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

Electric Resource Plan 2010 – 2020
Appendix E, Technical Appendices
E-2.c.i Northport Appendices
February 2010
Appendix E-2.c.i
Energy Plan 2004-2013 Follow-up Studies and
Reports
Northport Appendices
LIPA Electric Resource Plan
2010 – 2020

LIPA Electric Resource Plan
2010 – 2020
Electric Resource Plan 2010 – 2020
Appendix E, Technical Appendices
E-2.c.i Northport Appendices
February 2010

March 30, 2009
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendices Northport
Northport Appendices
Hybrid Option – May Be Designated as Option 4 in Appendices
Backyard Option – May Be Designated as Option 9 in Appendices
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Appendix I Northport Schedules
Appendix I Northport Schedules
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Northport Repower Study
Option 4
2x2x1 501G Re-use Unit 4 Steam Turbine
Once Through Cooling
LIPA issues RFP for PPA
National Grid Selected for PPA
Negotiate PPA
PPA Approved BY LIPA
NY State Comptroller PPA Approval
Bid & Award Owners Engineer Contract
Prepare Permitting Documents
Obtain Permits
Bid & Award EPC Contract
Detailed Engineering & Design
Begin Site Construction
Award PO for CTG
Manufacture & Deliver CTG
Erect CTG
Award PO for HRSG
Manufacture & Deliver HRSG
Erect HRSG
Demolish Unit 4 Turbine Bldg Piping & Equip
Install New Steam Piping and Refurbish U-4 STG
Commissioning
Unit 4 out of Service
Begin Commercial Operation
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Appendix I Northport Schedules
Year 1 Year 2 Year 3 Year 4 Year 5 Year 6
Q1 Q2 Q3 Q4 Q5 Q6 Q7 Q8 Q9 Q10 Q11 Q12 Q13 Q14 Q15 Q16 Q17 Q18 Q19 Q20 Q21 Q22 Q23 Q24
Month 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72
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Northport Repower Study
Option 9
3x3x1 7FB "Backyard" Repowering
W/New STG & Air Cooled Condenser
LIPA issues RFP for PPA
National Grid Selected for PPA
Negotiate PPA
PPA Approved BY LIPA
NY State Comptroller PPA Approval
Bid & Award Owners Engineer Contract
Prepare Permitting Documents
Obtain Permits
Bid & Award EPC Contract
Detailed Engineering & Design
Begin Site Construction
Award PO for CTG
Manufacture & Deliver CTG
Erect CTG
Award PO for HRSG
Manufacture & Deliver HRSG
Erect HRSG
Award PO for STG
Manufacture & Deliver STG
Erect STG
Commissioning
Begin Commercial Operation
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix I Northport Schedules
Year 1 Year 2 Year 3 Year 4
Year 5 Year 6
Q1 Q2 Q3 Q4 Q5 Q6 Q7 Q8 Q9 Q10 Q11 Q12 Q13 Q14 Q15 Q16 Q17 Q18 Q19 Q20 Q21 Q22 Q23 Q24
Month 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72
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Appendix II Northport System Descriptions
Appendix II Northport System Descriptions
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1.1 Main Steam
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Appendix II Northport System Descriptions
1 System Descriptions for Hybrid Option
Refer to PID-03-1A and 03-1B in Appendix III.
1.1.1 Main Flow Path
The Main Steam system conveys superheated steam from the HP superheater outlet of each HRSG to the
steam turbine via the turbine main steam trip and control valves. The HRSGs supply main steam within
the pressure and temperature limits required by the turbine design.
Inside each HRSG boundary, the HP superheater contains an attemperator which uses HP feedwater to
provide temperature control and maintain the HP superheater outlet temperature.
Isolation of each HRSG from the main steam system header, in the Northport Hybrid Option HRSG
configuration, is provided by a stop-check block valve located near the header. The turbine main steam
trip and control valve provides positive isolation of the steam turbine from the main steam system.
The Main Steam System also supplies steam to the steam turbine gland seals during startup. A pressure
reducing valve and spray desuperheater is provided in the line to this service to lower the steam pressure
and temperature to match the ST manufacturers’ requirements.
Low point drain pots are located in the system in accordance with ASME TPD, “Recommended Practices
for the Prevention of Water Damage to Steam Turbines Used for Electric Power Generation”.
Depending on the location, low point drains are directed to either the condenser or the atmospheric
blowoff tank associated with each HRSG.
1.1.2 Bypass Flow Path
The main steam bypass flow path provides the means to convey main steam from each HRSG to the cold
reheat system via a main steam bypass conditioning valve station. During normal load operation, the
main steam by-pass valves are shut. The bypass station permits main steam generated in each CT/HRSG
set to be removed during normal CT startup, normal shutdown, steam turbine trip, or when the steam
turbine is removed from service.
The conditioning valve controls main steam pressure by bleeding off main steam, reducing its pressure
and temperature to match the operating parameters of the cold reheat steam system. The conditioning
valve controls the temperature of the outlet by spraying HP feedwater at a controlled rate to match the
cold reheat steam temperature.
1.2 Cold Reheat
Refer to PID-03-02A in Appendix III.
The Cold Reheat Steam System directs the high pressure steam turbine exhaust to each HRSG reheat inlet
header. In the case of the Northport 4 Option, the cold reheat steam line from the steam turbine joins into
a common header, which then splits into branches, one to each HRSG reheater inlet.
For this option, a non-return valve is provided in the cold reheat line to prevent backflow into the high
pressure turbine. This valve protects the turbine when the main steam system is bypassed to the cold
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Appendix II Northport System Descriptions
reheat system during turbine start-up, shutdown, and turbine trip events. The valve is controlled through
the steam turbine control system to prevent closure whenever the main steam stop/throttle valve is open.
Each individual cold reheat line to both HRSGs has a motor-operated gate valve and a branch from the
main steam bypass valve. Main steam is bypassed around the steam turbine to the cold reheat steam
system during plant start-up, shutdown, and when the turbine is out of service. The multiple combustion
turbine generators at Northport are assumed to operate at the same load over their range of operation. For
this reason, no balancing valves are provided in the cold reheat lines.
Within the HRSG scope of supply, IP superheater outlet piping connects to the cold reheat piping prior to
the reheat inlet connection.
The Cold Reheat System also supplies cooling steam to the M501G as per MHI requirements once it is
available to do so. The Auxiliary Steam System and Auxiliary Boiler supply cooling steam according to
MHI specifications during startup and shutdown.
A branch connection from the cold reheat line supplies steam to the auxiliary steam system during normal
operation. The branch has a motor operated block valve and a pressure control valve.
All portions of the cold reheat pipe, as well as the steam turbine HP casing, require overpressure
protection. For Northport Hybrid Option, stop valves are located in the cold reheat leads to each HRSG.
These intervening stop valves could potentially isolate the relief path from the HP turbine outlet
connection to the HRSG reheater safety valves. Therefore, safety valves are required in the cold reheat
piping for this option between the HP turbine outlet connection and the non-return valve.
Low point drain pots, equipped with level sensing devices, are in accordance with ASME TPD,
"Recommended Practices for the Prevention of Water Damage to Steam Turbines Used for Electric
Power Generation".
1.3 Hot Reheat
Refer to PID-03-3A and PID-03-03B in Appendix III.
The Hot Reheat Steam System directs superheated steam from the Hot Reheat outlet of each HRSG to the
IP steam turbine.
The reheater outlet temperature is controlled by an attemperator located within the HRSG boundary
between the primary and final sections. The attemperator uses IP feedwater to provide temperature
control and maintain the hot reheat outlet temperature.
The hot reheat steam line from each HRSG contains a flow nozzle, a bypass branch and a motor operated
stop-check valve. For Northport Hybrid Option, the HRSG steam leads combine into a common header
en route to the steam turbine. At the steam turbine, the header splits into two branches, one to each
combined reheat valve.
For this option the hot reheat bypass valves provide the means to bypass hot reheat steam to the condenser
during startup, normal shutdown, steam turbine trips, or when the steam turbine is removed from service
while the combustion turbines continue to operate. The hot reheat lead from each HRSG is equipped with
a steam conditioning valve (bypass valve) to reduce the hot reheat pressure and temperature to acceptable
condenser design levels. Attemperating water for the bypass valves is from the condensate system
through temperature control valves.
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Appendix II Northport System Descriptions
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”.
1.4 Low Pressure Steam
Refer to PID-03-04A and PID-03-4B in Appendix III.
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. For Northport Hybrid Option, 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”.
1.5 Auxiliary Steam
Refer to PID-03-05A in Appendix III.
1.5.1 General
The auxiliary steam system provides 150 psig steam at 520ºF 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.
The Auxiliary Steam System also provides cooling steam to the M501G during startup and shutdown as
per MHI requirements. This steam is generated by the Auxiliary boiler in accordance with MHI quality,
flow, pressure, and temperature requirements.
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:
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Appendix II Northport System Descriptions
• 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
• Auxiliary Boiler System
• All associated piping and instrumentation.
1.5.2 Auxiliary Boiler System
The auxiliary boiler for The Hybrid 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 – 400 psig
• Operating Pressure – 300 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.
1.5.3 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 150 psig at a temperature of approximately 520 oF. The
condensate system provides attemperating water spray via a temperature control valve to maintain the
required steam conditions at setpoint.
1.5.4 Air Ejectors
The existing Unit 4 air removal system will remain in service
1.5.5 Steam Turbine Gland Sealing Steam
The existing Unit 4 steam turbine gland sealing system will remain in service.
1.6 Condensate
Refer to PID-04-01A and 04-01B in Appendix III.
The Condensate Systems for the Northport Hybrid Option each have two 100 percent condensate pumps.
The second condensate pump is started for steam turbine bypass operation. The new condensate pumps
will replace the existing pumps in the same location.
The 100 percent capacity vertical turbine-type centrifugal condensate pumps, set in suction cans, take
suction from the condenser hotwell through individual suction lines and hotwell connections. The
Condensate System supplies condensate to both electric and steam air ejectors, gland steam condenser, LP
economizers of each HRSG, auxiliary steam desuperheater, hot reheat and LP steam bypass valves,
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Appendix II Northport System Descriptions
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 condenser.
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 condenser
hotwell. The recirculation line is designed for single pump operation. Therefore, the duration of twopump
operation should be limited when in the minimum recirculation mode.
The hotwell level is controlled by make-up and draw-off. Hotwell make-up is provided by normal
make-up and the high-capacity make-up control valves which control condensate flow into individual
condenser connections in response to hotwell low level. The normal make-up control valve directs
condensate into the condenser above the tube bundle to allow it to be deaerated. The high-capacity
make-up control valve directs condensate directly into the hotwell to ensure the condensate pump suction
source.
In response to high hotwell level, the draw-off control valve directs condensate pump discharge to the
circulating water piping.
A sampling connection is provided on the condensate pump discharge to monitor water chemistry.
Chemicals controlling pH and oxygen are injected into the condensate discharge piping upstream of the
air ejectors and gland steam condenser to maintain water chemistry.
The control system is designed to automatically start the standby pump when the condensate header
pressure becomes low. The condensate pump(s) will automatically trip if the condenser hot well level
drops below a minimum acceptable level.
1.7 Feedwater
Refer toPID-06-1A and PID-06-01B in Appendix III.
For The Hybrid Option, the feedwater system has two feedwater pumps for each HRSG. The two 100%
capacity, segmental ring feedwater pumps are each fitted with an adjustable speed fluid coupling and
driven by a constant speed motor. The pumps take suction from the LP drum of the related HRSG. The
pump discharge feeds the relevant HRSG’s HP system. Each pump has an interstage bleed that feeds the
relevant IP system. The pump suction lines each contain a manual gate valve, pressure and temperature
instrumentation, and a duplex basket strainer with a differential pressure transmitter to provide indication
and a high alarm on the distributed control system (DCS).
1.7.1 High Pressure Feedwater
The feedwater pump HP discharge line is provided with an automatic recirculation (ARC) valve and a
manual gate valve. The ARC valve automatically maintains the required minimum flow through the pump
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Appendix II Northport System Descriptions
by recirculating water back to the HRSG LP drum. The recirculation line has a (spring-loaded) backpressure
regulator valve and a gate valve.
The feedwater pumps HP discharge line connects to the HRSG HP economizer inlet. The line has a
branch for LP drum filling, a sample connection, a branch to the HRSG HP superheater attemperator, and
a branch to the main steam bypass valve. The HP superheater attemperator spray branch has a manual
block valve, a flow element and transmitter for DCS flow indication. The main steam bypass
desuperheater branch has a manual block valve.
Downstream of the branch connections, the HP feedwater line connects to the HP economizer. The line
contains a drum level control valve, with manual isolation valves and a manual bypass valve. Upstream
of the control valve are a flow element with flow transmitter, a pressure transmitter, and a temperature
indicator. The flow signal, along with drum level and steam flow signals, is used to position the drum
level control valve. A pressure transmitter is provided downstream of the drum level control valve.
A constant differential pressure is maintained across the HP drum level control valves by varying the
speed of the feedwater pump.
A motor operated on-off tight shutoff valve is provided downstream of the HP drum level control valve to
prevent water leakage into the drum during startup.
1.7.2 Intermediate Pressure Feedwater
Each feedwater pump has an interstage bleed connection for IP feedwater supply to the HRSG IP
economizer inlet. The connection is piped to a line containing a pressure gage, a check valve, and a gate
valve. A branch line from the condensate system connects to the line to provide water to fill the IP drum.
A branch from the line provides water for the HRSG reheater attemperator. This line has a gate valve and
a flow element and transmitter for DCS indication.
Downstream of the branch connections there is a pressure transmitter. The IP feedwater line connects to
the HRSG IP feedwater inlet connection. Downstream of the inlet connection, within the HRSG's
vendors scope, there is a check valve, a manual gate valve, the IP economizer, a flow element with a flow
transmitter, a temperature element, a drum level control valve with manual block and bypass valves, and
an air operated on-off tight shutoff valve. The flow signal, along with the drum level and steam flow
signals, is used to position the drum level control valve.
A branch line immediately downstream of the economizer and upstream of the drum level control valve
provides the heating medium for the fuel gas performance heater.
1.8 Fuel Gas
Refer to PID-8-7A through 7D in Appendix III.
The fuel gas delivered to Northport is AGA pipeline quality gas. No gas compressors are required.
The fuel gas system (FGS) is designed to meet the requirements of the CTs including flow, pressure,
temperature, moisture content, and cleanliness. To provide these requirements the FGS will include a
pressure-reducing station, metering, filtration, gas heating, flow control, and scrubber with vent stack and
CH4 monitors to detect gas leakage.
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Appendix II Northport System Descriptions
The FGS piping begins at the outlet of the gas suppliers metering station. A single line is routed from the
metering station, through a knockout drum and filter/separator to meet the CT cleanliness requirements.
Liquids separated from the gas stream are automatically drained into a fuel gas drains tank. A
containment area is provided under the drain for capturing spills. A knockout drum, designed to remove
any liquids from the pipeline gas, will be installed at the interface with the gas supplier upstream of the
filter/separator.
A 100% capacity shell and tube fuel gas heat exchanger is provided for each gas turbine to raise the fuel
temperature to the gas turbine manufacturer’s requirements. The source of heat for these is the CT
compressor. The fuel gas supply lines leaving the heaters are routed to their respective CT enclosures.
The CT enclosures include the gas shutoff, vent, and control valves that control the flow of gas to the
CTs.
1.9 Aqueous Ammonia
Refer to PID-08-17A in Appendix III.
Industrial grade aqueous ammonia at 19% concentration is received by truck. A vapor return line from
the ammonia storage tank back to the delivery truck provides venting of the tank during filling operations.
A single storage tank provides five days of capacity based on full load operation of the particular option.
From the tank, two 100% ammonia feed pumps convey the aqueous ammonia through a strainer to the
ammonia vaporization skid for each HRSG. A self regulating positive displacement pump maintains the
required flow and a constant pressure to a dedicated injection skid for each HRSG.
The injection skid mixes the ammonia with high temperature flue gas drawn off the HRSG to vaporize the
ammonia as necessary to obtain proper distribution into the exhaust gas via the ammonia injection grid
located inside the HRSG upstream of the SCR. The injection skid includes two 100% blowers.
1.10 Component Cooling Water
Refer to P& ID 09-09A thru 09D in Appendix III.
The Hybrid Option will have two parallel CCW heat exchange systems working together to provide
adequate CCW cooling. The existing seawater cooled system will be used for primary CCW cooling and
a new system will provide additional cooling for the CCW System as needed. The two systems supply
cooling water to the steam turbine lube oil coolers, steam turbine generator hydrogen coolers, the
combustion turbine(s) lube oil coolers, combustion turbine(s) generator hydrogen coolers, the sampling
system sample coolers, and any other plant components that require cooling water.
The new system will include two 100% capacity pumps which provide the motive force for circulation of
the closed cooling water to all the system users. The third pump will provide capacity for the
supplemental fin fan heat exchangers as required. The pumps are horizontal, single stage, centrifugal
pumps. Butterfly valves are installed on the intake and discharge of each pump. For pump protection, a
check valve is installed on the discharge side of each pump. A fin-fan type heat exchanger is used to
transfer new CCW heat gains to the atmosphere as needed.
A surge tank is provided to allow for thermal expansion, and acts as a surge volume for the CCW System
water. The surge tank, which is installed at the highest point in the system, also provides net positive
suction head (NPSH) for the CCW pumps. The surge tank is equipped with level instrumentation, which
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Appendix II Northport System Descriptions
provides signals to operate an automatic make-up valve. Make-up water is supplied from the Condensate
System.
A chemical addition pot is installed for the addition of chemicals to control corrosion within the CCW
System.
The Hybrid Option at Northport uses the existing seawater cooled tubular liquid to liquid heat exchangers
to transfer existing ST associated CCW heat gains to the once through circulating water system.
The two CCW Systems supply the following components with cooling water:
• Steam Turbine Lube Oil Coolers
• Steam Turbine Generator Hydrogen Coolers
• Steam Turbine Generator Exciter Coolers
• Steam Turbine Generator Seal Oil Coolers
• Combustion Turbine Lube Oil Coolers
• Combustion Turbine Control Oil Coolers
• Combustion Turbine Starting Package Oil Coolers
• Combustion Turbine Generator Hydrogen Coolers
• Combustion Turbine Generator Seal Oil Coolers
• Condenser Vacuum Pumps [if applicable] (Cooling is provided to the liquid ring vacuum pump heat
exchangers)
• Feedwater Pump Lube Oil Cooler [if applicable]
• Sample System Sample Coolers
• Instrument/Service Air Compressors [if applicable]
System components that could be subject to greater than their design pressures during operation are
protected from over pressure during operation by pressure relief valves. Temperature control valves
regulate cooling water flow through the turbine lube oil coolers and generator coolers.
The flow of closed cooling water through the various components is either automatically regulated, or
manually adjustable to meet each manufacturer’s recommendations.
1.11 Instrument & Service Air
Refer to PID 12-01A and 12-02A in Appendix III.
Compressed air is supplied throughout the facility and subdivided into instrument air and service air
according to the air quality requirements. The instrument air serves all users where dry oil-free air is
required (i.e. air operated control valves, instrumentation), where there is a potential of freezing the
service air line or if interruption of the air supply is not acceptable (i.e. atomizing air to the ammonia skid
for the SCR system). The service air serves common users in the plant such as tools via hose connection
stations located throughout the facility.
The Instrument/Service Air System will have the following characteristics:
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Two (2) x 100% air compressors of the air-cooled (or water-cooled), lubricated, and rotary screw type.
Each compressor is equipped with an inlet air filter silencer, air/oil separator vessel, air/water separator,
aftercoolers, and controls.
One (1) x 100% service air receiver is provided. The receiver provides surge capacity for the Service Air
and Instrument Air Systems. It is constructed to ASME Code requirements and is designed for safe
shutdown of the facility.
The piping and control system will be arranged to prevent loss of pressure to the instrument air system on
a service air system failure by a pressure control valve. The pressure control valve isolate the service air
header on low instrument air pressure signal from the instrument air header and diverts air to the
instrument air system.
One, 100% duplex air drying train for the instrument air system. The train consists of a prefilter, air
dryers, and after filter stations. The prefilter removes the bulk liquid water and particles (5 microns or
smaller). After the air passes through the dryer, the after filter removes any particles from the dryer
desiccant (3 microns or smaller).
The air dryer is of the dual tower heatless regenerative desiccant type. The system automatically controls
the regeneration cycle of the dryers as required. Each air dryer tower is 100% unit capacity such that one
tower can supply full unit demand while the other is being regenerated. Each dryer and dryer tower will
be equipped with remote operated isolation valves.
One instrument air receiver is provided downstream of the dryers to provide surge capacity for the
Instrument Air System.
From the air filtration and drying units, instrument air is provided to the various instrument air users
throughout the plant.
1.12 Plant Makeup Water Treatment
Refer to PID 9-21A and 9-21B in Appendix III.
For Northport, raw water (city water) is used for service water, fire protection, and demineralized water
system makeup. Raw water is ultimately used in the steam cycle make up after being treated
appropriately.
Untreated water is stored in the raw water tank. The lower portion of the tank is dedicated for the fire
protection system and water for the other systems in the upper portion. Raw water is drawn from a nozzle
above the fire water storage high level. The upper portion of the tank has sufficient storage to meet raw
water demand for a safe shutdown of the plant in the event of a loss of off-site water supply.
Two 100% capacity service/raw water pumps are provided. The service water system provides a feed to
the water treatment cycle, and to miscellaneous plant washdown services.
Refer to PID-09-21A in Appendix III.
For Northport, two 100% demineralizer feed pumps direct water from the service water tank to a reverse
osmosis/EDI demineralizer system. Pumps are started and stopped by the operator from the control room
using the distributed control system (DCS). Demineralized water is directed via demineralizer outlet
pumps to the demineralized water storage tank. Two 100% demineralized water forwarding pumps draw
suction from the tank to distribute water to the condenser for steam cycle make-up, combustion turbine
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generator wash water skid, combustion turbine evaporative coolers, combustion turbine water injection
(when burning oil) and to the phosphate chemical feed skid.
1.13 Plant Waste Water Treatment
Refer to PID-13-19A in Appendix III.
All liquid wastes produced within Northport are collected in their designated sumps and pumped to the
existing wastewater treatment system. Each sump will have two 100 percent capacity sump pumps
controlled by float-switch actuated mechanical alternator to equalize the wear on pumps. Each sump
pump will be installed according to the manufacturer’s recommendations for the clearance between the
pump casing and the floor of the sump. Each sump float-switch actuated mechanical alternator will
provide protection for its pumps by stopping the operating pump at a predetermined low level in the
sump. The pump alternator will also have a high level switch to start the selected pumps and a high-high
level switch to start the standby pump and alarm. Each sump has its own set of controls and manual
valves.
Steam turbine area wastewater is collected in the condensate sump. One of two 100 percent condensate
sump pumps route condensate sump water to the oil/water separator.
Oily runoff and drainage from the power block and surrounding areas is collected in the oil/water
separator. Water separated from the oil is routed to the wastewater collection sump by one of two 100
percent oil/water separator sump pumps.
HRSG blowoff tank discharge and HRSG drain water is collected in the HRSG sumps. Each HRSG has a
dedicated sump. One of two 100 percent HRSG sump pumps route HRSG sump water to the circulating
water system for discharge.
Wastewater from the oil/water separator, the water treatment building, and the demineralizer system is
collected in the wastewater collection sump. One of two 100 percent wastewater collection sump pumps
route wastewater to the existing wastewater treatment system.
Sanitary waste is collected in the sanitary lift station. One of two 100 percent sanitary lift station pumps
route sanitary waste to the septic system.
1.14 CT Auxiliary Services
Refer to P&ID 39-02A in Appendix III.
CT auxiliary services consist of interconnecting piping and tubing associated with the combustion
turbine/generator vendor supplied equipments skids. The equipment skids supplied are:
1. CO2 Fire Protection Skid
2. Exhaust Duct Pressure Switch Package Skid
3. Performance Monitoring package Skid
4. Evaporative Cooler Skid
5. Water Wash Skid
6. Air Processing Unit Skid
7. Water Wash Drain Tank
8. Accessory Module (integral with combustion turbine skid)
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2.1 Main Steam
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Appendix II Northport System Descriptions
2 System Descriptions for Backyard Option
Refer to PID-03-1A and 03-1B in Appendix III.
2.1.1 Main Flow Path
The Main Steam system conveys superheated steam from the HP superheater outlet of each of the three
HRSG’s to the steam turbine via the turbine main steam trip and control valves. The three HRSGs supply
main steam within the pressure and temperature limits required by the turbine design.
Inside each HRSG boundary, the HP superheater contains an attemperator which uses HP feedwater to
provide temperature control and maintain the HP superheater outlet temperature.
Isolation of each HRSG from the main steam system header, in the Northport 3x3x1 configuration, is
provided by a stop-check block valve located near the header. The turbine main steam trip and control
valve provides positive isolation of the steam turbine from the main steam system.
The Main Steam System also supplies steam to the steam turbine gland seals during startup. A pressure
reducing valve and spray desuperheater is provided in the line to this service to lower the steam pressure
and temperature to match the ST manufacturers’ requirements.
Low point drain pots are located in the system in accordance with ASME TPD, “Recommended Practices
for the Prevention of Water Damage to Steam Turbines Used for Electric Power Generation”.
Depending on the location, low point drains are directed to either the condenser or the atmospheric
blowoff tank associated with each HRSG.
2.1.2 Bypass Flow Path
The main steam bypass flow path provides the means to convey main steam from each HRSG to the cold
reheat system via a main steam bypass conditioning valve station. During normal load operation, the
main steam by-pass valves are shut. The bypass station permits main steam generated in each CT/HRSG
set to be removed during normal CT startup, normal shutdown, steam turbine trip, or when the steam
turbine is removed from service.
The conditioning valve controls main steam pressure by bleeding off main steam, reducing its pressure
and temperature to match the operating parameters of the cold reheat steam system. The conditioning
valve controls the temperature of the outlet by spraying HP feedwater at a controlled rate to match the
cold reheat steam temperature.
2.2 Cold Reheat
Refer to PID-03-02A in Appendix III.
The Cold Reheat Steam System directs the high pressure steam turbine exhaust to each HRSG reheat inlet
header. The cold reheat steam line from the steam turbine joins into a common header, which then splits
into branches, one to each HRSG reheater inlet.
For The Backyard Option, a non-return valve is provided in the cold reheat line to prevent backflow into
the high pressure turbine. This valve protects the turbine when the main steam system is bypassed to the
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cold reheat system during turbine start-up, shutdown, and turbine trip events. The valve is controlled
through the steam turbine control system to prevent closure whenever the main steam stop/throttle valve
is open.
Each individual cold reheat line to an HRSG has a motor-operated gate valve and a branch from the main
steam bypass valve. Main steam is bypassed around the steam turbine to the cold reheat steam system
during plant start-up, shutdown, and when the turbine is out of service. The multiple combustion turbine
generators at Northport are assumed to operate at the same load over their range of operation. For this
reason, no balancing valves are provided in the cold reheat lines.
Within the HRSG scope of supply, IP superheater outlet piping connects to the cold reheat piping prior to
the reheat inlet connection.
A branch connection from the cold reheat line supplies steam to the auxiliary steam system during normal
operation. The branch has a motor operated block valve and a pressure control valve.
All portions of the cold reheat pipe, as well as the steam turbine HP casing, require overpressure
protection. For Northport Backyard Option, stop valves are located in the cold reheat leads to each
HRSG. These intervening stop valves could potentially isolate the relief path from the HP turbine outlet
connection to the HRSG reheater safety valves. Therefore, safety valves are required in the cold reheat
piping for Northport between the HP turbine outlet connection and the non-return valve.
Low point drain pots, equipped with level sensing devices, are in accordance with ASME TPD,
"Recommended Practices for the Prevention of Water Damage to Steam Turbines Used for Electric
Power Generation".
2.3 Hot Reheat
Refer to PID-03-3A and PID-03-03B in Appendix III.
The Hot Reheat Steam System directs superheated steam from the Hot Reheat outlet of each HRSG to the
IP steam turbine.
The reheater outlet temperature is controlled by an attemperator located within the HRSG boundary
between the primary and final sections. The attemperator uses IP feedwater to provide temperature
control and maintain the hot reheat outlet temperature.
The hot reheat steam line from each HRSG contains a flow nozzle, a bypass branch and a motor operated
stop-check valve. The HRSG steam leads combine into a common header en route to the steam turbine.
At the steam turbine, the header splits into two branches, one to each combined reheat valve.
Hot reheat bypass valves provide means to bypass hot reheat steam to the condenser during startup,
normal shutdown, steam turbine trips, or when the steam turbine is removed from service while the
combustion turbines continue to operate. The hot reheat lead from each HRSG is equipped with a steam
conditioning valve (bypass valve) to reduce the hot reheat pressure and temperature to acceptable
condenser design levels. Attemperating water for the bypass 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”.
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2.4 Low Pressure Steam
Refer to PID-03-04A and PID-03-4B in Appendix III.
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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
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• Auxiliary Boiler System
• All associated piping and instrumentation.
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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.
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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
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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
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storage tank. The recirculation line is designed for single pump operation. Therefore, the duration of twopump
operation should be limited when in the minimum recirculation mode.
The condensate storage tank level is controlled by make-up and draw-off. Condensate storage tank makeup
is provided by normal make-up and the high-capacity start-up make-up control valves which control
demineralized water flow into individual condensate storage tank connections in response to condensate
storage tank low level. Both make-up control valves direct demineralized water directly into the
condensate storage tank to ensure the condensate pump suction source.
In response to high tank level, the draw-off control valve directs condensate pump discharge to the plant
equipment drains.
A sampling connection is provided on the condensate pump discharge to monitor water chemistry.
Chemicals controlling pH and oxygen are injected into the condensate discharge piping upstream of the
air ejectors and gland steam condenser to maintain water chemistry.
The control system is designed to automatically start the standby pump when the condensate header
pressure becomes low. The condensate pump(s) will automatically trip if the condenser hot well level
drops below a minimum acceptable level.
2.8 Feedwater
Refer toPID-06-1A and PID-06-01B in Appendix III.
The feedwater system has two feedwater pumps for each HRSG. The two 100% capacity, segmental ring
feedwater pumps are each fitted with an adjustable speed fluid coupling and driven by a constant speed
motor. The pumps take suction from the LP drum of the related HRSG. The pump discharge feeds the
relevant HRSG’s HP system. Each pump has an interstage bleed that feeds the relevant IP system. The
pump suction lines each contain a manual gate valve, pressure and temperature instrumentation, and a
duplex basket strainer with a differential pressure transmitter to provide indication and a high alarm on
the distributed control system (DCS).
2.8.1 High Pressure Feedwater
Each feedwater pump HP discharge line is provided with an automatic recirculation (ARC) valve and a
manual gate valve. The ARC valve automatically maintains the required minimum flow through the pump
by recirculating water back to the HRSG LP drum. The recirculation line has a (spring-loaded) backpressure
regulator valve and a gate valve.
The feedwater pump HP discharge line connects to the HRSG HP economizer inlet. The line has a branch
for LP drum filling, a sample connection, a branch to the HRSG HP superheater attemperator, and a
branch to the main steam bypass valve. The HP superheater attemperator spray branch has a manual block
valve, a flow element and transmitter for DCS flow indication. The main steam bypass desuperheater
branch has a manual block valve.
Downstream of the branch connections, the HP feedwater line connects to the HP economizer. The line
contains a drum level control valve, with manual isolation valves and a manual bypass valve. Upstream
of the control valve are a flow element with flow transmitter, a pressure transmitter, and a temperature
indicator. The flow signal, along with drum level and steam flow signals, is used to position the drum
level control valve. A pressure transmitter is provided downstream of the drum level control valve.
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A constant differential pressure is maintained across the HP drum level control valves by varying the
speed of the feedwater pump.
A motor operated on-off tight shutoff valve is provided downstream of the HP drum level control valve to
prevent water leakage into the drum during startup.
2.8.2 Intermediate Pressure Feedwater
Each feedwater pump has an interstage bleed connection for IP feedwater supply to the HRSG IP
economizer inlet. The connection is piped to a line containing a pressure gage, a check valve, and a gate
valve. A branch line from the condensate system connects to the line to provide water to fill the IP drum.
A branch from the line provides water for the HRSG reheater attemperator. This line has a gate valve and
a flow element and transmitter for DCS indication.
Downstream of the branch connections there is a pressure transmitter. The IP feedwater line connects to
the HRSG IP feedwater inlet connection. Downstream of the inlet connection, within the HRSG's
vendors scope, there is a check valve, a manual gate valve, the IP economizer, a flow element with a flow
transmitter, a temperature element, a drum level control valve with manual block and bypass valves, and
an air operated on-off tight shutoff valve. The flow signal, along with the drum level and steam flow
signals, is used to position the drum level control valve.
A branch line immediately downstream of the economizer and upstream of the drum level control valve
provides the heating medium for the fuel gas heater.
2.9 Fuel Gas
Refer to PID-8-7A through 7D in Appendix III.
The fuel gas delivered to Northport is AGA pipeline quality gas. No gas compressors are required.
The fuel gas system (FGS) is designed to meet the requirements of the CTs including flow, pressure,
temperature, moisture content, and cleanliness. To provide these requirements the FGS will include a
pressure-reducing station, metering, filtration, gas heating, flow control, and scrubber with vent stack and
CH4 monitors to detect gas leakage.
The FGS piping begins at the outlet of the gas suppliers metering station. A single line is routed from the
metering station, through a knockout drum and filter/separator to meet the CT cleanliness requirements.
Liquids separated from the gas stream are automatically drained into a fuel gas drains tank. A
containment area is provided under the drain for capturing spills. A knockout drum, designed to remove
any liquids from the pipeline gas, will be installed at the interface with the gas supplier upstream of the
filter/separator.
For The Backyard Option at Northport, a 100% capacity shell and tube fuel gas heat exchanger is
provided for each gas turbine to raise the fuel temperature to the gas turbine manufacturer’s requirements.
The source of heat for these is cycle steam. The fuel gas supply lines leaving the heaters are routed to
their respective CT enclosures. The CT enclosures include the gas shutoff, vent, and control valves that
control the flow of gas to the CTs.
2.10 Aqueous Ammonia
Refer to PID-08-17A in Appendix III.
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Industrial grade aqueous ammonia at 19% concentration is received by truck. A vapor return line from
the ammonia storage tank back to the delivery truck provides venting of the tank during filling operations.
A single storage tank provides five days of capacity based on full load operation of the particular option.
From the tank, two 100% ammonia feed pumps convey the aqueous ammonia through a strainer to the
ammonia vaporization skid for each HRSG. A self regulating positive displacement pump maintains the
required flow and a constant pressure to a dedicated injection skid for each HRSG.
The injection skid mixes the ammonia with high temperature flue gas drawn off the HRSG to vaporize the
ammonia as necessary to obtain proper distribution into the exhaust gas via the ammonia injection grid
located inside the HRSG upstream of the SCR. The injection skid includes two 100% blowers.
2.11 Component Cooling Water
Refer to P& ID 09-09A thru 09D in Appendix III.
The CCW System supplies cooling water to the steam turbine lube oil coolers, steam turbine generator
hydrogen coolers, the combustion turbine(s) lube oil coolers, combustion turbine(s) generator hydrogen
coolers, the sampling system sample coolers, and any other plant components that require cooling water.
Two 100% capacity pumps provide the motive force for circulation of the closed cooling water to the
system users. The pumps are horizontal, single stage, centrifugal pumps. Butterfly valves are installed on
the intake and discharge of each pump. For pump protection, a check valve is installed on the discharge
side of each pump. A fin-fan type heat exchanger is used to transfer CCW heat duty to the atmosphere.
A surge tank is provided to allow for thermal expansion, and acts as a surge volume for the CCW System
water. The surge tank, which is installed at the highest point in the system, also provides net positive
suction head (NPSH) for the CCW pumps. The surge tank is equipped with level instrumentation, which
provides signals to operate an automatic make-up valve. Make-up water is supplied from the Condensate
System.
A chemical addition pot is installed for the addition of chemicals to control corrosion within the CCW
System.
The CCW System supplies the following components with cooling water:
• Steam Turbine Lube Oil Coolers
• Steam Turbine Generator Hydrogen Coolers
• Steam Turbine Generator Exciter Coolers
• Steam Turbine Generator Seal Oil Coolers
• Combustion Turbine Lube Oil Coolers
• Combustion Turbine Control Oil Coolers
• Combustion Turbine Starting Package Oil Coolers
• Combustion Turbine Generator Hydrogen Coolers
• Combustion Turbine Generator Seal Oil Coolers
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• Condenser Vacuum Pumps [if applicable] (Cooling is provided to the liquid ring vacuum pump heat
exchangers)
• Feedwater Pump Lube Oil Cooler [if applicable]
• Sample System Sample Coolers
• Instrument/Service Air Compressors [if applicable]
System components that could be subject to greater than their design pressures during operation are
protected from over pressure during operation by pressure relief valves.
Temperature control valves regulate cooling water flow through the turbine lube oil coolers and generator
coolers.
The flow of closed cooling water through the various components is either automatically regulated, or
manually adjustable to meet each manufacturer’s recommendations.
2.12 Instrument & Service Air
Refer to PID 12-01A and 12-02A in Appendix III.
At Northport, compressed air is supplied throughout the facility and subdivided into instrument air and
service air according to the air quality requirements. The instrument air serves all users where dry oil-free
air is required (i.e. air operated control valves, instrumentation), where there is a potential of freezing the
service air line or if interruption of the air supply is not acceptable (i.e. atomizing air to the ammonia skid
for the SCR system). The service air serves common users in the plant such as tools via hose connection
stations located throughout the facility.
The Instrument/Service Air System will have the following characteristics:
Two (2) x 100% air compressors of the air-cooled (or water-cooled), lubricated, and rotary screw type.
Each compressor is equipped with an inlet air filter silencer, air/oil separator vessel, air/water separator,
aftercoolers, and controls.
One (1) x 100% service air receiver is provided. The receiver provides surge capacity for the Service Air
and Instrument Air Systems. It is constructed to ASME Code requirements and is designed for safe
shutdown of the facility.
The piping and control system will be arranged to prevent loss of pressure to the instrument air system on
a service air system failure by a pressure control valve. The pressure control valve isolate the service air
header on low instrument air pressure signal from the instrument air header and diverts air to the
instrument air system.
One, 100% duplex air drying train for the instrument air system. The train consists of a prefilter, air
dryers, and after filter stations. The prefilter removes the bulk liquid water and particles (5 microns or
smaller). After the air passes through the dryer, the after filter removes any particles from the dryer
desiccant (3 microns or smaller).
The air dryer is of the dual tower heatless regenerative desiccant type. The system automatically controls
the regeneration cycle of the dryers as required. Each air dryer tower is 100% unit capacity such that one
tower can supply full unit demand while the other is being regenerated. Each dryer and dryer tower will
be equipped with remote operated isolation valves.
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One instrument air receiver is provided downstream of the dryers to provide surge capacity for the
Instrument Air System.
From the air filtration and drying units, instrument air is provided to the various instrument air users
throughout the plant.
2.13 Plant Makeup Water Treatment
For Northport, raw water (city water) is used for service water, fire protection, and demineralized water
system makeup. Raw water is ultimately used in the steam cycle make up after being treated
appropriately.
Untreated water is stored in the raw water tank. The lower portion of the tank is dedicated for the fire
protection system and water for the other systems in the upper portion. Raw water is drawn from a nozzle
above the fire water storage high level. The upper portion of the tank has sufficient storage to meet raw
water demand for a safe shutdown of the plant in the event of a loss of off-site water supply.
Two 100% capacity service/raw water pumps are provided. The service water system provides a feed to
the water treatment cycle, and to miscellaneous plant washdown services.
Refer to PID-09-21A in Appendix III.
Two 100% demineralizer feed pumps direct water from the service water tank to a reverse osmosis/EDI
demineralizer system. Pumps are started and stopped by the operator from the control room using the
distributed control system (DCS). Demineralized water is directed via demineralizer outlet pumps to the
demineralized water storage tank. Two 100% demineralized water forwarding pumps draw suction from
the tank to distribute water to the condenser for steam cycle make-up, combustion turbine generator wash
water skid, combustion turbine evaporative coolers, combustion turbine water injection (when burning
oil) and to the phosphate chemical feed skid.
2.14 Plant Waste Water Treatment
Refer to PID-13-19A in Appendix III.
All liquid wastes produced within Northport is collected in their designated sumps and pumped to the
existing wastewater treatment system. Each sump will have two 100 percent capacity sump pumps
controlled by float-switch actuated mechanical alternator to equalize the wear on pumps. Each sump
pump will be installed according to the manufacturer’s recommendations for the clearance between the
pump casing and the floor of the sump. Each sump float-switch actuated mechanical alternator will
provide protection for its pumps by stopping the operating pump at a predetermined low level in the
sump. The pump alternator will also have a high level switch to start the selected pumps and a high-high
level switch to start the standby pump and alarm. Each sump has its own set of controls and manual
valves.
Steam turbine area wastewater is collected in the condensate sump. One of two 100 percent condensate
sump pumps route condensate sump water to the oil/water separator.
Oily runoff and drainage from the power block and surrounding areas is collected in the oil/water
separator. Water separated from the oil is routed to the wastewater collection sump by one of two 100
percent oil/water separator sump pumps.
March 30, 2009 166

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix II Northport System Descriptions
HRSG blowoff tank discharge and HRSG drain water is collected in the HRSG sumps. Each HRSG has a
dedicated sump. One of two 100 percent HRSG sump pumps route HRSG sump water to the circulating
water system for disposal.
Wastewater from the oil/water separator, the water treatment building, and the demineralizer system is
collected in the wastewater collection sump. One of two 100 percent wastewater collection sump pumps
route wastewater to the existing wastewater treatment system.
Sanitary waste is collected in the sanitary lift station. One of two 100 percent sanitary lift station pumps
route sanitary waste to the septic system.
2.15 CT Auxiliary Services
Refer to P&ID 39-02A in Appendix III.
CT auxiliary services consist of interconnecting piping and tubing associated with the combustion
turbine/generator vendor supplied equipments skids. The equipment skids supplied are:
1. CO2 Fire Protection Skid
2. Exhaust Duct Pressure Switch Package Skid
3. Performance Monitoring package Skid
4. Evaporative Cooler Skid
5. Water Wash Skid
6. Air Processing Unit Skid
7. Water Wash Drain Tank
8. Accessory Module (integral with combustion turbine skid)
March 30, 2009 167

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix III Northport P &IDs
Appendix III Northport P&IDs
March 30, 2009 168

1
2
3
4
5
6
7
8
9
10
A
SUPERHEATER OUTLET
0608 PID-06-01B
DESUPERHEATING SPRAY
FROM HP FEEDWATER SYSTEM
SUPERHEATER OUTLET
0608 PID-06-01B
DESUPERHEATING SPRAY
FROM HP FEEDWATER SYSTEM
REVISION DESCRIPTION
FROM HRSG 1A MSS
FROM HRSG 1B MSS
B
APPR
CHECKED
CORRECT
DATE
FWS-V040
FWS-V040
FWS-STR002
FWS-STR002
REVISION DESCRIPTION
C
FWS
FWS
FWS
FE
+ +
+
0102
FWS
FE
FT
0102
FWS-V042
FWS-V041
FWS-V044
FWS-V043
FWS
FWS
TE
0103
TW
0103
FWS
+ +
+
0102
FT
0102
FWS-V042
FWS-V041
APPR
D
FWS-V044
FWS-V043
CHECKED
CORRECT
DATE
FWS
FWS
TE
0103
TW
0103
FWS
HV
0101
HV
0101
FC
FWS
FWS
REVISION DESCRIPTION
FC
E
ZSC
0101
ZSC
0101
FWS
FWS
FWS
FWS
ZSO
0101
TV
0102
ZSO
0101
TV
0102
=Hh=
FC
][
=Hh=
FC
APPR
][
CHECKED
CORRECT
DATE
F
MSS
MSS
PT
0100-1
PT
0100-1
MSS
MSS-V003A
MSS-V002A
FWS-V048
MSS
MSS-V003A
MSS-V002A
FWS-V048
PT
0100-2
PT
0100-2
MSS-V003B
MSS-V002B
MSS
MSS-V003B
MSS-V002B
MSS
REVISION DESCRIPTION
G
FE
+
0101
FE
+
0101
MSS
FT
0101-1
MSS-V005A
MSS-V004A
MSS
MSS
MSS-V004B
MSS-V005B
FT
0101-2
FT
0101-1
MSS-V005A
MSS-V004A
MSS
MSS-V004B
MSS-V005B
FT
0101-2
APPR
CHECKED
MSS-V007A
MSS-V006A
MSS-V006B
MSS-V007B
MSS
CRS
CRS
CRS
CRS
PV
+
0100
TE
0100-1
TW
0100-1
TE
0100-2
TW
0100-2
MSS-V007A
MSS-V006A
MSS-V006B
MSS-V007B
MSS
CRS
CRS
CRS
CORRECT
CRS
DATE
PV
+
0100
TE
0100-1
TW
0100-1
TE
0100-2
TW
0100-2
H
MSS
MSS
MAIN STEAM
TURBINE
BYPASS VALVE
MSS
MSS
FC
MAIN STEAM
TURBINE
BYPASS VALVE
TE
0102-1
TW
0102-1
TE
0102-1
TW
0102-1
FC
MSS
MSS
MSS
MSS
TE
0102-2
TW
0102-2
TE
0102-2
TW
0102-2
REVISION DESCRIPTION
I
APPR
CHECKED
CORRECT
DATE
CRS
CRS
J
PI
0101
PI
0101
CRS-V015
CRS-V015
CRS
CRS
CRS
CRS
TI
0110
TW
0110
TI
0110
TW
0110
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
0304 PID-03-02A
0301
PID-03-01B
0309 PID-03-05A
0304 PID-03-02A
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
DESIGNED BY
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
TO COLD REHEAT
SYSTEM
TO HP STEAM
TURBINE
TO AUX. STEAM
SYSTEM
TO COLD REHEAT
SYSTEM
M
MAIN STEAM SYSTEM
SHEET 1 OF 2
131134-PID-03-01A-C
NORTHPORT OPTION 4 PCT
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10

1
2
3
4
5
6
7
8
9
10
A
0301 PID-03-01A
FROM
HP STEAM
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
D
MSS
MSS
MSS
MSS
MSS-V020
MSS-V021
TE
0126
TW
0126
TE
0104
TW
0104
MSS
PP
0127
REVISION DESCRIPTION
C
MSS-V024
MSS-V023
LO
MSS-V022
MSS
MSS
PT
0103
TV
+
0126
MSS-V009
MSS-V008
FO
APPR
D
LBA
10/15
MSS
TW
0108
EMERGENCY STOP VALVE
TMB
CONTROL VALVE
STEAM TURBINE PACKAGE
CHECKED
CORRECT
DATE
MSS
ZSC
0126
MSS
LBA
10/O5
ESV
+
0101
TMB
ZSO
0126
CV
+
0101
REVISION DESCRIPTION
E
MAA
10/95
HP
SDS
MAA
10/90
TE
0103
APPR
CHECKED
CORRECT
DATE
F
MSS-T001
HIGH PRESSURE
STEAM TURBINE
LBA
10/10
MAA
10/85
REVISION DESCRIPTION
G
BEFORE SEAT DRAIN
CASING DRAIN
CASING DRAIN
CASING DRAIN
APPR
CHECKED
CORRECT
DATE
H
LO
SDS-V001
LO
SDS-V012
LO
SDS-V014
LO
SDS-V015
SDS
SDS
SDS
SDS
REVISION DESCRIPTION
ZSO
0129
ZSO
0142
ZSO
0140
ZSO
0138
I
SDS
SDS
SDS
SDS
ZSC
0129
ZSC
0142
ZSC
0140
ZSC
0138
SDS
SDS
SDS
SDS
APPR
FV
+
0129
MAL
10/65
FV
+
0142
MAL
10/45
FV
+
0140
MAL
10/15
FV
+
0138
CHECKED
CORRECT
DATE
FO
FO
FO
FO
MAL
10/70
NOTE 6
ALSTOM
MAL
10/50
MAL
10/20
J
SDS
SDS
SDS
MAL
10/75
RO
+
0142
MAL
10/55
RO
+
0140
MAL
10/25
RO
+
0138
RO
RO
RO
MAL
10/80
MAL
10/60
MAL
10/30
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
0306 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0303 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0307 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0308 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0305 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
DESIGNED BY
NOTES:
DSGN CHK’D BY
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
2. STRAINER INTEGRAL TO ESV.
M
MAIN STEAM SYSTEM
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
SHEET 2 OF 2
131134-PID-03-01B-C
nationalgrid
NORTHPORT OPTION 4
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
0304 PID-03-01A
FROM HP STEAM BYPASS
1A & 1B
FROM IP STEAMHEATER OUTLET
1A &1B
HP
MAA
10/30
CRS
CRS
CRS
CRS
CRS
CRS
CRS
CRS
STEAM TURBINE PACKAGE
REVISION DESCRIPTION
TE
0102-1
TW
0102-1
TE
0138-3
TW
0138-3
TE
0138-2
TW
0138-2
TE
0138-1
TW
0138-1
CRS
CRS-V018
CRS
CRS-V017
CRS
CRS-V016
CRS
CRS
PS
0137-3
PS
0137-2
PS
0137-1
TE
0102-2
TW
0102-2
B
APPR
CRS
CHECKED
CORRECT
TW
0103
CRS
CRS
DATE
CRS
PV
+
0139A
PV
+
0139B
PP
0100
CRS
CRS
CRS
PT
0104
CRS
CRS-V001 CRS-V002
3"
FO
FO
LSH
0129-1
LE
0129-1
CRS
CRS
ZSC
0139A
ZSC
0139B
V
D
PI
0105
CRS-V003 CRS-V004
CRS-V006
CRS
CRS
ZSO
0139A
ZSO
0139B
REVISION DESCRIPTION
C
D
CRS-V007
CRS
CRS-V005
RO
+
0139
PT PT
RO
APPR
D
LPS-VXXXX LPS-VXXXX LPS-VXXXX
V
D
CHECKED
CORRECT
CRS
CRS
CRS
DATE
NRV
+ +
0106A
TURBINE WARM-UP LINE
LSHH
0129-2
LE
0129-2
LO
CRS-V008
CRS
LV
+
0129
FT
LPS-VXXXX LPS-VXXXX
FT
CRS
FO
ZSC
0106A
LPS-VXXXX
CRS
CRS
CRS
REVISION DESCRIPTION
E
ZSO
0106A
TV
+
0136
ZSC
0129
CRS
CRS
TE
TW
ZSO
0129
ZSC
0136
APPR
CRS
SDS
CRS
CHECKED
CORRECT
NRV
0106B
TE
TE
TW
0111
DATE
F
ZSO
0136
0829
CRS
CRS
CRS
LSH
0131-1
LE
0131-1
ZSC
0106B
PID-03-02A
CRS
V
D
ZSO
0106B
CRS-V009
CRS-V012
REVISION DESCRIPTION
G
D
CRS
DESH
001
CRS-V013
CRS
DESUPERHEATER
CRS-V010
CRS-V011
APPR
CHECKED
CORRECT
V
D
DATE
CRS
CRS
H
10 DIA. MIN.
CRS
CRS
LSHH
0131-2
LE
0131-2
LO
CRS-V014
LSH
0143-1
LE
0143-1
CRS
CRS
CRS
LV
+
0131
TE
0000
TW
0000
V
D
FO
CRS
D
ZSC
0131
CRS
CNM
CRS-V019 CRS-V020
CRS-V021
REVISION DESCRIPTION
I
CNM-V026
CRS-V023
CRS-V022
CNM-V025
ZSO
0131
APPR
TV
+
0000
V
D
SDS
CHECKED
CORRECT
CRS
CRS
FC
CNM-V027
LO
CRS-V024
DATE
TE
0141
LSHH
0143-2
LE
0143-2
CRS
CNM-V024
LV
+
0143
J
CNM
FO
HV
+
0000
FC
CRS
D
ZSC
0143
CNM-STR009
CNM-V023
REVISION DESCRIPTION
CRS
ZSO
0143
K L
SDS
TE
0153
APPR
PID-04-01B
0324 PID-11-01A
CONDENSATE SUPPLY
8023A
1A
TO DESUPERHEATER
0328 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0326 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
PRESSURE RELEASE TO STEAM
CHECKED
CORRECT
DRAIN COLLECTION SYSTEM
DATE
PID-03-05A
TO AUX. STEAM
SYSTEM
0322 PID-11-02A
TO HRSG BLOWOFF
TANK
0409
TO REHEATER INLET A
1A
TO REHEATER INLET B
DESIGNED BY
NOTES:
DSGN CHK’D BY
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
COLD REHEAT
SYSTEM
131134-PID-03-02A-C
nationalgrid
NORTHPORT OPTION 4
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
HRSG REHEAT OUTLET 1A
0425 PID-04-01B
DESUPERHEATING SPRAY
FROM CONDENSATE SYSTEM
HRSG REHEAT OUTLET 1B
0425 PID-04-01B
DESUPERHEATING SPRAY
FROM CONDENSATE SYSTEM
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
CNM-V060A
CNM-V060A
CNM-STR003
CNM-STR003
REVISION DESCRIPTION
C
CNM
CNM
CNM
FE
+
0103
CNM
FE
+
0103
FT
0103
CNM-V061A CNM-V062A
FT
0103
CNM-V061A CNM-V062A
APPR
D
CHECKED
CORRECT
DATE
CNM
CNM
CNM
CNM
TE
0104
TW
0104
TE
0104
TW
0104
CNM
CNM
HV
+
0306
HV
+
0306
REVISION DESCRIPTION
E
FC
FC
CNM
CNM
ZSC
0306
ZSC
0306
CNM
CNM
CNM
CNM
ZSO
0306
ZSO
0306
APPR
TV
+
0104
TV
+
0104
CHECKED
CORRECT
DATE
FC
FC
F
HRS
PT
0100-1
CNM-V064A
HRS
PT
0100-1
CNM-V064A
HRS
HRS-V003A
HRS
HRS-V003A
REVISION DESCRIPTION
G
PT
0100-2
HRS
PT
0100-2
HRS
HRS-V003B
FE
+
0105
HRS-V003B
FE
+
0105
HRS
HRS
HRS
FT
0105-1
HRS-V004A
HRS-V004B
FT
0105-2
FT
0105-1
HRS-V004A
HRS-V004B
HRS
FT
0105-2
APPR
HRS
HRS
HRS
HRS
HRS
HRS
HRS
HRS
HRS
HRS
CHECKED
CORRECT
HRS-V005B
HRS-V005B
PV
+
0100
TE
0106-1
TW
0106-1
TE
0106-2
TW
0106-2
PV
+
0100
HOT REHEAT
BYPASS VALVE
FC
HRS-V005B
HRS-V005B
TE
0106-1
TW
0106-1
TE
0106-2
TW
0106-2
DATE
HOT REHEAT
BYPASS VALVE
FC
H
HRS
HRS
HRS
HRS
TE
0109-1
TW
0109-1
TE
VENDOR
VENDOR
0109-1
TW
0109-1
VENDOR
HRS
HRS
HRS
HRS
VENDOR
TE
0109-2
TW
0109-2
TE
0109-2
TW
0109-2
HRS
HRS
REVISION DESCRIPTION
HRS
LSH
0123-1
LE
0123-1
I
PI
0120
HRS-V006
HRS
HRS
APPR
TI
0121
TW
0121
HRS-V015 HRS-V016
HRS-V017
CHECKED
CORRECT
DATE
D
HRS
J
HRS-V019
PI
0120
HRS-V018
HRS-V006
HRS
HRS
LSH
HRS
HRS
0123-1
LE
0123-1
TI
0121
TW
0121
HRS
HRS
HRS
LAHH
0123-2
LSHH
0123-2
LE
0123-2
REVISION DESCRIPTION
HRS
HRS-V015 HRS-V016
HRS-V017
K L
XA
0123-2
D
APPR
HRS-V019
CHECKED
CORRECT
HRS-V018
DATE
HRS
HRS
HRS
LAHH
0123-2
LSHH
0123-2
LE
0123-2
HRS
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
0341 PID-03-03B
TO HOT REHEAT STEAM
0342 PID-11-01B
XA
0123-2
SHEET 2
TO STEAM DUCT SPRAGER
0342 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
0343 PID-03-12A
TO STEAM DUCT SPARGER
0342 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
M
HOT REHEAT STEAM SYSTEM
SHEET 1 OF 2
131134-PID-03-03A-C
NORTHPORT OPTION 4 PCT
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10

1
2
3
4
5
6
7
8
9
10
A
0341 PID-03-03A
HOT REHEAT STEAM
SHEET 1
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
D
HRS
HRS
HRS
HRS-V010
TE
0110
TW
0110
PT
0103
REVISION DESCRIPTION
C
HRS
PP
0115
HRS-V012 HRS-V013
LO
HRS-V011
HRS
HRS
TW
0107
TV
+
0110
APPR
D
CHECKED
CORRECT
HRS
HRS
FO
DATE
TE
0104
TW
0104
STEAM TURBINE
HRS
PACKAGE
ZSC
0110
HRS
ZSO
0110
REVISION DESCRIPTION
E
SDS
TE
0115
APPR
EMERGENCY STOP VALVE
CHECKED
CORRECT
HRS
EMERGENCY STOP VALVE
DATE
F
TMI
+
CONTROL VALVE
HRS
+
CONTROL VALVE
TMI
HRS
HRS
PP
0106A
PP
0106B
ESV
0103A
CV
0104A
CV
+
0104B
ESV
+
0103B
IP
REVISION DESCRIPTION
G
LP
CASING DRAIN
BEFORE SEAT DRAIN
APPR
CHECKED
CORRECT
DATE
H
REVISION DESCRIPTION
I
LO
SDS-V010
LO
SDS
FV
+
0146
SDS-V011 FO
SDS
FV
LO
SDS-V002
LO
SDS
SDS
SDS-V005
ZSC
0146
ZSC
0144
SDS
SDS
APPR
SDS
SDS
ZSC
0126
ZSC
0154
CHECKED
CORRECT
DATE
ZSO
0146
ZSO
0144
SDS
SDS
SDS
SDS
ZSO
0126
ZSO
0154
+
0144
FV
+
0126
FV
+
0154
J
FO
FO
FO
SDS
SDS
RO
+
0146
RO
+
0144
REVISION DESCRIPTION
RO
RO
K L
APPR
CHECKED
CORRECT
DATE
0344 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0346 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0347 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0348 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0345 PID-11-01A
TO STEAM DRAIN
NOTES:
COLLECTION SYSTEM
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
2. STRAINER INTEGRAL TO ESV.
M
HOT REHEAT STEAM SYSTEM
SHEET 2 OF 2
131134-PID-03-03B-C
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
REVISION DESCRIPTION
HRSG LP
SUPERHEATER OUTLET 1A
HRSG LP
SUPERHEATER OUTLET 1B
0424 PID-04-01B
DESUPERHEATER SUPPLY
FROM CONDENSATE SYSTEM
B
APPR
CHECKED
CORRECT
DATE
CNM-V060B
CNM-STR004
REVISION DESCRIPTION
C
CNM
FT
0101
CNM-V061B CNM-V062B
CNM
APPR
D
FE
+ +
0101
CHECKED
CORRECT
DATE
CNM
CNM
TE
0102
TW
0102
CNM
REVISION DESCRIPTION
E
HV
0305
FC
LPS
LPS
CNM
PT
0100-1
PT
0100-1
ZSC
0305
APPR
LPS
CNM
PT
0100-2
LPS-V001A LPS-V001B LPS-V002A
LPS
CNM
LPS
PT
0100-2
TV
+
0102
FE
+
0103
FC
LPS
LPS
FT
0103-1
LPS-V002B LPS-V003B
FT
0103-2
LPS-V001A LPS-V001B LPS-V002A
CHECKED
CORRECT
DATE
F
LPS
ZSO
0305
FE
+
0103
LPS
LPS
FT
0103-1
LPS-V003A
LPS-V002B LPS-V003B
FT
0103-2
LPS-V003A
REVISION DESCRIPTION
G
LPS
LPS
LPS
LPS
CNM-V064B
TE
0111-1
TW
0111-1
TE
0111-1
TW
0111-1
APPR
LPS
LPS
LPS
LPS
CHECKED
CORRECT
DATE
TE
0111-2
TW
0111-2
TE
0111-2
TW
0111-2
H
LPS
LPS
LPS
LPS
LPS
PV
+
0100
TE
0109-1
TW
0109-1
TE
0109-2
TW
0109-2
REVISION DESCRIPTION
FC
I
LPS
PI
0107
LPS
LPS
LPS
APPR
LPS-V012
CHECKED
CORRECT
LSH
0118-1
LSH
0118-1
LE
0118-1
DATE
LPS
LPS
I&C
TI
0108
TW
0108
J
LPS-V010 LPS-V011
LPS-V013
D
LPS-V015
REVISION DESCRIPTION
LPS-V014
K L
I&C
LPS
LPS
APPR
LSHH
0118-2
LE
0118-2
CHECKED
CORRECT
DATE
0368 PID-03-04B
TO LP STEAM TURBINE
0361
NOTES:
PID-03-12A
TO STEAM DUCT
SPARGER
0360 PID-11-01B
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
TO STEAM DRAIN
COLLECTION SYSTEM
M
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
LOW PRESSURE STEAM SYSTEM
SHEET 1 OF 2
131134-PID-03-04A-C
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
0368 PID-03-04A
LOW PRESSURE STEAM
0368
SUPPLY A
PID-03-04A
LOW PRESSURE STEAM
SUPPLY B
REVISION DESCRIPTION
LPS
B
LE
0114-1
APPR
CHECKED
CORRECT
V
D
DATE
I&C
LPS-V021
LPS-V024
D
LPS-V025
LPS-V022
LPS-V023
I&C
REVISION DESCRIPTION
C
V
D
LPS
LE
0114-2
APPR
D
LPS
CHECKED
CORRECT
DATE
PT
0106
LPS
LPS
PP
0100
LV
+
0114
LPS
LPS
LPS-V027 LPS-V028
LO
LPS-V026
FO
TE
0104
TW
0104
LPS
LPS
REVISION DESCRIPTION
E
TW
0105
ZSC
0114
LPS
ZSO
0114
APPR
CHECKED
CORRECT
EMERGENCY STOP VALVE
CONTROL VALVE
DATE
F
SDS
TE
0118
TMB
TMB
IP
ESV
+
0105
CV
+
0106
10"
LP
REVISION DESCRIPTION
G
APPR
CHECKED
CORRECT
DATE
H
REVISION DESCRIPTION
I
LO
SDS
SDS-V003
LO
SDS
SDS-V004
APPR
CHECKED
CORRECT
ZSC
0125
ZSC
0120
DATE
SDS
SDS
SDS
SDS
ZSO
0125
ZSO
0120
J
FV
+
0125
FV
+
0120
REVISION DESCRIPTION
FO
FO
K L
APPR
CHECKED
CORRECT
DATE
0364 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
0365 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
0366 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
0362 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
2. STRAINER INTEGRAL TO ESV.
M
LOW PRESSURE STEAM SYSTEM
SHEET 2 OF 2
131134-PID-03-04B-C
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
REVISION DESCRIPTION
0933 PID-09-21A
CONDENSATE MAKE-UP LINE
0936 PID-09-21A
CONDENSATE MAKE-UP LINE FOR START UP
1101 PID-11-01A
1102 PID-11-01A
STG STEAM DRAIN SYSTEM MANIFOLD
1103 PID-11-01B
LOW PRESSURE DRAIN SYSTEM MANIFOLD
B
HIGH PRESSURE DRAIN SYSTEM MANIFOLD
APPR
CHECKED
CORRECT
DATE
REVISION DESCRIPTION
C
APPR
D
CNM
CHECKED
CORRECT
DATE
TW
0110
LG-1
CNM
LG-1
TW
0114
CNM-V001A
CNM-V001B
REVISION DESCRIPTION
E
PI-1
CNM-VXXX
CNM
PDT
0115A
CNM-V002A
CNM
CNM-STR001A
D
PDT
0115B
CNM-V002B
CNM-STR001B
D
PI-1
CNM-V003A
CNM-V003B
CNM-VXXX
CONDENSATE HOTWELL TANK
APPR
CHECKED
CORRECT
CNM
CNM-V004A
CNM
CNM-V004B
DATE
F
PSV
+
0116A
PSV
+
0116B
PI-1
CNM-VXXX
CNM
PSET=50.psig
CNM
PSET=50.psig
PI
0118A
PI
0118B
LG-1
CNM-V005A
CNM-V005B
REVISION DESCRIPTION
G
CNM-V013A
CNM-V013B
APPR
CNM
CNM-V014A
CNM
CNM-EJ001A
CNM-V014B
CHECKED
CORRECT
TE
0162A
TE
0162B
CNM-EJ001B
DATE
VACUUM
BREAKER
H
M
CNM-P001A
CONDENSATE PUMP
1A
M
CNM-P001B
CONDENSATE PUMP
1B
CNM
TE
0163A
TE
0163B
CNM
CNM
CNM
CNM
PI
0170A
PI
0170B
REVISION DESCRIPTION
TE
0164A
TE
0164B
I
CNM
CNM
TE
0165A
TE
0165B
CNM
CNM
CNM
CNM
APPR
PCV
+
0171A
PCV
+
0171B
TE
0166A
CNM
TE
0166B
CNM
CHECKED
CORRECT
DATE
PI
0119A
PI
0119B
CNM
TE
0264A
CNM-V008A
CNM
CNM-V008B
CNM
TE
J
0264B
CNM
TW
0109A
TW
0109B
CNM-V009A CNM-V010A
D
CNM-STR002A
CNM-V012A
CNM-V011A
CNM-V009B CNM-V010B
D
CNM-STR002B
CNM-V012B
REVISION DESCRIPTION
CNM-V011B
K L
APPR
CHECKED
CORRECT
DATE
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
FROM HRSG 1A LP STEAM SYSTEM
0402
PID-03-4A 0361A
BYPASS VALVE
PID-03-4A 0343A
FROM HRSG 1B LP STEAM SYSTEM
BYPASS VALVE
PID-03-4A 0361B
FROM HRSG 1A HOT REHEAT SYSTEM
BYPASS VALVE
PID-03-4A 0343B
FROM HRSG 1B HOT REHEAT SYSTEM
BYPASS VALVE
PID-04-1B
PID-05-01A
PID-05-01A
PID-04-01B
CONDENSATE PUMP
0501
0502
DISTRIBUTION SYSTEM
0406
MIN. FLOW RECIRC. DRAIN
SJAE INTERCOND. DRAIN
SJAE AFTERCOND. DRAIN
PID-04-01B 0420
SUPPLY FOR SEALWATER
M
CONDENSATE SYSTEM
SHEET 1 OF 2
131134-PID-04-01A-D
NORTHPORT OPTION 4 PCT
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10

1
2
3
4
5
6
7
8
9
10
A
0831 PID-08-07D
FROM FUEL GAS HEATER
1302 PID-13-06B
FROM OXYGEN SCAVENGER
FEED SYSTEM
1301 PID-13-06A
FROM AMINE
FEED SYSTEM
0402 PID-04-01A
CONDENSATE PUMP
DISCHARGE HEADER
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
CNC-V001 CNC-V003
CNC-V002 CNC-V004
CNM
PT
0122
CNM-V030
REVISION DESCRIPTION
C
CNM
CNM
CNM
TE
0123
TW
0123
CNM
CNM
CNM
GLAND
STEAM
CONDENSER
PI
0126
CNM
CNM
CNM
REF. 2
STEAM JET
AIR EJECTOR
CONDENSER
CNM
TW
0128
TW
0127
TE
0127
CNM-V031
TW
0125
TW
0124
TE
0124
TW
0109C
APPR
D
CHECKED
CORRECT
DATE
MKM
CNM
7/2/03
FE
+
0132
REVISION DESCRIPTION
E
CNM
FT
0132
CNM-V032 CNM-V033
APPR
CHECKED
CORRECT
DATE
F
CNM
CNM
TI
0133
TW
0133
CNM
CNM
TE
0135-1
TW
0135-1
CNM
CNM
TE
0135-2
TW
0135-2
REVISION DESCRIPTION
G
CNM-V041
APPR
CHECKED
CORRECT
CNM
CNM
DATE
PT
0136-1
PT
0136-1
H
CNM
CNM-V034A
CNM
CNM-V034A
PT
0136-2
PT
0136-2
CNM-V034B
CNM-V034B
MKM 10/18/02
MKM
CNM
CNM
FE
FE
+
0139
CNM-V050
CNM
FT
0139-1
CNM-V035A CNM-V036A
CNM-V035B
CNM
FT
0139-2
CNM-V046
CNM-V022
CNM
FV
+
0132
CNM
FO
CNM-V051
CNM-V037
LV
+
0111-1
FC
CNM-V047
24MAY02
CNM-V053
+ +
0139
CNM
REVISION DESCRIPTION
CNM-V035A CNM-V036A
CNM-V035B
CNM
FT
0139-1
FT
I
0139-2
APPR
CHECKED
CORRECT
DATE
CNM-V037
J
CNM
CNM
LV
0137
LV
+
0137
6"
6"
FC
CNM-V038
FC
CNM-V038
CNM-V049
REVISION DESCRIPTION
CNM-V040
CNM-V040
K L
APPR
CHECKED
CORRECT
0406 PID-04-01A
MINIMUM FLOW RECIRC TO
CONDENSATE STORAGE TANK
0407
0407
0427 PID-06-01B
TO IP DRUM FILL
0426 PID-06-01B
TO HP DRUM FILL
0405 PID-15-01A
DRAW-OFF TO SERVICE WATER
/ FIRE PROTECTION TANK
0415 PID-11-01A
CONDENSATE SUPPLY TO
STEAM DRAIN SYSTEM
0425 PID-03-03A
HOT REHEAT BYPASS
VALVE SUPPLY
0424 PID-03-04A
LP-BYPASS
VALVE SUPPLY
0417 PID-03-05A
0428 PID-03-12A
0427 PID-06-01B
0426 PID-06-01B
TO AUX. STEAM SYSTEM
DESUPERHEATER
TO STEAM TURBINE VACUUM
BREAKER VALVE
HRSG
LP ECONOMIZER INLET
( HRSG A)
TO IP DRUM FILL
( HRSG A)
TO HP DRUM FILL
( HRSG A)
HRSG
LP ECONOMIZER INLET
( HRSG B)
( HRSG B)
( HRSG B)
0414 PID-21-03A
TO SAMPLE PANEL
TO AUX. STEAM DESUPERHEATERS
(MAIN STEAM SYSTEM)
0409 PID-03-02A
TO HRSG 1A & 1B COLD REHEAT DESUPERHEATERS
DATE
0416 PID-11-01A
CONDENSATE SUPPLY TO
STEAM DRAIN SYSTEM
0418 PID-11-01B
CONDENSATE SUPPLY TO
STEAM DRAIN SYSTEM
0429 PID-16-01A
TO GLAND STEAM SKID
EXHAUST HOOD SPRAY
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
CONDENSATE SYSTEM
SHEET 2 OF 2
131134-PID-04-01B-D
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
REVISION DESCRIPTION
HRSG HP DEAERATOR HEADER
OUTLET
HRSG LP DEAERATOR HEADER
OUTLET
B
APPR
CHECKED
CORRECT
DATE
FWS-V001A
REVISION DESCRIPTION
C
FWS
PDS
0110A
FWS-V002A
D
FWS
FWS-V003A
PSV
+
0112A
PSET=150.psig
FWS
PT
0114A
FWS
PI
0115A
FWS-V004A FWS-V005A FWS-V006A
FWS-STR001A
APPR
D
CHECKED
CORRECT
DATE
FWS
VE
0160A
FWS
VE
0161A
FWS
FWS
VE
0162A
FWS-V001B
REVISION DESCRIPTION
E
TW
0116A
FWS
FWS
FWS
FWS
VE
0164A
FWS
PDS
0110B
7/2/03
TE
0117A
TW
0117A
FWS-V002B
D
VE
0165A
FWS
FWS-V003B
FWS
FWS
PI
0118A
PSV
+
0112B
FWS-V013A
FWS
PT
0114B
FWS
PI
0115B
FWS-V004B FWS-V005B FWS-V006B
FWS-STR001B
APPR
HS
0001A
PSET=150.psig
CHECKED
CORRECT
FWS-P001A
BOILER
FEED PUMP 1A
DATE
F
FWS
TE
0168A
FWS
TE
0169A
FWS
TE
0170A
FWS
FWS
VE
TE
0171A
0160B
FWS
VE
0161B
FWS
FWS-V007A FWS-V008A
FWS
VE
0162B
REVISION DESCRIPTION
G
TE
0174A
FWS
FWS
TE
0175A
TW
0116B
FWS
FWS
VE
0164B
TE
0176A
FWS
FWS
FWS
FWS
VE
0165B
TI
0117B
TE
0117B
TW
0117B
APPR
CHECKED
CORRECT
DATE
FWS-V008B
FWS-V007B
10/18/02
H
FWS
FWS-V013B
FWS-P001B
BOILER
FEED PUMP 1B
FWS
TE
0168B
FWS
PI
0118B
TE
0169B
FWS
TE
0170B
FWS
TE
0171B
REVISION DESCRIPTION
FWS
FWS
FWS
I
PI
0125A
PI
0125B
TE
0174B
FWS-V015A
FWS-V014A FWS-V016A
FWS-V015B
FWS
FWS
PT
0155A
PT
0155B
FWS-V017A
FWS-V017B
FWS-V014B FWS-V016B
FWS
TE
0175B
FWS
TE
0176B
APPR
CHECKED
CORRECT
DATE
J
FWS-V0XXA
FWS-V0XXB
REVISION DESCRIPTION
FWS-V009A
FWS-V009B
FWS-V011A
FWS-V011B
K L
FWS-V010A
FWS-V010B
APPR
CHECKED
CORRECT
DATE
LO
FWS-V012A
LO
FWS-V012B
0601 PID-06-01B
0609
IP FEEDWATER
CONTROL VALVE
0602 PID-06-01B
0609
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
2. TYPICAL FOR EACH OF 2 HRSGS.
HRSG LP DRUM
BFP #1A MIN FLOW RECIRC.
HP FEEDWATER
CONTROL VALVE
HRSG LP DRUM
BFP #1B MIN FLOW RECIRC.
M
FEEDWATER SYSTEM
SHEET 1
131134-PID-06-01A-D
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
0427 PID-04-01B
FROM CONDENSATE SYSTEM
FOR IP DRUM 1A &1B FILL
0601 PID-06-01A
FROM BOILER FEED PUMP
IP DISCHARGE
0426 PID-04-01B
FROM CONDENSATE SYSTEM
FOR HP DRUM FILL
0602 PID-O6-01A
FROM BOILER FEED PUMP
HP DISCHARGE
REVISION DESCRIPTION
B
APPR
FWS-V029
CHECKED
CORRECT
DATE
FWS-V031
FWS-V064
FWS
TW
0123
FWS-V028
FWS-V066
FWS
FWS
PT
0119
REVISION DESCRIPTION
C
FWS-V022
FWS
FE
FWS-V023A FWS-V024A
TW
0123
FWS
FWS
TW
0130
PT
0119
+
0120
FWS
FWS-V023B FWS-V024B
FWS
FT
0120-1
FT
0120-2
FWS
PT
0131
FWS-V063
FWS
FWS
FWS-V053
FWS-V052
TE
0122-1
TW
0122-1
FWS-V022
FWS
FE
FWS-V023A FWS-V024A
APPR
D
CHECKED
CORRECT
DATE
+
0120
FWS
FWS-V023B FWS-V024B
FWS
FT
0120-1
FT
0120-2
FWS
FWS
FWS
FE
+
0132
TE
0122-2
TW
0122-2
FWS
FWS
REVISION DESCRIPTION
E
TE
0122-1
TW
0122-1
FWS
FT
0132-1
FWS-V055A
FWS-V054A
FWS-V054B
FWS-V055B
FWS
FWS
FWS
FT
0132-2
TE
0122-2
TW
0122-2
FWS
M
FWS-V057A
FWS-V056A
FWS-V056B
FWS-V057B
APPR
MOV
+
0511
CHECKED
CORRECT
DATE
FWS
FWS
F
FWS
M
TE
0133-1
TW
0133-1
MOV
+
0511
FWS
FWS
IP ECONOMIZER
TE
0133-2
TW
0133-2
1A
REVISION DESCRIPTION
G
IP ECONOMIZER
1B
FWS-V050
FWS
APPR
FWS
FWS
FWS
FE
+
0134
CHECKED
CORRECT
FWS
FE
+
0121
FWS
FE
+
0121
FWS
FT
0134
FWS-V033
FWS-V034
DATE
H
FT
0121
FWS-V032 FWS-V033
FT
0121
FWS-V032 FWS-V033
LV
+
0132
FO
FWS-V058
FWS-V035
FWS-V036
REVISION DESCRIPTION
I
FWS-V020
FWS-V020
FWS-V051
FWS
FWS
APPR
LV
+
0120
LV
+
0120
CHECKED
CORRECT
FO
FWS-V026
FO
FWS-V026
DATE
J
FWS-V021
FWS-V021
REVISION DESCRIPTION
K L
0610
TO HRSG IP DRUM 1A
0616 PID-08-07C
TO FUEL GAS HEATER
0610
TO HRSG IP DRUM 1B
0616 PID-08-07C
TO FUEL GAS HEATER
0611
TO REHEATER 1A ATTEMP SPRAY
0611
TO REHEATER 1B ATTEMP APRAY
0612
TO HRSG 1A & 1B HP
0613
1A + 1B
ECONOMIZER INLET
HP SUPERHEATER 1A & 1B
ATTEMP SPRAY
0608 PID-03-01A
MAIN STEAM FEEDWATER BYPASS
VALVE DESUPERHEATER
0608 PID-03-01A
MAIN STEAM TURBINE BYPASS
VALVE DESUPERHEATER SPRAY
APPR
CHECKED
CORRECT
DATE
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
FEEDWATER SYSTEM
SHEET 2
131134-PID-06-01B-D
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
EXISTING
GAS PIPELINE
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
REVISION DESCRIPTION
C
APPR
D
GEAR OPERATED
GEAR OPERATED
CHECKED
CORRECT
FGS-V017
FGS-V027
DATE
FGS
FGS
PDI
0168B
FGS-V011 FGS-V012
FGS-FLT001B
D
PDI
0168A
FGS-V021 FGS-V022
FGS-FLT001A
FGS-V013
FGS-V023
REVISION DESCRIPTION
D
E
APPR
FGS
FGS
FGS
FGS
CHECKED
CORRECT
DATE
F
FI
0171B
FE
0171B
FI
0171A
FE
0171A
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FY
0172B
TI
0172B
TE
0172B
TW
0172B
FY
0172A
TI
0172A
TE
0172A
TW
0172A
FGS
FGS
PT
0173B
PT
0173A
FGS-V015
FGS-V025
REVISION DESCRIPTION
G
APPR
CHECKED
CORRECT
DATE
H
FGS
FGS
ZSC
0175B
ZSC
0175A
FGS
FGS
FGS
FGS
FGS
ZSO
0175B
MOV
+
0175B
ZSO
0175A
MOV
+
0175A
REVISION DESCRIPTION
ASME
B31.8
ASME
B31.8
HS
0175B
M
M
I
ASME
B31.1
ASME
B31.1
NATIONAL GRID METERING STATION
(NOTE 2)
APPR
CHECKED
CORRECT
DATE
J
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
0801 PID-08-07B
TO FUEL GAS COMPRESSORS
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
2. ASSUME TYPICAL ARRANGEMENT BY OWNNER.
M
FUEL GAS SYSTEM
SHEET 1 OF 4
131134-PID-08-07A-C
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
0801 PID-08-07A
PI
0111ABC
PAH
0111ABC
PAHH
0111ABC
2 OF 3
PAHH
0111
PI
0121ABC
PAH
0121ABC
PAHH
0121ABC
PAHH
0121
LI
0385ABC
LAH
0385ABC
LAHH
0385ABC
2 OF 3 2 OF 2 2 OF 2
LAHH
0385
EV
0381
ZIO
0381
ZIC
0381
EV
0385
FROM NATIONAL GRID
METERING SYSTEM
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
REVISION DESCRIPTION
PDI
0100
PDAH
0100
PDL
0110
PDAL
0110
PDI
0120
PDAL
0120
LI
0308
LAH
0308
TI
0515
TAH
0515
TAHH
0515
TAHH
0515/6
TI
0516
TAH
0516
TAHH
0516
YSH
0502
YSHH
0502
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
TI
0201
TAL
0201
LAL
0201
TI
0360
TAH
0360
PCV
0360
ZI
0360
TI
0501
TAH
0501
TAHH
0501
TAHH
0501/2
TI
0502
TAH
0502
TAHH
0502
YSH
0501
YSHH
0501
B
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
APPR
PDI
0227
PDAH
0227
TI
0230ABC
TAH
0230ABC
TAHH
0230ABC
2 OF 3
TAHH
0230
PI
0230ABC
PAL
0230ABC
PALL
0230ABC
2 OF 3
PALL
0230
YSH
0503
YSH
0501
YSHH
0501
YSHH
0501
TI
0519
TAH
0519
TAHH
0519
CHECKED
CORRECT
DATE
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
2 OF 2
2 OF 2
2 OF 2
DCS
FUEL GAS
COMPRESSOR
LOGIC
FGS-C001A
CONTROL
PANEL
FGS-V006 FGS-V007
EV
0303
ZIO
0303
ZIC
0303
FCU
0311
ZI
0311
TI
0517
TAH
0517
TAHH
0517
TI
0521
TAH
0521
TAHH
0521
TAHH
0521
TAHH
0517/8
TAHH
PI
0519/20
0000
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
LI
0315ABC
LAH
0315ABC
LAHH
0315ABC
FGS
FGS-V001
PI
0311
DCS
FUEL GAS
COMPRESSOR
LOGIC
FGS-C001B
CONTROL
PANEL
FGS
FGS
FGS
2 OF 3
0311
2 OF 3
LAHH
0315
PCV
0390
ZIO
0370
ZSC
0370
EV
0315
TI
0522
TAH
0522
TAHH
0522
TI
0518
TAH
0518
TAHH
0518
TI
0520
TAH
0520
TAHH
0520
PT
0000
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
TI
0311
TAH
FCU
0305
ZI
0305
TI
0321
PDI
0320
TI
0505
TAH
0505
TAHH
0505
TI
0503
TAH
0503
TAHH
0503
TI
0507
TAH
0507
TAHH
0507
REVISION DESCRIPTION
C
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
TI
0322ABC
TAH
0322ABC
TAHH
0322ABC
TAHH
0322
PI
0322ABC
2 OF 3
PI
0322
EV
0380
ZIO
0380
ZIC
0380
2 OF 2
TAHH
0507/8
2 OF 2
TAHH
0503/4
2 OF 2
TAHH
0505/6
TI
0508
TAH
0508
TAHH
0508
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
APPR
TI
0504
TAH
0504
TAHH
0504
TI
0506
TAH
0506
TAHH
0506
TI
0541
TAH
0541
TAHH
0541
D
CHECKED
CORRECT
DATE
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
TI
0543
TAH
0543
TAHH
0543
TI
0545
TAH
0545
TAHH
0545
2 OF 2
TAHH
0531/2
2 OF 2
TAHH
0533/4
COMP PLC
MONITORING
COMP PLC
VIBRATION
MONITORING
COMP PLC
MONITORING
COMP PLC
VIBRATION
MONITORING
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
TI
0542
TAH
0542
TAHH
0542
TI
0544
TAH
0544
TAHH
0544
TI
0546
TAH
0546
TAHH
0546
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
TI
0531
TAH
0531
TAHH
0531
TI
0533
TAH
0533
TAHH
0533
TI
0532
TAH
0532
TAHH
0532
REVISION DESCRIPTION
E
N
A
A
N
Q
OIL FILL
M
COLD GAS SUPPLY
SKID
MOUNTED
CONTROL
PANELS
COMPRESSOR FGS-C001A
COMPRESSOR FGS-C001B
FGS
FGS
FGS
SKID
MOUNTED
CONTROL
PANELS
COLD GAS SUPPLY
OIL FILL
TI
0534
TAH
0534
TAHH
0534
FGS
FGS
H
HS
0000
HS
0000
FGS
FGS
F
XA
0000
XA
0000
E
FGS-COOL001A
RECYCLED FUEL GAS COOLER
REFERENCE 1
REFERENCE 1
REFERENCE 2
C
C
REFER TO
PID-09-09D FOR
CCW DETAILS
L K G
Q M
H F E
D L K G
APPR
CHECKED
CORRECT
DATE
F
REVISION DESCRIPTION
G
FGS-COOL001B
RECYCLED FUEL GAS COOLER
D
REFERENCE 2
APPR
CHECKED
CORRECT
DATE
H
REFER TO
PID-09-09D FOR
CCW DETAILS
REVISION DESCRIPTION
O
O
1"
SCRUBBER
DRAIN TO
DRAIN TANK
INSTRUMENT
AIR
NITROGEN
PURGE
WARM GAS TO
FUEL GAS
HEATER
WARM GAS TO
FUEL GAS
HEATER
NITROGEN
PURGE
INSTRUMENT
AIR
I
SCRUBBER
DRAIN TO
DRAIN TANK
P
J
I
B
B
I
J
P
APPR
2" CLASS 301D1
BLIND FLANGE
2" CLASS 301D1
BLIND FLANGE
CHECKED
CORRECT
DATE
J
FGS-V003
FGS-V004
FUEL GAS COMPRESSOR BUILDING
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
0810 PID-08-07D
TO FGS-TK001
PID-14-01A
NITROGEN SUPPLY
0812 PID-08-07C
TO FUEL GAS SCRUBBER
0813 PID-08-07C
TO FUEL GAS HEATER
PID-12-01A
INSTRUMENT AIR
SUPPLY
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
1207
M
FUEL GAS SYSTEM
SHEET 2 OF 4
131134-PID-08-07B-C
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
0812 PID-08-07B
COOL GAS FROM FUEL
0813 PID-08-07B
FROM FUEL GAS
COMPRESSORS DISCHARGE
0616 PID-06-01B
FROM HRSG IP ECONOMIZER
A
GAS COMPRESSORS
REVISION DESCRIPTION
FGS
B
LSHH
FGS
0000C
APPR
FGS
PI
0127
FWS
CHECKED
CORRECT
LSHH
0000A
FGS-V030
DATE
FGS
FGS
FWS
FE
+
0111
FWS
FGS
FGS
PSV
+
0000
LSHH
0000B
FI
0111
FT
0111
TE
0129
TW
0129
FGS
FGS-V059
FGS-V060
FGS-V061
FGS-V062
FGS-V063
FGS-V064
LO
FGS-V005
FWS-V080 FWS-V081
AT
0130
FWS
FWS
MOISTURE
ANALYZER
TI
0115
TW
0115
REVISION DESCRIPTION
C
FWS
V
FWS
FGS-V065
FGS-V065
FWS
FWS
PI
0116
FWS
PSV
+
0000
ZSO
0000
ZSC
0000
FWS-V082
FGS
HV
+
0000
LSH
0000
APPR
D
FC
CHECKED
CORRECT
FWS-V084
DATE
FGS-E001
FUEL GAS HEATER
FGS
FGS
HV
+
0000
HV
+
0000
FGS-E002
FUEL GAS HEATER
FGS-V066
FGS
FGS-V067
LSH
0000
FGS
REVISION DESCRIPTION
FC
E
FC
FGS
ZSO
0000
ZSO
0000
FGS
FGS
ZSC
0000
ZSC
0000
APPR
CHECKED
CORRECT
FGS
FGS
DATE
F
TI
0133
TW
0133
FGS
PSV
+
0134
FUEL GAS SCRUBBER
REVISION DESCRIPTION
G
FGS
PI
0167
FGS-V032
REF. 1
FGS-V041
FGS
FGS
FGS
LIT
0385B
LI
0385
LIT
0385C
APPR
CHECKED
CORRECT
VENDOR
DATE
H
FGS
REF. 1
PSV
+
0385
FGS-SCRB002
HOT GAS
SCRUBBER
FWS
PI
0124
REVISION DESCRIPTION
I
FWS
FWS
FWS-V088
TI
0126
TW
0126
FGS
LIT
0385A
FGS
APPR
LCV
+
0385A
CHECKED
CORRECT
DATE
FC
J
REVISION DESCRIPTION
2" CLASS (LATER)
BLIND FLANGE
K L
FGS
APPR
PI
0187
CHECKED
CORRECT
FGS-V033
DATE
0823 PID-08-07D
0820
TO TEMPERATURE
CONTROL STATION
0811 PID-08-07D
FGS-V042
TO DRAIN TANK
FGS-TK001
PID-08-07D
FUEL GAS CONTROL STATION
0821 PID-08-07D
TO DRAIN TANK
FGS-TK001
0814 PID-08-07D
TO DRAIN TANK
FGS-TK001
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
FUEL GAS SYSTEM
SHEET 3 OF 4
131134-PID-08-07C-C
NORTHPORT OPTION 4 PCT
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10

1
2
3
4
5
6
7
8
9
10
A
0823 PID-08-07C
FROM FUEL GAS HEATER
0820 PID-08-07C
FROM HOT GAS
SCRUBBER
0810 PID-08-07B
CONDENSATE DRAIN FROM
FUEL GAS COMPRESSORS
0821 PID-08-07C
FROM HOT GAS
SCRUBBER
0811 PID-08-07C
DRAIN FROM
FUEL GAS HEATER
0814 PID-08-07C
REVISION DESCRIPTION
DRAIN FROM
FUEL GAS HEATER
B
APPR
CHECKED
CORRECT
DATE
FWS
HV
+
0000
FGS
GSV
+
0158
REVISION DESCRIPTION
C
FWS
FC
FWS
ZSO
0000
FGS
ZI
0000
FWS
ZSO
0158
APPR
ZSC
0000
D
FGS
CHECKED
CORRECT
FWS-V077
DATE
ZSC
0158
FWS
FWS
FWS
FWS
LSL
0180
ZSC
0180
ZSO
0180
LSV
+
0180
FWS-V078
FWS-V079
REVISION DESCRIPTION
E
ZSO
0157
ZSC
0157
FC
GSV
+
0157
APPR
FGS
CHECKED
CORRECT
DATE
F
FGS-V055
FGS
FE
FLOW CONDITIONER
+
0142
POWERHOUSE
FGS
FT
0142
REVISION DESCRIPTION
G
FGS-V056
FWS-V093
FGS
FGS-TK001
DRAIN TANK
APPR
CHECKED
CORRECT
TE
0144
FGS-FA001
FGS-V052
DATE
H
FGS
FGS-V053
FGS
FGS-V054
LIT
0180
FWS-V090
LG
0181
FGS
FGS
PT
0191
TV
+
0143
REVISION DESCRIPTION
FO
FWS-V092
FGS
PT
0192
FGS-V068 FGS-V069
I
FWS-V091
APPR
CHECKED
CORRECT
FGS
POWERHOUSE
DATE
PT
0126
J
FGS-V057
FGS
FGS
TE
0143-1
TW
0143-1
REVISION DESCRIPTION
FWS
FGS
FGS
K L
PSV
+
0000
TE
0143-2
TW
0143-2
APPR
CHECKED
CORRECT
DATE
0831 PID-04-01B
0830
0830A
TO CONDENSATE
SUPPLY LINE
PID-39-02A
GAS TURBINE
ACCESSORY MODULE
PID-39-02A
GAS TURBINE
ACCESSORY MODULE 1B
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
FUEL GAS SYSTEM
SHEET 4 OF 4
131134-PID-08-07D-C
NORTHPORT OPTION 4 PCT
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10

1
2
3
4
5
6
7
8
9
10
A
VAPOR RETURN
FILL
REVISION DESCRIPTION
D
D
B
AFS
CHEMICAL FILL
AREA UNLOADING
CONTAINMENT
APPR
CHECKED
CORRECT
PI
0103
DATE
DRAIN
REVISION DESCRIPTION
C
APPR
D
CHECKED
CORRECT
DATE
AFS
PI
0102
AFS
AQUEOUS AMMONIA
FORWARDING PUMP SKID
24" MANHOLE
AFS-TK001
AQUEOUS AMMONIA
PI
0104
REVISION DESCRIPTION
E
STORAGE TANK
PSET=50.psig
APPR
CHECKED
CORRECT
AFS
DATE
F
TI
0102
AFS
AFS
PDI
0105A
PDI
0105B
D
D
AFS
LSH
0101
REVISION DESCRIPTION
G
M
AFS-P001A
AQUEOUS AMMONIA
FORWARDING PUMP
VENDOR
AFS-P001B
AQUEOUS AMMONIA
FORWARDING PUMP
VENDOR
AFS
LI
0101
APPR
AFS
CHECKED
CORRECT
DATE
LT
0101
H
REVISION DESCRIPTION
I
APPR
AFS
AFS
AFS
CHECKED
CORRECT
PCV
+
0106
TI
0107
TW
0107
DATE
V
J
AFS
PI
0107
REVISION DESCRIPTION
K L
APPR
POWERHOUSE
D
CHECKED
CORRECT
DATE
AFS
AFS-V001
LSH
0000
AFS-V002
SCR SYSTEM
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
AQUEOUS AMMONIA STORAGE
SYSTEM
131134-PID-13-17A-B
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
0904 PID-09-09B
PID-09-09B
A
CCW SUPPLY HEADER
0905
CCW RETURN HEADER
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
CCW
PP
0135
REVISION DESCRIPTION
C
CCW-V061B
CCW-V060
PID-09-09D
APPR
D
CCW
CCW
CCW
CCW
CCW RETURN FROM
CHECKED
CORRECT
VJPC548IH7QD4
BFP
DATE
CCW-V065C
CCW-V065D
0907
CCW
TI
0145
TW
0145
TI
0150
TW
0150
PP
0151
CCW-V061A
CCW-V064C
CCW
CCW-V064D
CCW
CCW
FE
+
0144
CCW
CCW
FE
+
0149
FT
0144
FI
0149
FT
0149
REVISION DESCRIPTION
E
CCW
CCW-V063C
CCW
CTG GEN H2 COOLERS
PSV
+
0143
PSV
+
0148
CCW
PP
0152
CTG LCI COOLER
CCW
CCW-V062A
CCW
PSV
+
0153
PP
0136
CCW
CCW-V062B
CCW-V062C
CCW-V063D CCW-V062D
APPR
CHECKED
CORRECT
DATE
F
CCW
CCW
PP
0142
PP
0147
CCW-V063A
PSV
+
0137
REVISION DESCRIPTION
G
CCW
CCW
FE
+
0154
FT
0154
CCW-V063B
CCW
CCW-V064A
CCW
FE
+
0138
APPR
CHECKED
CORRECT
CCW
CCW
FT
0138
DATE
TI
0155
TW
0155
H
VJPC548IH7QD4
CCW-V065A
CCW-V064B
CCW
CCW
TI
0139
TW
0139
CCW-V065B
REVISION DESCRIPTION
CCW
PP
0141
CTG FLAME DETECTORS
PP
0146
CTG LO COOLER
I
CCW-V061C
CCW
CCW-V061D
APPR
CHECKED
CORRECT
DATE
J
REVISION DESCRIPTION
CCW-V063E CCW-V064E
CCW
CCW
FE
+
0140
K L
FT
0140
APPR
CCW-V065E
CHECKED
CORRECT
DATE
0906 PID-09-09D
CCW SUPPLY TO
BFP
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
2. TYPICAL FOR EACH CTG.
M
COMPONENT COOLING WATER SYSTEM
SHEET 3 OF 4
131134-PID-09-09C-D
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
0906 PID-09-09C
CCW SUPPLY HEADER
TO BFP
0911 PID-09-09A
CCW SUPPLY FOR
FUEL GAS COMPRESSOR
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
REVISION DESCRIPTION
C
BOILER FEED
PUMP 1A
APPR
D
CHECKED
CORRECT
DATE
CCW
ZSC
0164A
CCW
FUEL GAS COMPRESSOR
LUBE OIL COOLER 1A
CCW
ZSC
0165A
ZSO
0164A
CCW
CCW
ZSO
0165A
HV
+
0164A
REVISION DESCRIPTION
E
CCW
FO
HV
+
0165A
CCW-V072
FO
CCW
CCW
APPR
PP
0156
PP
0162
CHECKED
CORRECT
DATE
F
CCW-V072
CCW-V077
CCW
CCW
CCW
TI
0163
TW
0163
CCW
HV
+
0165B
REVISION DESCRIPTION
G
HV
FUEL GAS COMPRESSOR
+
0164B
FO
FO
LUBE OIL COOLER 1B
BOILER FEED
PUMP 1B
CCW
CCW-V073
CCW
ZSO
0165B
APPR
ZSO
0164B
CCW
CHECKED
CORRECT
CCW
ZSC
0165B
DATE
ZSC
0164B
H
REVISION DESCRIPTION
CCW
CCW
TI
0157
TW
I
0157
APPR
CHECKED
CORRECT
DATE
J
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
0907 PID-09-09C
CCW RETURN FROM
BOILER FEED PUMPS
0912 PID-09-09A
CCW RETURN TO
POWERHOUSE
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A
2. CCW SUPPLY TO BFP TYPICAL FOR BOTH SETS OF
BOILER FEED PUMPS.
M
COMPONENT COOLING WATER SYSTEM
SHEET 4 OF 4
131134-PID-09-09D-D
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
FROM AIR COMPRESSOR/
DRYER SKID
REVISION DESCRIPTION
INSTRUMENT
AIR SUPPLY FOR
FIRE WATER PUMPHOUSE
B
APPR
CHECKED
CORRECT
DATE
IAS
INSTRUMENT
AIR SUPPLY TO
DEMIN. AREA
PT
0105-1
ELECTRONICS ROOM
IAS
IAS-V001
PT
0105-2
IAS
IAS-V013
REVISION DESCRIPTION
C
IAS-V003
PT
0105-3
IAS-V001
IAS
APPR
D
PI
0106
CHECKED
CORRECT
IAS-V002
DATE
REVISION DESCRIPTION
E
IAS-V011
IAS-V006
APPR
CHECKED
CORRECT
DATE
F
IAS-V004
IAS-V005
IAS-V010
REVISION DESCRIPTION
G
MACHINE SHOP
MACHINE SHOP
APPR
CHECKED
CORRECT
DATE
H
LOOP AT HRSG DRUM LEVEL
LOOP AT HRSG GROUND LEVEL
LOOP AT STG
REVISION DESCRIPTION
I
IAS-V012
APPR
CHECKED
CORRECT
DATE
J
IAS-V009
IAS-V007
IAS-V008
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
1202 LATER
TO CEMS SHELTER
1203 PID-39-02A
TO CTG
1204 PID-39-02A
TO CTG AIR INLET
FOGGER
1201 REF. 2
TO HIGH PRESSURE STEAM
BYPASS VALVE VOLUME TANK
1205 REF. 3
TO HOT REHEAT STEAM
BYPASS VALVE VOLUME TANK
1206 REF. 4
TO LOW PRESSURE STEAM
BYPASS VALVE VOLUME TANK
1207 PID-08-07B
TO FUEL GAS COMPRESSOR
SKIDS
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04.
INSTRUMENT AIR
SYSTEM
131134-PID-12-01A-E
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
FROM AIR COMPRESSORS
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
SAS
PSV
+
0101
REVISION DESCRIPTION
C
SAS-V010
SAS-V008
SAS
PT
0102
SAS-V011
SAS-V009
D
SAS-V018
SAS
PI
0103
SAS-V001 SAS-V002
3/4 " 3/4 "
APPR
D
CHECKED
CORRECT
DATE
REVISION DESCRIPTION
E
SAS-V012
SAS-V007
SAS-V021
APPR
CHECKED
CORRECT
F
SAS-V020
SAS-V003 SAS-V004
DATE
REVISION DESCRIPTION
G
APPR
CHECKED
CORRECT
DATE
D
H
SAS-V019
SAS-V014
SAS-V013
SAS-V005
REVISION DESCRIPTION
SAS-V015
I
SAS-V006
SAS-V022
APPR
SAS-V018
D
SAS-V016
CHECKED
CORRECT
DATE
J
SAS-V017
REVISION DESCRIPTION
D
K L
APPR
CHECKED
CORRECT
DATE
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
SERVICE AIR
SYSTEM
131134-PID-12-02A-E
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
REVISION DESCRIPTION
ANTISCALANT FEED
ALTERNATIVE
DEMIN SUPPLY
PERMEATE FROM
SECOND PASS RO
CHEMICAL TOTE
FILLING
B
CITY WATER
APPR
CHECKED
CORRECT
DATE
TO POTABLE
WATER SYSTEM
REVISION DESCRIPTION
C
APPR
D
CHECKED
CORRECT
DATE
RO PRETREATMENT
(ULTRA FILTRATION)
(BY VENDOR)
RO FEED PUMP
ELECTRO-DEIONIZATION SKID
D
(EDI)
REVISION DESCRIPTION
E
(BY VENDOR)
LT
PI PT
RO ANTISCALANT
SOLUTION TANK
APPR
LT
CHECKED
CORRECT
DATE
F
FIRST PASS
RO PRESSURE
VESSEL
REVISION DESCRIPTION
G
RO FEED PUMP
CONTAINMENT AREA
APPR
CHECKED
CORRECT
DATE
H
PI PT
REVISION DESCRIPTION
I
SECOND PASS
RO PRESSURE
VESSEL
APPR
CHECKED
CORRECT
DATE
J
(BY VENDOR)
(BY WATER TREATMENT VENDOR)
REVISION DESCRIPTION
PI
K L
APPR
CHECKED
CORRECT
DATE
RO PERMEATE
TO EDI SKID
NOTES:
RO CONCENTRATE
TO WASTE
CYCLE MAKE-UP /
DEMIN STORAGE TANK
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
FIRST PASS RO FEEDWATER
M
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04.
DEMINERALIZED WATER SYSTEM
SHEET 1 of 2
131134-PID-09-21A-C
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
EXISTING
REVISION DESCRIPTION
CONDENSATE OVERFLOW
DEMINERALIZER
B
APPR
CHECKED
CORRECT
DATE
DEMINERALIZED
WATER
STORAGE TANK
REVISION DESCRIPTION
C
PS
LI
LT
APPR
D
CHECKED
CORRECT
DATE
REVISION DESCRIPTION
E
APPR
CHECKED
CORRECT
DATE
F
REVISION DESCRIPTION
G
APPR
CHECKED
CORRECT
DATE
H
DEMINERALIZED WATER
PUMP 2A
DEMINERALIZED WATER
PUMP 2B
DEMINERALIZED WATER
PUMP 2C
REVISION DESCRIPTION
PI
PI
PI
I
APPR
CHECKED
CORRECT
DATE
J
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
NOTES:
CYCLE MAKE-UP
TO CONDENSER
DEMINERALIZER
CROSS TIE TO UNIT 1
VACUUM PUMP 2A
VACUUM PUMP 2B
SAMPLE PANEL
CYCLE CHEMICAL
FEED SYSTEM
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
MAKE-UP TO CLOSED CYCLE
COOLING WATER SYSTEM
VACUUM BREAKER VALVE/
COND EJ WATER SEAL
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04.
STATOR WINDING
H COOLING UNIT
2
CONDENSATE PUMP 2A
CONDENSATE PUMP 2B
ST OIL PURIFIER
CONDENSER FILL
M
DEMINERALIZED WATER SYSTEM
SHEET 2 of 2
131134-PID-09-21B-C
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
1330 PID-13-24A
FROM SANITARY LIFT
STATION
1106 PID-11-02B
FROM HRSG SUMP PUMPS
2303 PID-23-21A
FROM PLANT FLOOR DRAINS
2304 PID-23-21A
FROM PLANT FLOOR DRAINS
2305 PID-23-21A
FROM LUBE OIL COOLER
CURBED AREA
2306 PID-23-21A
FROM CTG ACCESSORY MODULE
CURBED AREA
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
WWT
WWT
LAH
0100
LSH
0100
REVISION DESCRIPTION
C
OIL/WATER SEPARATOR
CONTAINMENT VAULT
APPR
D
CHECKED
CORRECT
DATE
WWT
WWT
LSHH
0101
LSH
0101
WWT-V011
OIL/WATER SEPARATOR
REVISION DESCRIPTION
E
APPR
CHECKED
CORRECT
DATE
F
WWT-P002A
WASTEWATER LIFT PUMP
200 GPM
REVISION DESCRIPTION
G
WWT-V002A
WWT-V001A
OIL/WATER SEPARATOR
CLEARWELL VAULT
TSW-V004
WWT
PI
0103
WWT-V001B
WWT-P002B
WASTEWATER LIFT PUMP
APPR
CHECKED
CORRECT
200 GPM
DATE
H
WWT-V004
WWT-V002B
WWT-V012
WWT
WWT
WWT
WWT-V009
LSHH
0102
LSH
0102
LSL
0102
REVISION DESCRIPTION
WWT
I
FE
+
0104
APPR
WWT
CHECKED
CORRECT
AIT
0105-1
DATE
WWT
AIT
0105-2
pH pH
WWT-V005 WWT-V006
J
CO
WWT-V010
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
TO CITY WATER
NOTES:
TO EXISTING NORTHPORT
WASTE WATER TREATMENT FACILITY
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
WASTE WATER TREATMENT
SYSTEM
131134-PID-13-19A-B
NORTHPORT OPTION 4
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
131134-PID-39-02A-A
N
8
VAPOR
BALANCE
CONNECTION
FLOOR
A
PID-08-08D
FUEL GAS SUPPLY
1203 PID-12-01A
INSTRUMENT AIR
SUPPLY
CO2
SKID
REF. 7
N
7
FILL
CONNECTION
REVISION DESCRIPTION
N
5
N
6
N
3
N
4
N
1
N
2
IE
57A
PM
3-1
IE 57A
ALT
IE 57A
ALT
PM
3-2
IE
57B
PUMP OUT
CONNECTION
GTA-V004
1"
WW
24
GTA-TK001
FP
26
WASH WATER DRAIN TANK
4,000 GALLONS
151X1
GTA-V005
B
APPR
EXHAUST
FP
25
4"-GTA-048-NONE-P
GTA-V003
PM
11
IE
60
CHECKED
CORRECT
DATE
IE
62
PM
10
WW
16
EXHAUST
DUCT
PRESSURE
SWITCH
CCW
RETURN
PID-09-09C
CW
53
CW
52
PACKAGE
IE
PM
09
REF 12
63
GE
GTA-V006
GTA
LG
0000
GTA-V007
TO VENT
GTA
CCW
SUPPLY
PID-09-09C
LOCAL
WW
15
PM
08
ALARM PANEL
GTA
LS
0000
REVISION DESCRIPTION
C
CA
52
PERFORMANCE
GTA-V008
MONITORING
LT
0103
PACKAGE
WW
10
REF 12
CONDENSATE
FLOOR
DRAIN
PM
06
UNDERGROUND
APPR
D
CHECKED
CORRECT
WW
30
DATE
ROOF
WW
110
PM
05
PM
04
CCW
SUPPLY
PID-09-09C
CCW
RETURN
PID-09-09C
CA
52
ROOF
ROOF
COMBUSTION TURBINE
CA
51
UNDERGROUND
REVISION DESCRIPTION
E
GE
GE
TO VENT
TO VENT
LO
13F
CW
7
CW
6
LO
13E
FP
31
FP
32
LO
3B
FG
2
FG
1
LO
13D
FG
3
FG
7
FP
10
FP
11
ACCESSORY
MODULE
LO
13A
LO
1
LO
13B
LO
3A
LO
19
LO
13C
LO
2
WW
33
APPR
CHECKED
CORRECT
DATE
F
GTA-V002
CA
16
CA
20
LOW
POINT
DRAIN
LO
FILL
CA
5
LO COOLER
MAINTENANCE
LO
DRAIN
DRAIN
ROOF
REF 12
VM-15-1
10"
CA
53
CA
53
INLET AIR HEATING
ISOLATION VALVE
REVISION DESCRIPTION
G
PT
PM
2
PM
1
REF 12
IE
4
96BH-1 96BH-2
REF 12
VA20-1
- 96AC-40 AMBIENT AIR SENSOR
INLET AIR HEATING
CONTROL VALVE
GTA-V001
AP4
IE
97
IE
92C
WW
13
AIR PROCESSING UNIT
AP1
APPR
- 96TD-2 DEWPOINT SENSOR -REF. 12
PT
CHECKED
CORRECT
IE
97
REF 12
DATE
H
AP3
IE
92D
AP2
WW
12
WTD-V022
IE
20
INLET
REF. 8
WW
1
96AC - 40A,B,C,D
REF. 12
IE
92A
WW
112
IE
92B
TO SPRITS DUCT
DRAIN SKID A217
REVISION DESCRIPTION
WASH WATER
DETERGENT FLUSH
TO DRAIN TANK
UNDERGROUND
WW
111
IE
2
I
IE
94-1
- 96TD-1 DEWPOINT MONITOR -REF. 12
TO SPRITS DUCT
DRAIN SKID A-217
LOAD
COMPARTMENT
APPR
CHECKED
CORRECT
DATE
CW
12
8"
CCW
SUPPLY
PID-09-09C
IE
91B
IE
91A
IE
91D
IE
91C
IE
93
IE
93A
J
CW
13
8"
CCW
RETURN
PID-09-09C
FOGGER
SKID
SEAL OIL
LOOP SEAL
IE
110
IE
90
LE11
(OBD-2)
CW12
(AH)
ROOF
CW13
(AH)
LE4
(GAV)
GENERATOR
COMPARTMENT
REVISION DESCRIPTION
2"
ROOF
BEARING DRAIN
ENLARGEMENT VENT
GAS
SCAVENGE
LE5
(GAV)
WW20
UNDERGROUND
K L
UNDERGROUND
LE
3
CO2
FEED
LE12
(WRD)
LE
2
H2
FEED
(SEE PID-14-09A)
DETERGENT INLET
WW21
WATER WASH SKID
REF. 10
WW29
WW19
WW23 WW22
APPR
CHECKED
CORRECT
PID-12-01A
INSTRUMENT AIR
DATE
1204
PID-09-21A
0930
FROM DEMINERALIZED
WATER SYSTEM
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
2. TYPICAL FOR EACH CTG.
M
CTG AUXILIARIES & SERVICES
SYSTEM
131134-PID-39-02A-A
NORTHPORT OPTION 4 PCT
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10

1
2
3
4
5
6
7
8
9
10
A
FROM HRSG 1A
SUPERHEATER OUTLET
0608 PID-06-01B
DESUPERHEATING SPRAY
FROM HP FEEDWATER SYSTEM 1A
FROM HRSG 1B
SUPERHEATER OUTLET
0608 PID-06-01B
DESUPERHEATING SPRAY
FROM HP FEEDWATER SYSTEM 1B
0608 PID-06-01B
DESUPERHEATING SPRAY
FROM HP FEEDWATER SYSTEM 1C
REVISION DESCRIPTION
FROM HRSG 1C
SUPERHEATER OUTLET
B
APPR
CHECKED
CORRECT
DATE
FWS-V040
FWS-V040
FWS-V040
FWS-STR002
FWS-STR002
FWS-STR002
REVISION DESCRIPTION
C
FWS
FWS
FWS
FWS
FE
+ +
+
0102
FWS
FE
FT
0102
FWS-V042
FWS-V041
FWS-V044
FWS-V043
FWS
FWS
TE
0103
TW
0103
FWS
+ +
+
0102
FWS
FE
+ +
+
0102
FT
0102
FWS-V042
FWS-V041
FT
0102
FWS-V042
FWS-V041
APPR
D
FWS-V044
FWS-V043
FWS-V044
FWS-V043
CHECKED
CORRECT
DATE
FWS
FWS
FWS
FWS
TE
0103
TW
0103
TE
0103
TW
0103
FWS
FWS
HV
0101
HV
0101
HV
0101
FC
FC
FWS
FWS
FWS
REVISION DESCRIPTION
FC
E
ZSC
0101
ZSC
0101
ZSC
0101
FWS
FWS
FWS
FWS
FWS
FWS
ZSO
0101
TV
0102
ZSO
0101
TV
0102
ZSO
0101
TV
0102
=Hh=
FC
][
=Hh=
FC
=Hh=
FC
APPR
][
][
CHECKED
CORRECT
DATE
F
MSS
MSS
MSS
PT
0100-1
PT
0100-1
PT
0100-1
MSS
MSS-V003A
MSS-V002A
FWS-V048
MSS
MSS-V003A
MSS-V002A
FWS-V048
MSS
MSS-V003A
MSS-V002A
FWS-V048
PT
0100-2
PT
0100-2
PT
0100-2
MSS-V003B
MSS-V002B
MSS
MSS-V003B
MSS-V002B
MSS
MSS-V003B
MSS-V002B
MSS
REVISION DESCRIPTION
G
FE
+
0101
FE
+
0101
FE
+
0101
MSS
FT
0101-1
MSS-V005A
MSS-V004A
MSS
MSS
MSS-V004B
MSS-V005B
FT
0101-2
FT
0101-1
MSS-V005A
MSS-V004A
MSS
MSS
MSS-V004B
MSS-V005B
FT
0101-2
MSS-V005A
MSS-V004A
MSS
FT
0101-1
MSS-V004B
MSS-V005B
FT
0101-2
APPR
CHECKED
MSS-V007A
MSS-V006A
MSS-V006B
MSS-V007B
MSS
CRS
CRS
CRS
CRS
PV
+
0100
TE
0100-1
TW
0100-1
TE
0100-2
TW
0100-2
MSS-V007A
MSS-V006A
MSS-V006B
MSS-V007B
MSS
CRS
CRS
CRS
MSS
CRS
CRS
CRS
CORRECT
CRS
MSS-V007A
MSS-V006A
MSS-V006B
MSS-V007B
CRS
DATE
PV
+
0100
TE
0100-1
TW
0100-1
TE
0100-2
TW
0100-2
PV
+
0100
TE
0100-1
TW
0100-1
TE
0100-2
TW
0100-2
H
MSS
MSS
MAIN STEAM
TURBINE
BYPASS VALVE
MSS
MSS
MSS
MSS
FC
MAIN STEAM
TURBINE
BYPASS VALVE
MAIN STEAM
TURBINE
BYPASS VALVE
TE
0102-1
TW
0102-1
TE
0102-1
TW
0102-1
FC
FC
TE
0102-1
TW
0102-1
MSS
MSS
MSS
MSS
MSS
MSS
TE
0102-2
TW
0102-2
TE
0102-2
TW
0102-2
TE
0102-2
TW
0102-2
REVISION DESCRIPTION
I
APPR
CHECKED
CORRECT
CRS
DATE
PI
0101
CRS
CRS-V015
J
PI
0101
CRS
CRS
CRS-V015
TI
0110
TW
0110
CRS
CRS
TI
0110
TW
0110
REVISION DESCRIPTION
CRS
PI
0101
CRS-V015
K L
CRS
CRS
0304 PID-03-02A
APPR
TI
0110
TW
0110
CHECKED
CORRECT
DATE
TO COLD REHEAT
SYSTEM
0304 PID-03-02A
0301
PID-03-01B
0309 PID-03-05A
0304 PID-03-02A
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
TO COLD REHEAT
SYSTEM
TO HP STEAM
TURBINE
TO AUX. STEAM
SYSTEM
TO COLD REHEAT
SYSTEM
M
MAIN STEAM SYSTEM
SHEET 1 OF 2
131134-PID-03-01A-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
0301 PID-03-01A
FROM
HP STEAM
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
D
MSS
MSS
MSS
MSS
MSS-V020
MSS-V021
TE
0126
TW
0126
TE
0104
TW
0104
MSS
PP
0127
REVISION DESCRIPTION
C
MSS-V024
MSS-V023
LO
MSS-V022
MSS
MSS
PT
0103
TV
+
0126
MSS-V009
MSS-V008
FO
APPR
D
LBA
10/15
MSS
TW
0108
EMERGENCY STOP VALVE
TMB
CONTROL VALVE
STEAM TURBINE PACKAGE
CHECKED
CORRECT
DATE
MSS
ZSC
0126
MSS
LBA
10/O5
ESV
+
0101
TMB
ZSO
0126
CV
+
0101
REVISION DESCRIPTION
E
MAA
10/95
HP
SDS
MAA
10/90
TE
0103
APPR
CHECKED
CORRECT
DATE
F
MSS-T001
HIGH PRESSURE
STEAM TURBINE
LBA
10/10
MAA
10/85
REVISION DESCRIPTION
G
BEFORE SEAT DRAIN
CASING DRAIN
CASING DRAIN
CASING DRAIN
APPR
CHECKED
CORRECT
DATE
H
LO
SDS-V001
LO
SDS-V012
LO
SDS-V014
LO
SDS-V015
SDS
SDS
SDS
SDS
REVISION DESCRIPTION
ZSO
0129
ZSO
0142
ZSO
0140
ZSO
0138
I
SDS
SDS
SDS
SDS
ZSC
0129
ZSC
0142
ZSC
0140
ZSC
0138
SDS
SDS
SDS
SDS
APPR
FV
+
0129
MAL
10/65
FV
+
0142
MAL
10/45
FV
+
0140
MAL
10/15
FV
+
0138
CHECKED
CORRECT
DATE
FO
FO
FO
FO
MAL
10/70
NOTE 6
ALSTOM
MAL
10/50
MAL
10/20
J
SDS
SDS
SDS
MAL
10/75
RO
+
0142
MAL
10/55
RO
+
0140
MAL
10/25
RO
+
0138
RO
RO
RO
MAL
10/80
MAL
10/60
MAL
10/30
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
0306 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0303 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0307 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0308 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0305 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A
2. STRAINER INTEGRAL TO ESV
M
MAIN STEAM SYSTEM
SHEET 2 OF 2
131134-PID-03-01B-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
0304 PID-03-01A
FROM HP STEAM BYPASS
1A & 1B
FROM IP STEAMHEATER OUTLET
1A &1B
HP
MAA
10/30
CRS
CRS
CRS
CRS
CRS
CRS
CRS
CRS
STEAM TURBINE PACKAGE
REVISION DESCRIPTION
TE
0102-1
TW
0102-1
TE
0138-3
TW
0138-3
TE
0138-2
TW
0138-2
TE
0138-1
TW
0138-1
CRS
CRS-V018
CRS
CRS-V017
CRS
CRS-V016
CRS
CRS
PS
0137-3
PS
0137-2
PS
0137-1
TE
0102-2
TW
0102-2
B
APPR
CRS
CHECKED
CORRECT
TW
0103
CRS
CRS
DATE
CRS
PV
+
0139A
PV
+
0139B
PP
0100
CRS
CRS
CRS
PT
0104
CRS
CRS-V001 CRS-V002
3"
FO
FO
LSH
0129-1
LE
0129-1
CRS
CRS
ZSC
0139A
ZSC
0139B
V
D
PI
0105
CRS-V003 CRS-V004
CRS-V006
CRS
CRS
ZSO
0139A
ZSO
0139B
REVISION DESCRIPTION
C
D
CRS-V007
CRS
CRS-V005
RO
+
0139
PT PT
RO
APPR
D
LPS-VXXXX LPS-VXXXX LPS-VXXXX
V
D
CHECKED
CORRECT
CRS
CRS
CRS
DATE
NRV
+ +
0106A
TURBINE WARM-UP LINE
LSHH
0129-2
LE
0129-2
LO
CRS-V008
CRS
LV
+
0129
FT
LPS-VXXXX LPS-VXXXX
FT
CRS
FO
ZSC
0106A
LPS-VXXXX
CRS
CRS
CRS
REVISION DESCRIPTION
E
ZSO
0106A
TV
+
0136
ZSC
0129
CRS
CRS
TE
TW
ZSO
0129
ZSC
0136
APPR
CRS
SDS
CRS
CHECKED
CORRECT
NRV
0106B
TE
TE
TW
0111
DATE
F
ZSO
0136
0829
0830
CRS
CRS
CRS
LSH
0131-1
LE
0131-1
ZSC
0106B
PID-03-02B
PID-03-02C
CRS
V
D
ZSO
0106B
CRS-V009
CRS-V012
REVISION DESCRIPTION
G
D
CRS
DESH
001
CRS-V013
CRS
DESUPERHEATER
CRS-V010
CRS-V011
APPR
CHECKED
CORRECT
V
D
DATE
CRS
CRS
H
10 DIA. MIN.
CRS
CRS
LSHH
0131-2
LE
0131-2
LO
CRS-V014
LSH
0143-1
LE
0143-1
CRS
CRS
CRS
LV
+
0131
TE
0000
TW
0000
V
D
FO
CRS
D
ZSC
0131
CRS
CNM
CRS-V019 CRS-V020
CRS-V021
REVISION DESCRIPTION
I
CNM-V026
CRS-V023
CRS-V022
CNM-V025
ZSO
0131
APPR
TV
+
0000
V
D
SDS
CHECKED
CORRECT
CRS
CRS
FC
CNM-V027
LO
CRS-V024
DATE
TE
0141
LSHH
0143-2
LE
0143-2
CRS
CNM-V024
LV
+
0143
J
CNM
FO
HV
+
0000
FC
CRS
D
ZSC
0143
CNM-STR009
CNM-V023
REVISION DESCRIPTION
CRS
ZSO
0143
K L
SDS
TE
0153
APPR
PID-04-01B
0324 PID-11-01A
CONDENSATE SUPPLY
0323A
1A
TO DESUPERHEATER
0328 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0326 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
PRESSURE RELEASE TO STEAM
CHECKED
CORRECT
DRAIN COLLECTION SYSTEM
DATE
PID-03-05A
TO AUX. STEAM
SYSTEM
0322 PID-11-02A
TO HRSG BLOWOFF
TANK
0409
TO REHEATER INLET A
1A
TO REHEATER INLET B
1A
TO REHEATER INLET C
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
COLD REHEAT
SYSTEM
131134-PID-03-02A-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
HRSG REHEAT OUTLET 1A
0425 PID-04-01B
DESUPERHEATING SPRAY
FROM CONDENSATE SYSTEM
HRSG REHEAT OUTLET 1B
0425 PID-04-01B
DESUPERHEATING SPRAY
FROM CONDENSATE SYSTEM
HRSG REHEAT OUTLET 1C
0425 PID-04-01B
DESUPERHEATING SPRAY
FROM CONDENSATE SYSTEM
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
CNM-V060A
CNM-V060A
CNM-V060A
CNM-STR003
CNM-STR003
CNM-STR003
REVISION DESCRIPTION
C
CNM
CNM
CNM
CNM
FE
+
0103
CNM
FE
+
0103
CNM
FE
+
0103
FT
0103
CNM-V061A CNM-V062A
FT
0103
CNM-V061A CNM-V062A
FT
0103
CNM-V061A CNM-V062A
APPR
D
CHECKED
CORRECT
DATE
CNM
CNM
CNM
CNM
CNM
CNM
TE
0104
TW
0104
TE
0104
TW
0104
TE
0104
TW
0104
CNM
CNM
CNM
HV
+
0306
HV
+
0306
HV
+
0306
REVISION DESCRIPTION
E
FC
FC
FC
CNM
CNM
CNM
ZSC
0306
ZSC
0306
ZSC
0306
CNM
CNM
CNM
CNM
CNM
CNM
ZSO
0306
ZSO
0306
ZSO
0306
APPR
TV
+
0104
TV
+
0104
TV
+
0104
CHECKED
CORRECT
DATE
FC
FC
FC
F
HRS
PT
0100-1
CNM-V064A
HRS
PT
0100-1
CNM-V064A
HRS
PT
0100-1
CNM-V064A
HRS
HRS-V003A
HRS
HRS-V003A
HRS
HRS-V003A
REVISION DESCRIPTION
G
PT
0100-2
HRS
PT
0100-2
HRS
PT
0100-2
HRS
HRS-V003B
FE
+
0105
HRS-V003B
FE
+
0105
HRS-V003B
FE
+
0105
HRS
HRS
HRS
FT
0105-1
HRS-V004A
HRS-V004B
HRS
HRS
FT
0105-2
FT
0105-1
HRS-V004A
HRS-V004B
FT
0105-2
FT
0105-1
HRS-V004A
HRS-V004B
HRS
FT
0105-2
APPR
HRS
HRS
HRS
HRS
HRS
HRS
HRS
HRS
HRS
HRS
HRS
HRS
HRS
HRS
HRS
CHECKED
CORRECT
HRS-V005B
HRS-V005B
PV
+
0100
TE
0106-1
TW
0106-1
TE
0106-2
TW
0106-2
PV
+
0100
HOT REHEAT
BYPASS VALVE
FC
HRS-V005B
HRS-V005B
TE
0106-1
TW
0106-1
TE
0106-2
TW
0106-2
HOT REHEAT
BYPASS VALVE
FC
HRS-V005B
HRS-V005B
PV
+
0100
TE
0106-1
TW
0106-1
TE
0106-2
TW
0106-2
DATE
HOT REHEAT
BYPASS VALVE
FC
H
HRS
HRS
HRS
HRS
HRS
HRS
TE
0109-1
TW
0109-1
TE
VENDOR
VENDOR
0109-1
TW
0109-1
TE
VENDOR
0109-1
TW
0109-1
HRS
HRS
HRS
HRS
VENDOR
VENDOR
VENDOR
HRS
HRS
HRS
HRS
HRS
TE
0109-2
TW
0109-2
TE
0109-2
TW
0109-2
TE
0109-2
TW
0109-2
PI
0120
LSH
0123-1
LE
0123-1
REVISION DESCRIPTION
I
HRS-V006
HRS
HRS
TI
0121
TW
0121
HRS
HRS
HRS
HRS
HRS-V015 HRS-V016
HRS-V017
APPR
CHECKED
CORRECT
DATE
D
HRS-V019
J
HRS-V018
PI
0120
LSH
0123-1
LE
PI
0120
0123-1
HRS-V006
HRS
HRS
HRS-V006
LSH
HRS
HRS
0123-1
LE
0123-1
HRS
HRS
HRS
HRS
HRS
TI
0121
TW
TI
0121
TW
0121
0121
LAHH
0123-2
LSHH
0123-2
LE
0123-2
REVISION DESCRIPTION
HRS-V015 HRS-V016
HRS-V017
HRS
HRS-V015 HRS-V016
HRS-V017
XA
0123-2
K L
HRS-V019
D
HRS-V018
HRS-V019
HRS-V018
0343 PID-03-12A
0341 PID-03-03B
TO HOT REHEAT STEAM
HRS
HRS
HRS
TO STEAM DUCT SPARGER
APPR
CHECKED
CORRECT
DATE
SHEET 2
LAHH
0123-2
LSHH
0123-2
LE
0123-2
HRS
HRS
HRS
0342 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
HRS
LAHH
0123-2
LSHH
0123-2
LE
0123-2
XA
0123-2
HRS
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
0342 PID-11-01B
TO STEAM DUCT SPRAGER
XA
0123-2
0342 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
0343 PID-03-12A
TO STEAM DUCT SPARGER
M
0342 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
HOT REHEAT STEAM SYSTEM
SHEET 1 OF 2
131134-PID-03-03A-C
NORTHPORT OPTION 9 PCT
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10

1
2
3
4
5
6
7
8
9
10
A
0341 PID-03-03A
HOT REHEAT STEAM
SHEET 1
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
D
HRS
HRS
HRS
HRS-V010
TE
0110
TW
0110
PT
0103
REVISION DESCRIPTION
C
HRS
PP
0115
HRS-V012 HRS-V013
LO
HRS-V011
HRS
HRS
TW
0107
TV
+
0110
APPR
D
CHECKED
CORRECT
HRS
HRS
FO
DATE
TE
0104
TW
0104
STEAM TURBINE
HRS
PACKAGE
ZSC
0110
HRS
ZSO
0110
REVISION DESCRIPTION
E
SDS
TE
0115
APPR
EMERGENCY STOP VALVE
CHECKED
CORRECT
HRS
EMERGENCY STOP VALVE
DATE
F
TMI
+
CONTROL VALVE
HRS
+
CONTROL VALVE
TMI
HRS
HRS
PP
0106A
PP
0106B
ESV
0103A
CV
0104A
CV
+
0104B
ESV
+
0103B
IP
REVISION DESCRIPTION
G
LP
CASING DRAIN
BEFORE SEAT DRAIN
APPR
CHECKED
CORRECT
DATE
H
REVISION DESCRIPTION
I
LO
SDS-V010
LO
SDS
FV
+
0146
SDS-V011 FO
SDS
FV
LO
SDS-V002
LO
SDS
SDS
SDS-V005
ZSC
0146
ZSC
0144
SDS
SDS
APPR
SDS
SDS
ZSC
0126
ZSC
0154
CHECKED
CORRECT
DATE
ZSO
0146
ZSO
0144
SDS
SDS
SDS
SDS
ZSO
0126
ZSO
0154
+
0144
FV
+
0126
FV
+
0154
J
FO
FO
FO
SDS
SDS
RO
+
0146
RO
+
0144
REVISION DESCRIPTION
RO
RO
K L
APPR
CHECKED
CORRECT
DATE
0344 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0346 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0347 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0348 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
0345 PID-11-01A
TO STEAM DRAIN
NOTES:
COLLECTION SYSTEM
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A
2. STRAINER INTEGRAL TO ESV.
M
HOT REHEAT STEAM SYSTEM
SHEET 2 OF 2
131134-PID-03-03B-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
REVISION DESCRIPTION
HRSG LP
SUPERHEATER OUTLET 1A
HRSG LP
SUPERHEATER OUTLET 1B
HRSG LP
REF. 1
SUPERHEATER OUTLET 1C
0424 PID-04-01B
DESUPERHEATER SUPPLY
FROM CONDENSATE SYSTEM
B
APPR
CHECKED
CORRECT
DATE
CNM-V060B
CNM-STR004
REVISION DESCRIPTION
C
CNM
FT
0101
CNM-V061B CNM-V062B
CNM
APPR
D
FE
+ +
0101
CHECKED
CORRECT
DATE
CNM
CNM
TE
0102
TW
0102
CNM
REVISION DESCRIPTION
E
HV
0305
FC
LPS
LPS
LPS
CNM
PT
0100-1
PT
0100-1
PT
0100-1
ZSC
0305
APPR
LPS
CNM
PT
0100-2
LPS-V001A LPS-V001B LPS-V002A
LPS
CNM
LPS
PT
0100-2
TV
+
0102
FE
+
0103
FC
LPS
LPS
FT
0103-1
LPS-V002B LPS-V003B
FT
0103-2
LPS-V001A LPS-V001B LPS-V002A
LPS
PT
LPS
0100-2
ZSO
0305
FE
+
0103
LPS
LPS
FT
0103-1
LPS-V003A
LPS-V002B LPS-V003B
FT
0103-2
LPS-V001A LPS-V001B LPS-V002A
CHECKED
CORRECT
DATE
F
LPS
FE
+
0103
LPS
LPS
FT
0103-1
LPS-V003A
LPS-V002B LPS-V003B
FT
0103-2
LPS-V003A
REVISION DESCRIPTION
G
LPS
LPS
LPS
LPS
LPS
LPS
CNM-V064B
TE
0111-1
TW
0111-1
TE
0111-1
TW
0111-1
TE
0111-1
TW
0111-1
APPR
LPS
LPS
LPS
LPS
LPS
LPS
CHECKED
CORRECT
DATE
TE
0111-2
TW
0111-2
TE
0111-2
TW
0111-2
TE
0111-2
TW
0111-2
H
LPS
LPS
LPS
LPS
LPS
PV
+
0100
TE
0109-1
TW
0109-1
TE
0109-2
TW
0109-2
REVISION DESCRIPTION
FC
I
LPS
PI
0107
LPS
LPS
LPS
APPR
LPS-V012
CHECKED
CORRECT
LSH
0118-1
LSH
0118-1
LE
0118-1
DATE
LPS
LPS
I&C
TI
0108
TW
0108
J
LPS-V010 LPS-V011
LPS-V013
D
LPS-V015
REVISION DESCRIPTION
LPS-V014
K L
I&C
LPS
LPS
APPR
LSHH
0118-2
LE
0118-2
CHECKED
CORRECT
DATE
0368 PID-03-04B
TO LP STEAM TURBINE
0361
NOTES:
PID-03-12A
TO STEAM DUCT
SPARGER
0360 PID-11-01B
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
TO STEAM DRAIN
COLLECTION SYSTEM
M
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
LOW PRESSURE STEAM SYSTEM
SHEET 1 OF 2
131134-PID-03-04A-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
0368 PID-03-04A
LOW PRESSURE STEAM
SUPPLY A
0368 PID-03-04A
LOW PRESSURE STEAM
SUPPLY B
0368 PID-03-04A
LOW PRESSURE STEAM
SUPPLY C
REVISION DESCRIPTION
LPS
B
LE
0114-1
APPR
CHECKED
CORRECT
V
D
DATE
I&C
LPS-V021
LPS-V024
D
LPS-V025
LPS-V022
LPS-V023
I&C
REVISION DESCRIPTION
C
V
D
LPS
LE
0114-2
APPR
D
LPS
CHECKED
CORRECT
DATE
PT
0106
LPS
LPS
PP
0100
LV
+
0114
LPS
LPS
LPS-V027 LPS-V028
LO
LPS-V026
FO
TE
0104
TW
0104
LPS
LPS
REVISION DESCRIPTION
E
TW
0105
ZSC
0114
LPS
ZSO
0114
APPR
CHECKED
CORRECT
EMERGENCY STOP VALVE
CONTROL VALVE
DATE
F
SDS
TE
0118
TMB
TMB
IP
ESV
+
0105
CV
+
0106
10"
LP
REVISION DESCRIPTION
G
APPR
CHECKED
CORRECT
DATE
H
REVISION DESCRIPTION
I
LO
SDS
SDS-V003
LO
SDS
SDS-V004
APPR
CHECKED
CORRECT
ZSC
0125
ZSC
0120
DATE
SDS
SDS
SDS
SDS
ZSO
0125
ZSO
0120
J
FV
+
0125
FV
+
0120
REVISION DESCRIPTION
FO
FO
K L
APPR
CHECKED
CORRECT
DATE
0364 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
0365 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
0366 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
0362 PID-11-01B
TO STEAM DRAIN
COLLECTION SYSTEM
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
2. STRAINER INTEGRAL TO ESV.
M
LOW PRESSURE STEAM SYSTEM
SHEET 2 OF 2
131134-PID-03-04B-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
REVISION DESCRIPTION
0417 PID-04-01B
0323A
PID-03-02A
FROM COLD REHEAT
SYSTEM
0309 PID-03-01A
B
CONDENSATE PUMP
DISCHARGE
MAIN STEAM SUPPLY
PID-XX-XXX
CONDENSATE PUMP
DISCHARGE
APPR
CHECKED
CORRECT
DATE
MSS
PI
0131
CRS
MSS-V031
MSS-V030
PI
0130
CRS-V030
REVISION DESCRIPTION
C
CNM-STR005
CRS-V037
MSS
APPR
HV
+
0133
D
CHECKED
CORRECT
DATE
FC
ASF
MSS
0101A
PV
+
0101A
FC
CRS-V038
ZSC
0133
MSS
ZSO
0133
MSS-V035
CNM-V070
CRS-V039
D
CNM-V0XX
REVISION DESCRIPTION
E
D
CRS
MSS-V039
MSS-V040
ASF
CNM-V069
ASF
PI
0142
ASF
TV
+
0102
CRS-V042
PV
+
0101B
TV
+
FC
CRS-V040
FC
MSS-V037
FC
APPR
CHECKED
CORRECT
DATE
F
CRS
CNM-V072
CNM-V073
PSV
+
0128
CNM-V0XX
CNM-V0XX
ROOF
MSS-V038
CRS
CNM-V074
CRS-SIL001
PSV
+
0128
CNM-V0XX
REVISION DESCRIPTION
G
ROOF
CRS-SIL002
APPR
CHECKED
CORRECT
DATE
H
ASF
DESH
0001
ASF
DESH
0001
AUX. STEAM
DESUPERHEATER
REVISION DESCRIPTION
I
AUX. STEAM
DESUPERHEATER
10 DIAMETERS
10 DIAMETERS
APPR
CHECKED
CORRECT
DATE
J
ASF
PT
0101
ASF-V001
ASF
ASF
ASF
HV
+
0105
TE
0102
TW
0102
FC
ASF-V003
ASF-V004
REVISION DESCRIPTION
D
ASF
ASF
ASF-V002
ZSC
0105
ZSO
0105
K L
FC
ASF-V008
APPR
CHECKED
CORRECT
ASF
DATE
HV
0105
ASF
T
ZSC
0105
ASF-TRP001
ASF-V009
ASF
ASF-V003
ZSO
0105
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SDS-V007 SDS-V008
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A
0371 PID-05-01A
TO SJAE
0370 PID-16-01A
STG GLAND STEAM
SUPPLY
0372 PID-11-01A
TO STEAM DRAIN
COLLECTION SYSTEM
M
AUXILIARY STEAM
SYSTEM
131134-PID-03-05A-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
REVISION DESCRIPTION
0361 PID-03-04A
FROM LOW PRESSURE STEAM
SYSTEM BYPASS VALVE
0343 PID-03-03A
FROM HOT REHEAT STEAM
SYSTEM BYPASS VALVE
0428 PID-04-01B
CONDENSATE SUPPLY FOR
SEAL WATER
LP
PID-04-01A
TO CONDENSATE
STORAGE TANK
PID-04-01A
PID-04-01A
ACC DRAINS TO
0380
0381
EQUALIZING LINE TO
CONDENSATE STORAGE TANK
0382
CONDENSATE STORAGE TANK
B
APPR
CHECKED
CORRECT
DATE
MSE
PT
0101
MSE
MSE-V001 MSE-V002 MSE-V003 MSE-V004
M
M
PS
0100-1
CNM
CNM
MSE
ZSC
0066A
ZSC
0066B
REVISION DESCRIPTION
C
PS
0100-2
CNM
CNM
CNM
CNM
CNM
CNM
MSE
ZSO
0066A
ZSO
0066B
TE
0176A
TW
0176A
TE
0176B
TW
0176B
PS
0100-3
APPR
D
CHECKED
CORRECT
DATE
CNM
CNM
CNM
CNM
TE
0174B
TW
0174B
TE
0175B
TW
0175B
CNM
CNM
CNM
CNM
TW
0174A
TE
0174A
TW
0175A
TE
0175A
CNM-V086
REVISION DESCRIPTION
E
MSE
ZSO
0110
ZSC
0110
M
M
HV
+
0110
CNM-FN001D
CNM-FN002D
SEAL
WATER
VACUUM BREAKER
CNM-FN001C
M
CNM-FN002C
M M M M
CNM-FN003D
FC
APPR
CHECKED
CORRECT
DATE
F
CNM-FN003C
M
OUTDOORS
REVISION DESCRIPTION
G
DRAIN POT
APPR
CNM-FN001B
M
CNM-FN002B
CNM-FN003B
CHECKED
CORRECT
M
DATE
H
MSE
MSE
PP
0102
LSH
0109
MSE
CNM
CNM
PP
0103
VS
0101A
VS
0101B
MSE
REVISION DESCRIPTION
CNM-FN001A
TYPICAL FOR ALL AIR COOLED CONDENSER FANS
PT
0104-1
MSE
M
CNM-FN002A
CNM-FN003A
M
I
MSE
PT
0111
CNM
PT
0104-2
MSE
PSL
0101
APPR
MSE
PT
0112
CHECKED
CORRECT
PT
0104-3
DATE
MSE
J
PI
0105
MSE
MSE
TI
0106
TW
0106
MSE
MSE
REVISION DESCRIPTION
TE
0107
TW
0107
K L
TP
APPR
CHECKED
CORRECT
DATE
M
M
CNM
CNM
CNM
PSE
+
0210
ZSC
0065A
ZSC
0065B
CNM
CNM
ZSO
0065A
ZSO
0065B
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
PID-03-XXX
TO AIR REMOVED SYSTEM
AIR COOLED CONDENSER /
MAIN TURBINE EXHAUST SYSTEM
131134-PID-03-12A-A
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
0933 PID-09-21A
DEMINERALIZED WATER
MAKE-UP LINE
0380 PID-03-12A
FROM EXHAUST STEAM DUCT
DRAIN POT
0936 PID-09-21A
DEMINERALIZED WATER
MAKE-UP LINE FOR START-UP
1101 PID-11-01A
HIGH PRESSURE STEAM
DRAIN SYSTEM MANIFOLD
1102 PID-11-01A
STG STEAM DRAIN
SYSTEM MANIFOLD
1103 PID-11-01B
LOW PRESSURE DRAIN
SYSTEM MANIFOLD
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
WTD-STR001
WTD-V010
WTD-STR002
WTD-V015
REVISION DESCRIPTION
D
D
C
WTD-V011 WTD-V013
CNM
FC
LV
+
0111-2
WTD-V016
FC
WTD-V018
CNM
LV
CNM
CNM
CNM
TW
0110
WTD-V014
+
0111-3
WTD-V019
TW
0112
TE
0112
APPR
D
CHECKED
CORRECT
CNM
DATE
PI
0105
CNM
CNM
PT
0100
TW
0114
CNM-V001A
CNM-V001B
CNM
PDT
0115A
CNM-V002A
CNM
CNM-STR001A
D
PDT
0115B
CNM-V002B
CNM-STR001B
CNM-V003A
CNM-V003B
REVISION DESCRIPTION
D
E
CNM-TK001
CONDENSATE STORAGE TANK
CNM
CNM-V004A
CNM
CNM-V004B
PSV
+
0116A
PSV
+
0116B
1"
CNM
PSET=50.psig
CNM
PSET=50.psig
APPR
CHECKED
CORRECT
DATE
F
PI
0118A
PI
0118B
CNM-V005A
CNM-V005B
CNM-V013A
CNM-V013B
REVISION DESCRIPTION
G
CNM
CNM-V014A
CNM
TE
0162A
CNM-EJ001A
TE
0162B
CNM-V014B
CNM-EJ001B
M
CNM-P001A
CONDENSATE PUMP
1A
M
CNM-P001B
CONDENSATE PUMP
1B
APPR
CHECKED
CORRECT
CNM
DATE
TE
0163A
TE
0163B
H
CNM
CNM
CNM
CNM
CNM
PI
0170A
PI
0170B
TE
0164A
TE
0164B
LT
0111-1
CNM
CNM
TE
0165A
TE
0165B
CNM
CNM
CNM
CNM
CNM
REVISION DESCRIPTION
LT
0111-2
PCV
+
0171A
PCV
+
0171B
TE
0166A
CNM
TE
0166B
CNM
I
PI
0119A
PI
0119B
CNM
CNM
TE
0264A
CNM-V008A
CNM
CNM-V008B
CNM
TE
0264B
CNM
APPR
LSHH
0120
TW
0109A
TW
0109B
CHECKED
CORRECT
DATE
CNM
CNM-V009A CNM-V010A
D
LG
0113
CNM-STR002A
CNM-V012A
CNM-V011A
CNM-V009B CNM-V010B
D
J
CNM-STR002B
CNM-V012B
CNM-V011B
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
0403 PID-05-01A
SJAE
PID-03-12A
DRAINS FROM AIR
COOLED CONDENSER
PID-03-12A
0382
0381
EQUALIZING LINE FROM
STEAM DUCT
PID-04-01B
MIN. FLOW RECIRC
PID-05-01A
LINE
0406
0501
SJAE INTER CONDENSER
DRAIN
PID-05-01A
0502
SJAE AFTER CONDENSER
0402
DRAIN
PID-04-01B
CONDENSATE PUMP
DISTRIBUTION SYSTEM
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
CONDENSATE SYSTEM
SHEET 1 OF 2
131134-PID-04-01A-D
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
0831 PID-08-07D
FROM FUEL GAS HEATER
1302 PID-13-06B
FROM OXYGEN SCAVENGER
FEED SYSTEM
1301 PID-13-06A
FROM AMINE
FEED SYSTEM
0402 PID-04-01A
CONDENSATE PUMP
DISCHARGE HEADER
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
CNC-V001 CNC-V003
CNC-V002 CNC-V004
CNM
PT
0122
CNM-V030
REVISION DESCRIPTION
C
CNM
CNM
CNM
TE
0123
TW
0123
CNM
CNM
CNM
GLAND
STEAM
CONDENSER
PI
0126
CNM
CNM
CNM
REF. 2
STEAM JET
AIR EJECTOR
CONDENSER
CNM
TW
0128
TW
0127
TE
0127
CNM-V031
TW
0125
TW
0124
TE
0124
TW
0109C
APPR
D
CHECKED
CORRECT
DATE
MKM
CNM
7/2/03
FE
+
0132
REVISION DESCRIPTION
E
CNM
FT
0132
CNM-V032 CNM-V033
APPR
CHECKED
CORRECT
DATE
F
CNM
CNM
TI
0133
TW
0133
CNM
CNM
TE
0135-1
TW
0135-1
CNM
CNM
TE
0135-2
TW
0135-2
REVISION DESCRIPTION
G
CNM-V041
APPR
CHECKED
CORRECT
DATE
CNM
H
PT
0136-1
CNM
CNM-V034A
CNM
CNM
PT
0136-2
CNM-V034B
MKM 10/18/02
MKM
CNM
PT
0136-1
PT
0136-1
FE
+
0139
CNM
CNM-V034A
CNM
CNM-V034A
CNM-V050
CNM
REVISION DESCRIPTION
PT
0136-2
PT
0136-2
FT
0139-1
CNM-V035A CNM-V036A
CNM-V035B
CNM
FT
I
CNM-V034B
0139-2
CNM
CNM-V034B
CNM
FE
CNM-V046
CNM-V022
CNM
FV
+
0132
CNM
FO
CNM-V051
CNM-V037
LV
+
0111-1
FC
CNM-V047
24MAY02
CNM-V053
+ +
0139
FE
CNM
CNM-V035A CNM-V036A
CNM-V035B
CNM
FT
0139-1
FT
0139-2
CNM
CNM-V037
+ +
0139
CNM
APPR
CNM-V035A CNM-V036A
CNM-V035B
CNM
FT
0139-1
FT
0139-2
CHECKED
CORRECT
DATE
J
CNM-V037
LV
+
0137
6"
FC
CNM-V038
CNM-V049
REVISION DESCRIPTION
CNM
CNM
LV
0137
LV
0137
CNM-V040
K L
6"
FC
CNM-V038
6"
FC
CNM-V038
APPR
CHECKED
CORRECT
CNM-V040
CNM-V040
0406 PID-04-01A
MINIMUM FLOW RECIRC TO
CONDENSATE STORAGE TANK
0407
0427 PID-06-01B
TO IP DRUM FILL
0426 PID-06-01B
TO HP DRUM FILL
0405 PID-15-01A
DRAW-OFF TO SERVICE WATER
/ FIRE PROTECTION TANK
0415 PID-11-01A
CONDENSATE SUPPLY TO
STEAM DRAIN SYSTEM
0425 PID-03-03A
HOT REHEAT BYPASS
VALVE SUPPLY
0424 PID-03-04A
LP-BYPASS
VALVE SUPPLY
0417 PID-03-05A
0428 PID-03-12A
TO AUX. STEAM SYSTEM
DESUPERHEATER
TO STEAM TURBINE VACUUM
BREAKER VALVE
HRSG C
LP ECONOMIZER INLET
0414 PID-21-03A
TO SAMPLE PANEL
TO AUX. STEAM DESUPERHEATERS
(MAIN STEAM SYSTEM)
0409 PID-03-02A
TO HRSG 1A & 1B COLD REHEAT DESUPERHEATERS
DATE
0416 PID-11-01A
CONDENSATE SUPPLY TO
STEAM DRAIN SYSTEM
0418 PID-11-01B
CONDENSATE SUPPLY TO
STEAM DRAIN SYSTEM
0429 PID-16-01A
TO GLAND STEAM SKID
EXHAUST HOOD SPRAY
0407
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
LP ECONOMIZER INLET
0427 PID-06-01B
TO IP DRUM FILL
0426 PID-06-01B
0407
HRSG A
TO HP DRUM FILL
HRSG B
LP ECONOMIZER INLET
0427 PID-06-01B
TO IP DRUM FILL
0426 PID-06-01B
TO HP DRUM FILL
M
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
CONDENSATE SYSTEM
SHEET 2 OF 2
131134-PID-04-01B-D
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
REVISION DESCRIPTION
HRSG DEAERATOR HEADER
OUTLET
HRSG DEAERATOR HEADER
OUTLET
B
APPR
CHECKED
CORRECT
DATE
FWS-V001A
REVISION DESCRIPTION
C
FWS
PDS
0110A
FWS-V002A
D
FWS
FWS-V003A
PSV
+
0112A
PSET=150.psig
FWS
PT
0114A
FWS
PI
0115A
FWS-V004A FWS-V005A FWS-V006A
FWS-STR001A
APPR
D
CHECKED
CORRECT
DATE
FWS
VE
0160A
FWS
VE
0161A
FWS
FWS
VE
0162A
FWS-V001B
REVISION DESCRIPTION
E
TW
0116A
FWS
FWS
FWS
FWS
VE
0164A
FWS
PDS
0110B
7/2/03
TE
0117A
TW
0117A
FWS-V002B
D
VE
0165A
FWS
FWS-V003B
FWS
FWS
PI
0118A
PSV
+
0112B
FWS-V013A
FWS
PT
0114B
FWS
PI
0115B
FWS-V004B FWS-V005B FWS-V006B
FWS-STR001B
APPR
HS
0001A
PSET=150.psig
CHECKED
CORRECT
FWS-P001A
BOILER
FEED PUMP 1A
DATE
F
FWS
TE
0168A
FWS
TE
0169A
FWS
TE
0170A
FWS
FWS
VE
TE
0171A
0160B
FWS
VE
0161B
FWS
FWS-V007A FWS-V008A
FWS
VE
0162B
REVISION DESCRIPTION
G
TE
0174A
FWS
FWS
TE
0175A
TW
0116B
FWS
FWS
VE
0164B
TE
0176A
FWS
FWS
FWS
FWS
VE
0165B
TI
0117B
TE
0117B
TW
0117B
APPR
CHECKED
CORRECT
DATE
FWS-V008B
FWS-V007B
10/18/02
H
FWS
FWS-V013B
FWS-P001B
BOILER
FEED PUMP 1B
FWS
TE
0168B
FWS
PI
0118B
TE
0169B
FWS
TE
0170B
FWS
TE
0171B
REVISION DESCRIPTION
FWS
FWS
FWS
I
PI
0125A
PI
0125B
TE
0174B
FWS-V015A
FWS-V014A FWS-V016A
FWS-V015B
FWS
FWS
PT
0155A
PT
0155B
FWS-V017A
FWS-V017B
FWS-V014B FWS-V016B
FWS
TE
0175B
FWS
TE
0176B
APPR
CHECKED
CORRECT
DATE
J
FWS-V0XXA
FWS-V0XXB
REVISION DESCRIPTION
FWS-V009A
FWS-V009B
FWS-V011A
FWS-V011B
K L
FWS-V010A
FWS-V010B
APPR
CHECKED
CORRECT
DATE
LO
FWS-V012A
LO
FWS-V012B
0601 PID-06-01B
IP FEEDWATER
CONTROL VALVE
0609 REF. 1
0602 PID-06-01B
0609
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A
2. TYPICAL FOR EACH OF 3 HRSGS.
HRSG LP DRUM
BFP #1A MIN FLOW RECIRC.
HP FEEDWATER
CONTROL VALVE
HRSG LP DRUM
BFP #1B MIN FLOW RECIRC.
M
FEEDWATER SYSTEM
SHEET 1 OF 2
131134-PID-06-01A-D
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
0427 PID-04-01B
FROM CONDENSATE SYSTEM
FOR IP DRUM 1A - 1C FILL
0601 PID-06-01A
FROM BOILER FEED PUMP
IP DISCHARGE LINES
0426 PID-04-01B
FROM CONDENSATE SYSTEM
FOR HP DRUM FILL
0602 PID-O6-01A
FROM BOILER FEED PUMP
HP DISCHARGE LINES
REVISION DESCRIPTION
B
APPR
FWS-V029
CHECKED
CORRECT
DATE
FWS-V031
FWS-V064
FWS
TW
0123
FWS-V028
FWS-V066
FWS
FWS
FWS
PT
0119
REVISION DESCRIPTION
C
FWS-V022
FWS
FE
FWS-V023A FWS-V024A
TW
0123
TW
0123
FWS
FWS
FWS
TW
0130
PT
0119
PT
0119
+
0120
FWS
FWS-V023B FWS-V024B
FWS
FT
0120-1
FT
0120-2
FWS
FWS
FWS
FE
+
0121
PT
0131
FT
0121
FWS-V063
FWS
FWS
FWS-V053
FWS-V052
TE
0122-1
TW
0122-1
FWS-V022
FWS
FE
FWS-V023A FWS-V024A
+
0120
FWS
FWS
FWS-V023B FWS-V024B
FWS
FWS
FE
+
0121
FT
0120-1
FT
0120-2
FWS-V022
FWS
FE
FWS-V023A FWS-V024A
APPR
D
CHECKED
CORRECT
DATE
+
0120
FWS
FWS-V023B FWS-V024B
FWS
FT
0120-1
FT
0120-2
FWS-V032 FWS-V033
FT
0121
FWS
FWS
FWS
FWS-V032 FWS-V033
FE
+
0132
TE
0122-2
TW
0122-2
FWS
FWS
FWS
FWS
REVISION DESCRIPTION
E
TE
0122-1
TW
0122-1
TE
0122-1
TW
0122-1
FWS
FT
0132-1
FWS-V055A
FWS-V054A
FWS-V054B
FWS-V055B
FWS
FWS
FWS
FWS
FWS
FT
0132-2
TE
0122-2
TW
0122-2
TE
0122-2
TW
0122-2
FWS
M
FWS-V057A
FWS-V056A
FWS-V056B
FWS-V057B
APPR
MOV
+
0511
CHECKED
CORRECT
DATE
FWS
FWS
F
FWS
M
FWS
M
TE
0133-1
TW
0133-1
MOV
+
0511
MOV
+
0511
FWS
FWS
IP ECONOMIZER
TE
0133-2
TW
0133-2
1A
REVISION DESCRIPTION
G
IP ECONOMIZER
1B
IP ECONOMIZER
1B
FWS-V050
FWS
APPR
FWS
FE
+
0134
CHECKED
CORRECT
FWS
FT
0134
FWS-V033
FWS-V034
DATE
H
LV
+
0132
FO
FWS-V058
FWS-V035
FWS-V036
REVISION DESCRIPTION
I
FWS-V020
FWS-V020
FWS-V020
FWS-V051
FWS
FWS
FWS
APPR
LV
+
0120
LV
+
0120
LV
+
0120
CHECKED
CORRECT
FO
FWS-V026
FO
FWS-V026
FO
FWS-V026
DATE
J
FWS-V021
FWS-V021
FWS-V021
REVISION DESCRIPTION
K L
0610
TO HRSG IP DRUM 1A
0616 PID-08-07C
TO FUEL GAS HEATER
0610
TO HRSG IP DRUM 1B
0616 PID-08-07C
TO FUEL GAS HEATER
0610
TO HRSG IP DRUM 1C
0616 PID-08-07C
TO FUEL GAS HEATER
0611
0611
TO REHEATER 1B ATTEMP APRAY
0612
TO HRSG 1A - 1C HP
0613
TO HRSG 1A - 1C HP
ECONOMIZER INLET
ECONOMIZER INLET
HP SUPERHEATER 1A - 1C
ATTEMP SPRAY
0608 PID-03-01A
MAIN STEAM TURBINE BYPASS
VALVE DESUPERHEATER SPRAY
0608 PID-03-01A
MAIN STEAM TURBINE BYPASS
VALVE DESUPERHEATER SPRAY
0608 PID-03-01A
MAIN STEAM TURBINE BYPASS
VALVE DESUPERHEATER SPRAY
APPR
CHECKED
CORRECT
DATE
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
FEEDWATER SYSTEM
SHEET 2 OF 2
131134-PID-06-01B-D
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
EXISTING
GAS PIPELINE
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
REVISION DESCRIPTION
C
APPR
D
GEAR OPERATED
GEAR OPERATED
CHECKED
CORRECT
FGS-V017
FGS-V027
DATE
FGS
FGS
PDI
0168B
FGS-V011 FGS-V012
FGS-FLT001B
D
PDI
0168A
FGS-V021 FGS-V022
FGS-FLT001A
FGS-V013
FGS-V023
REVISION DESCRIPTION
D
E
APPR
FGS
FGS
FGS
FGS
CHECKED
CORRECT
DATE
F
FI
0171B
FE
0171B
FI
0171A
FE
0171A
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FY
0172B
TI
0172B
TE
0172B
TW
0172B
FY
0172A
TI
0172A
TE
0172A
TW
0172A
FGS
FGS
PT
0173B
PT
0173A
FGS-V015
FGS-V025
REVISION DESCRIPTION
G
APPR
CHECKED
CORRECT
DATE
H
FGS
FGS
ZSC
0175B
ZSC
0175A
FGS
FGS
FGS
FGS
FGS
ZSO
0175B
MOV
+
0175B
ZSO
0175A
MOV
+
0175A
REVISION DESCRIPTION
ASME
B31.8
ASME
B31.8
HS
0175B
M
M
I
ASME
B31.1
ASME
B31.1
NATIONAL GRID METERING STATION
(NOTE 2)
APPR
CHECKED
CORRECT
DATE
J
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
0801 PID-08-07B
TO FUEL GAS COMPRESSORS
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
2. ASSUME TYPICAL ARRANGEMENT BY OWNER.
M
FUEL GAS SYSTEM
SHEET 1 OF 4
131134-PID-08-07A-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
0801 PID-08-07A
PI
0111ABC
PAH
0111ABC
PAHH
0111ABC
2 OF 3
PAHH
0111
PI
0121ABC
PAH
0121ABC
PAHH
0121ABC
PAHH
0121
LI
0385ABC
LAH
0385ABC
LAHH
0385ABC
2 OF 3 2 OF 2 2 OF 2
LAHH
0385
EV
0381
ZIO
0381
ZIC
0381
EV
0385
FROM NATIONAL GRID
METERING SYSTEM
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
REVISION DESCRIPTION
PDI
0100
PDAH
0100
PDL
0110
PDAL
0110
PDI
0120
PDAL
0120
LI
0308
LAH
0308
TI
0515
TAH
0515
TAHH
0515
TAHH
0515/6
TI
0516
TAH
0516
TAHH
0516
YSH
0502
YSHH
0502
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
TI
0201
TAL
0201
LAL
0201
TI
0360
TAH
0360
PCV
0360
ZI
0360
TI
0501
TAH
0501
TAHH
0501
TAHH
0501/2
TI
0502
TAH
0502
TAHH
0502
YSH
0501
YSHH
0501
B
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
APPR
PDI
0227
PDAH
0227
TI
0230ABC
TAH
0230ABC
TAHH
0230ABC
2 OF 3
TAHH
0230
PI
0230ABC
PAL
0230ABC
PALL
0230ABC
2 OF 3
PALL
0230
YSH
0503
YSH
0501
YSHH
0501
YSHH
0501
TI
0519
TAH
0519
TAHH
0519
CHECKED
CORRECT
DATE
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
2 OF 2
2 OF 2
2 OF 2
DCS
FUEL GAS
COMPRESSOR
LOGIC
FGS-C001A
CONTROL
PANEL
FGS-V006 FGS-V007
EV
0303
ZIO
0303
ZIC
0303
FCU
0311
ZI
0311
TI
0517
TAH
0517
TAHH
0517
TI
0521
TAH
0521
TAHH
0521
TAHH
0521
TAHH
0517/8
TAHH
PI
0519/20
0000
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
LI
0315ABC
LAH
0315ABC
LAHH
0315ABC
FGS
FGS-V001
PI
0311
DCS
FUEL GAS
COMPRESSOR
LOGIC
FGS-C001B
CONTROL
PANEL
FGS
FGS
FGS
2 OF 3
0311
2 OF 3
LAHH
0315
PCV
0390
ZIO
0370
ZSC
0370
EV
0315
TI
0522
TAH
0522
TAHH
0522
TI
0518
TAH
0518
TAHH
0518
TI
0520
TAH
0520
TAHH
0520
PT
0000
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
TI
0311
TAH
FCU
0305
ZI
0305
TI
0321
PDI
0320
TI
0505
TAH
0505
TAHH
0505
TI
0503
TAH
0503
TAHH
0503
TI
0507
TAH
0507
TAHH
0507
REVISION DESCRIPTION
C
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
TI
0322ABC
TAH
0322ABC
TAHH
0322ABC
TAHH
0322
PI
0322ABC
2 OF 3
PI
0322
EV
0380
ZIO
0380
ZIC
0380
2 OF 2
TAHH
0507/8
2 OF 2
TAHH
0503/4
2 OF 2
TAHH
0505/6
TI
0508
TAH
0508
TAHH
0508
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
APPR
TI
0504
TAH
0504
TAHH
0504
TI
0506
TAH
0506
TAHH
0506
TI
0541
TAH
0541
TAHH
0541
D
CHECKED
CORRECT
DATE
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
TI
0543
TAH
0543
TAHH
0543
TI
0545
TAH
0545
TAHH
0545
2 OF 2
TAHH
0531/2
2 OF 2
TAHH
0533/4
COMP PLC
MONITORING
COMP PLC
VIBRATION
MONITORING
COMP PLC
MONITORING
COMP PLC
VIBRATION
MONITORING
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
TI
0542
TAH
0542
TAHH
0542
TI
0544
TAH
0544
TAHH
0544
TI
0546
TAH
0546
TAHH
0546
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
FGS
TI
0531
TAH
0531
TAHH
0531
TI
0533
TAH
0533
TAHH
0533
TI
0532
TAH
0532
TAHH
0532
REVISION DESCRIPTION
E
N
A
A
N
Q
OIL FILL
M
COLD GAS SUPPLY
SKID
MOUNTED
CONTROL
PANELS
COMPRESSOR FGS-C001A
COMPRESSOR FGS-C001B
FGS
FGS
FGS
SKID
MOUNTED
CONTROL
PANELS
COLD GAS SUPPLY
OIL FILL
TI
0534
TAH
0534
TAHH
0534
FGS
FGS
H
HS
0000
HS
0000
FGS
FGS
F
XA
0000
XA
0000
E
FGS-COOL001A
RECYCLED FUEL GAS COOLER
REFERENCE 1
REFERENCE 1
REFERENCE 2
C
C
REFER TO
PID-09-09D FOR
CCW DETAILS
L K G
Q M
H F E
D L K G
APPR
CHECKED
CORRECT
DATE
F
REVISION DESCRIPTION
G
FGS-COOL001B
RECYCLED FUEL GAS COOLER
D
REFERENCE 2
APPR
CHECKED
CORRECT
DATE
H
REFER TO
PID-09-09D FOR
CCW DETAILS
REVISION DESCRIPTION
O
O
1"
SCRUBBER
DRAIN TO
DRAIN TANK
INSTRUMENT
AIR
NITROGEN
PURGE
WARM GAS TO
FUEL GAS
HEATER
WARM GAS TO
FUEL GAS
HEATER
NITROGEN
PURGE
INSTRUMENT
AIR
I
SCRUBBER
DRAIN TO
DRAIN TANK
P
J
I
B
B
I
J
P
APPR
2" CLASS 301D1
BLIND FLANGE
2" CLASS 301D1
BLIND FLANGE
CHECKED
CORRECT
DATE
J
FGS-V003
FGS-V004
FUEL GAS COMPRESSOR BUILDING
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
0810 PID-08-07D
TO FGS-TK001
PID-14-01A
NITROGEN SUPPLY
0812 PID-08-07C
TO FUEL GAS SCRUBBER
0813 PID-08-07C
TO FUEL GAS HEATER
PID-12-01A
INSTRUMENT AIR
SUPPLY
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
1207
M
FUEL GAS SYSTEM
SHEET 2 OF 4
131134-PID-08-07B-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
0812 PID-08-07B
COOL GAS FROM FUEL
0813 PID-08-07B
FROM FUEL GAS
COMPRESSORS DISCHARGE
0616 PID-06-01B
FROM HRSG IP ECONOMIZER
A
GAS COMPRESSORS
REVISION DESCRIPTION
FGS
B
LSHH
FGS
0000C
APPR
FGS
PI
0127
FWS
CHECKED
CORRECT
LSHH
0000A
FGS-V030
DATE
FGS
FGS
FWS
FE
+
0111
FWS
FGS
FGS
PSV
+
0000
LSHH
0000B
FI
0111
FT
0111
TE
0129
TW
0129
FGS
FGS-V059
FGS-V060
FGS-V061
FGS-V062
FGS-V063
FGS-V064
LO
FGS-V005
FWS-V080 FWS-V081
AT
0130
FWS
FWS
MOISTURE
ANALYZER
TI
0115
TW
0115
REVISION DESCRIPTION
C
FWS
V
FWS
FGS-V065
FGS-V065
FWS
FWS
PI
0116
FWS
PSV
+
0000
ZSO
0000
ZSC
0000
FWS-V082
FGS
HV
+
0000
LSH
0000
APPR
D
FC
CHECKED
CORRECT
FWS-V084
DATE
FGS-E001
FUEL GAS HEATER
FGS
FGS
HV
+
0000
HV
+
0000
FGS-E002
FUEL GAS HEATER
FGS-V066
FGS
FGS-V067
LSH
0000
FGS
REVISION DESCRIPTION
FC
E
FC
FGS
ZSO
0000
ZSO
0000
FGS
FGS
ZSC
0000
ZSC
0000
APPR
CHECKED
CORRECT
FGS
FGS
DATE
F
TI
0133
TW
0133
FGS
PSV
+
0134
FUEL GAS SCRUBBER
REVISION DESCRIPTION
G
FGS
PI
0167
FGS-V032
REF. 1
FGS-V041
FGS
FGS
FGS
LIT
0385B
LI
0385
LIT
0385C
APPR
CHECKED
CORRECT
VENDOR
DATE
H
FGS
REF. 1
PSV
+
0385
FGS-SCRB002
HOT GAS
SCRUBBER
FWS
PI
0124
REVISION DESCRIPTION
I
FWS
FWS
FWS-V088
TI
0126
TW
0126
FGS
LIT
0385A
FGS
APPR
LCV
+
0385A
CHECKED
CORRECT
DATE
FC
J
REVISION DESCRIPTION
2" CLASS (LATER)
BLIND FLANGE
K L
FGS
APPR
PI
0187
CHECKED
CORRECT
FGS-V033
DATE
0823 PID-08-07D
0820
TO TEMPERATURE
CONTROL STATION
0811 PID-08-07D
FGS-V042
TO DRAIN TANK
FGS-TK001
PID-08-07D
FUEL GAS CONTROL STATION
0821 PID-08-07D
TO DRAIN TANK
FGS-TK001
0814 PID-08-07D
TO DRAIN TANK
FGS-TK001
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
FUEL GAS SYSTEM
SHEET 3 OF 4
131134-PID-08-07C-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
0823 PID-08-07C
FROM FUEL GAS HEATER
0820 PID-08-07C
FROM HOT GAS
SCRUBBER
0810 PID-08-07B
CONDENSATE DRAIN FROM
FUEL GAS COMPRESSORS
0821 PID-08-07C
FROM HOT GAS
SCRUBBER
0811 PID-08-07C
DRAIN FROM
FUEL GAS HEATER
0814 PID-08-07C
REVISION DESCRIPTION
DRAIN FROM
FUEL GAS HEATER
B
APPR
CHECKED
CORRECT
DATE
FWS
HV
+
0000
FGS
GSV
+
0158
REVISION DESCRIPTION
C
FWS
FC
FWS
ZSO
0000
FGS
ZI
0000
FWS
ZSO
0158
APPR
ZSC
0000
D
FGS
CHECKED
CORRECT
FWS-V077
DATE
ZSC
0158
FWS
FWS
FWS
FWS
LSL
0180
ZSC
0180
ZSO
0180
LSV
+
0180
FWS-V078
FWS-V079
REVISION DESCRIPTION
E
ZSO
0157
ZSC
0157
FC
GSV
+
0157
APPR
FGS
CHECKED
CORRECT
DATE
F
FGS-V055
FGS
FE
FLOW CONDITIONER
+
0142
POWERHOUSE
FGS
FT
0142
REVISION DESCRIPTION
G
FGS-V056
FWS-V093
FGS
FGS-TK001
DRAIN TANK
APPR
CHECKED
CORRECT
TE
0144
FGS-FA001
FGS-V052
DATE
H
FGS
FGS-V053
FGS
FGS-V054
LIT
0180
FWS-V090
LG
0181
FGS
FGS
PT
0191
TV
+
0143
REVISION DESCRIPTION
FO
FWS-V092
FGS
PT
0192
FGS-V068 FGS-V069
I
FWS-V091
APPR
CHECKED
CORRECT
FGS
POWERHOUSE
DATE
PT
0126
J
FGS-V057
FGS
FGS
TE
0143-1
TW
0143-1
REVISION DESCRIPTION
FWS
FGS
FGS
K L
PSV
+
0000
TE
0143-2
TW
0143-2
APPR
CHECKED
CORRECT
DATE
0831 PID-04-01B
0830
0830A
TO CONDENSATE
SUPPLY LINE
PID-39-01A
GAS TURBINE
ACCESSORY MODULE 1A
PID-39-02B
GAS TURBINE
ACCESSORY MODULE 1B
0830B
PID-39-02C
GAS TURBINE
ACCESSORY MODULE 1C
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
FUEL GAS SYSTEM
SHEET 4 OF 4
131134-PID-08-07D-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
VAPOR RETURN
FILL
REVISION DESCRIPTION
D
D
B
AFS
CHEMICAL FILL
AREA UNLOADING
CONTAINMENT
APPR
CHECKED
CORRECT
PI
0103
DATE
DRAIN
REVISION DESCRIPTION
C
APPR
D
CHECKED
CORRECT
DATE
AFS
PI
0102
AFS
AQUEOUS AMMONIA
FORWARDING PUMP SKID
24" MANHOLE
AFS-TK001
AQUEOUS AMMONIA
PI
0104
REVISION DESCRIPTION
E
STORAGE TANK
PSET=50.psig
APPR
CHECKED
CORRECT
AFS
DATE
F
TI
0102
AFS
AFS
PDI
0105A
PDI
0105B
D
D
AFS
LSH
0101
REVISION DESCRIPTION
G
M
AFS-P001A
AQUEOUS AMMONIA
FORWARDING PUMP
VENDOR
AFS-P001B
AQUEOUS AMMONIA
FORWARDING PUMP
VENDOR
AFS
LI
0101
APPR
AFS
CHECKED
CORRECT
DATE
LT
0101
H
REVISION DESCRIPTION
I
APPR
AFS
AFS
AFS
CHECKED
CORRECT
PCV
+
0106
TI
0107
TW
0107
DATE
V
J
AFS
PI
0107
REVISION DESCRIPTION
K L
APPR
POWERHOUSE
D
CHECKED
CORRECT
DATE
AFS
AFS-V001
LSH
0000
AFS-V002
SCR SYSTEM
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
AQUEOUS AMMONIA STORAGE
SYSTEM
131134-PID-13-17A-B
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
CCW
VSH
0132A
0937 PID-09-21A
MAKE-UP FROM
DEMIN WATER SYSTEM
A
CCW-V016
REVISION DESCRIPTION
CCW-SKD001
FAN SKID
TYPICAL ARRANGEMENT FOR ALL FANS
CCW-HOSE001
B
CCW-E001A
CCW HEAT EXCHANGER
CONNECT TO
AIR OPERATED
PORTABLE DRUM
APPR
(FIN-FAN)
WTD-V020
CCW-V017
PUMP
CHECKED
CORRECT
DATE
WTD-V021
CCW-TK001
CCW
EXPANSION TANK
CCW-V021
156X3
CCW
VSHH
0134A
CCW-V024
CCW
CCW-V023
CCW
CCW-V022
REVISION DESCRIPTION
C
CCW
LG
0100
LT
0100
CCW GRAB
SAMPLE
STATION
PI
0135
D
CCW-V020
CCW-V001A
CCW-V003
APPR
D
CCW-V001B
CHECKED
CORRECT
CCW-V031
DATE
TI
0135
TW
0135
V
CCW
V
CCW
CCW
CCW-V002A
CCW
TI
0143
TW
0143
PDT
0102A
CCW-STR001A
PDT
0102B
CCW
CCW-STR001B
PI
0143
CCW HEAT EXCHANGER
CCW-V004A
CCW
CCW
PI
0104A
PI
0104B
CCW-V006A
CCW-V002B CCW-V004B CCW-V006B
REVISION DESCRIPTION
E
CCW-V026
APPR
CHECKED
CORRECT
DATE
F
CCW-V013
CCW
TV
+
0109-1
FO
CCW-V039
CCW-P001A
CCW PUMP 1A
CCW-P001B
CCW PUMP 1B
REVISION DESCRIPTION
G
CCW-V012
CCW-V038
CCW
CCW
PP
0105A
PP
0105B
APPR
CCW-V007A
CCW-V007B
CHECKED
CORRECT
DATE
H
CCW
CCW
TE
0109-1
TW
0109-1
CCW-V036
TV
+
0109-2
CCW-V033
CCW
CCW-V034
CCW
CCW
CCW
CCW
D
PT
0108-1
PT
0108-2
CCW
CCW
CCW
CCW
CCW-V008A
CCW-V008B
TI
0110
TW
0110
TE
0107
TW
0107
TI
0106
TW
0106
CCW
CCW
CCW-V011
CCW-V010
CCW-V009A
CCW-V009B
REVISION DESCRIPTION
TE
0109-2
TW
I
0109-2
CCW-V035
APPR
CCW-V075
CHECKED
CORRECT
DATE
CCW
CCW
CCW
J
PT
0130-1
TI
0161
TW
0161
CCW
CCW-V014
PT
0130-2
CCW-V073
CCW
CCW-V074
CCW-V015
REVISION DESCRIPTION
PP
0160
K L
CCW-V080
FC
CCW-V082
CCW
PV
+
0130
APPR
CCW-V083
CHECKED
CORRECT
DATE
0901 PID-09-09B
CCW SUPPLY HEADER
0910 PID-21-03A
CCW SUPPLY TO STEAM/
WATER SAMPLING SYSTEM
0911 PID-09-09D
CCW SUPPLY TO
FUEL GAS COMPRESSORS
PID-09-09B
0903
CCW RETURN HEADER
PID-09-09D
CCW RETUNR FROM
0912
FUEL GAS COMPRESSORS
PID-21-03B
2101
CCW RETURN FROM STEAM/
WATER SAMPLING SYSTEM
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
COMPONENT COOLING WATER SYSTEM
SHEET 1 OF 4
131134-PID-09-09A-D
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
0901 PID-09-09A
PID-09-09A
A
CCW SUPPLY HEADER
0903
CCW RETURN HEADER
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
CCW
PP
0120
CCW-V040 CCW-V047
REVISION DESCRIPTION
C
CCW
PP
0124
APPR
D
CHECKED
CORRECT
DATE
REVISION DESCRIPTION
E
CCW-V048A
CCW-V048B
CCW
CCW
CCW
CCW
PSV
+
0121A
PSV
+
0121B
PSV
+
0121C
PSV
+
0121D
STG LO COOLER
CCW-V051A
CCW-V051B
CCW-V042A CCW-V045A
CCW-V042B CCW-V045B
CCW-V042C CCW-V045C
CCW-V042D CCW-V045D
APPR
CHECKED
CORRECT
DATE
F
STG GEN HYDROGEN COOLER
REVISION DESCRIPTION
G
CCW
CCW
CCW
CCW
TW
0122A
TW
0122B
TW
0122C
TW
0122D
APPR
CHECKED
CORRECT
DATE
H
CCW
CCW
CCW
CCW
TI
0125
TW
0125
TI
0123
TW
0123
REVISION DESCRIPTION
I
APPR
CHECKED
CORRECT
DATE
J
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
0904 PID-09-09C
CCW SUPPLY HEADER
PID-09-09C
0905
CCW RETURN HEADER
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
COMPONENT COOLING WATER SYSTEM
SHEET 2 OF 4
131134-PID-09-09B-D
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
0904 PID-09-09B
PID-09-09B
A
CCW SUPPLY HEADER
0905
CCW RETURN HEADER
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
CCW
PP
0135
REVISION DESCRIPTION
C
CCW-V061B
CCW-V060
PID-09-09D
APPR
D
CCW
CCW
CCW
CCW
CCW RETURN FROM
CHECKED
CORRECT
VJPC548IH7QD4
BFP
DATE
CCW-V065C
CCW-V065D
0907
CCW
TI
0145
TW
0145
TI
0150
TW
0150
PP
0151
CCW-V061A
CCW-V064C
CCW
CCW-V064D
CCW
CCW
FE
+
0144
CCW
CCW
FE
+
0149
FT
0144
FI
0149
FT
0149
REVISION DESCRIPTION
E
CCW
CCW-V063C
CCW
CTG GEN H2 COOLERS
PSV
+
0143
PSV
+
0148
CCW
PP
0152
CTG LCI COOLER
CCW
CCW-V062A
CCW
PSV
+
0153
PP
0136
CCW
CCW-V062B
CCW-V062C
CCW-V063D CCW-V062D
APPR
CHECKED
CORRECT
DATE
F
CCW
CCW
PP
0142
PP
0147
CCW-V063A
PSV
+
0137
REVISION DESCRIPTION
G
CCW
CCW
FE
+
0154
FT
0154
CCW-V063B
CCW
CCW-V064A
CCW
FE
+
0138
APPR
CHECKED
CORRECT
CCW
CCW
FT
0138
DATE
TI
0155
TW
0155
H
VJPC548IH7QD4
CCW-V065A
CCW-V064B
CCW
CCW
TI
0139
TW
0139
CCW-V065B
REVISION DESCRIPTION
CCW
PP
0141
CTG FLAME DETECTORS
PP
0146
CTG LO COOLER
I
CCW-V061C
CCW
CCW-V061D
APPR
CHECKED
CORRECT
DATE
J
REVISION DESCRIPTION
CCW-V063E CCW-V064E
CCW
CCW
FE
+
0140
K L
FT
0140
APPR
CCW-V065E
CHECKED
CORRECT
DATE
0906 PID-09-09D
CCW SUPPLY TO
BFP
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
2. TYPICAL FOR EACH CTG.
M
COMPONENT COOLING WATER SYSTEM
SHEET 3 OF 4
131134-PID-09-09C-D
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
0906 PID-09-09C
CCW SUPPLY HEADER
TO BFP
0911 PID-09-09A
CCW SUPPLY FOR
FUEL GAS COMPRESSOR
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
REVISION DESCRIPTION
C
BOILER FEED
PUMP 1A
APPR
D
CHECKED
CORRECT
DATE
CCW
ZSC
0164A
CCW
FUEL GAS COMPRESSOR
LUBE OIL COOLER 1A
CCW
ZSC
0165A
ZSO
0164A
CCW
CCW
ZSO
0165A
HV
+
0164A
REVISION DESCRIPTION
E
CCW
FO
HV
+
0165A
CCW-V072
FO
CCW
CCW
APPR
PP
0156
PP
0162
CHECKED
CORRECT
DATE
F
CCW-V072
CCW-V077
CCW
CCW
CCW
TI
0163
TW
0163
CCW
HV
+
0165B
REVISION DESCRIPTION
G
HV
FUEL GAS COMPRESSOR
+
0164B
FO
FO
LUBE OIL COOLER 1B
BOILER FEED
PUMP 1B
CCW
CCW-V073
CCW
ZSO
0165B
APPR
ZSO
0164B
CCW
CHECKED
CORRECT
CCW
ZSC
0165B
DATE
ZSC
0164B
H
REVISION DESCRIPTION
CCW
CCW
TI
0157
TW
I
0157
APPR
CHECKED
CORRECT
DATE
J
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
0907 PID-09-09C
CCW RETURN FROM
BOILER FEED PUMPS
0912 PID-09-09A
CCW RETURN TO
POWERHOUSE
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A
2. CCW SUPPLY TO BFP TYPICAL FOR ALL THREE SETS OF
BOILER FEED PUMPS.
M
COMPONENT COOLING WATER SYSTEM
SHEET 4 OF 4
131134-PID-09-09D-D
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
FROM AIR COMPRESSOR/
DRYER SKID
REVISION DESCRIPTION
INSTRUMENT
AIR SUPPLY FOR
FEEDWATER PUMPHOUSE
B
APPR
CHECKED
CORRECT
DATE
INSTRUMENT
AIR SUPPLY TO
DEMIN. AREA
IAS
PT
0105-1
ELECTRONICS ROOM
IAS
IAS-V001
PT
0105-2
IAS
IAS-V013
REVISION DESCRIPTION
C
IAS-V003
PT
0105-3
IAS-V001
IAS
APPR
D
PI
0106
CHECKED
CORRECT
IAS-V002
DATE
REVISION DESCRIPTION
E
IAS-V011
IAS-V006
APPR
CHECKED
CORRECT
DATE
F
IAS-V004
IAS-V005
IAS-V010
REVISION DESCRIPTION
G
MACHINE SHOP
MACHINE SHOP
APPR
CHECKED
CORRECT
DATE
H
LOOP AT HRSG DRUM LEVEL
LOOP AT HRSG GROUND LEVEL
LOOP AT STG
REVISION DESCRIPTION
I
IAS-V012
APPR
CHECKED
CORRECT
DATE
J
IAS-V009
IAS-V007
IAS-V008
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
1202 LATER
TO CEMS SHELTER
1203 PID-39-02A
TO CTGS
1204 PID-39-02A
TO CTG AIR INLET
FOGGERS
1201 REF. 2
TO HIGH PRESSURE STEAM
1205 REF. 3
TO HOT REHEAT STEAM
1206 REF. 4
TO LOW PRESSURE STEAM
1207 PID-08-07B
TO FUEL GAS COMPRESSOR
SKIDS
NOTES:
BYPASS VALVE VOLUME TANKS
BYPASS VALVE VOLUME TANKS
BYPASS VALVE VOLUME TANKS
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04.
INSTRUMENT AIR
SYSTEM
131134-PID-12-01A-E
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
FROM AIR COMPRESSOR SKID
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
SAS
PSV
+
0101
REVISION DESCRIPTION
C
SAS-V010
SAS-V008
SAS
PT
0102
SAS-V011
SAS-V009
D
SAS-V018
SAS
PI
0103
SAS-V001 SAS-V002
3/4 " 3/4 "
APPR
D
CHECKED
CORRECT
DATE
REVISION DESCRIPTION
E
SAS-V012
SAS-V007
SAS-V021
APPR
CHECKED
CORRECT
F
SAS-V020
SAS-V003 SAS-V004
DATE
REVISION DESCRIPTION
G
APPR
CHECKED
CORRECT
DATE
D
H
SAS-V019
SAS-V014
SAS-V013
SAS-V005
REVISION DESCRIPTION
SAS-V015
I
SAS-V006
SAS-V022
APPR
SAS-V018
D
SAS-V016
CHECKED
CORRECT
DATE
J
SAS-V017
REVISION DESCRIPTION
D
K L
APPR
CHECKED
CORRECT
DATE
NOTES:
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
SERVICE AIR
SYSTEM
131134-PID-12-02A-E
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
REVISION DESCRIPTION
ANTISCALANT FEED
ALTERNATIVE
DEMIN SUPPLY
PERMEATE FROM
SECOND PASS RO
CHEMICAL TOTE
FILLING
B
CITY WATER
APPR
CHECKED
CORRECT
DATE
TO POTABLE
WATER SYSTEM
REVISION DESCRIPTION
C
APPR
D
CHECKED
CORRECT
DATE
RO PRETREATMENT
(ULTRA FILTRATION)
(BY VENDOR)
RO FEED PUMP
ELECTRO-DEIONIZATION SKID
D
(EDI)
REVISION DESCRIPTION
E
(BY VENDOR)
LT
PI PT
RO ANTISCALANT
SOLUTION TANK
APPR
LT
CHECKED
CORRECT
DATE
F
FIRST PASS
RO PRESSURE
VESSEL
REVISION DESCRIPTION
G
RO FEED PUMP
CONTAINMENT AREA
APPR
CHECKED
CORRECT
DATE
H
PI PT
REVISION DESCRIPTION
I
SECOND PASS
RO PRESSURE
VESSEL
APPR
CHECKED
CORRECT
DATE
J
(BY VENDOR)
(BY WATER TREATMENT VENDOR)
REVISION DESCRIPTION
PI
K L
APPR
CHECKED
CORRECT
DATE
RO PERMEATE
TO EDI SKID
NOTES:
RO CONCENTRATE
TO WASTE
CYCLE MAKE-UP /
DEMIN STORAGE TANK
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
FIRST PASS RO FEEDWATER
M
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04.
DEMINERALIZED WATER SYSTEM
SHEET 1 of 2
131134-PID-09-21A-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
EXISTING
REVISION DESCRIPTION
CONDENSATE OVERFLOW
DEMINERALIZER
B
APPR
CHECKED
CORRECT
DATE
DEMINERALIZED
WATER
STORAGE TANK
REVISION DESCRIPTION
C
PS
LI
LT
APPR
D
CHECKED
CORRECT
DATE
REVISION DESCRIPTION
E
APPR
CHECKED
CORRECT
DATE
F
REVISION DESCRIPTION
G
APPR
CHECKED
CORRECT
DATE
H
DEMINERALIZED WATER
PUMP 2A
DEMINERALIZED WATER
PUMP 2B
DEMINERALIZED WATER
PUMP 2C
REVISION DESCRIPTION
PI
PI
PI
I
APPR
CHECKED
CORRECT
DATE
J
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
NOTES:
CYCLE MAKE-UP
TO CONDENSER
DEMINERALIZER
CROSS TIE TO UNIT 1
VACUUM PUMP 2A
VACUUM PUMP 2B
SAMPLE PANEL
CYCLE CHEMICAL
FEED SYSTEM
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
MAKE-UP TO CLOSED CYCLE
COOLING WATER SYSTEM
VACUUM BREAKER VALVE/
COND EJ WATER SEAL
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04.
STATOR WINDING
H COOLING UNIT
2
CONDENSATE PUMP 2A
CONDENSATE PUMP 2B
ST OIL PURIFIER
CONDENSER FILL
CT 3001/4001
WATER WASH SKID
MAKE-UP TO CT
CHILLER LOOP
CTG FW NOX CONTROL WATER
INJECTION
M
DEMINERALIZED WATER SYSTEM
SHEET 2 of 2
131134-PID-09-21B-C
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
A
1330 PID-13-24A
FROM SANITARY LIFT
STATION
1106 PID-11-02B
FROM HRSG SUMP PUMPS
2303 PID-23-21A
FROM PLANT FLOOR DRAINS
2304 PID-23-21A
FROM PLANT FLOOR DRAINS
2305 PID-23-21A
FROM LUBE OIL COOLER
CURBED AREA
2306 PID-23-21A
FROM CTG ACCESSORY MODULE
CURBED AREA
REVISION DESCRIPTION
B
APPR
CHECKED
CORRECT
DATE
WWT
WWT
LAH
0100
LSH
0100
REVISION DESCRIPTION
C
OIL/WATER SEPARATOR
CONTAINMENT VAULT
APPR
D
CHECKED
CORRECT
DATE
WWT
WWT
LSHH
0101
LSH
0101
WWT-V011
OIL/WATER SEPARATOR
REVISION DESCRIPTION
E
APPR
CHECKED
CORRECT
DATE
F
WWT-P002A
WASTEWATER LIFT PUMP
200 GPM
REVISION DESCRIPTION
G
WWT-V002A
WWT-V001A
OIL/WATER SEPARATOR
CLEARWELL VAULT
TSW-V004
WWT
PI
0103
WWT-V001B
WWT-P002B
WASTEWATER LIFT PUMP
APPR
CHECKED
CORRECT
200 GPM
DATE
H
WWT-V004
WWT-V002B
WWT-V012
WWT
WWT
WWT
WWT-V009
LSHH
0102
LSH
0102
LSL
0102
REVISION DESCRIPTION
WWT
I
FE
+
0104
APPR
WWT
CHECKED
CORRECT
AIT
0105-1
DATE
WWT
AIT
0105-2
pH pH
WWT-V005 WWT-V006
J
CO
WWT-V010
REVISION DESCRIPTION
K L
APPR
CHECKED
CORRECT
DATE
TO CITY WATER
NOTES:
TO EXISTING NORTHPORT
WASTE WATER TREATMENT FACILITY
M
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
WASTE WATER TREATMENT
SYSTEM
131134-PID-13-19A-B
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

1
2
3
4
5
6
7
8
9
10
N
8
VAPOR
BALANCE
CONNECTION
FLOOR
A
PID-08-08D
FUEL GAS SUPPLY
1203 PID-12-01A
INSTRUMENT AIR
SUPPLY
CO2
SKID
REF. 7
N
7
FILL
CONNECTION
REVISION DESCRIPTION
N
5
N
6
N
3
N
4
N
1
N
2
IE
57A
PM
3-1
IE 57A
ALT
IE 57A
ALT
PM
3-2
IE
57B
PUMP OUT
CONNECTION
GTA-V004
1"
WW
24
GTA-TK001
FP
26
WASH WATER DRAIN TANK
4,000 GALLONS
151X1
GTA-V005
B
APPR
EXHAUST
FP
25
4"-GTA-048-NONE-P
GTA-V003
PM
11
IE
60
CHECKED
CORRECT
DATE
IE
62
PM
10
WW
16
EXHAUST
DUCT
PRESSURE
SWITCH
CCW
RETURN
PID-09-09C
CW
53
CW
52
PACKAGE
IE
PM
09
REF 12
63
GE
GTA-V006
GTA
LG
0000
GTA-V007
TO VENT
GTA
CCW
SUPPLY
PID-09-09C
LOCAL
WW
15
PM
08
ALARM PANEL
GTA
LS
0000
REVISION DESCRIPTION
C
CA
52
PERFORMANCE
GTA-V008
MONITORING
LT
0103
PACKAGE
WW
10
REF 12
CONDENSATE
FLOOR
DRAIN
PM
06
UNDERGROUND
APPR
D
CHECKED
CORRECT
WW
30
DATE
ROOF
WW
110
PM
05
PM
04
CCW
SUPPLY
PID-09-09C
CCW
RETURN
PID-09-09C
CA
52
ROOF
ROOF
COMBUSTION TURBINE
CA
51
UNDERGROUND
REVISION DESCRIPTION
E
GE
GE
TO VENT
TO VENT
LO
13F
CW
7
CW
6
LO
13E
FP
31
FP
32
LO
3B
FG
2
FG
1
LO
13D
FG
3
FG
7
FP
10
FP
11
ACCESSORY
MODULE
LO
13A
LO
1
LO
13B
LO
3A
LO
19
LO
13C
LO
2
WW
33
APPR
CHECKED
CORRECT
DATE
F
GTA-V002
CA
16
CA
20
LOW
POINT
DRAIN
LO
FILL
CA
5
LO COOLER
MAINTENANCE
LO
DRAIN
DRAIN
ROOF
REF 12
VM-15-1
10"
CA
53
CA
53
INLET AIR HEATING
ISOLATION VALVE
REVISION DESCRIPTION
G
PT
PM
2
PM
1
REF 12
IE
4
96BH-1 96BH-2
REF 12
VA20-1
INLET AIR HEATING
CONTROL VALVE
AP4
IE
97
IE
92C
WW
13
AIR PROCESSING UNIT
AP1
APPR
PT
CHECKED
CORRECT
IE
97
REF 12
DATE
H
AP3
IE
92D
AP2
WW
12
WTD-V022
IE
20
INLET
REF. 8
WW
1
96AC - 40A,B,C,D
REF. 12
IE
92A
WW
112
IE
92B
TO SPRITS DUCT
DRAIN SKID A217
REVISION DESCRIPTION
WASH WATER
DETERGENT FLUSH
TO DRAIN TANK
UNDERGROUND
WW
111
IE
2
I
IE
94-1
TO SPRITS DUCT
DRAIN SKID A-217
LOAD
COMPARTMENT
APPR
CHECKED
CORRECT
DATE
CW
12
8"
CCW
SUPPLY
PID-09-09C
IE
91B
IE
91A
IE
91D
IE
91C
IE
93
IE
93A
J
CW
13
8"
CCW
RETURN
PID-09-09C
FOGGER
SKID
SEAL OIL
LOOP SEAL
IE
110
IE
90
LE11
(OBD-2)
CW12
(AH)
ROOF
CW13
(AH)
LE4
(GAV)
GENERATOR
COMPARTMENT
REVISION DESCRIPTION
2"
ROOF
BEARING DRAIN
ENLARGEMENT VENT
GAS
SCAVENGE
LE5
(GAV)
WW20
UNDERGROUND
K L
UNDERGROUND
LE
3
CO2
FEED
LE12
(WRD)
LE
2
H2
FEED
(SEE PID-14-09A)
DETERGENT INLET
WW21
WATER WASH SKID
REF. 10
WW29
WW19
WW23 WW22
APPR
CHECKED
CORRECT
PID-12-01A
INSTRUMENT AIR
DATE
1204
PID-09-21A
0930
FROM DEMINERALIZED
WATER SYSTEM
NOTES:
1. FOR GENERAL NOTES, SYMBOLS AND NUMBERING STANDARDS,
SEE S&W DRAWINGS 131134-PID-00-01A THRU 00-04A.
2. TYPICAL FOR EACH CTG.
M
CTG AUXILIARIES & SERVICES
SYSTEM
131134-PID-39-02A-A
NORTHPORT OPTION 9
DESIGNED BY
DSGN CHK’D BY
DRAWING NO.
TM
PIPING & INSTRUMENT
FUNDAMENTAL DIAGRAM
nationalgrid
DRAWN BY
CHK’D BY
CAD MODEL
N
LEVELS
WORK PKG
1
2
3
4
5
6
7
8
9
10
PCT

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix IV Northport Plant Equipment List
Appendix IV Northport Plant Equipment List
March 30, 2009 224

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix IV Northport Plant Equipment List
Hybrid Option Equipment List
Combustion Turbine Typical Scope of Supply
System System Scope
ENGINE ASSEMBLY Coupling to Generator, Dry Chemical Exhaust Bearing Fire Protection System,
Insulation Blankets, Platforms, Stairs and Ladders
Engine Assembly with Variable Inlet Guide Vane System, Compressor, Bleed System, Purge Air
Bedplate
System, Bearing Seal Air System, Combustors, Dual Fuel Nozzles, Turbine
Rotor Cooler
Walk-in acoustical HVAC, Lighting, and Low Pressure CO2 Fire Protection System
enclosure
MECHANICAL
HVAC and Lighting, Air Compressor for Pneumatic System, Low Pressure C02
PACKAGE
Fire Protection System
Lubricating Oil System Lube Oil Reservoir, Accumulators, AC Driven Oil Pumps, DC Emergency Oil
and Control Oil System Pump with Starter, Oil Coolers, Duplex Oil Filter, Oil Temperature and
Pressure Control Valves, Oil Vapor Exhaust Fans and Demister, Oil Heaters,
Oil Interconnect Piping (SS and CS), Oil System Instrumentation, Oil for
Flushing and First Filling
ELECTRICAL
HVAC and Lighting, AC and DC Motor Control Centers, Generator Voltage
PACKAGE
Regulating Cabinet, Generator Protective Relay Cabinet, DC Distribution
Panel, Battery Charger, Digital Control System with Local Control Panel (all
control and monitoring functions as well as data logger and sequence of
events recorder), Control System Valves and Instrumentation Communication
link for interface with plant DCS Supervisory System, Vibration Monitoring
System, Low Pressure C02 Fire Protection System, Cable Tray and Conduit
Provisions for Performance Testing including Test Ports, Thermowells,
Instrumentation and DCS interface cards
INLET AND EXHAUST Inlet Duct Trash Screens, Inlet Duct and Silencers, Self Cleaning Filters, Hoist
SYSTEMS
System For Filter Maintenance, Evaporative Cooler System, Exhaust Duct
Expansion Joint, Exhaust Silencers Inlet and Exhaust Flow, Pressure and
Temperature Ports and Instrumentation
FUEL SYSTEMS
N.Gas System
Gas Valves Including Vent, Throttle and Trip Valves, Gas Filter/Separator, Gas
Supply Instruments and Instrument Panel
STARTING SYSTEM Enclosure, Static Start System, Turning Gear and Clutch Assembly,
GENERATOR Static Exciter (including excitation transformer), Line Termination Enclosure
with CTs, VTs, Surge Arrestors, and Surge Capacitors, Neutral Cubicle with
CT, Neutral Tie Bus, Grounding Transformer, and Secondary Resistor,
Generator Gas Dryer, Seal Oil System (including Defoaming Tank, Reservoir,
Seal Oil Pump, Emergency Seal Oil Pump, Vapor Extractor, and Oil Mist
Eliminator), Generator Auxiliaries Control Enclosure, Generator Breaker, Iso-
Phase bus connecting generator and breaker, Grounding System Connectors
Generator Cooling Hydrogen Cooling System (including H2 to Glycol and Glycol to Air heat
exchangers, liquid level detector circulation system, interconnecting piping and
controls)
MISCELLANEOUS Interconnecting Pipe, Wire, Tubing and Cable Instrument Air System Including
Air Dryer On Line and Off Line Water Wash System LP CO2 Storage Tank
Drain System Drain Tanks Coupling, Coupling Cover and Associated
Hardware
March 30, 2009 225

Fuel Systems
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix IV Northport Plant Equipment List
Equipment
No.
Description Type
1 Gas Pipeline Underground, coated carbon steel, wrapped cathodic protection
2 Gas metering
Station
Kerosene 2 X 100%
3 Unloading
Pumps
4 Kerosene
Forwarding
Pumps
2 X 100%
5 Kerosene
Storage Tank
5,000,000 gallon field erected
Feedwater and Miscellaneous Systems and Equipment
Equipment
No.
Description Type
1 Demineralized
Water Storage
Tank
1,000,000 gallon field erected
2 Condensate
Pumps
Vertical canned
3 Boiler Feedwater Horizontal, split case, multi-stage, centrifugal, with interstage
Pump
bleed for IP water
4 Auxiliary Boiler Shop fabricated, water tube
5 Service Air
Compressors
Lubricated Screw
6 Instrument Air
Dryers
Duplex, regenerative
7 Closed Cycle
Cooling Heat
Exchangers
Fin Fan for GT/HRSG with existing shell and tube for ST
8 Closed Cycle
Cooling Water
Pumps
Horizontal centrifugal
9 Engine-Driven Fire
Pump
Horizontal, diesel engine
10 Fire Service
Booster Pump
Two-stage horizontal centrifugal
11 Raw Water Pumps Single suction
12 City/Fire Water
Storage Tank
500,000 gallon field erected
13 Makeup Water Multi-media filter, cartridge filter, RO membrane assembly and
Demineralizer electro- deionization unit
March 30, 2009 226

Heat Recovery Steam Generator, Ducting, and Stack
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix IV Northport Plant Equipment List
Equipment
No.
Description Type
1 Stack Concrete Dual Flue Chimney
2 Heat Recovery Drum, multi-pressure with economizer section and integral
Steam
Generator
deaerator
3 SCR Reactor Space for spare layer
4 SCR Catalyst
5 CO Catalyst
6 Dilution Air
Blowers
Centrifugal
7 Ammonia Feed
Pump
Centrifugal
8 Ammonia
Storage Tank
20,000 gallon pressurized shop fabricated tank
Accessory Electric Plant
Equipment
No.
Description Type
1 CTG
Transformers
2-Oil-filled 290 MVA 18kV/345 kV
2 STG
Transformer
1-Oil-filled 300 MVA 22 kV/345 kV
3 Auxiliary
Transformers
2-Oil-filled 10 MVA 18 kV/4.16 kV
4 Generator
Breaker
2, one for each CT
5 High Side GIS
Breaker
3, one for each CTG and one for the STG
6 Low Voltage
Transformer
Dry ventilated 4.16 kV/480V
7 CTG Isolated
Phase Bus
Ducts and Tap
Bus
Aluminum, self-cooled 18 kV
8 Medium
Voltage
Switchgear
Metal clad
9 Low Voltage
Switchgear
Metal enclosed
March 30, 2009 227

Accessory Electric Plant
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix IV Northport Plant Equipment List
Equipment
No.
Description Type
1 CTG
Transformers
2-Oil-filled 290 MVA 18kV/345 kV
2 STG
Transformer
1-Oil-filled 300 MVA 22 kV/345 kV
3 Auxiliary
Transformers
2-Oil-filled 10 MVA 18 kV/4.16 kV
4 Generator
Breaker
2, one for each CT
5 High Side GIS
Breaker
3, one for each CTG and one for the STG
6 Low Voltage
Transformer
Dry ventilated 4.16 kV/480V
7 CTG Isolated
Phase Bus
Ducts and Tap
Bus
Aluminum, self-cooled 18 kV
8 Medium
Voltage
Switchgear
Metal clad
9 Low Voltage
Switchgear
Instrumentation and Control
Metal enclosed
Equipment
No.
Description Type
1 DCS-Main
Control
Monitor/keyboard; Operator printer; Engineering printer
2 DCS-
Processor
Microprocessor with redundant input/output
3 DCS-Data
Highway
Fiber optic
March 30, 2009 228

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix IV Northport Plant Equipment List
Backyard Option Equipment List
Combustion Turbine Typical Scope of Supply
System System Scope
ENGINE ASSEMBLY Coupling to Generator, Dry Chemical Exhaust Bearing Fire Protection
Engine Assembly with
Bedplate
Walk-in acoustical
enclosure
MECHANICAL
PACKAGE
Lubricating Oil System
and Control Oil System
ELECTRICAL
PACKAGE
INLET AND EXHAUST
SYSTEMS
FUEL SYSTEMS
N.Gas System
System, Insulation Blankets, Platforms, Stairs and Ladders
Variable Inlet Guide Vane System, Compressor, Bleed System, Purge Air
System, Bearing Seal Air System, Combustors, Dual Fuel Nozzles, Turbine
Rotor Cooler
HVAC, Lighting, and Low Pressure CO2 Fire Protection System
HVAC and Lighting, Air Compressor for Pneumatic System, Low Pressure
C02 Fire Protection System
Lube Oil Reservoir, Accumulators, AC Driven Oil Pumps, DC Emergency Oil
Pump with Starter, Oil Coolers, Duplex Oil Filter, Oil Temperature and
Pressure Control Valves, Oil Vapor Exhaust Fans and Demister, Oil
Heaters, Oil Interconnect Piping (SS and CS), Oil System Instrumentation,
Oil for Flushing and First Filling
HVAC and Lighting, AC and DC Motor Control Centers, Generator Voltage
Regulating Cabinet, Generator Protective Relay Cabinet, DC Distribution
Panel, Battery Charger, Digital Control System with Local Control Panel (all
control and monitoring functions as well as data logger and sequence of
events recorder), Control System Valves and Instrumentation
Communication link for interface with plant DCS Supervisory System,
Vibration Monitoring System, Low Pressure C02 Fire Protection System,
Cable Tray and Conduit Provisions for Performance Testing including Test
Ports, Thermowells, Instrumentation and DCS interface cards
Inlet Duct Trash Screens, Inlet Duct and Silencers, Self Cleaning Filters,
Hoist System For Filter Maintenance, Evaporative Cooler System, Exhaust
Duct Expansion Joint, Exhaust Silencers Inlet and Exhaust Flow, Pressure
and Temperature Ports and Instrumentation
Gas Valves Including Vent, Throttle and Trip Valves, Gas Filter/Separator,
Gas Supply Instruments and Instrument Panel
STARTING SYSTEM Static Start System, Turning Gear and Clutch Assembly,
GENERATOR Static (including excitation transformer), Line Termination Enclosure with
CTs, VTs, Surge Arrestors, and Surge Capacitors, Neutral Cubicle with CT,
Neutral Tie Bus, Grounding Transformer, and Secondary Resistor,
Generator Gas Dryer, Seal Oil System (including Defoaming Tank,
Reservoir, Seal Oil Pump, Emergency Seal Oil Pump, Vapor Extractor, and
Oil Mist Eliminator), Generator Auxiliaries Control Enclosure, Generator
Breaker, Iso-Phase bus connecting generator and breaker, Grounding
System Connectors
Generator Cooling Hydrogen Cooling System (including H2 to Glycol and Glycol to Air heat
exchangers, liquid level detector circulation system, interconnecting piping
and controls)
MISCELLANEOUS Interconnecting Pipe, Wire, Tubing and Cable Instrument Air System
Including Air Dryer On Line and Off Line Water Wash System LP CO2
Storage Tank Drain System Drain Tanks Coupling, Coupling Cover and
Associated Hardware
March 30, 2009 229

Fuel and Feed
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix IV Northport Plant Equipment List
Equipment
No.
Description Type
1 Gas Pipeline Underground, coated carbon steel, wrapped cathodic protection
2 Gas metering
Station
Kerosene 2 X 100%
3 Unloading
Pumps
4 Kerosene
Forwarding
Pumps
2 X 100%
5 Kerosene
Storage Tank
5,000,000 gallon field erected
Feedwater and Miscellaneous Systems and Equipment
Equipment
No.
Description Type
1 Demineralized
Water Storage
Tank
1,000,000 gallon field erected
2 Condensate
Pumps
Vertical canned
3 Boiler Feedwater Horizontal, split case, multi-stage, centrifugal, with interstage
Pump
bleed for IP water
4 Auxiliary Boiler Shop fabricated, water tube
5 Service Air
Compressors
Lubricated Screw
6 Instrument Air
Dryers
Duplex, regenerative
7 Closed Cycle
Cooling Heat
Exchangers
Fin Fan
8 Closed Cycle
Cooling Water
Pumps
Horizontal centrifugal
9 Engine-Driven Fire
Pump
Horizontal, diesel engine
10 Fire Service
Booster Pump
Two-stage horizontal centrifugal
11 Raw Water Pumps Single suction
12 City/Fire Water
Storage Tank
500,000 gallon field erected
13 Makeup Water Multi-media filter, cartridge filter, RO membrane assembly and
Demineralizer electro- deionization unit
March 30, 2009 230

Heat Recovery Steam Generator, Ducting, and Stack
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix IV Northport Plant Equipment List
Equipment
No.
Description Type
1 Stack Concrete Triple Flue Chimney
2 Heat Recovery Drum, multi-pressure with economizer section and integral
Steam
Generator
deaerator
3 SCR Reactor Space for spare layer
4 SCR Catalyst
5 CO Catalyst
6 Dilution Air
Blowers
Centrifugal
7 Ammonia Feed
Pump
Centrifugal
8 Ammonia
Storage Tank
25,000 gallon pressurized shop fabricated tank
Steam Turbine Generator and Auxiliaries
Equipment
No.
Description Type
1 Steam Turbine Tandem compound, HP,IP,and two-flow LP turbines
2 Steam Turbine
Generator
Hydrogen cooled, static excitation
3 Steam Bypass One per HRSG
4 Air Cooled
Condenser
42 Cell, divided pass
5 Vacuum
Pumps
Hogging 1 X 1005
6 Steam Jet Air
Ejectors
Holding 2 X 100%
March 30, 2009 231

Accessory Electric Plant
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix IV Northport Plant Equipment List
Equipment
No.
Description Type
1 CTG
Transformers
3-Oil-filled 220 MVA 18kV/345 kV
2 STG
Transformer
1-Oil-filled 350 MVA 22 kV/345 kV
3 Auxiliary
Transformers
3-Oil-filled 5 MVA 18 kV/4.16 kV
4 Low Voltage
Transformer
Dry ventilated 4.16 kV/480V
5 Generator
Breaker
3, one for each CT
6 High Side GIS
Breaker
4, one for each CTG and one for the STG
7 CTG Isolated
Phase Bus
Ducts and Tap
Bus
Aluminum, self-cooled 18 kV
8 STG Isolated
Phase Bus
Duct and Tap
Bus
Aluminum, self-cooled 22 kV
9 Medium
Voltage
Switchgear
Metal clad
10 Low Voltage
Switchgear
Instrumentation and Control
Metal enclosed
Equipment
No.
Description Type
1 DCS-Main
Control
Monitor/keyboard; Operator printer; Engineering printer
2 DCS-
Processor
Microprocessor with redundant input/output
3 DCS-Data
Highway
Fiber optic
March 30, 2009 232

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix V Northport Electrical One-Line Diagrams
Appendix V Northport Electrical One-Line Diagrams
March 30, 2009 233

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix V Northport Electrical One-Line Diagrams
March 30, 2009 234

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix V Northport Electrical One-Line Diagrams
March 30, 2009 235

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VI Northport Water Balances
Appendix VI Northport Water Balances
March 30, 2009 236

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VI Northport Water Balances
March 30, 2009 237

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VI Northport Water Balances
March 30, 2009 238

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VI Northport Water Balances
March 30, 2009 239

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VI Northport Water Balances
March 30, 2009 240

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
Appendix VII Northport Capital Cost Estimate Descriptions
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Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
Hybrid Repowering Option of Unit 4 - 2x2x1 501G Combined Cycle
This section includes descriptive information for the Unit 4 hybrid
repowering using a 2 x 2 x 1 501G un-fired design. The plant utilizes
two MHI M501G combustion turbines (for study purposes). A heat
recovery steam generator (HRSG) is provided for each combustion
turbine. The existing Unit 4 steam turbine, condenser, circulating
water system and other miscellaneous plant equipment will be reused
as described in more detail below. The plant will have a nominal
capacity (ISO) of 744 MW. Based on a rating for the existing Unit 4
of 387 MW, the increase in unit capacity will be 357 MW.
Plant Description
Figure 1 is a schematic illustration of the MHI M501G combined cycle plants. The MHI M501G gas
turbine consists of a 17 stage axial flow compressor with a pressure ratio of 20:1, sixteen dry-low NOx
combustors with a firing temperature of over 2700ºF, and a four stage axial flow turbine. The turbine,
due to these high temperatures is provided with steam cooling for the transition pieces between the
combustors and the turbine itself. In addition cooling is provided for the compressor through external
heat exchangers which cool compressor bleed air while heating the incoming fuel gas to the combustors.
The M501G guaranteed NOx emissions (before the SCR) are 15 ppm on gas with Dry Low NOx
combustor and 42 ppm on distillate with water injection. The 501G was designed as a base load machine
intended for non-cyclic operation with minimal starts but high total generating hours each year.
Natural
Natural
Gas
Gas
Metering Metering &
&
Conditioning
Conditioning
Distillate
Distillate
Oil
Oil
Storage Storage &
&
Handling
Handling
Water
Water
Water
Water
Treatment
Treatment
M
Figure 1 – Hybrid Option Plant Schematic
G
CT
CP = Condensate Pump
CT = Combustion Turbine
CWS = Circulating Water System
G = Generator
HRSG = Heat Recovery Steam Generator
M = Main Step-up Transformer
S = Stack
ST = Steam Turbine
M G CT
G M
CWS
March 30, 2009 242
HRSG
HRSG
S
S
CP
ST
Existing

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
The M501G utilizes hot main compressor rotor air to heat the incoming combustion turbine fuel gas.
Therefore this energy is not available for use in kettle boilers to produce IP and LP steam from hot rotor
air as is done in the Siemens W501G design. The end result is that the MHI M501G uses rotor air to heat
the fuel gas directly while the W501G uses cycle steam for fuel gas heating, and no steam is produced
from rotor cooling air in the M501G design during this process while both LP and IP steam are produced
in the W501G design.
The plant is designed to operate on natural gas fuel as the primary fuel with distillate oil back up, using
dry, low NOx combustion and selective catalytic reduction for NOx control. When firing oil, water
injection is required to reduce the NOx produced by the combustion turbine. The units are to be designed
for an evaporative cooler with 85% effectiveness.
The following sections describe major plant characteristics and the facilities. This description is
organized by the list of accounts in the cost and performance models.
A0 Demolition
Demolition and/or relocation of existing equipment is included as described below:
• Remove existing No. 6 oil tank
• Remove existing high energy piping
• Disconnect and remove existing main boiler feed pump and fluid drive
• North-south gas line to be relocated.
• Tech services building to be relocated.
• Existing road to the north of the tech services building to be relocated to the south.
• Row of lighting poles to the south of the existing road to be relocated to the new road.
A1 Combustion Turbine Vendor Package
The M501G combustion turbines are equipped with a dry, low NOx combustor which limits NOx when
firing gas to 25 ppm and with water injection reduces NOx when firing oil to 42 ppm. Each combustion
turbine is provided with a hydrogen cooled generator. The combustion turbines and generators will
enclosed in a turbine building.
Each combustion turbine package includes:
• Pulse jet inlet air filter
• Inlet silencer
• Evaporative cooler
• Air processing unit
• Static start system
• Fuel skid
• Anti-icing inlet air heating system
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Appendix VII Northport Capital Cost Estimate Descriptions
• Water injection skid
• On-line and off-line compressor water wash system
• Fire protection (CO2) and fire detection systems
• Lube oil system
• Static exciter
• Control system with control options for combined cycle application, e.g. temperature matching,
external speed set point and high steam temperature protection
• Vibration and temperature monitoring
• Batteries and battery charger
• TCA cooler to cool a main compressor bleed stream of compressed air to be used for power
turbine blade cooling. Waste heat from this cooler is used to heat incoming fuel gas
A1 Combustion Turbine Balance of Plant
Each combustion turbine balance of plant includes:
• Combustion turbine foundation
• Step up transformers, 13.8 to 345 kV (one for each CT)
• Auxiliary transformers (one for each CT)
• Generator breakers (one for each CT)
• High side gas insulated breakers
• Generator hydrogen and CO system
2
• Associated electrical connections, metering and protection
• Oily water collection system
• Wash water drain tank and pumps
• Lube oil collection system
• CTG equipment closed cycle cooling water system including a 14 cell fin-fan cooler
B1 Existing Steam Turbine Upgrades
The existing steam turbine generator and associated auxiliary equipment will be reused. Normal
maintenance and overhaul cost for the steam turbine and other existing equipment is assumed to be part of
the plants maintenance budget. The following steam turbine modifications are included in the repowering
project cost estimate:
• Replace HP and IP turbine blades and diaphragms as required to improve performance
• Generator rewind
• New Mark VI steam turbine controls
• New static excitation system
March 30, 2009 244

• Disconnect and cap existing extraction steam piping.
• Connect an LP steam admission to the LP turbines
B1 Steam Turbine Balance of Plant
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
In general the existing steam turbine balance of plant equipment will be reused including:
• Steam turbine foundation and pedestal
• Lube oil system
• Gland Seal and Exhaust system
• Condenser air removal system
• Condensate system (except pumps)
• Hydrogen system
• CO system
2
• Nitrogen system
• Generator synchronizing
• Generator and transformer protection
• Fire protection for steam turbine area
• Closed cycle cooling water system including heat exchangers and pumps
The following steam turbine balance of plant modifications are included in the repowering project cost
estimate:
• New cascading type steam turbine bypass system to the existing condenser
• The condenser will be modified by removing the LP feedwater heaters and installing steam dump
lines for the new turbine bypass system
• New condensate pumps
• New main step-up transformer
• High side gas insulated breaker
• The existing auxiliary transformer will be retired
C1 HRSG Vendor Package
A heat recovery steam generator (HRSG) with integral deaerator, CO catalyst, and selective catalytic
reduction (SCR) is provided to accept the exhaust gases from each combustion turbine. The steam cycle
design is a triple pressure, reheat cycle with throttle steam conditions designed to accommodate the
requirements of the existing steam turbine operating at its new load point.
C2 HRSG Balance of Plant
The following items are included in the HRSG balance of plant:
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Appendix VII Northport Capital Cost Estimate Descriptions
• HRSG foundations
• Main steam piping
• Hot reheat steam piping
• Cold reheat steam piping
• LP steam piping
• Boiler feed water system with two 100-percent flow boiler feed water pumps per HRSG
• Stack, one common concrete shell 250 feet high with two 22 foot diameter flues
• Boiler blowdown system
• Boiler chemical feed system
• Steam/water sampling system
• Aqueous ammonia storage, 20,000 gallons (approximately 5 days)
• Aqueous ammonia vaporization skid, one per HRSG
D3 Fuel Oil Facilities
The distillate oil supply includes demolition of the existing dock west of unit 1 and installation of a new
dock for barge unloading including unloading pumps and piping. An existing No. 6 oil tank will be
demolished and replaced with a new 5,000,000 gallon distillate oil storage tank, sized for approximately
five days operation. The new storage tank will be equipped with distillate oil forwarding pumps.
D4 Onsite Natural Gas System
The natural gas supply system is comprised of fuel gas piping and fuel gas conditioning equipment such
as a scrubber, moisture separator, coalescing filters, filter /separator, and metering equipment for each
combustion turbine. The MHI 501G gas turbine utilizes a bleed from the main gas turbine compressor to
cool the power turbine blades. The compressor bleed air is first cooled in a fin-fan type cooler (TCA
cooler). Waste heat from the TCA cooler is used to heat the incoming fuel gas. This TCA heat exchanger
is provided as part of the gas turbine package. New, underground gas piping from a connection point at
the existing gas yard to the new units is included.
G5 Instruments and Controls
Existing equipment to be reused will be controlled by the new DCS. Existing field instruments,
transmitters, control drives will be reused. An allowance has been included in the repowering project cost
estimate for miscellaneous refurbishment/replacement of existing control components. The existing
uninterruptible power supply and battery system will remain in service for any existing equipment that
may not be connected to the new system.
This account includes the following required for the new combined cycle equipment:
• Distributed control system, including HRSG controls, combustion turbine generator controls,
boiler feed pump controls, computer for data acquisition and logging and controls for existing
equipment to be reused.
• Uninterruptible power supply and battery system sized to supply power for emergency controls
and safe plant shutdown.
March 30, 2009 246

• Continuous emissions monitoring system, one per HRSG
• Field instruments and controls
• Local control boards and panels
• Bulk installation materials
F Cooling System Area
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
It is assumed that cooling system modifications required to comply with 316b requirements will have
been accomplished before the repowering project is done. This will include converting the main
circulating water pumps to variable speed operation. The modified system will be reused for the
repowering project including trash racks, traveling screens, main circulating water pumps, concrete
circulating water piping, condenser, waterboxes, condenser air removal system, etc. An allowance has
been included in the repowering project cost estimate for miscellaneous refurbishment/replacement of
circulating water system components.
G1 Plant Electrical
The existing electrical equipment required for existing equipment that will remain in service will be
reused including 4160V switchgear, 480 V load centers, motor control centers, cable, raceway, lighting,
etc. An allowance has been included in the repowering project cost estimate for miscellaneous
refurbishment/replacement. The existing emergency generator will be retained.
This account includes the following required for the new combined cycle equipment:
• 4160 V switchgear
• 480 v load centers
• Motor control centers
• Non segregated bus duct
• Power cable and terminations
• Instrument cable and terminations
• Conduit and raceway
• Communications systems
• Security and surveillance system
• Fire detection system
G2 Yard Electrical
The existing yard electrical associated with the existing plant will be reused
This account includes required for the new combined cycle equipment:
• Yard lighting
• Cable tray and conduit
• Electrical duct bank
March 30, 2009 247

• Grounding and lightning protection
• Heat tracing
• Cathodic protection
E1 Site Development
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
This account includes the following required for new combined cycle equipment:
• Subsurface investigation
• Site preparation
• General excavation and backfill
• Piling
• Erosion control
• Roads and parking
• Fencing
• Landscaping
• Drainage
• Row of lighting poles to the north of existing road to be relocated (if required) to the new road.
• Buried communication line (possibly fiber optic) that runs north from a utility pole on the north
side of the existing road.
• Miscellaneous buried conduits that run north (or northwest) from a utility pole on the southeast
corner of the area.
• Storm drain on the north edge of the area.
• The existing recharge basin at the northwest corner of the area will be relocated
F1/F2 Water/Wastewater Treatment Area
The area includes:
• Makeup water supply and treatment systems consisting of two 100-percent makeup water supply
pumps, two-100% (130 gpm each) RO systems with electro deionization and including a
1,000,000 gallon storage tank for demineralized water. The tank will provide approximately 20
hours of storage when firing distillate oil and approximately 5 days of storage with natural gas
firing.
• Wastewater treatment for boiler blowdown, equipment washes, wastes and oily wastes from
equipment area drains; will be directed to the existing wastewater treatment facility. Drains for
plant equipment areas will be directed to oil/water separator(s) prior to discharge. Reject water
from the RO system will be directed to the inlet lagoon.
• It is assumed that the existing septic system(s) serving Unit 4 will be reused. A new septic
system is included for sanitary waste from the new administration building.
March 30, 2009 248

E3 Utilities
The following items are included in this account:
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
• New service and instrument air system connected to existing system
• Extension of the existing potable water system
• Extension of the existing service water system
• New fire protection system including dual fire pumps, jockey pump, and a 500,000 gallon
combination city water/firewater storage tank
PA Pipe Rack Module
Pipe rack from new HRSG’s to the south side of the Unit 4 turbine building including new high energy
and condensate piping
PW Miscellaneous Bulks-Plant Wide
This account includes the following:
• Miscellaneous equipment foundations
• Painting and protective finishes
• Pipe supports
• Nuts, bolts and gasket allowance
I/K Buildings
This account includes:
• Combustion turbine building
• Combustion turbine room crane
• HRSG building
• New administration, warehouse, water treatment and service/instrument air system building
• New fire pump house
• New auxiliary boiler building
• 4160 Power Distribution Control (PDC) buildings (one for each CT)
C5 Auxiliary Boiler
A 100,000 lb/hr auxiliary boiler including a boiler building will be provided to supply steam for
steam turbine and combustion turbine startup.
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Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
Backyard Repowering Option near Unit 1 - 3x3x1 7FB Combined Cycle
This section includes descriptive information for the backyard
repowering using a 3 x 3 x 1 7FB Un-fired design located north of
Unit 1. The plant utilizes three F class combustion turbines (GE 7FB
used for study purposes). A heat recovery steam generator (HRSG) is
provided for each combustion turbine. The plant has a single steam
turbine exhausting to an air cooled condenser. The plant will have a
nominal capacity (ISO) of 825 MW.
Plant Description
The GE 7FB combustion turbine is based on the GE 7FA combustion turbine with higher firing
temperatures extrapolated from data taken during the development of GE’s H technology. The 7FA has
the longest operating history of the advanced, high efficiency combustion turbines and the performance of
the most recent units indicates that it is a proven, low risk design. Figure 1 is a schematic illustration of
the GE 7FB combined cycle plants.
Natural
Natural
Gas
Gas
Metering Metering &
&
Conditioning
Conditioning
Distillate
Distillate
Oil
Oil
Storage Storage &
&
Handling
Handling
Water
Water
Water
Water
Treatment
Treatment
M
G
Figure 1 - Backyard Plant Schematic
CT
ACC = Air-cooled Condenser
CP = Condensate Pump
CT = Combustion Turbine
G = Generator
HRSG = Heat Recovery Steam Generator
M = Main Step-up Transformer
S = Stack
ST = Steam Turbine
M G CT
G M
M
G
CT
March 30, 2009 250
HRSG
HRSG
HRSG
S
S
S
ST
CP
ACC

Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
The plant is designed to operate on natural gas fuel as the primary fuel with distillate oil back up, using
dry, low NOx combustion and selective catalytic reduction for NOx control. When firing oil, water
injection is required to reduce the NOx produced by the combustion turbine. The units are to be designed
for an evaporative cooler with 85% effectiveness.
The following sections describe major plant characteristics and the facilities. This description is
organized by the list of accounts in the cost and performance models.
A0 Demolition
Demolition and/or relocation of existing equipment is included as described below:
• Remove existing No. 6 oil tank
• Relocate two existing septic systems
A1 Combustion Turbine Vendor Package
The 7FB combustion turbines are equipped with a dry, low NOx combustor which limits NOx when firing
gas to 25 ppm and with water injection reduces NOx when firing oil to 42 ppm. The combustion turbines
and generators will be enclosed in a turbine building.
Each combustion turbine package includes:
• Pulse jet inlet air filter
• Inlet silencer
• Evaporative cooler
• Air processing unit
• Static starting system
• Fuel skid
• Anti-icing inlet air heating system
• Water injection skid
• On-line and off-line compressor water wash system
• Fire protection (CO2) and fire detection systems
• Lube oil system
• Static exciter
• MARK VI control system with control options for combined cycle application, e.g. temperature
matching, external speed set point and high steam temperature protection
• Vibration (Bently Nevada 3500) and temperature monitoring
• Batteries and battery charger
A1 Combustion Turbine Balance of Plant
Each combustion turbine balance of plant includes:
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• Combustion turbine foundation
• Step up transformers 13.8 to 345 kV (one for each CT)
• Auxiliary transformers (one for each CT)
• Generator breakers (one for each CT)
• High side gas insulated breakers
• Generator hydrogen and CO system
2
• Associated electrical connections, metering and protection
• Oily water collection system
• Wash water drain tank and pumps
• Lube oil collection system
B1 Steam Turbine Vendor Package
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
A nominal 300 MW down exhaust reheat steam turbine with throttle steam conditions of 1900 psig,
1050ºF and a single low pressure admission point. The turbine has a hydrogen cooled electric generator.
The steam turbine includes:
• Hydraulically operated main steam valves consisting of partial arc admission valves with a
common emergency stop valve.
• Hydraulically operated governing control and stop valves for reheat and LP admission steam
• Strainers for valves, steam traps and drain valves
• Exhaust casing relief diaphragm(s)
• Vacuum breaker
• Exhaust hood spray system
• Turning gear
• Noise enclosure
• Complete, fault-tolerant, electrohydraulic control (EHC) system with
o Vibration probes, axial position probes and monitoring system.
o Dual redundant differential expansion measurement
o Bentley Nevada TDXNET Module
• Lube oil conditioning system
• Static excitation system
B1 Steam Turbine Balance of Plant
The following equipment is part of the steam turbine balance of plant:
• Steam turbine foundation and pedestal
• Lube oil system
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Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
• Gland Seal and Exhaust system
• Bypass steam system
• Condenser air removal system
• Condensate system including tank and two 100% capacity condensate pumps
• Hydrogen system
• CO system
2
• Nitrogen system
• Closed cycle cooling water system including a 20 cell fin-fan cooler sized for all new equipment
cooling requirements including steam turbine generator
• Main step up transformer 13.8 to 345kV
• High side gas insulated breaker
• Generator synchronizing
• Generator and transformer protection
• Fire protection for steam turbine area
C4 HRSG Vendor Package
A heat recovery steam generator (HRSG) with integral deaerator, CO catalyst and selective catalytic
reduction (SCR) is provided to accept the exhaust gases from each combustion turbine. The steam cycle
design is a triple pressure, reheat cycle with throttle steam conditions of 1900 psig, 1050ºF.
C4 HRSG Balance of Plant
The following items are included in the HRSG balance of plant:
• HRSG foundations
• Main steam piping
• Hot reheat steam piping
• Cold reheat steam piping
• LP steam piping
• Boiler feed water system with two 100-percent flow boiler feed water pumps per HRSG
• Stack, common concrete shell 275 feet high with three 18 foot diameter flues
• Boiler blowdown system
• Boiler chemical feed system
• Steam/water sampling system
• Aqueous ammonia storage, 25,000 gallon (approximately 5 days)
• Aqueous ammonia vaporization skid, one per HRSG
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D3 Fuel Oil facilities
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
The distillate oil supply includes demolition of the existing dock west of unit 1 and installation of a new
dock for barge unloading including unloading pumps and piping. An existing No. 6 oil tank will be
demolished and replaced with a new 5,000,000 gallon distillate oil storage tank sized for approximately
five days operation. The new storage tank will be equipped with distillate oil forwarding pumps.
D3 Onsite Natural Gas System
The natural gas supply system is comprised of fuel gas piping and fuel gas conditioning equipment such
as a scrubber, moisture separator, coalescing filters, filter /separator, metering equipment and fuel gas
heaters. New, underground gas piping from a connection point at the existing gas yard to the new units is
included.
G5 Plant Instruments and Controls
This account includes:
• Distributed control system, including HRSG controls, turbine generator controls, boiler feed
pump controls, and computer for data acquisition and logging.
• Continuous emissions monitoring system, one per HRSG
• Field instruments and controls
• Local control boards and panels
• Bulk installation materials
F Cooling Area
This account includes:
• Air-cooled condenser
• Foundation
• Air cooled condenser electrical building
• Condensate tank
G1 Plant Electrical
This account includes the following:
• 4160V switchgear
• 480 v load centers
• Motor control centers
• Non segregated bus duct
• Power cable and terminations
• Instrument cable and terminations
• Conduit and raceway
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Appendix VII Northport Capital Cost Estimate Descriptions
• Communications systems
• Security and surveillance system
• Fire detection system
• Uninterruptible power supply and battery system sized to supply power for emergency controls
and safe plant shutdown.
G1 Yard Electrical
This account includes:
• Yard lighting
• Cable tray and conduit
• Electrical duct bank
• Grounding and lightning protection
• Heat tracing
• Cathodic protection
E1 Site Development
This account includes:
• Subsurface investigation
• Site preparation
• General excavation and backfill
• Piling
• Erosion control
• Roads and parking
• Fencing
• Landscaping
• Drainage
F1/F2 Water/Wastewater Treatment Area
The area includes:
• Makeup water supply and treatment systems consisting of two 100-percent makeup water supply
pumps, two 100% (130 gpm each) RO systems with electro deionization and including a
1,000,000 gallon storage tank for demineralized water. The tank will provide approximately 20
hours storage when firing distillate oil and approximately 5 days storage with natural gas firing.
• Wastewater treatment for boiler blowdown, equipment washes, demineralizer regeneration wastes
and oily wastes from equipment area drains; will be directed to the existing wastewater treatment
facility. Drains for plant equipment areas will be directed to oil/water separator(s) prior to
discharge. Reject water
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Appendix VII Northport Capital Cost Estimate Descriptions
• A new septic system is included for sanitary waste from the new administration building.
E3 Utilities
The following items are included in this account:
• Service and instrument air system
• Potable water
• Service water system including two pumps
• Yard fire protection system including pump house with dual motor driven fire pumps, jockey
pump, combination 500,000 gallon city water/firewater storage tank and hydrants, deluge
systems; and hoses
PA Pipe Rack Module
Pipe rack from HRSG’s to steam turbine including high energy piping.
PW Miscellaneous Bulks-Plant Wide
This account includes the following:
• Miscellaneous equipment foundations
• Painting and protective finishes
• Pipe supports
• Nuts, bolts and gasket allowance
I/K Buildings and Structures
This account includes:
• Administration, control room, warehouse, water treatment, and service/instrument air systems
building
• Combustion turbine building
• Combustion turbine room crane
• Steam turbine building
• Steam turbine room crane
• HRSG building
• New fire pump house
• 4160 Power Distribution Control (PDC) buildings (one for each CT)
March 30, 2009 256

C5 Auxiliary Boiler
Re-powering Study for the Northport and Port Jefferson Power Stations
Appendix VII Northport Capital Cost Estimate Descriptions
A 50,000 lb/hr auxiliary boiler including a boiler building will be provided to supply steam for
steam turbine startup.
March 30, 2009 257