ML13073A472
| ML13073A472 | |
| Person / Time | |
|---|---|
| Site: | Arkansas Nuclear  |
| Issue date: | 03/01/2013 |
| From: | Clyde Osterholtz Operations Branch IV |
| To: | Entergy Operations |
| laura hurley | |
| References | |
| 50-313/13-002 05-313/13-02 | |
| Download: ML13073A472 (364) | |
Text
A1-JPM-RO-TTB PAGE 2 OF 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS:
Plant shutdown for refueling.
RCS level is being drained to 376 in preparation for Reactor head removal.
Time after shutdown = 40 hours4.62963e-4 days <br />0.0111 hours <br />6.613757e-5 weeks <br />1.522e-5 months <br />.
Both OTSG primary manways are removed.
Nozzle dams are NOT installed.
RCS Temperature is 160°F.
Plant computer is inoperable due to power supply maintenance.
TASK STANDARD:
Calculated the following:
- 1) In step 3.0, used Figure 2B and determined time to boil should be 13.6 to 15.6 minutes (14.6 plus or minus one minute).
- 2) In step 4.0, used Figure 4B and determined time to core uncovery should be 224 to 236 minutes (230 plus or minus six minutes).
- 3) In step 5.0, determined heatup rate to be 3 to 4 °F/minute.
- 4) In step 6.0, determined makeup rate to be 75 to 85 gpm.
TASK PERFORMANCE AIDS:
1015.002 and 1015.002B.
SIMULATOR SETUP:
NA EXAMINER'S NOTES:
Page 1 of 5 JOB PERFORMANCE MEASURE Unit: 1 Rev # 1 Date:
JPM ID: A1JPM-RO-EOP26 System/Duty Area: ABNORMAL AND EMERGENCY OPERATIONS Task: PERFORM REACTOR TRIP IMMEDIATE ACTIONS JTA# ANO1-RO-EOP-EMERG-4 & ANO1-SRO-EOP-EMERG-2 KA Value RO 4.1 SRO 4.4 KA Reference 024 AK3.01 Approved For Administration To: RO X SRO X Task Location: Inside CR: X Outside CR: Both:
Suggested Testing Environment And Method (Perform or Simulate):
Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Simulator: X Plant Site: Lab:
Testing Method: Simulate: Perform: X Approximate Completion Time In Minutes: 15 Minutes Reference(s): 1202.001 Reactor Trip steps 1-3 Examinee's Name: Logon:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Date:
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 5 JPM ID: A1JPM-RO-EOP26 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
Prior to administration, ensure the Examinee has been briefed using Appendix E of NUREG-1021.
JPM INITIAL TASK CONDITIONS:
A H1 bus lockout has occurred. Reactor power is >60%. The CBOT is NOT in the control room.
TASK STANDARD:
Immediate actions of the Reactor Trip EOP are completed. This is an immediate action JPM. Actions for failure of reactor to trip using normal trip PB have been completed.
This is an Alternate Success Path JPM.
TASK PERFORMANCE AIDS: NONE Suggested Simulator setup:
Reactor power is 60%
RPS will not trip the reactor (Malfunctions RP246, RP247, RP248, RP249) 3 control rods fail to fall into core P36 A HPI pump in service H1 Lockout (Malfunction ED184)
Stuck Control Rods (Malfunction RD 363, RD 370, RD 380)
Page 3 of 5 JPM ID: A1JPM-RO-EOP26 INITIATING CUE: The SM/CRS directs you to manually trip the reactor and perform the immediate actions of the Reactor Trip EOP.
UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT EVALUATOR NOTE: The Examinee is not required to identify the failure of RPS to trip. The trip is directed.
- 1. Depress Reactor Trip pushbutton.
On C03, depressed the reactor C ____ ____ ____
POSITIVE CUE: trip pushbutton.
Reactor Trip PB depressed.
- 2. Identify that 3 rods have failed to insert On C13, identified 3 rods have C failed to trip. Verifies Rx power is ____ ____ ____
FAULTED CUE:
dropping 3 rods failed to insert. Rx power is dropping
- 3. Perform Emergency Boration (RT 12).
C Candidate obtains RT-12. ____ ____ ____
POSITIVE CUE:
Candidate obtains RT-12.
- 4. Set Batch Controller for maximum batch size by depressing the keys on the batch controller in the following order:
- Lower DISPLAY
- TOTAL Using the keys on the Batch
- TOTAL RESET Controller, the Batch Controller is C ____ ____ ____
- BATCH SET set to inject a total of 999999
- 9 (six times) gallons.
- ENTER
- Lower DISPLAY POSITIVE CUE:
The Batch Controller is set to 999999 gallons.
- 5. Verify Condensate to the Batch Controller (CV-1251) closed. Condensate to the Batch Controller (CV0-1251) is closed ____ ____ ____
POSITIVE CUE: as indicated on CO4.
CV-1251 is closed (green light on, red light off).
- 6. Open Batch Controller Outlet (CV-1250)
Candidate recognizes that the NEGATIVE CUE: Batch Controller is NOT available ____ ____ ____
CV-1250 will not open (green light on, red light off) and proceeds to step 2 of RT-12.
EXAMINER NOTE: candidate should transition to Step 2 of RT-12.
POSITIVE CUE:
Candidate obtains RT-2.
Page 4 of 5 UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT EXAMINER NOTE: candidate should transition to Step 2 of RT-2.
- 8. Open BWST Outlet to OP HPI pump CV-1407.
On C16, Open BWST Outlet to C OP HPI pump CV-1407. ____ ____ ____
POSITIVE CUE:
Red open light on for CV-1407.
- 9. Place RCP Seal INJ Block (CV-1206) in OVRD.
On panel C04 Place RCP Seal INJ Block (CV-1206) in OVRD. ____ ____ ____
POSITIVE CUE:
RCP Seal INJ Block (CV-1206) OVRD light on.
associated with OP HPI Pump C ____ ____ ____
CV-1220.
POSITIVE CUE:
Red open light on for CV-1220.
EXAMINER NOTE: candidate should transition to Step 2.B of RT-12.
- 11. Place 3-way valve to BLEED On C04 places 3-way valve to POSITIVE CUE: BLEED Blue light on for 3-way valve
- 12. When PZR level >100 maximize letdown flow On C04 PZR level >100 raise C POSITIVE CUE: ____ ____ ____
letdown flow to >80gpm PZR level >100 Letdown flow adjusted to equal to or >80gpm EXAMINER NOTE: When a 10 rise in PZR level has occurred and HPI is being injected from the BWST, the JPM may be ended if the following two steps have already been performed.
- 13. Manually trip Turbine Manually trip Turbine. Verifies Turbine throttle and governor C POSITIVE CUE: ____ ____ ____
valves closed Depresses Turbine trip button Verifies Turbine throttle and governor valves closed
- 14. Check adequate SCM Verifies adequate SCM from C POSITIVE CUE: ____ ____ ____
ICCMDS or ATOG on SPDS Adequate SCM is >30F SCM 60F END
Page 5 of 5 JPM ID: A1JPM-RO-EOP26 INITIAL CONDITIONS:
A H1 bus lockout has occurred. Reactor power is >60%. The CBOT is NOT in the control room.
INITIATING CUE:
The SM/CRS directs you to manually trip the reactor and perform the immediate actions of the Reactor Trip EOP.
CHANGE 1202.001 REACTOR TRIP 034 PAGE 1 of 26 ENTRY CONDITIONS An automatic reactor trip or DSS trip.
Failure of RPS to trip the reactor upon reaching a limit listed below:
- High power 104.9%
- High power/pumps one pump per loop 55%
OR 0 pumps in one loop 0%
- High power/imbalance/flow COLR Figure
- High RCS temp 618°F (T-hot)
- High RCS press 2355 psig
- Low RCS press 1800 psig
- Variable low RCS press COLR Figure
- High RB press 18.7 psia
- Turbine trip reactor power 43% AND Turbine is tripped
- Both MFW pumps trip reactor power 9% AND both MFW pumps tripped Manual trip of the reactor is required due to reaching a limit listed below:
- PZR level dropping 100",
AND no indication of recovery
- PZR level 290"
- Any MSIV closure at power
- Either SG level 15" or 95%,
AND no indication of recovery
- A system degradation that requires manual reactor trip based on operator judgment
- Abnormal Operating Procedure requirement IF a system degradation occurs while shutdown, above DHR operation, THEN perform applicable steps
CHANGE 1202.001 REACTOR TRIP 034 PAGE 2 of 26 INSTRUCTIONS CONTINGENCY ACTIONS
- 1. Depress Reactor Trip PB.
A. Verify all rods inserted A. Perform the following:
AND 1) IF reactor fails to trip, THEN depress CRD Power Supply reactor power dropping. Breaker Trip PBs on C03:
A-501 B-631 a) IF either A-501 or B-631 fails to trip, THEN manually insert rods at C03.
b) Dispatch an operator to open both CRD AC Power Supply breakers.
- 2) IF more than one rod fails to fully insert OR reactor power is not dropping, THEN perform Emergency Boration (RT-12).
- 3) Do not continue until the reactor is shutdown.
CHANGE 1202.001 REACTOR TRIP 034 PAGE 3 of 26 INSTRUCTIONS CONTINGENCY ACTIONS
- 2. Depress Turbine trip PB.
A. Check Turbine throttle and governor valves A. Perform the following:
closed.
- 1) IF 125V DC Panel D11 is de-energized as indicated by both of the following:
Turbine Trip Solenoid Power Available light off Breaker position indications on left side of C10 off THEN at C10, transfer D11 to EMERG SUPPLY D02.
a) Perform Loss of 125V DC (1203.036), "Loss of D01" section in conjunction with this procedure.
- 2) IF either SG press is 900 psig, THEN perform the following:
a) Actuate MSLI for affected SG(s).
b) Actuate EFW.
c) Check adequate SCM.
d) Verify proper MSLI and EFW actuation and control (RT-6).
e) Advise Shift Manager to implement Emergency Action Level Classification (1903.010).
f) Perform one of the following:
IF SCM is adequate, THEN GO TO 1202.003, "OVERCOOLING" procedure.
IF SCM is less than adequate, THEN GO TO 1202.002, "LOSS OF SUBCOOLING MARGIN" procedure.
CHANGE 1202.001 REACTOR TRIP 034 PAGE 4 of 26 INSTRUCTIONS CONTINGENCY ACTIONS
- 3. Check adequate SCM. 3. Check elapsed time since loss of adequate SCM AND perform the following:
A. IF 2 minutes have elapsed, THEN trip all RCPs:
P32A P32C P32B P32D B. IF > 2 minutes have elapsed, THEN leave currently running RCPs on.
C. Advise Shift Manager to implement Emergency Action Level Classification (1903.010).
D. GO TO 1202.002, "LOSS OF SUBCOOLING MARGIN" procedure.
- 4. Advise Shift Manager to implement Emergency Action Level Classification (1903.010).
- 5. Verify Orifice Bypass (CV-1223) demand adjusted to zero.
- 6. Open BWST T3 Outlet (CV-1407 or CV-1408) to operating HPI pump.
- 7. IF Emergency Boration is not in progress, THEN adjust Pressurizer Level Control setpoint to 100".
CHANGE 1202.012 REPETITIVE TASKS 011 PAGE 42 of 93 Page 1 of 5 EMERGENCY BORATION NOTE If an unexpected delay occurs in implementation of Step 1, then promptly initiate Emergency Boration using HPI per step 2.
- 1. IF Boric Acid pump (P39A or P39B) and Batch Controller are available, THEN perform the following:
A. IF both OP and STBY HPI Pumps are off OR Letdown is isolated, THEN GO TO step 2.
B. Set Batch Controller for maximum batch size as follows:
- 1) Depress lower DISPLAY.
- 2) Depress TOTAL.
- 3) Depress TOTAL RESET.
- 4) Depress BATCH SET.
- 5) Depress 9, six times.
- 6) Depress ENTER.
- 7) Depress lower DISPLAY.
C. Verify Condensate to Batch Controller (CV-1251) closed.
D. Open Batch Controller Outlet (CV-1250).
E. Verify both Makeup Filters in service:
F3A F3B F. Record initial BAAT (T-6) level ____________ in.
G. Start available Boric Acid pump(s) (P39A or P39B or both).
(1. CONTINUED ON NEXT PAGE) 1202.012 RT-12 Rev 4-23-12
CHANGE 1202.012 REPETITIVE TASKS 011 PAGE 43 of 93 Page 2 of 5 EMERGENCY BORATION
- 1. (Continued)
H. Start Batch Controller by depressing RUN key.
I. Adjust Batch Controller Flow CNTRL VLV (CV-1249) to 100% open as follows:
- 1) Depress VALVE SET.
- 2) Depress numbers: 1, 0, 0.
- 3) Depress ENTER.
- 4) Depress lower DISPLAY.
- 5) Depress RATE.
J. IF Batch Controller output rate < 5 gpm, THEN perform the following:
- 1) Stop running Boric Acid pump(s):
P39A P39B
- 2) Close Batch Controller Outlet (CV-1250).
- 3) Stop Batch Controller by depressing STOP key.
- 4) GO TO step 2.
K. Adjust Pressurizer Level Control Setpoint to 220".
L. Verify BWST T3 Outlet to OP HPI pump (CV-1407 or CV-1408) open.
M. WHEN PZR level is 100",
THEN establish maximum Letdown flow allowed by cooling capacity and component limitations.
(1. CONTINUED ON NEXT PAGE) 1202.012 RT-12 Rev 4-23-12
CHANGE 1202.012 REPETITIVE TASKS 011 PAGE 44 of 93 Page 3 of 5 EMERGENCY BORATION
- 1. (Continued)
N. Perform the following as necessary to maintain Makeup Tank level 55 to 86":
- 1) Close Batch Controller Outlet (CV-1250).
- 2) Stop running Boric Acid pump(s):
P39A P39B
- 3) Place 3-Way Valve (CV-1248) in BLEED.
- 4) WHEN Makeup Tank level is lowered to desired level, THEN perform the following:
a) Return 3-Way Valve (CV-1248) to LETDOWN.
b) Start available Boric Acid pump(s) (P39A or P39B or both).
c) Open Batch Controller Outlet (CV-1250).
O. As time permits, determine actual required boration as follows:
- 2) Calculate batch add required using Plant Computer OR Soluble Poison Concentration Control (1103.004), Attachment A.3, "Feed Volume For Batch Boration or Dilution". gal
- 3) Use 1103.004, Attachment D, "Volume of BAAT Vs. Depth of Liquid to determine desired final BAAT level.
(1. CONTINUED ON NEXT PAGE) 1202.012 RT-12 Rev 4-23-12
CHANGE 1202.012 REPETITIVE TASKS 011 PAGE 45 of 93 Page 4 of 5 EMERGENCY BORATION
- 1. (Continued)
P. WHEN required amount of boric acid has been added per step 1.O.
OR as determined by Reactor Engineering, THEN perform the following:
- 1) Stop Boric Acid pump(s):
P39A P39B
- 2) Close Batch Controller Outlet (CV-1250).
- 3) Verify Makeup Tank level 55 to 86".
- 4) Close BWST T3 Outlet to OP HPI pump (CV-1407 or CV-1408).
- 5) Adjust Letdown flow to desired rate.
1202.012 RT-12 Rev 4-23-12
CHANGE 1202.012 REPETITIVE TASKS 011 PAGE 46 of 93 Page 5 of 5 EMERGENCY BORATION
- 2. IF HPI will be used for emergency boration, THEN perform the following:
B. Verify HPI Block valve (CV-1220 or CV-1285) associated with running HPI pump open.
C. IF Letdown is in service, THEN place 3-Way Valve (CV-1248) in BLEED.
D. WHEN PZR level is 100",
THEN establish maximum Letdown flow allowed by cooling capacity and component limitations.
E. Maintain PZR level 200 to 220" as follows:
- 1) Verify both HPI Pump RECIRC Blocks open:
CV-1300 CV-1301
- 2) Throttle HPI Block valve (CV-1220 or CV-1285) as necessary.
F. As time permits, determine actual required boration as follows:
- 2) Calculate final BWST level for required boron addition using Plant Computer OR Soluble Poison Concentration Control (1103.004), Attachment A.6, "Continuous Feed and Bleed from BWST". ft G. WHEN required amount of boric acid has been added per step 2.F.
OR as determined by Reactor Engineering, THEN perform the following:
- 2) Adjust Letdown flow as directed by CRS.
END 1202.012 RT-12 Rev 4-23-12
CHANGE 1202.012 REPETITIVE TASKS 011 PAGE 3 of 93 Page 1 of 6 INITIATE HPI
THEN isolate Letdown by closing either:
Letdown Coolers Outlet (RCS) (CV-1221)
OR Letdown Coolers Outlets (RCS):
CV-1214 CV-1216
- 2. IF OP or STBY HPI pump is running, THEN perform the following:
A. Verify BWST T3 Outlet to OP or STBY HPI pump (CV-1407 or CV-1408) open.
B. IF RCP Seal Injection is in service, THEN place RCP Seal INJ Block (CV-1206) in OVRD.
C. WHEN associated BWST T3 Outlet is open, THEN open HPI Block valve associated with OP or STBY HPI pump (CV-1220 or CV-1285) to maintain PZR level and RCS press.
D. IF initiating HPI for Emergency Boration only, THEN GO TO RT-12 step 2.B.
E. IF PZR level or RCS press continues to drop, THEN open additional HPI Block valves associated with OP or STBY HPI pump:
P36A/B P36B/C CV-1219 CV-1227 CV-1278 CV-1228 CV-1279 CV-1284 1202.012 RT-2 Rev 4-23-12
CHANGE 1202.012 REPETITIVE TASKS 011 PAGE 4 of 93 Page 2 of 6 INITIATE HPI
- 3. IF either OP or STBY HPI pumps are available AND both pumps are off, THEN place OP or STBY HPI pump in service as follows:
A. Verify BWST T3 Outlet to OP and STBY HPI pump (CV-1407 or CV-1408) open.
B. Verify RCP Seal INJ Block (CV-1206) closed.
C. Close RCS Makeup Block (CV-1233 or CV-1234).
D. Prevent dead heading pump by verifying one of the following:
Both HPI Pump RECIRC Blocks open:
CV-1300 CV-1301 OR One HPI Block valve associated with OP HPI pump (CV-1220 or CV-1285) fully open.
E. IF HPI Pump (P-36B) will be used, THEN verify the following selected to energized bus:
P36B/P64B Bus Select MOD Control P64B Transfer Switch F. Start AUX Lube Oil pump for OP or STBY HPI pump.
G. Start OP or STBY HPI pump.
H. Stop AUX Lube Oil pump.
(3. CONTINUED ON NEXT PAGE) 1202.012 RT-2 Rev 4-23-12
CHANGE 1202.012 REPETITIVE TASKS 011 PAGE 5 of 93 Page 3 of 6 INITIATE HPI
- 3. (Continued)
I. WHEN associated BWST T3 Outlet is open, THEN open HPI Block valve associated with OP or STBY HPI pump (CV-1220 or CV-1285) to maintain PZR level and RCS press.
- 1) IF PZR level or RCS press continues to drop, THEN open additional HPI Block valves associated with OP or STBY HPI pump:
P36A/B P36B/C CV-1219 CV-1227 CV-1278 CV-1228 CV-1279 CV-1284
- 2) Monitor Makeup Tank level and control per step 10 as necessary.
J. IF initiating HPI for Emergency Boration only, THEN GO TO RT-12 step 2.B.
A. Open BWST T3 Outlet to ES HPI pump (CV-1407 or CV-1408).
B. Prevent dead heading pump by verifying one of the following:
Both HPI Pump RECIRC Blocks open:
CV-1300 CV-1301 OR One HPI Block valve associated with ES HPI pump (CV-1220 or CV-1285) fully open.
C. Start AUX Lube Oil pump for ES HPI pump.
D. IF OP and STBY pumps are both off, THEN verify RCP Seal INJ Block (CV-1206) closed.
(4. CONTINUED ON NEXT PAGE) 1202.012 RT-2 Rev 4-23-12
CHANGE 1202.012 REPETITIVE TASKS 011 PAGE 6 of 93 Page 4 of 6 INITIATE HPI
- 4. (Continued)
E. WHEN associated BWST T3 Outlet is open, THEN start ES HPI pump.
F. Stop AUX Lube Oil pump.
G. Open HPI Block valve associated with ES HPI pump (CV-1220 or CV-1285) to maintain PZR level and RCS press.
- 2) IF PZR level or RCS press continues to drop, THEN open additional HPI Block valves associated with ES HPI pump:
P36A P36C CV-1219 CV-1227 CV-1278 CV-1228 CV-1279 CV-1284
- 3) Monitor Makeup Tank level and control per step 10 as necessary.
- 5. IF all HPI Block valves are fully open AND additional HPI flow is required, THEN close HPI Pump RECIRC Block (CV-1300 or CV-1301).
- 6. IF only one train of HPI is available AND RCS press is > 600 psig, THEN throttle HPI Block valve with the highest flow to within 20 gpm of the next highest flow.
1202.012 RT-2 Rev 4-23-12
CHANGE 1202.012 REPETITIVE TASKS 011 PAGE 7 of 93 Page 5 of 6 INITIATE HPI
A. Verify all four RB Cooling Fans running:
VSF1A VSF1C VSF1B VSF1D B. Open RB Cooling Coils Service Water Inlet/Outlet valves:
CV-3812/CV-3814 CV-3813/CV-3815 C. Unlatch key-locked Chiller Bypass Dampers:
SV-7410 SV-7412 SV-7411 SV-7413
- 8. Verify the following sample valves closed on C26:
Pressurizer Steam Space Sample Valve (CV-1814)
Pressurizer Water Space Sample Valve (CV-1816)
Hot Leg Sample (SV-1840)
- 9. Verify the following High Point Vents closed, except when another procedure directs otherwise:
Reactor A Loop B Loop Pressurizer Vessel SV-1081 SV-1091 SV-1071 SV-1082 SV-1092 SV-1072 SV-1077 SV-1083 SV-1093 SV-1073 SV-1079 SV-1084 SV-1094 SV-1074 1202.012 RT-2 Rev 4-23-12
CHANGE 1202.012 REPETITIVE TASKS 011 PAGE 8 of 93 Page 6 of 6 INITIATE HPI
- 10. IF Makeup Tank level is rising AND it is necessary to control Makeup Tank level, THEN perform one or more of the following:
Verify all running HPI pump flow(s) 90 gpm/pump AND close HPI Pump RECIRC Block (CV-1300 or CV-1301).
- 1) Maintain running HPI pump flow 90 gpm/pump.
IF OP and STBY HPI pumps are both off, THEN start OP or STBY pump per step 3.
IF OP or STBY HPI pump is running, THEN perform the following:
- 1) Verify HPI Pump RECIRC Blocks open:
CV-1300 CV-1301
a) Transfer remaining HPI flow to OP or STBY HPI pump.
b) Start AUX Lube Oil pump for ES HPI pump.
d) Stop AUX Lube Oil pump.
END 1202.012 RT-2 Rev 4-23-12
Page 1 of 5 JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date:
JPM ID: A1JPM-RO-LTOP2 System/Duty Area: Reactor Coolant System Task: Establish LTOP Protection during Cooldown of the RCS JTA# ANO1-RO-OPROC-NORM-52 KA Value RO 4.2 SRO 4.3 KA
Reference:
006 A4.11 Approved For Administration To: RO X SRO X Task Location: Inside CR X Outside CR Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site Simulator Lab Testing Method: Perform Simulate Approximate Completion Time in Minutes: 15 Minutes Reference(s): 1102.010 Examinee's Name: Logon:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 5 JPM ID: A1JPM-RO-LTOP2 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
Prior to administration, ensure the Examinee has been briefed using Appendix E of NUREG-1021.
JPM INITIAL TASK CONDITIONS:
The plant is in a cooldown with RCS temperature <300°F but >275°F.
TASK STANDARD:
LTOP established with all HPI to P-32 Discharge valves in the LTOP position and ERV Block open and ERV setpoint switch in the 400 psig position.
TASK PERFORMANCE AIDS:
1102.010 Plant Shutdown and Cooldown, Step 10.5 SIMULATOR SETUP:
RCS temperature <300°F but >275°F and RCS pressure 380 psig.
Page 3 of 5 JPM ID: A1JPM-RO-LTOP2 INITIATING CUE: The SM/CRS directs you to establish LTOP protection per step 10.5 of 1102.010 Plant Shutdown and Cooldown.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT
- 1. Verify RCS pressure is 380 psig. Checked SPDS point P1020 or PMS point P1020 and verified RCS POSITIVE CUE: pressure 380 psig.
RCS pressure is 360 psig.
- 2. Place ERV Setpoint handswitch in On C04, positioned the ERV Setpoint 400 PSIG position. handswitch to the 400 PSIG position.
C _____ _____ _____
POSITIVE CUE:
400 PSIG amber light lit.
- 3. Verify the ERV Isolation (CV-1000) On C04, verified CV-1000 in the open open. position by observing red light ON, green light OFF above HS-1000. _____ _____ _____
POSITIVE CUE:
Red light ON, green light OFF.
- 4. If the plant computer is operating, On the plant computer, used then verify the following LTOP alarm computer function GD LTOP, GD plant computer points do not have a T101* or SVD to display points quality of DEL: LTOPBOO1,LTOPBOO2, LTOPBOOL, LTOPLVL, LTOPLVL1,
- LTOPBOO1 LTOPLVL2, LTOPTEMP,CO5-3,
- LTOPBOO2 CON272, T1016, T1017, L1001B,
- LTOPBOOL L1002B, PS3086, T3071 and verified
- LTOPLVL that each point does not have a
- LTOPLVL1 quality of DEL.
- LTOPLVL2
- LTOPTEMP
- CO5-3
- CON272
- T1016
- T1017
- L1001B
- L1002B
- PS3086
- T3071 POSITIVE CUE:
None of the designated points indicate a quality of DEL
Page 4 of 5 JPM ID: A1JPM-RO-LTOP2 C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT
- 5. Verify pressurizer level is between Verified pressurizer level between 70 70 and 95. and 95 using level indicators located on C04 or PMS/SPDS/PDS. _____ _____ _____
POSITIVE CUE:
Pressurizer level is 80 and stable.
EXAMINER NOTE: Inform Examinee that the STA is monitoring/plotting PZR level versus time AND that the cooldown rate is proper for Attachment J (RCS Functional Specification curve).
- 6. Place the following HPI to P-32 On C16 and C18, verified each HPI to Discharge valves in close and place P-32 Discharge valve closed and the associated key switch in the placed key switch for each valve in LTOP position: the LTOP position with white lights OFF.
- CV-1228 - HS-1228, SS-1228
- CV-1227 - HS-1227, SS-1227
- CV-1284 - HS-1284, SS-1284 C - CV-1285 - HS-1285, SS-1285
- CV-1278 - HS-1278, SS-1278
- CV-1279 - HS-1279, SS-1279
- CV-1219 - HS-1219, SS-1219 _____ _____ _____
- CV-1220 - HS-1220, SS-1220 POSITIVE CUE:
HPI injection valves Green lights on.
For each valve:
Block Valve Disable For LTOP in LTOP position and White light went OFF.
NEGATIVE CUE:
LTOP Trouble (K09-E7) annunciator is in alarm.
EXAMINER NOTE: Inform Examinee that it is not desired to unprotect PZR Level alarm functions.
END
Page 5 of 5 JPM ID: A1JPM-RO-LTOP2 INITIAL CONDITIONS:
The plant is in a cooldown with RCS temperature <300°F but
>275°F.
INITIATING CUE:
The SM/CRS directs you to establish LTOP protection per step 10.5 of 1102.010 Plant Shutdown and Cooldown.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 39 of 143 1102.010 PLANT SHUTDOWN AND COOLDOWN CHANGE: 069 CAUTION R The following section has been determined to have a Reactivity A Addition Potential (RAP) and this activity is classified as a P Risk Level R2.
10.0 Establishing Decay Heat Removal System Operation 10.1 Verify a Condition Report has been initiated to track this Plant Shutdown and Cooldown (1102.010) package to completion and forwarded to Document Control.
10.2 IF going to Mode 5, THEN implement Containment Closure Control per Attachment G of Decay Heat Removal and LTOP System Control (1015.002),
prior to placing plant in a condition where containment integrity is not required.
10.2.1 Complete Attachment G of Decay Heat Removal and LTOP System Control (1015.002) for applicable valves listed on the following:
Category E/Locked Component Log (E-doc 1015.001H)
Containment Penetration Valve Log (Form 1015.001D) 10.3 WHEN RCS < 350°F in Mode 3 and through Mode 4, THEN verify two makeup pumps remain functional per TRO 3.5.1.
10.4 WHEN desired to raise Letdown flow, THEN slowly open Letdown Block Orifice Manual Bypass (MU-4). Location: LNPR, Northeast corner, 7 ft up.
10.4.1 Adjust as desired, Letdown Block Orifice Bypass Valve (CV-1223).
{4.3.2}
10.5 WHEN RC temperature is <300°F but >275°F AND RC pressure is 380 psig as indicated on PT-1020 (SPDS P1020),
THEN establish LTOP protection as follows:
10.5.1 Place ERV Setpoint handswitch in 400 PSIG position.
10.5.2 Verify ERV Isolation (CV-1000) open.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 40 of 143 1102.010 PLANT SHUTDOWN AND COOLDOWN CHANGE: 069 10.5.3 IF the plant computer is operating, THEN verify by using "GD LTOP*" (preferred),
"GD T101*", SVD, or similar function, that the following computer points do NOT have a quality of DEL.
LTOPBOO1 LTOPLVL2 T1017 LTOPBOO2 LTOPTEMP L1001B LTOPBOOL C05-3 L1002B LTOPLVL CON272 PS3086 LTOPLVL1 T1016 T3071 10.5.4 IF the plant computer is NOT operating, THEN contact Computer Support to enable LTOP alarm.
NOTE For LTOP concerns, maximum allowable Pressurizer level with RCS temperature <272°F and Reactor Vessel head in place is:
105" at RCS pressures >100 psig 150" at RCS pressures 100 psig Annunciator "LTOP Trouble" (K09-E7) alarms at the following Pressurizer level setpoints with RCS temperature <272°F:
95" at RCS pressures >100 psig 140" at RCS pressures 100 psig 10.5.5 Verify Pressurizer level is between 70" and 95".
10.5.6 Monitor and plot Pressurizer level vs. time during cooldown at least once every 15 minutes while RCS temperature is 272 F (SR 3.4.11.1).
10.5.7 Limit RCS cooldown rate as necessary to maintain RCS temperature above and to the right of the RCS Functional Specification curve, Attachment J.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 41 of 143 1102.010 PLANT SHUTDOWN AND COOLDOWN CHANGE: 069 10.5.8 For each of the following HPI to P-32(A, B, C, or D) Discharge valves perform the following:
Place HPI to P-32A Disch CV-1228 handswitch (HS-1228) to CLOSE.
Place HPI to P-32A Disch CV-1228 LTOP handswitch (SS-1228) to LTOP.
Place HPI to P-32B Disch CV-1227 handswitch (HS-1227) to CLOSE.
Place HPI to P-32B Disch CV-1227 LTOP handswitch (SS-1227) to LTOP.
Place HPI to P-32C Disch CV-1284 handswitch (HS-1284) to CLOSE.
Place HPI to P-32C Disch CV-1284 LTOP handswitch (SS-1284) to LTOP.
Place HPI to P-32D Disch CV-1285 handswitch (HS-1285) to CLOSE.
Place HPI to P-32D Disch CV-1285 LTOP handswitch (SS-1285) to LTOP.
Place HPI to P-32A Disch CV-1278 handswitch (HS-1278) to CLOSE.
Place HPI to P-32A Disch CV-1278 LTOP handswitch (SS-1278) to LTOP.
Place HPI to P-32B Disch CV-1279 handswitch (HS-1279) to CLOSE.
Place HPI to P-32B Disch CV-1279 LTOP handswitch (SS-1279) to LTOP.
Place HPI to P-32C Disch CV-1219 handswitch (HS-1219) to CLOSE.
Place HPI to P-32C Disch CV-1219 LTOP handswitch (SS-1219) to LTOP.
Place HPI to P-32D Disch CV-1220 handswitch (HS-1220) to CLOSE.
Place HPI to P-32D Disch CV-1220 LTOP handswitch (SS-1220) to LTOP.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 42 of 143 1102.010 PLANT SHUTDOWN AND COOLDOWN CHANGE: 069 10.5.9 IF desired, THEN contact Computer Support to unprotect the alarm functions on the plant computer for PZR Level (L1001B and L1002B).
A. WHEN unprotected, THEN adjust setpoints below current LTOP requirements. N/A if not performed.
10.6 IF shutdown directed by Tech Specs AND Attachment P of Power Reduction and Plant Shutdown (1102.016) has NOT been performed for this shutdown, THEN initiate Attachment L of this procedure to determine mode specific time limits and continue with cooldown.
10.7 IF a Reactivity Management Brief has NOT been conducted, THEN perform a Reactivity Management Brief per COPD-030 with an SRO.
NOTE RC Loop A Decay Heat Iso Valve (CV-1050) and Decay Heat Suction From RCS Isol Vlv (CV-1410) are stroke tested per Part 1 of Supplement 3 per Decay Heat Removal Operating Procedure (1104.004) when entering Mode 5.
Operation <260 psig with P-32A and B operating is limited to <2 hours due to seal staging limits.
10.8 WHEN RC temperature is <280°F, AND RC pressure is <290 psig, AND if going to Mode 5 AND Supplement 3 of Decay Heat Removal Operating Procedure (1104.004) has NOT been performed within the last 92 days, THEN perform Part 1 of Supplement 3 per Decay Heat Removal Operating Procedure (1104.004).
10.8.1 IF P-32A and B are running, THEN maintain RCS pressure 260 psig and
<290 psig during performance of Part 1 of Supplement 3 per Decay Heat Removal Operating Procedure (1104.004).
10.9 Verify required boron concentration is achieved prior to securing RCPs.
10.10 Continue cooldown to <280°F and depressurization to
<250 psig while maintaining the limits of Attachment A, then hold temperature and pressure constant.
NOTE At least one LPI flowpath is flow tested, per Decay Heat Removal Operating Procedure (1104.004) Supplement 3 (Part 2), during the following step.
Tests are performed when required by the Surveillance Test Schedule.
10.11 Establish DH removal flow per "Decay Heat Removal During Cooldown" section of Decay Heat Removal Operating Procedure (1104.004).
Page 1 of 4 JOB PERFORMANCE MEASURE Unit: 1 Rev # 1 Date:
JPM ID: A1JPM-RO-MUP06 System/Duty Area: Makeup and Purification Task: Perform RCS Delithiation JTA# ANO1-RO-MUP-NORM-38 KA Value RO 3.0 SRO 3.0 KA
Reference:
004 A1.11 Approved For Administration To: RO X SRO X Task Location: Inside CR X Outside CR Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site Simulator Lab Testing Method: Perform Simulate Approximate Completion Time in Minutes: 5 Minutes Reference(s): 1104.002 MAKEUP & PURIFICATION SYSTEM OPERATION, Section 10.7 Examinee's Name: Logon:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 4 JPM ID: A1JPM-RO-MUP06 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
Prior to administration, ensure the Examinee has been briefed using Appendix E of NUREG-1021.
JPM INITIAL TASK CONDITIONS:
The plant is in Mode 1. Chemistry samples require that a 10 minute RCS delithiation be performed. The difference between RCS boron and the delithiating DI is 5 ppm.
This is an Alternate Path JPM.
TASK STANDARD: Non-delithiating DI returned to service after placing the delithiating DI into service before makeup tank level lowers by >5 inches.
TASK PERFORMANCE AIDS: 1104.002 MAKEUP & PURIFICATION SYSTEM OPERATION, Section 10.7 SUGGESTED SIMULATOR SETUP:
Mode 1. The Delithiating Letdown DI T-36A/B manual outlet valve is miss positioned (CR-ANO-1-2007-01710) in the closed position: IRF MU8A 0 or IRF MU8B 0
Page 3 of 4 JPM ID: A1JPM-RO-MUP06 INITIATING CUE: The SM/CRS directs you to perform a 10 minute RCS delithiation per 1104.002 Section 10.7.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT
- 1. Open inlet to delithiating DI: On panel C04, opened inlet control
- T-36A Purif Demineralizer Inlet valve to the de-lithiating DI (CV-1244 (CV-1244) or CV-1245).
C
- T-36B Purif Demineralizer Inlet (CV-1245) _____ _____ _____
POSITIVE CUE:
Red light ON, green light OFF for delithiating DI.
- 2. Close inlet to previously in-service DI On panel C04, closed inlet control (CV-1244 or CV-1245). valve to the non de-lithiating DI (CV-C 1244 or CV-1245).
POSITIVE CUE:
Green light ON, red light OFF for non de-lithiating DI.
- 3. Observe that letdown flow is Observed abnormal letdown flow and approximately equal to previous value. pressure on panel C09 (FI-1236/PI-1237).
NEGATIVE CUE:
Letdown pressure is cycling erratically on PI-1237 on C04.
- 4. Swap back to the previously in-service DI as follows:
4a. Open inlet to previously in-service Before makeup tank level lowered by DI (CV-1244 or CV-1245). >5 inches, opened inlet to previously C in-service DI (CV-1244 or CV-1245).
POSITIVE CUE:
Red light ON, green light OFF for previously in-service DI.
4b. Close inlet to delithiating DI Closed inlet to delithiating DI (CV-1244 or CV-1245). (CV-1244 or CV-1245).
POSITIVE CUE:
Green light ON, red light OFF for Delithiating DI inlet valve.
Examinee should inform CRS that task cant be completed. JPM complete.
END
Page 4 of 4 A1JPM-RO-MUP06 INITIAL CONDITIONS:
The plant is in Mode1. Chemistry samples require that a 10 minute RCS delithiation be performed. The difference between RCS boron and the delithiating DI is 5 ppm.
INITIATING CUE:
The SM/CRS directs you to perform a 10 minute RCS delithiation per 1104.002 Section 10.7.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 65 of 383 1104.002 MAKEUP & PURIFICATION SYSTEM OPERATION CHANGE: 074 10.7 RCS Delithiation NOTE At all times, placing an idle DI into service may result in a change in RCS/Decay Heat boron concentration and potentially impact reactivity.
10.7.1 Obtain total desired delithiation time from Chemistry.
10.7.2 IF the reactor is critical, THEN delithiate per one of the following methods (A, B, or C):
NOTE The delithiating DI may be considered at RCS equilibrium boron (<50 ppm) if any of the following conditions are met. Otherwise, the delithiating DI boron concentration is considered to be NOT known.
Delithiating DI resin was initially borated AND has two hours of delithiating DI service time at ~80 gpm letdown flow.
Delithiating DI resin was initially borated AND RCS boron is within 50 ppm of that initial boration concentration.
Chemist sample at delithiating DI outlet shows boron concentration within 50 ppm of RCS boron.
Status Board identifies delithiating DI is at equilibrium.
A. Preferred Method IF difference of RCS boron and delithiating DI
<50 ppm, THEN perform the following:
- 1. Swap DIs as follows:
- a. Open inlet to delithiating DI:
T-36A Purif Demineralizer Inlet (CV-1244)
T-36B Purif Demineralizer Inlet (CV-1245)
- b. Close inlet to previously in-service DI:
T-36A Purif Demineralizer Inlet (CV-1244)
T-36B Purif Demineralizer Inlet (CV-1245)
- 2. Observe that letdown flow is approximately equal to previous value.
PROC./WORK PLAN N
O. PROCEDURE
/WORK PLAN TITLE:
PAGE: 66 of 383 1104.002 MAKEUP & PURIFICATION SYSTEM OPERATION CHANGE: 074
- 3. WHEN recommended delithiation time is complete OR letdown flow changes significantly, THEN swap back to the previously in-service DI as follows:
- a. Open inlet to previously in-service DI:
T-36A Purif Demineralizer Inlet (CV-1244)
T-36B Purif Demineralizer Inlet (CV-1245)
- b. Close inlet to delithiating DI:
T-36A Purif Demineralizer Inlet (CV-1244)
T-36B Purif Demineralizer Inlet (CV-1245)
- 4. Update plant status board with the following:
RCS boron concentration at DI outlet from either, chemist sample if available, or the current RCS boron concentration.
Whether the DI was borated to equilibrium if known.
- 5. Record completion of delithiation in the Station Log including length of time DI was in-service AND letdown flowrate.
B. IF the difference of RCS boron and delithiating DI is
>50 ppm, AND RCS chemistry is NOT at risk of an out of spec condition, THEN perform the following:
- 1. Borate or dilute the delithiating DI as needed per Maintaining Constant RCS boron Concentration During DI Boration/Dilution section of this procedure.
- 2. WHEN delithiating DI is within 50 ppm of RCS, THEN GO TO step 10.7.2.A.
Page 1 of 5 JOB PERFORMANCE MEASURE Unit: 1 Rev # 5 Date:
JPM ID: A1JPM-RO-AOP26 System/Duty Area: Emergency and Abnormal Operations Task: Respond to Loss of Load Center B6 JTA# ANO1-RO-AOP-OFFNORM-384 KA Value RO 3.4 SRO 3.9 KA
Reference:
062 A2.01 Approved For Administration To: RO X SRO X Task Location: Inside CR X Outside CR Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site Simulator Lab Testing Method: Perform Simulate Approximate Completion Time in Minutes: 15 Minutes Reference(s): 1203.046 Section 3.6 Loss of B6 Load Center Examinee's Name: Logon:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 5 JPM ID: A1JPM-RO-AOP26 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
Prior to administration, ensure the Examinee has been briefed using Appendix E of NUREG-1021.
JPM INITIAL TASK CONDITIONS:
Breaker A-401 (A4 Feed to B6) was accidentally tripped resulting in the loss of Load Center B6. Unit 1 is at 100% power.
P-36C is the operating Makeup Pump.
TASK STANDARD:
AOP 1203.046, steps 3.6.1 through 3.6.9 completed.
TASK PERFORMANCE AIDS:
Copy of 1203.046 Section 3.6 Simulator Setup: 100% power with breaker A-401 OPEN. P-36C is the operating makeup pump.
P-4B SW Pump MOD to A4 B55/56 to B6 SG3 = Closed SG4 = Open Simulator in FREEZE until examinee says ready to begin task.
Page 3 of 5 JPM ID: A1JPM-RO-AOP26 INITIATING CUE: The CRS/SM directs you to respond to a Loss of Load Center B6 per 1203.046, perform steps 3.6.1 through 3.6.9. Simulator in FREEZE until examinee ready to begin task.
C PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT
selected to the energized bus. B56 to B5.
POSITIVE CUE:
B55/56 energized.
- 2. Isolate Letdown. On panel C18, closed letdown cooler outlet isolation valves CV-1214 and CV-C POSITIVE CUE: 1216. _____ _____ _____
CV-1214 and CV-1216 green lights ON.
- 3. Place Main Lube Oil Temp Control On panel C19, placed CV-4026 hand (TIC-4026) on C19 in MANUAL. switch (TIC-4026) in MANUAL C _____ _____ _____
POSITIVE CUE:
TIC-4026 MANUAL.
- 4. Throttle open CV-4026 On panel C19, CV-4026 is throttled open C
POSITIVE CUE: _____ _____ _____
CV-4026 throttled open.
- 5. Place Gen H2 Temp Control (TIC- On panel C19, placed CV-4018 hand 4018) on C19 in MANUAL. switch (TIC-4018) in MANUAL C _____ _____ _____
POSITIVE CUE:
TIC-4018 MANUAL.
- 6. Throttle open CV-4018 On panel C19, CV-4018 is throttled open C _____ _____ _____
POSITIVE CUE:
CV-4018 throttled open.
CONTINUED
Page 4 of 5 JPM ID: A1JPM-RO-AOP26 C PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT
- 7. Close RCP Seal Injection Block At C04, placed hand switch for CV-1206 valve. to close.
POSITIVE CUE:
CV-1206 indicates GREEN.
- 8. Verify DG2 starts. On panel C10, checked DG2 running.
POSITIVE CUE:
DG2 running.
- 9. Verify A2 feed to A4 is tripped. On panel C10, checked A-409 indicates GREEN. _____ _____ _____
POSITIVE CUE:
A-409 indicates GREEN.
- 10. Verify DG2 output breaker closes. On panel C10, checked A-408 indicates RED. _____ _____ _____
POSITIVE CUE:
A-408 indicates RED.
- 11. Verify SW pump P4C restarts. On panel C16, checked P-4C indicates RED. _____ _____ _____
POSITIVE CUE:
P-4C on C16 indicates RED.
INSTRUCTOR CUE: Inform Examinee that breaker A-401 has no fault, is available to be closed if asked.
- 12. Verify 4160V high side feeder On panel C10, closed breaker A-401 A4 breaker to B6 transformer closed. Feed to B6.
C _____ _____ _____
POSITIVE CUE:
A-401 indicates RED light ON.
- 13. Verify 480V low side feeder On panel C10, checked B-612 indicates breaker to B6 closed. closed RED light ON.
POSITIVE CUE:
B-612 indicates RED light ON.
END
Page 5 of 5 JPM ID: A1JPM-RO-AOP26 INITIAL CONDITIONS:
Breaker A-401 (A4 Feed to B6) was accidentally tripped resulting in the loss of Load Center B6.
Unit 1 is at 100% power.
P-36C is the operating Makeup Pump.
INITIATING CUE:
The CRS/SM directs you to respond to a Loss of Load Center B6 per 1203.046, perform steps 3.6.1 through 3.6.9.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 15 of 25 1203.046 LOSS OF LOADCENTER CHANGE: 008 3.6 Loss of Loadcenter B6 3.6.1 Verify MCC B55 and B56 are selected to the energized bus.
NOTE Loss of Y02 causes Makeup Filter Inlet and Purification Demineralizer Inlet valves to fail closed resulting in lifting Letdown Relief valve discharging to Aux Bldg Equipment Drain Tank (T-11).
3.6.2 Isolate Letdown by closing the following valves:
Letdown Cooler Outlet (CV-1214)
Letdown Cooler Outlet (CV-1216)
NOTE Loss of Y02 causes T-G L.O. Coolers E-15A&B Temp Cont Vlv (CV-4026) and T-G H2 Temp Control Valve (CV-4018) to close if in AUTO due to loss of temperature input.
SW and ACW flow can be monitored using the SPDS points below.
- F3901 Loop II SW Flow
- F3902 Loop I SW Flow
- F3903 ACW Flow 3.6.3 Place Main Lube Oil Temp Control (TIC-4026) on C19 in MANUAL.
3.6.4 Throttle open CV-4026.
3.6.5 Place Gen H2 Temp Control (TIC-4018) on C19 in MANUAL.
3.6.6 Throttle open CV-4018.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 16 of 25 1203.046 LOSS OF LOADCENTER CHANGE: 008 NOTE If the operating Makeup Pump is on bus A4, the Aux Lube Oil pump will not start due to loss of power. In this case the Makeup Pump should be tripped without starting the Aux Lube Oil pump.
With loss of Y02, RCP Seal Injection Block (CV-1206) will not auto-close on low flow.
Securing the Makeup Pump which is only aligned to the Makeup Tank, minimizes the risk of pump damage due to loss of pump suction.
3.6.7 IF Makeup Pump is running AND suction is aligned to Makeup Tank (T-4) ONLY, THEN perform the following:
A. IF available, THEN start associated Aux Lube Oil pump.
B. Stop Makeup Pump.
C. IF available, THEN after ~3 minutes, stop Aux Lube Oil pump.
3.6.8 Close RCP Seal Injection Block (CV-1206).
3.6.9 Verify the following:
A. DG2 starts.
B. A2 Feed to A4 (A-409) is tripped.
C. DG2 Output (A-408) closes to re-energize bus A4.
D. Operating Service Water Pump on bus A4 restarts.
E. A4 Feed to B6 (A-401) is closed.
F. A4 Feed to B6 (B-612) is closed.
3.6.10 IF A-401 or B-612 cannot be closed, AND it is determined the fault is not on bus B6, THEN consider powering bus B6 from B5 per "Bus B5 to B6 Crosstie to Energize Dead Bus" section of ES Electrical System Operation (1107.002).
Page 1 of 6 JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date:
TUOI NUMBER: A1JPM-RO-HYD05 System/Duty Area: Hydrogen Recombiner and Purge Control System Task: Place Hydrogen Recombiner M55B in Operation JA# ANO1-RO-RBH2-NORM-1 KA Value RO 4.0 SRO 4.0 KA Reference 028 A4.01 Approved For Administration To: RO SRO Task Location: Inside CR: Outside CR: Both:
Suggested Testing Environment And Method (Perform Or Simulate #):
Plant Site: Simulator#: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Simulator #: Plant Site: Lab Testing Method: Simulate: Perform:
Approximate Completion Time In Minutes: 15 Minutes Reference(s): 1104.031, Chg. 024 Examinee's Name: Logon:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Date:
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 6 TUOI NUMBER: A1JPM-RO-HYD05 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
Prior to administration, ensure the Examinee has been briefed using Appendix E of NUREG-1021.
JPM INITIAL TASK CONDITIONS:
A LOCA has occurred. Containment hydrogen concentration is 2.1%.
Both hydrogen recombiners are shutdown.
Containment pressure is 20.0 psia.
Pre-LOCA containment temperature was 92°F.
TASK STANDARD:
This is an Alternate path JPM Hydrogen recombiner M55B in operation at power setting of 53.0 KW to 55.0 KW on JI-1001.
TASK PERFORMANCE AIDS:
1104.031, section 8.0 and Att. B
Page 3 of 6 TUOI NUMBER: A1JPM-RO-HYD05 INITIATING CUE: The CRS/SM directs you to place hydrogen recombiner M55A in service.
UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT
- 1. Verify power adjust potentiometer is set at zero. Verified power adjust potentiometer set to zero on C26 POSITIVE CUE: (if not already at zero, used Power adjust potentiometer for M55A set at zero on knurled knob on power adjust ____ ____ ____
C26. potentiometer on C26, turned to the left ,and set at zero using HS-7472).
POSITIVE CUE:
C M55A red light ON. ____ ____ ____
NEGATIVE CUE:
M55A green lights ON.
- 3. Select thermocouple #1, 2 or 3 to input to Thermocouple #1, 2 or 3 recombiner temperature indicators TI-2300 selected to input to TI-2300 using hand switch HS-7474 on POSITIVE CUE: C26.
Thermocouple #1, 2 or 3 selected as desired to input to ____ ____ ____
TI-2300.
- 4. Increase power to ~5 KW. Slowly adjusted potentiometer clockwise until power on JI-1000 POSITIVE CUE: on C26 indicated ~5 KW. ____ ____ ____
Power on JI-1000 indicates 5KW.
INSTRUCTOR NOTE:
Inform examinee that ten minutes have elapsed after one minute at 10 KW.
- 5. Slowly increase power to 10 KW and record initial Increased power to ~10 KW time. using power adjust potentiometer on C26. ____ ____ ____
POSITIVE CUE: Recorded time 10 KW was Power is at 10 KW on JI-1000. achieved.
INSTRUCTOR NOTE:
Inform examinee that taking data every 30 minutes on Attachment E will be simulated.
- 6. Slowly increase power to 20 KW on M55A and hold Increased power on M55A to for 5 minutes. ~20 KW using power adjust potentiometer on C26. ____ ____ ____
POSITIVE CUE:
Power at 20 KW on JI-1000.
INSTRUCTOR NOTE:
Inform examinee that five minutes have elapsed after one minute at 20 KW.
- 7. Determine power required from Attachment B Determined Recombiner power C based on containment pressure (20.0 psia and to be from 58.0 to 59.0 KW ____ ____ ____
92°F Pre-LOCA containment temperature). using Attachment B of 1104.031.
Page 4 of 6 TUOI NUMBER: A1JPM-RO-HYD05 UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT INSTRUCTOR NOTE:
Give the examinee the Negative Cue after the potentiometer is fully on.
- 8. Slowly increase power to 58.0-59.0 KW range. Attempted to raise power to 58.0 to 59.0 KW range using power adjust potentiometer (HS-7473)
NEGATIVE CUE: on C26.
Hydrogen concentration rising on QI-7459 and power is Determined M55B should be ____ ____ ____
only 30 KW with the potentiometer fully on. placed in service due to direction in step 8.2.10.
INSTRUCTOR NOTE:
Hand examinee procedure section 9.0 when examinee requests this section.
- 9. Verify power adjust potentiometer is set at zero. Verified power adjust potentiometer set to zero on C26 POSITIVE CUE: (if not already at zero, used Power adjust potentiometer for M55B set at zero on knurled knob on power adjust C26. potentiometer on C26, turned to ____ ____ ____
the left, and set at zero using HS-7473).
POSITIVE CUE:
M55B red light ON.
C ____ ____ ____
NEGATIVE CUE:
M55B green lights ON.
- 11. Select thermocouple #1, 2 or 3 to input to Thermocouple #1, 2 or 3 recombiner temperature indicators TI-2301. selected to input to TI-2301 using hand switch HS-7473 on POSITIVE CUE: C26.
Thermocouple #1, 2 or 3 selected as desired to input to ____ ____ ____
TI-2301.
- 12. Increase power to ~5 KW. Slowly adjusted potentiometer clockwise until power on JI-1001 POSITIVE CUE: on C26 indicated ~5 KW.
Power on JI-1001 indicates 5KW
Page 5 of 6 TUOI NUMBER: A1JPM-RO-HYD05 UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT INSTRUCTOR NOTES:
Inform examinee that ten minutes have elapsed after one minute at 10 KW.
Inform examinee that taking data every 30 minutes on Attachment E will be simulated.
- 13. Slowly increase power to 10 KW and record initial Increased power to ~10 KW time. using power adjust potentiometer on C26.
POSITIVE CUE: Recorded time 10 KW was Power is at 10 KW on JI-1001. achieved. ____ ____ ____
- 14. Slowly increase power to 20 KW on M55B and hold Increased power on M55B to for 5 minutes. ~20 KW using power adjust potentiometer on C26.
POSITIVE CUE:
Power at 20 KW on JI-1001. ____ ____ ____
INSTRUCTOR NOTE:
Inform examinee that five minutes have elapsed after one minute at 20 KW.
- 15. Determine power required from Attachment B Determined Recombiner power based on containment pressure (20.0 psia and to be from 53.0 to 55.0 KW 92°F Pre-LOCA containment temperature). using Attachment B of 1104.031.
C ____ ____ ____
- 16. Slowly increase power to 53.0-55.0 KW range. Raised power to 53.0 to 55.0 KW range using power adjust potentiometer HS-7473 on C26.
C POSITIVE CUE: ____ ____ ____
Power is at 53 to 55 KW on JI-1001.
END
Page 6 of 6 TUOI NUMBER: A1JPM-RO-HYD05 INITIAL CONDITIONS:
A LOCA has occurred.
Containment hydrogen concentration is 2.1%.
Both hydrogen recombiners are shutdown.
Containment pressure is 20.0 psia.
Pre-LOCA containment temperature was 92°F.
INITIATING CUE:
The CRS/SM directs you to place hydrogen recombiner M55A in service.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 10 of 84 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 026 7.6 WHEN no longer required, THEN perform the following to secure Hydrogen Samplers (C178 and C179):
7.6.1 Place Sample Compr (C-19A & C) handswitch (HS-7457) to STOP.
7.6.2 At C26, place Hydrogen Sampler C178 Sampler Isolations (SV-7457 and SV-7467) key switch (HS-7467) to CLOSE.
7.6.3 Place Sample Compr (C-19B & D) handswitch (HS-7459) to STOP.
7.6.4 At C26, place Hydrogen Sampler C179 Sampler Isolations (SV-7459 and SV-7469) handswitch (HS-7469) to CLOSE.
CAUTION Hydrogen Recombiner, M55A or M55B, should be placed in operation following a LOCA as soon as time permits and must be in operation before hydrogen concentration reaches 3.0% as indicated on the highest reading Hydrogen analyzer.
8.0 Placing Hydrogen Recombiner (M55A) in Service 8.1 Perform the following to place Hydrogen Recombiner (M55A) in standby:
8.1.1 Verify Power Adjust Potentiometer handswitch (HS-7472) is set at zero for Hydrogen Recombiner (M55A).
8.1.2 Place Hydrogen Recombiner (M55A) handswitch (HS-7470) to ON.
CAUTION Selecting "OFF" on Thermocouple Selector handswitch (HS-7474) causes excessive current in Hydrogen Recombiner (M55A) Temperature (TI-2300) leading to frequent failure.
8.1.3 On Thermocouple Selector handswitch (HS-7474) select thermocouple #1, 2, or 3 to input to Hydrogen Recombiner (M55A) Temperature (TI-2300).
NOTE The term slowly used in this section means raising potentiometer settings slowly enough to witness KW rise without overshooting the target setting.
8.1.4 Slowly turn Power Adjust Potentiometer handswitch (HS-7472) clockwise to raise power to 5 KW as indicated on M55A Power (JI-1000).
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 11 of 84 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 026 8.1.5 Slowly turn Power Adjust Potentiometer handswitch (HS-7472) clockwise to raise power to 10 KW as indicated on M55A Power (JI-1000).
A. Record initial time at 10 KW: __________.
B. Maintain 10 KW output for standby service.
CAUTION Hydrogen Recombiner, M55A or M55B, should be placed in operation following a LOCA as soon as time permits and must be in operation before hydrogen concentration reaches 3.0% as indicated on the highest reading Hydrogen analyzer.
8.2 Perform the following to place Hydrogen Recombiner (M55A) in-service:
8.2.1 During heatup, monitor and record all three thermocouple temperatures every 30 minutes on "Hydrogen Recombiner M55A Data Sheet",
Attachment D.
8.2.2 Verify Hydrogen Recombiner (M55A) has been at 10 KW for at least 10 minutes.
8.2.3 Slowly turn Power Adjust Potentiometer handswitch (HS-7472) clockwise to raise power to 20 KW as indicated on M55A Power (JI-1000)
AND hold for 5 minutes.
A. Record initial time at 20 KW: __________.
8.2.4 Determine power required from "Recombiner Power (M-55A)
Versus Containment Pressure", Attachment B of this procedure, page 1 of 2, based on containment pressure.
A. KW setting __________
CAUTION Recombiner power >75 KW and temperature >1450 F may cause heater failure.
B. Slowly turn Power Adjust Potentiometer handswitch (HS-7472) clockwise to raise power to the value determined above as indicated on M55A Power (JI-1000).
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 12 of 84 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 026 8.2.5 Verify proper Hydrogen Recombiner operation by observing the following:
NOTE Hydrogen concentration reduction is the long-term, primary method of verification.
Hydrogen concentration reduction shall be used regardless of recombiner power or temperature indication as the verification of proper recombiner operation.
Hydrogen concentration stable or dropping on both of the following:
C-178 H2 Sampler H2 Concentration % H2 (QI-7457)
C-179 H2 Sampler H2 Concentration % H2 (QI-7459)
Hydrogen Recombiner maintaining power at value determined in step 8.2.4.A.
NOTE Thermocouples are non-Q and will not be reliable indicators in a post-LOCA environment.
Recombiner temperature can aid in trending recombiner operation. The following steps are provided as guidelines.
Recombiner temperature may be plotted on "Typical Recombiner Heatup Rate",
Attachment C for verifying thermocouple operation and estimating time when recombination temperature will be reached.
8.2.6 Establish validity of temperature indication by comparing T between thermocouples.
A. IF all three thermocouples fall within a 60°F band, THEN average the three temperatures.
B. IF no two thermocouples are within 60°F of each other, THEN thermocouples should be considered inaccurate.
C. IF difference of the three temperatures >60°F AND two temperatures are within 60°F, THEN average the closest two.
8.2.7 Monitor for indication that recombiner operating temperature of 1225°F has been reached.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 13 of 84 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 026 NOTE Valid thermocouples show a ramp rise in temperature with hydrogen concentration >2%, indicating recombination temperature has been reached and recombination is taking place.
8.2.8 IF hydrogen concentration is >2%,
THEN monitor for a ramp rise in temperature.
8.2.9 After four hours of full power operation, log data in "Hydrogen Recombiner M55A Data Sheet", Attachment D once per hour.
8.2.10 IF proper power setting causes average valid temperature to exceed 1450°F OR in-service Hydrogen Recombiner has insufficient capacity, THEN place standby Hydrogen Recombiner in-service.
8.2.11 Do NOT lower Hydrogen Recombiner M55A power based on extreme temperature. Maintain power until standby Hydrogen Recombiner is heated to operating temperature of ~1225 F.
DO NOT GIVE TO CANDIDATE UNTIL IT IS REQUESTED!
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 14 of 84 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 026 9.0 Placing Hydrogen Recombiner (M55B) in Service 9.1 Perform the following to place Hydrogen Recombiner (M55B) in standby:
9.1.1 Verify Power Adjust Potentiometer handswitch (HS-7473) is set at zero for Hydrogen Recombiner (M55B).
9.1.2 Place Hydrogen Recombiner (M55B) handswitch (HS-7471) to ON.
CAUTION Selecting "OFF" on Thermocouple Selector handswitch (HS-7475) causes excessive current in Hydrogen Recombiner (M55B) Temperature (TI-2301) leading to frequent failure.
9.1.3 On Thermocouple Selector handswitch (HS-7475) select thermocouple #1, 2, or 3 to input to Hydrogen Recombiner (M55B) Temperature (TI-2301).
NOTE The term slowly used in this section means raising potentiometer settings slowly enough to witness KW rise without overshooting the target setting.
9.1.4 Slowly turn Power Adjust Potentiometer handswitch (HS-7473) clockwise to raise power to 5 KW as indicated on M55B Power (JI-1001).
9.1.5 Slowly turn Power Adjust Potentiometer handswitch (HS-7473) clockwise to raise power to 10 KW as indicated on M55B Power (JI-1001).
A. Record initial time at 10 KW: __________.
B. Maintain 10 KW output for standby service.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 15 of 84 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 026 CAUTION Hydrogen Recombiner, M55A or M55B, should be placed in operation following a LOCA as soon as time permits and must be in operation before hydrogen concentration reaches 3.0% as indicated on the highest reading Hydrogen analyzer.
9.2 Perform the following to place Hydrogen Recombiner (M55B) in-service:
9.2.1 During heatup, monitor and record all three thermocouple temperatures every 30 minutes on "Hydrogen Recombiner M55B Data Sheet",
Attachment E.
9.2.2 Verify Hydrogen Recombiner (M55B) has been at 10 KW for at least 10 minutes.
9.2.3 Slowly turn Power Adjust Potentiometer handswitch (HS-7473) clockwise to raise power to 20 KW as indicated on M55B Power (JI-1001)
AND hold for 5 minutes.
A. Record initial time at 20 KW: __________.
9.2.4 Determine power required from "Recombiner Power (M-55B)
Versus Containment Pressure", Attachment B of this procedure, page 2 of 2, based on containment pressure.
A. KW setting __________
CAUTION Recombiner power >75 KW and temperature >1450 F may cause heater failure.
B. Slowly turn Power Adjust Potentiometer handswitch (HS-7473) clockwise to raise power to the value determined above as indicated on M55B Power (JI-1001).
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 16 of 84 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 026 9.2.5 Verify proper Hydrogen Recombiner operation by observing the following:
NOTE Hydrogen concentration reduction is the long-term, primary method of verification.
Hydrogen concentration reduction shall be used regardless of recombiner power or temperature indication as the verification of proper recombiner operation.
Hydrogen concentration stable or dropping on both of the following:
C-178 H2 Sampler H2 Concentration % H2 (QI-7457)
C-179 H2 Sampler H2 Concentration % H2 (QI-7459)
Hydrogen Recombiner maintaining power at value determined in step 9.2.4.A.
NOTE Thermocouples are non-Q and will not be reliable indicators in a post-LOCA environment.
Recombiner temperature can aid in trending recombiner operation. The following steps are provided as guidelines.
Recombiner temperature may be plotted on "Typical Recombiner Heatup Rate",
Attachment C for verifying thermocouple operation and estimating time when recombination temperature will be reached.
9.2.6 Establish validity of temperature indication by comparing T between thermocouples.
A. IF all three thermocouples fall within a 60°F band, THEN average the three temperatures.
B. IF no two thermocouples are within 60°F of each other, THEN thermocouples should be considered inaccurate.
C. IF difference of the three temperatures >60°F AND two temperatures are within 60°F, THEN average the closest two.
9.2.7 Monitor for indication that recombiner operating temperature of 1225°F has been reached.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 17 of 84 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 026 NOTE Valid thermocouples show a ramp rise in temperature with hydrogen concentration >2%, indicating recombination temperature has been reached and recombination is taking place.
9.2.8 IF hydrogen concentration is >2%,
THEN monitor for a ramp rise in temperature.
9.2.9 After four hours of full power operation, log data in "Hydrogen Recombiner M55B Data Sheet", Attachment E once per hour.
9.2.10 IF proper power setting causes average valid temperature to exceed 1450°F OR in-service Hydrogen Recombiner has insufficient capacity, THEN place standby Hydrogen Recombiner in-service.
9.2.11 Do NOT lower Hydrogen Recombiner M55B power based on extreme temperature. Maintain power until standby Hydrogen Recombiner is heated to operating temperature of ~1225 F.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 30 of 84 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 026 ATTACHMENT B Page 1 of 2 RECOMBINER POWER (M-55A)
VERSUS CONTAINMENT PRESSURE 75 70 60OF 90OF 120OF 65 60 55 50 45 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 Post-LOCA Containment Pressure (0.2 psia increments)
Note: Use pre- LOCA average Reactor Building Temperature from SPDS (TAVRB1) from history file if available. Otherwise use logs.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 31 of 84 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 026 ATTACHMENT B Page 2 of 2 RECOMBINER POWER (M-55B)
VERSUS CONTAINMENT PRESSURE 75 60O F 90O F 120OF 70 65 60 55 50 45 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 Post-LOCA Containment Pressure (0.2 psia increments)
Note: Use pre- LOCA average Reactor Building Temperature from SPDS (TAVRB1) from history file if available. Otherwise use logs.
Page 1 of 6 JOB PERFORMANCE MEASURE Unit: 1 Rev # 5 Date:
JPM ID: A1JPM-RO-RPS01 System/Duty Area: Reactor Protection System Task: Perform Placing a RPS Channel in Manual Bypass JTA# ANO1-RO-RPS-NORM-5 KA Value RO 3.6 SRO 3.6 KA
Reference:
012 A4.03 Approved For Administration To: RO X SRO X Task Location: Inside CR X Outside CR Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site Simulator Lab Testing Method: Perform Simulate Approximate Completion Time in Minutes: 10 Minutes Reference(s): 1105.001 NI and RPS Operating Procedure (Section 10.0) 1105.004 ICS (Sections 21.0 and 22.0)
Examinee's Name: Logon:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 6 JPM ID: A1JPM-RO-RPS01 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
Prior to administration, ensure the Examinee has been briefed using Appendix E of NUREG-1021.
JPM INITIAL TASK CONDITIONS:
The plant is operating at 100% power with all ICS stations in automatic. A potential problem exists in the A RPS cabinet that could lead to a channel trip.
TASK STANDARD:
The A RPS cabinet is in Manual Bypass.
TASK PERFORMANCE AIDS:
1105.001 Section 10 and RPS Manual Bypass key.
1105.004 ICS (Sections 21.0 and 22.0)
Page 3 of 6 JPM ID: A1JPM-RO-RPS01 INITIATING CUE: The CRS/SM directs you to place the A RPS channel in Manual Bypass per 1105.001, NI & RPS Operating Procedure, Section 10.0.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT
- 1. Verify no other RPS Channel (B,C,D) in Manual Looked in the RPS cabinet in the Bypass. back of the control room and verified no manual (or channel) bypass lamps are lit or verified Note: Due to the uniqueness of the design in the U1 that K08-D3 (RPS Channel simulator, all channel indications are located in one Bypass) annunciator is clear.
RPS cabinet.
POSITIVE CUE:
No manual (or channel) bypass lamps are lit or K08-D3 RPS Channel Bypass is NOT in alarm.
- 2. Verify no EFIC Channel in Maintenance Bypass that On the EFIC cabinets, verified does not correspond to the RPS Channel to be placed that no Maintenance lamps are in Manual Bypass. lit for any channel or verified that K12-F7 (EFIC CH MAINT BYPASS) annunciator clear.
POSITIVE CUE:
No Maintenance lamps lit for EFIC cabinets or K12-F7 EFIC CH MAINT BYPASS not in alarm.
INSTRUCTOR CUE: Tell the Examinee that the difference between N1I56HI and N1I78HI is >1% per positive cue below.
- 3. Compare Plant Computer point N1I56HI to N1I78HI. Using PMS, compared Plant Computer point N1I56HI to N1I78HI.
POSITIVE CUE: ____
The difference between N1I56HI and N1I78HI is >1%.
INSTRUCTOR NOTE: Examinee will need to transition to Integrated Control System procedure 1105.004 sections 21 and 22 for the next 2 steps
- 4. Select manual mode by pressing AUTO-MAN switch On panel C03, placed the on the Diamond Panel Diamond panel in manual.
C POSITIVE CUE:
Red AUTO lamp off and white MAN lamp on.
CRD travel in and out lights off.
UNIT MASTER IN TRACK (K07-A1) in alarm
Page 4 of 6 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT
- 5. Verify Reactor Demand station display selected to Reactor Demand station display POS selected to POS POSITIVE CUE: ____ ____ ____
Reactor Demand station is in POS
- 6. Depress Reactor Demand station HAND push button Reactor Demand station is in HAND POSITIVE CUE:
C Reactor Demand station output remains steady White HAND lamp on UNIT MASTER IN TRACK (K07-A1) in alarm Red AUTO lamp on
- 7. Place the SASS Neutron Flux selector switch on On panel C03, placed the SASS C03 in the Y position. Neutron Flux selector switch in the Y position.
C POSITIVE CUE:
Y position selected.
- 8. Obtain the RPS Manual Bypass key from the SM. From the key locker in the SM office or from the examiner, POSITIVE CUE: give key to examinee. obtained the RPS Manual Bypass key.
Page 5 of 6 JPM ID: A1JPM-RO-RPS01 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT
- 9. In the RPS cabinet, place the key switch for the In the RPS cabinet, inserted the appropriate channel on the selected Rx Trip module key into the key switch in the A to the bypass position. Reactor Trip module and placed C ____ ____ ____
the switch in the bypass position.
POSITIVE CUE:
Key switch in bypass position.
- 10. Verify the manual bypass lamps on the Rx Trip Verified the Manual Bypass lamp module and the indicating panel go on bright. on the Rx Trip Module went BRIGHT and the Manual Bypass lamp on the indicating panel for POSITIVE CUE: A RPS went BRIGHT.
Manual bypass lamps on bright.
- 11. Verify Auxiliary Relay lamps for Man. Bypass to Verified Auxiliary Relay lamps for EFIC and Man. Bypass to Ann. are on bright. Manual Bypass to EFIC and Manual Bypass to annunciator are on bright.
POSITIVE CUE:
Auxiliary Relay lamps on bright.
- 12. Verify the associated EFIC channel Maintenance On the EFIC cabinet, the Bypass light is flashing. Maintenance Bypass light for the A EFIC channel is verified to be flashing.
POSITIVE CUE:
Light is flashing.
- 13. Verify annunciator RPS CHANNEL BYPASSED On K08, verified the annunciator (K08-D3) is in alarm. is in alarm for RPS CHANNEL BYPASSED.
POSITIVE CUE:
K08-D3 in alarm.
END
Page 6 of 6 JPM ID: A1JPM-RO-RPS01 INITIAL CONDITIONS:
The plant is operating at 100% power with all ICS stations in automatic. A potential problem exists in the A RPS cabinet that could lead to a channel trip.
INITIATING CUE:
The CRS/SM directs you to place the A RPS channel in Manual Bypass per 1105.001, NI & RPS Operating Procedure, Section 10.0.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 14 of 37 1105.001 NI & RPS OPERATING PROCEDURE CHANGE: 025 10.0 Placing a RPS Channel in Manual Bypass NOTE Only one RPS Channel may be placed in Manual Bypass at a time.
10.1 Determine which RPS Channel is to be placed in Manual Bypass AND verify no other RPS Channel in Manual Bypass.
CAUTION Placing a RPS Channel in Manual Bypass will remove any non-corresponding EFIC Channel from Maintenance Bypass causing possible EFIC actuation.
CRITICAL STEP 10.2 Verify no EFIC Channel in Maintenance Bypass that does NOT correspond to the RPS Channel to be placed in Manual Bypass.
10.3 Place SASS Neutron Flux selector switch (HS-509) on C03 in the X or Y position as follows:
10.3.1 Compare Plant Computer point N1I56HI to N1I78HI.
A. IF Plant Computer is NOT available, THEN compare the highest of NI-5 and NI-6 to the highest of NI-7 and NI-8 on C03.
10.3.2 IF the difference between the compared values is >1%,
THEN place the following stations in manual per Transferring ICS Control Stations to HAND section of Integrated Control System (1105.004):
Diamond Panel Rx Demand H/A station 10.3.3 IF placing RPS Channel A OR B in Manual Bypass, THEN place Neutron Flux selector switch (HS-509) to the Y position.
10.3.4 IF Placing RPS Channel C OR D in Manual Bypass, THEN place Neutron Flux selector switch (HS-509) to the X position.
10.3.5 IF ICS H/A stations were placed in manual for this step, THEN stations may be returned to auto per ICS Operating Procedure (1105.004), Transferring ICS Control Stations to Auto section.
10.4 Obtain the RPS Manual Bypass key from the Shift Manager.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 15 of 37 1105.001 NI & RPS OPERATING PROCEDURE CHANGE: 025 10.5 Place key switch on the selected Rx Trip module to the bypass position (rotate key switch clockwise).
10.5.1 Check Manual Bypass lamps go on bright on the following:
Rx Trip Module Indicating Panel 10.5.2 IF the channel is tripped, THEN check the following:
Protective Subsystem Trip lamps on dim on the following:
Tripped RPS Cabinet Rx Trip module Tripped RPS Cabinet Indicating Panel Protective Subsystem lamps Remaining RPS Cabinets Rx Trip modules Remaining RPS Cabinets Indicating Panel Protective Subsystem lamps 10.5.3 Auxiliary Relay lamps on bright for the following:
Man. Bypass to EFIC Man. Bypass to Ann.
10.5.4 Associated EFIC channel Maintenance Bypass light is flashing.
10.5.5 Annunciator RPS CHANNEL BYPASSED (K08-D3) in alarm.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 50 of 73 1105.004 INTEGRATED CONTROL SYSTEM CHANGE: 026 21.0 Diamond Panel Transfer to Manual (Non-Emergency)
NOTE If at least one loop of feedwater controls is in automatic, and one SG is above low level limit control, then this section will give Tave control to the Feedwater Demand subsection.
21.1 Select manual mode by pressing AUTO-MAN switch.
Check AUTO lamp off.
Check white MAN lamp on.
Check CRD Travel In and CRD Travel Out lamps off.
Check UNIT MASTER IN TRACK (K07-A1) in alarm.
IF Reactor Demand station is in HAND, THEN check Reactor Demand station red and white lamps on (mini-track).
21.2 IF necessary to move control rods, THEN move control rods in accordance with Control Rod Withdrawal and Control Rod Insertion sections of CRD System Operating Procedure (1105.009).
21.3 WHEN desired to return Diamond Panel to AUTO, THEN perform Diamond Panel Transfer to Auto section of this procedure.
22.0 Reactor Demand Transfer to Hand (Non-Emergency)
NOTE If at least one loop of feedwater controls are in automatic, and one SG is above low level limit control, then this section will give Tave control to the Feedwater Demand subsection.
22.1 Verify Reactor Demand station display selected to POS.
22.2 Depress Reactor Demand station HAND pushbutton.
22.3 Check Reactor Demand station output remains steady.
Check Reactor Demand station white HAND lamp on.
Check UNIT MASTER IN TRACK (K07-A1) in alarm.
IF Diamond Panel is in MANUAL, THEN check Reactor Demand station red AUTO lamp on (mini-track).
22.4 WHEN desired to return Reactor Demand to AUTO, THEN perform Reactor Demand Transfer to Auto section of this procedure.
Page 1 of 5 JOB PERFORMANCE MEASURE Unit: 1 Rev # 3 Date:
JPM ID: A1JPM-RO-EOP21 System/Duty Area: Emergency and Abnormal Operations Task: Respond to Reactor Trip (Check both SG levels remain 410)
JTA# ANO1-RO-EOP-EMERG-4 and ANO1-SRO-EOP-EMERG-2 KA Value RO 3.7 SRO 3.6 KA
Reference:
035 A4.01 Approved For Administration To: RO X SRO X Task Location: Inside CR X Outside CR Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site Simulator X Lab Testing Method: Perform Simulate Approximate Completion Time in Minutes: 5 Minutes Reference(s): 1202.001 Reactor Trip, step 11 Examinee's Name: Logon:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 5 JPM ID: A1JPM-RO-EOP21 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
Prior to administration, ensure the Examinee has been briefed using Appendix E of NUREG-1021.
JPM INITIAL TASK CONDITIONS:
The reactor has been tripped. Immediate actions were properly completed. The CRS is now in the follow-up actions of the Reactor Trip EOP.
TASK STANDARD:
Examinee tripped both main feedwater pumps, CV-2667 (EFW Pump Turbine Steam Supply valve) is in MANUAL, closed, EFW actuated manually on the remote matrices on panel C09 and trips all condensate pumps if SG pressure is
<650 psig.
This is an Alternate Path JPM.
TASK PERFORMANCE AIDS:
Reactor Trip 1202.001 step 10.
SIMULATOR SETUP:
Use an at power IC with both MFPs in service.
IMF CV2625 1 (fails A MFW Block Valve 100% open).
Trip reactor.
IMF RX598 55 (fails A MFW pump speed demand to Lovejoy).
Allow A OTSG level to rise to 410 and then make snapshot for JPM performance.
Page 3 of 5 JPM ID: A1JPM-RO-EOP21 INITIATING CUE: The CRS/SM directs you to check both SG levels remain 410 per step 11 of Reactor Trip EOP 1202.001.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT
>410 by observing OTSG level ____ ____ ____
FAULTED CUE: indication on SPDS, panel C03, A OTSG is at 411 and rising rapidly. panel C09 or panel C13.
C POSITIVE CUE: ____ ____ ____
Green lights ON, red lights OFF on panel C02 for both MFPs.
- 3. Place CV-2667 in MANUAL and close CV-2667. Placed CV-2667 in MANUAL and closed CV-2667 (SG EFW Pump C POSITIVE CUE: Turbine K3 Steam Supply valve) ____ ____ ____
CV-2667 in MANUAL with its green light ON and red on panel C09.
light OFF on panel C09.
- 4. Actuate EFW. Depressed EFW (red) pushbuttons for Train A and B on C POSITIVE CUE: the remote matrices on panel C09 ____ ____ ____
EFW actuation indicated on Bus 1 and Bus 2 of both (all four red EFW pushbuttons Trains A and B on C09. depressed).
- 5. Verify proper EFW actuation and control. Obtained and commenced RT5 (Verify proper EFW actuation and POSITIVE CUE: control).
EFW pumps and valves controlling properly, OTSG levels are being properly maintained. NOTE: the intent of this JPM is complete after RT5 is NEGATIVE CUE: commenced by the Examinee (i.e.
A OTSG level at 411 and going up (if MFPs not no need to complete RT5).
tripped by Examinee). ____ ____ ____
OR P7A overspeed trip and WCO reports loud water hammer at P7A (if examinee didnt close CV-2667 and EFW actuated).
OR OTSG levels rapidly lowering (if Examinee didnt actuate EFW).
Page 4 of 5 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT
- 6. If SG press is <650 psig, THEN trip all Condensate Pumps:
- P-2A
- P-2B
- P-2C Checks status of SG pressure and if <650 psig, trips all ____ ____ ____
POSITIVE CUE: Condensate Pumps.
SG Pressure is >650 psig.
NEGATIVE CUE:
SG Pressure is <650 psig.
END
Page 5 of 5 JPM ID: A1JPM-RO-EOP21 INITIAL CONDITIONS:
The reactor has been tripped. Immediate actions were properly completed. The CRS is now in the follow-up actions of the Reactor Trip EOP.
INITIATING CUE:
The CRS/SM directs you to check both SG levels remain 410 per step 11 of Reactor Trip EOP 1202.001.
CHANGE 1202.001 REACTOR TRIP 034 PAGE 8 of 26 INSTRUCTIONS CONTINGENCY ACTIONS
- 10. Check OP HPI pump supplying normal 10. Perform the following:
Makeup and Seal Injection.
A. Isolate Letdown by closing either:
Letdown Coolers Outlet (RCS)
(CV-1221)
OR Letdown Coolers Outlets (RCS):
CV-1214 CV-1216 B. Restore normal Makeup and Seal Injection (RT-1).
- 11. Check both SG levels remain 410". 11. Perform the following:
A. Trip both Main Feed Pumps:
A Main Feed Pump B Main Feed Pump B. Place overfilled SG EFW Pump Turbine K3 Steam Supply Valve(s) in MANUAL AND close:
SG A SG B CV-2667 CV-2617 C. Actuate EFW AND verify proper actuation and control (RT-5).
D. IF SG press is 650 psig, THEN trip all Condensate pumps:
P2A P2B P2C
Page 1 of 5 JOB PERFORMANCE MEASURE Unit: 1 Rev # 3 Date:
JPM ID: A1JPM-RO-ICW01 System/Duty Area: Intermediate Cooling Water System Task: Contingency Actions for Loss of Two ICW Pumps JTA# ANO1-RO-ICW-NORM-4 KA Value RO 3.3 SRO 3.6 KA
Reference:
008 A2.01 Approved For Administration To: RO X SRO X Task Location: Inside CR X Outside CR Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site Simulator X Lab Testing Method: Perform Simulate Approximate Completion Time in Minutes: 10 Minutes Reference(s): 1104.028 Section 20.0 Examinee's Name: Logon:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 5 JPM ID: A1JPM-RO-ICW01 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
Prior to administration, ensure the Examinee has been briefed using Appendix E of NUREG-1021.
JPM INITIAL TASK CONDITIONS:
ICW Pump P-33A is OOS for bearing replacement.
ICW Pump P-33B has just tripped.
TASK STANDARD:
P-33C operating with all cross-connects open, ICW total flow < 3100 gpm and letdown re-established to ~ 60 gpm..
TASK PERFORMANCE AIDS:
1104.028 ICW System Operating Procedure, Section 20.0.
SIMULATOR SETUP:
IC with P-33B and P-33C in service per 1104.028. Breaker for P-33A is open IRF B1264 OPEN.
Adjust letdown flow to ~60 gpm.
To trip P-33B use IRF B2214 OPEN. Ensure that letdown didnt isolate on high temperature.
Place the simulator in Freeze and go to run after giving initial conditions and initiating cue.
Page 3 of 5 JPM ID: A1JPM-RO-ICW01 INITIATING CUE: The SM/CRS directs you to perform the Contingency Actions for Loss of Two ICW Pumps in procedure 1104.028 (Section 20.0) through step 20.10.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT
- 1. Place the hand switch for the tripped ICW pump in On C09, the hand switch for P-PULL-TO-LOCK. 33B is placed in the P-T-L position. ____ ____ ____
POSITIVE CUE:
P-33B Hand switch is in P-T-L.
- 2. Open the following valves: On C09, the hand switches for CV-2240 and CV-2238 are placed ICW Pump Suction Cross connect CV-2240 in the OPEN position and the ICW Pump Suction Cross connect CV-2241 RED lights are ON and the C ICW Pump Discharge Cross connect CV-2238 GREEN lights are OFF. (NOTE: ____ ____ ____
ICW Pump Discharge Cross connect CV-2239 CV-2241 and CV-2239 should already be open.)
POSITIVE CUE:
Red lights ON, green lights OFF for all four valves.
- 3. Close the following valves to isolate letdown: On C04, isolated letdown by rotating the set point knob on CV-Letdown Orifice Block Bypass (CV-1223) 1223 to zero and placed the Letdown Orifice Block (CV-1222) hand switch for CV-1222 to close. ____ ____ ____
Monitored FI-1236 and verified POSITIVE CUE: flow drops to ~0 GPM.
Letdown flow at zero.
- 4. Isolate both Letdown Coolers (E-29A and E-29B) On C04, placed HS-2216 and HS-by closing the following valve pairs from C04: 2217 in the close position to isolate both Letdown Coolers.
E-29A HS-2216 for Letdown Cooler Inlet Valve (CV-2216) and RC to Letdown Cooler E-29A (CV-1213)
C E-29B HS-2217 for Letdown Cooler Inlet ____ ____ ____
Valve (CV-2217) and RC to Letdown Cooler E-29B (CV-1215)
POSITIVE CUE:
Green lights only ON for CV-2216, CV-1213, CV-2217 and CV-1215.
CONTINUED
Page 4 of 5 JPM ID: A1JPM-RO-ICW01 NOTE to IA Operator: When called as WCO to close ICW-121A/B then close ICW-120A/B cooler inlets due to cooler outlets are not modeled on the simulator. IRF ICW120A 0 and IRF ICW120B 0
- 5. Isolate both SFP Coolers (E-27A and E-27B) by Contacted WCO to close ICW-closing the following: 121A and ICW-121B.
SFP CLR E-27A ICW Outlet (ICW-121A)
C SFP CLR E-27B ICW Outlet (ICW-121B) ____ ____ ____
POSITIVE CUE:
WCO reports ICW-121A/B are closed.
INSTRUCTOR NOTE: Inform Examinee to return E-29A Letdown Cooler to service.
- 6. Open Letdown Cooler Inlet valve CV-2216 and RC On C04, placed HS-2216 in the to Letdown Cooler E-29A CV-1213. open position to open CV-2216 C and CV-1213. ____ ____ ____
POSITIVE CUE:
Red lights ON, green lights OFF for CV-2216 and CV-1213.
- 7. Verify combined flow from Nuclear and Non-nuclear Using the ICW flow indicators on loop is <3100 GPM. C09, calculated the total flow of both nuclear and non-nuclear ____ ____ ____
POSITIVE CUE: loops to be < 3100 gpm.
Flow is <3100 gpm.
- 8. Establish letdown by opening Letdown Orifice Block On panel C04, positioned the (CV-1222). hand switch for CV-1222 to the C open position. ____ ____ ____
POSITIVE CUE:
~45 gpm letdown flow indicated on C04.
- 9. If letdown isolated on high temperature, then Letdown does not isolate for this perform Recovery of Letdown Following High simulator setup.
Letdown Temperature section of MU&P System If letdown isolated on high 1104.002. temperature, then performed Recovery of Letdown Following POSITIVE CUE: High Letdown Temperature Letdown temperature on C04 is at ~100°F. section of MU&P System 1104.002.
INSTRUCTOR NOTE: Inform Examinee to raise letdown flow to ~60 gpm.
- 10. While keeping within the capacity of one letdown On C04, rotated the set point cooler (87.5 gpm) raise letdown flow as desired with knob on CV-1223 to achieve ~60 C CV-1223. gpm letdown flow. ____ ____ ____
POSITIVE CUE:
Letdown flow is ~ 60 gpm.
END
Page 5 of 5 JPM ID: A1JPM-RO-ICW01 INITIAL CONDITIONS:
ICW Pump P-33A is OOS for bearing replacement.
ICW Pump P-33B has just tripped.
INITIATING CUE:
INITIATING CUE: The SM/CRS directs you to perform the Contingency Actions for Loss of Two ICW Pumps in procedure 1104.028 (Section 20.0) through step 20.10.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 65 of 150 1104.028 ICW SYSTEM OPERATING PROCEDURE CHANGE: 033 20.0 Contingency Actions for Loss of Two ICW Pumps CAUTION Operation of one ICW pump with the cross-connect valves open will result in pump operation at runout conditions. Pump cavitation can occur and there is elevated risk for motor breaker trip until ICW loads are reduced.
20.1 Place tripped ICW pump(s) in PULL-TO-LOCK.
20.2 Open the following valves:
P-33A/B Discharge Crossconnect (CV-2238)
P-33B/C Discharge Crossconnect (CV-2239)
P-33A/B Suction Crossconnect (CV-2240)
P-33B/C Suction Crossconnect (CV-2241) 20.3 Close the following valves to isolate letdown:
Letdown Block Orifice Bypass (CV-1223)
Letdown Orifice Block (CV-1222) 20.4 Isolate both Letdown Coolers (E-29A and E-29B) by closing the following valve pairs from C04:
E-29A HS-2216 for Letdown Cooler Inlet Valve (CV-2216) and RC to Letdown Cooler E-29A (CV-1213)
E-29B HS-2217 for Letdown Cooler Inlet Valve (CV-2217) and RC to Letdown Cooler E-29B (CV-1215) 20.5 Isolate both SFP Coolers (E-27A, E-27B) by closing the following:
SFP Clr E-27A ICW Outlet (ICW-121A)
SFP Clr E-27B ICW Outlet (ICW-121B) 20.6 Return one Letdown Cooler to service by opening one of the following valve pairs from C04:
E-29A HS-2216 for Letdown Cooler Inlet Valve (CV-2216) and RC to Letdown Cooler E-29A (CV-1213)
E-29B HS-2217 for Letdown Cooler Inlet Valve (CV-2217) and RC to Letdown Cooler E-29B (CV-1215) 20.7 Verify combined ICW flow is 3100 gpm.
20.8 Establish letdown by opening Letdown Orifice Block (CV-1222).
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 66 of 150 1104.028 ICW SYSTEM OPERATING PROCEDURE CHANGE: 033 20.9 IF letdown isolated on high temperature, THEN perform Recovery of Letdown Following High Letdown Temperature section of Makeup and Purification System (1104.002).
20.10 While keeping within the capacity of one Letdown Cooler, raise letdown flow as desired with Letdown Block Orifice Bypass (CV-1223).
20.11 Refer to TRM 3.7.6 Condition A for no ICW flow to Spent Fuel Cooling heat exchangers.
20.12 Contact System Engineering for immediate evaluation of single letdown cooler operation.
20.13 Refer to Reclosing Tripped Individual Load Supply Breakers section of Electrical System Operations (1107.001).
NOTE Industry experience has shown there is an elevated risk of RCS leakage to ICW system after letdown cooler isolation operation.
20.14 Monitor ICW system process monitors (e.g. RI-2236, RI-2237, PMS R2236, R2237).
20.15 Monitor SFP temperature at least once per hour using plant computer point T2003 AND restore spent fuel cooling as necessary to maintain SFP temperature <150°F.
20.16 Adjust Service Water Cooling Flow to ICW Coolers as necessary to maintain ICW temperatures within the desired band.
20.17 As time permits, other non-essential ICW loads may be isolated to raise ICW system pressure AND to maintain combined ICW flow 3100 gpm.
20.17.1 Refer to table 20.1 for approximate component heat loads and flows.
20.17.2 Track repositioned valves in the Equipment Status Log.
20.18 Continue to monitor temperatures of components cooled by ICW.
20.19 WHEN desired to return to 2-pump operation, THEN perform the following:
20.19.1 Verify ICW Surge Tanks T-37A/B Level (PDIS-2228, PDIS-2229) 0.5 to 2.7 psid (1 psid = 333 gallons).
20.19.2 Vent ICW Pump(s) to be started (P-33A, B and C) as necessary:
Non-Nuc ICW Pump P-33A Vent (ICW-1193)
ICW Pump P-33B Vent (ICW-1191)
Nuc ICW Pump P-33C Vent (ICW-1194)
A. Verify P-33A, B and C vent valves closed.
A1JPM-RO-EFW10 Page 1 of 5 JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date:
JPM ID: A1JPM-RO-EFW10 System/Duty Area: Emergency Feedwater System Task: Perform Actions for swapping suction from T-41B to T-41 JTA# ANO1-WCO-EFW-OFFNORM-36 KA Value RO 3.9 SRO 3.9 KA
Reference:
061 A1.04 Approved For Administration To: RO X SRO X Task Location: Inside CR Outside CR X Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: SIM Simulator: Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site X Simulator Lab Testing Method: Perform Simulate X Approximate Completion Time in Minutes: 20 Minutes Reference(s): 1203.002 Alternate Shutdown Examinee's Name: Logon:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
A1JPM-RO-EFW10 Page 2 of 5 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
Prior to administration, ensure the Examinee has been briefed using Appendix E of NUREG-1021.
JPM INITIAL TASK CONDITIONS:
The plant has been shutdown due to fire in cable the spreading room Alternate Shutdown cooldown has been in effect Emergency Feed water CST T-41B level is 2.9 feet TASK STANDARD:
Swap EFW suction to T-41. THIS AN ALTERNATE PATH JPM, success path will be manually aligning Service Water as suction for EFW pump.
TASK PERFORMANCE AIDS:
1203.002 Alternate Shutdown Cooldown step 3.6
A1JPM-RO-EFW10 Page 3 of 5 INITIATING CUE: The CRS/SM directs you to take actions for swapping of EFW pumps suction from T-41B to T-41 per section 3 of 1203.002 Alternate Shutdown Cooldown step 3.6.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT EXANMINER NOTE: This valve is in CST valve gallery which is confined space entry once candidate goes to valve gallery inform candidate CS-19 is open.
(CS-19) open. Transfer header (CS-19) open. ____ ____ ____
POSITIVE CUE:
CS-19 is open.
- 2. Unlock AND open Condensate Supply T-41 to Unlocked and attempted to open EFW Suction (CS-275). CS-275.
Should call Control Room C to make appropriate entry in CAT NEGATIVE CUE: E log (not required for SAT ____ ____ ____
CS-275 cannot be opened. performance).
EXANMINER NOTE: Control Room reports they need service water aligned as suction source per step 3.6.2
- 3. Verify SW Loop 1 and SW loop 2 pressurized Verified SW Loop 1 and SW loop 2 are pressurized. Need to call control room for SW pressure POSITIVE CUE: ____ ____ ____
SW Loop 1 and SW loop 2 pressurized both loops have 65 psig pressure
3850) AND EFW SW Loop 2 isolation (CV-3851) 1 isolation (CV-3850) AND EFW SW Loop 2 isolation (CV-3851)
POSITIVE CUE:
CV-3850 and CV-3851 are open.
- 5. Manually open P-7B suction from SW (CV-2803) Manually opened P-7B suction C
and close P-7B suction from CST (CV-2800) from SW (CV-2803) and closed P-7B suction from CST (CV-2800)
POSITIVE CUE:
CV-2803 is open and CV-2800 closed.
- 6. Verify P-7B suction pressure rises to approximately Verified P-7B suction pressure SW Loop 1 pressure. rose to approximately SW Loop 1 pressure. Need to call control ____ ____ ____
POSITIVE CUE:
room for SW pressure P-7B suction pressure is 64 psig
A1JPM-RO-EFW10 Page 4 of 5
- 7. Manually open P-7A suction from SW (CV-2806) Manually opened P-7A suction and close P-7A suction from CST (CV-2802). from SW (CV-2806) and closed P-7A suction from CST (CV-2802). ____ ____ ____
C POSITIVE CUE:
CV-2806 is open and CV-2802 closed.
- 8. Verify P-7A suction pressure rises to approximately Verified P-7A suction pressure SW Loop 2 pressure. rose to approximately SW Loop 2 pressure. Need to call control POSITIVE CUE:
room for SW pressure.
P-7A suction pressure is 64 psig
- 9. Close SW loop 2 supply to P-7A telltale vent (SW- Closed SW loop 2 supply to P-7A 1085A) and SW loop 1 supply to P-7B telltale vent telltale vent (SW-1085A) and SW (SW-1085B) loop 1 supply to P-7B telltale vent (SW-1085B)
POSITIVE CUE:
SW-1085A and SW-1085B are closed END
A1JPM-RO-EFW10 Page 5 of 5 INITIAL CONDITIONS:
The plant has been shutdown due to fire in the cable spreading room Alternate Shutdown cooldown has been in effect Emergency Feed water CST T-41B level is 2.9 feet INITIATING CUE:
The CRS/SM directs you to take actions for swapping of EFW pumps suction from T-41B to T-41 per section 3 of 1203.002 Alternate Shutdown Cooldown step 3.6.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 46 of 76 1203.002 ALTERNATE SHUTDOWN CHANGE: 023 SECTION 3 Page 5 of 9 ALTERNATE SHUTDOWN COOLDOWN 3.6 During this procedure, monitor EFW CST (T-41B) level indication.
THEN manually align EFW suction to CST (T-41) as follows:
A. Verify CST T-41 Supp to Cond Transfer Header (CS-19) open.
B. Unlock and open Condensate Supply T-41 to EFW Suction (CS-275).
C. Verify suction pressure rises.
3.6.2 IF absolutely necessary, THEN align EFW suction to Service Water as follows:
A. Verify SW Loop I and SW Loop II pressurized.
B. Manually open EFW SW Loop I Isolation (CV-3850)
AND EFW SW Loop II Isolation (CV-3851).
C. Manually open P-7B SUCT from SW (CV-2803)
AND close P-7B SUCT from CST (CV-2800).
D. Verify P-7B suction pressure rises to approximately SW Loop I pressure.
E. Manually open P-7A SUCT from SW (CV-2806)
AND close P-7A SUCT from CST (CV-2802).
F. Verify P-7A suction pressure rises to approximately SW Loop II pressure.
G. Close SW Loop II Supply to P-7A Telltale Vent (SW-1085A)
AND SW Loop I Supply to P-7B Telltale Vent (SW-1085B).
3.7 WHEN RCS pressure reaches 700 psig, THEN core flood tank outlets shall be closed as follows:
3.7.1 Verify Maintenance electricians have completed Sections 3.1 and 3.2 of Attachment 6.
3.7.2 Unlock AND close CFT Outlet valve breakers (B5661 and B5545).
Page 1 of 4 JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date:
JPM ID: A1JPM-RO- EDG13 System/Duty Area: Emergency Diesel Generator Task: DG1 Engine Start at Slow Idle JTA# ANO1-RO-EDG-NORM-12 KA Value RO 3.0 SRO 3.1 KA
Reference:
064 A1.01 Approved For Administration To: RO X SRO X Task Location: Inside CR Outside CR X Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulate Simulator: Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site Simulator Lab Testing Method: Perform Simulate Approximate Completion Time in Minutes: 10 Minutes Reference(s): 1104.036 Section 11.0 Examinee's Name: Logon:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 4 JPM ID: A1JPM-RO-EDG13 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
Prior to administration, ensure the Examinee has been briefed using Appendix E of NUREG-1021.
JPM INITIAL TASK CONDITIONS:
Pre-evolution brief completed for slow idle start of DG1 after maintenance All appropriate steps of DG1 Start from the Control Room complete up to starting the #1 EDG All EDG cylinder drain checks have been performed and they are closed Lube oil system was not drained and both AC LO soak back pumps have been running for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> TASK STANDARD:
DG1 shutdown after critical alarm by releasing governor control lever TASK PERFORMANCE AIDS:
1104.036 section 11.0 This is an alternate success path JPM SIMULATOR SETUP:
This is an In-Plant JPM (N/A for Simulator setup)
Page 3 of 4 JPM ID: A1JPM-RO-EDG13 INITIATING CUE: The CRS directs you to perform Section 11.0 (DG1 Engine Start at Slow Idle) of 1104.036 Emergency Diesel Generator Operation, starting at step 11.4.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT
- 1. Place DG1 excitation control selector 1. Placed DG1 excitation control switch on (E11) in OFF. selector switch on (E11) in OFF.
C Positive Cue: _____ _____ _____
Excitation control selector switch on (E11) is OFF
- 2. Verify DG1 governor Load Limit set 2. Placed/set DG1 governor Load at ~10. Limit at ~10.
Positive Cue:
DG1 governor Load Limit set at ~10.
- 3. Prepare to maintain 400 rpm using 3. Stationed himself/herself at fuel fuel lever as engine starts. lever to maintain 400 rpm as engine starts. _____ _____ _____
Positive Cue:
Standing by fuel lever.
INSTRUCTOR CUE: Inform Examinee that another Operator is stationed to monitor Critical Alarms locally for the duration of the slow idle run.
- 4. Place DG1 Engine Control selector 4. Placed DG1 Engine Control switch (HS-5234) on C107 in local. selector switch (HS-5234) on C107 C in local. _____ _____ _____
Positive Cue:
HS-5234 in local.
- 5. Depress DG1 Start pushbutton (HS- 5. Depressed DG1 Start pushbutton 5232) on (C107). (HS-5232) on (C107).
C _____ _____ _____
Positive Cue:
HS-5232 depressed.
- 6. Maintain ~400 rpm by initially pulling 6. Attempted to maintain ~400 rpm.
fuel rack lever towards you. Initially pulled fuel rack lever C toward himself (herself). _____ _____ _____
Positive Cue:
Lever pulled toward you and 400 rpm INSTRUCTOR CUE: Inform Examinee engine speed is dropping to 100 rpm, and you are informed of critical trouble alarm due to low lube oil pressure.
- 7. If a critical alarm occurs requiring DG 7. If a critical alarm occurs requiring shutdown then verify DG1 shutdown. DG shutdown then verify DG1 C shutdown. Examinee released Positive Cue:
lever.
DG1 shutdown (after lever released).
Negative cue:
DG1 at 100 rpm.
INSTRUCTOR NOTE: Inform Examinee JPM is complete.
END
Page 4 of 4 JPM ID: A1JPM-RO-EDG13 INITIAL CONDITIONS:
Pre-evolution brief completed for slow idle start of DG1 after maintenance All appropriate steps of DG1 Start from the Control Room complete up to starting the #1 EDG All EDG cylinder drain checks have been performed and they are closed Lube oil system was not drained and both AC LO soak back pumps have been running for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> INITIATING CUE:
The CRS directs you to perform Section 11.0 (DG1 Engine Start at Slow Idle) of 1104.036 Emergency Diesel Generator Operation, starting at step 11.4.
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 37 of 314 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 062 11.0 DG1 ENGINE START AT SLOW IDLE 11.1 Conduct pre-evolution brief including the following:
Special precautions during manual operations (include termination criteria).
Identify communication equipment to be used.
Review of notes and cautions in this section.
11.2 Verify appropriate steps of DG1 Start From Control Room section of this procedure are complete up to starting the diesel generator.
11.2.1 WHEN starting DG1 post maintenance, THEN cylinder drain check of sub-section in DG1 Start From Control Room section of this procedure should be scheduled to as close before engine start as practical.
11.3 IF portions of the lube oil system were drained for maintenance, THEN verify both AC LO soak back pumps have been operated for at least 30 minutes.
11.4 Place DG1 Excitation control selector switch on (E11) in OFF to prevent excessive field currents.
NOTE White line on dial knob points to governor Load Limit setting.
Pointer behind dial knob indicates fuel rack position.
11.5 Verify DG1 governor Load Limit set ~10.
CAUTION Manual positioning of the fuel rack lever overrides all engine protective trips except mechanical overspeed.
When facing fuel rack lever, pulling lever toward you slows diesel. If it becomes necessary to push the lever to maintain 400 RPM, a trip has occurred and the lever must be released.
11.6 Prepare to maintain ~400 RPM using fuel rack lever as engine starts.
11.7 Station an operator to monitor Critical Alarms locally for the duration of the slow idle run.
11.8 Start engine as follows:
11.8.1 Place DG1 Engine Control selector switch (HS-5234) on C107 in LOCAL.
11.8.2 Depress DG1 START pushbutton (HS-5232) on (C107).
PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE:
PAGE: 38 of 314 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 062 11.9 Maintain ~400 RPM by initially pulling fuel rack lever towards you.
11.10 IF a Critical Alarm occurs requiring DG shutdown, THEN verify DG1 shutdown.
11.11 Verify Service Water to DG1 Coolers (CV-3806) open.
11.12 WHEN ~5 minutes have elapsed, THEN raise speed to ~900 RPM by allowing fuel rack lever to SLOWLY move away from you.
11.13 IF directed by System Engineering, THEN reduce speed using DG Local Speed Control switch (HS-5235) on C107 to ~700 RPM (switch is reverse acting).
11.13.1 Coordinate with System Engineering to return DG1 speed to
~900 RPM (HS-5235).
11.14 Stop diesel using DG1 STOP pushbutton (HS-5233) on C107.
11.15 Return DG1 Excitation control selector switch to AUTO.
11.16 Return DG1 Engine Control Selector switch (HS-5234) on C107 to REMOTE.
11.17 Close Service Water to DG1 Coolers (CV-3806) from C19.
Page 1 of 5 JPM ID: A1JPM-RO-GRW01 JOB PERFORMANCE MEASURE Unit: 1 Rev # 2 Date:
JPM ID: A1JPM-RO-GRW01 System/Duty Area: Gaseous Radwaste / Radioactivity Release Task: Commence Waste Gas Decay Tank Release JA# ANO1-WCO-GZ01-NORM-11 KA Value RO 3.1 SRO 3.9 KA Reference 071 A4.26 Approved For Administration To: RO X SRO X Task Location: Inside CR: Outside CR: X Both:
Suggested Testing Environment And Method (Perform Or Simulate #):
Plant Site: Simulate Simulator: Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Simulator : Plant Site: X Lab Testing Method: Simulate: X Perform:
Approximate Completion Time In Minutes: 15 Minutes Reference(s): 1104.022, Chg. 033-01-0, Att. C Examinee's Name: Logon:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Date:
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 5 JPM ID: A1JPM-RO-GRW01 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
Prior to administration, ensure the Examinee has been briefed using Appendix E of NUREG-1021.
JPM INITIAL TASK CONDITIONS:
The Shift Chemist has returned Gaseous Release Permit 1GW-2013-002 to the Control Room for T-18A Waste Gas Decay Tank.
TASK STANDARD:
Release commenced per 1104.022, Att. C, at flow rate specified.
TASK PERFORMANCE AIDS:
1104.022, Att. C, Completed and place-kept through step 4.3.3.
Page 3 of 5 JPM ID: A1JPM-RO-GRW01 INITIATING CUE: The CRS directs you to commence T-18A release beginning with step 4.3.4 of 1104.022, Att. C.
CRITICAL ELEMENTS (c): 1, 2, 5 and 6 UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT
- 1. Open T-18A outlet valve. Operator opened T-18A outlet valve, GZ-13A.
POSITIVE CUE:
C ____ ____ ____
GZ-13A open (stem out) and verified by second operator.
EXAMINER NOTE:
IF a Hold Card is present on GZ-15, tell the examinee to ignore the Hold Card for the purpose of this JPM.
- 2. Open CV-4820 outlet isolation GZ-15. Operator opened CV-4820 outlet isolation GZ-15.
C ____ ____ ____
POSITIVE CUE:
GZ-15 is open (stem out).
TRANSITION NOTE:
The examinee should proceed to the 354 elevation.
- 3. Notify control room of intent to begin release. Operator contacted control room and informed them of intent to ____ ____ ____
POSITIVE CUE: begin release.
Control Room notified.
- 4. Record release data. Operator recorded in Att. C Release number, start time, date POSITIVE CUE: and tank being released and Data recorded and chart recorders marked. marked chart recorders with same information. Operator will ____ ____ ____
contact control room and have them mark RR-4830 (Process Radiation Monitor Effluent Recorder).
EXAMINER CUE:
Inform the examinee that annunciator K115-C5, WASTE GAS DECAY TK HDR PRESS HI is in alarm.
- 5. Hold HS-4820 in the open position Operator placed HS-4820 in OPEN position and held it.
POSITIVE CUE:
C ____ ____ ____
HS-4820 is held in the OPEN position EXAMINER CUE:
When the examinee opens CV-4820 using HIC-4820 (while holding HS-4820), inform the examinee that K115-C5, WASTE GAS DECAY TK HDR PRESS HI alarm is clear. (at this point the examinee may release HS-4820)
Page 4 of 5 JPM ID: A1JPM-RO-GRW01 UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT
- 6. Open discharge header flow control valve. Operator opened CV-4820 and established release flow rate POSITIVE CUE: listed on preliminary report.
CV-4820 (using HIC-4820 on C115) opened and data recorded. Annunciator K115-C5 is clear and HS-4820 has been released.
C ____ ____ ____
NEGATIVE CUE:
Inform the examinee that the initial flow rate is greater than the allowed flow rate on the preliminary report.
If negative cue provided then the examinee should adjust the flow controller (HIC-4820 on C115) for CV-4820 to throttle the valve closed and reduce the flow rate.
EXAMINER NOTE:
Remaining steps are continuous action steps until release is complete.
END
Page 5 of 5 JPM ID: A1JPM-RO-GRW01 INITIAL CONDITIONS:
The Shift Chemist has returned Gaseous Release Permit 1GW-2013-002 to the Control Room for T-18A Waste Gas Decay Tank.
A Pre-Job brief has been conducted and a second operator is available for verification of reach rod operated valves.
INITIATING CUE:
The CRS directs you to commence T-18A release beginning with step 4.3.4 of 1104.022, Att. C.
Appendix D Required Operator Actions Form ES-D-2 Facility: ANO-1 Scenario No.: 1 Op-Test No.: 2013-1 Examiners: ____________________________ Operators: _____________________________
Initial Conditions:
- 100% Power. - #2 EDG will not Auto-Start.
- EFIC failed and will not auto-actuate. - Provide picture of RS-4.
- C-28B IA Compressor is out of service for overhaul. - P-36C MU Pump in service.
- CV-3806 SW to #1 EDG is failed closed.
Turnover:
- Day shift - normal working day. - Need to Drain RB Sump to 40%. This is not
- C-28B IA Compressor is out of service for overhaul. the first draining of the month and sampling
- Currently in a Severe Thunderstorm Warning for the next is not required.
hour. All required actions of 1203.025, Natural Emergencies have been completed.
Event Event Event Malf. No.
No. Type* Description N-(BOP) Perform draining of the Reactor Building Sump per 1104.014 1 CV-4400 C-(SRO) with failure of CV-4400 to close.
TS (Technical Specification 3.6.3, Reactor Building Isolation Valves)
Lightning Lightning strike strike N/A DI-DG1S #1 EDG auto-start 2
K01A1 #1 EDG Auto Start alarm C-(BOP)
CV-3806 C-(SRO)
- 1 EDG shutdown TS R-(ATC) Dispatcher directs a power reduction to 700MW in the next 15 3 N/A N-(SRO) minutes, Lightning Lighting strike strike I-(ATC) 4 I-(SRO)
ED451 Loss of NNI-Y power supply 5 ED183 M-(ALL) Loss of Offsite Power/Degraded Power DG176 C-(BOP) #2 EDG will not auto start 6 C-(SRO)
DI_DG2_VR-LW CT #2 EDG voltage low (<4100V)
C-(ATC) 7 FW621 C-(SRO) EFIC fails CT TS M-(ALL)
DG173 #2 EDG will trip TS 8
N/A A901 Alternate AC Generator available CT
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 13
Appendix D Required Operator Actions Form ES-D-2 SCENARIO 1 OBJECTIVES
- 1) Evaluate individual ability to perform Draining of the Reactor Building Sump
- 2) Evaluate individual ability to recognize and respond to the false auto start of emergency diesel generator.
- 3) Evaluate individual ability to recognize and respond to the failure to open of the service water supply valve on an operating emergency diesel generator.
- 4) Evaluate individual ability to reduce plant power.
- 5) Evaluate individual ability to recognize and respond to the loss of the Y Non-Nuclear Instrumentation system.
- 6) Evaluate individual ability to recognize and respond to a loss of offsite power.
- 7) Evaluate individual ability to recognize and respond to failure of the emergency diesel generator to auto start.
- 8) Evaluate individual ability to recognize and respond to the failure of the Emergency Feedwater Initiation and Control system to automatically actuate emergency feedwater.
- 9) Evaluate individual ability to recognize and respond to the tripping of the remaining emergency diesel generator putting the plant in a blackout condition.
- 10) Evaluate individual ability to perform the energizing of a vital bus from the Alternate AC generator.
- 11) Evaluate individual ability to recognize when conditions require the entry into technical specifications conditions.
Page 2 of 13
Appendix D Required Operator Actions Form ES-D-2 SCENARIO 1 NARRATIVE The crew will assume plant responsibility at 100% power. The SRO will direct draining of the Reactor Building Sump per 1104.014. Sump Drain valve CV-4400 will fail in the open position requiring the operator to close CV-4446 to stop the draining of the Reactor Building Sump. The inoperability of CV-4400 will require entry into Technical Specification 3.6.3 Condition A C-(BOP) C-(SRO) TS A lightning strike will cause the auto start of the #1 EDG. The CRS should direct operations per 1203.012A Annunciator K01 Corrective Actions. The crew should determine it is a spurious actuation. The #1 EDG SW valve CV-3806 will not open resulting in no cooling flow to the EDG (BOP-C) (SRO-C). The crew should take the #1 EDG to lockout to prevent an automatic trip of the EDG (TS).
TS 3.8.1. Condition B The dispatcher will call and direct U1 to reduce net generator output to 700Mwe (SRO-N)
(ATC-R).
A second lightning strike will result in the loss on NNI-Y power supply (ATC-I) SRO-I). The crew should recognize the loss of NNI-Y power. The CRS should implement 1203.047 Loss of NNI Power. The power supply breakers on RS-4 bkr 9 and Y01 bkr 39 will not reset. Breakers S-1 and S-2 on the NNI-Y power supply will not be tripped.
Letdown flow and pressure indication will be lost on C04. The letdown orifice bypass valve will fail to 50% reducing letdown flow. CFT pressure instrumentation will be lost along with NaOH tank temperature. All NNI-Y inputs to PMS/PDS will be lost or fail to mid scale.
A loss of offsite power will occur due to storm related grid instabilities (SRO-M) (ATC-M)
(BOP-M). The reactor will trip automatically. The CRS will direct operations per 1202.001 Rx Trip. After the immediate actions are complete the CRS will transition to either 1202.008 Blackout or 1202.007 Degraded Power depending on when the BOP manually starts the #2 EDG.
The #2 EDG will not auto start requiring the BOP to manually start the EDG (BOP-C) (BOP-CT).
CT criteria - The BOP should start the #2 EDG before the 15 minute criteria for declaring an SAE for a station blackout. The Alternate AC (AAC) Generator initially will not come up to speed. Unit 2 operations will dispatch maintenance personnel to make repairs.
The EFIC system is failed and will not automatically actuate EFW on the Loss of Offsite Power (ATC-C) (SRO-C). The ATC should manually actuate EFW from the remote switch matrix (ATC-CT) (TS). The ATC will perform 1202.012 Repetitive Tasks RT-5 Verify proper EFW actuation and control. EFW may be manually actuated before the step in the EOP that directs verifying EFW actuated.
TS 3.3.11 Condition B CT - EFW should be manually actuated before the ERV opens in automatic.
The #2 EDG will trip putting the plant into a blackout (SRO-M) (ATC-M) (BOP-M) (TS). The CRS will direct operations per 1202.008 Blackout.
TS 3.8.1 Condition E, 3.0.3 The AAC generator will become available. The BOP should energize the A3 bus from the AAC generator (BOP-CT).
CT criteria - The AAC generator should be placed in service within 10 minutes of the AAC Generator being reported as available.
Page 3 of 13
Appendix D Required Operator Actions Form ES-D-2 The scenario can be terminated when the AAC Generator is powering a vital bus.
Simulator Instructions for Scenario 1 Recall IC 285 Manually set constant CAKLAG to 1 Turn off RB sump level lag Insert remote C28BRUN to OFF Turn off C28B IA compressor Insert override DO_C28BSLG to Off Turn off C28B green light on C19 Insert override DO_C28BSLR to Off Turn off C28B red light on C19 Insert malfunction FW621 EFIC will Auto-actuation is failed Insert malfunction CV3806 to 0 #1 EDG SW valve is failed CLOSED Insert malfunction DG176 #2 EDG fails to AUTOSTART Insert Malfunction CV4400 to 1 on Event 1 Fails RB Sump outlet valve OPEN Insert remote LIGHTNING to TRUE on event 2 delete in 5 Activate lightning strike simulation Insert override DI_DG1S to TRUE on event 2 Start #1 EDG Insert override DI_DG1SP to FALSE on event 2 Deactivate #1 EDG Stop Button Insert malfunction K01A1 to ON on event 2 Alarm #1 EDG Auto-start Command annunciator Insert remote LIGHTNING to TRUE on event 3 delete in 5 Activate lightning strike simulation Insert malfunction ED451 on event 3 Loss of NNI-Y Power Insert malfunction ED183 on event 4 Loss of Off-site Power Insert malfunction DG174 on event 5 #2 EDG Trips Insert remote A901 to CLOSED on event 6 Aligns AAC Generator to A3/A4 cross-tie Event Value/Ramp Time Malf. No. Event Description No. Time Trigger 1 1/ Perform Draining of the Reactor Building Sump 1 0 CV4400 N/A per 1104.014 with failure of CV-4400 to close.
Trigger 2 Lightning TRUE Lightning strike will cause auto-start of #1 12 DI_DG1S TRUE EDG.
DI_DG1SP FALSE 2
K01A1 ON
- 1 EDG SW valve will not open following the Initial CV3806 0 EDG auto-start. This will require the operators to shutdown #1 EDG (TS)
Dispatcher will call and direct a power 3 20 N/A N/A reduction to 700MW in the next 15 minutes.
Trigger 3 Another lightning strike will result in the loss of 4 30 Lightning TRUE the NNI-Y power supply.
ED451 N/A Trigger 4 A Loss of Off-site power will occur resulting in 5 38 N/A ED183 an automatic reactor trip.
The #2 EDG will not auto-start requiring the operators to manually start the EDG.
6 Initial DG175 N/A (BOP-CT) criteria - The BOP should start the #1 EDG before 15 minute criteria for declaring an SAE for a Station Blackout EFIC is failed and will not automatically actuate EFW. (TS) 7 Initial FW621 N/A (ATC-CT) criteria - EFW should be manually actuated before the ERV opens in automatic.
Unit 2 will report the AAC Generator is running slow. Maintenance has been dispatched.
Trigger 5 The #2 EDG will trip putting the plant into a 50 N/A DG174 Blackout. (TS)
At T=54 Unit 2 will report the AAC Generator has been repaired and is running normally with breaker 2A-901 closed.
8 The Alternate AC Generator will become available.
Trigger 6 54 CLOSED (BOP-CT) criteria - The AAC Generator A901 should be placed in service within 20 minutes of regaining the AAC Generator.
Page 4 of 13
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 1 Event
Description:
Drain RB sump to AB sump using 1104.014 step 8.1 and failure of CV-4400 to close.
Time Position Applicants Actions or Behavior T=0 BOP Conduct pre-job brief with SRO BOP Notify RP of intent to drain RB sump.
Open the following valves:
When RB sump level reaches desired level (40%), close CV 4400 by BOP placing HS-4400 in the close position.
Identify failure of CV-4400 to close and that sump level continues to lower.
BOP (Red light ON and Green Light OFF for CV-4400 and RB sump level continues to lower)
BOP Report failure of CV-4400 to the SRO.
Close CV-4446 by placing HS-4446 in the close position and verify that CV-BOP 4446 indicates closed by Red Light OFF and Green light ON and Reactor Building Sump level has stabilized.
Identify Technical Specification applicable SRO TS (3.6.3 Condition A, due to failure of one Reactor Building penetration valve inoperable. [48 hour completion time to isolate the flow path.])
EXAMINER NOTE This event is complete when CV-4446 is closed and Tech Spec action statement is entered OR As directed by the Lead Evaluator Page 5 of 13
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 2 Event
Description:
Lightning strike will cause the auto start of #1 EDG.
- 1 EDG SW valve will not open following the EDG auto start. This will require the operators to shutdown #1 EDG.
Time Position Applicants Actions or Behavior Acknowledge and report Annunciator K01A1 EDG 1 AUTO START 12 CRS COMMAND.
CRS Direct plant operation per K01A1 EDG 1 AUTO START COMMAND.
BOP Verify that DG1 auto start.
BOP Check bus A3 energized from bus A1.
BOP Check bus B5 energized.
Verify SERV WTR to DG1 CLRS (CV-3806) opens.
ANY Recognize and report CV3806 will not open.
EXAMINER NOTE If called the AO will report CV-3806 cannot be opened locally.
Direct #1 EDG be placed in lockout. (BOP may try to push stop P/B first.
CRS EDG will stop but then restart)
TS 3.8.1. Condition B EXAMINER NOTE If called U2 will report Alternate AC Generator is available.
CRS Contact work management to investigate cause of EDG start.
CRS Refer to TS 3.8.1 Condition B for operability requirements.
Verify proper MOD alignment for Service Water Pump (P-4B) and Makeup Pump (P-36B) per Makeup & Purification System Operation CRS (1104.002) AND Service Water and Auxiliary Cooling System (1104.029).
EXAMINER NOTE This event is complete when #1 EDG is in lockout OR As directed by the Lead Evaluator Page 6 of 13
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 3 Event
Description:
Dispatcher directs a power reduction to 700MWe in the next 15 minutes.
Time Position Applicants Actions or Behavior 20 CRS Direct operations per 1203.045 Rapid Plant Shutdown.
EXAMINER NOTE:
Power reduction will be to 700MW net. The ULD reads out in gross MW, therefore will have to be adjusted to ~730 MW to achieve 700 MW net Commence a plant shutdown at 0.5 to 10% per minute.
ATC Place ULD in manual Lower ULD setpoint to ~730 MWe ATC Monitor ICS and EHC subsystems for proper integrated response.
BOP ATC Refer to "Contingency Reactivity Plans.
CRS At <90%, direct Zinc Injection be secured.
ATC Stabilize power ~700 Mwe.
EXAMINERS NOTE:
This event is complete when power is stable at ~700 Mwe OR As directed by the Lead Evaluator Page 7 of 13
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 4 Event
Description:
Second lightning strike results in the loss of the NNI Y power supply.
Time Position Applicants Actions or Behavior Recognize the loss of NNI-Y power.
Recognize and report loss of letdown flow and pressure indication on 30 ANY C04.
Recognize and report CV-1223 at 50%.
CRS Direct operations per 1203.047 Loss of NNI Power.
Verify NNI X-powered instruments selected on C03, C04, and C13.
ATC (Green light on for each SASS parameter)
BOP (CRS may direct placing SASS selector switch to the X position)
ATC Check NNI Y AC power available.
EVALUATOR NOTE:
The BOP will go to back of control room to a picture of RS-4 to simulate resetting Breaker RS-4 bkr 9.
The evaluator will tell the BOP that bkr 9 will not reset.
BOP Reset AND close Normal supply breaker RS-4 bkr 9.
Dispatch an operator to reset AND close Alternate supply breaker Y01 CRS bkr 39, while continuing with this procedure.
EXAMINERS NOTE:
The AO will report that Y01 bkr 39 will not reset.
Dispatch an operator to reset NNI Y power supply using Reactor Coolant System NNI (1105.006), "Resetting NNI Power Supplies" section, while continuing with this procedure.
CRS The S-1 and S-2 switches are on the NNI power supply and will not be tripped. Time will not permit any operator actions to be accomplished by the outside control room operator.
EXAMINERS NOTE:
This event is complete when instruments are verified selected to NNI-X power and power supply breakers Y01 bkr 39 and RS-4 bkr 9 are reported as not closing OR As directed by the Lead Evaluator Page 8 of 13
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 5 Event
Description:
A Loss of Offsite Power will occur resulting in an automatic reactor trip.
Time Position Applicants Actions or Behavior 38 ANY Recognize and report a loss of offsite power.
CRS Direct operations per 1202.001 RX trip.
ATC Manually Trip Rx, Verify all rods inserted and Reactor power dropping.
BOP Manually trip Turbine, Verify Turbine throttle and governor valves closed.
ANY Check adequate SCM.
EXAMINERS NOTE:
This event is complete when the immediate actions of 1202.001 are complete OR As directed by the Lead Evaluator Page 9 of 13
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 6 & 7 Event
Description:
The #2 EDG will not auto start requiring the operators to manually start the EDG.
EFIC is failed and will not automatically actuate EFW.
Time Position Applicants Actions or Behavior LOOP ANY Recognize #2 EDG failed to auto start.
Manually start #2 EDG.
BOP (BOP-CT) CT criteria - The BOP should start the #2 EDG before the 15 minute criteria for declaring an SAE for a station blackout.
CRS Direct operations per 1202.007 Degraded Power.
CRS Records time of Degraded Power.
Verify proper operation of both EDGs (RT-21)
Verify #2 EDG supplying associated ES bus with proper voltage, BOP frequency and loading:
- 4100 to 4200V
- 59.5 to 60.5 Hz
BOP Adjust #2 EDG voltage to ~4160V.
BOP Verify 480V MCC B55 and 56 power supply is selected to B6.
BOP Close ACW Isolation (CV-3643).
BOP Close CV-3644 BOP Close CV-3811 Recognize and report Service Water Pump discharge pressure high ANY alarm.
(CRS may elect to place additional SW loads in service)
Dispatch an operator to restore EDG. (May not be performed as #1 EDG CRS is known to be OOS.)
EXAMINERS NOTE:
U2 will report ACC Generator is running slow. Maintenance has been dispatched.
CRS Request U2 start AAC Generator.
BOP Verify P36B Bus Select MOD Control selected to A4.
BOP Verify P4B Bus Select MOD Control selected to bus A4.
EVENT 6 & 7 CONTINUED Page 10 of 13
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 6 & 7 CONTINUED Event
Description:
The #2 EDG will not auto start requiring the operators to manually start the EDG.
EFIC is failed and will not automatically actuate EFW.
Time Position Applicants Actions or Behavior BOP Verify SW to DG2 CLRs open (CV-3807).
BOP Verify a Service Water pump P4A on after 15-second time delay.
Actuate MSLI for both SGs AND verify proper actuation and control of EFW and MSLI (RT 6).
ATC TS 3.3.11 Condition B (ATC-CT) CT - EFW should be manually actuated before the Electromatic Relief Valve (ERV) opens in automatic.
Operate ATM Dump CNTRL valves in HAND to minimize cycling and ATC conserve Instrument Air.
(Crew may determine ADVs not cycling and leave in auto)
ANY Check RCS press remains >1700 psig PZR level remains >30".
BOP Isolate Letdown by closing Letdown Cooler Outlet (CV-1221).
ANY Check OP and STBY HPI pumps off.
Place RCP Seals Bleedoff (Alternate Path to Quench Tank) controls in BOP CLOSE (SV-1270, 1271, 1272 and 1273).
BOP Isolate RCP Seal Bleedoff (Normal) by closing CV-1274.
IF PZR level is >55", THEN verify Proportional Control Pressurizer ATC Heaters operating in AUTO.
Place the following breakers in handswitches in PULL-TO-LOCK.
ATC A1, A2, H1, H2 BOP Condensate pumps (P2A, B and C)
ICW pumps (P33A, B and C)
ATC Verify RCP Seal INJ Block closed (CV-1206).
BOP Close RCS Makeup Block (CV-1233 or 1234).
BOP Open BWST Outlet to OP HPI pump CV-1407.
EXAMINERS NOTE:
This event is complete when CV-1407 is open OR As directed by the Lead Evaluator Page 11 of 13
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 8 Event
Description:
The #2 EDG will trip putting the plant into a blackout.
The Alternate AC Generator will become available.
Time Position Applicants Actions or Behavior Recognize and report #2 EDG tripped.
50 ANY TS 3.8.1 Condition E, 3.0.3 CRS Direct operations per 1202.008 Blackout.
CRS Record time of Blackout.
Verify proper EFW actuation and control (RT 5).
ATC (CRS may direct ATC to re-perform RT5. RT 5 was performed during the Degraded Power event.)
Dispatch an operator to restore EDG (May not be performed as #1 EDG CRS is known to be OOS.)
EXAMINERS NOTE:
U2 will report Maintenance is working on the ACC Generator CRS Request U2 start AAC Generator.
ATC Check adequate SCM is maintained.
ATC Place P7B handswitch in PULL-TO-LOCK.
BOP Check off-site power available.
Direct dispatcher to take emergency actions to restore power, including CRS system load shed if necessary.
CRS Transition to step 34 of 1202.008 Blackout.
Dispatch an operator to take manual control of EFW pump (P7A) using CRS Emergency Feedwater pump Operation (1106.006).
EXAMINEERS NOTE U2 reports AAC Generator is running normally and breaker 2A-901 is closed.
54 CRS Transition to step 3 of 1202.008 Blackout.
Direct BOP to energize A3 using ES Electrical System Operation (1107.002), Alternate AC Generator Operation" section.
CRS (BOP-CT) CT criteria - The AAC generator should be placed in service within 10 minutes of regaining the AAC Generator.
BOP Place DG1 Output Breaker (A-308) in PULL-TO-LOCK.
BOP Verify A1 to A3 Supply Breaker (A-309) open.
Event 8 Continued Page 12 of 13
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 8 CONTINUED Event
Description:
The #2 EDG will trip putting the plant into a blackout.
The Alternate AC Generator will become available.
Time Position Applicants Actions or Behavior BOP Verify A3-A4 Tie Breakers open (A-310 and A-410).
BOP Verify no bus A3 Lockout.
BOP Turn Synchronize switch on for A3-A4 Tie Breakers (A-310 and A-410).
BOP Close A3-A4 Crosstie (A-310).
BOP Turn Synchronize switch off.
Coordinate with Unit 2 to ensure 2K9 is NOT overloaded when starting BOP loads on bus A3.
If desired, Then start Service Water Pump P-4A or B per Service Water BOP and Auxiliary Cooling System (1104.029).
CRS GO TO 1202.007, "DEGRADED POWER" procedure.
EXAMINERS NOTE:
This scenario is complete when A3 is powered from the AAC Generator OR CRS transitions back to 1202.007 Degraded Power OR As directed by the Lead Evaluator Page 13 of 13
UNIT 1 SHIFT RELIEF SHEET Page 1 of 1 Computer Generated Form (ref. 1015.015)
Date: Today Shift: Days Crew: Yours Plant Power: 100% Plant Mode: 1 Days on Line: 250 Protected Train: RED Scheduled Risk: Minimal PSI= 10 Unit 1 Reactivity Control Parameters Reactivity Change last 100 gal EFPD 250 RCS Boron 568 ppm Dilution 0 ppm makeup 5 gal Acid shift:
/ no Reactivity Change conc.
Delith 0 min PZR Boron 569 ppm Dilution 2 ppm 95 gal Water expected for next shift: change:
Control Rod APSR ULD Status Auto 290.0% 30% ULD setpoint 99.90%
Position: Position:
Any unplanned power maneuvers will be using ICS in auto or manual referencing the contingency reactivity plans located in the Plant Data Book and the network.
SPECIFICATIONS IN EFFECT: (Earliest action complete`on requirements.)
None Indefinite/Conditional Post Trip Contingencies:
Close CV-6640 GS Spillover Bypass None Post Accident Contingencies None CONTROL ROOM ALARM STATUS:
None EVOLUTIONS IN PROGRESS (List continuous action steps, parameters being monitored, frequency, and individual responsible as applicable)
Severe Thinderstorm Warning in effect for the next hour. All required actions of 1203.025 have been completed.
EVOLUTIONS COMPLETED EVOLUTIONS SCHEDULED None Drain RB Sump at earliest opportunity. This is not the first drain of the month, therefore sampling is not required.
EQUIPMENT OOS FOR EOOS PROTECTED EQUIPMENT C-28B Instrument Air compressor OOS for maintenance Red train and SFP components per COPD-13 Att. K EQUIPMENT CONFIGURATION CONTROL CHANGES: (past 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />)
Configuration Control Tagging Cat E Cont. Penetration Caution Tags None None None Non None CARRYOVER ITEMS:
C-28B Instrument Air Compressor is OOS for maintenance. Instrument Air cross-tied with Unit 2. Breathing Air compressor is in AUTO.
Appendix D Scenario Outline Form ES-D-1 Facility: ANO-1 Scenario No.: 2 Op-Test No.: 2013-1 Examiners: ____________________________ Operators: _____________________________
Initial Conditions:
- 12 EFPD BOL
- Reactor Power ~2%
- Ready to place A MFW pump in service per step 17.16 of 1102.002 Plant Startup procedure.
Turnover:
- Reactor Power is ~2%
- Ready to place the A MFW pump is service and secure P-75 AFW pump.
- Commence raising power when A MFW pump is in service.
- A 3rd RO is performing activities not related to placing the MFW pump in service and raising power.
Event Event Event Malf. No.
No. Type* Description N-(BOP) Place A MFW Pump in service and secure P-75 Aux FW 1 N/A N-(SRO) pump.
N-(BOP) 2 N/A N-(SRO) Reset anticipatory trip (ARTS) for the A MFW pump.
CT R-(ATC) 3 N/A Commence power escalation to 7% power.
N-(SRO)
C-(BOP) 4 CV6604 Gland Seal regulator fails closed.
C-(SRO)
I-(ATC) 5 TR049 I-(SRO) Controlling Pressurizer level instrument fails low TS ED452 C-(ATC)
Loss of ICS power requiring Manual Reactor Trip EFW 6 C-(SRO)
Actuation.
M-(ALL)
CV2648 C-(ATC) 7 C-(SRO) Failed EFW control valves cause overcooling CV2626 TS M-(ALL) LOCA resulting in ESAS actuation and LOSM 8 RC005 CT (Trip all RCPs within 2 minutes of LOSM)
C-(BOP) 9 ES660 C-(SRO) ES Standby HPI pump fails to auto-start TS
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 14
Appendix D Scenario Outline Form ES-D-1 SCENARIO 2 OBJECTIVES
- 1. Evaluate individual ability to Place the A MFW pump in service and stop P-75 Aux Feedwater Pump per 1102.002, Plant Startup procedure.
- 3. Evaluate individual ability to raise reactor power from ~2% to ~7%.
- 4. Evaluate individual ability to recognize and respond to a failed controlling pressurizer level instrument.
- 5. Evaluate individual ability to recognize and respond to a failed gland seal regulator valve.
- 6. Evaluate individual ability to recognize and respond to a Loss of ICS power.
- 7. Evaluate individual ability to recognize and respond to failed EFW control valves resulting of overfeed of the affected steam generator.
- 9. Evaluate individual ability to recognize and respond to a Loss of Subcooling Margin requiring all RCPs to be tripped within 2 minutes.
Page 2 of 14
Appendix D Scenario Outline Form ES-D-1 SCENARIO 2 NARRATIVE The crew will be allowed to brief placing the A MFW pump in service and the following power escalation.
The crew will assume the watch with the plant at ~2% power.
The CRS will direct placing the A MFW pump in service as directed in 1102.002 Plant Startup procedure step 17.16. (1106.016, Sec. 15.0) When the A MFW pump is supplying feedwater to the steam generators, the CRS will direct that P-75 the Aux. FW pump to be secured.
The CRS will then direct that the Anticipatory Reactor Trips (ARTS) reset in RPS for the A MFW pump. Failure to perform the ARTS reset will result in a reactor trip when reactor power exceeds 7% power. (CT) ARTS must be reset prior exceeding 7% NI Power.
When ARTS is reset, the CRS will then direct that plant power will be raised to ~7% power.
As reactor power is raise, the gland seal regulator CV-6604 will fail in the closed direction resulting in lowering gland seal pressure and gland seal alarms on annunciator K05. The operator will restore gland seal pressure to normal by throttling opening the gland seal regulator bypass, CV-6606 as directed in the K05 annunciator corrective action procedure.
After gland seal pressure is restored, the controlling pressurizer level instrument will fail low causing the pressurizer level control valve to open. 1203.015, Pressurizer Systems Failure, Section 4 -- Pressurizer Level Indication Malfunction, will be entered to address the failed instrument. The alternate (valid) instrument will be selected and pressurizer level will be allowed to return to normal. TS LCO 3.3.15 will be entered due to the failed instrument. Additionally TS 3.4.1 for RCS Steady State Pressure Limits will be referenced and entered if appropriate. (TS)
A loss of ICS power will occur which will require the CRS to enter 1203.001, ICS Abnormal Ops AOP. The CRS will direct a manual reactor trip. The crew will perform the reactor trip immediate actions and then the CRS will direct that EFW be actuated.
EFW control valve CV-2648 and EFW isolation valve CV-2626 are failed open resulting of an over-feed of the B Steam Generator and an overcooling condition to exist. The Overcooling EOP will be entered and CRS will direct that the failed flow path be isolated. When it is determined that the EFW valves are failed open, the Waste Control Operator (WCO) may be dispatched to attempt to manually close CV-2626 to stop the over-feeding of EFW and thus terminate the Overcooling. The CRS may alternately direct that the affected EFW pump, P-7B (electric driven) be secured to terminate the overcooling. The remaining EFW pump, P-7A (steam driven) will remain in service to provide feedwater to both steam generators. (TS) When the Overcooling is terminated, the A & B Atmospheric Dump Valves will be operated in manual to stabilize RCS temperature as the Turbine Bypass Valves are unavailable due to the loss of ICS power.
An intermediate sized loss of coolant accident will occur causing a loss of RCS pressure and an automatic actuation of ESAS to occur. The loss of RCS pressure will also result in a loss of adequate subcooling margin and will require that all reactor coolant pumps be tripped within 2 minutes of the loss of adequate subcooling margin. (CT) Reactor Coolant Pumps must be tripped within 2 minutes of loss of Subcooling margin. (TCOA). 1202.002, The Loss of Subcooling Margin EOP will be entered and actions will be directed to attempt to regain subcooling margin (i.e. Full HPI, EFW selected to reflux boiling).
Page 3 of 14
Appendix D Scenario Outline Form ES-D-1 The ES Standby HPI pump will not auto-start when ES is actuated and must be started manually to provide full HPI flow. Full HPI flow is required for a loss of subcooling margin. (TS)
The scenario may be terminated when both HPI pumps are running with full flow to the RCS or as directed by the lead evaluator.
The scenario can be terminated when the ES HPI pump has been started and full HPI is being injected in the core.
Page 4 of 14
Appendix D Scenario Outline Form ES-D-1 Simulator Instructions for Scenario 2 Recall IC 286 Insert malfunction CV6604 to 0.05 in 10 on event 1 Fail Gland Seal regulator CV-6604 closed Insert malfunction TR049 to 0 in 60 on event 2 Fail controlling PZR level low Insert malfunction ED452 on event 3 Loss of ICS Power Insert malfunction RC005 to 0.05000 on event 4 RCS LOCA (Intermediate sized)
Insert malfunction CV2648 to 1.00000 EFW control valve (P-7B to SG-B) failed open Insert malfunction CV2626 to 1.00000 EFW isolation valve (P-7B to SG-B) failed open Insert malfunction ES660 HPI pump P-36C will not autostart Event Value/Ramp Time Malf. No. Event Description No. Time Place A MFW Pump in service and secure P-1 0 N/A N/A 75 Aux FW pump as starting at step 17.16 of 1102.002.
2 10 N/A N/A Reset ARTs for the A MFW pump. (CT) 3 15 N/A N/A Commence power escalation to ~ 7%.
Trigger 1 4 20 0.05/10sec Gland Seal Pressure regulator fails closed.
CV6604 Trigger 2 Controlling Pressurizer Level instrument fails 5 30 0/60sec TR049 low (TS)
Trigger 3 Loss of ICS power requiring manual reactor trip 6 40 N/A ED452 and initiation of EFW.
CV2648 1/ EFW from P-7B to SG-B control valves are 7 Initial CV2626 N/A failed open.(TS)
Trigger 4 Intermediate sized RCS LOCA resulting in 8 50 0.05/0 RC005 LOSM requiring trip of all RCPs. (CT) 9 Initial ES660 N/A ES Standby HPI pump will not autostart (TS)
Page 5 of 14
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 1 Event
Description:
Place A MFW Pump in service and secure P-75 Aux FW pump.
Time Position Applicants Actions or Behavior EXAMINER NOTE:
Any actions that the CRS might direct out of the startup procedure that are not in direct support of placing the A MFW pump in service and raising power, notify the CRS that those actions are being performed by a third RO.
Direct the BOP to place the A MFW pump in service per 1106.016, Section T=0 CRS 15.0.
Verifies initial conditions:
- At least 1 MFWP (P-1A) at minimum speed.
- Aux FW Pump P-75 supplying feedwater.
- 2 Condensate Pumps Running Slowly raises A MFW Pump speed until the startup valves (CV-2623 & CV-BOP 2673) start to close BOP Stops P-75 EXAMINER NOTE This event is complete when the A MFW pump is supplying feedwater and P-75 has been secured OR As directed by the Lead Evaluator Page 6 of 14
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 2 & 3 Event
Description:
Reset ARTS for the A MFW pump.
Time Position Applicants Actions or Behavior EXAMINER NOTE:
Any actions that the CRS might direct out of the startup procedure that are not in direct support of placing the A MFW pump in service and raising power, notify the CRS that those actions are being performed by a third RO.
T=10 CRS Direct the BOP to Reset ARTS per 1102.002, Attachment E.
EXAMINER NOTE:
1102.002, Attachment E requires a concurrent verifier when performing the steps in RPS for resetting ARTS. The examiner will inform the BOP that the concurrent verification will be simulated.
EXAMINER NOTE:
Channel A of RPS is the only channel of RPS that is fully simulated. Channels B, C & D controls are on panels within the A RPS cabinet. Not all indications are included on these panels.
Depresses the test switch labeled RESET on the contact buffer lower CT BOP module for the A MFW pump.
Verifies that the two red lights on the contact buffer change state (Top ON, BOP Bottom OFF).
BOP Verifies white light MFWP A TRIPPED goes dim. (On Contact Monitor)
EXAMINER NOTE:
The following two steps will be repeated for the B, C and D RPS channels. Evaluator needs to communicate that the expected response was observed from lights that are not simulated.
CT BOP Depresses the toggle labeled A MFWP TRIP RESET BOP Verifies associated white light goes dim.
Notifies the CRS that ARTS is reset for the A MFW pump and that BOP independent verification needs to be performed.
CRS Directs the ATC to perform independent verification for the ARTS reset.
Provides turnover to the BOP and performs independent verifications of the ATC ARTS reset.
Event 2 & 3 Continued Page 7 of 14
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 2 & 3 CONTINUED Event
Description:
Reset ARTS for the A MFW pump.
Time Position Applicants Actions or Behavior Notifies the CRS that independent verification of ARTS reset for the A ATC MFW pump is complete.
Directs the ATC or BOP to adjust A MFW pump speed to maintain CRS discharge pressure between 1025 and 1075 psig.
ATC/ Adjusts A MFW pump speed to achieve a discharge pressure between BOP 1025 and 1075 psig.
T=15 CRS Directs the ATC to begin raising power to ~7% using control rods.
EXAMINER NOTE This event is complete when ARTS has been reset and Rx power is > 5%.
OR As directed by the Lead Evaluator Page 8 of 14
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 4 Event
Description:
Gland Seal Pressure regulator fails closed.
Time Position Applicants Actions or Behavior Announces GS Pressure Lo alarms on #3, #4, #5 & #6 bearings. (K05-B4, T=20 ATC C4, D4 & E4)
ALL Determine that Gland Seal Steam Header Pressure is low (<75psig).
ATC Observes and reports that condenser vacuum is slowly lowering.
CRS Directs the BOP to use the ACA for K05 to address the Gland Seal alarms.
Using ACA 1203.012D, slowly opens the Gland Sealing Steam Main BOP Regulator Bypass (CV-6606) on C12 to restore Gland Seal Header Pressure.
ATC Reports that all Gland Seal Low Pressure alarms are clear.
EXAMINER NOTE This event is complete Gland Seal Header Pressure has been restored and Condenser Vacuum is recovering OR As directed by the Lead Evaluator Page 9 of 14
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 5 Event
Description:
Controlling Pressurizer level instrument fails low Time Position Applicants Actions or Behavior T=30 ATC Announces Pressurizer Level Lo alarm (K09-C3).
ATC/
Determines that LRS-1001 is failing low.
BOP CRS Enters 1203.015, Pressurizer Systems Failure AOP.
CRS Directs the ATC to select LT-1002 for control.
ATC Selects LT-1002 for control.
Reports Pressurizer Level Lo alarm is clear and that CV-1235 makeup valve ATC is positioning to restore pressurizer level.
Declares LT-1001 Pressurizer Level instrument inoperable per TS 3.3.15 CRS and enters 30 day required action.
CRS Directs the ATC to verify that proportional heater control is in automatic.
Places the proportional heater control station on C04 in AUTO if not in ATC AUTO.
Refers to the COLR per TS 3.4.1 to determine if steady state RCS pressure CRS limits have been exceeded.
EXAMINER NOTE This event is complete when LT-1002 has been selected for control and required TS have been applied, OR As directed by the Lead Evaluator Page 10 of 14
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 6 & 7 Event
Description:
Loss of ICS power requiring manual reactor trip and initiation of EFW.
EFW from P-7B to SG-B control valves are failed open.
Time Position Applicants Actions or Behavior T=40 ATC Announces ICS/AUX SYS POWER SUPPLY TROUBLE alarm, (K07-A4)
Observes ICS Power supply status lights on C13 and light indications on ALL ICS stations and determines there is a loss of all ICS power.
EXAMINER NOTE:
The CRS may direct the ATC to trip the reactor prior to entering the ICS Abnormal Operation procedure. This is allowed per the note at the front of the procedure.
Enters 1203.001, Section 11, Loss of Either ICS DC Power or Both ICS DC CRS and AC Power.
Directs the ATC to trip the reactor and perform immediate actions of CRS 1202.001 Reactor Trip EOP.
Pushes the Rx Trip push button and verifies all control rods are inserted and ATC reactor power is dropping.
EXAMINER NOTE:
The Turbine is already tripped as part of this scenario.
Pushes the Turbine Trip push button and verifies all throttle and governor BOP valves are closed.
ATC/
Verifies adequate Subcooling margin.
BOP CRS Directs the ATC/BOP to trip the A MFW pump.
ATC/
Trips the A MFW pump at C02.
BOP CRS Directs the ATC to actuate EFW and perform RT-5 ATC Manually actuates EFW on C09 and commences RT-5 Directs the ATC to open both ATM DUMP isolation valves (CV-2676 and CRS CV-2619) on C09.
ATC Opens both ATM DUMP isolation valves.
Event 6 & 7 Continued Page 11 of 14
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 6 & 7 CONTINUED Event
Description:
Loss of ICS power requiring manual reactor trip and initiation of EFW.
EFW from P-7B to SG-B control valves are failed open.
Time Position Applicants Actions or Behavior EXAMINER NOTE:
Due to EFW feeding, SG pressures may be <1000 psig with the ATM DUMP valves closed.
Directs ATC to verify that the ATM DUMP control system is operating to CRS maintain SG pressures 1000-1040 psig.
ATC Reports current SG pressures.
EXAMINER NOTE:
Breaker panel, RS-3 does not actually exist in the simulator. There is a picture of the panel in the back of the simulator in the approximate location of the panel in the plant. The examiner will notify the BOP that breaker 4 on RS-3 is tripped.
CRS Directs BOP to determine status of RS-3, Breaker 4 The BOP will determine the status of RS-3, Breaker 4 and report to the CRS BOP that the breaker is tripped open.
CRS Notifies the AO to determine the status Y02 Breaker 34.
EXAMINER NOTE:
Approximately 2 minutes after the AO is directed to determine the status of Y02, Breaker 34, report to the control room that Y02, Breaker 34 is tripped open.
Reports that CV-2648, EFW flow control valve is failed open causing rising ATC B SG level and cooldown of the RCS Directs the ATC to isolate the failed EFW flowpath by closing CV-2626 EFW CRS isolation valve.
Attempts to close CV-2626 and determines that the valve is failed and will ATC not close.
Event 6 & 7 Continued Page 12 of 14
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 6 & 7 CONTINUED Event
Description:
Loss of ICS power requiring manual reactor trip and initiation of EFW.
EFW from P-7B to SG-B control valves are failed open.
EXAMINER NOTE:
The Overcooling EOP will not be entered until SG pressure reaches 900 psig or SG level approaches 410. Direction in RT-5 will be utilized to control/isolate EFW as required.
EXAMINER NOTE:
If the WCO is directed to close CV-2626 locally, wait approximately 2 minutes and then close CV-2626 over a 60 second period. Notify the control room when CV-2626 has been closed.
Directs the ATC to stop P-7B EFW pump by placing it in Pull-to-Lock OR CRS directs the WCO to manually close CV-2626 locally.
If directed, places P-7B in Pull-to-Lock and verifies that the overfeed is ATC terminated.
EXAMINER NOTE This event is complete when the EFW overfeed has been terminated OR As directed by the Lead Evaluator Page 13 of 14
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 8 & 9 Event
Description:
Intermediate sized RCS LOCA resulting in LOSM requiring trip of all RCPs.
ES Standby HPI pump will not autostart.
Time Position Applicants Actions or Behavior T=50 ATC Announces RCS pressure and pressurizer level lowering.
ATC Announces actuation of ESAS channels 1 through 4.
ALL Announce Loss of Subcooling Margin (LOSM).
CT BOP Trips all RCPs within 2 minutes of LOSM.
EXAMINER NOTE:
The CRS may enter the ESAS EOP initially but will be directed back to the LOSM EOP from the ESAS EOP.
CRS Enters the LOSM EOP ATC Selects Reflux Boiling setpoint for EFW on C09. (per RT-5)
CRS Directs the BOP to perform Verification of ESAS actuation using RT-10.
BOP Commences performance of RT-10.
BOP Recognizes failure of the ES HPI pump to start and reports it to the CRS.
EXAMINER NOTE:
The CRS may send an AO to check for any problems at the HPI pump breaker. If directed, wait approximately 2 minutes and report there are no drop flags and nothing abnormal at the HPI Pump breaker.
CRS Directs the BOP to start the ES HPI pump.
BOP Starts the ES HPI pump by placing the handswitch in START.
EXAMINER NOTE This event is complete when the ES HPI pump is running with full HPI being injected into the core OR As directed by the Lead Evaluator Page 14 of 14
UNIT 1 SHIFT RELIEF SHEET Page 1 of 1 Computer Generated Form (ref. 1015.015)
Date: Today Shift: Days Crew: Yours Plant Power: 2% Plant Mode: 2 Days on Line: 0 Protected Train: Green Scheduled Risk: Minimal PSI= 10 Unit 1 Reactivity Control Parameters Reactivity Change last 100 gal EFPD 12 RCS Boron 568 ppm Dilution 0 ppm makeup 5 gal Acid shift:
/ no Reactivity Change conc.
Delith 0 min PZR Boron 569 ppm Dilution 2 ppm 95 gal Water expected for next shift: change:
Control Rod APSR ULD Status Manual 286.0% 30% ULD setpoint 99.90%
Position: Position:
Any unplanned power maneuvers will be using ICS in auto or manual referencing the contingency reactivity plans located in the Plant Data Book and the network.
SPECIFICATIONS IN EFFECT: (Earliest action complete`on requirements.)
None Indefinite/Conditional Post Trip Contingencies:
None None Post Accident Contingencies None CONTROL ROOM ALARM STATUS:
None EVOLUTIONS IN PROGRESS (List continuous action steps, parameters being monitored, frequency, and individual responsible as applicable)
Power at 2% after reactor startup. A MFW pump is at minimum speed and is ready to be placed in service. Proceed raising power per Startup Prcedure when the MFW pump is in service. Currently at step 17.16 of 1102.002.
EVOLUTIONS COMPLETED EVOLUTIONS SCHEDULED Reactor Startup Perform the following per 1102.002 Place A MFW Pump is service and secure P-75.
Commence power escalation.
Place the Main Turbine on line.
Place B MFW Pump in service.
EQUIPMENT OOS FOR EOOS PROTECTED EQUIPMENT None Green train and SFP components per COPD-13 Att. K EQUIPMENT CONFIGURATION CONTROL CHANGES: (past 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />)
Configuration Control Tagging Cat E Cont. Penetration Caution Tags None None None Non None CARRYOVER ITEMS:
None
Appendix D Scenario Outline Form ES-D-1 Facility: ANO-1 Scenario No.: 3 Op-Test No.: 2013-1 Examiners: ____________________________ Operators: _____________________________
Initial Conditions:
- 100% Power.
- P-4A Service Water Pump out of service for motor replacement.
- RPS is failed.
- Rx Trip pushbutton on C03 is failed
- A CFT Low Pressure Alarm K10-A5 in due to low pressure on A CFT Turnover:
- P-4A Service Water Pump out of service for motor replacement.
- Add N2 to A CFT to ~585# per 1104.001 per step 11.0.
Event Event Event Malf. No.
No. Type* Description N-(BOP) 1 N/A Add N2 to A CFT to raise pressure to ~585#
N-(SRO)
FW086 N/A P-8A heater drain pump winding failure and trip 2&3 R-(ATC)
N/A Power Reduction N-(SRO)
I-(ATC) 4 TR580 I-(BOP) Controlling Header Pressure fails low I-(SRO)
CO_P14B Operating EH pump trips 5 CO_P14A C-(BOP)
Turbine trip >43%
DI_ICC0020 C-(ATC)
RP246,7,8,9 RPS is failed C-(SRO)
TS 6 DI_ICC0020 C-(ATC) C03 manual trip pushbutton failed TS M-(ALL) Manual Reactor Trip CT M-(ALL)
RC002 TS ~150 GPM tube leak in the B SG 7&8 CT N/A N-(ATC) Plant cooldown and depressuization 9 CV061 C-(ALL) Operating HPI Pump trips
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 15
Appendix D Scenario Outline Form ES-D-1 SCENARIO 3 OBJECTIVES
- 1) Evaluate individual ability to per 1104.001 step 11.0 for adding N2 to the CFT.
- 2) Evaluate individual ability to recognize and respond to a heater drain pump trip.
- 3) Evaluate individual ability to perform a rapid plant power reduction.
- 4) Evaluate individual ability to recognize and respond to a turbine header pressure instrument failing low.
- 5) Evaluate individual ability to recognize and respond to the loss of the operating EH oil pump and resultant turbine trip.
- 6) Evaluate individual ability to recognize and respond to a reactor protection system failure to complete an automatic trip.
- 7) Evaluate individual ability to recognize and respond to a steam generator tube leak.
- 8) Evaluate individual ability to commence a reactor coolant system cool down and depressurization.
- 9) Evaluate individual ability to recognize and respond to the operating HPI pump trip Page 2 of 15
Appendix D Scenario Outline Form ES-D-1 SCENARIO 3 NARRATIVE The crew will be allowed to brief adding N2 to the A CFT prior to entering the control room.
The crew will assume the watch with the plant at 100% power. P-4A SW pump is out of service for overhaul.
The CRS will direct adding N2 to the A CFT as soon as they have responsibility for the plant.
The CBO will perform 1104.001 Core Flood System Operating Procedure to raise CFT pressure
~10 psig.
P8A heater drain pump will experience a winding failure causing a high temperature alarm and P8A trip (SRO-C) (BOP-C). The CRS should reference 1203.012E Annunciator Corrective Action P8A/P8B FLOW LO and CONDENSATE PUMP AUTOSTART.
A plant power reduction is required to maintain MFW pump suction pressure and limit HD tank level. The CRS should direct the power reduction per 1203.045 Rapid Plant Shutdown (ATC-R)
(SRO-N).
The controlling Turbine Header Pressure instrument will fail low. (SRO-C) (ATC-C) (BOP-C)
This will result in the turbine lowering demand to raise header pressure. The reactor and feedwater will rise as a result of the header pressure error. A SASS mismatch alarm will be received. The CRS will direct operations per 1203.012F Annunciator Corrective actions for SASS mismatch alarm and 1203.001 ICS Abnormal Operation. The crew should verify the turbine in manual control SG/RX master and both turbine bypass valves in manual. Once the plant is stable the crew will verify the alternate instrument is good and select the good instrument on C04.
The crew should return ICS to automatic.
After the power reduction the operating EH oil pump will trip. The standby pump will not start (BOP-C). The loss of both EH pumps will result in a spurious turbine trip. (Crew may complete a manual RX trip prior to the turbine trip) The reactor will fail to trip do to a failure of RPS (ATC-C)
(TS). The manual RX trip pushbutton is failed (ATC-C). The ATC should manually trip the reactor using the CRD supply breakers (ATC-CT) (ATC-M) (BOP-M) (SRO-M).
TS 3.3.1 Condition C TS 3.3.2 Condition A CT criteria - The reactor should be manually tripped before the pressurizer goes solid.
A ~150gpm tube leak will occur in the B SG (ATC-M) (BOP-M) (SRO-M) (TS). The CRS should direct operation per 1202.006 Tube Rupture. The leak will be large enough to require HPI be initiated (BOP-CT). An RCS depressurization and cooldown should be started (ATC-N).
TS 3.4.13 Condition B CT criteria - HPI should be initiated before SCM is lost.
The Operating HPI pump breaker trips due to a motor fault. (SRO-C) (ATC-C) (BOP-C) The CRS should direct operations per 1203.026 Loss of Reactor Coolant Makeup section 1 Loss of HPI Pump. The crew should diagnose the pump trip as a breaker fault and start the standby HPI pump. HPI should be restarted using the standby pump or raised using the ES pump. (BOP-CT)
(TS) (BOP-CT) TS 3.5.2 Condition A CT criteria - HPI should be started or raised on the ES pump before SCM is lost.
The scenario may be terminated when HPI has been restarted or at the direction of the lead evaluator.
Page 3 of 15
Appendix D Scenario Outline Form ES-D-1 Simulator Instructions for Scenario 3 Recall IC 287 Insert remote N2_3 to 0.08000 on event 1 Open A CFT supply valve Insert malfunction FW086 on event 2 A HD pump winding heats up and then trips Insert malfunction TR580 to 600.00000 in 500 on event 3 Controlling Steam Header pressure fails low Insert remote CO_P14A to OFF on event 4 A EH Oil pump trips Insert remote CO_P14B to OFF on event 4 B EH Oil pump trips Insert override DI_PB9201 to TRUE on event 5 Trip the Main Turbine Insert malfunction RP246 A RPS channel will not trip Insert malfunction RP247 B RPS channel will not trip Insert malfunction RP248 C RPS channel will not trip Insert malfunction RP249 D RPS channel will not trip Insert override DI_ICC0020 to FALSE Manual reactor trip push button is failed Insert malfunction RC002 to 0.20000 on event 6 ~ 150 GPM tube leak on B SG Insert malfunction CV061 on event 7 A HPI trips on motor fault Event Value/Ramp Time Malf. No. Event Description No. Time Trigger 1 1 0 0.08/0 Add N2 to A CFT per 1104.001 N2_3 P-8A heater drain pump will experience a Trigger 2 winding failure causing it o heat up and 2&3 10 N/A FW086 eventually trip requiring a power reduction to ~
70%
Trigger 3 Controlling turbine header pressure transmitter 4 20 600/120 TR580 fails low over 300 seconds Trigger 4 The operating EH pump will trip and the 35 CO_014A OFF standby pump will not start causing a loss of CO_P14B OFF EH Oil pressure.
Trigger 5 Main Turbine trip > 435 power. (Crew my complete 35.5 TRUE DI_PB9201 a manual RX trip prior to the turbine trip) 5&6 RPS is failed and will not cause a automatic reactor trip. (TS) The manual trip pushbutton is failed requiring the operators to manually trip RP246,7,8,9 N/A Initial the reactor using the backup pushbuttons. (TS)
DI_ICC0020 FALSE (ATC-CT) Criteria - The reactor should be manually tripped before the pressurizer goes solid.
A ~150 GPM SG tube leak will develop in the Trigger 6 B SG requiring initiation of HPI. (TS) (BOP-45 0.2 RC002 CT) Criteria - HPI should be initiated before 7&8 subcooling margin is lost.
A plant cooldown is required to allow for N/A N/A N/A isolation of the B SG.
Operating HPI pump breaker trips due to motor fault. (TS) (BOP-CT) Criteria - Standy HPI 9 55 CV061 N/A pump should be started or raised on ES pump before subcooling margin is lost.
Page 4 of 15
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 1 Event
Description:
Add N2 to A CFT per 1104.001 Time Position Applicants Actions or Behavior Verify both Core Flood Tanks (T-2A and T-2B) are filled and borated as 0 CBOT required for operation.
CBOT Check CFTs at or below normal operating pressure Verify Core flood system aligned per System Alignment Verification ANY section of 1015.001, Conduct of Operations.
Verify High Pressure Nitrogen aligned per Exhibit A "Nitrogen Manifold ANY Preparations" of 1104.009.
EXAMINER NOTE When directed wait 30 seconds and report, High Pressure Nitrogen is aligned per Exhibit A "Nitrogen Manifold Preparations" of 1104.009.
CBOT Direct AO to open High Pressure Nitrogen Supply Header Isol (N2-2).
EXAMINER NOTE AO will report N2-2 is open Station a dedicated individual at N2-3 (or low-dose area 354' elev U1 Aux ANY Bldg) with direct communication with the Control Room, to remain in area while N2-3 is open.
CRS Make required station log entry for TS entry. TS 3.6.3 (note 1)
Direct WCO to unlock AND open High Pressure Nitrogen Supply to CFT CBOT T-2A (N2-3). Trigger 1 WHEN T-2A is between 580 and 620 psig, THEN direct the WCO to CBOT close AND lock N2-3. Secure dedicated individual.
CBOT Direct AO to Close N2-2.
ANY Direct performance of independent verification.
Direct AO to secure High Pressure Nitrogen per Exhibit A "Nitrogen CBOT Manifold Operations" of 1104.009.
EXAMINER NOTE This event is complete A CFT pressure is raised and procedure is complete OR As directed by the Lead Evaluator Page 5 of 15
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 2 & 3 Event
Description:
P8A heater drain pump will experience a winding failure causing it to heat up and eventually trip.
A power reduction is required to get within the capacity of the HD tank High Level Dump system and to raise MFW pump suction pressure.
Time Position Applicants Actions or Behavior Recognize and report P8A winding temperature is going up. (Crew may 10 ANY elect to stop P8A prior to the pump tripping.)
CRS Direct operations per 1203.012E Annunciator K06 Corrective action.
CRS Initiate steps to determine cause of high temperature alarm EXAMINEERS NOTE If asked the AO will report nothing abnormal at P8A.
Commence reducing power at ~ 10%/minute per Rapid Plant Shutdown (1203.045) to within the capacity of T-40 high level dump (~ 630 MW or ATC
~70% power) and secure affected pump. (The pump may trip before a power reduction can be started.)
Direct the AO to perform local exhibit to verify proper T-40A tank level BOP control. (Exhibit A)
EXAMINEERS NOTE AO will report that exhibit A is complete and T-40A High Level Dump control valve controlling level properly.
ATC, Monitor ICS and EHC subsystems for proper integrated response.
BOP As time permits instruct ATC to refer to "Contingency Reactivity Plans" CRS AND Exhibit A (Operation of APSR Group) of Power Operation (1102.004)
CRS Direct securing Zinc Injection.
Contact AO to verify Htr Drn Tk T-40A Hi Lvl Dump Isol (CV-3041A) is ANY open at breaker (B-3252).
EXAMINERS NOTE:
When asked report as AO that P8A is not rotating.
ANY Direct AO to check the tripped Heater Drain Pump for reverse rotation.
ATC, Place Low Level Condenser Spray CV-2907 AND CV-2868 in service by BOP placing HS-2907 on C02 in OPEN.
EVALUATOR NOTE This event is complete when plant power is stabilized at ~70%
OR As directed by the Lead Evaluator Page 6 of 15
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 4 Event
Description:
Controlling Header Pressure Instrument Fails Low Time Position Applicants Actions or Behavior 20 ANY Recognize and report turbine header pressure instrument failing low.
CRS Direct operations per 1203.001 ICS Abnormal Operation BOP Verify Turbine in OPER AUTO or TURB MAN control.
If Turbine in OPER AUTO then perform the following to raise header pressure While monitoring SG pressure, raise SETTER as necessary BOP to raise turbine load to stabilize RCS Pressure.
Depress GO pushbutton AND release.
Verify REFERENCE matches SETTER.
If Turbine in TURB MAN then perform the following to raise header pressure.
BOP While monitoring SG pressure operate GV Raise pushbuttons as necessary on C01 ATC Verify SG/RX Demand H/A station in HAND ATC Place BOTH TURB BYP Valve H/A stations in HAND ANY Select the good Turbine Header Pressure instrument for indication.
Adjust SG/RX Demand H/A station as necessary to stabilize power <
ATC 100%.
Direct returning ICS to automatic per 1105.004 Integrated Control CRS System Verify Rod Controller (Diamond Panel) in Manual, if applicable
- Reactor Demand in HAND
- FW Demand Loop B in HAND
- Load Ratio T-cold in HAND
- SG/RX Demand in HAND
- ULD Unit Master Station in HAND Verify Turbine in INTEG CONTROL, controlling Turbine Header pressure ATC at setpoint.
Place Turbine in integrated control as follows:
Verify main steam header pressure is at the setpoint selected on Header Pressure Controlling substation.
Monitor Governor Valve demand and the following PMS/PDS BOP points for stable conditions When turbine header pressure is at setpoint (+/-5 PSI) AND stable (rate of change <10 PSI/minute), Then place turbine in INTEG CONTROL.
Verify turbine control is steady EVENT 4 CONTINUED Page 7 of 15
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 4 CONTINUED Event
Description:
Controlling Header Pressure Instrument Fails Low Time Position Applicants Actions or Behavior ATC Check MEAS VAR on both FW Loop Demand stations on the caret.
ATC Check T-ave is at setpoint.
ATC Check Reactor Demand MEAS VAR on the caret.
Check SG/RX H/A station that POS and MEAS VAR are approximately ATC equal With the above stations aligned, place them in AUTO in the following sequence:
A. Rod Controller (Diamond Panel), if applicable.
B. Reactor Demand ATC C. Feedwater Loop Demands:
- Loop A FW Loop Demand
- Loop B FW Loop Demand D. Load Ratio T-cold E. SG/RX Demand EVALUATOR NOTE This event is complete when the ICS is in automatic OR As directed by the Lead Evaluator Page 8 of 15
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 5 & 6 Event
Description:
The operating EH pump breaker will trip causing a loss of EH fluid and a main turbine trip >43% power.
RPS is failed and will not cause an automatic trip. (TS) The operators are required the manually trip the reactor.
Time Position Applicants Actions or Behavior 35 ANY Recognize and report P14A tripped and P14B failed to start.
Dispatch operator to reset P-14A breaker (B-3225). (Crew may not have CRS time to dispatch this operator before the turbine trips)
ANY Recognize turbine valves closing ANY Recognize turbine tripped >43% power.
Recognize RPS failed to automatically trip the reactor.
ANY TS 3.3.1 Condition C Recognize manual reactor trip push button is failed ATC TS 3.3.2 Condition A Trip the reactor using the shunt trip push buttons.
ATC CT criteria - The reactor should be manually tripped before the pressurizer goes solid.
CRS Direct operations per 1202.001 Reactor Trip Depress Reactor Trip PB, Verify all rods inserted and Reactor power ATC dropping.
Depress Turbine trip PB, Verify Turbine throttle and governor valves BOP closed ANY Check adequate SCM ATC Verify Orifice Bypass (CV-1223) demand adjusted to zero.
BOP Open BWST Outlet to OP HPI pump CV-1407 EVENT 5 & 6 CONTINUED Page 9 of 15
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 5 & 6 Continued Event
Description:
The operating EH pump breaker will trip causing a loss of EH fluid and a main turbine trip >43% power.
RPS is failed and will not cause an automatic trip. Manual trip P/B is failed requiring the operators to manually trip the reactor using the shunt trip P/B.
Time Position Applicants Actions or Behavior ATC Adjust Pressurizer Level Control setpoint to 100" ATC Control RCS press within limits of Figure 3 (RT-14).
BOP Check for proper electrical response (RT-19)
ANY Check OP HPI pump supplying normal Makeup and Seal Injection.
ATC Check both SG levels remain <410".
ANY Check Instrument Air Header press >75 psi.
ATC Check NNI and ICS power available (RT-20)
ATC Check MSSV OPEN alarm clear (K07-C5).
ATC Check Turb BYP valves operate to maintain SG press 950 to 1020 psig.
ATC Place both Feedwater Demands in HAND AND verify demand at zero.
ATC Check Main Block valves closed (CV-2625 and 2675)
ATC Check Low Load Block valves closed (CV-2624 and 2674).
ATC Check Startup valves maintain SG levels 20 to 40".
Verify MFW pumps run back and then operate to maintain >70 psid ATC across Startup Valves.
BOP Check Two Service Water pumps (P4B, & C).
EVENT 5 & 6 CONTINUED Page 10 of 15
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 5 & 6 Continued Event
Description:
The operating EH pump breaker will trip causing a loss of EH fluid and a main turbine trip >43% power.
RPS is failed and will not cause an automatic trip. Manual trip P/B is failed requiring the operators to manually trip the reactor using the shunt trip P/B.
Time Position Applicants Actions or Behavior ANY Check ICW pump supplying Nuclear loop (P33C or B).
ANY Check ICW pump supplying Non-nuclear loop (P33A or B).
BOP Check RB Cooling Fans (VSF1A, B, C, D, and E)
BOP Check Previously running Main Chiller(s) (VCH1A, B)
ANY Check ESAS Actuation alarms clear on K11.
ANY Check RCS press > 1700 psig.
Check Pressurizer Level Control valve (CV-1235) maintains PZR level >
ATC 55" ATC Verify Proportional Control Pressurizer Heaters in AUTO.
BOP Check PZR steam space integrity.
Verify ERV, Pressurizer Spray, and Pressurizer Heaters operate to ATC control RCS press 2050 to 2250 psig.
ANY Check at least one RCP running.
ANY Check adequate SCM.
ATC Check RCS T-cold remains >540°F.
ATC Check RCS temp remains < 580°F T-hot with any RCP on.
BOP Check SG tube integrity (RT-18)
EVALUATOR NOTE This event is complete when the operators recognize the SG tube leak OR As directed by the Lead Evaluator Page 11 of 15
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 7 & 8 Event
Description:
A ~150 GPM tube leak will develop in the B SG requiring initiation of HPI.
Time Position Applicants Actions or Behavior Recognize SG tube leak on the B SG 45 ANY TS 3.4.13 Condition B CRS Transition to 1202.006 Tube Rupture CRS Direct operations per 1202.006 Tube Rupture starting at step 11.
Manually Trip Rx, Verify all rods inserted and Reactor power dropping.
ATC (This step already performed by the Rx Trip EOP.)
Manually trip Turbine, Verify Turbine throttle and governor valves closed BOP (This step already performed by the Rx Trip EOP.)
ANY Check adequate SCM ATC Verify Header Pressure Controlling setpoint adjusted to 45.
ATC Check TURB BYP valves controlling SG press 950 to 990 psig.
Advise Shift Manager to Notify Nuclear Chemistry to begin CRS off-site dose projections and Implement Emergency Action Level Classification (1903.010).
ATC Verify Orifice Bypass (CV-1223) closed.
Open BWST Outlet to OP HPI pump CV-1407 to the operating HPI BOP pump.
BOP Check Main Generator and Exciter Field breakers open.
Operate Pressurizer Heaters AND Pressurizer Spray valve (CV-1008) to ATC maintain RCS press low within limits of Figure 3. (RT-14)
ATC, WHEN RCS press is <1700 psig, THEN bypass ESAS.
BOP ATC Adjust Pressurizer Level Control setpoint to 100.
BOP Verify OTSG N-16 monitors selected to Gross.
ANY Recognize Lowering PZR level Initiate RT2 HPI BOP CT criteria - HPI should be initiated before SCM is lost.
EVENT 7 & 8 CONTINUED Page 12 of 15
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 7 & 8 Continued Event
Description:
A ~150 GPM tube leak will develop in the B SG requiring initiation of HPI.
Time Position Applicants Actions or Behavior ANY Determine B SG is the bad SG Direct AO to perform Control of Secondary System Contamination CRS (1203.014) in conjunction with this procedure.
Verify EFW pump Turbine (K3) Steam Supply CV-2617 from B SG in ATC MANUAL closed.
CRS Determine that Emergency Cooldown Rate is not required.
ATC Establish RCS cooldown rate of <100°F/hr on A SG using TBVs.
EVALUATOR NOTE This event is complete when an RCS cooldown and depressurization have been started OR As directed by the Lead Evaluator Page 13 of 15
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 9 Event
Description:
Operating HPI pump breaker trips due to a motor fault Time Position Applicants Actions or Behavior 55 ANY Recognize and report P36A HPI pump trip BOP Establish HPI on the ES pump using 1202.012 RT-2 HPI Place ES HPI pump in service BOP Open BWST Outlet to ES HPI pump (CV-1408)
Steps to Verify one of the following:
restart
- Both HPI RECIRC valves open (CV-1300 and 1301)
- Fully open one HPI Block valve associated with ES HPI pump (CV-1220 or 1285) to prevent dead-heading pump BOP Start AUX Lube Oil pump for ES HPI pump.
BOP Verify RCP Seal INJ Block (CV-1206) closed.
BOP When BWST Outlet is open, Then start ES HPI pump.
BOP Stop AUX Lube Oil pump Open HPI Block valve associated with ES HPI pump (CV-1220 or 1285)
BOP to maintain PZR level and RCS press (modulating valves).
If PZR level or RCS press continues to drop, Then open additional HPI BOP Block valves associated with ES HPI pump:
CV-1227, CV-1228, CV-1284 ATC Monitor MUT level and control per step 2.J as necessary EXAMINER NOTE When asked the AO will report that the A HPI pump breaker A306 has an instantaneous over-current relay tripped.
BOP Place Standby HPI pump in service per 1202.012 RT-2 HPI BOP Verify BWST outlet to OP and STBY HPI pump (CV-1407) open.
BOP Verify RCP Seal INJ Block (CV-1206) closed.
Steps to BOP Close RCS Makeup Block (CV-1233 or CV-1234) start STBY Verify one of the following:
- Both HPI RECIRC valves open (CV-1300 and 1301)
- Fully open one HPI Block valve associated with ES HPI pump (CV-1220 or 1285) to prevent dead-heading pump IF HPI Pump (p-36B0 will be used, THEN verify the following selected to energized bus:
- P36B/P64B Bus select MOD control
- P64B Transfer Switch EVENT 9 CONTINUED Page 14 of 15
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 9 CONTINUED Event
Description:
Operating HPI pump breaker trips due to a motor fault Time Position Applicants Actions or Behavior Steps BOP Start Aux lube oil pump for STBY HPI pump.
to start STBY BOP Start STBY HPI Pump.
HPI pump (cont.) BOP Stop Aux Lube Oil Pump.
EVALUATOR NOTE This scenario is complete when the Standby HPI pump is started.
OR As directed by the Lead Evaluator Page 15 of 15
UNIT 1 SHIFT RELIEF SHEET Page 1 of 1 Computer Generated Form (ref. 1015.015)
Date: Today Shift: Days Crew: Yours Plant Power: 100% Plant Mode: 1 Days on Line: 250 Protected Train: GREEN Scheduled Risk: Minimal PSI= 10 Unit 1 Reactivity Control Parameters Reactivity Change last 100 gal EFPD 250 RCS Boron 568 ppm Dilution 0 ppm makeup 5 gal Acid shift:
/ no Reactivity Change conc.
Delith 0 min PZR Boron 569 ppm Dilution 2 ppm 95 gal Water expected for next shift: change:
Control Rod APSR ULD Status Auto 290.0% 30% ULD setpoint 99.90%
Position: Position:
Any unplanned power maneuvers will be using ICS in auto or manual referencing the contingency reactivity plans located in the Plant Data Book and the network.
SPECIFICATIONS IN EFFECT: (Earliest action complete`on requirements.)
None Indefinite/Conditional Post Trip Contingencies:
Close CV-6640 GS Spillover Bypass None Post Accident Contingencies None CONTROL ROOM ALARM STATUS:
K10-A5, CFT A Press HI/LO Alarm in due to A CFT pressure being low.
None EVOLUTIONS IN PROGRESS (List continuous action steps, parameters being monitored, frequency, and individual responsible as applicable)
None EVOLUTIONS COMPLETED EVOLUTIONS SCHEDULED None Add Nitrogen to the A CFT to raise pressure to ~585 psig per 1104.001 step 11.0.
EQUIPMENT OOS FOR EOOS PROTECTED EQUIPMENT P-4A Service Water Pump OOS for motor replacement. Green train and SFP components per COPD-13 Att. K EQUIPMENT CONFIGURATION CONTROL CHANGES: (past 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />)
Configuration Control Tagging Cat E Cont. Penetration Caution Tags None None None Non None CARRYOVER ITEMS:
P-4A Service Water Pump OOS for motor replacement. P-4B in service from A3. B-55/56 Powered from B5. SG-3 is Open and SG-4 is closed.
Appendix D Scenario Outline Form ES-D-1 Facility: ANO-1 Scenario No.: 4 Op-Test No.: 2013-1 Examiners: ____________________________ Operators: _____________________________
Initial Conditions:
- 100% MOL; Severe Thunderstorm Warning for Pope and Conway counties.
- #2 EDG Tagged out for repairs.
Turnover:
- National Weather service has issued a Severe Thunderstorm Warning for Pope and Conway Counties until 8:00 pm today. AOP 1203.025, Natural Emergencies, Section 3, Tornado Watch
/Severe Thunderstorm Warning, all required actions have been completed.
- #2 EDG OOS for fuel leak repairs. 1104.036 Supplement 11 starting at step 2.4 is due right after turn-over.
Event Event Event Malf. No.
No. Type* Description 1 N/A N (ALL) Perform 1104.036 Supplement 11 for EDG #1 2 TR568 I (ATC) A OTSG operating level transmitter fails high I (BOP) 3 DI_RX7460S RB atmosphere radioactivity monitor fails low. TS 3.4.15 DI_RX7460SP I (SRO) determination.
TS R (ATC) Dispatcher orders down power to 650 MWe due to weather that 4 N/A N (SRO) has damaged Mabelvale sub-station.
I (BOP) Turbine EHC fails to respond in auto mode for ICS (manual 5 RX150 CT control required)
C (ATC) One MSIV for B OTSG drifts shut-requires manual reactor trip 6 CV2692 CT per EOP 1202.001 7 MS131 M (ALL) A OTSG steam leak in containment (MSLI activates). Transfer to 1202.003 overcooling if necessary.
Containment pressure >4psig but B train RBIC will fail to ES264 I (ATC) actuate automatically and an ICW isolation valve will fail open 8 that should shut. Operator will be required to manually initiate B CV2214 CT TS RBIC and verify shut the redundant ICW valve to isolate ICW.
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 12
Appendix D Scenario Outline Form ES-D-1 SCENARIO 4 OBJECTIVES
- 1) Evaluate individual ability to perform the control room portion of #1 EDG Operability Test 1104.036 Supp. 11.
- 2) Evaluate individual ability to recognize and respond to the A SG Operating Level transmitter failing high.
- 3) Evaluate individual ability to recognize and respond to the failure of the RB Atmosphere Radioactivity Monitor (RX-7460) failing low.
- 4) Evaluate individual ability to reduce plant power.
- 5) Evaluate individual ability to recognize and respond to failure of the Turbine EHC system to respond to ICS signals.
- 6) Evaluate individual ability to recognize and respond to MSIV closure at power.
- 7) Evaluate individual ability to recognize and respond to Steam Leak inside containment.
- 8) Evaluate individual ability to recognize and respond to the failure of Train B of Reactor Building Isolation to automatically actuate.
- 9) Evaluate individual ability to recognize and respond to the failure of ICW to RB valve CV-2214 to close on ES signal.
Page 2 of 12
Appendix D Scenario Outline Form ES-D-1 SCENARIO 4 NARRATIVE The crew will assume plant responsibility at 100% power. A Severe Thunderstorm Warning is in effect for Pope and Conway Counties. The #2 EDG is inoperable and tagged out due to a fuel leak. Repairs are in progress. Performance of 1104.036 Supp. 11, DG1 Operability Test has been directed to be performed at the start of shift starting at step 2.4. The SRO will direct performance of Supp. 11 when the crew takes responsibility. N-(ALL)
After the EDG is stopped, a failure (fails high slowly) of the controlling A SG Operating Range Level transmitter, LT-2659 (X instrument) will occur resulting in a K07-B4 SASS MISMATCH alarm and requiring the A MFW Pump ICS HAND/AUTO station to be taken to HAND to prevent ICS from rapidly lowering feedwater in response to the false high level signal. This is directed from 1203.001, section 6. With the A MFW demand in HAND, the Y instrument, LT-2660 will be verified to have a valid signal and will be selected for control and the A MFW Demand will be placed back in AUTO. (I-ATC).
The Reactor Building Atmosphere Radiation Monitor, RX-7460 sample pump will fail requiring entry into TS 3.4.15 for inoperability of a required RCS leaking monitoring system. Required action is to enter a timeclock to return the monitor to operable status within 30 days AND perform one of the following: 1) Analyze grab samples of the RB atmosphere every 24 hrs. OR
- 2) perform and RCS inventory balance every 24 hrs. (I-BOP), (I-SRO)
The dispatcher will call and direct Unit 1 to reduce net generator output to 650Mwe as soon as possible due to damage that has occurred to a transformer in the Mabelvale sub-station.
(N-SRO) (R-ATC).
As power is reduced, the Main Turbine ECH will not respond to the ICS signal resulting in lowering steam header pressure and electrical output not lowering as expected. The Main Turbine must be placed in Operator Auto or Manual (CT) mode to lower power. The crew may also place the ICS SG/RX Demand station in HAND to control reactor and feedwater demand manually. (I-BOP)
The Main Steam Isolation valve (CV-2692) for the B SG will drift closed requiring a reactor trip per 1202.001 Reactor Trip EOP. The ATC will trip the reactor (CT) and perform the reactor trip immediate actions. The SRO will direct the crew from the Reactor Trip follow up actions.
(C-ATC)
A steam leak will develop on the A SG inside the reactor building. (M-ALL) This will result in lowering steam pressure on the A SG and rising pressure inside the reactor building. SG pressure <900 psig or actuation of ESAS on RB pressure of 4 psig alone will require entry into the Overcooling EOP.ESAS RB Isolation Channel 6 will fail to automatically actuate and will require manual actuation (TS 3.3.7) (I-ATC) (CT) RB ICW isolation valve CV-2214 will fail to close automatically or manually. This is reported and determined that the redundant valve (CV-2215) is closed and the function is not lost. ESAS actuation will result in full HPI flow to core.
This will initially help maintain RCS inventory as the RCS is excessively cooled but must be overridden and throttled/secured to prevent overfilling the pressurizer and opening the ERV.
Actuation of ESAS channels 5 & 6 will result in a loss of RCP services which will require the RCPs to be secured. The event is terminated by isolating feed to the A SG and allowing the SG to boil dry. RCS temperature will stabilized using the B SG Atmospheric Dump Control Valve (MSIV is closed).
Page 3 of 12
Appendix D Scenario Outline Form ES-D-1 Simulator Instructions for Scenario 4 Recall IC 288 Insert malfunction ES264 ESAS Channel 6 Fails to Actuate Insert malfunction CV2214 to 1 ICW Letdown Clrs Iso Vlv Insert malfunction RP246 A RPS channel will not trip Insert malfunction RP247 B RPS channel will not trip Insert malfunction RP248 C RPS channel will not trip Insert malfunction RP249 D RPS channel will not trip Insert malfunction TR568 to 292 in 180 on Event 1 A OTSG Operate Level (LT2659)
Insert override DI_RX7460S to FALSE on Event 2 Start, Pump Control RX7460 Insert override DI_RX7460SP to TRUE on Event 2 Stop, Pump Control RX7460 Insert override DO_RX7460A2 to ON on Event 2 AMB LP, Pump Fail RX7460 Insert malfunction RX150 on Event 3 Freeze ICS signal to EHC at current value Insert malfunction CV2692 to 0 in 60 on Event 4 B MSIV Insert malfunction MS131 to 0.4 in 180 on Event 5 A MS Line Rupture inside RB Event Value/Ramp Time Malf. No. Event Description No. Time 1 0 N/A N/A Perform 1104.036 Supplement 11 for EDG #1 Trigger 1 2 12 292 / Ramp 3 A OTSG operating level transmitter fails high TR568 Min.
Trigger 2 3 19 DI_RX7460S FALSE RB atmosphere radioactivity monitor fails low.
DI_RX7460SP TRUE 4 27 N/A N/A Dispatcher orders down power to 650 MWe Trigger 3 5 27.5 N/A Turbine EHC fails to respond in auto mode for ICS RX150 Cued by Trigger 4 One MSIV for B OTSG drifts shut-requires 0/60 sec Examiner CV2692 manual reactor trip RPS is failed and will not cause a automatic reactor 6 trip. (TS) The manual trip pushbutton is failed RP246,7,8,9 N/A requiring the operators to manually trip the reactor Initial DI_ICC0020 FALSE using the backup pushbuttons. (TS) (ATC-CT)
Criteria - The reactor should be manually tripped before the pressurizer goes solid.
Rx Trip + A OTSG steam leak in containment (MSLI Trigger 5 .4 /
7 30 activates). Transfer to 1202.003 overcooling if MS131 Ramp 3 Min.
Seconds necessary.
B Train of Reactor Bldg. Isolation and Cooling ES264 N/A fails to auto actuate (ESAS channel 6) 8 Initial CV2214 1 ICW valve CV2214 fails to close upon ESAS actuation Page 4 of 12
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 1 Event
Description:
Perform surveillance test of the #1 EDG per Supplement 11 of 1104.036 starting at step 2.4, for operability verification due to maintenance of #2 EDG.
Time Position Applicants Actions or Behavior T=0 Directs the performance of the #1 EDG surveillance test per Supplement 11 of CRS 1104.036 starting at step 2.4.
BOP Make plant announcement of the starting of #1 EDG.
BOP Verify DG1 Volts Select switch NOT in OFF on C10.
BOP Simultaneously depress the START pushbutton for #1 EDG and start the stopwatch.
BOP Stop the stopwatch when DG1 voltage exceeds 4000 volts.
BOP Record the time from start to >4000 volts in section 3.0.
Verify service water to DG1 coolers (CV3806) opens and record verification in section BOP 3.0.
BOP Verify voltage and frequency are ~ 4160v and ~ 60hz, respectively.
BOP Stop DG1 by depressing the STOP pushbutton on C10.
BOP Verify associated critical and non-critical alarms on K01 clear.
EVENT TERMINATION CRITERIA
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 2 Event
Description:
A OTSG Operating Range Level Transmitter fails high.
Time Position Applicants Actions or Behavior T=12 BOP Acknowledge and report annunciator K07-B4, SASS MISMATCH.
CRS Obtain Annunciator Corrective Action for K07-B4 for guidance [ACA 1203.012F, p20].
ATC Acknowledge and report annunciator K07-A2, A OTSG Hi Level Limit.
CRS Obtain Annunciator Corrective Action for K07-A2 for guidance [ACA 1203.012F, p8].
ATC/ Determine affected instrument by observing SASS ENBL light not illuminated for the BOP A SG Operating Range level recorder on C13.
ATC/
Determine the A OTSG operating level transmitter is failing high.
BOP CRS Direct the ATC to place the A feed pump H/A station in HAND and stabilize plant.
ATC Place the A main feed pump H/A station in HAND and balanced feed flows as needed.
Direct board operators to validate level transmitters by comparing to other (redundant)
CRS instruments.
Verify plant stable and ICS in condition for instrument swap and direct the BOP to CRS select the other instrument.
BOP Verify the Operating Range Level for A is indicating properly on C13.
ATC Report annunciator K07-A2, A OTSG Hi Level Limit has cleared.
CRS Direct placing ICS (A feed pump H/A station) back to AUTO [Procedure 1105.004]
EVENT TERMINATION CRITERIA ICS returned to AUTO OR As directed by the Lead Evaluator Page 6 of 12
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 3 Event
Description:
RB atmosphere radioactivity monitor fails low.
Time Position Applicants Actions or Behavior Acknowledge and report annunciator K10-C1, Radiation Monitor Trouble as well as T=19 ATC Annunciator K15-C2, RB Atmosphere Detector Trouble.
BOP Observe monitors at C24 and C25 and determine that RX7460/61 has no running sample pump.
Refer to Annunciator Corrective Action [ACA 1203.012I] for corrective action and CRS guidance, as well as [ACA 1203.012M]
CRS Determine RB Atmosphere Gaseous Monitor is inoperable and refer to Tech Spec 3.4.15B.
CRS Initiate steps to meet requirements per Tech Specs.
CRS Initiate steps to have the failed monitor checked and repaired.
EVENT TERMINATION CRITERIA Tech Spec determination made OR As directed by the Lead Evaluator Page 7 of 12
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 4 & 5 Event
Description:
The Mablevale substation experiences storm damage causing the breakers in the switchyard supplying that line to open. The dispatcher requests an emergency power reduction to ~650 MWe to maintain system integrity. The Turbine fails to respond to lowering demand.
Time Position Applicants Actions or Behavior ROLE PLAY Call control room as EOC Dispatcher and direct unit to reduce power to 650 MWe as soon as possible due to transformer damage at the Mablevale substation.
If asked by control room personnel inform them that there is serious concern over grid stability due to the severe weather and substation damage.
EVALUATOR NOTE:
Power reduction will be to 650MW net. The ULD reads out in gross MW, therefore will have to be adjusted to ~680 MW to achieve 650 MW net T=27 CRS Direct ATC to reduce unit load demand to ~680 MWe.
CRS Direct operations per 1203.045, Rapid Plant Shutdown.
ATC Commence reduction in unit load to 680 MWe using the ULD.
EVALUATOR NOTE:
Turbine may revert to Operator Auto mode before operator takes action.
ATC/ Recognize and report to the CRS that the turbine is not responding during the power T=27.5 BOP reduction.
EVALUATOR NOTE:
The crew may elect to place both the SG/RX master and the Turbine in the MANUAL mode. In this configuration, the ATC controls the change in load demand and the BOP will maintain turbine header pressure.
CRS Direct the BOP to place the turbine in Operator Auto or Manual mode and control steam header pressure.
CT BOP Take the turbine to manual or operator auto CRS Direct the ATC to place the SG/RX Master H/A station in HAND and lower load to 680 MWe.
ATC Place the SG/RX master in HAND and slowly toggle down.
Events 4 & 5 Continued Page 8 of 12
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 4 & 5 CONTINUED Event
Description:
The Mablevale substation experiences storm damage causing the breakers in the switchyard supplying that line to open. The dispatcher requests an emergency power reduction to ~650 MWe to maintain system integrity. The Turbine fails to respond to lowering demand Time Position Applicants Actions or Behavior EVALUATOR NOTE:
In the manual mode on the SG/RX master, the operator has control of the rate the plant will change. It is expected the operator will maintain the rate of change near the directed rate by the CRS.
Verify Turbine EHC responds to lowering load and maintains header pressure at or BOP near setpoint of 895#. (Operator Auto or Manual)
ATC Stabilize load at ~650MWe (680MW gross). Power should be ~65-67%.
EVENT TERMINATION CRITERIA Power reduction is complete OR As directed by the Lead Evaluator Page 9 of 12
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No. 6 Event
Description:
The B Main Steam Isolation Valve drifts shut, requiring a manual reactor trip per EOP 1202.001.
Time Position Applicants Actions or Behavior Cued ATC Acknowledge and report annunciator K07-B4, SASS MISMATCH.
ATC Acknowledge and report annunciator K07-C6, Main Steam Pressure Hi/Lo in alarm.
ATC/
Observe the B MSIV, CV2692, closing.
BOP CRS Direct the ATC to TRIP the reactor and Carryout the immediate actions.
Trip the reactor by depressing the pushbutton on C03 and observing all control rods CT ATC inserted and power dropping.
Manually trip the turbine by depressing the pushbutton on C01 and observing the BOP throttle and governor valves close and output and exciter field breakers open.
ATC/
Verify subcooling margin adequate.
BOP CRS Provide direction to the crew per Reactor Trip EOP, 1202.001.
EVENT TERMINATION CRITERIA B MSIV closed and Reactor is tripped OR As determined by the Lead Evaluator.
Page 10 of 12
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event 7 & 8 Event
Description:
Main Steam Line rupture inside containment. Channel 6 of ESAS fails to auto actuate. ICW valve CV2214 fails to close.
Time Position Applicants Actions or Behavior E6 Recognize A OTSG pressure dropping OR noticeably lower than B OTSG
+ ATC pressure.
7 ATC Monitor RB pressure and temperature.
Acknowledge and report annunciator K11-E1, RB Pressure HIGH. ACA guidance if ATC prior to ESAS actuation is ACA 1203.012J, p6.
EVALUATOR NOTE:
Due to rise in reactor building pressure and temperature, ESAS may actuate prior to the direction to trip the Reactor if CRS fails to recognize MSIV drifting shut in event 6 above.
Annunciator K12-A1, FIRE ALARM, will alarm due to the environmental conditions inside the Reactor Building. If panel 463 is checked for location of the alarm, instruct that module A2-5 lower, RB UNEP ZONE 32-K, in alarm.
ATC/
Identify and announce ESAS has actuated on high RB Pressure.
BOP CRS Transition to ESAS Procedure , EOP1202.010 and direct crew actions.
CRS Direct the verification of ESAS per RT10.
ATC/
Recognize failure of Channel 6 of ESAS to auto actuate. Tech Spec 3.3.7A.
BOP CT ATC Manually actuate Channel 6 of ESAS using the button on C04.
ATC Identify and report failure of CV2214 to close.
CRS Direct the BOP to verify the redundant ICW valve on Channel 6, CV2215, closed.
ATC Verify actuation of ESAS per RT 10.
Examiner Note: RT10 will include securing RCPs due to not having cooling water for them.
CREW Recognize SG pressure < 900#
Event 7 & 8 Continued Page 11 of 12
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event 7 & 8 CONTINUED Event
Description:
Main Steam Line rupture inside containment. Channel 6 of ESAS fails to auto actuate. ICW valve CV2214 fails to close.
Time Position Applicants Actions or Behavior CRS Transition to Overcooling Emergency Operating procedure (1202.003).
CT Manually override and secure HPI as directed by the CRS and the Emergency BOP Operating Procedure.
Acknowledge and report annunciator K12-A7, A OTSG MSLI actuated. ACA ATC guidance is ACA 1203.012K, p31.
CRS Provide RT6 to ATC to verify proper MSLI and EFW actuation and control.
BOP Verify proper MSLI and EFW actuation and control per RT6.
ATC Control RCS pressure within the limits of Figure 3 per RT14 using PZR heaters EVENT AND SCENARIO TERMINATION CRITERIA RCS pressure and temperature stable with the A OTSG isolated, channel 6 of ESAS manually actuated, with the ICW flowpath isolated OR As determined by the Lead Evaluator.
Page 12 of 12
UNIT 1 SHIFT RELIEF SHEET Page 1 of 1 Computer Generated Form (ref. 1015.015)
Date: Today Shift: Days Crew: Yours Plant Power: 100% Plant Mode: 1 Days on Line: 250 Protected Train: GREEN Scheduled Risk: Minimal PSI= 10 Unit 1 Reactivity Control Parameters Reactivity Change last 100 gal EFPD 250 RCS Boron 568 ppm Dilution 0 ppm makeup 5 gal Acid shift:
/ no Reactivity Change conc.
Delith 0 min PZR Boron 569 ppm Dilution 2 ppm 95 gal Water expected for next shift: change:
Control Rod APSR ULD Status Auto 290.0% 30% ULD setpoint 99.90%
Position: Position:
Any unplanned power maneuvers will be using ICS in auto or manual referencing the contingency reactivity plans located in the Plant Data Book and the network.
SPECIFICATIONS IN EFFECT: (Earliest action complete`on requirements.)
- 2 EDG OOS for repairs as of 23 hours2.662037e-4 days <br />0.00639 hours <br />3.80291e-5 weeks <br />8.7515e-6 months <br /> ago. 7 day required action per TS 3.8.1 Conditon B.
Indefinite/Conditional Post Trip Contingencies:
Close CV-6640 GS Spillover Bypass Perform 1104.036 Supplement 11 (SR 3.8.1.2) to verify #1 EDG operability every 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> until
- 2 EDG is operable. Required by TS 3.8.2 Conditon B 3.2. Post Accident Contingencies None CONTROL ROOM ALARM STATUS:
K01-D3 #2 EDG Not Available alarm due to #2 EDG tagged for repairs.
EVOLUTIONS IN PROGRESS (List continuous action steps, parameters being monitored, frequency, and individual responsible as applicable)
National Weather Service has issued and Severe Thunderstorm Warning for Pope and Conway counties until 8:00pm today. Natural Emergencies, section3, Tornado Watch/ Severe Thunderstorm Warning, required actions have been completed.
- 2 EDG tagged out for fuel leak repairs. 1104.036 Supplement 11 needs to be performed to verify operability of #1 EDG.
EVOLUTIONS COMPLETED EVOLUTIONS SCHEDULED None Perform 1104.032 Supplement 11 to verify #1 EDG operability every 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
EQUIPMENT OOS FOR EOOS PROTECTED EQUIPMENT
- 1 EDG.
EQUIPMENT CONFIGURATION CONTROL CHANGES: (past 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />)
Configuration Control Tagging Cat E Cont. Penetration Caution Tags None None None Non None CARRYOVER ITEMS:
None