ML040130464
| ML040130464 | |
| Person / Time | |
|---|---|
| Site: | Monticello  |
| Issue date: | 09/23/2003 |
| From: | Allex G Nuclear Management Co |
| To: | NRC/RGN-III |
| References | |
| 50-263/03-301 50-263/03-301 | |
| Download: ML040130464 (125) | |
Text
Appendix D Scenario Outline Form ES-D-1 Facility:
MNGP Scenario No. NRC 03-01 Op-Test No:
03-01 Examiners:
Operators:
Initial Conditions: A reactor startup is in progress from a refueling outage. The crew will assume the shift with the plant operating at 11% power making preparations for rolling the Main Turbine. Operations Manual C.1, Reactor Startup, has been completed up through step VII.A.18.
Turnover: Withdraw control rods to achieve 1-1/2 Turbine Bypass Valves open in accordance with step C.1 Step VII.B.1 and then roll the Main Turbine per C.1 Step VII.B and continue with plant startup.
Event No.
Malf.
No.
Event Type*
Event Description 1
N/A RO (R)
Withdraw control rods to establish 1-1/2 Bypass Valves 2
RW01 RO (I)
RWM Equipment Failure (Tech Spec Call) 3 N/A BOP (N)
Roll the Main Turbine 4
TC05B BOP (C)
Pressure Regulator Oscillations, MPR 5
SW01A RO (C)
- 11 RBCCW Pump Trip 6
IA04 BOP (C)
Instrument Air Header Failure 7
CH02 Note 1 M
Failure to Scram (West SDV hydraulic lock) 8 RM03K RM03H RX01 M
Rupture of West SDV 9
S025-01 BOP(C)
Failure of A SRV to Open Equipment Out of Service B RWCU Pump APRM Channel #5 Note 1: This event requires 61 malfunctions to be inserted to have 61 control rods associated with the West SDV stuck.
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Op-Test No. Scenario No. 1 Event No. 1 Page 1 of 1 Event
Description:
The crew will assume the shift with the plant operating at 11% power making preparations for rolling the Main Turbine. Operations Manual C.1, Reactor Startup, has been completed up through step VII.A.18. Control Rods need to be pulled to achieve 1 1/2 Turbine Bypass Valves in accordance with step VII.B.1.
Time Position Actions or Behavior SRO Direct withdrawal of control rods to achieve 1 1/2 Main Turbine Bypass Valves open.
RO Withdraws control rods in accordance with Ops Man B.05.05-05.E.1, Control Rod Movement.
Place ROD SELECT POWER switch, 3A-S1, to ON.
Press the appropriate ROD SELECT pushbutton (determined from the roller tape, RWM and control rod sequence package).
NOTE: The control rod will move 1 notch in the indicated direction when the ROD MOVEMENT CONTROL switch is momentarily placed in ROD NOTCH OUT or ROD IN.
Momentarily place ROD MOVEMENT CONTROL switch, 3A-S2, to ROD OUT NOTCH or ROD IN to obtain desired rod movement.
NOTE: The RO will withdraw one rod from notch 12 to notch 48. On selection of the second rod, Event # 2 will occur.
BOP Monitoring plant parameters and may act as Peer Checker.
Monitors Turbine Bypass valve position on Panel C-07 BYPASS VALVE 1 POSITION (POI-1788) and BYPASS VALVE 2 POSITION (POI-1789)
Notes:
Op-Test No. Scenario No. 1 Event No. 2 Page 1 of 4 Event
Description:
During control rod withdrawal, the RWM will fail. This will cause control rod withdrawal to stop to investigate the failure. This failure will result in the RWM being bypassed and Tech Specs reviewed.
SRO When Form 2169 is complete directs the operator to bypass the RWM.
SRO Directs RO to recommence rod withdrawal to achieve 1 1/2 bypass valves.
Time Position Actions or Behavior Simulator Operator TRG #1: When the RO selects the second rod, ensure that event trigger #1 activates to cause the RWM to fail.
SRO Acknowledge report of annunciator 5-A-35, RWM ROD BLOCK.
SRO Phone Talker Notifies the Nuclear Engineer and System Engineer.
When contacted as the Nuclear Engineer, acknowledge the report and state that you will investigate. Wait 2 minutes and then enter the simulator as the nuclear engineer. He reports that he performed additional diagnostics in the cable spreading room and cannot determine a problem with the RWM.
Chief Examiner An exam team member will enter the simulator as the nuclear engineer. He will pretend to assist in filling out the form 2169, but will provide no specific direction. He will concur with any recommended made by the crew.
SRO Refers to Tech Spec 3.3.B.3.b. This TS states Whenever the reactor is in the startup or run mode below 10% rated thermal power, no control rods shall be moved unless the rod worth minimizer is operable or a second independent operator or engineer verifies that the operator at the reactor console is following the control rod program. The second operator may be used as a substitute for an inoperable rod worth minimizer during a startup only if the rod worth minimizer fails after withdrawal of at least twelve control rods.
Determines that power is >10% and that TS allows bypassing the RWM.
Op-Test No. Scenario No. 1 Event No. 2 Page 2 of 4 Event
Description:
During control rod withdrawal, the RWM will fail. This will cause control rod withdrawal to stop to investigate the failure. This failure will result in the RWM being bypassed and Tech Specs reviewed.
RO Acknowledges and informs CRS of annunciator 5-A-35, RWM ROD BLOCK.
RO Reviews ARP 5-A-35 and determines alarm is due to an inop RWM.
RO When directed by the SRO, performs procedure B.05.02-05.G.2, RWM BYPASS.
- 1.
Perform 2169 (ROD WORTH MINIMIZER BYPASS CHECKLIST)
RO Performs procedure 2169, ROD WORTH MINIMIZER BYPASS CHECKLIST.
Note 1: This procedure may be terminated at any STEP if the RWM returns to an operable condition.
Note 2: The RWM bypass should be removed immediately when no longer required for continued operation.
STEP 1 Check the SELF-TEST status on the RWM.
A. If the self-test indicates OK, continue with STEP 2. (Mark STEP N/A if SELF-TEST: FAULT).
Note for examiner: Self-Test will show FAULT. Marks step with an N/A.
B. If the self-test indicates FAULT, cycle power on the NUMAC RWM instrument (Cable Spreading Room - Panel C289A) by removing the power cable in the rear of the chassis (J8), then re-installing it. (Mark step N/A if self-test: OK)
Note for examiner: Directs operator to cable spreading room to cycle power.
Time Position Action or Behavior
Op-Test No. Scenario No. 1 Event No. 2 Page 3 of 4 Event
Description:
During control rod withdrawal, the RWM will fail. This will cause control rod withdrawal to stop to investigate the failure. This failure will result in the RWM being bypassed and Tech Specs reviewed.
Time Position Action or Behavior Phone talker Have operator stand by at operating station for 2 minutes. Then tell operator that power has been cycled to RWM and to return to the control room.
RO STEP 2 Select the MESSAGES menu and check the upper part of the screen for the current insert/withdraw block messages. These messages will also appear with the message number on the PCS alarm typer.
Note: The RWM will always issue a Critical self-test failure message immediately after initial power-up until the first self-test is completed.
Note to examiner: RWM will not display any messages.
RO STEP 3 Consult Table 1 for most recent rod block messages and note message number of block below.
Note: Table 1 is intended to provide guidance as to the type of RWM rod block and probable cause.
Note to examiner: RWM will not display any message numbers.
RO STEP 4 If type is BYP, the RWM may be bypassed in accordance with the requirements of Tech spec 3.3.B.3 (b)
Note to examiner: Determines this step is N/A.
RO STEP 5 If STEP 4 is N/A, and if it is determined that the RWM still must be bypassed, apply the bypass in accordance with Tech Spec 3.3.B.3 (b)
Note to examiner: RO should determine that RWM can be bypassed.
Op-Test No. Scenario No. 1 Event No. 2 Page 4 of 4 Event
Description:
During control rod withdrawal, the RWM will fail. This will cause control rod withdrawal to stop to investigate the failure. This failure will result in the RWM being bypassed and Tech Specs reviewed.
Time Position Actions or Behavior RO From B.05.02-05.G.2
- 2. WHEN Shift Supervisor permission is obtained to bypass the RWM, THEN place the RWM to BYPASS using the keylock switch on the OD (Panel C-05)
- 3. Withdraws/inserts one group in the rod sequence.
Note to examiner: Steps 3 and 4 mean to continue with the rod withdrawal with a second person present.
- 4. Independently verifies the rod pattern.
- 5. Repeats step 3 and step 4 for each group in the rod sequence.
Note to examiner: Step 6 of the procedure is NA.
RO When directed by the CRS, recommences withdrawal of control rods to 1 1/2 bypass valves..
BOP Monitoring plant parameters and may act as Peer Checker.
Notes:
Op-Test No. Scenario No. 1 Event No. 3 Page 1 of 1 Event
Description:
After bypassing the RWM, the crew will continue with the startup and begin to roll the Main Turbine.
Time Position Actions or Behavior SRO Direct the BOP operator to roll the turbine in accordance with C.1.VII.B.
RO Monitor plant parameters.
BOP Rolls the Main Turbine in accordance with C.1.VII.B.
BOP Determine initial First Stage Shell Temperature is < 250°F.
BOP Determine Turbine acceleration rate is 60 RPM/min.
BOP NOTE: The acceleration rate may be exceeded momentarily when increasing speed.
Raise the Load Limit setpoint and spin the turbine to approximately 200 rpm.
(LLM CO7)
BOP Adjust the Load Limit to maintain approximately 200 rpm.
BOP Verify the TURB TURNING GEAR amber ENGAGED light is OFF.
BOP STOP the TURB TURNING GEAR drive motor. (CS-42-4216/CS CO7)
Note to the examiner: Initiate event 4 at this point.
BOP Phone Talker Direct that a local inspection of the turbine be conducted and verify the TURBINE TURNING GEAR has disengaged.
When directed as an extra licensed operator to perform a local inspection of the Main Turbine and verify the turning gear has disengaged reply Local inspection of the Main Turbine is satisfactory, no abnormal noise or vibrations, and the turning gear is disengaged.
Notes:
Op-Test No. Scenario No. 1 Event No. 4 Page 1 of 2 Event
Description:
When turbine speed reaches 200 rpm a failure of the Electrical Pressure Regulator (EPR) will occur while the operator is securing the Turning Gear resulting in Turbine Bypass Valve oscillations. The crew should recognize cycling of the bypass valves, reactor pressure and Main Steam Pressure Control System. The failure will clear once the crew has taken control with the MPR.
Time Position Actions or Behavior Simulator Operator TRG #2: When directed by the Chief Examiner at 200 rpm main turbine speed and the BOP operator is securing the Turning Gear motor insert event trigger #2 to cause a failure of the EPR.
SRO Acknowledge report of computer alarms:
TRB021 Turb Elec Press Reg Cont Off TRB023 Turb Mech Press Reg Cont On Note to examiner: There may be other computer alarms present, but these two are the only ones germane to the scenario.
SRO Verify Bypass Valve Oscillations are occurring and notices MPR and EPR green and red lights are cycling ON and OFF.
SRO Direct that pressure control be switched to the MPR per B.5.09-05.H.2 BYPASS VALVE OSCILLATIONS.
SRO Direct that the MPR be left in control.
SRO Phone Talker Notify Supt. Electrical and Instrument Engineering.
When contacted as Superintendent of Electrical and Instrument Engineering then acknowledge the report and inform the crew that you will investigate the failure.
Op-Test No. Scenario No. 1 Event No. 4 Page 2 of 2 Event
Description:
When turbine speed reaches 200 rpm a failure of the Electrical Pressure Regulator (EPR) will occur while the operator is securing the Turning Gear resulting in Turbine Bypass Valve oscillations. The crew should recognize cycling of the bypass valves, reactor pressure and Main Steam Pressure Control System. The failure will clear once the crew has taken control with the MPR.
Time Position Actions or Behavior RO Monitoring plant parameters.
BOP Acknowledge computer alarms:
TRB021 Turb Elec Press Reg Cont Off TRB023 Turb Mech Press Reg Cont On Note: There may be other computer alarms present, but these two are the only ones germane to the scenario.
BOP Notify SRO of computer alarms.
BOP Determines Bypass Valve oscillations are occurring and notices MPR and EPR green and red lights are cycling ON and OFF.
BOP LOWER the MPR setpoint until the red MPR CONTROLLING YES light is ON.
BOP RAISE the EPR setpoint until the green EPR CONTROLLING NO light is ON.
BOP Determines that oscillations have stopped.
BOP Notify SRO Bypass Valve oscillations have stopped.
BOP Leave MPR in pressure control.
Notes:
Op-Test No. Scenario No. 1 Event No. 5 Page 1 of 2 Event
Description:
After the bypass valve oscillations have been corrected a trip of the 11 RBCCW Pump will occur with a failure of the standby pump to auto start. The crew will manually start the 12 RBCCW Pump and verify proper system response.
Time Position Actions or Behavior Simulator Operator TRG #3: When directed by the Chief Examiner insert event trigger #3 to cause a trip of the 11 RBCCW Pump with a failure of the 12 RBCCW Pump to auto start.
Note to examiner: Insert trigger when BOP operator is away from panel (i.e. raising speed on the turbine) so that the OATC is closest to the panel and most likely to respond.
SRO Acknowledge report of 6-B-32, RBCCW LOW DISCH PRESS.
SRO Acknowledges report of actions taken to start No. 12 RBCCW Pump.
SRO Acknowledges reports of RWCU and Recirc pump alarms RO Acknowledge annunciator 6-B-32, RBCCW LOW DISCH PRESS.
RO Reports annunciator 6-B-32 to SRO.
RO Verify a RBCCW pump is running.
RO Phone Talker Identifies that No. 11 RBCCW Pump has tripped and No. 12 RBCCW Pump has failed to automatically start.
If directed as TBO to investigate the failure, report that the breaker for the No. 11 RBCCW Pump is tripped.
Note: RO may start 12 RBCCW pump without the C.4 procedure in hand as this is an immediate action.
RO Phone Talker Manually starts No. 12 RBCCW Pump.
If directed as RBO to investigate the failure, report that the No. 12 RBCCW Pump is running satisfactorily and that the No. 11 RBCCW Pump is secured; no indication of the trip.
RO Refers to ARP 6-B-32, RBCCW LOW DISCH PRSS.
Op-Test No. Scenario No. 1 Event No. 5 Page 2 of 2 Event
Description:
After the bypass valve oscillations have been corrected a trip of the 11 RBCCW Pump will occur with a failure of the standby pump to auto start. The crew will manually start the 12 RBCCW Pump and verify proper system response.
Time Position Actions or Behavior RO Phone Talker Notifies Shift Supervision and System Engineer.
When contacted as System Engineering, acknowledge the report and inform the crew that you will investigate the failure.
RO Refers to C.4-B.02.05.A, LOSS OF RBCCW FLOW to verify actions taken.
RO Notify Shift Supervision.
RO Acknowledges ARP 4-B-26 (CLEAN UP DEMIN TEMP HI), 4-B-21 (CLEANUP FILTER DEMIN FAILURE) and 4-B-31 (CLEANUP DEMIN TEMP HI-HI)
RO Verifies RWCU isolates and notifies Control Room Supervisor.
RO Notifies Reactor Building Operator that RWCU has isolated.
RO Acknowledges ARPs 4-B-5 (RECIRC PUMP A LOW COOL WATER FLOW) and 4-B-10 (RECIRC PUMP B LOW COOL WATER FLOW)
Notifies Control Room Supervisor of Recirc Alarms.
RO IF RBCCW System pressure cannot be restored within 60 seconds,
- a.
Trip the Recirc pumps, then execute C.4-B.01.04.B (TRIP OF TWO RECIRC PUMPS) concurrently.
- b. Close RBCCW drywell isolation valves MO-1426, MO-4229 and MO-4230.
Note to examiner: This action is not expected to happen. RBCCW should be returned within 60 seconds.
BOP Monitor plant parameters.
Notes:
Op-Test No. Scenario No. 1 Event No. 6 Page 1 of 2 Event
Description:
At the completion of actions for the trip of the running RBCCW pump a failure of the instrument air header will occur. This event will ultimately result in a manual (or automatic) scram being inserted by the crew. After a scram has been inserted the crew will discover that a hydraulic ATWS has occurred in the West SDV.
Time Position Actions or Behavior Simulator Operator TRG #4: At the completion of actions for trip of the No. 11 RBCCW Pump or when directed by the Chief Examiner, insert event trigger #4 to cause a rupture of the Instrument Air Header.
SRO Acknowledge report of annunciators.
SRO Acknowledge action taken in response to loss of Instrument Air.
SRO Per C.4.K - IMMEDIATE REACTOR SHUTDOWN NOTE: C.4.K actions may not be performed if Instrument Air header pressure decreases too rapidly.
SRO May direct the Reactor Operator to reduce Recirculation flow to minimum or realizes that Recirc flow is already minimum.
SRO Directs the Reactor Operator to manually scram the reactor.
RO Determines Main Feedwater Reg Valves have locked up.
RO May direct Turbine building operator to take local manual control of low flow Feedwater Reg Valves.
Phone Talker If directed as the Tubine building operator to take local manual control of low flow Feedwater Reg Valve, than acknowledge the order.
RO If directed performs steps of C.4.K
- 1. Verifies that Recirc pump speed is at minimum.
RO Recognize control rods are NOT inserted to or beyond position 04.
RO Place the reactor mode switch in SHUTDOWN.
RO Notify Shift Supervision.
Op-Test No. Scenario No. 1 Event No. 6 Page 2 of 2 Event
Description:
At the completion of actions for the trip of the running RBCCW pump a failure of the instrument air header will occur. This event will ultimately result in a manual (or automatic) scram being inserted by the crew. After a scram has been inserted the crew will discover that a hydraulic ATWS has occurred in the West SDV.
Time Position Actions or Behavior BOP Acknowledge annunciators:
6-B-24, INSTRUMENT AIR DRYER BYPASSED.
6-B-30, INSTRUMENT AIR PRESSURE LOW.
6-B-35, SERVICE AIR HEADER LOW PRESS.
BOP Enters C.4-B.08.04.01.A, LOSS OF INSTRUMENT AIR.
BOP Phone Talker Dispatch an operator to verify proper operation of all available air compressors and an instrument air dryer.
When directed as TBO to investigate the Instrument Air header and air compressors wait 2 minutes and then report, A large rupture exists in the instrument air header and I cant find an isolation.
BOP Notifies Shift Supervision.
BOP Makes plant page announcement to secure use of breathing air.
BOP Closes CV-1474, SERVICE AIR ISOLATION.
BOP Makes plant page announcement to secure use of air systems.
Op-Test No. Scenario No. 1 Event No. 7 Page 1 of 4 Event
Description:
After a scram has been inserted the crew will discover that a hydraulic ATWS has occurred in the West SDV. They will be required to enter C.5-2007 FAILURE TO SCRAM and take action to insert control rods.
Time Position Actions or Behavior SRO Enter: C.5-1100 (RPV CONTROL)
SRO Verify Reactor Scram has been initiated.
SRO Determine all rods ARE NOT in to at least 04.
SRO Determine the reactor WILL NOT stay shutdown under all conditions without boron.
SRO Leave C.5-1100 (RPV CONTROL) and Enter C.5-2007 (FAILURE TO SCRAM)
SRO Enter C.5-2007: FAILURE TO SCRAM SRO
- Critical Step
- Critical Step
- Direct the BOP operator to prevent Core Spray injection per C.5-3205.
TERMINATE AND PREVENT.
SRO Directs BOP operator to defeat the Low-Low isolation for MSIVs per C.5-3301 (DEFEATING RPV LOW-LOW LEVEL ISOLATION FOR MISV CLOSURE)
POWER LEG SRO Verify Mode switch in SHUTDOWN.
SRO Directs RO to trip Recirc Pumps.
SRO Direct RO to actuate ATWS.
SRO Directs RO to insert control rods per C.5-3101. ALTERNATE ROD INSERTION
Op-Test No. Scenario No. 1 Event No. 7 Page 2 of 4 Event
Description:
After a scram has been inserted the crew will discover that a hydraulic ATWS has occurred in the West SDV. They will be required to enter C.5-2007 FAILURE TO SCRAM and take action to insert control rods.
Time Position Action or Behavior PRESSURE LEG SRO Determine Drywell pressure is < 2 psig.
SRO Determine SRVs are not rapidly cycling.
SRO Determines PRV pressure can be controlled with main turbine bypass valves.
LEVEL LEG SRO Check Detail A for instrument limits.
SRO Determine no instrument limits have been exceeded.
SRO Directs an operator to maintain RPV water level +9 to 48 using one or more of the following:
CRD RCIC HPCI RO Trip the MG set drive motors.
Place HS 2A-S1A to STOP (#11 MG set drive motor breaker)
Place HS 2A-S1B to STOP (#12 MG set drive motor breaker)
RO Refer to procedure B.05.06-05 ATWS SYSTEM MANUAL INITIATION (hard card)
RO SET the arming collars of one pair of the following switches to the armed position and depress the pushbuttons ATWS A MAN and ATWS C MAN (PB S-5A & S-5C) (CO5)
ATWS B MAN and ATWS D MAN (PB S-5B & S-5D) (CO5)
Op-Test No. Scenario No. 1 Event No. 7 Page 3 of 4 Event
Description:
After a scram has been inserted the crew will discover that a hydraulic ATWS has occurred in the West SDV. They will be required to enter C.5-2007 FAILURE TO SCRAM and take action to insert control rods.
Time Position Actions or Behavior RO Verifies the MG set drive motor breakers are tripped.
RO Determine Control Rods DO NOT insert.
RO Inserts control rods per C.5-3101, ALTERNATE ROD INSERTION, Part C.
RO Determines that Parts A through D are not available due to loss of instrument air.
RO Determines that Part E, MANUALLY OPEN SDV VENT AND DRAIN VALVES, should be performed due to the hydraulic lock on the West SDV.
RO Phone Talker Directs the RBO to determine the position of CV-127, OUTLET SCRAM VALVES, for all West SDV HCUs.
When directed as RBO to determine the position of the CV-127 valves associated with the West SDV HCUs, acknowledge the order. No further response is required.
NOTE: The crew will not actually perform all of the steps of C.5-3101 (ALTERNATE ROD INSERTION), Part E. The next event should begin once the crew has addressed all of the concerns associated with the ATWS.
Op-Test No. Scenario No. 1 Event No. 7 Page 4 of 4 Event
Description:
After a scram has been inserted the crew will discover that a hydraulic ATWS has occurred in the West SDV. They will be required to enter C.5-2007 FAILURE TO SCRAM and take action to insert control rods.
Time Position Actions or Behavior BOP Defeat RPV low-low level isolation for MSIV closure per C.5-3301.
BOP Determines prerequisites are met.
Main condenser available No fuel element failure No steam line break BOP Places the following switches in BYPASS (Panels C-15 and C-17):
16A-S62A 16A-S62C 16A-S62B 16A-S62D BOP
- Critical Step
- Critical Step
- Prevents Core Spray per C.5-3205, TERMINATE AND PREVENT, Part A.
BOP Places MO-1751 CS INJECTION BYPASS handswitch in BYPASS (14A-S16A).
BOP Closes MO-1751.
BOP Places No. 11 Core Spray Pump in PTL.
BOP Places MO-1752 CS INJECTION BYPASS handswitch in BYPASS (14A-S16B).
BOP Closes MO-1752.
BOP Places No. 12 Core Spray Pump in PTL.
Notes:
Op-Test No. Scenario No. 1 Event No. 8 Page 1 of 3 Event
Description:
While trying to insert control rods, a rupture of the West SDV will occur. With a loss of instrument air the operators will not be able to reset the scram, which will result in an un-isolable rupture into the reactor building.
This will result in high radiation levels in the West SDV area and Outside RWCU area causing the crew to emergency depressurize.
Time Position Actions or Behavior Simulator Operator Prior to initiating this event select (highlight) all 61 stuck control rod malfunctions in the Malfunction block of the Summary Screen.
TRG #6: When all of the concerns associated with the ATWS have been addressed or as directed by the Chief Examiner, select the Delete button of the Malfunction Block to remove the stuck rod malfunction for all 61 stuck control rods and then insert event trigger
- 6 to cause a rupture of the West SDV.
SRO Acknowledges report that all control rods have inserted.
SRO Exits C.5-2007 FAILURE TO SCRAM and re-enters C.5-1100 RPV CONTROL.
SRO Phone Talker Acknowledge report of annunciator 4-A-11, REACTOR BUILDING HI RADIATION.
About 2 minutes after initiation of this event or at the discretion of the Chief Examiner, inform the crew as the RP Tech A rupture of the West SDV has occurred.
OR If the RBO was dispatched to the West HCU area, immediately report as the RBO that a rupture of the West SDV has occurred.
SRO Acknowledges report of alarming ARM.
Note: The ARM in the West SDV area of Rx building will be rising quickly.
Eventually it will peg high at 1 R/hr. This will be followed shortly by ARM outside the RWCU rising. It too, will eventually peg high at 1 R/hr.
SRO Enters C.5-1300, SECONDARY CONTAINMENT CONTROL.
SRO Determines that a rupture of the West SDV has occurred.
SRO Directs entry into C.4-B.02.04-A Steam Leak Outside Primary Containment
Op-Test No. Scenario No. 1 Event No. 8 Page 2 of 3 Event
Description:
While trying to insert control rods, a rupture of the West SDV will occur. With a loss of instrument air the operators will not be able to reset the scram, which will result in an un-isolable rupture into the reactor building.
This will result in high radiation levels in the West SDV area and Outside RWCU area causing the crew to emergency depressurize.
Time Position Actions or Behavior SRO Determines that the leak cannot be isolated due to the loss of Instrument Air.
SRO Acknowledges the report that the West CRD HCU and Outside RWCU room are above max safe radiation.
SRO Enters C.5-2002, EMERGENCY RPV DEPRESSURIZATION.
SRO Determines Drywell pressure is below 2 psig.
SRO Determines Torus level is above -5.9 feet.
- Critical Step
RO Determines that all control rods have inserted.
RO Reports to the CRS all rods in.
RO Performs C.4-A, REACTOR SCRAM, Part A actions.
Op-Test No. Scenario No. 1 Event No. 8 Page 3 of 3 Event
Description:
While trying to insert control rods, a rupture of the West SDV will occur. With a loss of instrument air the operators will not be able to reset the scram, which will result in an un-isolable rupture into the reactor building.
This will result in high radiation levels in the West SDV area and Outside RWCU area causing the crew to emergency depressurize.
Time Position Actions or Behavior BOP Acknowledges annunciator 4-A-11, REACTOR BUILDING HI RADIATION.
BOP Checks ARMs on Panel C-11.
BOP Determines that West CRD HCU Area ARM is in alarm.
BOP Notifies CRS of alarming ARM.
BOP Per C.4-B.02.04-A STEAM LEAKS OUTSIDE PRIMARY CONTAINMENT makes plant announcement to evacuate the Reactor Building.
BOP Notifies Radiation Protection to perform surveys and control entry.
BOP Reports that the West CRD HCU and Outside RWCU room are above max safe radiation.
BOP Performs C.4-A, REACTOR SCRAM, Part B actions.
Notes:
Op-Test No. Scenario No. 1 Event No. 9 Page 1 of 1 Event
Description:
When directed to open 3 SRVs to depressurize the vessel, one SRV will fail to open. The operator will be required to notice that one SRV failed to open and to open another SRV to ensure that 3 SRVs are open.
Time Position Actions or Behavior SRO Acknowledges report that one SRV failed to open SRO Directs BOP to open more SRVs until three SRVs are open.
- Critical Step
- Opens all 3 ADS valves.
BOP Determines that the A SRV did not open and informs the CRS.
- Critical Step Opens a third SRV.
Termination Point:
All control rods have been inserted.
3 Safety/Relief Valves are open.
At the discretion of the Chief Examiner.
Classification:
Guideline 28.B (General Emergency) Loss of 2 of 3 Fission Product Barriers with a Potential Loss of the Third
Appendix D Scenario Outline Form ES-D-1 Facility:
MNGP Scenario No.
NRC 03-02 Op-Test No:
03-01 Examiners:
Operators:
Initial Conditions: Reactor power was reduced to approximately 47% last shift to perform some on-line maintenance on the No. 11 RFP. The maintenance is complete and the RFP is ready to start.
Turnover: Start the No. 11 RFP and return to 100% power.
Event No.
Malf.
No.
Event Type*
Event Description 1
N/A BOP (N)
Start the No. 11 RFP 2
N/A RO (R)
Raise Reactor Power with Recirc 3
RR09A RO (C)
A Recirc Speed Control Signal Failure 4
RC02 BOP (C)
RCIC Auto Initiation & Isolation (Tech Spec Call) 5 EG02A BOP (C)
No. 11 Stator Cooling Pump Trip with Failure of No. 12 Pump to Auto Start 6
A165-07 RO (I)
Failure of RPV Level Control Setpoint 7
ED12 M
Loss of Off-Site Power DG02B Failure of No. 12 EDG to Start 8
RR01B M
HPCI Steam Line Break on Start (inside drywell)
(simulated via small Recirc line break) 9 RC03 RO (C)
RCIC Turbine Trip Equipment Out of Service B RWCU Pump APRM Channel #5
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Op-Test No. Scenario No. 2 Event No. 1 Page 1 of 2 Event
Description:
The crew will take the duty with the plant at approximately 47% reactor power. Power was reduced last shift to perform on-line maintenance on the No. 11 RFP. After taking the duty the crew will start the No. 11 RFP.
Time Position Actions or Behavior SRO Direct the BOP to start the No. 11 RFP per B.06.05-05.D.7, PLACING 11 RFP IN SERVICE FROM WARM-UP.
SRO Acknowledges report that No. 11 RFP is in service.
RO Monitoring plant parameters and may act as Peer Checker.
BOP Directs TBO to perform step 5 of B.06.05-05.D.7 PLACING 11 RFP IN SERVICE FROM WARM-UP.
Phone talker When requested to perform step 5 state Step 5 for starting No. 11 RFP is complete.
BOP Places HS-1100, 11 RFP RECIRC VALVE, handswitch in AUTO/START.
BOP Verifies OPEN CV-3489.
BOP Phone Talker Stations an operator at the RFP area, makes a plant announcement and starts the No. 11 RFP.
When directed as TBO to report to the RFP area report that you are standing by in the feed pump area.
BOP Phone Talker Verifies the following: (Note: These are steps 11-13 of the procedure.)
Balance drum flow is 30 - 115 gpm.
Vibration is less than 2.5 mils on all local vibration monitors.
Axial position is between +35 mils and -35 mils.
When directed to verify the following or perform steps 11-13:
Balance drum flow is 30 - 115 gpm.
Vibration is less than 2.5 mils on all local vibration monitors.
Axial position is between +35 mils and -35 mils.
Report that steps 11 though 13 are complete.
BOP Place HS-1100, 11 RFP RECIRC VALVE, handswitch in AUTO.
Op-Test No. Scenario No. 2 Event No. 1 Page 2 of 2 Event
Description:
The crew will take the duty with the plant at approximately 47% reactor power. Power was reduced last shift to perform on-line maintenance on the No. 11 RFP. After taking the duty the crew will start the No. 11 RFP.
Time Position Actions or Behavior BOP Phone Talker Verifies minimum flow of 3300 gpm on local flow controller, FIC-3489.
When requested as TBO to verify minimum flow of 3300 gpm on local flow controller FIC-3489, report minimum flow of 3400 gpm on FIC-3489.
BOP Phone Talker Verifies the following:
Bearing header oil flow is > 8 gpm.
Bearing header discharge pressure is > 6 psig.
When requested to verify bearing header flow and pressure report bearing header flow is 14 gpm and bearing header discharge pressure is 12 psig.
BOP Places the No. 11 RFP Aux Oil pump handswitch to AUTO, pausing momentarily in OFF to allow logic to reset.
BOP Verifies No. 11 RFP Aux Oil Pump has stopped.
BOP Phone Talker Directs out plant operator to: (Note to examiner: May tell TBO to perform steps 18-20 of the procedure.)
Maintain oil temp to bearings at 100 to 120°F.
Ensure seal water drain temperatures are maintained approx. 170°F.
Closes warm-up valves FW-69-1 & FW-70-1.
States that steps 18-20 are complete BOP Verifies the bias setting of the main FW control valve M/A stations is set to maintain approximately equal flow in each feedwater train.
Note to examiner: Bias settings should not require adjustment because feedwater flows are matched.
BOP Verifies final FW temperatures within 3.5°F of each other by comparing computer points CFW524 & CFW525.
Note to examiner: These temperatures do work in the simulator and the candidate should check the process computer to complete this step.
BOP Report to the SRO that #11 RFP is in service Notes:
Op-Test No. Scenario No. 2 Event No. 2 Page 1 of 1 Event
Description:
After the No. 11 RFP has been started the crew will begin to return reactor power to 100%.
Time Position Actions or Behavior SRO Review Official 3D Monitor printout and Periodic Log.
SRO Reviews the Reactivity Adjustment Request form and determines that power should be raised to 70% using Recirc pumps at a rate of ~5 MWe/ minute.
SRO Directs RO to raise Reactor power to 70% using recirc flow.
RO Raise Reactor power to 70% per C.2-05, POWER OPERATION.
BOP Monitoring plant parameters and may act as Peer Checker.
Notes:
Op-Test No. Scenario No. 2 Event No. 3 Page 1 of 2 Event
Description:
While the crew is raising power with Recirc pumps, a failure will occur causing a slow, steady rise in No. 11 Recirc pump speed. The RO should diagnose this failure of speed control and by procedure lock the scoop tube.
Time Position Actions or Behavior Simulator Operator TRG #1: While the crew is raising power with Recirc pumps or at the discretion of the Chief Examiner, insert trigger #1 to cause a speed failure on A Recirc Flow Control.
SRO Acknowledges report from RO that speed continues to increase on the A Recirc Pump.
SRO Directs the RO to perform B.01.04-05.H.1, UNSTABLE SPEED CONTROL ON ONE PUMP.
SRO Acknowledge report from RO of annunciator 4-C-5, FLUID DRIVE A SCOOP TUBE LOCK.
SRO Phone Talker Notifies the Nuclear Engineer.
When informed as the Nuclear Engineer of the loss of speed control on the A Recirc Pump, ask them what the crews plans are and then concur to whatever they say.
SRO May direct the RO to reduce speed locally for the A Recirc Pump, coordinating with licensed RO in-plant, to match B Recirc Pump speed.
Note: If speed mismatch is within specifications, reduction of speed locally is not required.
SRO Phone Talker Notifies the following:
General Superintendent Operations Superintendent Electrical and Instrument Engineering Instrument Engineer Acknowledge report from CRS as the managers stated for the given plant condition.
RO Informs CRS that speed is increasing on the A Recirc Pump.
Op-Test No. Scenario No. 2 Event No. 3 Page 2 of 2 Event
Description:
While the crew is raising power with Recirc pumps, a failure will occur causing a slow, steady rise in No. 11 Recirc pump speed. The RO should diagnose this failure of speed control and by procedure lock the scoop tube.
Time Position Actions or Behavior RO Performs actions from B.01.04-05.H.1, UNSTABLE SPEED CONTROL ON ONE PUMP.
RO Depressed the SCOOP TUBE LOCK pushbutton for the A Recirc Pump.
RO Acknowledges annunciator 4-C-5 FLUID DRIVE A SCOOP TUBE LOCK.
RO Coordinates with in-plant RO to adjust speed of the A Recirc Pump to match speed of the B Recirc Pump.
RO Phone Talker Establishes communications with the RO in-plant.
When directed as in-plant RO, report that communications have been established at the A Recirc MG Set.
RO Phone Talker Simulator Operator Directs the in-plant RO to slowly turn the handcrank in the counter-clockwise direction to lower pump speed.
When directed as in-plant RO to slowly reduce A Recirc Pump speed; coordinate with the simulator operator, begin to reduce pump speed from the simulator computer, and report to the RO that you are turning the handcrank in the counter-clockwise direction.
RO Phone Talker Simulator Operator Stops the in-plant RO when speeds are matched.
When directed as the in-plant RO to stop reducing pump speed stop, coordinate with the simulator operator to stop reducing pump speed and report to the RO that you have stopped turning the handcrank.
RO Informs CRS that Recirc pump speeds are matched.
BOP Monitoring plant parameters and may act as a peer checker.
Notes:
Op-Test No. Scenario No. 2 Event No. 4 Page 1 of 2 Event
Description:
After completing the actions for increasing Recirc pump speed, an automatic initiation of the RCIC system will occur. The crew should work together to diagnose this event by watching reactor water level and RCIC controls and indications. The crew should enter the C.4 to secure RCIC and determine Tech Spec and reportability requirements.
Time Position Actions or Behavior Simulator Operator TRG #2: While increasing reactor power and when directed by the Chief Examiner, insert event trigger #2 to cause an auto initiation of RCIC.
SRO Recognize RCIC has started.
SRO Directs performance of C.4-G INADVERTENT ECCS INITIATION SRO Directs one of the following to shutdown RCIC
- 1. Directs that MO-2080 be closed.
- 2. Manual initiation of a Group V.
SRO Review Technical Specification 3.5.A.2 - 14 day LCO SRO Phone Talker Directs System Eng and I&C to investigate.
When contacted as System Engineering or I&C to investigate RCIC initiation acknowledge the request.
SRO May look into Reportability Requirements, this is normally the duty of the Shift Manager.
(Procedure 4 AWI-04.08.02)
RO Recognize RCIC has started.
RO Acknowledge annunciator 5-B-24 REACTOR WATER LEVEL HI/LO (if actuated).
Note: This assumes RCIC injects and RPV high water level results.
RO Verify RPV water level is >-47 inches as indicated on LI-6-94A & B and LI-2-3-85A & B.
RO Notify Shift Supervision.
Op-Test No. Scenario No. 2 Event No. 4 Page 2 of 2 Event
Description:
After completing the actions for increasing Recirc pump speed, an automatic initiation of the RCIC system will occur. The crew should work together to diagnose this event by watching reactor water level and RCIC controls and indications. The crew should enter the C.4 to secure RCIC and determine Tech Spec and reportability requirements.
Time Position Actions or Behavior BOP Recognize RCIC has started BOP Perform applicable C.4-G INADVERTENT ECCS INITIATION Immediate Operator Actions.
BOP Verify RPV water level >-47 inches.
BOP Verify RPV water level is normal.
BOP Determine manual override is allowed.
BOP Depress the RCIC TURBINE TRIP pushbutton.
Note: This will not trip the RCIC turbine and additional action will be needed.
BOP When directed by the SRO performs one of the following:
- 1. Closes MO-2080.
- 2. Initiates a manual Group V The following steps are the applicable steps for a manual initiation of a Group V.
BOP Closes MO-2075 BOP Closes MO-2080 BOP Report to CRS actions taken and plant conditions.
Notes
Op-Test No. Scenario No. 2 Event No. 5 Page 1 of 2 Event
Description:
After the initiation of RCIC has been addressed a trip of the running stator cooling pump will occur with a failure of the standby pump to auto start. The BOP operator should manually start the standby pump.
Time Position Actions or Behavior Simulator Operator TRG #3: When actions for the initiation of RCIC are completed or when directed by the Chief Examiner, insert event trigger #3 to cause a trip of the Stator Cooling Pump with a failure of the 12 Stator Cooling Pump to auto start.
SRO Acknowledge report of annunciator 8-A-17, NO. 1 GENERATOR COOLING WTR FAILURE.
SRO Acknowledges failure of 11 Stator Cooling Water Pump and manual start of 12 Stator Cooling Water Pump.
RO Monitoring plant parameters.
BOP Acknowledge annunciator 8-A-17 NO. 1 GENERATOR COOLING WTR FAILURE and reports to SRO.
BOP Determines that 11 Stator Cooling Water pump is not running and 12 Stator Cooling Water Pump has not automatically started.
BOP Manually starts 12 Stator Cooling Water Pump.
BOP Consults ARP 8-A-17 NO. 1 GENERATOR COOLING WTR FAILURE.
BOP Phone Talker Determine trouble from annunciator Panel C-83A.
When requested as TBO to check Panel C-83A and report indications wait 3 minutes and report Annunciator C-83A-8, Reserve Pump Running, is in alarm.
Op-Test No. Scenario No. 2 Event No. 5 Page 2 of 2 Event
Description:
After the initiation of RCIC has been addressed a trip of the running stator cooling pump will occur with a failure of the standby pump to auto start. The BOP operator should manually start the standby pump.
Time Position Actions or Behavior BOP Phone Talker Verify a Stator Cooling Water Pump is running.
If asked as TBO to perform post-start checks of 12 Stator Cooling Water Pump wait 2 minutes and report Post start checks of 12 Stator Cooling Water Pump are completed satisfactorily.
BOP Phone Talker Notify Shift Supervisor and System Engineer.
If asked to investigate the trip of the stator cooling water pump as system engineer acknowledge the request.
BOP Refer to C.4-B.6.2.4.A STATOR COOLING WATER FAILURE for further guidance.
BOP Verify a Stator Cooling Water Pump is running.
BOP Notify Shift Supervision.
BOP Determines that no further action is required per C.4-B.6.2.4.A.
BOP Reports failure of 11 Stator Cooling Water Pump and manual start of 12 Stator Cooling Water Pump to SRO.
Notes:
Op-Test No. Scenario No. 2 Event No. 6 Page 1 of 1 Event
Description:
At the completion of actions for the trip of the running stator cooling pump a failure of the reactor water level setpoint on the digital feedwater control system will occur. This will result in a slowly lowering reactor water level and will require the RO to take manual control of both FWRVs.
Time Position Actions or Behavior Chief Examiner Simulator Operator NOTE: This event may need to start before completing actions for the loss of No. 11 Stator Cooling Pump to ensure that the OATC takes the applicable actions.
TRG #4: When actions for loss of 11 Stator Cooling Pump are completed or when directed by the Chief Examiner, insert event trigger #4 to cause a failure of reactor water level setpoint on the digital feedwater control system.
SRO Acknowledge report of annunciator 5-B-24, REACTOR WATER LEVEL HI/LO.
SRO Acknowledge report of actions taken by RO to control reactor water level.
SRO Phone Talker Notifies I&C and System Engineering to investigate.
When contacted as System Engineering or I&C acknowledge the request; no further response is required.
RO Acknowledge annunciator 5-B-24, REACTOR WATER LEVEL HI/LO.
RO Refers to C.4-B.05.07.A, LOSS OF REACTOR WATER LEVEL CONTROL.
RO Takes manual control of both FW Reg Valves to control reactor water level.
Note to examiner: RO must place the control switches for both FW Reg valves in manual to prevent both Reg valves from closing. However, he may only adjust on one Reg valve to actually control the water level.
RO Notifies CRS of actions taken.
RO Controls reactor water level between 30 and 40 inches in manual.
RO Notifies System Engineer to investigate the cause and correct if possible.
BOP Monitoring plant parameters and may assume manual control of reactor water level.
Op-Test No. Scenario No. 2 Event No. 7 Page 1 of 12 Event
Description:
After the crew has manual control of both FWRVs, or if the reactor scrams, then a loss of off-site power with a failure of the No. 12 EDG to start will occur. The crew will need to take level control actions through the use of HPCI, RCIC, CRD and SBLC.
Time Position Actions or Behavior Simulator Operator TRG #5: When RPV level control is in manual or when directed by the Chief Examiner, insert event trigger #5 to cause a loss of offsite power with a concurrent failure of the No.
12 EDG to start.
SRO Phone Talker Notify the Transmission System Operator of the LONOP Condition and determine the status of offsite power. (C.4-B.9.02.B)
If notified of the Loss of Offsite Power and questioned about status report that Transmission System Operator acknowledges the loss of off-site power at Monticello, Grid status is normal. The problem appears to be in your subyard and further investigation will be performed.
SRO Enter C.5-1100, RPV CONTROL.
SRO Verify:
Reactor Scram All rods in to at least 04 SRO Check Detail A for instrument limits.
SRO Verify no instrument limits have been exceeded.
SRO Directs RO/BOP to restore and maintain RPV water level +9 to +48 inches using:
RCIC CRD (C.5-3204 - RPV MAKEUP WITH CRD)
HPCI SBLC NOTE: If RCIC is manually started ensure event trigger #7 automatically inserts to cause RCIC overspeed trip.
NOTE: If HPCI is manually started ensure event trigger #6 automatically inserts to cause HPCI steam line break.
Op-Test No. Scenario No. 2 Event No. 7 Page 2 of 12 Event
Description:
After the crew has manual control of both FWRVs, or if the reactor scrams, then a loss of off-site power with a failure of the No. 12 EDG to start will occur. The crew will need to take level control actions through the use of HPCI, RCIC, CRD and SBLC.
Time Position Actions or Behavior SRO Ascertain that RPV water level cannot be restored and maintained > +9 inches.
SRO Direct BOP operator to inhibit ADS.
NOTE: ADS may have been inhibited per step 1 if the ADS timer started.
SRO Modify RPV water level band to maintain level >-126 inches.
SRO Direct RO to inject with SBLC per C.5-3203 - USE OF ALTERNATE INJECTION SYSTEMS FOR RPV MAKEUP SRO Ascertain that RPV level cannot be maintained >-126 inches.
SRO Proceed to Step 2 in C.5-1100. (RPV CONTROL)
SRO Direct BOP operator to start Div 1 LPCI and Core Spray pumps (if not already running) such that a minimum of two (2) injection subsystems are running.
SRO Verify two or more injection subsystems lined up.
SRO Determine RPV level has dropped to -126 inches.
SRO Verify any injection source lined up with pump running.
SRO Enters C.5-2002 - EMERGENCY RPV DEPRESSURIZATION, before water level drops to -149 inches, while continuing on in 1100 step 5.
SRO C.5-2002 - EMERGENCY RPV DEPRESSURIZATION SRO Verify all rods inserted.
Op-Test No. Scenario No. 2 Event No. 7 Page 3 of 12 Event
Description:
After the crew has manual control of both FWRVs, or if the reactor scrams, then a loss of off-site power with a failure of the No. 12 EDG to start will occur. The crew will need to take level control actions through the use of HPCI, RCIC, CRD and SBLC.
Time Position Actions or Behavior SRO Verify drywell pressure >2 psig.
SRO Determine Core Spray and LPCI injection IS required for core cooling and leave pumps running.
SRO Verify Torus level >-5.9 ft.
SRO Critical Step Direct BOP operator to open 3 ADS valves.
SRO Continue C.5-1100 RPV CONTROL SRO Verify 1 Core Spray and 1 RHR pump available.
SRO Verify injection to the RPV with running injection systems.
SRO When RPV level can be restored and maintained above -126 inches then return to C.5-1100 step 1.
SRO Modify level band to restore and maintain RPV water level +9 to +48 inches.
SRO Direct Core Spray and LPCI injection be prevented, as necessary, to maintain water level per C.5-3205 - TERMINATE AND PREVENT.
RO Carry out actions of C.4.A REACTOR SCRAM RO Determine all control rods are inserted to or beyond position 04.
RO Place the reactor mode switch in SHUTDOWN.
Op-Test No. Scenario No. 2 Event No. 7 Page 4 of 12 Event
Description:
After the crew has manual control of both FWRVs, or if the reactor scrams, then a loss of off-site power with a failure of the No. 12 EDG to start will occur. The crew will need to take level control actions through the use of HPCI, RCIC, CRD and SBLC.
Time Position Actions or Behavior RO Notify Shift Supervision.
RO Verify that the Recirc pumps have tripped.
RO Control Reactor water level between +9 and +48.
RO Simulator Operator Verify HPCI or RCIC initiate to restore and control Reactor water level.
Note: RCIC must be started manually and HPCI may be started manually prior to automatic initiation at -47 inches.
NOTE: Verify that RCIC trips on overspeed (Trigger #7) and HPCI steam line rupture occurs (Trigger #6) on start of RCIC and HPCI.
RO Insert SRM and IRM detectors.
RO Verify the Scram Discharge Vent and Drain Valves close.
RO Phone Talker Direct the TBO to verify proper operation of the EDG SW pumps and verify EDG room ventilation is operating properly.
If contacted as TBO to verify proper operation of EDG SW pumps and EDG room ventilation acknowledge direction, no further communication is necessary.
RO Enter C.5-3204 RPV MAKEUP WITH CRD RO Verify 11 CRD pump is available.
RO Verify CRD is not being used to insert control rods.
RO Verifies RBCCW flow established to CRD pumps.
Note to examiner: This step cannot be accomplished until the BOP operator completes the applicable steps of C.4-H RESTORATION OF PLANT LOADS
Op-Test No. Scenario No. 2 Event No. 7 Page 5 of 12 Event
Description:
After the crew has manual control of both FWRVs, or if the reactor scrams, then a loss of off-site power with a failure of the No. 12 EDG to start will occur. The crew will need to take level control actions through the use of HPCI, RCIC, CRD and SBLC.
Time Position Actions or Behavior RO Phone Talker Direct the RBO to:
Verify CLOSED CRD-168.
Verify OPEN CRD-8.
Verify OPEN CRD-30.
Close CRD 7-1.
When directed as RBO to perform the following:
Verify CLOSED CRD-168 Verify OPEN CRD-8 Verify OPEN CRD-30 Close CRD 7-1 & CRD 7-2 After approximately 2 minutes report that you have accomplished the above listed items.
RO Locate Part E of procedure C.5-3203 - USE OF ALTERNATE INJECTION SYSTEMS FOR RPV MAKEUP.
RO Verify No. 11 (A) SBLC pump is available.
RO Query the CRS as to the desired SBLC suction source: (either is permissible)
Boron Tank or Demin Water RO If directed to use the boron tank suction, perform the following:
RO Verify SBLC in standby readiness.
RO Start 11 or 12 SBLC pump from CO5.
RO Place HS 11A-S1 on CO5 to SYS 1 or SYS 2.
Op-Test No. Scenario No. 2 Event No. 7 Page 6 of 12 Event
Description:
After the crew has manual control of both FWRVs, or if the reactor scrams, then a loss of off-site power with a failure of the No. 12 EDG to start will occur. The crew will need to take level control actions through the use of HPCI, RCIC, CRD and SBLC.
Time Position Actions or Behavior RO Phone Talker Direct the RBO to attempt to fill the SBLC tank with any of the following:
Demin Water Condensate Service Water Fire System If directed as RBO to attempt to fill the SBLC tank, wait approximately 2 minutes and report that valves have been repositioned.
RO If directed to line up Demin water to the SBLC suction, perform the following RO Direct the RBO to CLOSE XP-1.
RO Direct the RBO to OPEN DM-56.
Phone Talker If directed to line up Demin water to fill the SBLC tank, wait approximately 2 minutes and report that valve XP-1 is closed and valve DM-56 is open.
RO Start 11 or 12 SBLC pump from CO5.
RO Place HS 11A-S1 on CO5 to SYS 1 or SYS 2.
BOP Carry out actions of C.4.A REACTOR SCRAM BOP Verify 8N4 and 8N5 are open.
BOP Verify the Turbine is tripped.
BOP Verify the Turbine-Generator field breaker is OPEN.
Op-Test No. Scenario No. 2 Event No. 7 Page 7 of 12 Event
Description:
After the crew has manual control of both FWRVs, or if the reactor scrams, then a loss of off-site power with a failure of the No. 12 EDG to start will occur. The crew will need to take level control actions through the use of HPCI, RCIC, CRD and SBLC.
Time Position Actions or Behavior BOP Carry out actions of C.4-B.9.2.B LOSS OF NORMAL OFFSITE POWER BOP Notify Shift Supervision.
BOP Place the following C-O8 switches in the position noted.
Control Switch Breaker Position 152-301/CS 2R XFMR SEC TO 13 BUS NORMAL AFTER TRIP 152-101/CS 2R XFMR SEC TO 11 BUS NORMAL ATER TRIP 152-201/CS 2R XFMR SEC TO 12 BUS NORMAL AFTER TRIP 152-401/CS 2R XFMR SEC TO 14 BUS NORMAL AFTER TRIP 52-209/CS 101/102 LC TIE ACB 52-908 PULL-TO-LOCK 52-908/CS 109/102 LC TIE ACB 52-908 PULL-TO-LOCK BOP Verify 1AR Voltmeter indicates zero volts.
BOP Place the following C-08 switches in the position noted.
Control Switch Breaker Position 152-511/CS 1AR TRANS TO 15 BUS PULL-TO-LOCK 152-610/CS 1AR TRANS TO 16 BUS PULL-TO-LOCK BOP If Bus 16 is de-energized perform the following:
BOP Place the following control switches on C-03 in the position noted.
Control Switch Breaker Position 152-604/CS 12 RHR PUMP (10A-S2B) PULL-TO-LOCK 152-603/CS 12 RHR PUMP (10A-S2B) PULL-TO-LOCK 152-605/CS 12 CS PUMP (14A-S5B) PULL-TO-LOCK
Op-Test No. Scenario No. 2 Event No. 7 Page 8 of 12 Event
Description:
After the crew has manual control of both FWRVs, or if the reactor scrams, then a loss of off-site power with a failure of the No. 12 EDG to start will occur. The crew will need to take level control actions through the use of HPCI, RCIC, CRD and SBLC.
Time Position Actions or Behavior BOP Place the following control switches on C-08 in the position noted.
Control Switch Breaker Position 152-610/CS 1AR TRANS TO 16 BUS PULL-TO-LOCK 152-602/CS 12 STDBY DG TO BUS 16 PULL-TO-LOCK BOP Phone Talker Initiate an investigation to determine the status of the No. 12 EDG.
If contacted as System Engineer or the Turbine Building Operator to investigate the cause of the failure of No. 12 EDG to start, report that you will investigate the problem.
Wait approximately 3 minutes and than call back to the control room and state There are no indications of a problem and the diesel appears to be in a proper standby condition and is read to start.
BOP Place DG2/CS, 12 EDG CS, in PTL.
Op-Test No. Scenario No. 2 Event No. 7 Page 9 of 12 Event
Description:
After the crew has manual control of both FWRVs, or if the reactor scrams, then a loss of off-site power with a failure of the No. 12 EDG to start will occur. The crew will need to take level control actions through the use of HPCI, RCIC, CRD and SBLC.
Time Position Actions or Behavior BOP Directs Turbine building operator to press both local ENGINE STOP pushbuttons on C-94 simultaneously.
BOP When the report that 12 Diesel appears to be ready to be started, operator may attempt to start 12 Diesel.
- 1. Places 152-602/CS in AUTO
- 2. Places DG2/CS in START Simulator Operator If BOP operator starts 12 Diesel. Allow Diesel to be started and place on the bus then trip the Diesel.
BOP Determines 12 EDG trips after starting and reports to the CRS.
BOP Verify a Service Water Pump is running.
NOTE: No. 11 Service Water Pump breaker remains closed therefore
- 11 Service Water Pump will automatically restart when power is restored to Bus #15.
NOTE: RBCCW will trip and must be restarted after power is restored via the EDGs.
BOP CRD Pumps will trip and must be restarted after power is restored via the EDGs.
NOTE: CRD Pumps will trip and must be restarted after power is restored using C.4-H. This procedure is showed on page 21.
Op-Test No. Scenario No. 2 Event No. 7 Page 10 of 12 Event
Description:
After the crew has manual control of both FWRVs, or if the reactor scrams, then a loss of off-site power with a failure of the No. 12 EDG to start will occur. The crew will need to take level control actions through the use of HPCI, RCIC, CRD and SBLC.
Time Position Actions or Behavior BOP Place the following switches on C-06 in the position noted.
Control Switch Position 11 REACTOR FEED PUMP P-2A STOP 12 REACTOR FEED PUMP P-2B STOP 11 CONDENSATE PUMP P-1A STOP 12 CONDENSATE PUMP P-1B STOP 11 CIRC WATER PUMP P-100A TRIP S/D 12 CIRC WATER PUMP P-100B TRIP S/D BOP Restore Drywell Cooling as conditions allow.
BOP Drywell Cooling fans will trip on the ECCS load shed.
NOTE: Drywell Cooling fans will restart but the fan dampers must be opened.
BOP Verify the Emergency Diesel Generators meet the following load limitations during the performance of procedure.
2500 KW 2750 KW 3050 KW Continuous 2000 hrs 30 min BOP Verify start of the Emergency Seal Oil Pump.
BOP Start the Turning Gear Oil Pump.
BOP Phone Talker Direct the TBO to verify proper operation of #13 Diesel Generator.
When directed as the TBO to verify proper operation of the No. 13 EDG wait 4 minutes and reply, The No. 13 EDG is operating properly.
Op-Test No. Scenario No. 2 Event No. 7 Page 11 of 12 Event
Description:
After the crew has manual control of both FWRVs, or if the reactor scrams, then a loss of off-site power with a failure of the No. 12 EDG to start will occur. The crew will need to take level control actions through the use of HPCI, RCIC, CRD and SBLC.
Time Position Actions or Behavior BOP C.4-H, Part C, Step 6, Div. I ECCS Load Shed bypass.
NOTE: When high drywell pressure (+2 psig) is reached an ECCS load shed will occur which trips operating Service Water, RBCCW, CRD pumps and Drywell Cooling fans. Part C, step 6, of C.4-H RESTORATION OF PLANT LOADS must be performed to restore Div. I loads. Personnel availability may preclude entering C.4-H until EOP Containment Control (1200 series) actions are complete.
BOP Place 11 Instrument and Service Air Compressor to OFF.
BOP Place 11 Service Water Pump handswitch 52-305/CS in STOP.
BOP Place 11 RBCCW Pump P-6A handswitch 42-3318/CS in STOP.
BOP Verify A CGCS Containment isolation switches CS-1A &
CS-2A are in close. (Panel C-291A)
BOP Place Drywell Fan control switches 42-3312/CS (V-RF-1) and 42-3313/CS (V-RF-3) in OFF.
BOP Boot contacts 7-8 on Relay 14A-K1A. (Div. I Bypass)
BOP Start loads as necessary (see attached procedures).
BOP 11 Service Water Pump per steps 1 - 10 of B.08.01.01-05.D.1 BOP 11 RBCCW Pump per steps 1 - 14 of B.02.05-05.D.1 BOP 11 Instrument & Service Air Compressors per steps 1 - 16 of B.08.04.01-05.D.1
Op-Test No. Scenario No. 2 Event No. 7 Page 12 of 12 Event
Description:
After the crew has manual control of both FWRVs, or if the reactor scrams, then a loss of off-site power with a failure of the No. 12 EDG to start will occur. The crew will need to take level control actions through the use of HPCI, RCIC, CRD and SBLC.
Time Position Actions or Behavior BOP 11 and 13 Drywell Fans per steps 1 - 10 of B.08.16-05.D.1 BOP 11CRD Pump per steps 1 - 15 of B.01.03-05.D.1 BOP Place switches 2E-S7A & 2E-S7B on CO3 to INHIBIT.
BOP Place hand switches on CO3 for RHR and Core Spray pumps to START as directed.
_____ 11 RHR PUMP (HS 10A-S2A)
_____ 13 RHR PUMP (HS 10A-S3A)
_____ 11 CORE SPRAY (HS 14A-S5A)
BOP Verifies No. 11 EDG meets the following load limitations during the performance of procedure C.4-B.9.02.B.
2500 KW 2750 KW 3050 KW Continuous 2000 hrs 30 min BOP Critical Step Place hand switches for A, C & D SRVs to OPEN.
Notes:
Op-Test No. Scenario No. 2 Event No. 8 Page 1 of 7 Event
Description:
When HPCI starts a steam line rupture from the HPCI system will occur. This will prevent HPCI from injecting into the reactor. If RCIC is manually started it will trip on overspeed. This will result in reactor water level continuing to lower until a blowdown is required. In addition to the HPCI steam line break, a small Recirc line break will occur simultaneously to help cause drywell pressure and temperature to rise. The crew will need to prioritize the needs of the low pressure systems for core cooling and containment control.
Time Position Actions or Behavior SRO Acknowledge Annunciator 5-B-28 DRYWELL HI PRESS SCRAM TRIP SRO Confirm Drywell high pressure as indicated on PR-2994 (CO4) and SPDS SRO Enter C.5-1200 PRIMARY CONTAINMENT CONTROL.
SRO Determine Drywell pressure >2 psig SRO Go to step 17 SRO Verify Torus level <14.1 ft and Torus pressure >2 psig.
SRO Critical Step Direct BOP operator to start Torus spray per C.5-3502 - CONTAINMENT SPRAY.
NOTE: If it is determined that RHR pumps are needed for core cooling, Torus spray will not be initiated until RPV level is restored.
SRO Determine Drywell pressure >12 psig.
SRO Verify within Fig. N, DW SPRAY LIMIT (SPDS 79)
SRO Verify Torus level below 4.3 ft.
SRO Verify Recirc Pumps have tripped
Op-Test No. Scenario No. 2 Event No. 8 Page 2 of 7 Event
Description:
When HPCI starts a steam line rupture from the HPCI system will occur. This will prevent HPCI from injecting into the reactor. If RCIC is manually started it will trip on overspeed. This will result in reactor water level continuing to lower until a blowdown is required. In addition to the HPCI steam line break, a small Recirc line break will occur simultaneously to help cause drywell pressure and temperature to rise. The crew will need to prioritize the needs of the low pressure systems for core cooling and containment control.
Time Position Actions or Behavior SRO Direct BOP operator to place DW COOLING FAN CONTROL SWITCHES in OFF.
SRO Critical Step Direct BOP operator to start Drywell spray per C.5-3502.
NOTE: Drywell spray will not be initiated until RPV level is restored.
SRO Direct BOP operator to stop Torus spray if Torus pressure drops below 2 psig.
SRO Direct BOP operator to stop Drywell spray if Drywell pressure drops below 2 psig.
SRO Direct BOP operator to start all available DW cooling per C.5-3503 - DEFEAT DRYWELL COOLER TRIPS SRO Maintain Torus level -4.0 to +3.0 inches SRO Determine that Torus level can be maintained <+4.3 ft and >-3.3 ft. (steps 15 &
19)
SRO Determine that Torus temperature cannot be maintained <90 deg F.
SRO Direct BOP operator to place Torus cooling in service.
NOTE: If it is determined that RHR pumps are needed for core cooling, Torus Cooling will not be initiated until RPV water level is restored.
SRO Direct BOP operator to perform procedure C.5-3501 - H2/O2 ANALYZER OPERATION, as time permits.
BOP Critical Step Start Div 1 Torus Spray per C.5-3502 - CONTAINMENT SPRAY, Part A.
Op-Test No. Scenario No. 2 Event No. 8 Page 3 of 7 Event
Description:
When HPCI starts a steam line rupture from the HPCI system will occur. This will prevent HPCI from injecting into the reactor. If RCIC is manually started it will trip on overspeed. This will result in reactor water level continuing to lower until a blowdown is required. In addition to the HPCI steam line break, a small Recirc line break will occur simultaneously to help cause drywell pressure and temperature to rise. The crew will need to prioritize the needs of the low pressure systems for core cooling and containment control.
Time Position Actions or Behavior BOP Place CONTAINMENT SPRAY 2/3 CORE HEIGHT BYPASS switch to MANAUL OVERRIDE.
BOP Place CONTAINMENT SPRAY/COOLING LPCI INITIATION BYPASS switch to BYPASS.
BOP Open MO-2006.
BOP Open MO-2010.
BOP Throttle open MO-2008.
BOP Verify closed, if necessary:
MO-2012 MO-2013 BOP Verify CV-1728 controller set at 20%.
BOP Close MO-2002.
BOP Place 11 and 13 RHRSW PUMPS LPCI AND ECCS LOAD SHED MANUAL OVERRIDE switch to MANUAL OVERRIDE.
BOP Place 11 or 13 RHRSW Pump in PTL.
BOP Start 11 or 13 RHRSW Pump.
Note: Operator will start the Pump that was NOT previously placed in PTL.
BOP Adjust RHRSW flow using CV-1728.
Op-Test No. Scenario No. 2 Event No. 8 Page 4 of 7 Event
Description:
When HPCI starts a steam line rupture from the HPCI system will occur. This will prevent HPCI from injecting into the reactor. If RCIC is manually started it will trip on overspeed. This will result in reactor water level continuing to lower until a blowdown is required. In addition to the HPCI steam line break, a small Recirc line break will occur simultaneously to help cause drywell pressure and temperature to rise. The crew will need to prioritize the needs of the low pressure systems for core cooling and containment control..
Time Position Actions or Behavior BOP Verify MO-2002 closed.
BOP Place DW COOLING FAN CONTROL SWITCHES in OFF.
BOP Critical Step Start Div 1 Drywell Spray per C.5-3502 - CONTAINMENT SPRAY, Part C.
BOP Place CONTAINMENT SPRAY 2/3 CORE HEIGHT BYPASS switch to MANAUL OVERRIDE.
BOP Place CONTAINMENT SPRAY/COOLING LPCI INITIATION BYPASS switch to BYPASS.
BOP Open MO-2020.
BOP Open MO-2022.
BOP Verify closed MO-2008.
BOP Verify closed, if necessary:
MO-2012 MO-2013 BOP Verify CV-1728 controller set at 20%.
BOP Close MO-2002.
BOP Place 11 and 13 RHRSW PUMPS LPCI AND ECCS LOAD SHED MANUAL OVERRIDE switch to MANUAL OVERRIDE.
Op-Test No. Scenario No. 2 Event No. 8 Page 5 of 7 Event
Description:
When HPCI starts a steam line rupture from the HPCI system will occur. This will prevent HPCI from injecting into the reactor. If RCIC is manually started it will trip on overspeed. This will result in reactor water level continuing to lower until a blowdown is required. In addition to the HPCI steam line break, a small Recirc line break will occur simultaneously to help cause drywell pressure and temperature to rise. The crew will need to prioritize the needs of the low pressure systems for core cooling and containment control.
Time Position Actions or Behavior BOP Place 11 or 13 RHRSW Pump in PTL.
BOP Start 11 or 13 RHRSW Pump.
BOP Adjust RHRSW flow using CV-1728.
BOP Verify MO-2002 closed.
BOP Stops Torus spray if Torus pressure drops below 2 psig.
BOP Close MO-2010.
BOP Stops Drywell spray if Drywell pressure drops below 2 psig.
BOP Close MO-2020.
BOP Close MO-2022.
BOP Perform procedure C.5-3503 - DEFEAT DRYWELL COOLER TRIPS BOP Place all DW cooling fan control switches to OFF.
BOP OPEN knife switch KS3100 (behind panel C25).
BOP Verify FAN INLET DAMPER control switches in AUTO (C25).
BOP Place DW cooling fan control switch in ON.
Op-Test No. Scenario No. 2 Event No. 8 Page 6 of 7 Event
Description:
When HPCI starts a steam line rupture from the HPCI system will occur. This will prevent HPCI from injecting into the reactor. If RCIC is manually started it will trip on overspeed. This will result in reactor water level continuing to lower until a blowdown is required. In addition to the HPCI steam line break, a small Recirc line break will occur simultaneously to help cause drywell pressure and temperature to rise. The crew will need to prioritize the needs of the low pressure systems for core cooling and containment control.
Time Position Actions or Behavior BOP OPEN associated discharge dampers for started fans.
BOP Perform procedure B.03.04-05.H.3 - TRANSFERRING A RHR FROM LPCI TO TORUS COOLING UNDER LOSS OF NORMAL OFF-SITE POWER CONDITIONS DURING ABNORMAL AND EMERGENCY CONDITIONS.
BOP Verify CV-1728 controller is set at 20%.
BOP Verify 11 and 13 RHRSW PUMPS LPCI AND ECCS LOAD SHED MANUAL OVERRIDE switch is in MANUAL OVERRIDE.
BOP Place CONTAINMENT SPRAY 2/3 CORE HEIGHT BYPASS switch to MANAUL OVERRIDE.
BOP Place CONTAINMENT SPRAY/COOLING LPCI INITIATION BYPASS switch to BYPASS.
BOP Verify closed MO-2002.
BOP Verify 11 or 13 RHR Pump in PTL.
BOP Verify 11 or 13 RHRSW Pump is running.
BOP Adjust RHRSW flow to approximately 3500 gpm using CV-1728.
BOP Partially open MO-2008 by holding handswitch to OPEN for 8 seconds.
Op-Test No. Scenario No. 2 Event No. 8 Page 7 of 7 Event
Description:
When HPCI starts a steam line rupture from the HPCI system will occur. This will prevent HPCI from injecting into the reactor. If RCIC is manually started it will trip on overspeed. This will result in reactor water level continuing to lower until a blowdown is required. In addition to the HPCI steam line break, a small Recirc line break will occur simultaneously to help cause drywell pressure and temperature to rise. The crew will need to prioritize the needs of the low pressure systems for core cooling and containment control.
Time Position Actions or Behavior BOP Open MO-2006.
BOP Close MO-2012 or MO-2013 while throttling open MO-2008 to maintain approximately 4000 gpm total flow.
BOP Verify MO-2002 closed.
BOP Phone Talker Verify V-AC-5 in operation.
If directed as RBO to verify V-AC-5 is in operation then wait 2 minutes and report, V-AC-5 is operating normally.
BOP Perform C.5-3501 - H2/O2 ANALYZER OPERATION.
Notes:
Op-Test No. Scenario No. 2 Event No. 9 Page 1 of 1 Event
Description:
If RCIC is manually started it will trip on overspeed. This will result in reactor water level continuing to lower until a blowdown is required.
Time Position Actions or Behavior SRO May direct RCIC be started manually.
SRO Acknowledges that RCIC tripped on overspeed.
BOP If directed to manually start RCIC, perform the following:
BOP Verify flow controller in AUTO and set at 80%.
BOP OPEN MO-2096, RCIC Cooling Water Supply valve.
BOP Place P-211 (RCIC Barometric condenser Vacuum Pump Handswitch 13A-S15, in the START position.
BOP OPEN CV-2104, RCIC Pump Minimum Flow Valve BOP Open the following:
- a.
MO-2107, RCIC Pump Disch Inbd valve.
Note to examiner: The following steps are not per the procedure but may be required depending on how Recirc was secured in Event #3.
BOP Opens the following valves.
MO-2075 MO-2080 BOP Verify the following valves are closed:
- a.
CV-2848 and CV-2849, RCIC Cond Pump Discharge to CRW
- b. CV-2082A and CV-2082B, RCIC Steam Line Drain to Main Condenser BOP Verify SI-7321, RCIC Turbine Speed Indicator is increasing, indicating that unit is rolling BOP Verify AO-13-22, RCIC Injection Testable Ckv, is open BOP Verify RCIC pump flow is maintained at desired level.
BOP Determines RCIC trips on overspeed and informs the CRS.
Termination Point:
Low pressure systems are injecting into the RPV.
RPV level is above the top of active fuel.
At the discretion of the Lead Evaluator.
Classification:
Classification: Guideline 4 (Reactor Coolant Leak); Site Area Emergency
Appendix D Scenario Outline Form ES-D-1 Facility:
MNGP Scenario No. NRC 03-03 Op-Test No:
03-01 Examiners:
Operators:
Initial Conditions: The plant is operating at approximately 14% power. The Main Turbine has been placed on-line and the next step is to place the Main Turbine Generator in service. Ops Man C.1 is complete through step VII.C.4.
Turnover: Place the Main Turbine Generator in service and continue power increase.
Event No.
Malf.
No.
Event Type*
Event Description 1
N/A BOP (N)
Synchronize the Main Generator to the Grid.
2 N/A RO (R)
Increase Power by Pulling Control Rods.
3 CH08A RO (C)
Trip of No. 11 CRD Pump.
4 A28 BOP (C)
Steam Packing Exhauster High Temperature 5
C08 C13 C18 M
ED05C BOP (C)
Loss of No. 13 Bus 7
RR04A RR24 RR04B M
Nuclear Boiler Reference Line Break (results in loss of all level indication)
Equipment Out of Service B RWCU Pump APRM Channel #5
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Op-Test No. Scenario No. 3 Event No. 1 Page 1 of 5 Event
Description:
The Main Turbine has been placed in service by the previous shift. The crew will take the shift and then place the Main Generator in service.
Time Position Actions or Behavior SRO Direct the BOP Operator to synchronize the Main Generator to the grid.
SRO Acknowledge that Main Generator has been synchronized to the grid.
RO Monitoring plant parameters and may act as Peer Checker BOP Place the synchronizing switch for 8N4 or 8N5 in ON and verify the following:
(8N4SS or 8N5SS) (PROCEDURE C.1, STEP VII.C.5)
BOP Synchronizer pointer is moving. (Synchronizing meter CO8)
BOP Synchronizing Voltmeters and sensing lights are activated.
(Running and Incoming voltage meters CO8)
(White sensing lights below synchronizing meter CO8)
BOP Using the Speed Load Changer control switch, ADJUST generator speed until synchronous pointer rotation of one revolution in 30 - 120 seconds is achieved.
BOP Verify Generator Voltage is between 20.9 KV and 23.1 KV.
(Main Generator voltage meter CO8)
BOP Using the Manual Voltage Adjust control switch, ADJUST incoming voltage to match running voltage. (Running and Incoming voltage meters CO8)
BOP Verify the synchroscope makes at least two complete revolutions.
BOP Load the Main Generator by performing the following:
BOP Verify the synchrocope pointer is in the GREEN band.
Op-Test No. Scenario No. 3 Event No. 1 Page 2 of 5 Event
Description:
The Main Turbine has been placed in service by the previous shift. The crew will take the shift and then place the Main Generator in service.
Time Position Actions or Behavior BOP Place either 8N4 or 8N5 control switch to close for approx. 1 sec.
(Closed indication for the output breaker is indicated by RED lamp indication above the breaker and generator load present)
BOP If the selected output breaker does not close place the breaker control switch to TRIP and return to step 1 above.
BOP Phone Talker If the selected output breaker does not close on the second attempt, DO NOT reset the breaker and notify System Engineer.
If contacted as System Engineering because the output breaker will not close state that you will investigate. Wait 1 minute than contact the control room and state that you could not find anything wrong and that you have received permission to attempt a third time.
Chief Examiner NOTE: If the breaker does not close the second time, the operator will stop attempting and contact the system engineer to investigate. System engineer will allow another attempt.
BOP Place the SPEED LOAD CHANGER to RAISE and increase load to approximately 30 Mwe. (HS SLCM CO8)
BOP Verify phase-to-phase voltages are approx. equal. (HS VS1 CO8)
(Main Generator voltage meter CO8)
BOP Verify phase-to-phase currents are approx. equal.
(3 Generator Amperage meters CO8)
BOP Place synchroscope to OFF and remove handle from switch.
BOP LOG in the Control Room log.
BOP Phone Talker Direct TBO to locally inspect the No. 1 Generator Transformer area and 345KV disconnects.
If directed as the TBO to inspect the No. 1 Generator Transformer area and 345KV disconnects wait 2 minutes and report back that everything appears normal.
Op-Test No. Scenario No. 3 Event No. 1 Page 3 of 5 Event
Description:
The Main Turbine has been placed in service by the previous shift. The crew will take the shift and then place the Main Generator in service.
Time Position Actions or Behavior BOP Place the other output breaker synchronizing switch to ON and verify.
BOP Incoming and Running voltmeters are matched.
BOP Synchroscope indicated frequency is matched.
BOP CLOSE the selected output breaker. (8N4/CS or 8N5/CS)
BOP Verify phase-to-phase voltages are approx. equal. (HS VS1 CO8)
(Main Generator voltage meter CO8)
BOP Verify phase-to-phase currents are approx. equal.
(3 Generator Amperage meters CO8)
BOP Place synchroscope to OFF and remove handle from switch.
BOP LOG in the Control Room log.
BOP Phone Talker Notify the Transmission System Operator.
If notified as Transmission System Operator of Generator synchronization, acknowledge report.
BOP CLOSE the following valves:
MO-1197 (HS 1197 CO7)
MO-1184 (HS 1184 CO7)
MO-1185 (HS 1185 CO7)
MO-1186 (HS 1186 CO7)
MO-1187 (HS 1187 CO7)
MO-1180 (HS-1180 CO7)
MO-1181 (HS-1181 CO7)
MO-1182 (HS-1182 CO7)
MO-1183 (HS-1183 CO7)
Op-Test No. Scenario No. 3 Event No. 1 Page 4 of 5 Event
Description:
The Main Turbine has been placed in service by the previous shift. The crew will take the shift and then place the Main Generator in service.
Time Position Actions or Behavior BOP ZERO the No. 1 MAIN GENERATOR AMPLIDYNE VOLTAGE using the REGULATOR VOLTAGE ADJUST. (CS-70 CO8)
BOP Place the REGULATOR TRANSFER switch to AUTO. (243/CS CO8)
BOP Verify the white and red lights above the switch are ON.
BOP Phone Talker ADJUST MVAR loading per system dispatch. (CS-90 CO8) (MVAR digital display)
When contacted as Transmission System Operator to determine what MVAR loading should be maintained at, direct to maintain MVAR loading between +10 and +20 MVAR.
BOP ZERO the No. 1 MAIN GENERATOR AMPLIDYNE VOLTAGE using the MANUAL VOLTAGE ADJUST. (CS-70 CO8)
BOP NOTE: The following steps place the Power System Stabilizer in service. These steps will not be completed.
Verify the Automatic Voltage Regulator is in service.
(white and red lights above the switch are ON)
Verify the No. 1 MAIN GENERATOR AMPLIDYNE VOLTAGE meter is at ZERO.
PRESS the Power System Stabilizer START button on CO8.
Verify the RED light below the button is ON.
BOP Verify Exhaust Hood Temperature is < 125 deg F.
(SPDS 654, Pt. TRB138 or TR-1717 Pts. 16 & 17)
BOP RAISE (slowly) the SPEED/LOAD CHANGER to increase generator load.
BOP Verify the SPEED/LOAD CHANGER is no longer controlling.
Op-Test No. Scenario No. 3 Event No. 1 Page 5 of 5 Event
Description:
The Main Turbine has been placed in service by the previous shift. The crew will take the shift and then place the Main Generator in service.
Time Position Actions or Behavior BOP RAISE the SPEED/LOAD CHANGER setpoint to the high speed stop (107%).
BOP SELECT SPDS Format 701 and monitor Generator Gross Rate of Change.
BOP Report to the SRO that the Main Generator has been synchronized to the grid.
Notes:
Op-Test No. Scenario No. 3 Event No. 2 Page 1 of 1 Event
Description:
The crew will increase Reactor power using control rods in accordance with the roller tape starting at Step 30 rod 14-39.
Time Position Actions or Behavior SRO Phone Talker C.1.VIII - Power Ascension Verify outside air temperature is > 32 deg.
Verify Isophase Bus Blower in service.
If directed to verify that Isophase Bus Blower is in service report that the Isophase Bus Blower is in service.
SRO Phone Talker Direct RBO to reduce RWCU flow to 140 GPM.
When directed to reduce RWCU flow to 140 gpm wait 2 minutes, verify that the Simulator Operator has reduced flow to 140 gpm, and then report that RWCU flow has been reduce to 140 gpm.
SRO Reviews Reactivity Adjustment Request and determines that reactor power should be raised to 30% power using control rods per C.2-05 Power Operation - System Operation.
- Direct the RO to commence Control Rod Withdrawal continuing at step 30, Control Rod 14-39.
RO Withdraws control rods in accordance with Ops Man B.05.05-05.E.1, Control Rod Movement.
Place ROD SELECT POWER switch, 3A-S1, to ON.
Press the appropriate ROD SELECT pushbutton (control rod 14-39, step 30).
NOTE: The control rod will move 1 notch in the indicated direction when the ROD MOVEMENT CONTROL switch is momentarily placed in ROD NOTCH OUT or ROD IN.
Momentarily place ROD MOVEMENT CONTROL switch, 3A-S2, to ROD OUT NOTCH or ROD IN to obtain desired rod movement.
BOP Monitor Plant Parameters Notes:
Op-Test No. Scenario No. 3 Event No. 3 Page 1 of 2 Event
Description:
When directed by the chief examiner, the No. 11 CRD pump will trip. The OATC should start the standby CRD pump. The in-plant operator should find the breaker in the trip free position. System engineering will need to investigate to determine the cause of the problems with the pump.
Time Position Actions or Behavior Simulator Operator TRG #1: When directed by the Chief Examiner, insert event trigger #1 to cause a trip of No. 11 CRD pump.
SRO Acknowledges report of trip of No. 11 CRD pump.
SRO Directs OATC to perform actions of C.4-B.01.03.A, LOSS OF CRD PUMP FLOW.
SRO Phone Talker Notify Shift Supervision and System Engineer.
If directed as system engineering to investigate the cause of the trip, acknowledge the request; no further communication is necessary.
SRO Acknowledge report of actions taken by RO.
RO Observes that No. 11 CRD pump tripped.
Red Lamp is OFF CRDH system flow and pump discharge pressure has decreased to 0 as indicated on :
o PI-3-302 Charging Water Header Pressure (C05) o FI-3-306 Cooling Water Header Flow (C05)
RO Acknowledge annunciators:
5-B CHARGING WATER LOW PRESSURE 5-B CRD PUMP 3-16A BREAKER TRIPPED 5-B CRD PUMP 3-16A OL RO Phone Talker Directs in-plant operator to investigate No. 11 CRD pump.
If dispatched as RBO to No.11 CRD pump, wait 2 minutes and report that The No. 11 CRD pump motor seems to be hot.
If dispatched as the TBO, wait 2 minutes and report that ACB-152-506 overcurrent flag is dropped.
Op-Test No. Scenario No. 3 Event No. 3 Page 2 of 2 Event
Description:
When directed by the chief examiner, the No. 11 CRD pump will trip. The OATC should start the standby CRD pump. The in-plant operator should find the breaker in the trip free position. System engineering will need to investigate to determine the cause of the problems with the pump.
Time Position Actions or Behavior RO Starts #12 CRD Pump. (HS-3B-S4B to START)
RO Phone Talker Verify #12 CRD Pump Starts
(#12 CRD Pump breaker indication - Green lamp OFF, Red lamp ON)
(PI-3-302 Charging Water Header Pressure - CO5)
(FI-3-306 Cooling Water Header Flow - CO5)
If dispatched as RBO to check the No. 12 CRD Pump for proper operation wait 2 minutes and report, The No. 12 CRD Pump is operating properly.
RO Verify required action per C.4-B.01.03.A, LOSS OF CRD PUMP FLOW, are complete.
RO Report actions taken for trip of CRD Pump to SRO.
BOP Monitoring plant parameters and may act as Peer Checker.
Notes:
Op-Test No. Scenario No. 3 Event No. 4 Page 1 of 1 Event
Description:
A high temperature will be experienced on Steam Packing Exhauster K-3A. This will require the operator to start Steam Packing Exhauster K-3B and establish vacuum and then shutdown Steam packing Exhauster K-3A.
Time Position Actions or Behavior Simulator Operator TRG #3: When actions for trip of No. 11 CRD pump are complete or when directed by the Chief Examiner, insert event trigger #3 to cause high motor temperatures on steam packing exhauster K-3A.
SRO Acknowledge report of 7-A-28, STM PKG EXH K3A & K3B BLWR MTR HI TEMP.
SRO Acknowledge report of action taken for Steam Packing Exhauster trouble.
RO Monitor plant parameters.
BOP Acknowledge annunciator 7-A-28 STM PKG EXH K3A & K3B BLWR MTR HI TEMP.
BOP Consult ARP 7-A-28 BOP Determine Steam Packing Exhauster K-3A is in service.
BOP START Steam Packing Exhauster K-3B. (HS 42-2122/CS to RUN CO7)
BOP ADJUST K-3B outlet valve MO-1049 to establish 10 H20 as indicated on PI-1220, STEAM PACKING EXH VAC. (HS-1049 CO7)
BOP STOP Steam Packing Exhauster K-3A. (HS 3122/CS to OFF CO7)
BOP CLOSE K-3A outlet valve MO-1048. (HS-1048 to CLOSE CO7)
BOP Phone Talker Notify Shift Supervision and Plant Electrician.
If called as Plant Electrician to look at Steam Packing Exhauster K-3A acknowledge report and state that you will have somebody look at it as soon as possible.
Notes:
Op-Test No. Scenario No. 3 Event No. 5 & 6 Page 1 of 6 Event
Description:
A Design Basis Earthquake will be felt which will cause a lockout of Bus 13. The Reactor will be manually scrammed and mitigative actions will be taken for the scram and the Bus 13 lockout.
Time Position Actions or Behavior Simulator Operator TRG #5: When actions for high temperature on the Steam Packing Exhauster are complete or when directed by the Chief Examiner, insert event trigger #5 to initiate the following:
- Operational Basis Earthquake
- Design Basis Earthquake after a 45 second time delay
- Lockout of 4160 VAC Bus 13 NOTE: When trigger #5 is inserted shake the procedure/form file cabinet for 5 seconds. When the Design Basis Earthquake alarms, 45 seconds after initiation of the event, shake the file cabinet again for 5 seconds.
SRO Acknowledge report of annunciators.
SRO Phone Talker Determine a Design Basis Earthquake has occurred. (Prairie Island could be called if further clarification is desired).
If called as Prairie Island to confirm the earthquake reply an earthquake has been confirmed.
Chief Examiner NOTE: C.4.K Immediate Reactor Shutdown may be entered but is not required.
SRO Direct the RO to manually scram the reactor.
RO Depress REACTOR SCRAM A and B pushbuttons. (5A-S3A and 5A-S3B)
Op-Test No. Scenario No. 3 Event No. 5 & 6 Page 2 of 6 Event
Description:
A Design Basis Earthquake will be felt which will cause a lockout of Bus 13. The Reactor will be manually scrammed and mitigative actions will be taken for the scram and the Bus 13 lockout.
Time Position Actions or Behavior RO Carry out actions of C.4.A REACTOR SCRAM RO Determine all control rods are inserted to or beyond position 04.
RO Place the reactor mode switch in SHUTDOWN.
RO Notify Shift Supervision.
RO Verify that the Recirc pumps are at minimum speed.
RO Control Reactor water level between +9 and +48 with Cond & Feed.
RO Place CV-6-13 (low flow valve) in AUTO.
Note: Operator may decide this shouldnt be done because of the reference line break.
RO Place CV-6-13 controller setpoint to 15 to 20 inches.
RO Verify CV-6-13 is closed when RPV level reaches 15 to 20 inches.
RO Insert SRM and IRM detectors.
RO Switch APRM/IRM recorders to IRM.
RO Monitor power by ranging down the IRMs to maintain indication on scale.
RO Verify the Scram Discharge Vent and Drain Valves close.
Op-Test No. Scenario No. 3 Event No. 5 & 6 Page 3 of 6 Event
Description:
A Design Basis Earthquake will be felt which will cause a lockout of Bus 13. The Reactor will be manually scrammed and mitigative actions will be taken for the scram and the Bus 13 lockout.
Time Position Actions or Behavior BOP Acknowledge annunciators:
6-C-8, EARTHQUAKE 6-C-13, OPERATIONAL BASIS EARTHQUAKE BOP Consult ARPs 6-C-8 & 6-C-13.
BOP Verify actuation of the Accelerograph Recording System. (Contacting system engineering is an option)
BOP Enter C.4-B.5.14A, EARTHQUAKE NOTE: Annunciator 6-C-18 will occur 45 seconds after initial earthquake annunciators (6-C-8 & 6-C-13).
BOP Acknowledge annunciator 6-C-18, DESIGN BASIS EARTHQUAKE.
BOP Announce over the paging system that a Reactor scram has occurred. (C.4.A)
BOP Carry out actions of C.4.A, REACTOR SCRAM BOP When Generator power is 0 Mwe OPEN 8N4 and 8N5. (CO8)
Op-Test No. Scenario No. 3 Event No. 5 & 6 Page 4 of 6 Event
Description:
A Design Basis Earthquake will be felt which will cause a lockout of Bus 13. The Reactor will be manually scrammed and mitigative actions will be taken for the scram and the Bus 13 lockout.
Time Position Actions or Behavior BOP TRIP the Turbine (Turbine emergency trip switch - CO7)
BOP Verify that Turbine-Generator field breaker is OPEN. (CO8)
BOP STOP the amplidyne. (Regulator Transfer Switch to OFF - CO8)
BOP START the Turbine Auxiliary Oil Pump. (CO7)
NOTE: Turbine Aux Oil Pump electrical reset is required for start. (C.4.H)
BOP Enter the following procedure:
C.4-B.09.06.B, LOSS OF BUS 13 OR BUS 14 C.4-B.01.03.A, LOSS OF CRD PUMP FLOW C.4-B.06.04.A, DECREASED CIRCULATING WATER FLOW C.4-B.06.03.A, DECREASING CONDENSER VACUUM C.4-B.09.06.C, LOSS OF BUS 15 OR BUS 16 C.4-B.09.07.A, LOSS OF POWER TO LC-101 OR ITS MCCS C.4-B.09.07.C, LOSS OF POWER TO LC-103 OR ITS MCCS C.4-B.09.07.E, LOSS OF POWER TO LC-107 OR MCC-114 C.4-B.09.07.G, LOSS OF POWER TO LC-109 OR ITS MCCS BOP Per ARP 8-B-11 NO 13 4160V BUS LOCKOUT BOP Verify #15 4160V bus has transferred to 1AR.
(152-511 breaker indication - Red OFF, Green ON - CO8)
(#15 bus voltage indication - CO8)
BOP Verify #11 & #12 Emergency Diesel Generators have started.
(#11 & #12 EDG voltage indication - CO8)
BOP Verify LC-107 transfer to LC-108.
Op-Test No. Scenario No. 3 Event No. 5 & 6 Page 5 of 6 Event
Description:
A Design Basis Earthquake will be felt which will cause a lockout of Bus 13. The Reactor will be manually scrammed and mitigative actions will be taken for the scram and the Bus 13 lockout.
Time Position Actions or Behavior BOP Per C.4-B.09.06.B, LOSS OF BUS 13 OR BUS 14:
BOP OPEN ACB 52-901 (52-901/CS - CO8)
BOP Place 52-908/SS SYNC 109 CTR SEC ACB to ON - CO8 BOP CLOSE ACB 52-908 109/102 LOAD CTR TIE ACB (52-908/CS - CO8)
BOP Verify MO-1850 11 Cir Wtr Pump P-100 Discharge Valve has closed. (Bkr indicating lamps - CO6)
NOTE: MO-1850 will begin to automatically close when power is restored to LC-109.
BOP C.4-B.06.04.A, DECREASED CIRCULATING WATER FLOW BOP Place #11 Circulating Water Pump control switch to SHUTDOWN.
(152-305/CS - CO6)
BOP C.4-B.06.03.A, DECREASING CONDENSER VACUUM BOP Monitor LP Turbine exhaust pressures per SPDS 656.
BOP C.4-B.09.06.C, LOSS OF BUS 15 OR BUS 16 BOP Determine that Bus 15 is being powered by 1AR.
(152-511 breaker indication - Red OFF, Green ON - CO8)
(#15 bus voltage indication - CO8)
Op-Test No. Scenario No. 3 Event No. 5 & 6 Page 6 of 6 Event
Description:
A Design Basis Earthquake will be felt which will cause a lockout of Bus 13. The Reactor will be manually scrammed and mitigative actions will be taken for the scram and the Bus 13 lockout.
Time Position Actions or Behavior BOP Consider shutdown of #11 & #12 Emergency Diesel Generators.
BOP C.4-B.09.07.A, LOSS OF POWER TO LC-101 OR ITS MCCS BOP No action required - LC-101 re-powered automatically.
BOP C.4-B.09.07.C, LOSS OF POWER TO LC-103 OR ITS MCCS BOP Monitor system operation for RBCCW, Stator Cooling, Drywell Ventilation, Service Water and Hydrogen Seal Oil.
BOP C.4-B.09.07.E, LOSS OF POWER TO LC-107 OR MCC-114 BOP Determine crosstie between LC-107 and LC-108 is closed.
(Indicated by control room lighting restored)
BOP C.4-B.09.07.G, LOSS OF POWER TO LC-109 OR ITS MCCS BOP No action required - LC-109 re-powered when breaker 52-908 was closed.
Notes:
Op-Test No. Scenario No. 3 Event No. 7 Page 1 of 6 Event
Description:
A reference line break will occur on the A side followed by a break in the B side after approximately 4 minutes. This will cause a loss of all level indication, which will drive the crew into C.5-2006, RPV FLOODING. Emergency Depressurization will be accomplished and then water injected to flood the vessel.
Time Position Actions or Behavior Simulator Operator TRG #6: When directed by the Chief Examiner, insert event trigger #6 to cause the following to occur:
Rupture of RPV Instrumentation Line A immediately.
Failure of the Wide Range Level Transmitter after 1 minute.
Rupture of RPV Instrumentation Line B after 5 minutes.
Chief Examiner NOTE: B side level instruments will fail 4 minutes after the A side. B side instruments will fail as drywell pressure approaches +2 psig requiring entry into C.5-1100.
SRO Acknowledge report of annunciators.
SRO Verify RPV water level is known per:
SPDS (Display 051)
LI-6-52B and LI-2-3-85A.
SRO Enter C.5-1100, RPV CONTROL (Entry condition +2 psig drywell pressure)
SRO Verify:
Reactor scram All rods in to at least 04 SRO Verify RPV water level instrument limits have not been exceeded.
SRO Critical Step Determine RPV water level is unknown SRO Leave C.5-1100 - RPV CONTROL SRO Enter C.5-2006 - RPV FLOODING at step 24 SRO Determine Torus level is above -5.9 ft.
Op-Test No. Scenario No. 3 Event No. 7 Page 2 of 6 Event
Description:
At the completion of Event No. 5&6 or at the direction of the Chief Examiner, A reference line break will occur on the A side followed by a break in the B side after approximately 4 minutes. This will cause a loss of all level indication which will drive the crew into C.5-2006, RPV FLOODING.
Time Position Actions or Behavior SRO Critical Step Direct BOP operator to open 3 ADS valves.
SRO Verify 3 ADS valves are open.
SRO Direct BOP operator to close the:
MSIVs Main Steam Line Drains RCIC steam isolation valves HPIC steam isolation valves SRO Critical Step Directs BOP and RO to inject to the RPV. May direct use of one or more of the following:
Condensate/Feedwater (O.K to defeat the high level trip.)
LPCI Core Spray CRD SRO Inject until 3 SRVs are verified OPEN and RPV pressure at least 50 psi above DW pressure, but low as possible.
SRO Confirm Drywell high pressure as indicated on PR-2994 (CO4) and SPDS SRO Enter C.5-1200 PRIMARY CONTAINMENT CONTROL (Entry Condition +2 psig Drywell pressure).
SRO Determine Drywell pressure >2 psig SRO Go to step 17 SRO Verify Torus level <14.1 ft and Torus pressure >2 psig.
Op-Test No. Scenario No. 3 Event No. 7 Page 3 of 6 Event
Description:
At the completion of Event No. 5&6 or at the direction of the Chief Examiner, A reference line break will occur on the A side followed by a break in the B side after approximately 4 minutes. This will cause a loss of all level indication which will drive the crew into C.5-2006, RPV FLOODING.
Time Position Actions or Behavior SRO Direct BOP operator to start Torus spray per C.5-3502.
NOTE: If it is determined that RHR pumps are needed for core cooling, Torus spray will not be initiated until RPV level is restored.
SRO Direct BOP operator to stop Torus spray if Torus pressure drops below 2 psig.
SRO Direct BOP operator to start all available DW cooling per C.5-3503 SRO Maintain Torus level -4.0 to +3.0 inches SRO Determine that Torus level can be maintained <+4.3 ft and >-3.3 ft.
(steps 15 & 19)
SRO Direct BOP operator to perform procedure C.5-3501 H2/02 ANALYZER OPERATION as time permits.
RO Acknowledge annunciator 5-B-24 REACTOR WATER LEVEL HI/LO.
RO Consult ARP 5-B-24 REACTOR WATER LEVEL HI/LO.
RO Report annunciator 5-B-24 to SRO RO Determine LI-6-52A and LI-2-3-85B have failed upscale. (CO5)
RO Verify LI-6-52B and LI-2-3-85A indicates correctly. (CO5)
RO Determine Reactor Feed Pump trip has occurred on high RPV level and cannot be re-started.
Op-Test No. Scenario No. 3 Event No. 7 Page 4 of 6 Event
Description:
At the completion of Event No. 5&6 or at the direction of the Chief Examiner, A reference line break will occur on the A side followed by a break in the B side after approximately 4 minutes. This will cause a loss of all level indication which will drive the crew into C.5-2006, RPV FLOODING.
Time Position Actions or Behavior BOP Critical Step Place hand switches for A, C & D SRVs to OPEN.
BOP Determine ADS valves opened. (amber lamps on CO3 for A, C & D SRVs illuminated)
BOP Place MSIV handswitches to CLOSE. (C-03)
(HS 16A-S1A - 16A-S1D) (HS 16A-S2A - 16A-S2D)
BOP CLOSE MO-2373. (C-03) (Main Steam Line Drain) (HS 16A-S5)
BOP CLOSE MO-2374. (C03) (Main Steam Line Drain) (HS 16A-S6)
BOP CLOSE MO-2075. (C-04) (RCIC Isolation) (HS 13A-S1)
BOP CLOSE MO-2076. (C-04) (RCIC Isolation) (HS 13A-S3)
BOP CLOSE MO-2034. (C-03) (HPCI Isolation) (HS 23A-S2)
BOP CLOSE MO-2035. (C-03) (HPCI Isolation) (HS 23A-S3)
BOP Critical Step Reports injection from Core Spray A & B and LPCI.
BOP Verify 3 SRVs are OPEN after floodup is complete by SRV open AMBER lamps ON and RPV pressure increasing as indicated by Recirculation Pump Seal pressure.
BOP Remove Core Spray & LPCI injection as directed.
Notes:
Op-Test No. Scenario No. 3 Event No. 7 Page 5 of 6 Event
Description:
At the completion of Event No. 5&6 or at the direction of the Chief Examiner, A reference line break will occur on the A side followed by a break in the B side after approximately 4 minutes. This will cause a loss of all level indication which will drive the crew into C.5-2006, RPV FLOODING.
Time Position Actions or Behavior BOP Perform C.5-3502 Part A (B) for placing Torus Spray in service.
BOP Place CONTAINMENT SPRAY 2/3 CORE HEIGHT BYPASS switch to MANAUL OVERRIDE.
BOP Place CONTAINMENT SPRAY/COOLING LPCI INITIATION BYPASS switch to BYPASS.
BOP Open MO-2006 (MO-2007).
BOP Open MO-2010 (MO-2011).
BOP Throttle open MO-2008 (MO-2009).
BOP Verify closed, if necessary:
MO-2012 MO-2013 BOP Verify CV-1728 controller set at 20%.
BOP Close MO-2002 (MO-2003).
BOP Place 11 and 13 RHRSW PUMPS LPCI AND ECCS LOAD SHED MANUAL OVERRIDE switch to MANUAL OVERRIDE.
BOP Start 11 and/or 13 RHRSW Pump.
BOP Adjust RHRSW flow using CV-1728.
BOP Verify MO-2002 (MO-2003) closed.
Op-Test No. Scenario No. 3 Event No. 7 Page 6 of 6 Event
Description:
At the completion of Event No. 5&6 or at the direction of the Chief Examiner, A reference line break will occur on the A side followed by a break in the B side after approximately 4 minutes. This will cause a loss of all level indication which will drive the crew into C.5-2006, RPV FLOODING.
Time Position Actions or Behavior BOP Locate procedure C.5-3503, Defeat Drywell Cooler Trips.
BOP Place all DW cooling switches to OFF (42-3312/CS, 42-4312/CS, 42-3313/CS, 42-4313/CS on C25 BOP OPEN knife switch KS3100 (behind panel C25)
BOP Verify FAN INLET DAMPER control switches in AUTO (C25)
BOP Place DW cooling fan control switch in ON. (42-3312/CS, 42-4312/CS, 42-3313/CS, 42-4313/CS on C25)
BOP OPEN associated discharge dampers for started fans.
BOP Locate C.5-3501 - H2/O2 ANALYZER OPERATION Perform as time allows.
Notes:
Termination Point:
3 SRVs open RPV flooded to the Main Steam Lines.
Upon approval of Chief Examiner Classification:
Site Area Emergency - Guideline 22 (Earthquake)
Appendix D Scenario Outline Form ES-D-1 Facility:
MNGP Scenario No. NRC 03-04 Op-Test No:
03-01 Examiners:
Operators:
Initial Conditions: The crew will take the duty with the plant at 100% reactor power. HPCI has been inoperable for the past 5 days for repairs. The off-going crew is in the progress of performing procedure 0255-06-IA-1 to complete the PMT requirements to restore HPCI to operable status. The next step in the procedure is to secure Torus cooling. The off-going crew has secured A RHR from Torus Cooling.
Turnover: Secure B RHR from the Torus Cooling Mode per step 81 of 0255-06-IA-1.
Event No.
Malf.
No.
Event Type*
Event Description 1
N/A BOP (N)
Secure B RHR from Torus Cooling 2
SW03A B22 BOP (C)
No. 11 Service Water Pump Trip 3
NI13D RO (I)
APRM Channel No. 4 Fails Upscale (Tech Spec call) 4 FW22 RO (C)
Hotwell Low Level 5
CW02B BOP(C)
Trip of No. 12 Circ Water Pump RO (R)
Rapid Power Reduction 6
TU05 BOP (C)
Loss of Turbine Bearing Oil Header Pressure 7
CH16 M
Failure to Scram CH19 Multiple Stuck Control Rods 8
SL01A (SL01B)
RO (C)
Failure of SBLC System 1(2) Note: The 1st train used (1) or (2) will fail, requiring the use of the other train.
Equipment Out of Service B RWCU Pump APRM Channel #5 HPCI is inop for performance of 0255-06-IA-1.
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Op-Test No. Scenario No. 4 Event No. 1 Page 1 of 2 Event
Description:
The crew will take the duty with the plant at 100% reactor power. HPCI has been inoperable for the past 5 days for repairs. The off-going crew is in the progress of performing procedure 0255-06-IA-1 to complete the PMT requirements to restore HPCI to operable status. The next step in the procedure is to secure Torus cooling. The off-going crew has secured A RHR from Torus Cooling. The crew should secure the B loop of Torus Cooling.
Time Position Actions or Behavior SRO Directs the BOP operator to secure B RHR from Torus Cooling per B.03.04-05.F.2, TORUS COOLING MODE-SHUTDOWN.
SRO Exits LCO 3.5.A and declares both LPCI injection paths operable.
SRO Directs BOP operator to complete procedure 0255-06-IA-1.
RO Monitors plant parameters.
BOP Secures Torus Cooling on B RHR per B.03.04-05.F.2.
BOP Slowly closes MO-2009 and holds control switch in close for 5 seconds after valve indicates closed.
BOP Closes MO-2007.
BOP Makes a plant announcement for securing 12 RHR Pump and to stand clear of the breaker in the upper 4kv room.
BOP Stops 12 RHR Pump and verifies min flow valves are closed.
BOP Verifies MO-2003 is open.
BOP Informs CRS that LCO 3.5.A can be exited.
BOP Makes a plant announcement for securing 12 RHRSW Pump and to stand clear of the breaker in the upper 4kv room.
Op-Test No. Scenario No. 4 Event No. 1 Page 2 of 2 Event
Description:
The crew will take the duty with the plant at 100% reactor power. HPCI has been inoperable for the past 5 days for repairs. The off-going crew is in the progress of performing procedure 0255-06-IA-1 to complete the PMT requirements to restore HPCI to operable status. The next step in the procedure is to secure Torus cooling. The off-going crew has secured A RHR from Torus Cooling. The crew should secure the B loop of Torus Cooling.
Time Position Actions or Behavior BOP Stops 12 RHRSW Pump per B.08.01.03-05.F.1 (SHUTDOWN OF RHRSW LOOP).
BOP Phone Talker Verifies closed RHRSW-32.
When directed as the TBO to verify RHRSW-32 is closed wait 2 minutes and reply, RHRSW-32 is closed.
BOP Phone Talker Contacts Chemistry to inject Biocide if required.
When contacted as Chemistry to determine if Biocide injection is required reply, Biocide injection is not required.
BOP Adjusts DPIC-10-130A to 0 to close CV-1728.
BOP Phone Talker Directs TBO to verify no motor cooling water flow into floor drain.
When directed as TBO to perform step 7 and verify no motor cooling water flow into floor drain wait 2 minutes and reply, B.08.01.03-05.F.1 Step 7 has been completed.
BOP Phone Talker Notifies Shift Chemist to valve out B RHR conductivity cell.
When directed as Shift Chemist to valve out B RHR conductivity cell, acknowledge the order, wait 3 minutes and then reply, The B RHR conductivity cell is valved-out.
BOP Vents high points and depressurizes per procedure 2145, RHR SYSTEM DISCHARGE VENTING.
Notes:
Op-Test No. Scenario No. 4 Event No. 2 Page 1 of 2 Event
Description:
No. 11 Service Water Pump will trip and No. 12 Service Water Pump will not automatically start.
Operators will need to manually start No. 12 Service Water Pump.
Time Position Actions or Behavior Simulator Operator TRG #1: When directed by the Chief Examiner insert event trigger #1 to cause the 11 Service Water Pump to trip.
SRO Acknowledge report of 6-B-22, SERVICE WATER HDR LOW PRESSURE.
SRO Acknowledge report of action taken for trip of No. 11 Service Water Pump.
RO Monitor plant parameters.
BOP Acknowledge annunciator 6-B-22, SERVICE WATER HDR LOW PRESSURE.
BOP Report 6-B-22 to SRO BOP Monitor Service Water System pressure. (PI-1535 CO6)
BOP Determine Service Water System pressure is low, #11 Service Water Pump has tripped and 12 Service Water Pump did not automatically start.
(Indicating lights above HS 52-305CS & HS 52-405CS)
BOP Start #12 Service Water Pump. (HS 52-405CS to START)
BOP Verify #12 Service Water Pump starts and system pressure is restored.
(Indicating lights above HS 52-405CS) (PI-1535 CO6)
BOP Verify actions per C.4-B.8.1.1.A, LOSS OF SERVICE WATER.
BOP Notify Shift Supervision.
Notes:
Op-Test No. Scenario No. 4 Event No. 2 Page 2 of 2 Event
Description:
No. 11 Service Water Pump will trip and No. 12 Service Water Pump will not automatically start.
Operators will need to manually start No. 12 Service Water Pump.
Time Position Actions or Behavior BOP Phone Talker Direct TBO to:
Verify proper operation and alignment of Service Water Pumps.
Verify integrity of the Service Water System.
Verify proper operation of the Service Water Auto Strainer.
When directed to:
verify proper operation and alignment of Service Water Pumps.
verify integrity of the Service Water System.
verify proper operation of the Service Water Auto Strainer.
Wait 2 minutes and then report that system integrity is intact and operation appears normal.
Op-Test No. Scenario No. 4 Event No. 3 Page 1 of 2 Event
Description:
After completion of the actions for a trip of No. 11 SW pump, channel 4 APRM will fail high causing a 1/2 trip of Channel B RPS scram logic. The OATC will need to insert a full B 1/2 scram. An evaluation will need to be done to ensure Tech Specs is being complied with.
Time Position Actions or Behavior Simulator Operator TRG #2: When actions for a trip of No.11 SW pump are complete or when directed by the Chief Examiner, insert event trigger #2 to cause APRM channel 4 to fail full scale.
SRO Acknowledge report of annunciators SRO Acknowledge failure of full RPS Bus B 1/2 scram to occur.
SRO Acknowledge action taken in response to APRM failure.
SRO Determine APRM has failed due to equipment failure.
SRO Determines minimum number of APRM channels is not satisfied per Technical Specification, Section 3.2 - Table 3.2.3.
SRO Direct RO to insert a full RPS B 1/2 scram.
SRO Phone Talker Notify System Engineer and I&C.
If called as System Engineer about APRM Channel 4 failing high acknowledge report and state that you will begin an investigation of the problem.
RO Acknowledge annunciators:
5-A-3, ROD WITHDRAW BLOCK 5-A-14, APRM HIGH 5-A-30, APRM HI HI INOP CH 4, 5, 6 5-B-3, REACTOR NEUTRON MONITOR SCRAM TRIP 5-B-5, REACTOR AUTO SCRAM CHANNEL B RO Report annunciators to SRO RO Determines that only RPS Bus B Scram Lights 1 & 4 have de-energized and that the full 1/2 scram has not occurred.
Op-Test No. Scenario No. 4 Event No. 3 Page 2 of 2 Event
Description:
After completion of the actions for trip of No. 11 SW pump, channel 4 APRM will fail high causing a 1/2 trip of Channel B RPS scram logic. The OATC will need to insert a full B 1/2 scram. An evaluation will need to be done to ensure Tech Specs is being complied with.
Time Position Actions or Behavior RO Consult ARPs RO Determine APRM #4 is indicating UPSCALE. (NR-7-46B CO5)
RO Determine Rod Block is actuated. (Annunciator 5-A-3 is in alarm)
RO Determine HI-HI indicating lamp for APRM 4 on panel C37 is ON.
RO Determine remaining APRM channels are within expected range. (NR-7-46A -D CO5)
RO Phone Talker Notify Shift Supervision and I&C.
If called as I&C about APRM Channel 4 failing high and failure of a complete RPS Bus B 1/2 scram, acknowledge report and state that somebody will begin to check it out as soon as possible.
RO Chief Examiner Inserts a full 1/2 scram on RPS Bus B by depressing the B Scram Pushbutton.
Note: Candidates may notice there was no noise for when the relays drop out as would be on a true scram signal. This can not be simulated. If this is a point of confusion, state that relays are deenergized.
BOP Monitors plant parameters and may act as a peer checker.
Notes:
Op-Test No. Scenario No. 4 Event No. 4 Page 1 of 2 Event
Description:
A Hotwell Low Level will be received due to the reject valve controller (CV-1093A & B) calling for 100% open. The controller will need to be placed in manual and the reject valve closed.
Time Position Actions or Behavior Simulator Operator TRG #8: When actions for APRM Channel 4 failing high are complete or when directed by the Chief Examiner, insert event trigger #8 to cause the hotwell reject level control valve to fail open.
SRO Acknowledge report of the following annunciator:
6-A-33, CONDENSATE PUMP LOW DISCH PRESS SRO Acknowledge report of action taken on Hotwell Low Level.
RO Acknowledge annunciator 6-A-33, CONDENSATE PUMP LOW DISCH PRESS.
RO Consult ARP 6-A-33 RO Verify adequate Hotwell level. (LR-1278 CO6)
Note: Level will be decreasing. The reject valve will be full open and the Makeup valve will be opening slowly.
RO Monitor Reactor Feed Pump suction pressure. (PI-1120 & PI-1121 CO6)
Note: RFT suction pressure will be lower than normal.
RO Phone Talker Contacts TBO to notify him of the problem and to investigate.
When contacted as TBO, acknowledge the order. Wait 2 minutes and if the candidate has not taken the controller for the Reject valve to manual yet state discharge pressure on the condensate pumps are low. If he has taken the controller to manual and the problem has corrected itself, state that you can not find anything wrong in the plant.
Op-Test No. Scenario No. 4 Event No. 4 Page 2 of 2 Event
Description:
A Hotwell Low Level will be received due to the reject valve controller (CV-1093A & B) calling for 100% open. The controller will need to be placed in manual and the reject valve closed.
Time Position Actions or Behavior RO Determines LC-1093, Hotwell Reject Level Controller, is calling for 100% open.
RO Places LC-1093 in MANUAL.
Note: When controller is placed in manual, the valve will close.
RO Verify LC-1093 is closed.
RO Monitor Reactor Feed Pump suction pressure. (PI-1120 & PI-1121 CO6)
RO Notify Shift Supervision.
RO Phone Talker Contact I&C to correct controller problem.
If contacted as I&C about controller CV-1093A & B failure acknowledge report, and state that it will be looked at very soon.
BOP Monitor plant parameters and assist in following up on annunciators.
Notes:
Op-Test No. Scenario No. 4 Event No. 5 Page 1 of 2 Event
Description:
At the completion of actions Hotwell level failure, a trip of the No. 12 Circ Water pump will occur.
This will cause condenser vacuum to start decreasing. The crew should enter the abnormal procedures for reduced circ water flow and lowering condenser vacuum. The CRS should direct the OATC to perform a rapid power reduction to aid in holding condenser vacuum. With Recirc reduced condenser vacuum will start to recover and power reduction can stop.
Time Position Actions or Behavior Simulator Operator TRG #3: When the actions for Hotwell level failure are complete or when directed by the Chief Examiner, insert event trigger #3 to cause a trip of the No. 12 Circ Water Pump.
SRO Acknowledges report of annunciators 6-C-10, CIRC WTR PP P-100B TRIP, 6-C-15, CIRC WTR PP P-100B OVERLOAD, and 5-B-46, CONDENSER LOW VACUUM.
SRO Directs BOP to perform C.4-B.06.04.A, DECREASED CIRCILATING WATER FLOW, and C.4-B.06.03.A, DECREASING CONDENSER VACUUM.
SRO Directs OATC to reduce Reactor Recirc flow per C.4-F, RAPID POWER REDUCTION.
SRO Notifies Shift Supervision.
SRO Phone Talker Notifies the System Engineer.
When contacted as the System Engineer to investigate the trip of the No. 12 Circ Water Pump acknowledge the order.
SRO Phone Talker Directs the TBO to investigate the cause of the pump trip.
If contacted as TBO to investigate the cause of No. 12 Circ Water Pump trip wait 5 minutes and report, I am unable to determine the cause of the No. 12 Circ Water Pump trip.
RO Acknowledges annunciator 5-B-46, CONDENSER LOW VACUUM.
RO Reduces Recirc flow per C.4-F, RAPID POWER REDUCTION, as necessary, to control condenser vacuum.
Op-Test No. Scenario No. 4 Event No. 5 Page 2 of 2 Event
Description:
At the completion of actions for Hotwell level failure, a trip of the No. 12 Circ Water pump will occur. This will cause condenser vacuum to start decreasing. The crew should enter the abnormal procedures for reduced circ water flow and lowering condenser vacuum. The CRS should direct the OATC to perform a rapid power reduction to aid in holding condenser vacuum. With Recirc reduced condenser vacuum will start to recover and power reduction can stop.
Time Position Actions or Behavior RO If core flow is < 32 Mlbm/hr then performs C.4-B.05.01.02.A, CONTROL OF NEUTRON FLUX OSCILLATIONS, concurrently.
Note: The candidate may drive flow < 32 Mlbm/hr. However, it is anticipated that he will not.
RO Determines core flow is > 32 Mlbm/hr.
RO Notifies CRS of actions taken.
BOP Acknowledges annunciators 6-C-10, CIRC WTR PP P-100B TRIP, and 6-C-15, CIRC WTR PP P-100B OVERLOAD.
BOP Enters C.4-B.06.04.A, DECREASED CIRCILATING WATER FLOW.
BOP Places the control switch for the No. 12 Circ Water Pump in SHUTDOWN and verifies system valves automatically reposition.
BOP Monitors condenser d/p and circulating water condenser outlet temperature for air binding.
BOP Verifies that one cooling tower pump is shutdown and that cooling towers are aligned for one pump operation.
BOP Enters C.4-B.06.03.A, DECREASING CONDENSER VACUUM.
BOP Monitors LP turbine exhaust pressure on SPDS screen 656.
BOP Determines that neither LP turbine is in the ALERT region of Figure 1, TURBINE EXHAUST PRESSURE LIMITS. (after Recirc flow is reduced)
Notes:
Op-Test No. Scenario No. 4 Event No. 6 Page 1 of 2 Event
Description:
After the crew has performed the rapid power reduction and addressed the loss of the circ water pump, then a loss of turbine bearing oil header pressure will occur. Header pressure will slowly begin to lower and eventually cause a low pressure alarm. The BOP operator will respond to the annunciator procedure and start the AOP and TGOP. This will cause header pressure to begin to rise and reach approximately 35 psig. In-plant operators will report that there is a large lube oil rupture in the turbine building. The crew will decide that they will eventually loose oil pressure and should scram the reactor.
Time Position Actions or Behavior Simulator Operator Phone Talker TRG #4: When the actions for trip of 12 Circ water pump are completed or when directed by the Chief Examiner, insert event trigger #4 to cause a rupture of the turbine bearing oil header.
Two minutes after inserting event trigger #4, call the Control Room as the TBO and report that there is a large oil rupture near the Main Turbine.
SRO Acknowledges report of annunciator 7-A-33, TURB BRG OIL LOW PRESSURE.
SRO Acknowledges report from BOP operator that turbine header pressure has been restored above 30 psig.
SRO Acknowledges report of annunciator 7-A-31, TURB LO TK T-40 LOW LEVEL SRO Directs the OATC to scram the reactor per C.4-K, IMMEDIATE REACTOR SHUTDOWN.
Chief Examiner The plant will scram when the Turbine Stop valves lose enough oil pressure. The plant may scram prior to the manual scram being inserted.
SRO Phone Talker Notifies Shift Supervision and System Engineer.
When contacted as System Engineer about turbine bearing oil header rupture, acknowledge the report. No further action is necessary.
RO Monitors plant parameters.
RO May manually scram the reactor based on plant conditions or as directed by CRS.
NOTE: If the crew does not manually scram the reactor and decides to shutdown the Turbine Generator per C.3, SHUTDOWN PROCEDURE, then the reactor will automatically scram due a loss of oil pressure to the TCVs and TSVs.
Op-Test No. Scenario No. 4 Event No. 6 Page 2 of 2 Event
Description:
After the crew has performed the rapid power reduction and addressed the loss of the circ water pump, then a loss of turbine bearing oil header pressure will occur. Header pressure will slowly begin to lower and eventually cause a low pressure alarm. The BOP operator will respond to the annunciator procedure and start the AOP and TGOP. This will cause header pressure to begin to rise and reach approximately 35 psig. In-plant operators will report that there is a large lube oil rupture in the turbine building. The crew will decide that they will eventually loose oil pressure and should scram the reactor.
Time Position Actions or Behavior RO Reports reactor scram and all control rods not inserted to the CRS.
BOP Acknowledges annunciator 7-A-33, TURB BRG OIL LOW PRESSURE.
BOP Monitors turbine bearing oil header pressure on C-07 Panel.
BOP Determines that header pressure continues to lower and starts the following pumps:
Auxiliary Oil Pump Turning Gear Oil Pump BOP Determines that turbine bearing oil header pressure is restored above 30 psig.
BOP Acknowledges annunciator 7-A-31, TURB LO TK T-40 LOW LEVEL BOP Monitors Turbine Generator bearing temperatures as indicated on TR-1730 (C20)
BOP Dispatches an operator to the turbine building to verify not leaks and proper system lineup.
Notes:
Op-Test No. Scenario No. 4 Event No. 7 Page 1 of 11 Event
Description:
Because of the loss of turbine bearing oil header pressure a scram will occur. The crew will identify that all control rods have not inserted and will enter failure to scram procedure. Without any oil pressure the bypass valves will not open to relieve reactor pressure and with the turbine tripped all of the steam will dump into the Torus.
Torus temperature will eventually rise above 110°F forcing the crew to terminate and prevent to control reactor power.
Time Position Actions or Behavior SRO Acknowledges report of Reactor Scram and ATWS.
SRO Enter C.5-1100 RPV CONTROL (Entry Condition - Reactor power above 3% when scram required.
SRO Verify Reactor Scram has been initiated.
SRO Determine all rods ARE NOT in to at least 04.
SRO Determine the reactor WILL NOT stay shutdown under all conditions without boron.
SRO Leave C.5-1100 and Enter C.5-2007 SRO Enter C.5-2007 FAILURE TO SCRAM SRO Critical Step Direct the BOP operator to inhibit ADS SRO Critical Step Direct the BOP operator to prevent Core Spray injection per C.5-3205, TERMINATE AND PREVENT.
SRO Directs BOP operator to defeat RPV low water level MSIV isolation per C.5-3301.
Op-Test No. Scenario No. 4 Event No. 7 Page 2 of 11 Event
Description:
Because of the loss of turbine bearing oil header pressure a scram will occur. The crew will identify that all control rods have not inserted and will enter failure to scram procedure. Without any oil pressure the bypass valves will not open to relieve reactor pressure and with the turbine tripped all of the steam will dump into the Torus.
Torus temperature will eventually rise above 110°F forcing the crew to terminate and prevent to control reactor power.
Time Position Actions or Behavior POWER LEG SRO Verify Mode switch in SHUTDOWN.
SRO Directs RO to run back Recirc to minimum.
SRO Directs RO to trip Recirc Pumps.
SRO Direct RO to actuate ATWS.
SRO Directs RO to insert control rods per C.5-3101.
PRESSURE LEG SRO Determine Drywell pressure is < 2 psig.
SRO Determine SRVs are not rapidly cycling.
SRO Consider LO-LO SET can stabilize RPV pressure.
Op-Test No. Scenario No. 4 Event No. 7 Page 3 of 11 Event
Description:
Because of the loss of turbine bearing oil header pressure a scram will occur. The crew will identify that all control rods have not inserted and will enter failure to scram procedure. Without any oil pressure the bypass valves will not open to relieve reactor pressure and with the turbine tripped all of the steam will dump into the Torus.
Torus temperature will eventually rise above 110°F forcing the crew to terminate and prevent to control reactor power.
Time Position Actions or Behavior LEVEL LEG SRO Check Detail A for instrument limits.
SRO Determine no instrument limits have been exceeded.
SRO Determine:
Reactor power above 3%
RPV water level >-33 inches SRO Direct BOP operator to Terminate and Prevent HPCI, LPCI and Condensate and Feed per C.5-3205.
SRO Determine Reactor power is < 3%.
SRO Record final RPV level on line 3.
SRO Direct that RPV level be maintained between -149 inches and value recorded on line 3 with Condensate and Feedwater and RCIC.
SRO Enter C.5-1200 PRIMARY CONTAINMENT CONROL TORUS TEMPERATURE STEP SRO Determine Torus temperature cannot be maintained < 90 deg f.
SRO Direct BOP operator to start all available torus cooling.
Op-Test No. Scenario No. 4 Event No. 7 Page 4 of 11 Event
Description:
Because of the loss of turbine bearing oil header pressure a scram will occur. The crew will identify that all control rods have not inserted and will enter failure to scram procedure. Without any oil pressure the bypass valves will not open to relieve reactor pressure and with the turbine tripped all of the steam will dump into the Torus.
Torus temperature will eventually rise above 110°F forcing the crew to terminate and prevent to control reactor power.
Time Position Actions or Behavior SRO Verify Reactor scram has occurred.
SRO Determine Torus temperature can be maintained below fig M, HEAT CAPACITY LIMIT. (SPDS 78)
SRO Direct BOP operator to perform procedure C.5-3501H2/O2 ANALYZER OPERATION as time permits.
SRO Acknowledges report from OATC that all rods are in.
RO Carry out actions of C.4.A REACTOR SCRAM.
RO Determine if all control rods are inserted to or beyond position 04.
RO Place the reactor mode switch in SHUTDOWN.
RO Notify Shift Supervision.
RO Verify that the Recirc pumps have tripped.
RO Control Reactor water level between +9 and +48.
RO Verify Condensate and Feedwater and RCIC are used to restore and control Reactor water level.
RO Insert SRM and IRM detectors.
Op-Test No. Scenario No. 4 Event No. 7 Page 5 of 11 Event
Description:
Because of the loss of turbine bearing oil header pressure a scram will occur. The crew will identify that all control rods have not inserted and will enter failure to scram procedure. Without any oil pressure the bypass valves will not open to relieve reactor pressure and with the turbine tripped all of the steam will dump into the Torus.
Torus temperature will eventually rise above 110°F forcing the crew to terminate and prevent to control reactor power.
Time Position Actions or Behavior RO Verify the Scram Discharge Vent and Drain Valves close.
RO Phone Talker Direct the TBO to verify proper operation of the EDG SW pumps and verify EDG room ventilation is operating properly.
When directed as TBO to verify proper operation of the EDG SW pumps and verify EDG room ventilation is operating properly wait 4 minutes and reply EDG SW Pumps and EDG Room Ventilation is operating properly.
RO Refer to procedure B.05.06-05 ATWS SYSTEM MANUAL INITIATION (hard card)
B MAN and ATWS D MAN (PB S-5B & S-5D) (CO5)
RO SET the arming collars of one pair of the following switches to the armed position and depress the pushbuttons:
ATWS A MAN and ATWS C MAN (PB S-5A & S-5C) (CO5)
OR ATWS B MAN and ATWS D MAN (PB S-5B & S-5D) (CO5)
RO Verify Recirc Pump MG Set generator field breakers have tripped.
(Field breaker indicating lights - CO4)
RO Trip the MG set drive motors.
RO Place HS 2A-S1A to STOP (#11 MG set drive motor breaker)
RO Place HS 2A-S1B to STOP (#12 MG set drive motor breaker)
RO Determine Control Rods DO NOT insert.
Op-Test No. Scenario No. 4 Event No. 7 Page 6 of 11 Event
Description:
Because of the loss of turbine bearing oil header pressure a scram will occur. The crew will identify that all control rods have not inserted and will enter failure to scram procedure. Without any oil pressure the bypass valves will not open to relieve reactor pressure and with the turbine tripped all of the steam will dump into the Torus.
Torus temperature will eventually rise above 110°F forcing the crew to terminate and prevent to control reactor power.
Time Position Actions or Behavior RO Inserts control rods per C.5-3101, ALTERNATE ROD INSERTION, Part C.
RO Determine Part C is appropriate.
RO Determine prerequisites are met:
CRD pump available (Breaker indication CO5)
Instrument air available (PI-1476 - CO6 or PR-1176 - CO7)
Reactor Building accessible.
RO Places RWM Owner Display Keylock Switch is in BYPASS.
RO Place FC-301 - CRD FLOW CONTROL STATION in MANUAL.
RO OPEN MO-3-20, DRIVE PRESSURE TO CRD.
RO Phone Talker CLOSE the following valves:
CRD-79-1, RV-7364A INLET (behind CRDH instrument rack)
CRD-79-2, RV-7364B INLET (behind CRDH instrument rack)
CRD-168, CRD PUMP BYPASS ISOL When directed as RBO to close CRD-79-1, CRD-79-2, and CRD-168, then wait 3 minutes and reply, CRD 79-1, CRD 79-2, and CRD-168 are closed or Step 5 of part C of C.5-3101 is complete.
Op-Test No. Scenario No. 4 Event No. 7 Page 7 of 11 Event
Description:
Because of the loss of turbine bearing oil header pressure a scram will occur. The crew will identify that all control rods have not inserted and will enter failure to scram procedure. Without any oil pressure the bypass valves will not open to relieve reactor pressure and with the turbine tripped all of the steam will dump into the Torus.
Torus temperature will eventually rise above 110°F forcing the crew to terminate and prevent to control reactor power.
Time Position Actions or Behavior RO Establishes 400 psid drive pressure by throttling closed on MO-3-20.
RO Inserts control rods using RMCS.
RO Reports to the CRS of all rods in.
BOP Critical Step Places ADS INHIBIT switches 2E-S7A & 2E-S7B on CO3 to INHIBIT.
BOP Critical Step Prevents Core Spray per C.5-3205, TERMINATE AND PREVENT, Part A.
BOP Places MO-1751 CS INJECTION BYPASS handswitch in BYPASS (14A-S16A).
BOP Closes MO-1751.
BOP Places No. 11 Core Spray Pump in PTL.
BOP Places MO-1752 CS INJECTION BYPASS handswitch in BYPASS (14A-S16B).
BOP Closes MO-1752.
BOP Places No. 12 Core Spray Pump in PTL.
Op-Test No. Scenario No. 4 Event No. 7 Page 8 of 11 Event
Description:
Because of the loss of turbine bearing oil header pressure a scram will occur. The crew will identify that all control rods have not inserted and will enter failure to scram procedure. Without any oil pressure the bypass valves will not open to relieve reactor pressure and with the turbine tripped all of the steam will dump into the Torus.
Torus temperature will eventually rise above 110°F forcing the crew to terminate and prevent to control reactor power.
Time Position Actions or Behavior BOP Defeat RPV low-low level isolation for MSIV closure per C.5-3301.
BOP Determines prerequisites are met.
Main condenser available No fuel element failure No steam line break BOP Places the following switches in BYPASS (Panels C-15 and C-17):
16A-S62A 16A-S62C 16A-S62B 16A-S62D BOP Maintain Reactor water level within band given by CRS using Condensate and Feed or RCIC.
BOP Terminate and Prevent Condensate and Feed, HPCI & LPCI per C.5-3205 TERMINATE AND PREVENT parts E, B & C.
Part E BOP Verify CLOSED CV-6-12A, A MAIN FW REG VALVE.
BOP Verify CLOSED CV-6-12B, B MAIN FW REG VALVE.
BOP Verify CLOSED CV-6-13, FW LOW FLOW REG VALVE.
Op-Test No. Scenario No. 4 Event No. 7 Page 9 of 11 Event
Description:
Because of the loss of turbine bearing oil header pressure a scram will occur. The crew will identify that all control rods have not inserted and will enter failure to scram procedure. Without any oil pressure the bypass valves will not open to relieve reactor pressure and with the turbine tripped all of the steam will dump into the Torus.
Torus temperature will eventually rise above 110°F forcing the crew to terminate and prevent to control reactor power.
Time Position Actions or Behavior Part C BOP Determine HPCI is operating.
BOP Depress and hold the TURBINE TRIP pushbutton.
BOP Place AUX OIL PUMP in PULL-TO-LOCK.
BOP Wait 5 seconds after AUX OIL PUMP in placed PULL-TO-LOCK then release the HPCI TURBINE TRIP pushbutton.
BOP Verify HO-7 CLOSED.
Part B BOP OPEN knife switch 10A-S31A.
BOP OPEN knife switch 10A-S31B.
BOP CLOSE MO-2012.
BOP CLOSE MO-2013.
Op-Test No. Scenario No. 4 Event No. 7 Page 10 of 11 Event
Description:
Because of the loss of turbine bearing oil header pressure a scram will occur. The crew will identify that all control rods have not inserted and will enter failure to scram procedure. Without any oil pressure the bypass valves will not open to relieve reactor pressure and with the turbine tripped all of the steam will dump into the Torus. Torus temperature will eventually rise above 110°F forcing the crew to terminate and prevent to control reactor power.
Time Position Actions or Behavior BOP Perform procedure B.03.04-05.H.1(2) - TRANSFERRING A (B) RHR FROM LPCI TO TORUS COOLING WITH NORMAL OFF-SITE POWER AVAILABLE DURING ABNORMAL AND EMERGENCY CONDITIONS.
BOP Verify CV-1728 (CV-1729) controller is set at 20%.
BOP Place MO-2002 (MO-2003) bypass keylock switch in CLOSE.
BOP Place 11 and 13 (12 and 14) RHRSW PUMPS LPCI AND ECCS LOAD SHED MANUAL OVERRIDE switch in MANUAL OVERRIDE.
BOP Start No. 11 and/or No. 13 (No. 12 and/or No. 14) RHRSW Pump.
BOP Adjust RHRSW flow to approximately 3500 gpm using CV-1728 (CV-1729).
BOP Place CONTAINMENT SPRAY 2/3 CORE HEIGHT BYPASS switch to MANAUL OVERRIDE.
BOP Place CONTAINMENT SPRAY/COOLING LPCI INITIATION BYPASS switch to BYPASS.
BOP Partially open MO-2008 (MO-2009) by holding handswitch to OPEN for 8 seconds.
BOP Open MO-2006 (MO-2007).
Op-Test No. Scenario No. 4 Event No. 7 Page 11 of 11 Event
Description:
Because of the loss of turbine bearing oil header pressure a scram will occur. The crew will identify that all control rods have not inserted and will enter failure to scram procedure. Without any oil pressure the bypass valves will not open to relieve reactor pressure and with the turbine tripped all of the steam will dump into the Torus. Torus temperature will eventually rise above 110°F forcing the crew to terminate and prevent to control reactor power.
Time Position Actions or Behavior BOP Close MO-2012 or MO-2013 while throttling open MO-2008 (MO-2009) to maintain approximately 4000 gpm total flow per pump.
BOP Verify MO-2002 (MO-2003) closed.
BOP Verify V-AC-5 (V-AC-4) in operation.
BOP Perform C.5-3501 - H2/O2 ANALYZER OPERATION, as time permits.
Notes:
Op-Test No. Scenario No. 4 Event No. 8 Page 1 of 1 Event
Description:
Torus temperature will eventually rise above 110°F forcing the crew to terminate and prevent to control reactor power. When directed to inject SBLC the first system selected by the OATC will not work (the pump will trip) however, the second SBLC system will work.
Time Position Actions or Behavior SRO Critical Step Direct RO to inject SBLC.
SRO Acknowledge report that SBLC System No. 1 failed and that SBLC System No. 2 is injecting.
RO Injects SBLC per the hard card.
RO Place SLC system selector switch to SYS 1.
RO Determines SBLC SYS 1 did not actuate (green OFF pump light lit).
NOTE: The simulator is setup such that the first SBLC Pump started will fail requiring the standby SBLC pump to start.
RO Critical Step Places SLC system selector switch to SYS 2.
RO Determines that SBLC SYS 2 did actuate.
RO System 2 SBLC Pump breaker indication - (Green-OFF, Red-ON CO5).
RO SBLC DISCHARGE PRESSURE reads slightly higher than reactor vessel pressure. (PI-11-65 CO5)
RO SBLC tank level decreasing. (LI-11-66)
RO Review procedure B.03.05-05 MANUAL INITIATION as time permits.
Termination Point:
All control rods have been inserted.
RPV level has been restored to the normal band.
Primary containment parameters are being addressed.
At the discretion of the Chief Examiner.
Classification:
Guideline 12 (Alert) RPS Failure