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Materials from Interviews with Dry Cooling System Operators • Approx. 2/3 of condensate returned; discarded if it contains detectable TOC; otherwise, polished and reused • Electric to PG&E • Gas/steam turbines on single shaft. • Can augment HRSG with 20 Mw duct burner • Steam augmentation to gas turbines of ~20 Mw. Air-cooled condenser: (See attached sketch and spec. sheet end of section) Balcke-Duerr, 405 N. Reo Street, Suite 300, Tampa, FL 33609, 813-289-1516 (main). Contact: Ralph Wyndrum, 813-342-4916 (direct), 813-342-7916 (fax). ACC Model No.: 120-9310-8810-2---4-TR Dry cooling was chosen for two primary reasons: 1. space considerations (plant on 2 1⁄2 acre site) 2. regulatory schedule (estimated 5 years to get permit to use Bay water) A general description of the system includes: • 15 cells; 12 for steam condesaton/3 for plant water cooling (lube oil/bearings/etc) • Cells in three parallel banks of 5 cells (4 for condenser) each. One cell in each bank in reflux configuration for non-condensable removal. (See sketch 1.) • All heat exchanger, fan and other descriptive information in attached spec. sheet. Operating issues include: • Unit runs well • No problems with wind effects on performance • Freeze protection has not been a problem but the cold weather operating controls sometimes act strangely; i.e., fans will turn off and operators don’t know why. Apparent conflict between Balcke-Duerr operating system and the plant Foxboro I&C package---not a serious problem. • No air in-leakage problems; vacuum systems/de-aerators work well. • Water chemistry not difficult to control (HRSG at pH = 9 with amine treatment). • High make-up rates because of condensate not being returned by C&H or having to be discarded. • Results in complete turnover of cycle water every 2 or 3 days. C-2PDF Image | Comparison of Alternate Cooling Technologies for California Power Plants Economic, Environmental and Other Tradeoffs
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