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that might otherwise be lost can be stored for later generation. Multiplying out all these factors gives the annual efficiency for each system. The annual efficiency is higher for the plant with thermal storage. These two cases that are being compared are the optimum designs for each. This means that the solar fields have been sized to provide the minimum cost of energy for that plant design. Clearly, the solar field size could be reduced in the no- storage case to reduce the losses of excess energy to the power plant. This might result in a higher annual solar-to-electric efficiency; however, it would also result in a higher cost of electricity. It was previously noted that the turbine was limited to 100% of design gross electric output in this analysis. In actual operational practice, the operators of the SEGS plants routinely operate the plants up to 115% of design output when sufficient solar input exists. Figure 4 highlights the effect of allowing the turbine to operate up to 115% of design. The plant designs for the 115% curve are not the same as the 100% curve. The solar field sizes were re-optimized and are larger in the 115% cases. Allowing the plant to operate at higher output is comparable to reducing the capital cost of the power plant. The impact is largest for the case without thermal storage, because the solar field can be increased the most. In this case, the benefit of adding thermal storage is reduced if the plant is allowed to operate above design output. turbine to operate above rated output, can significantly impact the optimum design. CONCLUSIONS NREL has developed a parabolic trough model that integrates system capital and O&M cost, plant performance, and economic analysis. This provides an important tool that has been used to assess the value of R&D efforts, help optimize plant designs, and support commercial project development efforts. The annual performance calculated by the model has been validated against actual operating data from the one of the existing SEGS plants. ACKNOWLEDGMENTS The author would like to thank KJC Operating Company for providing plant performance and O&M data, and the U.S. Department of Energy’s Concentrating Solar Power Program for support of this work. NOMENCLATURE CSP concentrating solar power DLR Deutsches Zentrum fur Luft-und Raumfahrt e.V DOE Department of Energy DNI direct normal insolation FSI Flabeg Solar International HCE heat collection element HTF heat transfer fluid IPP independent power producer ISCCS integrated solar combined cycle system KJCOC KJC Operating Company LCOE levelized cost of energy LMTD log mean temperature difference LS-2 Luz second-generation trough collector LS-3 Luz third-generation trough collector NREL National Renewable Energy Laboratory O&M operation and maintenance PB power block R&D research and development SEGS solar electric generating system SF solar field SNL Sandia National Laboratory TES thermal energy storage TMY typical meteorological year REFERENCES [1] Luz International Limited (LIL), 1990, “Solar Electric Generating System IX (SEGS IX) Project Description,” LIL Documentation, Los Angeles, CA. [2] Pilkington Solar International GmbH, 1996, “Status Report on Solar Thermal Power Plants,” ISBN 3- 9804901-0-6, Köln, Germany. 0.125 0.120 0.115 0.110 0.105 0.100 Figure 4 Impact of Turbine Maximum Operational Load This thermal storage design optimization study provides a good example of why the NREL model is valuable. The optimization includes complex interactions in components that affect the capital and O&M cost and the system performance. The size of the TES heat exchanger affects the TES system cost, the solar field return temperature, and the power cycle supply temperature. The TES cost is impacted by the heat exchanger cost, but also the resulting temperature difference between the hot and cold tank, which affects the physical volume, required for storing a fixed amount of thermal energy. The solar field return temperature impacts the resulting solar field heat losses and HTF pumping parasitics. The power cycle supply temperature affects the power cycle efficiency and resulting electric output. Even operating constraints, such allowing the 115% 100% 0 2 4 6 8 10 12 Hours of TES 8 LCOE ($/kWh)PDF Image | A Parabolic Trough Solar Power Plant Simulation Model
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