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field and power cycle costs, more representative functions could be used in their place if more detailed data was available. SunLab predicts that the solar field collector system will represent approximately 75% of the total project capital cost with the remainder accounting for power cycle and balance- of-plant equipment. This information is used to formulate the following cost functions that relate relative solar field and power cycle investment in terms of solar field area, power cycle heat exchanger area and power cycle output: [5.2.19] [5.2.20] The functional form of equations [5.2.19] and [5.2.20] is based on models presented by Boehm [1987]. The power cycle cost is divided into two components, power output and heat exchanger area. Heat exchanger area is related to heat exchanger and cooling system cost. Plant output is related to turbine, generator, piping and auxiliary system cost. The equal weighting is based on a break-down of power cycle costs at the SEGS VI parabolic trough plant reported by Pilkington [2000]. The cost scaling factors for heat exchanger area and power are obtained from data compiled by Boehm [1987]. Solar field unit cost is expected to reduce over time as global production increases, however current production capacity is insufficient to create economies of scale [5.2.19] [Sargent & Lundy, 2003]. APC,REF, and ASF,REF are defined in terms of a baseline case consistent with current parabolic-trough plant design practice. The cost models (Eqns [5.2.19] and [5.2.20]) include only capital expenses and neglect O&M costs. Inclusion of O&M costs would favor smaller solar fields because the solar field is responsible for the majority of the planned O&M costs in PTSPs [Price, 1999]. The investment ratio (IR) is defined as the ratio of total plant capital cost to design point 3⎛ A ⎞1 Solar Field Cost = ⎜ SF ⎟ 4⎜A ⎟ ⎝ SF,REF ⎠ PowerCycleCost=1⎢1⎛ W ⎞ +1⎜ APC ⎟ ⎥ ⎜&⎟⎜⎟ 4⎢2⎝WREF ⎠ 2⎝APC,REF ⎠ ⎥ ⎣⎦ 77 ⎡ & 0.67 ⎛ ⎞0.59⎤PDF Image | Organic Rankine Cycle Solar-Thermal Powerplants
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