Appendix E-2.c.i Energy Plan 2004-2013 Follow-up Studies and ...

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2.4 Low Pressure Steam Refer to PID-03-04A and PID-03-4B in Appendix III. Re-powering Study for the Northport and Port Jefferson Power Stations Appendix II Northport System Descriptions The LP steam system directs superheated steam from the LP superheater outlet of each HRSG to the steam turbine low pressure admission valves. The LP steam line from each HRSG contains a flow orifice, a bypass branch, and a motor operated stopcheck valve. The HRSG lines combine into a common header en route to the steam turbine. The common header connects to a single connection in the intermediate pressure (IP) steam turbine outlet. Admission stop and control valves are installed in the LP steam piping near the steam turbine. The LP steam combines with the IP turbine exhaust steam and travels through the crossover into the LP section of the steam turbine. The LP steam bypass valves provide a means for bypassing LP steam to the condenser during startup and during steam turbine trip conditions. The LP steam lead from each HRSG is equipped with a steam conditioning valve (bypass valve) to lower the steam pressure and temperature to acceptable condenser design levels. Attemperating water for the steam conditioning valves is from the condensate system through temperature control valves. Low point drains are in accordance with ASME TPD, “Recommended Practices for the Prevention of Water Damage to Steam Turbines Used for Electric Power Generation”. 2.5 Auxiliary Steam Refer to PID-03-05A in Appendix III. 2.5.1 General The auxiliary steam system provides 150 psig steam at 520F to the condenser steam jet holding air ejector, and the steam turbine gland steam system. The source of the steam for the auxiliary steam system is from the cold reheat system. During start up steam is provided to the auxiliary steam system from the main steam system. Both sources of steam are each provided with pressure reducing valves to lower steam pressure to the correct auxiliary steam pressure. Two desuperheater stations are provided to condition the auxiliary steam from either source. During short duration outages, typically overnight and weekends, or whenever it is desired to maintain the plant in a hot or warm condition and during normal plant start-ups, steam is supplied by the auxiliary boiler. The system is equipped with roof mounted safety valves, system traps, and drains, as well as suitable nonreturn valves and isolation valves to prevent steam back flow during unit trips. The source of the desuperheater water is from the condensate pump discharge. The Auxiliary steam system contains the following major components: • Main Steam Letdown Pressure Control Valve • Cold Reheat Letdown Pressure Control Valve • Main Steam Letdown Attemperating Water Spray Control Valve • Cold Reheat Letdown Attemperating Water Spray Control Valve March 30, 2009 158
• Auxiliary Boiler System • All associated piping and instrumentation. Re-powering Study for the Northport and Port Jefferson Power Stations Appendix II Northport System Descriptions The auxiliary boiler for each option is a natural gas fired watertube packaged boiler with an integral superheater. The auxiliary boiler is equipped with single or double low-NOX burners, a forced draft fan and a stack. The following ratings apply to the auxiliary boiler: • Boiler Capacity – To be determined • Design Pressure – 300 psig • Operating Pressure –160 psig • SH Steam Temperature – 520°F • Feedwater Temperature - 228°F The auxiliary boiler system is supplied with support equipment including a deaerator, feedwater pumps, blowdown tank, chemical feed equipment, instrumentation and associated control system for independent operation. 2.5.2 Auxiliary Steam Attemperating Valves The main steam and the cold reheat auxiliary steam attemperating valve conditions superheated main steam to maintain a nominal pressure of 160 psig at a temperature of approximately 420°F. The condensate system provides attemperating water spray via a temperature control valve to maintain the required steam conditions at setpoint. 2.5.3 Air Ejectors Steam jet air ejectors are used to remove non-condensable air and gases from the condenser during normal holding operation. Two holding ejectors steam jet air ejectors are provided. For start up, a liquid ring vacuum pump will be used for hogging (start up). The hogging vacuum pump is used for initial evacuation of the condenser and the holding ejectors are used to maintain the condenser at full vacuum during operation. Each holding ejector is sized for 100% operation utilizing auxiliary steam as the motive through a steam nozzle producing a high-velocity jet of steam that induces vacuum conditions to pull out non-condensable gases from the non-condensable collection zone within the condenser. The holding ejectors are each full capacity two-stage ejectors with a surface type inter-condenser between the first and second stage along with a second stage discharge condenser. The condensate system provides cooling water for the ejector and to maintain the inter-condenser loop seal. The SJAE condensers are small heat exchangers in a common shell that condense the motive steam and allow the non-condensable gases to be expelled to atmosphere. The steam supply requirements for the holding ejector is 900 lb/hr at 150 psig. The electric powered hogging vacuum pump is a single stage design and is only in service during initial startup. The hogging pump exhausts to atmosphere. March 30, 2009 159
Page 1 and 2: Electric Resource Plan 2010 - 2020
Page 3 and 4: March 30, 2009 Re-powering Study fo
Page 5 and 6: Northport Repower Study Option 4 2x
Page 7 and 8: Re-powering Study for the Northport
Page 19: Re-powering Study for the Northport
Page 31 and 32: 1 2 3 4 5 6 7 8 9 10 A SUPERHEATER
Page 33 and 34: 1 2 3 4 5 6 7 8 9 10 A 0304 PID-03-
Page 35 and 36: 1 2 3 4 5 6 7 8 9 10 A 0341 PID-03-
Page 37: 1 2 3 4 5 6 7 8 9 10 A 0368 PID-03-
Page 40 and 41: 1 2 3 4 5 6 7 8 9 10 A 0831 PID-08-
Page 42 and 43: 1 2 3 4 5 6 7 8 9 10 A 0427 PID-04-
Page 44 and 45: 1 2 3 4 5 6 7 8 9 10 A FGS FGS FGS
Page 46 and 47: 1 2 3 4 5 6 7 8 9 10 A 0823 PID-08-
Page 50 and 51: 1 2 3 4 5 6 7 8 9 10 0904 PID-09-09
Page 52 and 53: 1 2 3 4 5 6 7 8 9 10 A FROM AIR COM
Page 54 and 55: 1 2 3 4 5 6 7 8 9 10 A REVISION DES
Page 56 and 57: 1 2 3 4 5 6 7 8 9 10 A 1330 PID-13-
Page 58 and 59: 1 2 3 4 5 6 7 8 9 10 A FROM HRSG 1A
Page 60 and 61: 1 2 3 4 5 6 7 8 9 10 A 0304 PID-03-
Page 62 and 63: 1 2 3 4 5 6 7 8 9 10 A 0341 PID-03-
Page 64 and 65: 1 2 3 4 5 6 7 8 9 10 A 0368 PID-03-
Page 66 and 67: 1 2 3 4 5 6 7 8 9 10 A REVISION DES
Page 68 and 69: 1 2 3 4 5 6 7 8 9 10 A 0831 PID-08-
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1 2 3 4 5 6 7 8 9 10 A 0427 PID-04-
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1 2 3 4 5 6 7 8 9 10 A FGS FGS FGS
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1 2 3 4 5 6 7 8 9 10 A 0823 PID-08-
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1 2 3 4 5 6 7 8 9 10 CCW VSH 0132A
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1 2 3 4 5 6 7 8 9 10 0904 PID-09-09
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1 2 3 4 5 6 7 8 9 10 A FROM AIR COM
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1 2 3 4 5 6 7 8 9 10 A REVISION DES
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1 2 3 4 5 6 7 8 9 10 A 1330 PID-13-
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Re-powering Study for the Northport
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Fuel Systems Re-powering Study for
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Accessory Electric Plant Re-powerin
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Fuel and Feed Re-powering Study for
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Accessory Electric Plant Re-powerin
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• Grounding and lightning protect
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• Combustion turbine foundation
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D3 Fuel Oil facilities Re-powering
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Appendix E-2.c.i Energy Plan 2004-2013 Follow-up Studies and ...

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