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NREL in 1999 [9]. The FSI cost model is very detailed and uses reference quotes for each cost element. When the quote is for a specific equipment capacity, the model uses scaling factors to adjust the costs for sizes other than the reference cases. The scaling equation takes the general form: Cost2 = (C2/C1) 0.7 x Cost1 where: Cost1 is the reference cost for a piece of equipment of capacity C1 Cost2 is the predicted cost of the equipment at the desired capacity C2. The exponent varies for each cost element and is calculated from two reference quotes; however, 0.7 is used for common equipment when only one quote is available. The cost data provided to NREL is a summarized version. All components that make up the collector structure, for example, are grouped into a single cost element. The NREL cost model uses the same scaling factor approach to adjust costs on the grouped expenses. The NREL cost model generally reproduces the FSI costs within a few percentage points. The cost data has been modified in a few places to better reflect the baseline parabolic trough system that would be built. Specifically, the collector model has been enhanced to account for different collector designs. The thermal storage costs are based on the Nexant thermal storage cost model [10] and adjusted for variations in thermal storage configuration as appropriate [11]. All variations from the Flabeg cost assumptions are detailed in the appropriate section below. Land: A parabolic trough field uses approximately one hectare per 3,000 m2 of collector area, or a coverage of factor of about 0.3 m2 of collector for every 1.0 m2 of land area. Site Works and Infrastructure: The site works and infrastructure includes general land preparation, roads, fences, and site infrastructures, such as firewater system, warehouse, and control building. The cost model assumptions are based on the FSI input. This category scales based on the size of the solar field. Solar Field: The solar-field cost estimates are based on an updated cost assessment produced by FSI [9]. The cost estimate is based on the LS-3 collector design. Several adjustments are made to the collector cost to account for a specific collector design used: • The number of receiver tubes, flex hoses, drives, sensors, and local controllers are adjusted per unit area of collector. • The drive costs are adjusted to account for the collector size. • The mirror, steel structure, pylons, header piping, and civil work costs are assumed to be the same on a per-square- meter basis for different collectors. Heat Transfer Fluid (HTF) System: The HTF system includes the HTF pumps, solar heat exchangers, HTF expansion vessel, piping, valves, and instrumentation. HTF system costs scale based on the power-plant size, except for the HTF pumps, which scale based on solar-field size. The HTF costs are based on the FSI roadmap data. The later data was only appropriate for an ISCCS-type plant. Thermal Energy Storage (TES): The thermal storage costs are based on the detailed design study performed by Nexant for a two-tank, molten-salt storage system [10]. Thermal storage tanks and costs are based on detailed data from Solar Two and Solar Tres. The heat exchanger costs are based on manufacturer quotes. Storage costs were broken into mechanical equipment (pumps and heat exchangers), tanks, nitrate salt, piping, instrumentation and electrical, and civil and structural. The mechanical equipment and piping, instrumentation, and electrical costs were scaled by power-plant size. The tank, salt, and civil costs were scaled by storage volume. All storage costs assume a scaling factor of 1.0, so a storage system twice as big costs twice as much. Thermal storage tank and salt costs are consistent between the trough and tower designs. The trough thermal storage system must be approximately three times as big as the tower storage system (both in tank size and volume of salt required) to store as much energy because of the much lower temperature difference between the fluid in the hot and cold tanks in the trough plant. Power Cycle: The power cycle includes the steam turbine and generator and all condensate and steam cycle equipment including pumps, heat exchangers, piping, valves, instrumentation, and controls. The FSI studies [2] have the most recent Rankine steam-cycle cost data for the systems used in trough designs. Balance of Plant: The BOP includes other power plant systems, such as cooling towers, water treatment and storage, electrical, and control systems. Contingencies: Contingencies of 10% are included for all costs, except the solar field (5%), structures and improvements (20%), and thermal storage. The cost of the solar field is very well understood at this point. The larger contingency for structures and improvements is included to account for potential differences in site preparation. Nexant included cost contingencies separately in the thermal storage. Indirect Costs: Indirect costs include services, project costs, and management reserve. The indirect cost assumptions were based on input from Nexant. Service costs include project management, project engineering, and construction management services. Project costs include permits and licenses, utility connections, and telecommunication links. No interest during construction is included; this is accounted for in the financial model. O&M COST MODEL The O&M cost model is an expansion of the work presented in the KJCOC O&M cost reduction study [12]. The model builds on the KJCOC methodology for O&M of large- scale parabolic trough power plants. The O&M costs are broken into categories of labor, spare parts, and equipment and into 4PDF Image | A Parabolic Trough Solar Power Plant Simulation Model
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