laboratory cost was 9.3% of total cost. In fact, the cost averaged 11.5% (i.e., 24% above the expected cost level), and costs represented an even greater percentage of DRG reimbursement at 12.9%. If we regard the reimbursement as a total cost target (to eliminate losses from Medicare), then that 12.9% is 39% above the "expected" laboratory proportion of 9.3%. The Hospital lost an average of $1,091 on each DRG inpatient. The laboratory contributed 29% to this loss per case. Compared to other large hospitals, the Hospital was slightly (3%) above the mean direct cost per on-site test and significantly (58%) above the mean number of inpatient tests per inpatient day compared to large teaching hospitals. The findings suggest that careful laboratory cost analyses will become increasingly important as the proportion of patients reimbursed in a fixed manner grows. The future may hold a prospective zero-based laboratory budgeting process based on predictable patterns of DRG admissions or other fixed-reimbursement admission and laboratory utilization patterns.

Electric utilities and the demand for natural gas

Energy Technology Data Exchange (ETDEWEB)

Uri, N D; Atkinson, S

1976-03-01

The scarcity of natural gas has given rise to a series of priorities of deliveries based on end use and drafted by the Federal Power Commission. The U.S. Supreme Court, on June 7, 1972, held that the Commission has jurisdiction over curtailments in the service of gas in interstate commerce to both resale and direct industrial customers. This decision reversed a Fifth Circuit Court ruling that protected direct industrial customers from curtailments. The FPC priority curtailments are classed from 1 to 9, for which electric utilities are concentrated in classes 4 to 9. As weather conditions become more severe, not only do the residential and commercial consumers demand more electrical energy, they also demand more natural gas. The result is that there is less natural gas available for electric utilities to use for generation so they change to an alternative fuel. A demand model for the short term for natural gas for electric utilities is given; primary factors involve the price of natural gas, the prices of substitute fuels, and the demand for electrical energy by the various consumer classes. (MCW)

Utilization of uranium cost/benefit study for nuclear powered merchant ships. Special study

International Nuclear Information System (INIS)

Smith, E.R.

1977-05-01

This study presents a cost/benefit analysis for the utilization of uranium in merchant ships versus the use of uranium for the generation of electricity in central power stations. The study concludes that an alternative naval fuel to oil must be developed for the merchant marine to reduce U.S. dependency upon foreign supplies of a critical fuel. The study further indicates that use of uranium for ship propulsion results in transport of large quantities of needed import/exports while the residual oil saved will generate the same quantity of electricity in a central power station as the uranium used for ship propulsion

Demand for electrical energy

International Nuclear Information System (INIS)

Bergougnoux, J.; Fouquet, D.

1983-01-01

The different utilizations of electric energy are reviewed in the residential and tertiary sectors, in the industry. The competitive position of electricity in regard to other fuels has been strengthned by the sudden rise in the price of oil in 1973-1974 and 1979-1980. The evolution of electricity prices depended on the steps taken to adjust the electricity generation system. The substitution of electricity applications for hydro-carbons is an essential point of energy policy. The adjustment at all times, at least cost and most reliability, of the supply of electricity to the demand for it is a major problem in the design and operation of electric systems. National demand for power at a given moment is extremely diversified. Electricity consumption presents daily and seasonal variations, and variations according to the different sectors. Forecasting power requirements is for any decision on operation or investment relating to an electrical system. Load management is desirable (prices according to the customers, optional tariffs for ''peak-day withdrawal''). To conclude, prospects for increased electricity consumption are discussed [fr

Conference Proceedings: Effectively utilizing energy derivatives in a deregulated electricity market

International Nuclear Information System (INIS)

1998-01-01

This conference was devoted to a discussion about the likely impacts of deregulation on electricity markets in North America. Many of the presentations emphasized price risk in a competitive open access energy market. It was noted that deregulation is frequently associated with the creation of larger companies, higher risks and lower costs. Some of the individual topics addressed by the speakers included discussion of : (1) how underlying physical markets will work in Ontario, (2) experiences in derivative trading in the natural gas industry, (3) how to create value through multiple commodity risk management products, (4) trading with energy derivatives in the U.S. (5) how derivatives can add value for municipal electrical utilities, and (6) risk management mechanisms for energy derivative trading. refs., tabs., figs

Cost-benefit assessment of energy storage for utility and customers: A case study in Malaysia

International Nuclear Information System (INIS)

Chua, Kein Huat; Lim, Yun Seng; Morris, Stella

2015-01-01

Highlights: • Energy storage can replace the peaking plants. • The cost of electricity for the plants with energy storage is as competitive as fossil fuel power plants. • Energy storage can reduce CO_2 emissions and defer the reinforcement of transmissions and distributions infrastructure. • Energy storage can reduce peak demand charge for customers. - Abstract: Under the existing commercial framework of electricity in Malaysia, commercial and industrial customers are required to pay for the peak power demand charge every month. Usually, the peak demand charge can contribute up to 30% to their electricity bills due to the use of open-cycle gas power plants that deliver expensive electricity to the customers. Therefore, alternative means are sought after in order to reduce the peak demand for the customers. Distributed small-scaled energy storage can offer a good option to reduce the peak. This paper aims to identify the financial benefits of the energy storage system for utility companies and customers. An energy dispatch model is developed in HOMER to determine the cost of electricity. The model considers the heat rates of power plants in calculating the costs of electricity under different regulatory frameworks of natural gas with various prices of battery components. Apart from that, the cost-benefit for the customers under various electric tariff structures is evaluated. Four battery storage technologies, namely lead acid, vanadium redox flow, zinc-bromine, and lithium-ion are considered. The simulation results show that the storage system with lead acid batteries is more cost-effective than other battery technologies. The customers can reduce their electricity bills with the payback period of 2.8 years. The generation cost for the power system with energy storage is lower than that without energy storage. Besides, the system with energy storage has lower greenhouse gas emissions than that without energy storage. The deferral of the reinforcement of

Financial statistics of major U.S. publicly owned electric utilities 1997

Energy Technology Data Exchange (ETDEWEB)

NONE

1998-12-01

The 1997 edition of the ``Financial Statistics of Major U.S. Publicly Owned Electric Utilities`` publication presents 5 years (1993 through 1997) of summary financial data and current year detailed financial data on the major publicly owned electric utilities. The objective of the publication is to provide 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 publicly owned electric utility issues. Generator (Tables 3 through 11) and nongenerator (Tables 12 through 20) summaries are presented in this publication. Five years of summary financial data are provided (Tables 5 through 11 and 14 through 20). Summaries of generators for fiscal years ending June 30 and December 31, nongenerators for fiscal years ending June 30 and December 31, and summaries of all respondents are provided in Appendix C. The composite tables present aggregates of income statement and balance sheet data, as well as financial indicators. Composite tables also display electric operation and maintenance expenses, electric utility plant, number of consumers, sales of electricity, operating revenue, and electric energy account data. The primary source of publicly owned financial data is the Form EIA-412, ``Annual Report of Public Electric Utilities.`` Public electric utilities file this survey on a fiscal year basis, in conformance with their recordkeeping practices. The EIA undertook a review of the Form EIA-412 submissions to determine if alternative classifications of publicly owned electric utilities would permit the inclusion of all respondents. The review indicated that financial indicators differ most according to whether or not a publicly owned electric utility generates electricity. Therefore, the main body of the report provides summary information in generator/nongenerator classifications. 2 figs., 101 tabs.

Financial statistics of major U.S. publicly owned electric utilities 1997

International Nuclear Information System (INIS)

1998-12-01

The 1997 edition of the ''Financial Statistics of Major U.S. Publicly Owned Electric Utilities'' publication presents 5 years (1993 through 1997) of summary financial data and current year detailed financial data on the major publicly owned electric utilities. The objective of the publication is to provide 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 publicly owned electric utility issues. Generator (Tables 3 through 11) and nongenerator (Tables 12 through 20) summaries are presented in this publication. Five years of summary financial data are provided (Tables 5 through 11 and 14 through 20). Summaries of generators for fiscal years ending June 30 and December 31, nongenerators for fiscal years ending June 30 and December 31, and summaries of all respondents are provided in Appendix C. The composite tables present aggregates of income statement and balance sheet data, as well as financial indicators. Composite tables also display electric operation and maintenance expenses, electric utility plant, number of consumers, sales of electricity, operating revenue, and electric energy account data. The primary source of publicly owned financial data is the Form EIA-412, ''Annual Report of Public Electric Utilities.'' Public electric utilities file this survey on a fiscal year basis, in conformance with their recordkeeping practices. The EIA undertook a review of the Form EIA-412 submissions to determine if alternative classifications of publicly owned electric utilities would permit the inclusion of all respondents. The review indicated that financial indicators differ most according to whether or not a publicly owned electric utility generates electricity. Therefore, the main body of the report provides summary information in generator/nongenerator classifications. 2 figs., 101 tabs

The ''reference costs'' of the electrical production

International Nuclear Information System (INIS)

1997-05-01

This study objective is to give an aid for the investments choice in the field of electricity production and for national choices in the field of long-dated production. Important evolutions appeared since the last exercise ''reference costs'' of 1993. Electricity production costs, presented in this study, are actualized economic costs. They consider the following production facilities: nuclear, pulverized coal with fumes processing, circulating fluidized bed, combustion turbines, cogeneration and wind turbines. (A.L.B.)

Network governance in electricity distribution: Public utility or commodity

International Nuclear Information System (INIS)

Kuenneke, Rolf; Fens, Theo

2005-01-01

This paper addresses the question whether the operation and management of electricity distribution networks in a liberalized market environment evolves into a market driven commodity business or might be perceived as a genuine public utility task. A framework is developed to classify and compare different institutional arrangements according to the public utility model and the commodity model. These models are exemplified for the case of the Dutch electricity sector. It appears that the institutional organization of electricity distribution networks is at the crossroads of two very different institutional development paths. They develop towards commercial business if the system characteristics of the electricity sector remain basically unchanged to the traditional situation. If however innovative technological developments allow for a decentralization and decomposition of the electricity system, distribution networks might be operated as public utilities while other energy services are exploited commercially. (Author)

Financial statistics of major US publicly owned electric utilities 1993

Energy Technology Data Exchange (ETDEWEB)

1995-02-01

The 1993 edition of the Financial Statistics of Major U.S. Publicly Owned Electric Utilities publication presents five years (1989 to 1993) of summary financial data and current year detailed financial data on the major publicly owned electric utilities. The objective of the publication is to provide Federal and State governments, industry, and the general public with current and historical data that can be used for policymaking and decision making purposes related to publicly owned electric utility issues. Generator and nongenerator summaries are presented in this publication. The primary source of publicly owned financial data is the Form EIA-412, the Annual Report of Public Electric Utilities, filed on a fiscal basis.

Improving World Health: A Least Cost Strategy. Worldwatch Paper 59.

Science.gov (United States)

Chandler, William U.

Least-cost health strategies designed to attack the world's leading causes of unnecessary death are explored. Section 1 emphasizes the value of primary health-care procedures--midwifery, maternal education on breastfeeding and weaning, vaccinations, oral rehydration of victims of diarrhea, and antibiotics against respiratory infections--in…

The cost of nuclear electricity: economic values and political calculations

International Nuclear Information System (INIS)

Stauffer, T.

1985-01-01

The subject is covered in sections: introduction (monetary inflation; US-style rate-base formula; cost escalation); electricity generation costs (rate-base calculation formula; regulatory versus economic costs; inflationary case; cost-of-service rates versus inflation; first year electricity costs); rate shock (A. comparison with oil; B. nuclear case; C. comparison with coal/nuclear system; vintaged electricity costs versus growth and inflation); conclusions. (U.K.)

Incorporating the cost of protecting the environment into decisions about electric power

International Nuclear Information System (INIS)

Ottinger, R.; Robinson, N.; Wooley, D.

1991-01-01

This paper reviews the range of issues raised by the task of valuing the environmental impacts resulting from generation and conservation of electric power. We review the literature on the methodologies used to assign monetary costs to environmental externalities and present the results of studies which have applied these methodologies. For those environmental damages for which the literature has not established a value, the paper identifies the indicative ranges of adverse effects and provides a map of issues that require research. The paper is intended to assist utilities, government regulators, legislators, policy analysts, and public interest groups in estimating the costs of the environmental impacts of electricity. It should be useful, as well, to assist in valuing the environmental impacts of pollutants from other industries, for setting environmental control standards, and in establishing pollution taxes or fees. (author)

Markets for utility electricity

International Nuclear Information System (INIS)

Brooks, D.B.

1990-01-01

Every analysis of energy use, no matter what the sector or the country, has shown enormous opportunities for cost-effective conservation. Such opportunities should be identified and pursued wherever they appear. Because of its capital intensity and balance-of-payments implications on the supply side, and its potential to improve industrial efficiency and quality of life on the demand side, nowhere are such opportunities more critical than with electricity. Indeed, given the large and unsatisfied demand for electricity in those markets where it can be used efficiently, to ignore those opportunities is to invite ever more serious energy supply and demand problems. (author). 34 refs., 3 tabs., 1 appendix

Electric utility resource expansion planning using environmental externalities

International Nuclear Information System (INIS)

Mitchell, D.

1992-01-01

This paper describes the recent experience of San Diego Gas ampersand Electric Company using environmental externalities in the expansion planning of its electrical system. This is the first time that this method of planning has been used in the electric utility industry in California. The paper reviews the conceptual development of the monetary values for environmental externalities and shows how the application of these values modifies the resource selection process. This paper should be of interest to professionals involved in policy issues relating to the use of environmental externalities as a means to improve the environment. The experience gained through this analyses should also benefit electric utility personnel involved in planning, and regulators interested in planning

Marginal Cost Pricing in a World without Perfect Competition: Implications for Electricity Markets with High Shares of Low Marginal Cost Resources

Energy Technology Data Exchange (ETDEWEB)

Frew, Bethany A. [National Renewable Energy Lab. (NREL), Golden, CO (United States); Clark, Kara [National Renewable Energy Lab. (NREL), Golden, CO (United States); Bloom, Aaron P. [National Renewable Energy Lab. (NREL), Golden, CO (United States); Milligan, Michael [National Renewable Energy Lab. (NREL), Golden, CO (United States)

2017-12-02

A common approach to regulating electricity is through auction-based competitive wholesale markets. The goal of this approach is to provide a reliable supply of power at the lowest reasonable cost to the consumer. This necessitates market structures and operating rules that ensure revenue sufficiency for all generators needed for resource adequacy purposes. Wholesale electricity markets employ marginal-cost pricing to provide cost-effective dispatch such that resources are compensated for their operational costs. However, marginal-cost pricing alone cannot guarantee cost recovery outside of perfect competition, and electricity markets have at least six attributes that preclude them from functioning as perfectly competitive markets. These attributes include market power, externalities, public good attributes, lack of storage, wholesale price caps, and ineffective demand curve. Until (and unless) these failures are ameliorated, some form of corrective action(s) will be necessary to improve market efficiency so that prices can correctly reflect the needed level of system reliability. Many of these options necessarily involve some form of administrative or out-of-market actions, such as scarcity pricing, capacity payments, bilateral or other out-of-market contracts, or some hybrid combination. A key focus with these options is to create a connection between the electricity market and long-term reliability/loss-of-load expectation targets, which are inherently disconnected in the native markets because of the aforementioned market failures. The addition of variable generation resources can exacerbate revenue sufficiency and resource adequacy concerns caused by these underlying market failures. Because variable generation resources have near-zero marginal costs, they effectively suppress energy prices and reduce the capacity factors of conventional generators through the merit-order effect in the simplest case of a convex market; non-convexities can also suppress prices.

Second-order polynomial model to solve the least-cost lumber grade mix problem

Science.gov (United States)

Urs Buehlmann; Xiaoqiu Zuo; R. Edward. Thomas

2010-01-01

Material costs when cutting solid wood parts from hardwood lumber for secondary wood products manufacturing account for 20 to 50 percent of final product cost. These costs can be minimized by proper selection of the lumber quality used. The lumber quality selection problem is referred to as the least-cost lumber grade mix problem in the industry. The objective of this...

Assessing the impact of changes in the electricity price structure on dairy farm energy costs

International Nuclear Information System (INIS)

Upton, J.; Murphy, M.; Shalloo, L.; Groot Koerkamp, P.W.G.; De Boer, I.J.M.

2015-01-01

electricity consumption within a farm was 7% for SF, 5% for MF and 5% for LF. This difference was accounted for by the variation in the milk cooling system coefficient of performance. The greatest scope to reduce total annual electricity costs by adjusting milking start times was on TOU2 (39%, 34% and 33% of total annual electricity costs on the SF, MF and LF) and the least scope for reductions using this method was on the Flat tariff (7%, 5% and 7% of total annual electricity costs). The potential for reduction of annual electricity consumption and related costs per litre of milk produced by adjusting milking times was higher for the LF than the SF or MF across all electricity tariffs. It is anticipated that these results and the use of the MECD will help support the decision-making process at farm level around increasing energy efficiency and electricity cost forecasts in future electricity pricing tariff structures

Electric utility system benefits of factory packaged GE LM Modular Generator sets

Energy Technology Data Exchange (ETDEWEB)

West, G.

1994-12-31

Electric utility system benefits of factory packaged GE LM modular generator sets are outlined. The following topics are discussed: GE LM gas turbine history, operating experience, maintenance, gas turbine spare engines, modular gas turbine generator sets, typical LM2500 cogeneration plant and STIG cycle plant, factory packaging concept, gas turbine/generator package, performance, comparison, competitive capital cost, phased construction, comparison of revenue requirements, capacity evaluation, heat rate evaluation, fuel evaluation, startup, and dispatch flexibility without maintenance penalty.

From franchise to state commission: Regulation of the electric utility industry, 1907 to 1932

Science.gov (United States)

Reutter, Keith Alan

1997-09-01

Empirical research into the effects of regulation on industry has been around since the early 1960s. Over the last thirty plus years a number of interesting results have been brought to the fore. For instance, it has been found that regulation of the trucking industry limits entry and increases prices. A similar result has been pointed to in other industries such as commercial airlines and banking. The effect of the state commission form of regulation on the electric utility industry has been less conclusive. State commissions became dominant during the period 1910-1930, replacing local franchising as a method of regulating the electric utility industry. Two competing theories suggest why this transformation took place, the "capture" and "public interest" theories of regulation. The capture theory of regulation suggests that the electric utility industry demanded state regulation as a way to earn above normal profits and reduce competition. The public interest theory suggests the purpose of regulation by state commissions was to benefit the general public by forcing the industry to be competitive. Few studies have tried to determine which theory more aptly describes the actual events that took place. The empirical model developed in Chapter V, is an extension of the current literature. A set of simultaneous equations describing the natural gas and electricity markets is estimated using cross-sectional time-series data from 1907 to 1932. The effect of regulation on the electric utility industry is modeled with a dummy variable taking on a value of one to designate that a state commission had been established. The results suggest the capture theory of regulation best describes the period under study. The empirical estimates indicate that state commissions (1) reduced the rate at which the real price of electricity was falling, (2) had a negative impact on firms entering the industry, (3) had a positive influence on the cost of producing a kwh of electricity, and (4

The Nuclear option for U.S. electrical generating capacity additions utilizing boiling water reactor technology

International Nuclear Information System (INIS)

Garrity, T.F.; Wilkins, D.R.

1993-01-01

The technology status of the Advanced Boiling Water (ABWR) and Simplified Boiling Water (SBWR) reactors are presented along with an analysis of the economic potential of advanced nuclear power generation systems based on BWR technology to meet the projected domestic electrical generating capacity need through 2005. The forecasted capacity needs are determined for each domestic North American Electric Reliability Council (NERC) region. Extensive data sets detailing each NERC region's specific generation and load characteristics, and capital and fuel cost parameters are utilized in the economic analysis of the optimal generation additions to meet this need by use of an expansion planning model. In addition to a reference case, several sensitivity cases are performed with regard to capital costs and fuel price escalation

Design study of wind turbines, 50 kW to 3000 kW for electric utility applications: Executive summary

Science.gov (United States)

1977-01-01

Preliminary designs of low power (50 to 500 kW) and high power (500 to 3000 kW) wind generator systems (WGS) for electric utility applications were developed. These designs provide the bases for detail design, fabrication, and experimental demonstration testing of these units at selected utility sites. Several feasible WGS configurations were evaluated, and the concept offering the lowest energy cost potential and minimum technical risk for utility applications was selected. The selected concept was optimized utilizing a parametric computer program prepared for this purpose. The utility requirements evaluation task examined the economic, operational and institutional factors affecting the WGS in a utility environment, and provided additional guidance for the preliminary design effort. Results of the conceptual design task indicated that a rotor operating at constant speed, driving an AC generator through a gear transmission is the most cost effective WGS configuration.

Benefit/cost comparisons for utility SMES applications

International Nuclear Information System (INIS)

De Steese, J.G.; Dagle, J.E.

1991-01-01

This paper summarizes eight cases studies that account for the benefits and costs of superconducting magnetic energy storage (SMES) in system-specific utility applications. Four of these scenarios are hypothetical SMES application in the Pacific Northwest, where relatively low energy costs impose a stringent test on the viability of the concept. The other four scenarios address SMES applications on high-voltage, direct-current (HVDC) transmission lines. While estimated SMES benefits are based on a previously reported methodology, this paper presents results of an improved cost-estimating approach that includes an assumed reduction in the cost of the power conditioning system (PCS) from approximately $160/kW to $80/kW. The revised approach results in all the SMES scenarios showing higher benefit/cost ratios that those reported earlier. However, in all but two cases, the value of any single benefit is still less than the unit's levelized cost. This suggests, as a general principle, that the total value of multiple benefits should always be considered if SMES is to appear cost effective in may utility applications. These results should offer utilities further encouragement to conduct more detailed analyses of SMES benefits in scenarios that apply to individual systems

Benefit/cost comparison for utility SMES applications

Science.gov (United States)

Desteese, J. G.; Dagle, J. E.

1991-08-01

This paper summarizes eight case studies that account for the benefits and costs of superconducting magnetic energy storage (SMES) in system-specific utility applications. Four of these scenarios are hypothetical SMES applications in the Pacific Northwest, where relatively low energy costs impose a stringent test on the viability of the concept. The other four scenarios address SMES applications on high-voltage, direct-current (HVDC) transmission lines. While estimated SMES benefits are based on a previously reported methodology, this paper presents results of an improved cost-estimating approach that includes an assumed reduction in the cost of the power conditioning system (PCS) from approximately $160/kW to $80/kW. The revised approach results in all the SMES scenarios showing higher benefit/cost ratios than those reported earlier. However, in all but two cases, the value of any single benefit is still less than the unit's levelized cost. This suggests, as a general principle, that the total value of multiple benefits should always be considered if SMES is to appear cost effective in many utility applications. These results should offer utilities further encouragement to conduct more detailed analyses of SMES benefits in scenarios that apply to individual systems.

The potential contribution of renewable energy to electricity supply in Saudi Arabia

International Nuclear Information System (INIS)

Alnatheer, Othman

2005-01-01

Saudi Arabia has enormous oil resources. At the same time, the Kingdom has other resources, notably solar energy that may figure in future supplies of electricity. In the past several years, considerable operational experience has been gained throughout the world in the implementation of renewable energy systems of types that would be relevant to the Kingdom. This paper reviews the nature of this experience and applies it in a quantitative assessment of the costs, savings, and environmental benefits of renewable energy conducted as a part of an electric utility integrated resource planning (IRP) project in the Kingdom. Integrated resource planning is an approach that systematically evaluates potential electricity supply and demand-side resources with the aim of developing a plan that provides energy services to customers at the least societal cost. The analysis summarized in this paper has shown that, when some of the non-market benefits of renewable energy are also included in the assessment of their overall costs and benefits, a supply expansion plan that includes wind and solar resources can provide energy services for the Kingdom at a lower societal cost than a 'Business-as-usual' plan utilizing only fossil-fueled generating resources

Design fractures and commercial potential of superconducting magnetic energy storage for electric utility application

International Nuclear Information System (INIS)

Lloyd, R.J.; Schoenung, S.

1986-01-01

Historically, energy storage in the United States has been provided by a few pumped hydroelectric plants, but siting constraints and high cost severely limit the use of this option. Two other options which will soon be in use are batteries and compressed air energy storage. A fourth option, currently being developed for load leveling is Superconducting Magnetic Energy Storage (SMES). This paper reports the design features and estimated costs of utility scale SMES plants. For moderate discharge duration, SMES is projected to have substantially lower revenue requirements and better availability than other load leveling options. The Electric Power Research Institute has prepared a plan for commercialization which could, if aggressively pursued, lead to a demonstrated SMES technology that is available for utility commitment by the late 1990's

Superconducting magnetic energy storage for electric utilities and fusion systems

International Nuclear Information System (INIS)

Rogers, J.D.; Boenig, H.J.; Hassenzahl, W.V.

1978-01-01

Superconducting inductors provide a compact and efficient means of storing electrical energy without an intermediate conversion process. Energy storage inductors are under development for load leveling and transmission line stabilization in electric utility systems and for driving magnetic confinement and plasma heating coils in fusion energy systems. Fluctuating electric power demands force the electric utility industry to have more installed generating capacity than the average load requires. Energy storage can increase the utilization of base-load fossil and nuclear power plants for electric utilities. The Los Alamos Scientific Laboratory and the University of Wisconsin are developing superconducting magnetic energy storage (SMES) systems, which will store and deliver electrical energy for load leveling, peak shaving, and the stabilization of electric utility networks. In the fusion area, inductive energy transfer and storage is being developed. Both 1-ms fast-discharge theta-pinch systems and 1-to-2-s slow energy transfer tokamak systems have been demonstrated. The major components and the method of operation of a SMES unit are described, and potential applications of different size SMES systems in electric power grids are presented. Results are given of a reference design for a 10-GWh unit for load leveling, of a 30-MJ coil proposed for system stabilization, and of tests with a small-scale, 100-kJ magnetic energy storage system. The results of the fusion energy storage and transfer tests are presented. The common technology base for the various storage systems is discussed

The effect of the Fukushima nuclear accident on stock prices of electric power utilities in Japan

International Nuclear Information System (INIS)

Kawashima, Shingo; Takeda, Fumiko

2012-01-01

The purpose of this study is to investigate the effect of the accident at the Fukushima Daiichi nuclear power station, which is owned by Tokyo Electric Power Co. (TEPCO), on the stock prices of the other electric power utilities in Japan. Because the other utilities were not directly damaged by the Fukushima nuclear accident, their stock price responses should reflect the change in investor perceptions on risk and return associated with nuclear power generation. Our first finding is that the stock prices of utilities that own nuclear power plants declined more sharply after the accident than did the stock prices of other electric power utilities. In contrast, investors did not seem to care about the risk that may arise from the use of the same type of nuclear power reactors as those at the Fukushima Daiichi station. We also observe an increase of both systematic and total risks in the post-Fukushima period, indicating that negative market reactions are not merely caused by one-time losses but by structural changes in society and regulation that could increase the costs of operating a nuclear power plant.

Future vision of advanced telecommunication networks for electric utilities; Denki jigyo ni okeru joho tsushin network no shorai vision

Energy Technology Data Exchange (ETDEWEB)

Tonaru, S.; Ono, K.; Sakai, S.; Kawai, Y.; Tsuboi, A. [Central Research Institute of Electric Power Industry, Tokyo (Japan); Manabe, S. [Shikoku Electric Power Co., Inc., Kagawa (Japan); Miki, Y. [Kansai Electric Power Co. Inc., Osaka (Japan)

1995-06-01

The vision of an advanced information system is proposed to cope with the future social demand and business environmental change in electric utilities. At the large turning point such as drastic reconsideration of Electricity Utilities Industry Law, further improvement of efficiency and cost reduction are requested as well as business innovation such as proposal of a new business policy. For that purpose utilization of information and its technology is indispensable, and use of multimedia and common information in organization are the future direction for improving information basis. Consequently, free information networks without any limitation due to person and media are necessary, and the following are important: high-speed, high-frequency band, digital, easily connectable and multimedia transmission lines, and cost reduction and high reliability of networks. Based on innovation of information networks and the clear principle on advanced information system, development of new applications by multimedia technologies, diffusion of communication terminals, and promotion of standardization are essential. 60 refs., 30 figs., 5 tabs.

Environmental degradation costs in electricity generation: The case of the Brazilian electrical matrix

International Nuclear Information System (INIS)

Alves, Laura Araujo; Uturbey, Wadaed

2010-01-01

The main purpose of this paper is to emphasize the importance of including environmental degradation costs in the long-term planning of the Brazilian electricity sector. To this aim, environmental external costs associated to both hydro-power and thermal-power electricity generation are investigated. Monetary valuation methodologies are applied and environmental degradation costs, expressed in per kWh of generated energy, are obtained for the main types of generation sources of the Brazilian electricity matrix. Both local pollution due to particulate matter emissions and global warming effects are assessed. A classification of the sources from the point of view of their impact on the environment is given. Degradation costs associated to the installed capacity expansion in the Brazilian electricity sector during the time horizon 2007-2016 are estimated. These resulting costs represent lower boundary damage estimates associated only with the energy to be generated during the period. Results indicate that local pollution caused by a small number of plants could be even more costly to society than global warming and, also, show the importance of considering not only unitary damage costs but the participation of each source on the generated energy during the time horizon, as a guide to planning and policy making.

Electricity transmission congestion costs: A review of recent reports

Energy Technology Data Exchange (ETDEWEB)

Lesieutre, Bernard C.; Eto, Joseph H.

2003-10-01

Recently, independent system operators (ISOs) and others have published reports on the costs of transmission congestion. The magnitude of congestion costs cited in these reports has contributed to the national discussion on the current state of U.S. electricity transmission system and whether it provides an adequate platform for competition in wholesale electricity markets. This report reviews reports of congestion costs and begins to assess their implications for the current national discussion on the importance of the U.S. electricity transmission system for enabling competitive wholesale electricity markets. As a guiding principle, we posit that a more robust electricity system could reduce congestion costs; and thereby, (1) facilitate more vibrant and fair competition in wholesale electricity markets, and (2) enable consumers to seek out the lowest prices for electricity. Yet, examining the details suggests that, sometimes, there will be trade-offs between these goals. Therefore, it is essential to understand who pays, how much, and how do they benefit in evaluating options (both transmission and non-transmission alternatives) to address transmission congestion. To describe the differences among published estimates of congestion costs, we develop and motivate three ways by which transmission congestion costs are calculated in restructured markets. The assessment demonstrates that published transmission congestion costs are not directly comparable because they have been developed to serve different purposes. More importantly, critical information needed to make them more comparable, for example in order to evaluate the impacts of options to relieve congestion, is sometimes not available.

Regional differences in electricity distribution costs and their consequences for yardstick regulation of access prices

International Nuclear Information System (INIS)

Filippini, M.; Wild, J.

2001-01-01

In this paper we estimate an average-cost function for a panel of 59 Swiss local and regional electricity distribution utilities as a basis for yardstick regulation of the distribution-network access prices. Shleifer (1985) proposed yardstick competition in terms of price to regulate local monopolies producing a homogeneous good. The regulated price for the individual firms depends on the average costs of identical firms. The yardstick competition concept can also be applied to firms that produce heterogeneous goods if these goods differ only in observable characteristics. To correct the yardstick for heterogeneity the regulator can use a multivariate estimation of an average-cost function. In the case of electricity distribution, the heterogeneity of output consists mainly of different characteristics of the distribution service areas. In this paper we follow Shleifer's suggestion to estimate a multivariate average-cost function that can be employed by the regulatory commission to benchmark network access prices at the distribution level. Several exogenous variables measuring the heterogeneity of the service areas were included in the cost model specification. We find that the regional differences of the service areas - e.g. area shares of forests, agricultural areas or unproductive land and population density - significantly influence electricity distribution costs

The Municipal Electrical Utilities' role in buying and selling power

International Nuclear Information System (INIS)

Crocker, D.I.

1999-01-01

Ontario's Municipal Electrical Utilities (MEUs) are the front-line providers of electricity services for most of the consumers in Ontario. MEUs serve 2.8 million customers (about 70 per cent of all power sold in Ontario). The new regulatory regime resulting from Ontario's Energy Competition Act (1998) will significantly impact MEUs. The changes aim to consolidate and rationalize the point of sale provision of power to Ontario customers and increase the efficiency of the sector. The Energy Competition Act (1998) creates a competitive electricity marketplace and provides mechanisms for its operation, but it is the MEUs which will bear the risk of market failures. Some of the changes which will be most important to MEUs are: (1) incorporation, (2) default supplier, and (3) oversight by the OEB. It is the author's view that the move towards open markets in electricity is unlikely to enlarge the decision making power of MEUs. On the contrary, the legislative scheme creates a complex regulatory environment wherein the distribution corporation must strictly comply with the OEB's requirements and public policy concerns in exercising its functions. As the MEUs essentially serve as a buffer in the newly opened retail markets, they must find ways to minimize their risk of market failures or spread the cost so as to remain viable commercial entities. They must also devise new information systems prior to the opening of the new market to deal with customer and default consumer pricing, billing and transfer of customers to and from retailers. Municipal utilities will also have to consider restructuring of their own operations, including determining which businesses should be pursued through competitive affiliates

An essay pertaining to the supply and price of natural gas as fuel for electric utilities and independent power producers; and, the related growth of non-utility generators to meet capacity shortfalls in the next decade

International Nuclear Information System (INIS)

Clements, J.R.

1990-01-01

This paper addresses the impact natural gas and petroleum prices have on how the electric power industry decides to meet increasing demand for electric power. The topics of the paper include the pricing impact of the Iraq-Kuwait conflict, the BTU parity argument, electric utility capacity shortfalls in 1993, the growth of the non-utility generator and the independent power developer market, natural gas as the desired fuel of the decade, the financial strategy in acquiring natural gas reserves, the cost and availability of natural gas supplies for non-utility generators, and the reluctance of the gas producers to enter long term contracts

Cost modelling of electricity producing hot dry rock (HDR) geothermal systems in the UK

International Nuclear Information System (INIS)

Doherty, P.S.

1992-03-01

A detailed and comprehensive cost model for Hot Dry Rock (HDR) electricity producing systems has been developed in this study. The model takes account of the major aspects of the HDR system, parameterized in terms of the main physical and cost parameters of the resource and the utilization system. A doublet configuration is assumed, and the conceptual HDR system which is defined in the study is based upon the UK Department of Energy (DEn) HDR geothermal R and D programme. The model has been used to calculate the costs of HDR electricity for a UK defined base case which represents a consensus view of what might be achieved in Cornwall in the long term. At 14.2 p/kWh (1988 costs) this cost appears to be unacceptably high. A wide-ranging sensitivity study has also been carried out on the main resource, geometrical, and operational parameters of the HDR system centred around the UK base case. The sensitivity study shows the most important parameters to be thermal gradient and depth. (Author)

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

Energy Technology Data Exchange (ETDEWEB)

1991-02-06

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.

Financial statistics of major U.S. investor-owned electric utilities 1993

Energy Technology Data Exchange (ETDEWEB)

1995-01-01

The Financial Statistics of Major US 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 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.

Review of inter-utility trade in electricity: Analyses of submissions

International Nuclear Information System (INIS)

1994-04-01

In November 1992, Canada's National Energy Board released two discussion papers describing its review of inter-utility trade in electricity. The review was undertaken to report on measures that could be taken to enhance interprovincial trade in electricity by encouraging greater cooperation among utilities in systems planning and development, and by enabling buyers and sellers of electricity to obtain commercial access to available transmission capacity through intermediate provinces for wheeling purposes. Interested parties were invited to comment on the papers and 42 responses were received from Canadian utilities, provincial governments, regulatory agencies, and others. These responses are summarized and analyzed, providing an indication of how future policy initiatives on electricity trade might be received. Most submitters agreed that there is a need to enable commercial access to available transmission capacity through intermediate provinces for wheeling purposes. Of the seven options described in the discussion papers that would enable buyers and sellers of electricity to gain commercial access to transmission grids, the status quo was preferred by those utilities and provinces that have direct access to export markets by virtue of their geographic location. Those utilities and provinces that do not have such direct access tend to support, as a last resort, mandated solutions to disputes concerning electricity trade. 78 figs

Defining landscape resistance values in least-cost connectivity models for the invasive grey squirrel: a comparison of approaches using expert-opinion and habitat suitability modelling.

Science.gov (United States)

Stevenson-Holt, Claire D; Watts, Kevin; Bellamy, Chloe C; Nevin, Owen T; Ramsey, Andrew D

2014-01-01

Least-cost models are widely used to study the functional connectivity of habitat within a varied landscape matrix. A critical step in the process is identifying resistance values for each land cover based upon the facilitating or impeding impact on species movement. Ideally resistance values would be parameterised with empirical data, but due to a shortage of such information, expert-opinion is often used. However, the use of expert-opinion is seen as subjective, human-centric and unreliable. This study derived resistance values from grey squirrel habitat suitability models (HSM) in order to compare the utility and validity of this approach with more traditional, expert-led methods. Models were built and tested with MaxEnt, using squirrel presence records and a categorical land cover map for Cumbria, UK. Predictions on the likelihood of squirrel occurrence within each land cover type were inverted, providing resistance values which were used to parameterise a least-cost model. The resulting habitat networks were measured and compared to those derived from a least-cost model built with previously collated information from experts. The expert-derived and HSM-inferred least-cost networks differ in precision. The HSM-informed networks were smaller and more fragmented because of the higher resistance values attributed to most habitats. These results are discussed in relation to the applicability of both approaches for conservation and management objectives, providing guidance to researchers and practitioners attempting to apply and interpret a least-cost approach to mapping ecological networks.

Defining landscape resistance values in least-cost connectivity models for the invasive grey squirrel: a comparison of approaches using expert-opinion and habitat suitability modelling.

Directory of Open Access Journals (Sweden)

Claire D Stevenson-Holt

Full Text Available Least-cost models are widely used to study the functional connectivity of habitat within a varied landscape matrix. A critical step in the process is identifying resistance values for each land cover based upon the facilitating or impeding impact on species movement. Ideally resistance values would be parameterised with empirical data, but due to a shortage of such information, expert-opinion is often used. However, the use of expert-opinion is seen as subjective, human-centric and unreliable. This study derived resistance values from grey squirrel habitat suitability models (HSM in order to compare the utility and validity of this approach with more traditional, expert-led methods. Models were built and tested with MaxEnt, using squirrel presence records and a categorical land cover map for Cumbria, UK. Predictions on the likelihood of squirrel occurrence within each land cover type were inverted, providing resistance values which were used to parameterise a least-cost model. The resulting habitat networks were measured and compared to those derived from a least-cost model built with previously collated information from experts. The expert-derived and HSM-inferred least-cost networks differ in precision. The HSM-informed networks were smaller and more fragmented because of the higher resistance values attributed to most habitats. These results are discussed in relation to the applicability of both approaches for conservation and management objectives, providing guidance to researchers and practitioners attempting to apply and interpret a least-cost approach to mapping ecological networks.

Reference costs of electricity

International Nuclear Information System (INIS)

Terraz, N.

1997-01-01

The calculation of electric power production reference costs is used in France, even in the present case of over-capacity, for comparing the relative interest of the various means of power generation (nuclear plants, coal plants, hydroelectricity, gas combined cycles, etc.) and as an aid for future investment decisions. Reference costs show a sharp decrease between 1993 and 1997 due to advancements in nuclear plant operating ability and fossil fuel price decrease. Actuarial rates, plant service life, fuel costs and exchange rates are important parameters. The various costs from the research stage to the waste processing stages are discussed and the reference costs of the various power generation systems are presented and compared together with their competitiveness; the future of wind energy and cogeneration and the prospective of the renewal of nuclear plants at the 2010 horizon are also addressed

Practical uses of galvanized steel in electric utility applications

International Nuclear Information System (INIS)

Bueche, D.G.

1995-01-01

Steel corrosion has been shown to be a major problem for the electric utility industry. Galvanizing has been shown to prevent or substantially slow steel corrosion. This paper describes the galvanizing process, discusses the properties associated with the galvanized coating, and demonstrates galvanizing's durability in specific, real world applications in the electric utility industry

Economic cost of electricity sold to new aluminium smelters

International Nuclear Information System (INIS)

Belanger, G.; Bernard, J.T.

2008-01-01

Low cost electricity was a key factor for establishing an aluminium industry in Quebec. Smelters in the province use 50 terawatt hours of electricity per year, which represents 25 per cent of the total consumed in Quebec. This article assessed the profitability of new industrial projects that require large quantities of electricity at a time when the cost of new power plants is increasing. However, electricity is being sold below cost and the difference is subsidized by the government. The investment is justified by the government because these new projects create high paying jobs. The authors presented cases of 2 new aluminium plants, and concluded that they represented a very high economic cost for the province. 1 tab

What is heartburn worth? A cost-utility analysis of management strategies.

Science.gov (United States)

Heudebert, G R; Centor, R M; Klapow, J C; Marks, R; Johnson, L; Wilcox, C M

2000-03-01

To determine the best treatment strategy for the management of patients presenting with symptoms consistent with uncomplicated heartburn. We performed a cost-utility analysis of 4 alternatives: empirical proton pump inhibitor, empirical histamine2-receptor antagonist, and diagnostic strategies consisting of either esophagogastroduodenoscopy (EGD) or an upper gastrointestinal series before treatment. The time horizon of the model was 1 year. The base case analysis assumed a cohort of otherwise healthy 45-year-old individuals in a primary care practice. Empirical treatment with a proton pump inhibitor was projected to provide the greatest quality-adjusted survival for the cohort. Empirical treatment with a histamine2 receptor antagonist was projected to be the least costly of the alternatives. The marginal cost-effectiveness of using a proton pump inhibitor over a histamine2-receptor antagonist was approximately $10,400 per quality-adjusted life year (QALY) gained in the base case analysis and was less than $50,000 per QALY as long as the utility for heartburn was less than 0.95. Both diagnostic strategies were dominated by proton pump inhibitor alternative. Empirical treatment seems to be the optimal initial management strategy for patients with heartburn, but the choice between a proton pump inhibitor or histamine2-receptor antagonist depends on the impact of heartburn on quality of life.

A new algorithm for least-cost path analysis by correcting digital elevation models of natural landscapes

Science.gov (United States)

Baek, Jieun; Choi, Yosoon

2017-04-01

Most algorithms for least-cost path analysis usually calculate the slope gradient between the source cell and the adjacent cells to reflect the weights for terrain slope into the calculation of travel costs. However, these algorithms have limitations that they cannot analyze the least-cost path between two cells when obstacle cells with very high or low terrain elevation exist between the source cell and the target cell. This study presents a new algorithm for least-cost path analysis by correcting digital elevation models of natural landscapes to find possible paths satisfying the constraint of maximum or minimum slope gradient. The new algorithm calculates the slope gradient between the center cell and non-adjacent cells using the concept of extended move-sets. If the algorithm finds possible paths between the center cell and non-adjacent cells with satisfying the constraint of slope condition, terrain elevation of obstacle cells existing between two cells is corrected from the digital elevation model. After calculating the cumulative travel costs to the destination by reflecting the weight of the difference between the original and corrected elevations, the algorithm analyzes the least-cost path. The results of applying the proposed algorithm to the synthetic data sets and the real-world data sets provide proof that the new algorithm can provide more accurate least-cost paths than other conventional algorithms implemented in commercial GIS software such as ArcGIS.

Implementing a least cost and risk focused maintenance process

International Nuclear Information System (INIS)

Darling, S.S.

1996-01-01

The paper will focus on the vital role maintenance, big ''M'' (spares, PM program, planning and scheduling, turning the wrench), has in preserving return of investment, and safety in operation of high risk high value facilities/platforms. The maintenance process of today and for the future must utilize risk assessment and reliability engineering techniques to prioritize plant resources. The new process must provide for high levels of safety assurance yet allow for improved generation and transmission capacity while maintaining adequate system reliability. This approach ultimately leads to continuous and sustained reduction in operating cost, improved production capacity, and a safety culture based upon a risk determent cost-beneficial decision process

Electric utility preferred stock financing - twilight or new dawn?

International Nuclear Information System (INIS)

Klein, R.

1991-01-01

The tax laws have greatly diminished the importance of utility preferred stock. But with utility construction programs expected to rise, it is an opportune time to see if preferreds can be an attractive option again. As recently as 1980, preferred stock financing by electric utilities comprised 55% of all U.S. corporate preferred stock issued. By 1989, this percentage had declined to under 12%. In dollar amounts, electric utility preferred stock financing had decreased by two-thirds over the same time period. The author analyzes just why this decline occurred and what it portends for the future

The utility target market model

International Nuclear Information System (INIS)

Leng, G.J.; Martin, J.

1994-01-01

A new model (the Utility Target Market Model) is used to evaluate the economic benefits of photovoltaic (PV) power systems located at the electrical utility customer site. These distributed PV demand-side generation systems can be evaluated in a similar manner to other demand-side management technologies. The energy and capacity values of an actual PV system located in the service area of the New England Electrical System (NEES) are the two utility benefits evaluated. The annual stream of energy and capacity benefits calculated for the utility are converted to the installed cost per watt that the utility should be willing to invest to receive this benefit stream. Different discount rates are used to show the sensitivity of the allowable installed cost of the PV systems to a utility's average cost of capital. Capturing both the energy and capacity benefits of these relatively environmentally friendly distributed generators, NEES should be willing to invest in this technology when the installed cost per watt declines to ca $2.40 using NEES' rated cost of capital (8.78%). If a social discount rate of 3% is used, installation should be considered when installed cost approaches $4.70/W. Since recent installations in the Sacramento Municipal Utility District have cost between $7-8/W, cost-effective utility applications of PV are close. 22 refs., 1 fig., 2 tabs

The rural utility response to Colorado's electricity mandates

International Nuclear Information System (INIS)

Tierney, Sean

2011-01-01

When Colorado voters passed Amendment 37 in 2004, it became the first state to pass a renewable portfolio standard at the ballet box, suggesting broad appeal to harness and pay for renewable energy. While large urban utilities are prepared to make this transition, smaller cities and rural areas, for various financial and scale issues are severely disadvantaged in trying to incorporate more renewable energy sources into their electricity mix. This was evident by the state's support for Amendment 37, which was passed due to strong support in the Denver metro area-representing nearly half of the state's population. Support for the bill was poor in the rest of the state. Nevertheless, in 2007, the state expanded up Amendment 37 by forcing the utilities in rural communities to diversify their electricity mix. This study surveyed the managers at the state's various rural electric cooperatives and municipal utilities in an effort to gage their attitudes concerning: carbon legislation, conservation and efficiency programs, and their plans for making the transition away from fossil fuel generation. - Highlights: → Communities served by rural utilities opposed Colorado's state-wide RPS, but were forced to adhere anyway. → Most rural utilities are very concerned about the economic impacts of trying to diversify their energy portfolios. → Many of these unregulated utilities were already pushing DSM programs to promote conservation and improve efficiency.

Comparative Study on Electric Generation Cost of HTR with Another Electric Plant Using LEGECOST Program

International Nuclear Information System (INIS)

Mochamad-Nasrullah; Soetrisnanto, Arnold Y.; Tosi-Prastiadi; Adiwardojo

2000-01-01

Monetary and economic crisis in Indonesia resulted in impact of electricity and demand and supply planning that it has to be reevaluated. One of the reasons is budget limitation of the government as well as private companies. Considering this reason, the economic calculation for all of aspect could be performed, especially the calculation of electric generation cost. This paper will discuss the economic aspect of several power plants using fossil and nuclear fuel including High Temperature Reactor (HTR). Using Levelized Generation Cost (LEGECOST) program developed by IAEA (International Atomic Energy Agency), the electric generation cost of each power plant could be calculated. And then, the sensitivity analysis has to be done using several economic parameters and scenarios, in order to be known the factors that influence the electric generation cost. It could be concluded, that the electric generation cost of HTR is cheapest comparing the other power plants including nuclear conventional. (author)

Region-specific study of the electric utility industry: financial history and future power requirements for the VACAR region

International Nuclear Information System (INIS)

Pochan, M.J.

1985-07-01

Financial data for the period 1966 to 1981 are presented for the four investor-owned electric utilities in the VACAR (Virginia-Carolinas) region. This region was selected as representative for the purpose of assessing the availability, reliability, and cost of electric power for the future in the United States. The estimated demand for power and planned additions to generating capacity for the region through the year 2000 are also given

Cost Utility Analysis of Cervical Therapeutic Medial Branch Blocks in Managing Chronic Neck Pain.

Science.gov (United States)

Manchikanti, Laxmaiah; Pampati, Vidyasagar; Kaye, Alan D; Hirsch, Joshua A

2017-01-01

Background: Controlled diagnostic studies have established the prevalence of cervical facet joint pain to range from 36% to 67% based on the criterion standard of ≥ 80% pain relief. Treatment of cervical facet joint pain has been described with Level II evidence of effectiveness for therapeutic facet joint nerve blocks and radiofrequency neurotomy and with no significant evidence for intraarticular injections. However, there have not been any cost effectiveness or cost utility analysis studies performed in managing chronic neck pain with or without headaches with cervical facet joint interventions. Study Design: Cost utility analysis based on the results of a double-blind, randomized, controlled trial of cervical therapeutic medial branch blocks in managing chronic neck pain. Objectives: To assess cost utility of therapeutic cervical medial branch blocks in managing chronic neck pain. Methods: A randomized trial was conducted in a specialty referral private practice interventional pain management center in the United States. This trial assessed the clinical effectiveness of therapeutic cervical medial branch blocks with or without steroids for an established diagnosis of cervical facet joint pain by means of controlled diagnostic blocks. Cost utility analysis was performed with direct payment data for the procedures for a total of 120 patients over a period of 2 years from this trial based on reimbursement rates of 2016. The payment data provided direct procedural costs without inclusion of drug treatments. An additional 40% was added to procedural costs with multiplication of a factor of 1.67 to provide estimated total costs including direct and indirect costs, based on highly regarded surgical literature. Outcome measures included significant improvement defined as at least a 50% improvement with reduction in pain and disability status with a combined 50% or more reduction in pain in Neck Disability Index (NDI) scores. Results: The results showed direct

Internalising external costs of electricity and heat production in a municipal energy system

International Nuclear Information System (INIS)

Holmgren, Kristina; Amiri, Shahnaz

2007-01-01

Both energy supply and waste treatment give rise to negative effects on the environment, so-called external effects. In this study, monetary values on external costs collected from the EU's ExternE project are used to evaluate inclusion of these costs in comparison with an energy utility perspective including present policy instruments. The studied object is a municipal district heating system with a waste incineration plant as the base supplier of heat. The evaluation concerns fuels used for heat production and total electricity production, for scenarios with external costs included and for a scenario using the present policy instrument. Impacts of assumptions on marginal power producers (coal or natural gas power plants) are investigated, since locally produced electricity is assumed to replace marginal power and thus is credited for the avoided burden. Varying levels of external costs for carbon dioxide emissions are analysed. The method used is an economic optimisation model, MODEST. The conclusion is that present policy instruments are strong incentives for cogeneration, even when external costs are included. Waste is fully utilised in all scenarios. In cases where coal is the marginal power producer, more electricity is produced; when natural gas is the marginal power producer, less is produced. There are several uncertainties in the data for external costs, both methodological and ethical. In the ExternE data, not all environmental impacts are included. For waste incineration, ashes are not included, and another difficulty is how to treat the avoided burden of other waste treatment methods

Communications architecture for an electric company, European utility communications architecture, EURUCA

Energy Technology Data Exchange (ETDEWEB)

Uuspaeae, P [VTT Energy, Espoo (Finland)

1998-08-01

The scope of this research is integration and interoperability of various information systems and data communications for electric utilities. Utility Communication Architecture refers to an overall view of the communications needs and communication systems in an electric utility. The objective is to define and specify suitable and compatible communications procedures within the Utility and also to outside parties

Favourability towards electric utilities jumps 10 per cent in 1997

International Nuclear Information System (INIS)

Anon.

1997-01-01

A recent survey of public opinion has shown that 85 per cent of the public view their electric utility company favourably. This represents a 10 per cent increase over last year. A survey of 4,090 Canadians was conducted which looked at the perceptions of the value of electricity services compared to telephone, natural gas, banking, and home insurance services. The study showed that Canadian electric utility companies are viewed as positively as the telephone companies and almost as favourably as the banks. Some 71 per cent of respondents reported that the value they receive from their electric utility is excellent or good. Lower prices, better customer services and increased research into alternative power sources were among the benefits that Canadians perceive would result from a more competitive electricity sector. Some misgivings about deregulation included a belief that there would be less attention to environmental concerns and more outages. Four per cent of the respondents said they would 'definitely' switch to an alternative supplier of electricity, while 25 per cent said they would 'probably' switch to an alternative supplier of electricity. 2 tabs

Comparative financial analysis of electricity utilities in West Africa

International Nuclear Information System (INIS)

Fritsch, Remi

2011-01-01

Access to electricity is a major issue in West Africa. Governments have a difficult equation to solve. They naturally seek to offer their people a cheap kWh. But they are constrained by a production based largely on oil and therefore highly volatile production costs. How to fix an acceptable tariff, taking into account the investment needs required to expand the network and increase production? This analysis should provide some answers. The study presented in this paper provides a financial analysis of electricity utilities in West Africa. It allows a comparison of performances on a number of key financial ratios related to operations (Earning Before Interest Taxes Debt and Amortization/sales, working capital requirement/sales, days of receivables or payables), investment (net fixed assets/gross fixed assets), bank financing (financial structure, debt/EBITDA, interest expense/EBITDA) and economic and financial returns (Return On Capital Employed, Return On Equity). The conclusion focuses on the growth opportunity that the electricity sector could represent for each country. But this opportunity may only materialize if the EBITDA margins are restored. The available options appear limited and must be assessed taking into account the context of each country: tariff increase, improvement of technical losses or diversification into means of production no longer based primarily on oil or gas. - Highlights: → The study provides a financial analysis of electricity distribution companies in West Africa. → The study highlights generally insufficient EBITDA margins. → The study raises the question of tariffs and contribution to Gross Domestic Product of the electricity sector. → The conclusion focuses on the growth opportunity that the electricity sector could represent for each country.

Electric utilities strategies in final energy markets

International Nuclear Information System (INIS)

Bianchi, A.

2000-01-01

In rapidly changing markets, electric utilities pay growing attention to customers and service. They are aware that competition needs strategies capable of transforming and strengthening the privileged position resulting from the knowledge of the market. Moreover, this aspect is the link between different value chains to describe new multi utility approaches [it

The future of the electric utility industry in Canada

International Nuclear Information System (INIS)

Threlkeld, R.

1995-01-01

A discussion of future changes in the electric power utility industry in Canada was presented. The impacts of deregulation were considered, including increased competition, and reduced profits resulting from it. Restructuring measures taken by BC Hydro to prepare for industry changes were described. Competition was not only expected to result from new electric utilities, but also gas utilities that are establishing themselves in the home heating business. Emphasis was placed on making the utilities' priorities, the same as their customers'. Flexibility of rate scheduling and increased dependence on customer-owned generation were needed to remain competitive. Exportation of surplus electricity and development of power utilities in developing nations was considered as a potentially lucrative development strategy. It was suggested that making use of strategic alliances within Canada and worldwide, will help to keep utilities ahead of the competition. A warning was issued to the effect that environmental concerns must always be considered well in advance of regulations since they are continually becoming more stringent. Making common cause with customers, and continuous improvement were considered to be the most important keys to future success for the industry

A cost-utility analysis of psychoanalysis versus psychoanalytic psychotherapy.

Science.gov (United States)

Berghout, Caspar C; Zevalkink, Jolien; Hakkaart-van Roijen, Leona

2010-01-01

Despite the considerable and growing body of research about the clinical effectiveness of long-term psychoanalytic treatment, relatively little attention has been paid to economic evaluations, particularly with reference to the broader range of societal effects. In this cost-utility study, we examined the incremental cost-effectiveness ratio (ICER) of psychoanalysis versus psychoanalytic psychotherapy. Incremental costs and effects were estimated by means of cross-sectional measurements in a cohort design (psychoanalysis, n = 78; psychoanalytic psychotherapy, n = 104). Quality-adjusted life-years (QALYs) were estimated for each treatment strategy using the SF-6D. Total costs were calculated from a societal perspective (treatment costs plus other societal costs) and discounted at 4 percent. Psychoanalysis was more costly than psychoanalytic psychotherapy, but also more effective from a health-related quality of life perspective. The ICER--that is, the extra costs to gain one additional QALY by delivering psychoanalysis instead of psychoanalytic psychotherapy--was estimated at 52,384 euros per QALY gained. Our findings show that the cost-utility ratio of psychoanalysis relative to psychoanalytic psychotherapy is within an acceptable range. More research is needed to find out whether cost-utility ratios vary with different types of patients. We also encourage cost-utility analyses comparing psychoanalytic treatment to other forms of (long-term) treatment.

Electricity generation cost

International Nuclear Information System (INIS)

Bald, M.

1984-01-01

Also questions of efficiency play a part in the energy discussion. In this context, the economic evaluation of different energy supply variants is of importance. Especially with regard to the generation of electric power there have been discussions again and again during the last years on the advantage of the one or the other kind of electric power generation. In the meantime, a large number of scientific studies has been published on this topic which mainly deal with comparisons of the costs of electric power generated by hard coal or nuclear energy, i.e. of those energy forms which still have the possibilities of expansion. The following part shows a way for the evaluation of efficiency comparisons which starts from simplified assumptions and which works with arithmetical aids, which don't leave the area of the fundamental operations. The general comprehensibility is paid for with cuts on ultimate analytical and arithmetical precision. It will, however, turn out that the results achieved by this method don't differ very much from those which have been won by scientific targets. (orig./UA) [de

Least-cost groundwater remediation design using uncertain hydrogeological information. 1998 annual progress report

International Nuclear Information System (INIS)

Pinder, G.F.

1998-01-01

'The objective of the project is to formulate, test, and evaluate a new approach to the least-cost design of groundwater contamination containment and decontamination systems. The proposed methodology employs robust optimization, the outer-approximation method of non-linear programming, and groundwater flow and transport modeling to find the most cost-effective pump-and-treat design possible given the physical parameters describing the groundwater reservoir are known with uncertainty. The result is a methodology that will provide the least-cost groundwater remediation design possible given a specified set of design objectives and physical and sociological constraints. As of the end of the first year of this 3-year project the author has developed and tested the concept of robust optimization within the framework of least-cost groundwater-contamination-containment design. The outer-approximation method has been employed in this context for the relatively simple linear-constraint case associated with the containment problem. In an effort to enhance the efficiency and applicability of this methodology, a new strategy for selecting the various realizations arising out of the Monte-Carlo underpinnings of the robust-optimization technique has been developed and tested. Based upon observations arising out of this work a yet more promising approach has been discovered. The theoretical foundation for this most recent approach has been, and continues to be, the primary focus of the research.'

Variable population exposure and distributed travel speeds in least-cost tsunami evacuation modelling

Science.gov (United States)

Fraser, Stuart A.; Wood, Nathan J.; Johnston, David A.; Leonard, Graham S.; Greening, Paul D.; Rossetto, Tiziana

2014-01-01

Evacuation of the population from a tsunami hazard zone is vital to reduce life-loss due to inundation. Geospatial least-cost distance modelling provides one approach to assessing tsunami evacuation potential. Previous models have generally used two static exposure scenarios and fixed travel speeds to represent population movement. Some analyses have assumed immediate departure or a common evacuation departure time for all exposed population. Here, a method is proposed to incorporate time-variable exposure, distributed travel speeds, and uncertain evacuation departure time into an existing anisotropic least-cost path distance framework. The method is demonstrated for hypothetical local-source tsunami evacuation in Napier City, Hawke's Bay, New Zealand. There is significant diurnal variation in pedestrian evacuation potential at the suburb level, although the total number of people unable to evacuate is stable across all scenarios. Whilst some fixed travel speeds approximate a distributed speed approach, others may overestimate evacuation potential. The impact of evacuation departure time is a significant contributor to total evacuation time. This method improves least-cost modelling of evacuation dynamics for evacuation planning, casualty modelling, and development of emergency response training scenarios. However, it requires detailed exposure data, which may preclude its use in many situations.

The Social Costs of Electricity Generation—Categorising Different Types of Costs and Evaluating Their Respective Relevance

Directory of Open Access Journals (Sweden)

Sascha Samadi

2017-03-01

Full Text Available Various electricity generation technologies using different primary energy sources are available. Many published studies compare the costs of these technologies. However, most of those studies only consider plant-level costs and do not fully take into account additional costs that societies may face in using these technologies. This article reviews the literature on the costs of electricity generation technologies, aiming to determine which types of costs are relevant from a societal point of view when comparing generation technologies. The paper categorises the relevant types of costs, differentiating between plant-level, system and external costs as the main categories. It discusses the relevance of each type of cost for each generation technology. The findings suggest that several low-carbon electricity generation technologies exhibit lower social costs per kWh than the currently dominant technologies using fossil fuels. More generally, the findings emphasise the importance of taking not only plant-level costs, but also system and external costs, into account when comparing electricity generation technologies from a societal point of view. The article intends to inform both policymakers and energy system modellers, the latter who may strive to include all relevant types of costs in their models.

Electric power in Canada 1993

International Nuclear Information System (INIS)

1994-01-01

The electric power industry in Canada in 1993 is reviewed. Items discussed include: the international context of Canadian electricity; regulatory structures; electricity and the environment; electricity consumption; electricity generation; generating capacity and reserve; electricity trade; transmission; electric utility investment and financing; costing and pricing; electricity outlook; demand-side management; and non-utility generation. Information is appended on installed capacity and electrical energy consumption in Canada, installed generating capacity, conventional thermal capacity by principal fuel type, provincial electricity imports and exports, Canadian electricity exports by exporter and importer, generation capacity by type, installed generating capacity expansion in Canada by station, federal environmental standards and guidelines, and prices paid by major electric utilities for non-utility generation. 26 figs., 90 tabs

Effect of regulation on the rate of adoption of cost saving scale technology in the electric utility industry: a portfolio approach

International Nuclear Information System (INIS)

Scheraga, C.A.

1984-01-01

This study presents a new analytical framework for examining the relationship between regulation and the investment behavior of electric utilities. The particular kind of investment behavior considered is the adoption of new as well as innovative electrical generation technology. The technologies of interest are large scale coal and nuclear generation plants. The theoretical model used in this study differs from traditional approaches in its utilization of a behavioral framework of analysis. The responsiveness of utilities to the required rate of return demanded by stockholders is demonstrated using an augmented form of the standard Capital Asset Pricing Model. Regulation is viewed as affecting utility investment behavior through the effect of the actions of regulatory commissions on the required rate of return that utilities must earn on equity. The particular regulatory policies considered are modification of existing rate structure, automatic adjustment clauses, and required efficiency standards. These policies are of particular interest both because their effects have not been previously examined in detail, and because they are recommended for adoption in the Public Utility Regulatory Policies Act of 1978. It is demonstrated empirically that the above policies do affect the required rate of return for utilities and hence their innovative investment behavior

The effects of Title IV of the Clean Air Act amendments of 1990 on electric utilities: An update

Energy Technology Data Exchange (ETDEWEB)

NONE

1997-03-01

This report presents data and analyses related to Phase I implementation of the Clean Air Act Amendment by electric utilities. It describes the strategies used to comply with the Acid Rain Program in 1995, the effect of compliance on sulfur dioxide emissions levels, the cost of compliance, and the effects of the program on coal supply and demand. The first year of Phase I demonstrated that the market-based sulfur dioxide emissions control system could achieve significant reductions in emissions at lower than expected costs. Some utilities reduced aggregate emissions below legal requirements due to economic incentives; other utilities purchased additional allowances to avoid noncompliance. More than half of the utilities switched to or blended with lower sulfur coal, due to price reductions in the coal market which were partially due to the allowance trading program. 21 figs., 20 tabs.

Impact of the legislation on electric utilities

International Nuclear Information System (INIS)

De Long, M.

1982-01-01

The possible impact of Federal nuclear waste legislation on electric utilities is discussed. The proposed legislation will set forth a well defined program enabling utilities with nuclear plants to make long term plans under a statutory mandate committed to an available technology and implementation timetable. The legislation includes the necessary specificity for the utility companies to fulfill their responsibilities in describing their waste disposal plans to their customers, the concerned public, and state and local legislators

Financial statistics of major U.S. publicly owned electric utilities 1995

Energy Technology Data Exchange (ETDEWEB)

NONE

1997-07-01

The 1995 Edition of the Financial Statistics of Major U.S. Publicly Owned Electric Utilities publication presents 5 years (1991 through 1995) of summary financial data and current year detailed financial data on the major publicly owned electric utilities. The objective of the publication is to provide 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 publicly owned electric utility issues. Generator (Tables 3 through 11) and nongenerator (Tables 12 through 20) summaries are presented in this publication. Five years of summary financial data are provided (Tables 5 through 11 and 14 through 20). Summaries of generators for fiscal years ending June 30 and December 31, nongenerators for fiscal years ending June 30 and December 31, and summaries of all respondents are provided in Appendix C. The composite tables present aggregates of income statement and balance sheet data, as well as financial indicators. Composite tables also display electric operation and maintenance expenses, electric utility plant, number of consumers, sales of electricity, and operating revenue, and electric energy account data. 9 figs., 87 tabs.

Financial statistics of major U.S. publicly owned electric utilities 1995

International Nuclear Information System (INIS)

1997-07-01

The 1995 Edition of the Financial Statistics of Major U.S. Publicly Owned Electric Utilities publication presents 5 years (1991 through 1995) of summary financial data and current year detailed financial data on the major publicly owned electric utilities. The objective of the publication is to provide 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 publicly owned electric utility issues. Generator (Tables 3 through 11) and nongenerator (Tables 12 through 20) summaries are presented in this publication. Five years of summary financial data are provided (Tables 5 through 11 and 14 through 20). Summaries of generators for fiscal years ending June 30 and December 31, nongenerators for fiscal years ending June 30 and December 31, and summaries of all respondents are provided in Appendix C. The composite tables present aggregates of income statement and balance sheet data, as well as financial indicators. Composite tables also display electric operation and maintenance expenses, electric utility plant, number of consumers, sales of electricity, and operating revenue, and electric energy account data. 9 figs., 87 tabs

Financing the electric power utilities, especially the nuclear power in Japan

International Nuclear Information System (INIS)

Tajima, T.

1975-04-01

Electric power demands in Japan have shown a remarkable growth at an annual rate of 12% since 1965. Nine electric power companies have invested large amounts of money so far, amounting to over 1 trillion yen every year since 1972. A survey of the electric power supply system and an estimation of the electric power demands in 1980 and in 1985 are given. It is expected that the main portion of electric power in the future will gradually be generated by nuclear plants. Financial features of the electrical power utilities, the credit risk of the electric power utilities, and the raising of funds by electric power utilities are discussed. It is concluded that it will be necessary (1) to expand the capital market, (2) to enable the electric power companies to issue a sufficient amount of bonds, (3) to make the Government financing institutions, such as the Japan Development Bank, provide the electric power companies with larger funds on a long-term and low-interest rate basis, and (4) even to take such drastic steps as subsidizing interest on private loans to the electric power companies. (B.P.)

Risk, innovation, electricity infrastructure and construction cost overruns: Testing six hypotheses

International Nuclear Information System (INIS)

Sovacool, Benjamin K.; Gilbert, Alex; Nugent, Daniel

2014-01-01

This study investigates the frequency and magnitude of cost and time overruns occurring during the construction of 401 electricity projects built between 1936 and 2014 in 57 countries. In aggregate, these projects required approximately $820 billion in investment, and amounted to 325,515 MW of installed capacity and 8495 km of transmission lines. We use this sample of projects to test six hypotheses about construction cost overruns related to (1) diseconomies of scale, (2) project delays, (3) technological learning, (4) regulation and markets, (5) decentralization and modularity, and (6) normalization of results to scale. We find that nuclear reactors are the riskiest technology in terms of mean cost escalation as a percentage of budget and frequency; that hydroelectric dams stand apart for their mean cost escalation in total dollars; that many of the hypotheses grounded in the literature appear wrong; and that financing, partnerships, modularity, and accountability may have more to do with overruns than technology. - Highlights: • Many hypotheses about construction overruns grounded in the literature appear wrong. • Nuclear reactors are the most prone to cost overruns as a percentage of budget and frequency. • Hydroelectric dams stand apart for their mean cost escalation in total dollars. • Solar and wind energy systems are least at risk to cost overruns

Utility-scale variable-speed wind turbines using a doubly-fed generator with a soft-switching power converter

Energy Technology Data Exchange (ETDEWEB)

Weigand, C.H.; Lauw, H.K.; Marckx, D.A. [Electronic Power Conditioning, Inc., Corvallis, OR (United States)

1996-12-31

Utility-scale wind turbines operating at variable RPM have been studied for a considerable period of time. Whereas the increase in energy output originally has been considered the principal benefit of variable-speed operation, the ability to tightly control the drive-train torque by electronic means is becoming another very important cost factor, especially for turbine ratings above 500 kilowatts. This cost benefit becomes even more significant as optimum turbine ratings today are approaching (and surpassing) 1 Megawatt. Having identified the benefits for the turbine, the designer is confronted with the task of finding the most cost-effective variable-speed generation system which allows him to make use of the benefits, yet does not introduce well-known electrical problems associated with state-of-the-art variable-speed generator controls, such as drastically reduced generator winding life, excessive harmonics on the utility, and poor utility power factor. This paper will indicate that for high-power (> 500 kW), utility-scale wind turbines a doubly-fed generator system in connection with a soft-switching resonant power converter is the least-cost variable-speed generation system offering all of the desired benefits, yet avoids the introduction of the potential electrical problems stated above. 3 refs., 3 figs., 1 tab.

A comparison of hydrogen-fueled fuel cells and combustion engines for electric utility applications

International Nuclear Information System (INIS)

Schoenung, S.M.

2000-01-01

Hydrogen-fueled systems have been proposed for a number of stationary electric generation applications including remote power generation, load management, distribution system peak shaving, and reliability or power quality enhancement. Hydrogen fueling permits clean, low pollution operation. This is particularly true for systems that use hydrogen produced from electrolysis, rather than the reforming of hydrocarbon fuels. Both fuel cells and combustion engines are suitable technologies for using hydrogen in many electric utility applications. This paper presents results from several studies performed for the U.S. Department of Energy Hydrogen Program. A comparison between the two technologies shows that, whereas fuel cells are somewhat more energy efficient, combustion engine technology is less expensive. In this paper, a comparison of the two technologies is presented, with an emphasis on distributed power and power quality applications. The special case of a combined distributed generation I hydrogen refueling station is also addressed. The comparison is made on the basis of system costs and benefits, but also includes a comparison of technology status: power ratings and response time. A discussion of pollutant emissions and pollutant control strategies is included. The results show those electric utility applications for which each technology is best suited. (author)

The effect of short recovery period investment on least-cost generation system expansion

International Nuclear Information System (INIS)

Yiqun He; David, A.K.; Fernando, P.N.

1995-01-01

The effect of the short recovery period of private investment on least-cost generation system expansion is analysed, and a trade-off method for generation system expansion, which gives consideration to both the least-cost strategy and the short recovery period of private investment, is presented. First, the optimal mix of generation units under a standard recovery period for all units is established, and then the surcharge, due to the difference between the short recovery period and the standard recovery period, is calculated and shared between all units. The former is an optimization to make best use of natural resources, and the latter is a trade-off method to spread the surcharge throughout the system. (Author)

A perspective on electric vehicles: cost-benefit analysis and potential demand

International Nuclear Information System (INIS)

2011-01-01

This report proposes some quantitative elements to assess the large scale diffusion of electric vehicles and analyse the potential demand for such vehicles. The first part proposes a cost-benefit analysis of the development of electric vehicles based on estimated costs and expected benefits by 2020. It addresses the following issues: framework and hypothesis, total cost of ownership, costs related to the deployment of a network of recharging infrastructures, assessment of external costs, and comparative cost-benefit analysis of electric vehicles. In the second part, the authors aim at identifying a potential demand for electric vehicles from the 2008 French national transport displacement survey (ENTD 2008) which provides recent data on the mobility of the French population

Transmission cost minimization strategies for wind-electric generating facilities

Energy Technology Data Exchange (ETDEWEB)

Gonzalez, R. [Northern States Power Company, Minneapolis, MN (United States)

1997-12-31

Integrating wind-electric generation facilities into existing power systems presents opportunities not encountered in conventional energy projects. Minimizing outlet cost requires probabilistic value-based analyses appropriately reflecting the wind facility`s operational characteristics. The wind resource`s intermittent nature permits relaxation of deterministic criteria addressing outlet configuration and capacity required relative to facility rating. Equivalent capacity ratings of wind generation facilities being a fraction of installed nameplate rating, outlet design studies contingency analyses can concentrate on this fractional value. Further, given its non-dispatchable, low capacity factor nature, a lower level of redundancy in outlet facilities is appropriate considering the trifling contribution to output unreliability. Further cost reduction opportunities arise from {open_quotes}wind speed/generator power output{close_quotes} and {open_quotes}wind speed/overhead conductor rating{close_quotes} functions` correlation. Proper analysis permits the correlation`s exploitation to safely increase line ratings. Lastly, poor correlation between output and utility load may permit use of smaller conductors, whose higher (mostly off-peak) losses are economically justifiable.

A Cost-Effective Electric Vehicle Charging Method Designed For Residential Homes with Renewable Energy

Science.gov (United States)

Lie, T. T.; Liang, Xiuli; Haque, M. H.

2015-03-01

Most of the electrical infrastructure in use around the world today is decades old, and may be illsuited to widespread proliferation of personal Electric Vehicles (EVs) whose charging requirements will place increasing strain on grid demand. In order to reduce the pressure on the grid and taking benefits of off peak charging, this paper presents a smart and cost effective EV charging methodology for residential homes equipped with renewable energy resources such as Photovoltaic (PV) panels and battery. The proposed method ensures slower battery degradation and prevents overcharging. The performance of the proposed algorithm is verified by conducting simulation studies utilizing running data of Nissan Altra. From the simulation study results, the algorithm is shown to be effective and feasible which minimizes not only the charging cost but also can shift the charging time from peak value to off-peak time.

Demand-controlling marketing of electric utilities

Energy Technology Data Exchange (ETDEWEB)

Raffee, H; Fritz, W

1980-01-01

In situations like the shortage of energy resources the particular autonomy of the users concerning energy demand raises more and more aggravating problems for the electric utilities (EU) and, last not least, for society (i.e. the peak-load problem, threatening bottlenecks in the supply situation). Thus the requirement for a demand-controlling marketing strategy of the EU with the help of which the individual demand should be influenced in the following manner is legitimate. The article discusses the targets, strategies, and instruments of marketing performed by the EU under the aspect of their efficiency concerning demand control. The discussion leads to e.g. the following results: that a marketing strategy for the sensible, responsible, and efficent use of energy, in the long-term, serves both the interests of the users and the interests of the EU; that such a marketing programme can have the required controlling effects especially with the help of strategies like market segmentation and cooperation. The discussion makes also clear that a demand-controlling marketing strategy of the EU can hardly be realized without a considerable change within the organization of the EU on one hand and, on the other, without expanding the marketing programme toward a marketing strategy of balance.

National Maglev initiative: California line electric utility power system requirements

Science.gov (United States)

Save, Phil

1994-01-01

The electrical utility power system requirements were determined for a Maglev line from San Diego to San Francisco and Sacramento with a maximum capacity of 12,000 passengers an hour in each direction at a speed of 300 miles per hour, or one train every 30 seconds in each direction. Basically the Maglev line requires one 50-MVA substation every 12.5 miles. The need for new power lines to serve these substations and their voltage levels are based not only on equipment loading criteria but also on limitations due to voltage flicker and harmonics created by the Maglev system. The resulting power system requirements and their costs depend mostly on the geographical area, urban or suburban with 'strong' power systems, or mountains and rural areas with 'weak' power systems. A reliability evaluation indicated that emergency power sources, such as a 10-MW battery at each substation, were not justified if sufficient redundancy is provided in the design of the substations and the power lines serving them. With a cost of $5.6 M per mile, the power system requirements, including the 12-kV DC cables and the inverters along the Maglev line, were found to be the second largest cost component of the Maglev system, after the cost of the guideway system ($9.1 M per mile), out of a total cost of $23 M per mile.

Electric power in Canada 1993

International Nuclear Information System (INIS)

1994-01-01

The electric power industry in Canada in 1993 is reviewed. Items discussed include: the international context of Canadian electricity; regulatory structures; electricity and the environment; electricity consumption; electricity generation; generating capacity and reserve; electricity trade; transmission; electric utility investment and financing; costing and pricing; electricity outlook; demand-side management; and non-utility generation. Appended information is presented on installed capacity and electrical energy consumption in Canada, installed generating capacity, conventional thermal capacity by principal fuel type, provincial electricity imports and exports, Canadian electricity exports by exporter and importer, generation capacity by type, installed generating capacity expansion in Canada by station, federal environmental standards and guidelines, and prices paid by major electric utilities for non-utility generation. 23 figs., 95 tabs

Electric power in Canada 1992

International Nuclear Information System (INIS)

1993-01-01

The electric power industry in Canada in 1991 is reviewed. Items discussed include: the international context of Canadian electricity; regulatory structures; electricity and the environment; electricity consumption; electricity generation; generating capacity and reserve; electricity trade; transmission; electric utility investment and financing; costing and pricing; electricity outlook; demand-side management; and non-utility generation. Appended information is presented on installed capacity and electrical energy consumption in Canada, installed generating capacity, conventional thermal capacity by principal fuel type, provincial electricity imports and exports, Canadian electricity exports by exporter and importer, generation capacity by type, installed generating capacity expansion in Canada by station, federal environmental standards and guidelines, and prices paid by major electric utilities for non-utility generation. 26 figs., 90 tabs

Effect of improved glycemic control on health care costs and utilization.

Science.gov (United States)

Wagner, E H; Sandhu, N; Newton, K M; McCulloch, D K; Ramsey, S D; Grothaus, L C

2001-01-10

Because of the additional costs associated with improving diabetes management, there is interest in whether improved glycemic control leads to reductions in health care costs, and, if so, when such cost savings occur. To determine whether sustained improvements in hemoglobin A(1c) (HbA(1c)) levels among diabetic patients are followed by reductions in health care utilization and costs. Historical cohort study conducted in 1992-1997 in a staff-model health maintenance organization (HMO) in western Washington State. All diabetic patients aged 18 years or older who were continuously enrolled between January 1992 and March 1996 and had HbA(1c) measured at least once per year in 1992-1994 (n = 4744). Patients whose HbA(1c) decreased 1% or more between 1992 and 1993 and sustained the decline through 1994 were considered to be improved (n = 732). All others were classified as unimproved (n = 4012). Total health care costs, percentage hospitalized, and number of primary care and specialty visits among the improved vs unimproved cohorts in 1992-1997. Diabetic patients whose HbA(1c) measurements improved were similar demographically to those whose levels did not improve but had higher baseline HbA(1c) measurements (10.0% vs 7.7%; Pcosts were $685 to $950 less each year in the improved cohort for 1994 (P =.09), 1995 (P =.003), 1996 (P =.002), and 1997 (P =.01). Cost savings in the improved cohort were statistically significant only among those with the highest baseline HbA(1c) levels (>/=10%) for these years but appeared to be unaffected by presence of complications at baseline. Beginning in the year following improvement (1994), utilization was consistently lower in the improved cohort, reaching statistical significance for primary care visits in 1994 (P =.001), 1995 (Pcost savings within 1 to 2 years of improvement.

Historical costs of coal-fired electricity and implications for the future

International Nuclear Information System (INIS)

McNerney, James; Doyne Farmer, J.; Trancik, Jessika E.

2011-01-01

We study the cost of coal-fired electricity in the United States between 1882 and 2006 by decomposing it in terms of the price of coal, transportation cost, energy density, thermal efficiency, plant construction cost, interest rate, capacity factor, and operations and maintenance cost. The dominant determinants of cost have been the price of coal and plant construction cost. The price of coal appears to fluctuate more or less randomly while the construction cost follows long-term trends, decreasing from 1902 to 1970, increasing from 1970 to 1990, and leveling off since then. Our analysis emphasizes the importance of using long time series and comparing electricity generation technologies using decomposed total costs, rather than costs of single components like capital. By taking this approach we find that the history of coal-fired electricity suggests there is a fluctuating floor to its future costs, which is determined by coal prices. Even if construction costs resumed a decreasing trend, the cost of coal-based electricity would drop for a while but eventually be determined by the price of coal, which fluctuates while showing no long-term trend. - Research highlights: → 125-year history highlights the dominant determinants of coal-fired electricity costs. → Results suggest a fluctuating floor to future costs, determined by coal prices. → Analysis emphasizes importance of comparing technologies using decomposed total costs.

Low-cost distributed solar-thermal-electric power generation

Science.gov (United States)

Der Minassians, Artin; Aschenbach, Konrad H.; Sanders, Seth R.

2004-01-01

Due to their high relative cost, solar electric energy systems have yet to be exploited on a widespread basis. It is believed in the energy community that a technology similar to photovoltaic (PV), but offered at about $1/W would lead to widespread deployment at residential and commercial sites. This paper addresses the investigation and feasibility study of a low-cost solar thermal electricity generation technology, suitable for distributed deployment. Specifically, we discuss a system based on nonimaging solar concentrators, integrated with free-piston Stirling engine devices incorporating integrated electric generation. We target concentrator-collector operation at moderate temperatures, in the range of 125°C to 150°C. This temperature is consistent with use of optical concentrators with concentration ratios on the order of 1-2. These low ratio concentrators admit wide angles of radiation acceptance and are thus compatible with no diurnal tracking, and no or only a few seasonal adjustments. Thus, costs and reliability hazards associated with tracking hardware systems are avoided. Further, we note that in the intended application, there is no shortage of incident solar energy, but rather it is the capital cost of the solar-electric system that is most precious. Thus, we outline a strategy for exploiting solar resources in a cost constrained manner. The paper outlines design issues, and a specific design for an appropriately dimensioned free-piston Stirling engine. Only standard low-cost materials and manufacturing methods are required to realize such a machine.

Moving from Outsider to Insider: Peer Status and Partnerships between Electricity Utilities and Residential Consumers

Science.gov (United States)

Morris, Peter; Buys, Laurie; Vine, Desley

2014-01-01

An electricity demand reduction project based on comprehensive residential consumer engagement was established within an Australian community in 2008. By 2011, both the peak demand and grid supplied electricity consumption had decreased to below pre-intervention levels. This case study research explored the relationship developed between the utility, community and individual consumer from the residential customer perspective through qualitative research of 22 residential households. It is proposed that an energy utility can be highly successful at peak demand reduction by becoming a community member and a peer to residential consumers and developing the necessary trust, access, influence and partnership required to create the responsive environment to change. A peer-community approach could provide policymakers with a pathway for implementing pro-environmental behaviour for low carbon communities, as well as peak demand reduction, thereby addressing government emission targets while limiting the cost of living increases from infrastructure expenditure. PMID:24979234

Cost-effectiveness of plug-in hybrid electric vehicle battery capacity and charging infrastructure investment for reducing US gasoline consumption

International Nuclear Information System (INIS)

Peterson, Scott B.; Michalek, Jeremy J.

2013-01-01

Federal electric vehicle (EV) policies in the United States currently include vehicle purchase subsidies linked to EV battery capacity and subsidies for installing charging stations. We assess the cost-effectiveness of increased battery capacity vs. nondomestic charging infrastructure installation for plug-in hybrid electric vehicles as alternate methods to reduce gasoline consumption for cars, trucks, and SUVs in the US. We find across a wide range of scenarios that the least-cost solution is for more drivers to switch to low-capacity plug-in hybrid electric vehicles (short electric range with gasoline backup for long trips) or gasoline-powered hybrid electric vehicles. If more gasoline savings are needed per vehicle, nondomestic charging infrastructure installation is substantially more expensive than increased battery capacity per gallon saved, and both approaches have higher costs than US oil premium estimates. Cost effectiveness of all subsidies are lower under a binding fuel economy standard. Comparison of results to the structure of current federal subsidies shows that policy is not aligned with fuel savings potential, and we discuss issues and alternatives. - Highlights: ► We compare cost of PHEV batteries vs. charging infrastructure per gallon of gasoline saved. ► The lowest cost solution is to switch more drivers to low-capacity PHEVs and HEVs. ► If more gasoline savings is needed, batteries offer a better value than chargers. ► Extra batteries and chargers are both more costly per gal than oil premium estimates. ► Current subsidies are misaligned with fuel savings. We discuss alternatives.

Healthcare Utilization and Costs of Systemic Lupus Erythematosus in Medicaid

Directory of Open Access Journals (Sweden)

Hong J. Kan

2013-01-01

Full Text Available Objective. Healthcare utilization and costs associated with systemic lupus erythematosus (SLE in a US Medicaid population were examined. Methods. Patients ≥ 18 years old with SLE diagnosis (ICD-9-CM 710.0x were extracted from a large Medicaid database 2002–2009. Index date was date of the first SLE diagnosis. Patients with and without SLE were matched. All patients had a variable length of followup with a minimum of 12 months. Annualized healthcare utilization and costs associated with SLE and costs of SLE flares were assessed during the followup period. Multivariate regressions were conducted to estimate incremental healthcare utilization and costs associated with SLE. Results. A total of 14,777 SLE patients met the study criteria, and 14,262 were matched to non-SLE patients. SLE patients had significantly higher healthcare utilization per year than their matched controls. The estimated incremental annual cost associated with SLE was $10,984, with the highest increase in inpatient costs (P<0.001. Cost per flare was $11,716 for severe flares, $562 for moderate flares, and $129 for mild flares. Annual total costs for patients with severe flares were $49,754. Conclusions. SLE patients had significantly higher healthcare resource utilization and costs than non-SLE patients. Patients with severe flares had the highest costs.

Illinois statewide gas utility plan, 1993-2002. Volume 1. Executive summary

International Nuclear Information System (INIS)

1992-12-01

The second Illinois Statewide Natural Gas Utility Plan is a continuation of the Least-Cost Planning effort introduced by the Public Utilities Act of 1986. The purpose of the Plan, like its predecessor, is to provide a framework and a set of policies which will allow and encourage local distribution companies to develop least-cost plans consistent with the goals of the Act: to provide efficient, environmentally sound, reliable, and equitable public utility service at the least possible cost. The Plan assesses natural gas demand and supply under five scenarios for the period 1993-2002. Key issues related to the development of least-cost natural gas plans are identified, and policies for addressing the issues are developed. The rationale and potential for natural gas demand side management (DSM) programs and policies are explored, and recommendations made with respect to utility DSM capability-building and DSM cost-recovery

Cost modelling of electricity-producing hot dry rock (HDR) geothermal systems in the United Kingdom

International Nuclear Information System (INIS)

Doherty, P.; Harrison, R.

1995-01-01

A detailed and comprehensive cost model for Hot Dry Rock (HDR) electricity producing systems has been developed in this study. The model takes account of the major aspects of the HDR system, parameterized in terms of the main physical and cost parameters of the resource and the utilization system. A doublet configuration is assumed, and the conceptual HDR system which is defined in the study is based upon the UK Department of Energy (DEn) HDR geothermal R and D programme. The model has been used to calculate the costs of HDR electricity for a UK defined base case which represents a consensus view of what might be achieved in Cornwall in the long term. At 14.2 p/kWh (1988 costs) this cost appears to be unacceptably high. A wide-ranging sensitivity study has also been carried out on the main resource, geometrical, and operational parameters of the HDR system centred around the UK base case. The sensitivity study shows the most important parameters to be thermal gradient and depth. The geometrical arrangement and the shape of the reservoir constitute major uncertainties in HDR systems. Their effect on temperature has a major influence on system performance, and therefore a range of theoretically possible geometries have been studied and the importance of geometrical effects on HDR electricity costs assessed. The most cost effective HDR arrangement in terms of optimized volumes and flow rates has been investigated for a world-wide range of thermal settings. The main conclusions from this study suggests that for HDR electricity to be economic, thermal gradients of 55 o C/km and above, well depths of 5 km or less, and production fluid temperatures of 210 o C and above are required. (UK)

Tacit Knowledge Capture and the Brain-Drain at Electrical Utilities

Science.gov (United States)

Perjanik, Nicholas Steven

As a consequence of an aging workforce, electric utilities are at risk of losing their most experienced and knowledgeable electrical engineers. In this research, the problem was a lack of understanding of what electric utilities were doing to capture the tacit knowledge or know-how of these engineers. The purpose of this qualitative research study was to explore the tacit knowledge capture strategies currently used in the industry by conducting a case study of 7 U.S. electrical utilities that have demonstrated an industry commitment to improving operational standards. The research question addressed the implemented strategies to capture the tacit knowledge of retiring electrical engineers and technical personnel. The research methodology involved a qualitative embedded case study. The theories used in this study included knowledge creation theory, resource-based theory, and organizational learning theory. Data were collected through one time interviews of a senior electrical engineer or technician within each utility and a workforce planning or training professional within 2 of the 7 utilities. The analysis included the use of triangulation and content analysis strategies. Ten tacit knowledge capture strategies were identified: (a) formal and informal on-boarding mentorship and apprenticeship programs, (b) formal and informal off-boarding mentorship programs, (c) formal and informal training programs, (d) using lessons learned during training sessions, (e) communities of practice, (f) technology enabled tools, (g) storytelling, (h) exit interviews, (i) rehiring of retirees as consultants, and (j) knowledge risk assessments. This research contributes to social change by offering strategies to capture the know-how needed to ensure operational continuity in the delivery of safe, reliable, and sustainable power.

Electricity '93: Focussed for the future [Canadian Electrical Association annual report, 1992

International Nuclear Information System (INIS)

1993-01-01

The Canadian Electrical Association annual report for 1993 is presented. The Association's objectives include providing a forum for studying, discussing, and exchanging information related to the electric utility industry; developing and promotion of policies on production, distribution, and utilization of electricity; acting as an industry advocate before the public and governments; and facilitating Canadian involvement in international activities affecting the electric utility industry. Association members include individuals, 35 corporate utilities, 35 corporate manufacturers, 180 associate companies, and representation from contractors, consultants, academia, and government. Association activities in helping utilities to control costs, sponsoring research and development, enhancing value of electricity to members' customers, and meeting public responsibilities are reviewed. Selected research and development projects are summarized and statistics on Canadian electricity production, generating capacity, energy demand, electricity prices, and exports are included. Lists of research and development projects awarded and completed in 1992 are appended. 10 figs., 2 tabs

Least-cost planning. The way for the restructuring of our energy supply system. Least-Cost Planning. Der Weg zum Umbau unseres Energieversorgungssystems

Energy Technology Data Exchange (ETDEWEB)

Seifried, D

1992-09-01

With the introduction of the central element 'least-cost-planning' the most important and cheapest energy source could be trapped: rational use of energy. For this purpose no new technologies have to be developed. This booklet shows how the in the present energy economy system existing 'forces' to waste energy can be eliminated and financial incentives for rational supply of customers with energy services created. In the area of energy economy not - as often demanded in discussions in the last month - 'deregulation' is needed but the misregulations described in this booklet have to be corrected. This booklet is directed to decision takers in politics and energy economy. (orig.).

Projected costs of generating electricity - 2010 edition

International Nuclear Information System (INIS)

2010-01-01

This joint report by the International Energy Agency (IEA) and the OECD Nuclear Energy Agency (NEA) is the seventh in a series of studies on electricity generating costs. It presents the latest data available for a wide variety of fuels and technologies, including coal and gas (with and without carbon capture), nuclear, hydro, onshore and offshore wind, biomass, solar, wave and tidal as well as combined heat and power (CHP). It provides levelised costs of electricity (LCOE) per MWh for almost 200 plants, based on data covering 21 countries (including four major non-OECD countries), and several industrial companies and organisations. For the first time, the report contains an extensive sensitivity analysis of the impact of variations in key parameters such as discount rates, fuel prices and carbon costs on LCOE. Additional issues affecting power generation choices are also examined. The study shows that the cost competitiveness of electricity generating technologies depends on a number of factors which may vary nationally and regionally. Readers will find full details and analyses, supported by over 130 figures and tables, in this report which is expected to constitute a valuable tool for decision makers and researchers concerned with energy policies and climate change

76 FR 3517 - Standards of Performance for Fossil-Fuel-Fired, Electric Utility, Industrial-Commercial...

Science.gov (United States)

2011-01-20

... Standards of Performance for Fossil-Fuel-Fired, Electric Utility, Industrial-Commercial-Institutional, and... following: Category NAICS \\1\\ Examples of regulated entities Industry 221112 Fossil fuel-fired electric utility steam generating units. Federal Government 22112 Fossil fuel-fired electric utility steam...

Replacement energy costs for nuclear electricity-generating units in the United States: 1997--2001. Volume 4

International Nuclear Information System (INIS)

VanKuiken, J.C.; Guziel, K.A.; Tompkins, M.M.; Buehring, W.A.

1997-09-01

This report updates previous estimates of replacement energy costs for potential short-term shutdowns of 109 US nuclear electricity-generating units. This information was developed to assist the US Nuclear Regulatory Commission (NRC) in its regulatory impact analyses, specifically those that examine the impacts of proposed regulations requiring retrofitting of or safety modifications to nuclear reactors. Such actions might necessitate shutdowns of nuclear power plants while these changes are being implemented. The change in energy cost represents one factor that the NRC must consider when deciding to require a particular modification. Cost estimates were derived from probabilistic production cost simulations of pooled utility system operations. Factors affecting replacement energy costs, such as random unit failures, maintenance and refueling requirements, and load variations, are treated in the analysis. This report describes an abbreviated analytical approach as it was adopted to update the cost estimates published in NUREG/CR-4012, Vol. 3. The updates were made to extend the time frame of cost estimates and to account for recent changes in utility system conditions, such as change in fuel prices, construction and retirement schedules, and system demand projects