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We selected inlet evaporative cooling for power augmentation for both plant types because it increases their output substantially for only a small increase in cost. The slightly higher output that inlet chilling could provide does not appear cost-effective for the incremental cost, as indicated by the relatively higher cost per unit of output than that of the overall plant. Table 9 Power Augmentation Comparison for Gas CT Total Cost Inlet Evaporatiw Cooling $193 Inlet Chilling $205 Capacity Incremental Output Incremental C o s t s IS0 Summer IS0 Summer IS0 Summer Conditions Conditions Conditions Conditions Conditions Conditions 420 395 8 18 $84 $39 425 417 5 22 $2,306 $555 -. (MW) (MW (MW ,(MW ($/ICW ($/kW $62 $16 $2,640 $580 Solimes mid Notes CH2M HIL,L (201 I), using GE software International Organization for Standardization (ISO) conditions are 59 "F and 60% relative humidity Suininer conditions are 90 "F and 53% relative humidity. None $449 Inlet Ewporatiw Cooling $450 Inlet Chilling $463 618 550 627 589 633 613 10 39 5 24 Table 10 Power Augmentation Comparison for Gas CC Total Cost ($111) Capacity Incremental Output I S 0 Summer IS0 Summer Incremental Costs I S 0 Summer Conditions Conditions Conditions Conditions Conditions Conditions Soli/ces aiid Notes CH2M HILL. (201I), using GE software. International Organization for Standardization (ISO) conditions are 59 O F and 60% relative humidity Summer conditions are 90 O F and 53% relative humidity. G. NOx CONTROLS In deteiinining the NOx controls that will be required for each new unit to pass its new source review ("NSR') and receive an operating air pennit, we considered the following: controls installed by recently developed gas-fired units, tightening standards due to recent and imminent EPA regulations, special peiinitting considerations in each plant location, and special technological considerations for each plant configuration we selected. Table 11 contains a sununary of NOx control equipment on units built in PJM since 2002. The data is displayed separately for single-fuel and dual-fuel gas CCs and CTs, and by turbine type. The table shows that there are several NOx controls that are consistently required under NSR for all units regardless of locational air permitting considerations. The table shows that all 7FA units in either CT or CC configuration are equipped with dry low-NOx burners, as expected because dry-low NOx burners are part of the 7FA turbine model design. All 7FA CC and CT units with dual-fuel capability are also equipped with water injection for NOx control for use during firing 12PDF Image | THE APPLICATION OF KENTUCKY POWER
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