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ambient temperature using 2008-2011 heat consumption and meteorological data (CU Facilities Services, 2013). Our model calculates both the required reservoir temperature and the geofluid flow rate based on a given heat load and a selected DH supply temperature. The DH supply temperature is chosen by the governing optimization procedure described in a latter section of this paper. The DH return temperature is then calculated using a generalized model of a space heating system and countercurrent heat exchanger. The space heating supply/return temperatures vary from 82°C/72°C at high heat demand to 71°C/65°C at low heat demand (CU Facilities Services, 2013). Heat and pressure losses in the district heating network District heating system in the North Campus and Vet School areas was converted from steam to hot water. Replaced pipe diameters were selected to yield a moderate pressure drop of 160 Pa/m (Petitjean, 1994). Pressure losses and parasitic power requirements were evaluated using Darcy-Weisbach equation. In addition, we calculated heat losses from the district heating network. The overall heat transfer coefficient of DH piping was found to be very similar for both hot water and steam distribution systems. Thus, the heat losses were almost entirely determined by the temperature difference between the heat transfer medium and the surrounding environment. Enhanced Geothermal System (EGS) The maximum productivity of a single geothermal well was set at 80 kg/s (Tester et al., 2006), which corresponds to an assumed commercially mature level for EGS technology. One injection well can be used in conjunction with up to two production wells. The geothermal gradient in Ithaca, NY was set at 30°C/km (Shope et al., 2012). To simulate the lifetime of an EGS reservoir, we used a multiple parallel fracture model developed at Cornell Energy Institute (Fox et al., 2013). This model evaluates the temperature within reservoir as a function of time. The analytical solution is based on Green‟s functions and utilizes a convolution integral to accommodate for variable geothermal fluid reinjection temperatures throughout the course of a year. Organic Rankine Cycle (ORC) The efficiency of the ORC power plant was evaluated using a model of a sub and supercritical working fluid cycle conditions created in Aspen Plus software. Twenty five different working fluids were considered in this study. R32 fluid was chosen based on its high utilization efficiency at heat source temperatures between 100°C and 140°C. Both the net power output and the temperature of the heat source fluid exiting the ORC plant were evaluated as a function of heat source and heat sink temperatures. ECONOMIC EVALUATION The numerical model of the proposed system incorporates an economic evaluation module. In our calculations, the annual discount rate was set at 6% and the payback time was assumed to be 20 years. The remaining economic assumptions are discussed below. Capital investment costs: Geothermal well drilling and completion costs were estimated using the following correlation in 2012 $U.S. (Beckers et al., 2013): (1) Where the measured well depth in meters. is expressed in M$ and MD is ORC power plant cost: 4000 $/kWe of installed capacity Pre-insulated district heating distribution piping costs were obtained from (Rafferty, 1996) and normalized to current year dollars using a plant construction cost index (Intratec, 2012) District heating circulation pumps: 150 $/kWe Costs of heat exchangers were based on (Perry et al., 2008) and normalized to the current year dollars using a cost index. Costs of space heating systems in greenhouses were based on (Boyd et al., 2008) Component-specific factors were used to convert delivered-equipment costs to installed costs. We used factors of 3.5 for heat exchangers and 4 for pumps (Perry et al., 2008) Operation and maintenance (O&M) costs: Natural gas price (as purchased by Cornell University): 4.5 $/MMBTU. No escalation rate was assumed. O&M costs of the existing CHP plant and DH system without fuel costs: 20 M$/year O&M costs of EGS system were obtained from (Tester et al., 2006). O&M costs of ORC power plant: 7$/MWhe producedPDF Image | PROPOSED HYBRID GEOTHERMAL - NATURAL GAS - BIOMASS ENERGY SYSTEM
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