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Risk indices of loss-of-load expectation and loss-of-energy expectation were traditionally used to determine generation adequacy. However, because responsibility of generation installation and transmission upgrades rests with different entities, both generation and transmission need to be examined to evaluate the resource adequacy of today's deregulated power systems. Further, it is important to delineate the contribution to curtailments arising from insufficient installed capacity and bottlenecks in transmission system. Hence, risk-based planning and market decision-makings have to address both generation and transmission jointly. This paper presents a procedure to combine dynamic optimization and Monte Carlo simulation to generate a vector space of solution, from which optimal solutions for different objectives can then be easily obtained. Determining locational capacity and transmission requirements serves the example of such an application. This paper closes with a discussion on some possible changes to risk criteria. Index Terms--Installed capacity, loss-of-load expectation (LOLE), optimization, reliability, risk, transfer capability.

Under the deregulated environment of electric power industry, generation can be installed anywhere in the system resulting in an 'imbalance' between the generation and transmission. Shortages of generation in some subregions result in 'bottlenecks' within a system raising reliability concerns regarding subregional adequacy. Excess of generation capacity raises the issue of how much capacity in which location is entitled to receive payments for installed capacity. Therefore, there is a need to determine locational requirement for both generation and transmission such that assistance to subregions under random generator outages is not restricted. This paper presents optimization procedures for the determination of adequacy and responsibility for locational generation and transmission. The outlined procedures applicable to situations of planning to identify additional needs as well as to situations of market design for installed capacity in subregions. The paper closes by a discussion of forward auctions for the procurement of capacity in subregions. Index Terms--Installed capacity, loss of load expectation, optimization, reliability, risk, transfer capability.

There are several issues in the deregulated markets that impinge on dispatching, pricing, and planning. It appears premature to desire a standard practice before resolution of such issues. This paper outlines the issues and debates possible remedies.

Complying with FERC Orders 888 and 889, electric utilities in the United States of America are setting up competitive markets for Installed and Operable Capacity, Energy, Spinning and Non-Spinning Reserve, and Automatic generation Control. This paper addresses the issues of Installed and Operable Capacity. The possibilities of combining the two markets using reliability as a yardstick is proposed. The proposed market is dynamic (hourly) in which participating entities carry capacity such that all systems have the same reliability.

We examine some alternatives available to postpone the upgrading of distribution facilities such as upgrading a transformer in a substation, or reconductoring a line. This concept of distributed utility installation examines alternative technologies from a central inventory to be wheeled into a substation, operated for a few months and moved to a different substation if conditions warrant. The economics of holding portable energy storage units to postpone transformer upgrades are examined for their optimum size, using the distribution system of a utility in a large metropolitan area as an example. The optimization method uses a dynamic program. This analysis is also applicable to other technologies such as flywheel energy storage, photo-voltaic generation, or fuel cells.

The concept of installing dispersed resources in a utility distribution or subtransmission system is gaining interest in the industry. Such resources could be photovoltaic cells, wind generation, battery storage, fuel cells or demand-side management solicitations. Research by others has suggested that the benefits of distributed resources could be substantial. However, these distributed benefits are site specific. A method to optimally locate such resources in a meshed network for maximizing the potential benefits is outlined in this paper. The proposed second order algorithm computes the amount of resources in selected nodes to make up a given total to achieve the desired optimizing objectives. The network under consideration could be a transmission, sub-transmission, or distribution network. The benefit expressed as a performance index can be the minimization of losses, var losses, or loadings in selected lines.

Present techniques used in value-based planning do not properly represent neither the durations of capacity outage nor the effects of outage on post-interruption demand. Generation outage models do not relate the expected quantum of shortages to particular durations of outage. A model is proposed to compute this expectation by using the generator outage statistics in its entirety. The application of this model to the IEEE test system gave different results, depending on which outage cost data were used. Consequently, there is a need for a uniform procedure to report outage costs. A 'bottom-up' procedure based on end use is proposed as a possibility. Keywords: Planning, outage costs, Value of service, reliability worth.

Optimal re-dispatch to alleviate transmission congestion has been modeled as a nonlinear optimization program. A hyperbolic tangent function in the index of performance permits the dispatch of reactive power based on bids. A new approach to allocate the cost of congestion and losses to the nodes of the transmission network based on the nodes' responsibility is proposed. This approach overcomes some asymmetries of the Locational Marginal Pricing methods. Index Terms--Load flow analysis, optimization methods, power transmission.

In deregulated electricity markets, transactions take place between suppliers and buyers located at different nodes of the network. The electrical network connecting such transacting nodes may form complex paths between nodes with intermediate nodes and parallel paths. This paper maps the complex meshed electrical network to radial network equivalents to mirror the transactions. Such equivalent networks do not replace the existing power flow analyzes, simultaneous feasibility tests, or other procedures. However, the equivalents obtained by using quadratic programs, retain the properties and laws of physics of the original network while offering a convenient method of tracking market transactions to allocate costs and responsibilities. Applications to the allocation of losses, reactive power, and congestion contracts are shown. Index Terms--Equivalent circuits, load flow analysis, optimization methods, power transmission, quadratic programming.

Formulates and solves the optimal dispatch problem in an electric power system as a Mixed Integer Linear Program. Overview of the market structure; Background information on optimal choice of ancillary service; Mixed integer program formulation; Results of computation.