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higher pressure of the sCO2 system, which therefore results in heavier (although smaller volume) components. For instance, the EPS100 condenser takes up 15% of the footprint of the equivalent steam condenser, but weighs approximately the same. Air cooled condensers are of interest in many regions where water is of limited availability. Here the lower volumetric flow rate of sCO2 systems can lead to much lower cost ACCs, since pipe and tubing diameters can be drastically reduced compared to steam. We are finding that the cost of ACC systems for sCO2 is comparable to that of a WCC system, when including the condenser, cooling tower, pumps and water treatment systems. This stands in contrast to the situation for steam ACC’s which are considerably more expensive than their water cooled counterparts. OPERATION AND MAINTENANCE Several factors are expected to lead to reduced O&M costs for sCO2 systems relative to conventional steam-based systems: • Elimination of water treatment and blowdown disposal systems. • Reduced turbine wear due to reduced stage count and non-condensing operation. • Reduced pump impeller wear due to reduced stage count and elimination of cavitation damage. • Reduced EHX maintenance compared to HRSG due to single-phase operation (no condensate flooding or desuperheater overspray), elimination of boiler drums, a major source of fatigue cracking failures, and reduction in instrumentation and controls complexity. The reduced capital cost of sCO2 systems and lower O&M costs will also lead to substantial improvement in levelized cost of electricity (LCOE). A set of example calculated values are shown in Figure 10. Figure 10: Projected LCOE for bottoming cycle power generation, assuming 5% discount rate, 30 year plant life and 85% utilization factor for several sample applications. 17PDF Image | SUPERCRITICAL CO2 CYCLES FOR GAS TURBINE COMBINED CYCLE
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