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temperature for dry systems. As these temperatures rise, the turbine back pressure also rises, with a resultant reduction in turbine efficiency. Plant output can sometimes be maintained by increasing the steam flow to the turbine if the steam supply system has additional capacity. Alternatively, in the case of a fixed steam supply, the plant output will decrease. Capacity Penalties If ambient temperatures rise sufficiently high, the achievable back pressure may exceed the maximum allowable back pressure specified for the turbine. In this case, steam flow must be reduced to protect the turbine, and plant output will be limited at that level. Cost The performance and cost issues are inextricably related. The initial choice of a larger, higher capacity and, hence, more expensive cooling system will result in higher plant capacity and more efficient operation for the life of the plant. This is true for all cooling systems, wet as well as dry. In general, a proper cost comparison among alternative cooling systems must be made between optimized selections at a particular site. An optimized system would normally be defined as one that minimizes the sum of all costs---initial capital cost, operating energy cost, efficiency penalty cost, and capacity penalty cost---for the life of the plant. The magnitudes of these cost elements are dependent on many variables. Some of the most important include the operating characteristics of the plant generating components, the meteorology at the plant site, the present and projected costs of fuel, the present and projected price of power, and the projected demand profiles for the plant. The choice of the optimum or preferred design also depends on the relative importance assigned to present vs. future costs, which depends strongly on the economic objectives and business plans of the plant owner. Therefore, the “optimum system” or the “system of choice” might range from a system of lowest first cost to one of lowest total lifetime cost projected for a 30-year or longer lifetime. To illustrate the methodology for determining the various cost elements and for selecting an “optimum” system based on a range of criteria, case studies were conducted at four sites typical of conditions in California. In each case the cooling system was sized to condense the turbine exhaust steam from the steam portion of a nominal 500-MW gas-fired combined-cycle plant typical of what is currently being proposed and built in California. Initial capital costs for wet and dry cooling systems that could provide suitable cooling for the four case study sites vary greatly, ranging from $2.7 to $4.1 million for wet systems and from $18 to $47 million for dry systems. Figure 9-1 displays the initial capital costs for wet and dry cooling systems of both “lowest first cost” and “optimized” designs for each of the four sites. Summary and Conclusions 9-3PDF Image | Comparison of Alternate Cooling Technologies for California Power Plants Economic, Environmental and Other Tradeoffs
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