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cost as well. The non-evacuated receiver appears to be a reasonable trade-off to reduce O&M requirements and initial capital cost. The analysis assumes a two-tank Caloria thermal storage system, which should be acceptable given appropriate design. A critical focus of the plant design is to minimize O&M costs. The plant should be designed to operate without the need of an onsite operator. Ideally, the plant would be able to start-up and shut down automatically. The system should allow remote monitoring and control. Although this type of operation has not been possible at the SEGS plants, it may be feasible for a small ORC system. The solar field may consist of a single or only a few flow paths, which greatly simplifies the flow balance issues that the large SEGS plants face with 50 or 100 parallel flow loops. In addition, the smaller size means that the collectors will all see cloud cover at approximately the same time, whereas the large SEGS plants can experience significant differences in cloud cover from one side of the solar field to the other. Also the two-tank thermal storage will allow better automation and flow control of the solar field. The recuperated ORC power cycle should be much simpler to start-up and shut down than the complex regenerative reheat steam turbines with sub-atmospheric condensers. However, this type of automated operation has not been demonstrated and, thus, remains an issue. Based on the results of the design analysis and discussion with industry, we believe that the modular trough power plant evaluated in this study is technically feasible. Given the apparent maturity of the two technologies being integrated, we believe that with appropriate care in design, manufacture, and construction, a commercial system could be produced today by the existing ORC and solar industry without too much difficulty. The economic feasibility is more difficult to assess. The baseline system optimized for solar field size and amount of thermal storage required a 20¢/kWh energy payment for economic feasibility. Although some potential exists to reduce this cost, in the near-term it is clear that higher value markets, premiums for green power, or other incentives are likely to be necessary for these systems to make economic sense in a commercial environment. However, some of the incentives currently available for photovoltaic systems would be more than sufficient to make these systems economic in existing markets. In the longer-term, systems could potentially achieve economic competitiveness with other power technologies for distributed retail, high-value green markets, and remote power applications. Expanded tax incentives could greatly help current and future MTPP economics. Siting issues significantly impact system performance and the resulting cost of electricity. The solar resource is the primary issue, but ambient temperature is also important (lower temperatures are better). However, availability of special market, financial, or taxation incentives could be even more important than solar resource or ambient temperature considerations. Future development needs include: further analysis of ORC working fluids, additional optimization of ORC power cycles, an improved understanding of O&M costs, development of automated control systems, design of SF for modular systems, and additional development of thermal storage for this size system. The technology is generally ready for commercial demonstration. In our judgment, modular trough power plants are likely to be the lowest risk and most cost effective solar technology option in the 100-kWe to 10-MWe system range for the near-term applications. 48PDF Image | Modular Trough Power Plant Cycle and Systems Analysis
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