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the load factor of the EGS, which shortens the reservoir lifetime. Given that EGS capacity factor in „DH-ORC‟ is 53% higher compared to „DH‟ scenario, it may seem surprising that its reservoir lifetime is just 10% shorter. This is due to much higher seasonal load fluctuations in the „DH‟ case. In the „DH‟ scenario, after 21 years the model EGS reservoir can still meet the heat demand at the beginning of the heating season, but the production EGS temperature becomes too low at the end of the winter. capital investment cost has only partially been included in the economic analysis. Table 2: System performance metrics Scenario Current DH System Share of district heat supplied by DH- ORC 75% 24.9% 0.1% 4.31 34 200.3 49.7 149,500 14.7% 2) 16% Natural gas 100% 75% 0% 24% 0% 1% The optimal design ambient temperatures of the two proposed systems are quite different: -3.3°C for the „DH‟ and -12.2°C for the „DH-ORC‟. In the „DH‟ system, the design outdoor temperature is higher to avoid oversizing the geothermal heat source. Too many geothermal wells would result in a low capacity factor of the EGS and a high capital investment. In the „DH-ORC‟ design, the geothermal heat source can be oversized to meet the heat demand at very low ambient temperatures. The additional heat extracted from subsurface is converted into work by the ORC power plant. This increases the overall capacity factor of EGS and almost eliminates the need for a peaking biomass boiler. Economic and environmental impact Both proposed systems meet the heat demand of the Cornell campus. A summary of the economic and environmental impacts of transition to hybrid EGS- biomass systems is provided in Table 2. The results for both „DH‟ and „DH-ORC‟ configurations represent the whole campus energy system including the existing CHP natural gas plant and the remaining steam district heating network. Implementation of the proposed EGS-biomass systems results in a 13%-15% reduction of CO2 emissions and a 21% reduction in natural gas consumption at Cornell. Expressed on an annual basis, 560 Mscf less of natural gas can be used, which could save Cornell 2.55 M$/year. While achieving both of these goals, implementation of EGS increases the LCOE of the existing system by 0.72-0.81₵ /kWhe (21-23%). The proposed systems require a 22 to 34 M$ capital investment. They cannot compete with the existing CHP plant on purely economic basis as long as social and environmental effects of fossil fuels consumption are not accounted for. The primary reasons for this are a low natural gas price and high energy conversion efficiency of the existing state of the art CHP system at Cornell. The LCOE for all three discussed energy systems is below the typical market prices. This is because of the pre-existing infrastructure at Cornell, which Biomass LCOE, Performance metrics 3.5 4.22 ₵ /kWhe Capital investment, M$ Produced electricity, GWhe Purchased electricity, GWhe Net annual CO2 emissions, t/yr1) Reduction in CO2 emissions Heat losses from the whole DH network - 22 221 192 29 58 175,000 152,000 - 13.2% 2) 18% 15.7% 1) Includes CO2 emissions from the purchased electricity 2) Heat losses from part of the DH system, which was converted from steam to hot water are 7.2% and 8.4% for the ‘DH’ and ‘DH-ORC’ systems, respectively. The influence of the design ambient temperature on the cost of electricity from the Cornell energy system is presented in Figure 5. Figure 5: Variation in the levelized cost of electricity with the ambient temperature value used to size the Enhanced Geothermal System. With a limited number of existing Enhanced Geothermal Systems, the geothermal well productivity remains uncertain. Sensitivity analysis was performed to quantify the impact of lower well mass flow productivity. The results are presented in Figure 6. While well productivity has an impact ofPDF Image | PROPOSED HYBRID GEOTHERMAL - NATURAL GAS - BIOMASS ENERGY SYSTEM
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