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• The effect can be seen of different approaches to the cost comparison methodology; effects arise from – Different methods of setting baselines and determining the amount of reduced capacity or generated energy resulting from the use of dry cooling; – Different methods of determining the cost of replacing these shortfalls; – Differences in site meteorology; and – Differences in plant characteristics, such as the effect of different steam turbine designs (conventional, high back pressure, extended range, etc.). The studies were done by steam turbine vendors (GE and Westinghouse), architect-engineering firms (R. W. Beck, Gilbert Associates, United Engineers and Constructors) and consulting firms (Dynatech R/D Company). A comprehensive survey of these studies was conducted by Mitchell (Mitchell 1989) to put them on a common basis and understand the differences among them. Detailed discussions of each study are found in that reference. The studies summarized in this section were performed by R.W. Beck (Rossie, 1970; Rossie, 1972; Rossie, 1973; Mitchel,l 1978), United Engineers and Constructors (Hu, 1976; Hu, 1977 ; UEC, 1975), GE (Sebald, 1976), Westinghouse (Oleson, 1972), Gilbert Associates (Clukey, 1976), and Dynatech (Guyer, 1980). Summary results are presented here in Figures 5-3 to 5-6 as ratios of the important cost indicators: • Capital cost ratios (Figure 5-3) • Capital cost + capacity replacement cost ratios (Figure 5-4) • Total evaluated cost ratios (Figure 5-5) • Busbar power production cost ratios (Figure 5-6). Cost factors are defined as follows: • Capital cost: includes everything from the turbine flange outward plus, where appropriate, incremental steam supply costs, turbine-generator cost adders, and cost of supplemental system for providing cooling for plant auxiliaries. • Capacity replacement cost: cost of equipment needed to deliver to the power system that amount of generating capacity lost on the hottest hour of the year as a result of using dry cooling as compared to a reference (baseline system), usually wet cooling. • Total evaluated cost: includes only costs affected by the choice of cooling system (cooling system capital cost, fixed O&M costs, replacement capacity and energy costs, cooling system make-up water costs, and incremental fuel costs in cases where the steam supply was scaled up to account for the poorer heat rates of high back-pressure turbines). • Busbar production cost: includes all the costs of generating electricity and the plants being compared (since the cooling system costs are a small fraction of the total plant capital, operating, and fuel costs, these ratios are normally close to unity, even when the total cooling system cost ratios are 3 to 5 or higher). Comparative Cost Analyses 5-5PDF Image | Comparison of Alternate Cooling Technologies for California Power Plants Economic, Environmental and Other Tradeoffs
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