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Coal consumption accounted for 36% of America's C[O.sub.2] emissions in 2005, yet because coal is a relatively inexpensive, widely available, and politically secure fuel, its use is projected to grow in the coming decades (USEIA, 2007, 'World Carbon Dioxide Emissions From the Use of Fossil Fuels,' International Energy Annual 2005, http:// www.eia.doe.gov/emeu/iea/carbon.html). In order for coal to contribute to the U.S. energy mix without detriment to an environmentally acceptable future, implementation of carbon capture and sequestration (CCS) technology is critical. Techno-economic studies establish the large expense of CCS due to substantial energy requirements and capital costs. However, such analyses typically ignore operating dynamics in response to diurnal and seasonal variations in electricity demand and pricing, and they assume that C[O.sub.2] capture systems operate continuously at high C[O.sub.2] removal and permanently consume a large portion of gross plant generation capacity. In contrast, this study uses an electric grid-level dynamic framework to consider the possibility of turning C[O.sub.2] capture systems off during peak electricity demands to regain generation capacity lost to C[O.sub.2] capture energy requirements. This practice eliminates the need to build additional generation capacity to make up for C[O.sub.2] capture energy requirements, and it might allow plant operators to benefit from selling more electricity during high price time periods. Post-combustion C[O.sub.2] absorption and stripping is a leading capture technology that, unlike many other capture methods, is particularly suited for flexible or on/off operation. This study presents a case study on the Electric Reliability Council of Texas (ERCOT) electric grid that estimates C[O.sub.2] capture utilization, system-level costs, and C[O.sub.2] emissions associated with different strategies of using on/off C[O.sub.2] capture on all coal-fired plants in the ERCOT grid in order to satisfy peak electricity demand. It compares base cases of no C[O.sub.2] capture and 'always on' capture with scenarios where capture is turned off during: (1) peak demand hours every day of the year, (2) the entire season of peak system demand, and (3) system peak demand hours only on seasonal peak demand days. By eliminating the need for new capacity to replace output lost to C[O.sub.2] capture energy requirements, flexible C[O.sub.2] capture could save billions of dollars in capital costs. Since capture systems remain on for most of the year, flexible capture still achieves substantial C[O.sub.2] emissions reductions. [DOI: 10.1115/1.4001573]

This paper is the first of a two-part paper presenting a multiperiod generalized network flow model of the integrated energy system in the United States. Part I describes the modeling approach used to evaluate the economic efficiencies of the systemwide energy flows, from the coal and natural gas suppliers to the electric load centers. Under the proposed problem formulation, fuel supply and electricity demand nodes are connected via a transportation network, and the model is solved for the most efficient allocation of quantities and corresponding prices. The methodology includes physical, economic, and environmental aspects that characterize the different networks. Part II of this paper provides numerical results that demonstrate the application of the model. Index Terms--Generalized network flow model, integrated energy networks, nodal prices, optimization.

The usage of autoregressive integrated moving average models, for the statistical analysis of the trends pertaining to the demand and supply of electricity in Turkey, is described.

The usage of hydro-electricity in meeting high energy demands is discussed by focusing on Turkey's energy policy.

A regulatory policy for efficient generation and supply of Brazilian electricity distribution companies that use hydrothermal systems is presented.

Long term demand for electricity and energy in Syria is estimated and analyzed.

The backstop level concept used by developed economies for controlling electricity supply and demand is discussed.

We present a model of a purchaser of electricity in Norway, bidding into a wholesale electricity pool market that operates a day ahead of dispatch. The purchaser must arrange purchase for an uncertain demand that occurs the following day. Deviations from the day-ahead purchase are bought in a secondary market at a price that differs from the day-ahead price by virtue of regulating offers submitted by generators. Under an assumption that arbitrageurs are absent in these markets, we study conditions under which the purchaser should bid their expected demand and examine the two-period game played between a single generator and purchaser in the presence of a competitive fringe. In all our models, it is found that purchasers have an incentive to underbid their expected demand, and so the day-ahead prices will be below expected real-time prices. We also derive conditions on the optimal demand curve that purchasers should bid if the behavior of the other participants is unknown but can be modeled by a market distribution function. Index Terms--Games, optimization methods, power system economics.

The failure of Britain's electric utilities industry in meeting with increasing energy demands is discussed.

The environmental benefits of electric system expansion and the possible use of renewable energy sources, in coping with growing demand for electricity in Saudi Arabia, are discussed. The impact of expanded electricity system is assessed by the Integrated Resource Planning (IRP) frame work by a team of Saudi utility planners and international consultants.

Climate is a major determinant of energy demand. Changes in climate may altar energy demand as well as energy demand patterns. This study investigates the implications of climate change for energy demand under the hypothesis that impacts are scale dependent due to region-specific climatic variables, infrastructure, socioeconomic, and energy use profiles. In this analysis we explore regional demand responses to climate change by assessing temperature-sensitive energy demand in the Commonwealth of Massachusetts. The study employs a two-step estimation and modeling procedure. The first step evaluated the historic temperature sensitivity of residential and commercial demand for electricity and heating fuels, using a degree-day methodology. We find that when controlling for socioeconomic factors, degree-day variables have significant explanatory power in describing historic changes in residential and commercial energy demands. In the second step, we assess potential future energy demand responses to scenarios of climate change. Model results are based on alternative climate scenarios that were specifically derived for the region on the basis of local climatological data, coupled with regional information from available global climate models. We find notable changes with respect to overall energy consumption by, and energy mix of the residential and commercial sectors in the region. On the basis of our findings, we identify several methodological issues relevant to the development of climate change impact assessments of energy demand.

The energy procurement decisions made by California in response to different energy scenarios over the years are discussed. The likely reasons behind the state's continued reliance on polluting and diminishing fossil fuel and its failure to develop cleaner and more abundant alternative energy sources are analyzed.

A study of different methods to account for change in greenhouse gas emissions due to a change in use or supply of electricity in the deregulated Nordic electricity market having hydropower, nuclear and fossil fuel types of power generation are discussed. A comprehensive accounting scheme facilitates cost-effective carbon dioxide mitigation procedures by providing an accurate link between the different energy measures and their related emissions and to reduce Greenhouse gases (GHG) in line with the Kyoto mechanisms is presented.

The usefulness of cross subsidies in electricity tariffs in India is examined. Data from a distribution company in the state of Uttar Pradesh, India is used to estimate industrial demand for electricity, and it is found that the policy of cross subsidy may have indeed gone overboard in India.

Local distribution companies (LDCs) have the mandate to supply electricity to the customers, upon demand, with whom they have contracted. An LDC can acquire electricity through its own plant facility, spot market purchases, and fixed-price forward contracts.

Demand for electricity in India is studied using local data. Electricity demand is found to be inelastic in price and income.

The manufacturing segment in Nigeria sufferes considerable loss of electricity, indicating a need for increased supply.

The unilateral incentives for excising market power by the five largest electricity suppliers in California's wholesale market during specific periods between 1998 to 2000 is analyzed. The firm-level measures of market power indicate that co-ordinated action by suppliers where unnecessary to bring about the substantial price increase. This increase was a result of the expected profit maximizing response of each of the suppliers to the bidding behavior of all other market participants in the California market.

Wholesale electricity payments are comprised of three parts, i.e., production costs, competitive rents and market power. A study of the electricity payments data from June 1998 to October 2000 in California reveals that competitive pricing is indirectly proportionate to demand.

Byline: Mark Lijesen (1), Hein Mannaerts (2), Machiel Mulder (2) Keywords: electricity; liberalization; service reliability Abstract: We discuss under what conditions California's electricity crisis may happen in Western European countries, taking The Netherlands as an example. We use a simulation model containing the electricity generation and distribution sector. We simulate exogenous events, such as a sudden shift in demand levels, a sharp rise in world fuel prices and a cutback in foreign supply. We use the model to investigate whether supply remains secured under different regulatory regimes. Our results suggest a trade-off between controlled prices and security of supply. Europe's electricity supply security is vulnerable if prices are not allowed to reflect scarcity. If prices are unrestricted however, they will reach oligopoly levels. Author Affiliation: (1) Department of energy and raw materials, CPB, Netherlands Bureau for Economic Policy Research, USA (2) Department of energy and raw materials, CPB, Netherlands Bureau for Economic Policy Research, USA Article History: Registration Date: 12/10/2004

Byline: Carl Blumstein (1), Richard Green (2) Keywords: electricity markets; electricity restructuring; California's electricity crisis Abstract: This short piece introduces the papers in the special issue on the California Energy Crisis of 2000/2001. The papers illustrate aspects of the crisis, such as the role of the gas market, future trends for investment, and the crisis' impact on consumers. Three papers analyze policy-makers' responses to the crisis, with case studies of over-lapping regulation, the trade-off between prices, reliability and the environment, and policies that helped achieve demand reductions in the summer of 2001. Two papers consider lessons for other countries, in Latin America and Europe. Author Affiliation: (1) University of California Energy Institute, 2539 Channing Way, Berkeley, CA, 94720-5180, USA (2) Economics Group, University of Hull Business School, Cottingham Road, Hull HU6 7RX, UK Article History: Registration Date: 12/10/2004

The problem of ensuring that there is enough generation capacity to meet future demand has been an issue in market design since the beginning of the deregulation process. Although ideally the market itself should be enough to provide adequate investment incentives, there are several factors that prevent this result from being achieved, and some actual markets have already experienced problems related with a lack of generation capacity. A regulatory framework to address this question is presented. The procedure is based on an organized market where reliability contracts (based on financial call options) are auctioned, so both their price and their allocation among the different plants are determined through competitive mechanisms. This results in a stabilization of the income of the generators and provides a clear incentive for new generation investment, with a minimum of regulatory intervention. Additionally, the method represents a market-compatible mechanism to hedge demand from the occurrence of high market prices. Index Terms--Capacity markets, capacity payments, electricity markets, generation adequacy, long-term guarantee of supply, wholesale market design.

Strategies for generators making offers into electricity markets in circumstances where both the demand for electricity and the behavior of competing generators is unknown but can be represented by a probability distribution are studied. Necessary optimality conditions for a broad class of supply offer curves are derived and the ways in which these conditions can be used to construct an optimal solution for a simple example are shown.

The rationing of electricity could be done via a two-step process that assumes a significant degree of customer willingness to pay. This process involves knowledge of current rationing systems to establish rationing plans and implement them. The resultant welfare enhancements of the method should convince consumers of its soundness and encourage a higher degree of participation from them.

China's energy industry is troubled by increasing demand and inability to manufacture new power-generating equipment because of lack of funds. Only two-thirds of the population is provided with electricity while power shortages are a frequent occurrence. The influx of an adequate amount of foreign investment and the establishment of more efficient power plants appear as the best solution to this critical problem.

The problem of forecasting electricity consumption in terms of load-duration curves is discussed. A variant of a time-series method which includes Kalman filtering, smoothing and prediction is used on empirical data from New Zealand to forecast the country's electricity load curve and subsequent load-duration curve considering such factors as holidays, daylight savings and temporal cycles. This particular model can also produce confidence intervals for the forecasts of the two curves.

A new framework with a combination of fixed and random coefficients is proposed for regional modeling and impact analysis. The results show that the framework allows the presence of region-specific effects and commonality of responses among regions. The framework uses Bayes solutions for estimating required parameters and generating predictions while a density function is used to assess the impact of policy changes.

A study was conducted on the use of the cross-sectionally correlated and time-wise autoregressive model (CSCTWA) to estimate residential demand for electricity. CSCTWA simultaneously considers autocorrelation, spatial correlation and heteroscedasticity. Pooled data from five Southern states during the 1981-1990 period were used. Results showed that CSCTWA provides better estimates containing lesser standard errors compared to the OLS and cross-sectionally heteroscedastic and time-wise autoregressive models.