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

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Re-powering Study for the Northport and Port Jefferson Power Stations Appendix II Northport System Descriptions 2.5.4 Steam Turbine Gland Sealing Steam Auxiliary steam is provided to the steam turbine gland sealing system during shutdown periods when the Steam Turbine is maintained is a warm or hot condition as well as during Steam Turbine start-up and low load operations. At higher Steam Turbine loads gland-sealing steam is provided from the HP gland leakoff(s). Excess HP gland leakoff steam is bled off to the condenser by means of a steam packing unloader valve. Auxiliary steam is provided to the steam turbine gland sealing steam system through a flow control valve. Steam is used to seal the turbine glands to prevent the steam from being expelled to the atmosphere and to prevent air from leaking into the turbine through the gland seals. A steam seal feed valve and a steam packing unloading valve is provided to maintain the system at a constant pressure. A steam seal feed bypass valve is used to provide a means to maintain steam pressure in the event of failure of the control valve and for plant startup. 2.6 Air Cooled Condenser/Steam Turbine Exhaust Refer to PID-03-12A in Appendix III. The Air Cooled Condenser system condenses steam from the LP exhaust of the steam turbine and returns condensate to the condensate tank and to the HRSG condensate system. This system will be provided on The Backyard Option at Northport and is composed of the following equipment necessary to condense the steam and return the condensate to the condensate storage tank. These items are: 1. Air-cooled steam condenser tower. 2. Air-flow control equipment. 3. Wind and/or cell-partition walls. 4. Steam-bypass heating system. 5. Air removal equipment. 6. Steam ducts and expansion joints. 7. Condensate drain and air-removal piping. 8. Instrumentation, controls and alarms. 9. Pressure-relief device for protection of steam-turbine exhaust casing. 10. Steam-duct condensate drain system. 11. Condensate Storage Tank The air-cooled condenser includes tube bundles, a steam distribution manifolds, fans, motors, gear boxes and supporting steel. Steam from the turbine exhaust, or bypass station, flows through a main steam duct to a roof-shaped air-cooled condenser. The steam is then condensed inside the finned tube bundles using ambient air as the cooling medium. The cooling air is provided by axial fans, which are driven by electric motors via speed reducing gearboxes. At the bottom outlet of the finned tubes, the condensate is collected in condensate manifolds and flows by gravity to the main condensate tank. The condensate flowing to the tank is partially reheated with steam coming from the main steam duct via the equalization line. The condensate in the tank is then pumped back to the boiler feed water system. At the lowest point of the steam duct, a condensate sump collects entrained moisture from the steam turbine exhaust flow and the steam that is condensed on the steam duct walls. The accumulated condensate is then gravity drained to the main condensate tank. The condenser design consists of seven rows (streets) of six cells each for a March 30, 2009 160
Re-powering Study for the Northport and Port Jefferson Power Stations Appendix II Northport System Descriptions total of 42 cells. The cells are in a “butterfly” arrangement with four streets on one side of the main exhaust header and three streets on the opposite side. Noncondensables are extracted from the steam by a hogging vacuum pump and a continuous holding ejector. During startup, the hogging pump removes air from inside the steam ducts, steam manifolds and bundles. It reduces the air pressure within the system from atmospheric to about 10 in. Hg absolute in a time period usually not to exceed 30 minutes.. The condensate storage tank will be sized for a 10 minute operating storage capacity. The total tank size will exceed the operating storage capacity by an amount equal to the total condensate held in the drain pots and drain piping. The steam duct system will connect the condenser inlet-steam manifold to the turbine exhaust flange. It includes expansion joints, anchor points, elbows, turning vanes and duct supports. Instrumentation includes temperature indicators and thermocouples; pressure indicators and transducers; vibration-pickup transducers; liquid-level devices; status lights; annunciator panel; and recorders. The controls will also control storage-tank condensate level; fan pitch control; air louver control; steam-valve control; and fan-motor control. These controls will be designed to minimize auxiliary-fan power consumption, and protect the condenser from freezing. In the event of complete electric-power failure to the steam-condenser fans, an atmospheric-relief diaphragm safety device is installed in the turbine exhaust system, to protect the turbine exhaust hood from excessive steam pressure. A steam-bypass system is provided which exhausts attemperated main steam directly into the cold reheat line during startup. 2.7 Condensate Refer to PID-04-01A and 04-01B in Appendix III. The Condensate System for Northport has two 100 percent condensate pumps. The second condensate pump is started for steam turbine bypass operation. The 100 percent capacity vertical turbine-type centrifugal condensate pumps, set in suction cans, take suction from the condensate storage tank through individual suction lines and storage tank connections. The Condensate System supplies condensate to both electric and steam air ejectors, gland steam condenser, LP economizers of each HRSG, the auxiliary steam desuperheater, hot reheat and LP steam bypass valves, turbine exhaust hood spray, and condenser curtain spray, as well as water for HRSG IP and HP drum fill and closed cooling water system make-up. The Condensate System is capable of continuous operation for flow rates ranging from minimum recirculation to 100 percent of design capacity. Each pump suction line contains a butterfly isolation valve, a basket strainer, a relief valve and an expansion joint at the pump suction connection. The basket strainer is supplied with a coarse mesh element for normal plant operation and a fine mesh element for flushing and start-up. Pressure differential indication is provided for each strainer in the distributed control system (DCS). Each pump discharge line contains a local pressure gage, check valve, butterfly isolation valve, and slipstream for pump seal water. Each pump is vented by individual lines to the condensate storage tank. A recirculation valve provides condensate pump minimum flow protection and maintains the required minimum flow through the gland steam condenser. Recirculation water is returned to the condensate March 30, 2009 161
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 21: • Auxiliary Boiler System • All
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
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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
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Page 58 and 59: 1 2 3 4 5 6 7 8 9 10 A FROM HRSG 1A
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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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