ARCHIVED REPORTS LEC APPLICATION FOR CERTIFICATION

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SECTION 2.0:PROJECT DESCRIPTION average annual ambient conditions with no HRSG duct firing.The project is expected to have an overall annual availability of more than 95 percent. The heat balance for the power plant's baseload operation assuming the use of GE Energy 7FA CTG is shown in Figures 2.14A and 2.14B. This balance is based on operation at an ambient temperature of 61.2 degrees Fahrenheit (°F),with evaporative cooling of the CTG inlet air to 55.8°F, and without the use of duct firing. The predicted net electrical output of the facility under these conditions is approximately 261.3 MW at a heat rate of approximately 6,797 British thermal units per kilowatt hour (Btu/kWh) on a higher heating value (HHV)basis. This corresponds with an efficiency of about 55.6 percent. With HRSG duct firing,the facility will be able to produce a net output of up to 285.3 MW at an ambient temperature of 61.2°F with evaporative cooling of the CTG inlet air to 55.8°F using the GE 7FA.The incremental heat rate of the peaking capacity will be approximately 8,773 Btu/kWh,corresponding to an efficiency of 43.3 percent,which is comparable to that of a CTG operating in simple-cycle mode. The combustion turbine and associated equipment will include the use of best available control technology (BACT) to limit emissions of criteria pollutants and hazardous air pollutants. NOX will be controlled to 2.0 ppm by volume, dry basis (ppmvd),corrected to 15 percent oxygen through the use of dry low-NO,,combustors and an SCR system using ammonia injection. Good combustion practices and a CO catalyst will also be used to control CO emissions to 3.0 ppm at 15 percent oxygen. Emissions of volatile organic compounds (VOCs) will also be controlled to 2.0 ppm. BACT for PM10 and SO2 will be the exclusive use of natural gas. Ammonia slip will be limited to 10 ppm. 2.1.5 Power Plant Cycle CTG combustion air will flow through the inlet air filters,evaporative cooler and associated air inlet ductwork,be compressed in the CTG compressor section, and then enter the CTG combustion section. Natural gas fuel will be injected into the compressed air in the combustion section and ignited. The hot combustion gases will expand through the power turbine section of the CTG,causing it to rotate and drive both the electric generator and CTG compressor. The hot combustion gases will exit the turbine sections and enter the HRSG,where they will heat feedwater that is pumped into the HRSG. The feedwater will be converted to superheated steam and delivered to the steam turbine at high pressure (HP), intermediate pressure (IP),and low pressure (LP). The use of multiple steam delivery pressures will permit an increase in cycle efficiency and flexibility. High-pressure steam will be delivered to the HP section of the steam turbine,intermediate pressure steam will augment the reheat section of the HRSG and will deliver this steam to the IP section of the STG,LP steam will be injected at the beginning of the LP section of the steam turbine, and both flows will be expanded in the LP steam turbine section. Steam leaving the LP section of the steam turbine will enter the deaerating surface condenser and transfer heat to circulating cooling water,which will cause the steam to condense to water. The condensed water, or condensate,will be delivered to the HRSG feedwater system. The condenser cooling water will circulate through a mechanical draft evaporative cooling tower where the heat absorbed in the condenser will be rejected to the atmosphere. 2-10 SAC/371322/082340003(LEC_2.0_PROJECT_DESC.DOC)