Laughing Bear
OPERATING PROCEDURE
|Electric Generator System |
| |
|UNIT 8 |
TABLE OF CONTENTS
Section Page
1.0 Introduction 1
1.1 Purpose and Scope 1
1.2 System Identification and Scope Definition 1
2.0 SYSTEM STARTUP 1
2.1 Preoperational Procedures 1
2.1.1 Prerequisites 1
2.1.2 Prestart Requirements 1
2.2 Precautions and Limitations 2
2.3 Electric Generator System Block Flow Diagram 2
2.3.1 Electric Generator Auxiliary Systems 2
2.3.2 Electric Generator Synchronization 4
2.4 Replacing Generator Air with Carbon Dioxide 7
2.5 Replacing Generator Carbon Dioxide with Hydrogen 7
2.6 Placing the Generator Seal Oil System in Service 8
2.7 Manual Synchronization of Generator 9
2.8 Automatic Synchronization of Generator 11
3.0 SYSTEM NORMAL OPERATION 13
3.1 System Routine Checks 13
4.0 SYSTEM ABNORMAL OPERATION 14
4.1 Gas Dryer Reactivation 14
5.0 SYSTEM SHUTDOWN 14
5.1 Electric Generator Shutdown 14
5.2 Removing Seal Oil System from Service 15
5.3 Purging Generator Hydrogen with Carbon Dioxide 15
5.4 Replacing Generator Carbon Dioxide with Air 16
5.5 System Post-Shutdown Checklist 17
5.5.1 Short Term 17
5.5.2 Long Term 17
6.0 ALARM RESPONSES 17
6.1 Summary of Alarms 17
7.0 CHECKLISTS AND TABLES 48
Table 1 - Power Supply Checklist 48
Table 2 - Prestart Valve Lineup Checklist 48
Table 3 - Local Indicating Instruments 50
Table 4 - Control Room Indicating Instruments 51
8.0 REFERENCES 51
8.1 P&ID 51
8.2 Electrical One Line Diagrams 52
8.3 Control Diagrams 52
8.4 Instrument Loop Diagrams 52
8.5 Instruction Manuals 53
8.6 Miscellaneous 53
1. Introduction
1. PURPOSE AND SCOPE
The purpose of this operating procedure is to provide the operator with specific procedures for operating the Electric Generator and Associated Systems. The operating procedures include those detailed procedures required to start up, operate, and shut down the Steam Turbine System in a logical, efficient, and safe manner. The steam turbine system supplies the rotational energy required by the generator to create electrical energy. The operating procedure includes the following sections:
➢ Section 2.0 - System Startup
➢ Section 3.0 - Normal Operations
➢ Section 4.0 - System Abnormal Operations
➢ Section 5.0 - System Shutdown
➢ Section 6.0 - Alarm responses
➢ Section 7.0 - Checklists and Tables
2. System Identification and Scope Definition
The Electric Generator System takes the mechanical, rotational energy provided by natural gas and steam and converts the energy into electric energy, or power. The system contains the following subsystems and major components:
a. Electric Generator - Gas
b. Electric Generator - Steam
c. Exciter
d. Seal Oil System
e. Gas System
Operation of the Combustion Turbine Generator is described in these procedures. The operation of the steam turbine generator and the combustion turbine generator are virtually identical, except that the steam turbine generator is air-cooled and does not use the Generator Seal Oil System or the Generator Gas System. When operating the steam turbine generator, disregard steps that apply to the Generator Seal Oil and Generator Gas Systems.
2. SYSTEM STARTUP
1. PREOPERATIONAL PROCEDURES
1. Prerequisites
a. The 125 VDC electrical distribution system is in service.
b. The 480 VAC electrical distribution system is in service.
c. The compressed air system is in service.
d. The circulating water system is in service.
e. The steam turbine and auxiliary system are ready for service.
f. The fire protection system is in service.
g. The main steam system is in service.
h. The steam generation system is in service.
i. The condensate cooling system is in service.
j. The condensate and feedwater systems are in service.
2. Prestart Requirements
a. All clearances are released and the equipment is in safe operating condition.
k. The power supply lineup is correct per Table 1
l. The prestart valve lineup is correct per Table 2.
m. All system instrumentation is available per Tables 3 and 4.
n. There are sufficient quantities of hydrogen and carbon dioxide on hand for filling the generator.
2. Precautions and Limitations
THE FOLLOWING PRECAUTIONS ARE SYSTEM SPECIFIC OPERATIONAL CONSIDERATIONS THAT MUST BE CLOSELY FOLLOWED. FAILURE TO FOLLOW THESE PRECAUTIONS MAY RESULT IN PERSONNEL INJURY OR EQUIPMENT DAMAGE.
a. All pumps and heat exchangers must be filled and vented to ensure proper and efficient operation.
o. The discharge valve on a positive displacement pump must be open prior to starting the pump.
p. Absolutely no smoking or open flames are allowed in any areas of the hydrogen system.
q. Immediately report any suspected hydrogen leaks. Leaks in the gas piping should be corrected immediately. A mixture of hydrogen in air is explosive from 4 to 74 percent by volume.
r. Carbon dioxide must always be used as the scavenging medium to remove air or hydrogen from the generator. NEVER add air to hydrogen or hydrogen to air.
s. Carbon dioxide is odorless, colorless, and tasteless. It is non-toxic but can cause asphyxiation because it displaces oxygen in confined spaces. Do not allow anyone to enter the generator until it is verified that the generator atmosphere is suitable for breathing.
t. The generator seals must be supplied with oil whenever the shaft is rotating.
u. The generator seals must be supplied with oil whenever there is hydrogen in the generator.
3. Electric Generator System Block Flow Diagram
1. Electric Generator Auxiliary Systems
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2. Electric Generator Synchronization
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4. Replacing Generator Air with Carbon Dioxide
|ACTION |LOC |VERIFICATION |
|NOTE: The LOC column in this procedure specifies where the associated ACTION step is taken. A "C" step is performed in the Control Room, an "L"|
|step is performed locally, and an "L/P" step is performed at a local panel. A "C/L" or "L/C" step indicates a combination of Control Room and |
|local activities. |
|1. VERIFY all gas system valves are aligned per Table 2. |L | |
|2. DISCONNECT the hydrogen supply line removable link. |L | |
|3. PLACE blanks on link flanges. |L | |
|4. CLOSE valves 1, 3, 8, and 50. |L |Valves are closed |
|5. OPEN valves 2, 4, 5, and 7. |L |Valves are open. |
|6. OPEN CO2 bottle supply valves. |L |Valves are open. |
|7. OPEN valve 60. |L |Valve is open. |
|8. VERIFY carbon dioxide pressure on bottle header gauge. |L | |
|9. VERIFY the purity meter on the Hydrogen Control Panel goes to |L |Hydrogen Control Panel purity meter. |
|95% or greater CO2. | | |
|10. CLOSE CO2 bottle supply valves. |L |Valves are open. |
|11. CLOSE valve 60. |L |Valve is closed. |
|12. CLOSE valves 2, 4, 5, and 7. |L |Valves are closed. |
|13. OPEN valves 1 and 3. |L |Valves are open. |
5. Replacing Generator Carbon Dioxide with Hydrogen
|ACTION |LOC |VERIFICATION |
|NOTE: The LOC column in this procedure specifies where the associated ACTION step is taken. A "C" step is performed in the Control Room, an "L"|
|step is performed locally, and an "L/P" step is performed at a local panel. A "C/L" or "L/C" step indicates a combination of Control Room and |
|local activities. |
|1. REMOVE the hydrogen line removable link blanks. |L | |
|2. REPLACE the hydrogen removable link. |L | |
|3. OPEN valves 6, 8 and 53. |L |Valves are open. |
|4. OPEN valve 50. |L |Valve is open. |
|NOTE: In an emergency filling situation, valve 52 can be used to fill the generator faster. |
|5. ADJUST hydrogen pressure regulator to supply 60 psig hydrogen.|L | |
|6. VERIFY the purity meter value reads 95% or greater hydrogen. |L |Hydrogen control panel purity meter. |
|7. CLOSE valve 6. |L |Valve is closed. |
|8. OPEN valve 24 for 2 minutes and then CLOSE valve. |L | |
|9. ADJUST the hydrogen regulator as required to maintain the |L | |
|proper hydrogen pressure. | | |
|10. VERIFY the generator gas system maintains the proper hydrogen|L/C |Hydrogen Control Panel or indicators in control room. |
|pressure and purity in the generator. | | |
6. Placing the Generator Seal Oil System in Service
|ACTION |LOC |VERIFICATION |
|NOTE: The LOC column in this procedure specifies where the associated ACTION step is taken. A "C" step is performed in the Control Room, an "L"|
|step is performed locally, and an "L/P" step is performed at a local panel. A "C/L" or "L/C" step indicates a combination of Control Room and |
|local activities. |
|1. VERIFY electrical lineup per Table 1. |L | |
|2. VERIFY the seal oil system valves are aligned per Table 2. |L | |
|3. CLOSE turbine lube oil backup supply valves, 263 and 265. |L |Valves closed. |
|4. START the air side seal oil pump. |L |RED indicating light illuminates. |
| | |Pressure increases on local pressure indicator. |
|5. VERIFY hydrogen side drain regulator level increases. |L |Local level gauge. |
|6. VERIFY hydrogen side drain regulator level is maintained by |L |Local level gauge. |
|drain (231) and fill (232) valves. | | |
|7. CLOSE air side seal oil outlet valve (254). |L |Valve is closed. |
|8. ADJUST the air side seal oil pump relief valve (258) until the|L |Local pressure indicator. |
|pressure indicator reads 100 psig. | | |
|9. OPEN air side seal oil outlet valve (254). |L |Valve is open. |
|10. ADJUST the differential pressure regulator (256) to bring air|L |Air side seal oil pressure indicator. |
|side seal oil pressure to 12 psig above gas pressure. | | |
|11. START the hydrogen side seal oil pump. |L |RED indicating light illuminates. |
| | |Pressure increases on local pressure indicator. |
|12. CLOSE hydrogen side seal oil valves 211 and 218. |L |Valves are closed. |
|13. CLOSE hydrogen side seal oil recirc valve 242. |L |Valve is closed. |
|14. ADJUST the hydrogen side seal oil pump relief valve (243) |L |Local pressure indicator. |
|until the pressure indicator reads 100 psig. | | |
|15. OPEN hydrogen side seal oil valves 211, 218, and 242. |L |Valves are open. |
|16. ADJUST regulating valves 210 and 217 until the associated |L |Local pressure gauges. |
|pressure gauges read ± 2" H2O. | | |
|17. ADJUST the backup main oil pressure regulating valve (291) to|L |Local pressure indicator |
|a 125 psig outlet. | | |
|18. OPEN turbine oil backup supply valves 263 and 265. |L |Valves are open. |
|19. STOP the air side seal oil pump. |L |Green indicating light illuminates. |
| | |Pressure decreases on local pressure indicator. |
| | |AIR SIDE SEAL OIL PUMP OFF alarm annunciates at the Hydrogen |
| | |Control Panel. |
|20. ADJUST the backup supply regulator (264) to maintain the seal|L |Local pressure indicators. |
|oil supply at 8 psig above hydrogen pressure. | | |
|21. RESTART the air side seal oil pump. |L |RED indicating light is illuminated. |
| | |Pressure increases on local pressure indicator. |
|22. OPEN pressure switch PS-8 test valve (274). |L | |
|23. When pressure on associate indicator reaches 5 psi, VERIFY |L |RED indicating light illuminates. |
|the air side seal oil backup pump starts. | |BACKUP SEAL OIL PUMP RUNNING alarm is annunciated at the Hydrogen|
| | |Control Panel. |
|24. CLOSE pressure switch PS-8 test valve (274). |L | |
|25. STOP the air side seal oil backup pump. |L |GREEN indicating light illuminates. |
|26. STOP the hydrogen side seal oil pump. |L |GREEN indicating light is illuminated. |
| | |Pressure decreases on local pressure indicator. |
|27. VERIFY the HYDROGEN SIDE SEAL OIL PUMP OFF alarm at the |L |Alarm annunciates. |
|Hydrogen Control Panel. | | |
|28. RESTART the hydrogen side seal oil pump. |L |RED indicating light illuminates. |
| | |Pressure increases on local pressure indicator. |
7. Manual Synchronization of Generator
|ACTION |LOC |VERIFICATION |
|NOTE: The LOC column in this procedure specifies where the associated ACTION step is taken. A "C" step is performed in the Control Room, an "L"|
|step is performed locally, and an "L/P" step is performed at a local panel. A "C/L" or "L/C" step indicates a combination of Control Room and |
|local activities. |
|NOTE: This procedure is not a stand along procedure and should be used in conjunction with the Steam Turbine Operating Procedure, 2-ST-OP. The |
|Steam Turbine Operating Procedure will instruct the operator when the generator is ready for synchronization. |
|1. VERIFY the generator is filled with hydrogen with at least 95%|L/C |Local or control room indicators. |
|purity and a pressure of 50 psig. | | |
|2. VERIFY the generator seal oil system is in service per section|L/C | |
|2.6 of this procedure. | | |
|3. VERIFY the turbine is at synchronous speed, 3,600 rpm. |L/C |Speed indicators. |
|4. VERIFY the generator is ready for synchronization, per |L/C | |
|2-ST-OP. | | |
|5. CLOSE the generator field breaker. |C |Pistol grip switch on BTG. |
| | |RED indicating light illuminates on BTG. |
| | |CLOSE flag indicated on control switch. |
|6. VERIFY the field voltage rises to the no load value. |C |Control room indicator. |
|7. PLACE the synchroscope to the bus that will be synchronized, |C |Switch in position. |
|east or west. | | |
|8. PLACE the synchronizing bus switch for the proper bus in the |C |Switch in MANUAL. |
|MANUAL position. | | |
|9. VERIFY the power transformer disconnects are closed. |L | |
|10. ADJUST the "INCOMING" voltage slightly higher than the |C |Incoming and running voltage meters. |
|"RUNNING" voltage by 200 - 400 volts. | | |
|11. ADJUST turbine speed slightly above system frequency. |C |Synchroscope moving slowly in the clockwise direction. |
|CAUTION |
| |
|IT IS IMPORTANT THAT THERE ARE NO DISTRACTIONS OR CONVERSATIONS WHEN |
|THE OPERATOR IS PREPARING TO SYNCHRONIZE THE GENERATOR. |
|STRICT ATTENTION TO PROCEDURES MUST BE OBSERVED. |
|12. When the scope hand reaches the 12 o'clock position, CLOSE |C |Pistol grip switch on BTG. |
|the selected generator breaker, east (HP112) or west (HP113). | |RED indicating light illuminates on BTG. |
| | |CLOSE flag indicated on control switch. |
|13. CLOSE the remaining generator breaker. |C |Pistol grip switch on BTG. |
| | |RED indicating light illuminates on BTG. |
| | |CLOSE flag indicated on control switch. |
|Note: The unit will be held for 30 minutes at 5% of rated load, plus one minute for every degree of throttle steam inlet temperature change. |
|14. RAISE load of generator to 5% for the hold period. |C | |
|15. PLACE the voltage (WTA) regulator in service. |C |Switch in ON position. |
| | |RED indicating light illuminates. |
|16. VERIFY generator operation. |C |Voltage and ammeters in control room. |
|17. INCREASE load as desired using the Steam Turbine Operating |C/L | |
|Procedure, 2-ST-OP. | | |
|NOTE: The following steps are adjustments that must be made to the seal oil system once the generator has been synchronized. |
|18. VERIFY the seal oil coolers are maintaining seal oil |L |Local temperature indicators. |
|temperatures between 80 and 120 F. | | |
|19. READJUST the differential seal oil pressure regulator (256), |L |Local pressure indicator. |
|if necessary, to establish seal oil pressure 12 psi above the | | |
|hydrogen gas pressure. | | |
|20. OPEN seal oil hydrogen side recirculation valve until |L | |
|pressure indicators give a steady reading. | | |
|21. ADJUST regulating valves 210 and 217 until the associated |L |Local pressure gauges. |
|pressure gauges read ± 2" H2O. | | |
8. Automatic Synchronization of Generator
|ACTION |LOC |VERIFICATION |
|NOTE: The LOC column in this procedure specifies where the associated ACTION step is taken. A "C" step is performed in the Control Room, an "L"|
|step is performed locally, and an "L/P" step is performed at a local panel. A "C/L" or "L/C" step indicates a combination of Control Room and |
|local activities. |
|NOTE: This procedure is not a stand along procedure and should be used in conjunction with the Steam Turbine Operating Procedure, 2-ST-OP. The |
|Steam Turbine Operating Procedure will instruct the operator when the generator is ready for synchronization. |
|1. VERIFY the generator is filled with hydrogen with at least 95%|L/C |Local or control room indicators. |
|purity and a pressure of 50 psig. | | |
|2. VERIFY the generator seal oil system is in service per section|L/C | |
|2.5 of this procedure. | | |
|3. VERIFY the turbine is at synchronous speed, 3,600 rpm. |L/C |Speed indicators. |
|4. VERIFY the generator is ready for synchronization, per |L/C | |
|2-ST-OP. | | |
|5. CLOSE the generator field breaker. |C |Pistol grip switch on BTG. |
| | |RED indicating light illuminates on BTG. |
| | |CLOSE flag indicated on control switch. |
|6. VERIFY the field voltage rises to the no load value. |C |Control room indicator. |
|7. PLACE the synchroscope to the bus that will be synchronized, |C |Switch in position. |
|east or west. | | |
|9. VERIFY the power transformer disconnects are closed. |L | |
|10. ADJUST the "INCOMING" voltage slightly higher than the |C |Incoming and running voltage meters. |
|"RUNNING" voltage by 200 - 400 volts. | | |
|11. ADJUST turbine speed slightly above system frequency. |C |Synchroscope moving slowly in the clockwise direction. |
|CAUTION |
| |
|IT IS IMPORTANT THAT THERE ARE NO DISTRACTIONS OR CONVERSATIONS WHEN |
|THE OPERATOR IS PREPARING TO SYNCHRONIZE THE GENERATOR. |
|STRICT ATTENTION TO PROCEDURES MUST BE OBSERVED. |
|12. When the scope hand reaches the 12 o'clock position, VERIFY |C |RED indicating light illuminates on BTG. |
|the selected bus generator breaker closes, east (HP112) or west | |CLOSE flag indicated on control switch. |
|(HP113). | | |
|13. PLACE the synchronizing bus switch for the remaining bus in |C |Switch in AUTO. |
|the AUTO position. | | |
|14. VERIFY the remaining bus generator breaker closes, east |C |RED indicating light illuminates on BTG. |
|(HP112) or west (HP113). | |CLOSE flag indicated on control switch. |
|Note: The unit will be held for 30 minutes at 5% of rated load, plus one minute for every degree of throttle steam inlet temperature change. |
|15. RAISE load of generator to 5% for the hold period. |C | |
|16. PLACE the voltage (WTA) regulator in service. |C |Switch in ON position. |
| | |RED indicating light illuminates. |
|17. VERIFY generator operation. |C |Voltage and ammeters in control room. |
|18. INCREASE load as desired using the Steam Turbine Operating |C/L | |
|Procedure, 2-ST-OP. | | |
|NOTE: The following steps are adjustments that must be made to the seal oil system once the generator has been synchronized. |
|19. VERIFY the seal oil coolers are maintaining seal oil |L |Local temperature indicators. |
|temperatures between 80 and 120 F. | | |
|20. READJUST the differential seal oil pressure regulator (256), |L |Local pressure indicator. |
|if necessary, to establish seal oil pressure 12 psi above the | | |
|hydrogen gas pressure. | | |
|21. OPEN seal oil hydrogen side recirculation valve until |L | |
|pressure indicators give a steady reading. | | |
|22. ADJUST regulating valves 210 and 217 until the associated |L |Local pressure gauges. |
|pressure gauges read ± 2" H2O. | | |
3. SYSTEM NORMAL OPERATION
1. SYSTEM ROUTINE CHECKS
|ACTION |LOC |VERIFICATION |
|NOTE: The LOC column in this procedure specifies where the associated ACTION step is taken. A "C" step is performed in the Control Room, an "L"|
|step is performed locally, and an "L/P" step is performed at a local panel. A "C/L" or "L/C" step indicates a combination of Control Room and |
|local activities. |
|NOTE: Proper operation of plant equipment will lead to increased availability, sustained performance, and extended life of the equipment, while |
|reducing the chance of failure. Proper operations include close adherence to operating procedures when starting the equipment, proper |
|monitoring and inspections when the equipment is in normal operation, and following proper operating procedures when shutting down. |
|1. CHECK all indication listed in Tables 3 and 4, Local and |C/L |Verify each is within the normal operating range. |
|Control Room Indicating Instruments. | | |
|2. CHECK the generator for unusual noises or vibrations. |L |No unusual noises or vibrations. |
|3. VERIFY hydrogen side seal oil pump operation. |L | Check the bearings. |
| | |Check for signs of leaks. |
| | |Check motor/pump coupling. |
| | |Check for abnormal noises or vibration. |
|4. VERIFY air side seal oil pump operation. |L | Check the bearings. |
| | |Check for signs of leaks. |
| | |Check motor/pump coupling. |
| | |Check for abnormal noises or vibration. |
|5. VERIFY generator seal oil vapor extractor operation. |L | Check the bearings. |
| | |Check motor/extractor coupling. |
| | |Check for abnormal noises or vibration. |
|6. VERIFY hydrogen side seal oil drain regulator operation. |L | Check the level. |
| | |Check for signs of leaks. |
| | |Check for valve/float malfunction. |
|7. VERIFY seal oil coolers operation. |L |Temperature between 80 and 120 F. |
|8. ADJUST the seal oil regulating valves as require to maintain |L | Valve 256 maintains 12 psi difference. |
|the proper seal pressure. | |Valves 210 and 217 maintain ± 2" H2O. |
|9. Once per shift, ROTATE the seal oil knife filter handles. |L | |
|10. VERIFY gas dryer operation and if required REACTIVATE per |L | Check the two-way valves. |
|section 4.1 of this procedure. | |Check for depleted (gray) desiccant. |
| | |Check for gas leakage. |
|11. VERIFY the hydrogen control panel operation. |L | Check purity blower operation. |
| | |Test the annunciators. |
4. SYSTEM ABNORMAL OPERATION
1. GAS DRYER REACTIVATION
|ACTION |LOC |VERIFICATION |
|NOTE: The LOC column in this procedure specifies where the associated ACTION step is taken. A "C" step is performed in the Control Room, an "L"|
|step is performed locally, and an "L/P" step is performed at a local panel. A "C/L" or "L/C" step indicates a combination of Control Room and |
|local activities. |
|NOTE: The gas dryer should be reactivated when the crystals turn gray and have become saturated. |
|1. PLACE the gas dryer inlet and outlet two-way valves (20 and |L |Lever in upper position. |
|21) lever in the reactivating, or upper, position. | | |
|2. START reactivation blower. |L |Blower switch in ON position. |
|3. START reactivation heater. |L |Heater switch in ON position. |
|4. REACTIVATE gas dryer for 4 hours, or until the crystals turn |L |Observation port indicates crystal color. |
|blue. | | |
|5. STOP reactivation heater. |L |Heater switch in OFF position. |
|6. STOP reactivation blower. |L |Blower Switch in OFF position. |
|7. PLACE the gas dryer inlet and outlet two-way valves (20 and |L |Lever in lower position. |
|21) lever in the operating, or lower, position. | | |
5. SYSTEM SHUTDOWN
1. ELECTRIC GENERATOR SHUTDOWN
|ACTION |LOC |VERIFICATION |
|NOTE: The LOC column in this procedure specifies where the associated ACTION step is taken. A "C" step is performed in the Control Room, an "L"|
|step is performed locally, and an "L/P" step is performed at a local panel. A "C/L" or "L/C" step indicates a combination of Control Room and |
|local activities. |
|NOTE: The electric generator shutdown is performed in conjunction with the steam turbine shutdown, as outlined in 2-ST-OP. |
|1. VERIFY the generator is no longer required for service. |L/C | |
|2. REDUCE generator load to 5% per steam turbine operating |L/C | |
|procedure. | | |
|3. REMOVE voltage regulator from service. |C |GREEN indicating light illuminates. |
|4. ADJUST voltage and base of WTA as required. |C | |
|5. OPEN both generator breakers. |C |GREEN indicating lights illuminate. |
| | |GREEN flags indicate at switches. |
|6. REMOVE voltage from the field. |C | |
|7. OPEN generator field breaker. |C |GREEN indicating light illuminates. |
| | |GREEN flag indication at switch. |
|8. If required, TRIP or SHUTDOWN steam turbine per 2-ST-OP. |C/L | |
|9. REPLACE hydrogen with carbon dioxide per section 5.3. | | |
|10. If required, SHUTDOWN the seal oil system per section 5.2. | | |
|11. For extended shutdown, FILL the generator with air per | | |
|section 5.4. | | |
2. Removing Seal Oil System from Service
|ACTION |LOC |VERIFICATION |
|NOTE: The LOC column in this procedure specifies where the associated ACTION step is taken. A "C" step is performed in the Control Room, an "L"|
|step is performed locally, and an "L/P" step is performed at a local panel. A "C/L" or "L/C" step indicates a combination of Control Room and |
|local activities. |
|1. VERIFY the generator seal oil system is no longer required for|L/C | |
|service. | | |
|2. STOP the hydrogen side seal oil pump. |L |GREEN indicating light is illuminated. |
| | |Pressure decreases on local pressure indicator. |
| | |HYDROGEN SIDE SEAL OIL PUMP OFF alarm annunciates at the Hydrogen|
| | |Control Panel. |
|3. STOP the air side seal oil pump. |L |GREEN indicating light illuminates. |
| | |Pressure decreases on local pressure indicator. |
| | |AIR SIDE SEAL OIL PUMP OFF alarm annunciates at the Hydrogen |
| | |Control Panel. |
|4. When pressure on associate indicator reaches 5 psi, VERIFY the|L |RED indicating light illuminates. |
|air side seal oil backup pump starts. | |BACKUP SEAL OIL PUMP RUNNING alarm is annunciated at the Hydrogen|
| | |Control Panel. |
|5. STOP the air side seal oil backup pump. |L |GREEN indicating light illuminates. |
| | |Pressure decreases on local pressure indicator. |
|6. CLOSE turbine seal oil backup supply valves 263 and 265. |L |Valves close. |
|7. VERIFY the seal oil pressure decrease to 0. |L |Local pressure indicators. |
|8. CLOSE condensate cooling water valves to and from seal oil |L |Valves are closed. |
|coolers. | | |
|9. STOP the generator seal oil vapor extractor. |L/C |GREEN indicating lights illuminated at local and remote switches.|
3. Purging Generator Hydrogen with Carbon Dioxide
|ACTION |LOC |VERIFICATION |
|NOTE: The LOC column in this procedure specifies where the associated ACTION step is taken. A "C" step is performed in the Control Room, an "L"|
|step is performed locally, and an "L/P" step is performed at a local panel. A "C/L" or "L/C" step indicates a combination of Control Room and |
|local activities. |
|NOTE: This procedure will be performed with the generator unit at standstill or while on the turning gear. |
|1. OPEN meter sampling valves 2 and 4. |L |Valves are open. |
|2. CLOSE meter sampling valves 1 and 3. |L |Valves are closed. |
|3. CLOSE hydrogen feed valves 8 and 50. |L |Valves are closed. |
|4. DISCONNECT the hydrogen supply line removable link. |L | |
|5. PLACE blanks on link flanges. |L | |
|6. OPEN hydrogen vent valve 7. |L |Valve is open. |
|7. OPEN carbon dioxide bottle supply valves (63 - 66) and block |L |Valve is open. |
|valve (60). | | |
|8. OPEN carbon dioxide generator block valve (5). |L |Valve is open. |
|9. VERIFY gas pressure does not exceed 3 - 5 psig during carbon |L |Gas pressure indicator. |
|dioxide admission. | | |
|10. When the purity meter reads 95% CO2, or greater, CLOSE the |L |Valves are closed. |
|carbon dioxide bottle supply valves (63-66) and supply block | | |
|valves (60 and 5) | | |
4. Replacing Generator Carbon Dioxide with Air
|ACTION |LOC |VERIFICATION |
|NOTE: The LOC column in this procedure specifies where the associated ACTION step is taken. A "C" step is performed in the Control Room, an "L"|
|step is performed locally, and an "L/P" step is performed at a local panel. A "C/L" or "L/C" step indicates a combination of Control Room and |
|local activities. |
|NOTE: This procedure will be performed when the generator is at standstill prior to opening the generator for inspection/maintenance. |
|1. VERIFY the seal oil system is removed from service per section|L/C | |
|5.2 of this procedure. | | |
|2. REMOVE the manhole cover at each end of the generator. |L | |
|3. TAKE a gas sample from the generator with a portable gas |L |Observe gas properties. |
|analyzer. | | |
|4. After a one hour ventilation period, PLACE a non-sparking fan |L | |
|at one of the manholes. | | |
|5. OPEN all water detector drain valves. |L | |
|6. VENTILATE for several hours. |L | |
|7. TAKE a gas sample from the generator with a portable gas |L |Analyzer scale. |
|analyzer and VERIFY generator is within human limits. | | |
|8. ENTER generator as required. |L | |
|9. REINSTALL manhole cover. |L | |
|10. CLOSE water detector drain valves. |L | |
5. System Post-Shutdown Checklist
When not required for operation, the steam turbine generator system must be maintained in a layup condition to preserve its integrity and to prevent internal deterioration and contamination of the internal components. The type of layup required is determined by the time period the system is estimated to be out of service. If it is estimated that the Electric Generator System is to be out of service less than three months, a short term layup must be performed. If three or more months is anticipated, a long term layup will be required.
1. Short Term
When the electric generator is to be taken out of service for a short time period, it is essential that the steam turbine be left on turning gear. The turning gear minimizes the temporary thermal bowing of the turbine rotor. Once the generator is removed from service and the turbine is on turning gear the hydrogen gas can be removed from the generator following the appropriate gas procedure. The seal oil system may be shutdown when the generator is sufficiently purged and replaced with carbon dioxide or air.
2. Long Term
When the unit is to be shut down for a long duration, the lube oil system and the turning gear should be operated for several hours each month. During this operational period, the operator should look and listen for any signs of deterioration and abnormal operation. Any water within the seal oil tank should be drained off and discoloration of the oil should be checked, sampled and the corrective actions taken.
It is extremely important when the unit is shutdown to leave any generator drains in the open position to facilitate draining and such that collections of condensate due not accumulate and corrode the internal surfaces of the generator.
Once the generator has been purged with air, per the proper procedure, and the internal condition analyzed personnel may enter the generator.
Once the long term shutdown is completed and the integrity of the generator and auxiliary systems has been re-established, the generator may be placed in service following the steps in Section 2.0 of this procedure.
6. ALARM RESPONSES
1. SUMMARY OF ALARMS
|ALARM CONDITIONS |
|Alarms |Initiating Device(s) |Device Setpoint(s) |
| Control Room (BTG) Alarms |
|Hydrogen Annunciator Panel Alarm |Hydrogen Panel |n/a |
|Exciter Switchgear Alarm |Relay |n/a |
|Field Breaker Trip Alarm |Relay |n/a |
| Control Room (Generator Panel) Alarms |
|Generator is Motoring |Relay |n/a |
|Generator Loss of Field |Relay |n/a |
|Generator Ground Fault |Relay |n/a |
|HP 112/113 (Generator Breaker) Failure |Relay |n/a |
|86G Relay Trip |Relay |n/a |
|86T Relay Trip |Relay |n/a |
|Exciter Power No. 1 or 2 Firing Circuit |Relay |n/a |
|Exciter Pulse No. 1 or 2 Firing Circuit |Relay |n/a |
|Exciter Auto Trip |Relay |n/a |
|Exciter Regulator Trip |Relay |n/a |
|Exciter Forcing Alarm |Relay |n/a |
|Exciter Maximum Excitation Timing |Relay |n/a |
|Exciter Field Ground Detector |Relay |n/a |
|Exciter Volts/Hertz Limiting |Relay |n/a |
| Hydrogen Control Panel |
|Hydrogen Purity High/Low |Purity Meter |> 100% |
| | |< 90% |
|Hydrogen Pressure High |Hydrogen Pressure Transmitter|56 High |
| | |18 Low |
|Hydrogen Supply Pressure Low |PS-3 |75 psig |
|Water Detector High |ASH614A/B/C |High |
|Hydrogen Temperature High |n/a |45 C |
|Defoaming Tank Level High |LS-6 |High |
|Air Side Seal Oil Pump Off |PDS-7 |5 psi |
|Seal Oil Pressure Low |PDS-8 |8 psi |
|Hydrogen Side Level Low |LS-9 |Low |
|Seal Oil Turbine Backup Pressure Low |PS-10 |70 psig at seals |
|Hydrogen Side Seal Oil Pump Off |PDS-11 |5 psi |
|Air Side Seal Oil Backup Pump Running |PDS-8 |8 psi |
Alarm: Hydrogen Annunciator Panel Alarm
Initiating Device(s): Hydrogen Panel
Setpoint(s): n/a
Possible Causes
1. Hydrogen system malfunction.
2. Seal oil system malfunction.
3. Hydrogen control panel malfunction.
Consequences
1. Loss of seal oil to generator.
2. Loss of hydrogen pressure/purity to generator.
Immediate Operator Action
1. Investigate actual alarm at hydrogen control panel.
Follow Up Operator Action
1. Follow response procedure for specific alarm.
2. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Exciter Switchgear Alarm
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Voltage regulator malfunction.
2. Exciter electrical malfunction/overload.
3. Initiating device malfunction.
Consequences
1. Loss of excitation.
2. Loss of generator.
Immediate Operator Action
1. Verify exciter operation.
2. Shutdown generator, as required.
Follow Up Operator Action
1. Re-establish exciter operation.
2. Restart turbine generator.
3. Inform Maintenance Department to check/repair exciter switchgear, if necessary.
4. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Field Breaker Trip Alarm
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Excess field voltage.
2. Field overload.
3. Breaker malfunction.
4. Initiating device malfunction.
Consequences
1. Loss of field.
2. Loss of generator.
Immediate Operator Action
1. Verify generator operation.
2. Shutdown generator/turbine, if required.
Follow Up Operator Action
1. Re-establish field.
2. Restart turbine generator.
3. Inform Maintenance Department to check/repair field breaker, if necessary.
4. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Generator is Motoring
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Reverse current (power) in generator.
2. Reverse power relay malfunction.
Consequences
1. Broken drive shaft.
2. Generator damage.
3. Generator trip.
4. Steam turbine damage.
Immediate Operator Action
1. Trip turbine generator.
2. Verify reverse current.
Follow Up Operator Action
1. Correct condition of reverse power.
2. Restart steam turbine generator.
3. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Generator Loss of Field
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Field breaker open/trip.
2. Voltage regulator malfunction.
3. Loss of excitation.
4. Initiating device malfunction.
Consequences
1. Generator acts as induction generator.
2. generator overheating.
3. Generator trip.
Immediate Operator Action
1. Trip turbine generator.
2. Verify field breaker condition.
3. Verify exciter operation.
Follow Up Operator Action
1. Re-establish field voltage.
2. Restart turbine generator.
3. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Generator Ground Fault
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Generator insulation failure.
2. Ground detection system malfunction.
3. Initiating device malfunction.
Consequences
1. Loss of output power.
2. Generator windings overheat.
3. Hydrogen overheating.
4. Extensive generator damage.
Immediate Operator Action
1. Verify generator cold end gas temperature.
2. Verify generator output.
3. Verify ground detection system operation.
4. Shutdown generator, if required.
Follow Up Operator Action
1. Verify loss of insulation and repair.
2. Startup turbine generator.
3. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: HP 112/113 (Generator Breaker) Failure
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Excess voltage or overload.
2. Breaker malfunction (Fail to open/close).
3. Initiating device malfunction.
Consequences
1. Loss of bus power.
2. Damage to generator.
Immediate Operator Action
1. Verify generator operation.
2. Verify bus operation.
Follow Up Operator Action
1. Re-synchronize generator.
2. Verify breaker operation.
3. Inform Maintenance Department to check/repair generator breaker, if necessary.
4. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: 86G Relay Trip
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Generator differential voltage.
2. Generator malfunction.
3. 86G relay malfunction.
Consequences
1. Generator lockout trip.
2. Generator trip.
Immediate Operator Action
1. Verify turbine generator shutdown.
2. Have electrical department investigate cause of lockout.
Follow Up Operator Action
1. Reset lockout.
2. Restart turbine generator.
3. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: 86T Relay Trip
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Bus transfer differential voltage.
2. Generator breaker malfunction.
3. 86T relay malfunction.
Consequences
1. Transfer lockout trip.
2. Generator breaker trip.
Immediate Operator Action
1. Verify generator breaker trip shutdown.
2. Shutdown generator, if required.
3. Have electrical department investigate cause of lockout.
Follow Up Operator Action
1. Reset lockout.
2. Reset generator breaker.
3. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Exciter Power No. 1/2 Firing Circuit
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Firing circuit power module malfunction.
2. Firing circuit loss of power.
3. Initiating device malfunction.
Consequences
1. Loss of voltage regulation.
2. Loss of excitation.
3. Loss of generator load.
Immediate Operator Action
1. Verify exciter firing circuit power supply.
2. Verify voltage regulator operation.
3. Adjust generator load, as required.
Follow Up Operator Action
1. Observe voltage regulator/generator operation.
2. Inform Maintenance Department to check/repair/calibrate exciter power module, if necessary.
Alarm: Exciter Pulse No. 1/2 Firing Circuit
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Firing circuit pulse module malfunction.
2. Firing circuit loss of pulse.
3. Initiating device malfunction.
Consequences
1. Loss of voltage regulation.
2. Loss of excitation.
3. Loss of generator load.
Immediate Operator Action
1. Verify exciter firing circuit pulse module.
2. Verify voltage regulator operation.
3. Adjust generator load, as required.
Follow Up Operator Action
1. Observe voltage regulator/generator operation.
2. Inform Maintenance Department to check/repair/calibrate exciter pulse module, if necessary.
Alarm: Exciter Auto Trip
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Exciter voltage trip.
2. Exciter power trip.
3. Voltage regulator malfunction.
4. Initiating device malfunction.
Consequences
1. Generator overheating.
2. Poor power factor control on grid.
3. Unstable generator operation.
Immediate Operator Action
1. Verify exciter trip condition.
2. Remove generator from grid, if required.
3. Shutdown generator, if required.
Follow Up Operator Action
1. Place voltage regulator back into service.
2. Return exciter to service.
3. Start or synchronize generator, if required.
4. Inform Maintenance Department to check/repair/calibrate exciter pulse module, if necessary.
Alarm: Exciter Regulator Trip
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Regulator voltage trip.
2. Regulator power trip.
3. Initiating device malfunction.
Consequences
1. Generator overheating.
2. Poor power factor control on grid.
3. Loss of generator field.
Immediate Operator Action
1. Verify exciter trip condition.
2. Remove generator from grid, if required.
3. Shutdown generator, if required.
Follow Up Operator Action
1. Place voltage regulator back into service.
2. Return exciter to service.
3. Start or synchronize generator, if required.
4. Inform Maintenance Department to check/repair/calibrate exciter pulse module, if necessary.
Alarm: Exciter Forcing Alarm
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Excessive excitation required.
2. Exciter malfunction.
3. Voltage regulator malfunction.
4. Initiating device malfunction.
Consequences
1. Generator overheating.
2. Generator trip.
Immediate Operator Action
1. Verify generator temperatures.
2. Verify exciter operation.
3. Verify voltage regulator operation.
4. Remove generator from service, if required.
Follow Up Operator Action
1. Place voltage regulator back into service.
2. Return exciter to service.
3. Start or synchronize generator, if required.
4. Inform Maintenance Department to check/repair/calibrate exciter pulse module, if necessary.
Alarm: Exciter Maximum Excitation Timing
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Forcing past time limits.
2. Exciter malfunction.
3. Voltage regulator malfunction.
4. Initiating device malfunction.
Consequences
1. Generator overheating.
2. Generator trip.
Immediate Operator Action
1. Verify generator temperatures.
2. Verify exciter operation.
3. Verify voltage regulator operation.
4. Remove generator from service, if required.
Follow Up Operator Action
1. Place voltage regulator back into service.
2. Return exciter to service.
3. Start or synchronize generator, if required.
4. Inform Maintenance Department to check/repair/calibrate exciter pulse module, if necessary.
Alarm: Exciter Field Ground Detector
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Exciter insulation failure.
2. Ground detection system malfunction.
3. Initiating device malfunction.
Consequences
1. Loss of exciter output power.
2. Exciter windings overheat.
3. Extensive exciter damage.
Immediate Operator Action
1. Verify exciter temperatures.
2. Verify exciter output.
3. Verify ground detection system operation.
4. Shutdown generator, if required.
Follow Up Operator Action
1. Verify loss of insulation and repair.
2. Startup turbine generator.
3. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Exciter Volts/Hertz Limiting
Initiating Device(s): Relay
Setpoint(s): n/a
Possible Causes
1. Excessive exciter voltage.
2. Low exciter/generator speed.
3. Voltage regulator malfunction.
4. Initiating device malfunction.
Consequences
1. Generator overheating.
2. Power transformer overheating.
Immediate Operator Action
1. Increase speed.
2. Decrease field voltage.
3. Verify operation of voltage regulator.
4. Shutdown generator, if required.
Follow Up Operator Action
1. Verify speed and voltage.
2. Startup turbine generator.
3. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Hydrogen Purity High/Low
Initiating Device(s): Purity Meter
Setpoint(s): above 100%/below 90%
Possible Causes
1. Improper valve alignment.
2. Equalizing valve malfunction.
3. Purity meter blower malfunction.
4. Generator gas system malfunction.
5. Generator hydrogen side seal oil drain regulator malfunction.
6. Initiating device malfunction.
Consequences
1. Generator overheating.
2. Reduction in generator load.
Immediate Operator Action
1. Verify generator hydrogen purity.
2. Add/vent hydrogen.
3. Adjust load as required.
Follow Up Operator Action
1. Periodically monitor generator hydrogen purity.
2. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
3. Inform Maintenance Department to check/repair/calibrate purity meter, if necessary.
Alarm: Hydrogen Pressure High/Low
Initiating Device(s): Pressure Transmitter
Setpoint(s): 56 high/18 low
Possible Causes
1. Hydrogen regulator malfunction.
2. Sudden reduction/increase in load.
3. Improper valve alignment.
4. Hydrogen leak.
5. Low/high hydrogen temperature.
6. Pressure switch malfunction.
Consequences
1. Reduction in hydrogen purity.
2. Generator overheating.
3. Reduction in generator load.
Immediate Operator Action
1. Verify hydrogen pressure.
2. Adjust regulator, if required.
3. Adjust hydrogen cooler operation, if required.
4. Verify hydrogen supply pressure.
5. Verify valve alignment.
Follow Up Operator Action
1. Adjust generator load, if required.
2. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
3. Inform Maintenance Department to check/repair/calibrate temperature control valve, if necessary.
Alarm: Hydrogen Supply Pressure Low
Initiating Device(s): PS-3
Setpoint(s): 75 psig
Possible Causes
1. Insufficient hydrogen bottles.
2. Supply header leak.
3. Improper valve alignment.
4. Pressure switch malfunction.
Consequences
1. Loss of generator gas pressure.
2. Reduced hydrogen purity.
3. Generator overheating.
Immediate Operator Action
1. Verify hydrogen supply pressure.
2. Verify valve alignment.
3. Increase bottles of hydrogen.
4. Reduce generator load, if required.
Follow Up Operator Action
1. Verify pressure return to normal.
2. Verify purity returns to normal.
3. Order more hydrogen bottles, if required.
4. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Water Detector High
Initiating Device(s): ASH614A/B/C
Setpoint(s): High
Possible Causes
1. Oil/Water in liquid level detector(s).
2. Hydrogen cooler leak.
3. Generator seal overflow.
4. Liquid level detector float malfunction.
Consequences
1. Oil/Water in generator.
2. Emergency shutdown of generator.
Immediate Operator Action
1. Verify which detector(s) are initiating the alarm.
2. Verify cause water/oil.
3. Verify if detector will immediately fill up after draining, if so shutdown will be required.
Follow Up Operator Action
1. Verify generator seals operation.
2. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
3. Inform Maintenance Department to check/repair hydrogen cooler, if necessary.
Alarm: Hydrogen Temperature High
Initiating Device(s): n/a
Setpoint(s): 45 C
Possible Causes
1. Hydrogen cooler fouling.
2. Condensate cooling water temperature control valve malfunction.
3. Generator overload.
4. Low hydrogen purity.
3. Initiating device malfunction.
Consequences
1. Loss of generator capabilities.
2. Generator overheating.
Immediate Operator Action
1. Verify hydrogen temperature.
2. Verify hydrogen purity.
3. Verify hydrogen cooler temperature control valve.
4. Reduce load, if required.
Follow Up Operator Action
1. Continuously monitor hydrogen temperature.
2. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
3. Inform Maintenance Department to check/repair/calibrate temperature control valve, if necessary.
4. Inform Maintenance Department to check/repair hydrogen cooler(s), if necessary.
Alarm: Defoaming Tank Level High
Initiating Device(s): LS-6
Setpoint(s): High
Possible Causes
1. Clogged defoaming tank overflow.
2. Improper valves alignment.
3. Level switch malfunction.
Consequences
1. Backup of oil into seals.
2. Insufficient return to hydrogen side drain regulator.
3. Possible reduction of load of generator.
Immediate Operator Action
1. Verify level in each defoaming tank.
2. Verify valve alignment.
3. Verify level in drain regulator and turbine oil loop seal return tank.
4. Adjust generator load if required.
Follow Up Operator Action
1. Frequently observe level in defoaming tanks.
2. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Air Side Seal Oil Pump Off
Initiating Device(s): PDS-7
Setpoint(s): 5 psid
Possible Causes
1. Air side seal oil pump malfunction or trip.
2. Improper valve alignment.
3. Pressure switch malfunction.
Consequences
1. Reduce air side seal oil pressure.
2. Air side seal oil backup pump starts.
3. Reduced load capacity.
Immediate Operator Action
1. Verify air side seal oil pressure.
2. Check air side seal oil pump operation.
3. Check air side seal oil backup pump operation.
4. Reduce load if required.
Follow Up Operator Action
1. Restart air side seal oil pump.
2. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Seal Oil Pressure Low
Initiating Device(s): PDS-8
Setpoint(s): 8 psid
Possible Causes
1. Pressure Switch malfunction.
2. Improper valve alignment.
3. Seal oil pressure regulator malfunction.
4. Air side seal oil pump and/or backup pump malfunction or trip.
Consequences
1. No consequence if air side seal oil backup pump start maintains seal oil pressure.
2. Possible loss of hydrogen from generator.
3. Possible load reduction.
Immediate Operator Action
1. Verify air side seal oil backup pump running.
2. Prepare for load reduction.
3. Check for oil leaks.
4. Verify seal oil differential pressure 12 psid above machine gas pressure.
5. Check air side seal oil pump and motor.
Follow Up Operator Action
1. Monitor seal oil pressure.
2. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Hydrogen Side Level Low
Initiating Device(s): LS-9
Setpoint(s): Low
Possible Causes
1. Feed valve malfunction.
2. Dump valve malfunction.
3. Level switch malfunction.
Consequences
1. Low hydrogen seal oil pump side suction head.
2. Loss of hydrogen side seal oil.
3. Possible reduced load.
Immediate Operator Action
1. Verify operation of hydrogen side drain regulator.
2. Manually adjust feed or dump valve.
3. Adjust generator load if required.
4. Verify hydrogen side pump operation.
Follow Up Operator Action
1. Adjust hydrogen side drain regulator level.
2. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Seal Oil Turbine Backup Pressure Low
Initiating Device(s): PS-10
Setpoint(s): 70 psig at seals
Possible Causes
1. Pressure switch malfunction.
2. Turbine lube oil system malfunction.
3. Improper valve alignment.
4. Pressure regulator (291) malfunction.
Consequences
1. Possible loss of hydrogen from generator.
2. Possible load reduction.
Immediate Operator Action
1. Verify air side seal oil pump or backup pump is running.
2. Prepare for load reduction.
3. Check for oil leaks.
4. Verify seal oil differential pressure 12 psid above machine gas pressure.
5. Check pressure regulator (219).
Follow Up Operator Action
1. Monitor seal oil pressure.
2. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
3. Inform Maintenance Department to check/repair pressure regulator, if necessary.
Alarm: Hydrogen Side Seal Oil Pump Off
Initiating Device(s): PDS-11
Setpoint(s): 5 psid
Possible Causes
1. Hydrogen side seal oil pump malfunction or trip.
2. Improper valve alignment.
3. Pressure switch malfunction.
Consequences
1. Reduce hydrogen side seal oil pressure.
2. Loss of hydrogen from generator.
3. Reduced load capacity.
Immediate Operator Action
1. Verify hydrogen side seal oil pressure.
2. Check hydrogen side seal oil pump operation.
3. Reduce load if required.
Follow Up Operator Action
1. Restart hydrogen side seal oil pump.
2. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
Alarm: Air Side Seal Oil Backup Pump Running
Initiating Device(s): PDS-8
Setpoint(s): 8 psid
Possible Causes
1. Pressure Switch malfunction.
2. Pressure Differential Switch malfunction
3. Improper valve alignment.
4. Seal oil pressure regulator malfunction.
5. Air side seal oil pump malfunction or trip.
6. Loss of AC power.
Consequences
1. No consequence if air side seal oil backup pump start maintains seal oil pressure.
2. Possible loss of hydrogen from generator.
3. Possible load reduction.
Immediate Operator Action
1. Verify air side seal oil backup pump running.
2. Prepare for load reduction.
3. Check for oil leaks.
4. Verify seal oil differential pressure 12 psid above machine gas pressure.
5. Check air side seal oil pump and motor.
Follow Up Operator Action
1. Monitor seal oil pressure.
2. Inform Maintenance Department to check/repair/calibrate initiating device, if necessary.
7. CHECKLISTS AND TABLES
|TABLE 1 - POWER SUPPLY CHECKLIST |
|Breaker Location |Description |Voltage |Breaker Position |
| MCC 2-2, 4B |Hydrogen Vapor Extractor Motor |480 VAC |ON, Reset |
| MCC 2-2, 1K |Air Side Seal Oil Pump Motor |480 VAC |ON, Reset |
| MCC 2-1, 1H |Hydrogen Side Seal Oil Pump Motor |480 VAC |ON, Reset |
| DCB |Air Side Seal Oil Backup Pump |120 VDC |ON |
| MCC 2-2 |Gas Dryer | |ON |
| MCC 2-2 |Hydrogen Control Panel | |ON |
| Table 2 - Prestart Valve Lineup Checklist |
|Valve No. |Location |Description |Open |Closed |
|Generator Gas System |
|1 |First Floor |Purity meter blower carbon dioxide header return |X | |
|2 |First Floor |Purity meter blower hydrogen header return | |X |
|3 |First Floor |Purity meter blower carbon dioxide header suction |X | |
|4 |First Floor |Purity meter blower hydrogen header suction | |X |
|5 |First Floor |Carbon dioxide downstream supply | |X |
|6 |First Floor |Carbon dioxide manifold vent | |X |
|7 |First Floor |Hydrogen manifold vent | |X |
|8 |First Floor |Hydrogen downstream supply |X | |
|9 |First Floor |Gas dryer supply |X | |
|10 |First Floor |Gas dryer return |X | |
|11 |First Floor |Dual element transmitter low pressure supply |X | |
|12 |First Floor |Dual element transmitter high pressure supply |X | |
|13 |First Floor |Liquid level detector (turbine end) isolation |X | |
|14 |First Floor |Liquid level detector (turbine end) isolation |X | |
|15 |First Floor |Liquid level detector (turbine end) drain | |X |
|16 |First Floor |Liquid level detector (middle) isolation |X | |
|17 |First Floor |Liquid level detector (middle) isolation |X | |
|18 |First Floor |Liquid level detector (middle) drain | |X |
|19 |First Floor |Liquid level detector (exciter end) isolation |X | |
|20 |First Floor |Gas dryer inlet |absorb | |
|21 |First Floor |Gas dryer outlet |absorb | |
|22 |First Floor |Liquid level detector (exciter end) isolation |X | |
|23 |First Floor |Liquid level detector (exciter end) drain | |X |
|24 |First Floor |Generator exciter end vent | |X |
|40 |First Floor |Dual element transmitter bypass | |X |
|41 |First Floor |Dual element transmitter low pressure isolation |X | |
|42 |First Floor |Dual element transmitter high pressure isolation |X | |
|43 |First Floor |Dual element transmitter low pressure drain | |X |
|44 |First Floor |Dual element transmitter high pressure drain | |X |
|50 |First Floor |Hydrogen pressure regulator supply valve |X | |
|51 |First Floor |Hydrogen pressure regulator vent | |X |
|52 |First Floor |Hydrogen pressure regulator bypass | |X |
|53 |First Floor |Hydrogen bulk supply isolation | |X |
|60 |First Floor |Carbon dioxide main isolation | |X |
|62 |First Floor |Carbon dioxide supply header vent | |X |
|63 |First Floor |Carbon dioxide bottle 1 isolation | |X |
|64 |First Floor |Carbon dioxide bottle 2 isolation | |X |
|65 |First Floor |Carbon dioxide bottle 3 isolation | |X |
|66 |First Floor |Carbon dioxide bottle 4 isolation | |X |
|67 |First Floor |Carbon dioxide bottle 5 isolation | |X |
|68 |First Floor |Carbon dioxide bottle 6 isolation | |X |
|69 |First Floor |Carbon dioxide bottle 7 isolation | |X |
|70 |First Floor |Carbon dioxide bottle 8 isolation | |X |
|71 |First Floor |Carbon dioxide bottle 9 isolation | |X |
|72 |First Floor |Carbon dioxide bottle 10 isolation | |X |
|73 |First Floor |Carbon dioxide bottle 11 isolation | |X |
|Generator Seal Oil System |
|200 |Second Floor |Air side seal oil pressure indicator isolation |X | |
|201 |Second Floor |Air side seal oil pressure indicator isolation |X | |
|202 |Second Floor |Seal oil equalizing valve 210 root isolation #1 |X | |
|203 |Second Floor |Seal oil equalizing valve 210 root isolation #2 |X | |
|204 |Second Floor |Seal oil equalizing valve 217 root isolation #1 |X | |
|205 |Second Floor |Seal oil equalizing valve 217 root isolation #2 |X | |
|208 |Second Floor |Exciter end defoaming tank drain | |X |
|209 |Second Floor |Turbine end defoaming tank drain | |X |
|211 |First Floor |Equalizing valve 210 outlet |X | |
|212 |First Floor |Equalizing valve 210 actuator upper isolation |X | |
|213 |First Floor |Equalizing valve 210 actuator lower isolation |X | |
|214 |First Floor |Equalizing valve 210 pressure indicator upper isolation |X | |
|215 |First Floor |Equalizing valve 210 pressure indicator lower isolation |X | |
|218 |First Floor |Equalizing valve 217 outlet |X | |
|219 |First Floor |Equalizing valve 217 actuator upper isolation |X | |
|220 |First Floor |Equalizing valve 217 actuator lower isolation |X | |
|221 |First Floor |Equalizing valve 217 pressure indicator upper isolation |X | |
|222 |First Floor |Equalizing valve 217 pressure indicator lower isolation |X | |
|231 |First Floor |Drain regulator drain |AUTO | |
|232 |First Floor |Drain regulator fill |AUTO | |
|233 |First Floor |Hydrogen side seal oil pump suction |X | |
|239 |First Floor |Hydrogen side seal oil cooler outlet |X | |
|240 |First Floor |Hydrogen side seal oil cooler inlet |X | |
|241 |First Floor |Hydrogen side seal oil cooler bypass | |X |
|242 |First Floor |Hydrogen side seal oil pump recirculation |1/2 | |
|243 |First Floor |Pressure switch (11) isolation 1 |X | |
|244 |First Floor |Pressure switch (11) isolation 2 |X | |
|236 |First Floor |Air side pressure indicator isolation |X | |
|237 |First Floor |Backup regulator actuator lower isolation |X | |
|247 |First Floor |Pressure switch PS-8 isolation |X | |
|248 |First Floor |Test leg isolation |X | |
|238 |First Floor |Differential pressure regulator actuator lower isolation |X | |
|249 |First Floor |Differential pressure regulator actuator upper isolation |X | |
|250 |First Floor |Air side seal oil cooler outlet |X | |
|251 |First Floor |Air side seal oil cooler inlet |X | |
|252 |First Floor |Air side seal oil cooler bypass | |X |
|254 |First Floor |Air side seals oil pump discharge |X | |
|253 |First Floor |Air side seal oil pump suction |X | |
|263 |First Floor |Backup regulator outlet |X | |
|265 |First Floor |Backup regulator inlet |X | |
|266 |First Floor |Backup regulator bypass | |X |
|273 |First Floor |Test gauge isolation | |X |
|274 |First Floor |Pump test | |X |
|262 |First Floor |Pressure switch PS-10 isolation |X | |
|277 |First Floor |Pressure switch PS-7 isolation 1 |X | |
|278 |First Floor |Pressure switch PS-7 isolation 2 |X | |
|279 |First Floor |Valve 291 test gauge isolation | |X |
|Table 3 - Local Indicating Instruments |
|Instrument |Function/Description |Normal Range |
|Seal Oil System |
|n/a |Gland Seal Oil Collector End Pressure |± 2 "H2O |
|n/a |Air Side Seal Oil Pressure |60 - 65 psig |
|n/a |Gland Seal Oil Turbine End Pressure |± 2 "H2O |
|n/a |Pressure Regulator Actuator Pressure |55 - 65 psig |
|n/a |Air Side Discharge Pressure |55 - 65 psig |
|n/a |Hydrogen Side Discharge Pressure |90 - 100 psig |
|n/a |Hydrogen Side Temperature |90 - 100 F |
|n/a |Air Side Temperature |90 - 100 F |
|n/a |Hydrogen Downstream Pressure |120 - 130 psig |
|Generator Gas System |
|Hydrogen Panel |Purity Meter |100 % Hydrogen |
|Hydrogen Panel |Hydrogen and Fan Pressure |Fan 50 - 60 "H2O |
| | |H2 45 - 55 psig |
|n/a |Hydrogen (Control Regulator) Pressure |45 - 55 psig |
|n/a |CO2 Pressure |0 |
|Generator |
|n/a |Seal Oil Pressure (Turbine End) |55 - 65 psig |
|n/a |Seal Oil Pressure |55 -65 psig |
|n/a |Bearing No. 5 Temperature |130 - 140 F |
|n/a |Bearing No. 6 Temperature |130 - 140 F |
|n/a |WTA Regulator Exciter Field Current |25 - 35 Amps |
|n/a |WTA Regulator Exciter Field Voltage |65 -75 V |
|n/a |WTA Regulator PMG Supply Voltage |120 - 130 V |
|Table 4 - Control Room Indicating Instruments |
|Instrument |Function/Description |Normal Range |
|Seal Oil System |
|n/a |None | |
|Generator Gas System |
|n/a |Hydrogen Pressure |45 - 55 psig |
|n/a |Hydrogen Purity |100 % Hydrogen |
|Generator System |
|n/a |Generator Watt Meter |Load MW |
|n/a |Generator VAR Meter |0 - 50 VAR |
|n/a |Generator Balance |0 V |
|n/a |Generator Ampere |4 - 6 KA |
|n/a |Generator DC Field Amperes |28 - 32 |
|n/a |Generator DC Field Volts |60 - 70 |
|n/a |Generator Volts |20 - 25 |
|n/a |Generator Frequency |59.99 - 60.01 |
|n/a |22/115 Transformer No. 1 |2450 - 2550 Amps |
|n/a |22/115 Transformer No. 2 |2450 - 2550 Amps |
8. REFERENCES
1. P&ID
a. GE Power Generation, Steam Turbine Systems, 117E1111, Rev. D
b. GE Power Generation, Hydraulics (Steam Turbine Systems), 117E1113, Rev. B
c. Raytheon Engineers and Constructors, Boiler Feedwater System, MD2200, Rev. 2
d. Raytheon Engineers and Constructors, Condensate System, MD2300, Rev. 2
e. Raytheon Engineers and Constructors, Circulating Water System, MD2400, Rev. 2
f. Raytheon Engineers and Constructors, Closed Cooling Water System, MD2500, Rev. 2
g. Raytheon Engineers and Constructors, Steam Turbine Lube Oil and Air Evacuation Systems, MD3200, Rev. 2
h. Raytheon Engineers and Constructors, Auxiliary Steam System, MD4200, Rev. 2
2. Electrical One Line Diagrams
a. City of Tallahassee, Purdom Generating Station One Line Diagram, 5410166-001, Rev. 0
b. Raytheon Engineers and Constructors, Key One Line Diagram, ED1100, Rev. 4
c. Raytheon Engineers and Constructors, Main One Line Diagram Sheet No. 1, ED1101, Rev. 3
d. Raytheon Engineers and Constructors, Main One Line Diagram Sheet No. 2, ED1102, Rev. 3
e. Raytheon Engineers and Constructors, 4.16kV Auxiliary One Line Diagram, ED1200, Rev. 2
f. Raytheon Engineers and Constructors, 480V Auxiliary One Line Diagram, ED1201, Rev. 2
g. Raytheon Engineers and Constructors, 480V Motor Control Center One Line Diagram Sheet No. 1, ED1300, Rev. 2
h. Raytheon Engineers and Constructors, 480V Motor Control Center One Line Diagram Sheet No. 2, ED1301, Rev. 3
i. Raytheon Engineers and Constructors, 125V DC One Line Diagram, ED1600, Rev. 3
j. Raytheon Engineers and Constructors, 120V AC SUPS One Line Diagram, ED1601, Rev. 3
3. Instruction Manuals
a. GE Power Systems, Steam Turbine Generator Operation Training Manual, S. O. Purdom Generating Station, Unit No. 8, City of Tallahassee, St. Mark's, Florida, 2000
4. Miscellaneous
a. GE Power Generation, Gas Turbine Generator Unit Nameplate, 355B5650, Rev. 0
b. GE Power Generation, Steam Turbine Generator Unit Nameplate, 351B1892, Rev. 0
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