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Locating the four Rankine cycles at one location offered the following benefits: • Plant Availability The default plant availability within Excelergy is 94.0 percent, based on the following: a 10-day scheduled outage every year; an extended 5-week scheduled outage every 10 years (3.5 days per year); and an unscheduled forced outage rate of 2.3 percent (8.4 days per year). For the adjacent plant option, the 4 steam generators can, during the winter months, supply steam to 1, 2, 3, or all of the Rankine cycles. As such, each Rankine cycle can, in series, be removed from service during the winter months for scheduled maintenance without reducing the plant electric output. In principle, it should be possible to eliminate both the 10 day scheduled outage and the 3.5 day extended scheduled outage from the availability calculations. The flexibility in Rankine cycle operation should also allow a reduction in the unscheduled forced outage rate of perhaps 10 percent. With these changes, the plant availability increased by 3.7 percentage points to a new value of 97.9 percent. • Annual Solar-to-Electric Efficiency The Rankine cycle efficiency, as a function of load, is modeled in Excelergy as follows: Nth = .Qtpb / Qdesign Nel = T2EPLF0 + T2EPLF1 * Nth + T2EPLF2 * Nth2 + T2EPLF3 * Nth3 + T2EPLF4 * Nth4 The default values for the coefficients are -0.0377, 1.0062, 0.0763, -0.0448, and 0.0000. For the adjacent plant option, it should be possible to isolate one or more Rankine cycles during the winter months. The Rankine cycles which remain in operation then operate at higher loads and at higher thermal-to-electric efficiencies. In the limit, the improved efficiencies can be modeled in Excelergy by selecting coefficients of 0, 1, 0, 0, and 0 for the equation above. Running Excelergy with the latter coefficients increased the net plant output by about 0.36 percent. The modest improvement can be traced to a comparison of Nel for the two sets of coefficients. For loads above 40 percent, the two efficiency values were almost identical; only when the load fell below 25 percent was there a marked advantage to isolating a Rankine cycle. Since the annual winter energy delivered with the Rankine cycle operating at loads below 25 percent was rather limited, the annual improvement in energy output was also modest. • Operation and Maintenance Costs A modest improvement in the efficiency of the operation and maintenance staff should accrue if all of the thermal storage and the Rankine cycle equipment are in one location. An analysis of the potential savings is described in Section 7, Operation and Maintenance Costs. Compared to the separated power block option, the adjacent plant option required additional field piping headers to distribute the heat transport fluid to the collector loops. The incremental piping, and the associated design point pressure losses, are presented in Table 2. In principle, the primary North-South headers to and from the power blocks could use a 102 inch diameter line for both the cold fluid and the hot fluid. However, the required wall thicknesses would be about 1.5 inches for the cold line, and 1.1 inches for the hot. For pipe sizes of 42 inches and above, the heaviest commercial wall thickness is 1.00 inch. For the purposes of the study, three 60 inch diameter lines for the cold fluid, and two 84 inch diameter lines for the hot fluid, were selected to retain the use of commercial pipe sizes and wall thicknesses. Task 3 Multiple Plants at a Common Site - 10 -PDF Image | Nexant Parabolic Trough Solar Power Plant Systems Analysis 2005
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