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Line 48: Line 48:
OP-903-117, Emergency Diesel Generator Fuel Oil Transfer Pump Operability Check Time Critical:
OP-903-117, Emergency Diesel Generator Fuel Oil Transfer Pump Operability Check Time Critical:
No Validation Time:
No Validation Time:
15 mins. K/A 2.1.23, Ability to perform specif ic system and Importance Rating 4.4 integrated plant procedur es during all modes of plant operation.  
15 mins. K/A 2.1.23, Ability to perform specif ic system and Importance Rating  
 
===4.4 integrated===
plant procedur es during all modes of plant operation.  


Applicant:
Applicant:
Line 187: Line 190:
OP-004-005, Core Operating Limits Supervisory System Operation Time Critical:
OP-004-005, Core Operating Limits Supervisory System Operation Time Critical:
No Validation Time:
No Validation Time:
15 mins. K/A 2.1.20, Ability to interpret and execute. Importance Rating 4.6 procedure steps Applicant:
15 mins. K/A 2.1.20, Ability to interpret and execute. Importance Rating  
 
===4.6 procedure===
steps Applicant:
Time Start:
Time Start:
Time Finish:
Time Finish:
Line 285: Line 291:
OP-903-026, Emergency Co re Cooling System Valve Lineup Verification Time Critical:
OP-903-026, Emergency Co re Cooling System Valve Lineup Verification Time Critical:
No Validation Time:
No Validation Time:
15 mins. K/A 2.2.40, Ability to apply Tec hnical  Importance Rating 4.7 Specifications for a system Applicant:
15 mins. K/A 2.2.40, Ability to apply Tec hnical  Importance Rating  
 
===4.7 Specifications===
for a system Applicant:
Time Start:
Time Start:
Time Finish:
Time Finish:
Line 374: Line 383:
EC-M84-001 Time Critical:
EC-M84-001 Time Critical:
No Validation Time:
No Validation Time:
20 mins. K/A 2.3.6, Ability to approve releas e permits Importance Rating 3.8           Applicant:
20 mins. K/A 2.3.6, Ability to approve releas e permits Importance Rating  
 
===3.8 Applicant===
 
Time Start:
Time Start:
Time Finish:
Time Finish:
Line 522: Line 534:
EP-001-001 Recognition and Classification of Emergency Conditions Time Critical:
EP-001-001 Recognition and Classification of Emergency Conditions Time Critical:
No Validation Time:
No Validation Time:
15 mins. K/A 2.4.41, Knowledge of the emergency action Importance Rating 4.6 level thresholds and classifications.
15 mins. K/A 2.4.41, Knowledge of the emergency action Importance Rating  
 
===4.6 level===
thresholds and classifications.
Applicant:
Applicant:
Time Start:
Time Start:
Line 1,452: Line 1,467:
o DI-01A06S08-1 overridden to OFF  
o DI-01A06S08-1 overridden to OFF  


(Initial/Date) 9.1 PowER INCREASE To 100%(lnitiaI/Dat) 9.1.1 Verify Initial Conditions as follows:__________
(Initial/Date)
 
===9.1 PowER===
INCREASE To 100%(lnitiaI/Dat)
 
====9.1.1 Verify====
Initial Conditions as follows:__________
9.1.1.1 Reactor Power is 10%.9.1.1.2 Pressurizer pressure is being maintained at 2250 PSIA (2175-2265 PSIA).9.1.1.3 Pressurizer level is being maintained at 33%by Control Channel indication.
9.1.1.1 Reactor Power is 10%.9.1.1.2 Pressurizer pressure is being maintained at 2250 PSIA (2175-2265 PSIA).9.1.1.3 Pressurizer level is being maintained at 33%by Control Channel indication.
9.1.1.4 Steam Generator levels are being maintained between 50 to 70%NR by Main Feedwater.
9.1.1.4 Steam Generator levels are being maintained between 50 to 70%NR by Main Feedwater.
Line 1,469: Line 1,490:
9.1.4.4.1 Adjust output indication equal to process indication.
9.1.4.4.1 Adjust output indication equal to process indication.
9.1.4.4.2 Depress the Auto pushbutton.
9.1.4.4.2 Depress the Auto pushbutton.
9.1.4.5 Slowly adjust FW Master Controllers setpoint to desired//Ojt Steam Generator level.9.1.5 Verify Steam Generator levels 63 to 73%NR./,o_I0 9.1.6 Verify Generator Output Breakers Open./K?.'11c 9.1.7 Verify Ground Disconnects are Open./i0')-lc'OP-010-004 Revision 308 Attachment 9.1 (2 of 18)20 (jitial/Date) 9.1.8 Verify Manual Disconnects for Generator Output Breakers iiD-7-7 are Closed, 9.1.9 Prepare the MSR Tube Bundles for pressurization by/performing Section 6.1, MSR Cold Start Mode, of/OP-005-005, Reheat Steam System.NOTE When rolling and loading the Turbine, monitor Seal Oil temperatures.
9.1.4.5 Slowly adjust FW Master Controllers setpoint to desired//Ojt Steam Generator level.9.1.5 Verify Steam Generator levels 63 to 73%NR./,o_I0 9.1.6 Verify Generator Output Breakers Open./K?.'11c 9.1.7 Verify Ground Disconnects are Open./i0')-lc'OP-010-004 Revision 308 Attachment 9.1 (2 of 18)20 (jitial/Date)
 
====9.1.8 Verify====
Manual Disconnects for Generator Output Breakers iiD-7-7 are Closed, 9.1.9 Prepare the MSR Tube Bundles for pressurization by/performing Section 6.1, MSR Cold Start Mode, of/OP-005-005, Reheat Steam System.NOTE When rolling and loading the Turbine, monitor Seal Oil temperatures.
9.1.10 Priorrolling Main Turbine, verify the following:
9.1.10 Priorrolling Main Turbine, verify the following:
9.1.10.1 Turbine Cooling Water available to Exciter Coolers in accordance with OP-003-027, Turbine Closed Cooling Water System.Exciter field breaker is Open.Voltage Regulator is not in Service.The Exciter doors are Closed.All personnel are clear of Main Turbine.Verify afl Turbine Trips are clear on PMC group TGTRIP.Verify operability of the following Reverse Current Valves (RCV)by checking them Closed:*ES-ill#1 ESHdrRCV*ES-207#2 ES Hdr RCV*ES-309A(B,C)
9.1.10.1 Turbine Cooling Water available to Exciter Coolers in accordance with OP-003-027, Turbine Closed Cooling Water System.Exciter field breaker is Open.Voltage Regulator is not in Service.The Exciter doors are Closed.All personnel are clear of Main Turbine.Verify afl Turbine Trips are clear on PMC group TGTRIP.Verify operability of the following Reverse Current Valves (RCV)by checking them Closed:*ES-ill#1 ESHdrRCV*ES-207#2 ES Hdr RCV*ES-309A(B,C)
Line 2,347: Line 2,371:


or  Emergency Boration using one Charging Pump ATC Steps for Direct Boration:
or  Emergency Boration using one Charging Pump ATC Steps for Direct Boration:
CAUTION (1) This section affects reactivity. This evolution should be crosschecked and completed prior to leaving CP-4. (2) At least one reactor coolant pump in each loop should be operating prior to performing direct boration operations to ensure proper chemical mixing.
CAUTION (1) This section affects reactivity. This evolution should be crosschecked and completed prior to leaving CP-4. (2) At least one reactor coolant pump in each loop should be operating prior to performing direct boration operations to ensure proper chemical mixing.  
6.7.1 Inform SM/CRS that this Section is being performed.
 
====6.7.1 Inform====
SM/CRS that this Section is being performed.
NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level  1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD)  1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD)  1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD)  1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be added on Attachment 11.6, Calculation of Boric Acid Volume for Direct Boration or VCT Borate Makeup Mode. Should use Reactor Engineering Reactivity Worksheet 6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Acid desired. 6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desired Boric Acid Makeup Pump A(B).
NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level  1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD)  1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD)  1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD)  1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be added on Attachment 11.6, Calculation of Boric Acid Volume for Direct Boration or VCT Borate Makeup Mode. Should use Reactor Engineering Reactivity Worksheet 6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Acid desired. 6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desired Boric Acid Makeup Pump A(B).
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 9 of 24          Event
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 9 of 24          Event


== Description:==
== Description:==
Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 6.7.5 Place Direct Boration Valve, BAM-143, control switch to AUTO.
Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 1  
6.7.6 Place Makeup Mode selector switch to BORATE.
 
6.7.7 Verify selected Boric Acid Makeup Pump A(B) Starts.
====6.7.5 Place====
6.7.8 Verify Direct Boration Valve, BAM-143, Opens.
Direct Boration Valve, BAM-143, control switch to AUTO.  
 
====6.7.6 Place====
Makeup Mode selector switch to BORATE.  
 
====6.7.7 Verify====
selected Boric Acid Makeup Pump A(B) Starts.  
 
====6.7.8 Verify====
Direct Boration Valve, BAM-143, Opens.
NOTE  The Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is most accurate in the range of 10 - 25 GPM.
NOTE  The Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is most accurate in the range of 10 - 25 GPM.
6.7.9 If manual control of Boric Acid flow is desired, then perform the following:
6.7.9 If manual control of Boric Acid flow is desired, then perform the following:
Line 2,366: Line 2,401:
Place available Pressurizer Pressure Backup Heater Control Switches to ON. Reduce Pressurizer Spray Valve Controller (RC-IHIC-0100) setpoint potentiometer to establish spray flow and maintain RCS pressure 2250 PSIA (2175 - 2265).
Place available Pressurizer Pressure Backup Heater Control Switches to ON. Reduce Pressurizer Spray Valve Controller (RC-IHIC-0100) setpoint potentiometer to establish spray flow and maintain RCS pressure 2250 PSIA (2175 - 2265).
This manipulation is performed at CP-2.
This manipulation is performed at CP-2.
ATC Operate CEAs to maintain ASI using CEA Reg. Group 6 or Group P Control Element Assemblies. Operate CEAs in Manual Group mode as follows:
ATC Operate CEAs to maintain ASI using CEA Reg. Group 6 or Group P Control Element Assemblies. Operate CEAs in Manual Group mode as follows:  
6.7.1 Verify Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer.
 
====6.7.1 Verify====
Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 10 of 24          Event
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 10 of 24          Event


== Description:==
== Description:==
Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 6.7.2 Position Group Select switch to desired group.
Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 1  
6.7.3 Place Mode Select switch to MG and verify the following:  White lights Illuminated on Group Selection Matrix for selected group  MG light Illuminates 6.7.4 Operate CEA Manual Shim switch to INSERT group to desired height while monitoring the following:  CEA Position Indicator selected CEA group is moving in desired direction  If Reactor is critical, then monitor the following:  Reactor Power  Reactor Coolant System (RCS) temperature  Axial Shape Index (ASI)
 
====6.7.2 Position====
Group Select switch to desired group.  
 
====6.7.3 Place====
Mode Select switch to MG and verify the following:  White lights Illuminated on Group Selection Matrix for selected group  MG light Illuminates  
 
====6.7.4 Operate====
CEA Manual Shim switch to INSERT group to desired height while monitoring the following:  CEA Position Indicator selected CEA group is moving in desired direction  If Reactor is critical, then monitor the following:  Reactor Power  Reactor Coolant System (RCS) temperature  Axial Shape Index (ASI)
NOTE The Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when the Mode Select switch is not in OFF.
NOTE The Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when the Mode Select switch is not in OFF.
6.7.5 When desired set of moves have been completed, then place Mode Select switch to OFF.
6.7.5 When desired set of moves have been completed, then place Mode Select switch to OFF.
Line 2,650: Line 2,695:
== Description:==
== Description:==
Dilute from 5x10 -4% to 5 - 10% Power Time Position Applicant's Actions or Behavior ATC Aligns for 100 gallon Primary Makeup Water Addition in accordance with OP-002-005, Chemical and Volume Control.
Dilute from 5x10 -4% to 5 - 10% Power Time Position Applicant's Actions or Behavior ATC Aligns for 100 gallon Primary Makeup Water Addition in accordance with OP-002-005, Chemical and Volume Control.
Procedure Caution THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSSCHECKED AND COMPLETED PRIOR TO LEAVING CP-4.
Procedure Caution THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSSCHECKED AND COMPLETED PRIOR TO LEAVING CP-4.  
6.9.1 Inform SM/CRS that this Section is being performed.
 
====6.9.1 Inform====
SM/CRS that this Section is being performed.
Procedure Note When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level  1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD)  1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD)  1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD)  1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.9.2 At SM/CRS discretion, calculate volume of Primary Makeup water to be added on Attachment 11.7, Calculation of Primary Makeup Water Volume for Direct Dilution or VCT Dilute Makeup Mode.
Procedure Note When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level  1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD)  1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD)  1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD)  1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.9.2 At SM/CRS discretion, calculate volume of Primary Makeup water to be added on Attachment 11.7, Calculation of Primary Makeup Water Volume for Direct Dilution or VCT Dilute Makeup Mode.
Not applicable, reactivity plan gives required volume.
Not applicable, reactivity plan gives required volume.
Line 2,658: Line 2,705:


== Description:==
== Description:==
Dilute from 5x10 -4% to 5 - 10% Power Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 6.9.4 Place Makeup Mode selector switch to DILUTE.
Dilute from 5x10 -4% to 5 - 10% Power Time Position Applicant's Actions or Behavior Scenario 3, Revision 1  
 
====6.9.4 Place====
Makeup Mode selector switch to DILUTE.
6.9.5 Open VCT Makeup Valve, CVC-510.
6.9.5 Open VCT Makeup Valve, CVC-510.
Procedure Note The Dilution Flow Totalizer will not register below 5 GPM. The Dilution Flow Totalizer is most accurate at >10 GPM.
Procedure Note The Dilution Flow Totalizer will not register below 5 GPM. The Dilution Flow Totalizer is most accurate at >10 GPM.
Procedure Caution DILUTION SHALL IMMEDIATELY BE STOPPED IF PRE-POWER DEPENDENT INSERTION LIMIT (H-9, CABINET H) ALARM IS INITIATED OR ANY UNEXPECTED REACTI VITY CHANGE OCCURS.
Procedure Caution DILUTION SHALL IMMEDIATELY BE STOPPED IF PRE-POWER DEPENDENT INSERTION LIMIT (H-9, CABINET H) ALARM IS INITIATED OR ANY UNEXPECTED REACTI VITY CHANGE OCCURS.
6.9.6.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Manual.      6.9.6.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, output to >5 GPM flow rate.
6.9.6.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Manual.      6.9.6.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, output to >5 GPM flow rate.  
6.9.8 Verify Primary Makeup Water Control Valve, PMU-144, Intermediate or Open.      6.9.9 Observe Primary Makeup water flow rate for proper indication.
 
====6.9.8 Verify====
Primary Makeup Water Control Valve, PMU-144, Intermediate or Open.      6.9.9 Observe Primary Makeup water flow rate for proper indication.
6.9.10 Operate VCT Inlet/Bypass to Holdup Tanks, CVC-169 Control Switch to BMS/Auto positions as necessary to maintain VCT pressure and level within normal operating bands.
6.9.10 Operate VCT Inlet/Bypass to Holdup Tanks, CVC-169 Control Switch to BMS/Auto positions as necessary to maintain VCT pressure and level within normal operating bands.
6.9.11 When Primary Makeup Water Batch Counter has counted down to desired value, then verify Primary Makeup Water Control Valve, PMU-144, Closed.      Procedure Note Step 6.9.12 may be repeated as necessary to achieve desired total Primary Makeup Water addition for plant conditions.
6.9.11 When Primary Makeup Water Batch Counter has counted down to desired value, then verify Primary Makeup Water Control Valve, PMU-144, Closed.      Procedure Note Step 6.9.12 may be repeated as necessary to achieve desired total Primary Makeup Water addition for plant conditions.
Line 2,696: Line 2,748:
== Description:==
== Description:==
PMU Failure / Inadvertent Dilution Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 ATC Aligns for 50 gallon Primary Makeup Water Addition in accordance with OP-002-005, Chemical and Volume Control.
PMU Failure / Inadvertent Dilution Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 ATC Aligns for 50 gallon Primary Makeup Water Addition in accordance with OP-002-005, Chemical and Volume Control.
Procedure Caution THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSSCHECKED AND COMPLETED PRIOR TO LEAVING CP-4.
Procedure Caution THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSSCHECKED AND COMPLETED PRIOR TO LEAVING CP-4.  
6.9.1 Inform SM/CRS that this Section is being performed.
 
====6.9.1 Inform====
SM/CRS that this Section is being performed.
Procedure Note When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level  1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD)  1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD)  1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD)  1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.9.2 At SM/CRS discretion, calculate volume of Primary Makeup water to be added on Attachment 11.7, Calculation of Primary Makeup Water Volume for Direct Dilution or VCT Dilute Makeup Mode.
Procedure Note When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level  1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD)  1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD)  1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD)  1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.9.2 At SM/CRS discretion, calculate volume of Primary Makeup water to be added on Attachment 11.7, Calculation of Primary Makeup Water Volume for Direct Dilution or VCT Dilute Makeup Mode.
Not applicable, reactivity plan gives required volume.
Not applicable, reactivity plan gives required volume.
Line 2,708: Line 2,762:
Procedure Note The Dilution Flow Totalizer will not register below 5 GPM. The Dilution Flow Totalizer is most accurate at >10 GPM.
Procedure Note The Dilution Flow Totalizer will not register below 5 GPM. The Dilution Flow Totalizer is most accurate at >10 GPM.
Procedure Caution DILUTION SHALL IMMEDIATELY BE STOPPED IF PRE-POWER DEPENDENT INSERTION LIMIT (H-9, CABINET H) ALARM IS INITIATED OR ANY UNEXPECTED REACTI VITY CHANGE OCCURS.
Procedure Caution DILUTION SHALL IMMEDIATELY BE STOPPED IF PRE-POWER DEPENDENT INSERTION LIMIT (H-9, CABINET H) ALARM IS INITIATED OR ANY UNEXPECTED REACTI VITY CHANGE OCCURS.
6.9.6.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Manual.      6.9.6.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, output to >5 GPM flow rate.
6.9.6.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Manual.      6.9.6.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, output to >5 GPM flow rate.  
6.9.8 Verify Primary Makeup Water Control Valve, PMU-144, Intermediate or Open.      6.9.9 Observe Primary Makeup water flow rate for proper indication.
 
====6.9.8 Verify====
Primary Makeup Water Control Valve, PMU-144, Intermediate or Open.      6.9.9 Observe Primary Makeup water flow rate for proper indication.
6.9.10 Operate VCT Inlet/Bypass to Holdup Tanks, CVC-169 Control Switch to BMS/Auto positions as necessary to maintain VCT pressure and level within normal operating bands.
6.9.10 Operate VCT Inlet/Bypass to Holdup Tanks, CVC-169 Control Switch to BMS/Auto positions as necessary to maintain VCT pressure and level within normal operating bands.
6.9.11 When Primary Makeup Water Batch Counter has counted down to desired value, then verify Primary Makeup Water Control Valve, PMU-144, Closed.
6.9.11 When Primary Makeup Water Batch Counter has counted down to desired value, then verify Primary Makeup Water Control Valve, PMU-144, Closed.
Line 2,730: Line 2,786:
== Description:==
== Description:==
PMU Failure / Inadvertent Dilution Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 Examiner Note Crew may wait to see the effect of the extra PMU prior to performing boration. The steps for Direct Boration and CEA insertion are included in this section. It is not necessary to hold at this point for either action ATC Steps for Direct Boration:
PMU Failure / Inadvertent Dilution Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 Examiner Note Crew may wait to see the effect of the extra PMU prior to performing boration. The steps for Direct Boration and CEA insertion are included in this section. It is not necessary to hold at this point for either action ATC Steps for Direct Boration:
CAUTION (1) This section affects reactivity. This evolution should be crosschecked and completed prior to leaving CP-4. (2) At least one reactor coolant pump in each loop should be operating prior to performing direct boration operations to ensure proper chemical mixing.
CAUTION (1) This section affects reactivity. This evolution should be crosschecked and completed prior to leaving CP-4. (2) At least one reactor coolant pump in each loop should be operating prior to performing direct boration operations to ensure proper chemical mixing.  
6.7.1 Inform SM/CRS that this Section is being performed.
 
NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level  1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD)  1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD)  1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD)  1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be added on Attachment 11.6, Calculation of Boric Acid Volume for Direct Boration or VCT Borate Makeup Mode. Should use Reactor Engineering Reactivity Worksheet 6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Acid desired. 6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desired Boric Acid Makeup Pump A(B).
====6.7.1 Inform====
6.7.5 Place Direct Boration Valve, BAM-143, control switch to AUTO.
SM/CRS that this Section is being performed.
6.7.6 Place Makeup Mode selector switch to BORATE.
NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level  1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD)  1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD)  1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD)  1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be added on Attachment 11.6, Calculation of Boric Acid Volume for Direct Boration or VCT Borate Makeup Mode. Should use Reactor Engineering Reactivity Worksheet 6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Acid desired. 6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desired Boric Acid Makeup Pump A(B).  
6.7.7 Verify selected Boric Acid Makeup Pump A(B) Starts.
 
6.7.8 Verify Direct Boration Valve, BAM-143, Opens.
====6.7.5 Place====
Direct Boration Valve, BAM-143, control switch to AUTO.  
 
====6.7.6 Place====
Makeup Mode selector switch to BORATE.  
 
====6.7.7 Verify====
selected Boric Acid Makeup Pump A(B) Starts.  
 
====6.7.8 Verify====
Direct Boration Valve, BAM-143, Opens.
NOTE  The Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is most accurate in the range of 10 - 25 GPM.
NOTE  The Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is most accurate in the range of 10 - 25 GPM.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 9 of 17          Event
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 9 of 17          Event
Line 2,745: Line 2,811:
6.7.9.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, output to >3 GPM flow rate.
6.7.9.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, output to >3 GPM flow rate.
6.7.11 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate or Open. 6.7.12 Observe Boric Acid flow rate for proper indication.
6.7.11 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate or Open. 6.7.12 Observe Boric Acid flow rate for proper indication.
Steps for CEA insertion ATC Operate CEAs to maintain ASI using CEA Reg. Group 6 or Group P Control Element Assemblies. Operate CEAs in Manual Group mode as follows:
Steps for CEA insertion ATC Operate CEAs to maintain ASI using CEA Reg. Group 6 or Group P Control Element Assemblies. Operate CEAs in Manual Group mode as follows:  
6.7.1 Verify Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer.
 
6.7.2 Position Group Select switch to desired group.
====6.7.1 Verify====
6.7.3 Place Mode Select switch to MG and verify the following:  White lights Illuminated on Group Selection Matrix for selected group  MG light Illuminates 6.7.4 Operate CEA Manual Shim switch to INSERT group to desired height while monitoring the following:  CEA Position Indicator selected CEA group is moving in desired direction  If Reactor is critical, then monitor the following:  Reactor Power  Reactor Coolant System (RCS) temperature  Axial Shape Index (ASI)
Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer.  
 
====6.7.2 Position====
Group Select switch to desired group.  
 
====6.7.3 Place====
Mode Select switch to MG and verify the following:  White lights Illuminated on Group Selection Matrix for selected group  MG light Illuminates  
 
====6.7.4 Operate====
CEA Manual Shim switch to INSERT group to desired height while monitoring the following:  CEA Position Indicator selected CEA group is moving in desired direction  If Reactor is critical, then monitor the following:  Reactor Power  Reactor Coolant System (RCS) temperature  Axial Shape Index (ASI)
NOTE The Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when the Mode Select switch is not in OFF.
NOTE The Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when the Mode Select switch is not in OFF.
6.7.5 When desired set of moves have been completed, then place Mode Select switch to OFF.
6.7.5 When desired set of moves have been completed, then place Mode Select switch to OFF.

Revision as of 01:21, 14 October 2018

Waterford-2010-10-Final Operating Test
ML103080004
Person / Time
Site: Waterford Entergy icon.png
Issue date: 11/04/2010
From: Apger G W
Operations Branch IV
To:
Entergy Operations
References
50-382/10-302, ES-301, ES-301-1 50-382/10-301
Download: ML103080004 (211)
v • d • e


Text

ES-301 Administrative Topics Outline Form ES-301-1 NRC Revision 1 Facility: WATERFORD 3 Date of Examination: October 4, 2010 Examination Level:

SRO Operating Test Number: NRC Administrative Topic (see Note)

Type Code* Describe activity to be performed A1 Conduct of Operations K/A Importance:

4.4 S, N 2.1.23, Ability to perform specific system and integrated plant procedures during all modes of plant operation. Review and approve completed OP-903-117, Emergency Diesel Generator Fuel Oil Transfer Pump Operability Check, Attachment 10.1, Fuel Oil Transfer Pump A IST Data.

A2 Conduct of Operations K/A Importance:

4.6 S, M 2.1.20, Ability to interpret and execute procedure steps. Review COLSS constant calculation in accordance with OP-004-005, Core Operating Limits Supervisory System Operation A3 Equipment Control K/A Importance:

4.7 S, N 2.2.40, Ability to apply Technical Specifications for a system. Evaluate Safety Injection System voiding in accordance with OP-903-026, Emergency Core Cooling System Valve Lineup Verification.

A4 Radiation Control K/A Importance:

3.8 S, D, P 2.3.6, Ability to approve release permits. Review and approve a liquid release permit in accordance with OP-007-001, Boron Management.

A5 Emergency Plan K/A Importance:

4.6 S, M 2.4.41, Knowledge of the emergency action level thresholds and classifications. Determine appropriate Emergency Plan action level in accordance with EP-001-001, Recognition and Classification of Emergency Conditions.

NOTE: All items (5 total are required for SROs. RO applicants require only 4 items unless they are retaking only the administrative topics, when 5 are required.

  • Type Codes & Criteria: (C)ontrol room, (S)imulator, or Class(R)oom (D)irect from bank ( 3 for ROs; 4 for SROs & RO retakes) (N)ew or (M)odified from bank ( 1) (P)revious 2 exams ( 1; randomly selected)

Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

A1 Review Completed Surveillance for Approval

Applicant:

Examiner:

JPM A1 JOB PERFORMANCE MEASURE DATA PAGE Task: Review and approve surveill ance OP-903-117, Emergency Diesel Generator Fuel Oil Transfer Pump Operability Check.

Task Standard:

Applicant's review discover ed 3 errors, and the applicant correctly evaluated Tech Specs as identified in the key.

References:

OP-903-117, Emergency Diesel Generator Fuel Oil Transfer Pump Operability Check Time Critical:

No Validation Time:

15 mins. K/A 2.1.23, Ability to perform specif ic system and Importance Rating

4.4 integrated

plant procedur es during all modes of plant operation.

Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 5 2010 NRC SRO Exam JPM A1 Revision 1 Page 3 of 5 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-903-117, Emergency Diesel Generator Fuel Oil Transfer Pump Operability

Check

==

Description:==

This JPM is performed in the simulator, but use of the simulator is not required. The applicant will be given a completed OP-903-117, Attachment 1 for EDG Fuel Oil Transfer Pump A. The key indicates the errors that the applicant must identify. One of the errors will make EDG Fuel Oil Transfer Pump A inoperable. The applicant will be

required to identify the correct Tech Spec.

READ TO APPLICANT

DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any

other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then

give the cue sheet to the applicant.

JPM A1 Revision 1 Page 4 of 5 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD Review Attachment 10.1 for accuracy.

The following errors must be identified:

  • The vibration meter and probe are past their calibration dates.
  • Pump differential pressure was calculated incorrectly. The

corrected pressure is below the low limit of 70.7 PSID.

  • The flow calculation for EGF-109 A, Fuel Oil Transfer

Pump A Discharge Check, was performed incorrectly.

The corrected flow is greater than the required 30 gpm.

  • Test Results should be checked as "Required Action".

This is not critical.

Comment: Critical SAT / UNSAT TASK ELEMENT 2 STANDARD Determine applicable Tech Spec

associated with EDG Fuel Oil Transfer

Pump A being inoperable.

Tech Spec 3.8.1.1 b and d must be entered.

Actions include:

  • Restore EDG A within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD

SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

  • Restoration within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> may be extended to 10 days if

a temporary emergency diesel generator is verified

available.

  • Complete OP-903-066, Electrical Breaker Alignment

Check, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, and at least every 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter.

The following must be satisfied within 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />s:

  • All required systems, subsystems, trains, components, and devices that depend on the remaining OPERABLE

diesel generator as a source of emergency power must be

OPERABLE

Comment:

Critical SAT / UNSAT END OF TASK

JPM A1 Revision 1 Page 5 of 5 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

Emergency Diesel Generator A Fuel Oil Transfer Pump IST has been completed in accordance with OP-903-117, Emergency Diesel Generator Fuel Oil Transfer Pump Operability Check. The completed attachment for the surveillance has been reviewed and is ready for SM/CRS review.

INITIATING CUES:

Review the attachment and provide any comments on this sheet

Hf q STEP 10.1 FUEL OIL TRANSFER PUMP A 1ST DATA PERMISSION:

C*e/0/sf/La/a 07oo WONUMBER: 52233?/71.1 (SM/C S Signature)(Elate/time)

Reference Data Run (Check one)[]YES[v}'NO STEP INSTRUMENT NUMBER I SCALE/CAL.

RANGE*CAL DUE DATE*Fuel Oil Transfer Pump A EG F-IDPI-0638A Recirc Flow Indicator Millivolt PMC PID A60501 Suction Press otr353 0Z9-30 7.1.1 Discharge Press or 33 eoa-(O-2oc'Vibration Meter 5 Zo.o//o/.'c, Vibration Probe mnt,vrf 3$?002-c-'2..eoo f/.*/o Stopwatch 357 OZa J/4*May be NIi'.for plant installed instruments or plant monitoring computer points, if no'applicable.

OP-903-1 17 Revision 304 Attachment 10.1 (1 of 5)24 FUEL OIL TRANSFER PUMP A iST DATA (CONT'D)PUMP ACCEPTANCE CRITERIA PARAMETER Recirc Differential Pressure (PSID)Outboard Bearing Vibration (IN/SEC)Suction Press (PSIG)Pump Differential Press (PSID)Test gage at EGF-1 08A Disch-Suct OP-903-1 17 Revision 304 Attachment 10,1 (2 of 5)STEP POINT DATA EG Fl DPIO63BA 7.1.13 ACCEPTABLE 55.5-56.5 ALERT HIGH 3V V0.080 Inboard Bearing Vibration (IN/SEC)3H V0,068 REQUIRED ACTION LOW I HIGH 4V 4H o.o2.2-o.o1-1 0.080<V 0.192 0.068<V 0.162 V0.048 Disch Press (PSIG)Test gage at EGF-11OA 837 V0.043 7.1.13.1 0.048<V 0,114 0.043<V 0.102 V>0.192 V>0.162 V>0.114 V>0 102 70.7zP 86.5 RESTORATION tP<70.7 P>86.5 eJo'Low REQUIRED PERFORMED IV BY STEP COMPONENT POSITION BY (Initials)(Initials) 7,1.16.1 EGF-1 1 1A, FUEL OIL TRANSFER PUMP A DISCHARGE ISOLATION LOCKED OPEN EGF-1092A, FUEL OIL TRANSFER PUMP A RECIRC EGFIDPIO638A HP RT CLOSED 7.1.17.1 EGF-1093A, FUEL OIL TRANSFER PUMP A RECIRC EGFIDPIO638A LP RT CLOSED 7.1.18.1 EGF-1 091A, FUEL OIL TRANSFER PUMP A RECIRC ISOLATION LOCKED OPEN 7.1.19.1 All test instruments.

REMOVED 25 FUEL OIL TRANSFER PUMP A I ST DATA (CONT'D)STEP PARAMETER POINT DATA 7.1.23 Starting Millivolt Value PIDA6O5O1'7/25 7.1.26 Ending Millivolt Value PIDA6O5O1 7.1.26 Elapsed Time (Minutes)Stopwatch/*4/',.i., RESTORATION REQUIRED PERFORMED IV BY STEP COMPONENT POSITION BY (Initials)(Initials)

EGF-123A, EG A FUEL OIL INJECTOR DRAIN HEADER ISOLATION LOCKED OPEN 7.1.29.1 7.1.28.1 EGF1 22A, EG A FEED TK OUTLET ISOL TO F.O.GRAVITY DRAIN HDR LOCKED CLOSED EGF-124A, EG A FUEL OIL INJECTOR DRAIN HEADER ISOLATION LOCKED OPEN 7.1.30.3.1 EGF-103A.FUEL OIL STORAGE TANK A FILL TOTALIZER BYPASS CLOSED.OP-903-1 17 Revision 304 STEP ACTION INITIAL 7.1.31 Instrument information recorded on Work Order.I--Attachment 10.1 (3 of 5)di 26 Al kc 7 1 32 2-Gals Millivolt Change==Gallons Pumped 18.1 mV/Gal 18.1 7,132.3 FLOW==GPM STEP 1>VALVE ACCEPTANCE CRITERIA I TEST RESULTS INITIAL 7 1 33 Calculated Flow (Step 7.1.32.3)>30 GPM verifies operability of[-fAT[]UNSAT[J N/A*I Fuel Oil Transfer Pump A Discharge Check, EGF-109A.,, (1)May be N/A if performing check valve performance monitoring.

TEST RESULTS (check one)ptable lert (Submit Work Request to perform another Operability surveillance within six weeks and write a CR to double testing frequency.

tCR-WF3-2008-05882])

WR No.__________________

CR No.___________________

El Required Action (Declare pump Inoperable)(WR and CR must be initiated)

WR No.__________________

CR No.___________________

El Reference Data Run (Results to be evaluated by Programs Engineering)

OP-903-1 17 Revision 304 Attachment 10.1 (4 of 5)FUEL OIL TRANSFER PUMP A 1ST DATA (coNT'D)DATA us'27 Al Ky FUEL OIL TRANSFER PUMP A 1ST DATA (coNT'D)REMARKS: STEP ACTION INITIAL[7.1.36 Copy of 1ST Data submitted to P.E.1ST Coordinator.

I O;7Rc.s-r?'/(Date)/o,//zofo (nate)OP-903-1 17 Revision 304 Attachment 10.1 (5 of 5)(Signatu)Performed by: IV by: Independent Reviewed by: SM/CRS Review:;i;:4a t',L 0 (Signature F (Signature)(Signature)

I (Date/Time) 28 10.1 FUEL OIL TRANSFER PUMP A 1ST DATA STEP PERMISSION:

/0/SF/Lob 0'1o WONUMBER: 7.1.1 (SM/CfS Signature)(L3'ate/time)

Reference Data Run (Check one)[}YES[i4NO Fuel Oil Transfer Pump A Recirc Flow Indicator If (Discharge Press 3ç0 Vibration Meter 5 Lo.o fi;?/°/.e/o Vibration Probe mf,1r.ff357ool-c_zoooft ,J/4*May be N/i for plant installed instruments or plant monitoring computer points, if fapplicable.

OP-903-1 17 Revision 304 Attachment 10.1 (1 of 5)STEP INSTRUMENT NUMBER Millivolt 7.1.1 EGF-IDPI-0638A Suction Press SCALEICAL.

RANGE*CAL DUE DATE*PMC PID A60501 orirr353 oz c'-3o Stopwatch/1//c/zo/0 24 FUEL OIL TRANSFER PUMP A 1ST DATA (00NT'D)ACCEPTABLE ALERT HIGH REQUIRED ACTION LOW HIGH 55.5-56.5 WA WA WA V 0.080 0.080<V 0.192 IA V>0.192 V0,068 0.068<V0.162 V>0.162 0.048<V 0.114 V>0.114 O.043cV0.102 NJA V>0.102 NIA NIA N!A WA IJIh i iIIiiI IIa*707AP865 iXP<707 1P>865 V S 0.048 V 0.043 RESTORATION REQUIRED PERFORMED IV BY STEP COMPONENT POSITION BY (Initials)(Initials) 7.1.16.1 EGF-111A, FUELOILTRANSFER PUMPA DISCHARGE ISOLATION LOCKEDOPEN EGF-1092A, FUEL OIL TRANSFER PUMP A RECIRC EGFIDPIO638A HP RT CLOSED 7.1.1 7.1 EGF-1093A, FUEL OIL TRANSFER PUMP A RECIRC EGFIDPIO638A LP RT CLOSED 7.1.18.1 EGF-1091A, FUEL OIL TRANSFER PUMP A RECIRC ISOLATION LOCKED OPEN 7.1.19.1 All test instruments.

REMOVED OP-903-117 Revision 304 Attachment 10.1 (2 of 5)STEP PARAMETER POINT DATA Recirc Differential Pressure (PSID)EGFIDPIO638A Inboard Bearing Vibration (IN/SEC)PUMP ACCEPTANCE CRITERIA 7.1.13 5", 3V 3H 4V o.o2.2-Outboard Bearing Vibration (INISEC)4H Disch Press (PSIG)Test gage at EGF-1 1OA Suction Press (PSIG)7.1.13.1 83.7 Test gage at EGF-1 08A Pump Differential Press (PSID)r.S Disch-Suet 25 FUEL OIL TRANSFER PUMP A 1ST DATA (coNT'D)STEP PARAMETER POINT DATA 7.1.23 Starting Millivolt Value PIDA6O5O1 7.1.26 Ending Millivolt Value PIDA6O5O1 7.1.26 Elapsed Time (Minutes)Stopwatch//'F1 RESTORATION REQUIRED PERFORMED IV BY STEP COMPONENT POSITION BY (Initials)(Initials)

EGF-123A, EG A FUEL OIL INJECTOR DRAIN HEADER ISOLATION LOCKED OPEN 7.1.29.1 7.1.28.1 EGF-122A, EG A FEED TK OUTLET ISOL TO F,O, GRAVITY DRAIN HDR LOCKED CLOSED EGF-124A, EG A FUEL OIL INJECTOR DRAIN HEADER ISOLATION LOCKED OPEN 7.1.30.3.1 EGF-103A, FUEL OIL STORAGE TANK A FILL TOTALIZER BYPASS CLOSED STEP ACTION INITIAL 7.1.31 Instrument information recorded on Work Order.F-Attachment 10.1 (3 of 5)OP-903-1 17 Revision 304 26 FUEL OIL TRANSFER PUMP A 1ST DATA (coNT'D)STEP ACTION DATA STEP j VALVE ACCEPTANCE CRITERIA I TEST RESULTS INITIAL I 7 1 33 Calculated Flow (Step 7.1.32.3)>30 GPM verifies operability of[L-1AT[]UNSAT[]N/A*I Fuel Oil Transfer Pump A Discharge Check, EGF-109A.-.(1)May be N/A if not performing check va[ve performance monitoring.

STEP TEST RESULTS (check one)INITIAL AcceptabIe El Alert (Submit Work Request to perform another Operability surveillance within six weeks and write a CR to double testing frequency.

[CR-WF3-2008-05882])

7.1.33 WR No.CR No.l Required Action (Declare pump Inoperable)(WR and CR must be initiated)

WR No.CR No.El Reference Data Run (Results to be evaluated by Programs Engineering)

OP-903-1 17 Revision 304 Attachment 10.1 (4 of 5)End (Step 7.1.26)7.1.32.1 Millivolt-=o'513-732-//?8 Change Start (Step 7.1.23)End Start Gals Millivolt Change/198=2._Gallons 7.1.32.2 Pumped=18.1 mV/Gal-18.1 7.1.32.3 FLOW Gals Pumped--GPM Elapsed Time-/y 27 FUEL OIL TRANSFER PUMP A 1ST DATA (cONT'D)STEP ACTION INITIAL 7.1.36 Copy of 1ST Data submitted to P.E.1ST Coordinator.

REMARKS:___________________________________

Performed by:'%L_________(Signatu e)/(Date)IV by:"Signature Independent Reviewed by: (Signature)

(ate)SM/CRS Review:___________________________

I (Signature)(Date/Time)

OP-903-117 Revision 304 Attachment 10.1 (5 of 5)28 Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

A2 Review COLSS Constant Calculation in accordance with OP-004-005, Core Operating Limits Supervisory System Operation

Applicant:

Examiner:

JPM A2 JOB PERFORMANCE MEASURE DATA PAGE Task: Review COLSS constant calculation in accordance with OP-004-005, Core Operating Limits Supervisory System Operation

Task Standard:

Applicant identified errors as identified in the key for Attachment 11.6, Calculation of Charging and Letdown Parameters.

References:

OP-004-005, Core Operating Limits Supervisory System Operation Time Critical:

No Validation Time:

15 mins. K/A 2.1.20, Ability to interpret and execute. Importance Rating

4.6 procedure

steps Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 6 2010 NRC SRO Exam JPM A2 Revision 1 Page 3 of 6 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

Simulator / Plant Monitoring Computer OP-004-005, Core Operating Limits Supervisory System Operation

==

Description:==

This JPM is performed in the simulator and use of the Plant Monitoring Computer is required. The applicant will be given a co mpleted OP-004-005, Attachment 11.6 for COLSS Charging and Letdown Constants. The key identifies errors that the applicant must identify. There will be a combinati on of data collection and procedure execution errors.

READ TO APPLICANT

DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any

other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then

give the cue sheet to the applicant.

JPM A2 Revision 1 Page 4 of 6 2010 NRC SRO Exam Evaluator Note Provide the completed Attachment 11.6 on colored paper to the applicant.

TASK ELEMENT 1 STANDARD Review Attachment 11.6 for accuracy.

The following errors must be identified:

  • The data collected for PMC point A39103 was incorrect.

307.0 °F from point A39104 was recorded vice 354.38

°F. This affects the value of step 11.6.2.1. The correct

value for step 11.6.2.1 is 329.0484.

  • Step 11.6.2.2 was calculated incorrectly. The

parentheses were not used properly when the

calculation was performed. The correct value for step

11.6.2.2 is 43705.72.

  • Step 11.6.2.4 was calculated incorrectly. The value

0.000031 was entered with too few characters. The

correct value for step 11.6.2.4 is 0.021127.

Comment: Critical SAT / UNSAT

END OF TASK

JPM A2 Revision 1 Page 5 of 6 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

Plant conditions are as you see on the Simula tor. Use of the Simulator, RM-11, and Plant Monitoring Computer is acceptable.

You are not allowed to use any network computers.

Plant configuration was changed from 1 Char ging Pump running to 2 Charging Pumps running.

You are the CRS and have been given a comple ted Attachment 11.6, Calculation of Charging and Letdown Parameters, from OP-004-005, Core Operating Limits

Supervisory System Operation, to review.

Perform this review and mark any comments on this sheet.

JPM A2 Revision 1 Page 6 of 6 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-190

After all simulator generated alarms are clear, place the simulator in FREEZE.

Verify the parameters on the PMC match the values on the key.

OP-004-005 Revision 020Attachment 11.6 (1 of 2) 3511.6 CALCULATION OF CHARGING AND LETDOWN PARAMETERS(typical)Plant Power 100%NOTE If PMC point is not available, then use alternate indication and document indications used inRemarks.11.6.1 Record the following data:STEPPARAMETERPMC PID VALUEUNITS 11.6.1.1RCS Pressure A122052247.1 PSIA 11.6.1.2Charging Flow C2624587.6 GPM 11.6.1.3Charging Temperature A39103354.8 F 11.6.1.4Charging PumpDischarge Temperature A39102114.9 F 11.6.1.5RCS Loop 2B T Cold A12120543.3 F11.6.2 Perform the following calculations:329.048411.6.2.1 Charging Enthalpy (K24215)= [1.0705 x (Step 11.6.1.3)] 50.765=BTU/lbm43705.7211.6.2.2 Charging Flow (K24214)= (Step 11.6.1.2) x 8.02 .015615 + [0.000004 x (Step 11.6.1.4)]

=lbm/hr538.74311.6.2.3 Letdown Enthalpy (K24203)= [1.2555 x (Step 11.6.1.5)] 143.37=BTU/lbm0.02112711.6.2.4 Letdown SpecificVolume= .004285 + [0.000031 x (Step 11.6.1.5)]

=Ft 3/lbm43705.7211.6.2.5 Letdown Flow (K24202)= (Step 11.6.2.2)

=Lbm/hr OP-004-005 Revision 020Attachment 11.6 (1 of 2) 3511.6 CALCULATION OF CHARGING AND LETDOWN PARAMETERS(typical)Plant Power 100%NOTE If PMC point is not available, then use alternate indication and document indications used inRemarks.11.6.1 Record the following data:STEPPARAMETERPMC PID VALUEUNITS 11.6.1.1RCS Pressure A122052247.1 PSIA 11.6.1.2Charging Flow C2624587.6 GPM 11.6.1.3Charging Temperature A39103307.0 F 11.6.1.4Charging PumpDischarge Temperature A39102114.9 F 11.6.1.5RCS Loop 2B T Cold A12120543.3 F11.6.2 Perform the following calculations:277.878511.6.2.1 Charging Enthalpy (K24215)= [1.0705 x (Step 11.6.1.3)] 50.765=BTU/lbm44992.1211.6.2.2 Charging Flow (K24214)= (Step 11.6.1.2) x 8.02 .015615 + [0.000004 x (Step 11.6.1.4)]

=lbm/hr538.74311.6.2.3 Letdown Enthalpy (K24203)= [1.2555 x (Step 11.6.1.5)] 143.37=BTU/lbm0.17270811.6.2.4 Letdown SpecificVolume= .004285 + [0.000031 x (Step 11.6.1.5)]

=Ft 3/lbm44992.1211.6.2.5 Letdown Flow (K24202)= (Step 11.6.2.2)

=Lbm/hr Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

A3 Evaluate Low Pressure Safety Injection Train B Operability

Applicant:

Examiner:

JPM A3 JOB PERFORMANCE MEASURE DATA PAGE Task: Evaluate the operability of Low Pr essure Safety Injection Train B during the performance of OP-903-026, Emergency Core Cooling System Valve Lineup Verification.

Task Standard:

Applicant determined the total gas volume for each of the 2 penetrations and determined that LPSI Train B became inoperable after the void was discovered at SI-134 B.

References:

OP-903-026, Emergency Co re Cooling System Valve Lineup Verification Time Critical:

No Validation Time:

15 mins. K/A 2.2.40, Ability to apply Tec hnical Importance Rating

4.7 Specifications

for a system Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 5 2010 NRC Walk Through Exam JPM A3 Revision 1 Page 3 of 5 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-903-026, Emergency Core Cooling System Valve Lineup Verification

==

Description:==

This JPM is performed in the simulator, but use of the simulator is not required. The applicant will be provided information describing the results of surveillance OP-903-026, Emergency Core Cooling System Valve Lineup Verification and will be required to

evaluate void size to determine what the to tal gas volume was in the 2 locations of importance. The applicant will also be requi red to determine when in the testing sequence Low Pressure Safety Injection Train B became inoperable.

READ TO APPLICANT

DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any

other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then

give the cue sheet to the applicant.

JPM A3 Revision 1 Page 4 of 5 2010 NRC SRO Exam Evaluator Note The simulator is not required for this JPM. Provide the applicant with the colored cue sheet.

TASK ELEMENT 1 STANDARD A. What was the total gas volume applicable to each of the 2 penetrations?

Penetration 36, for SI-1412 B and SI-133 B = 1.71 ft 3 Penetration 37, for SI-1402 B

and SI-134 B = 1.459 ft 3 Comment: Critical SAT / UNSAT TASK ELEMENT 2 STANDARD B. At what point in the sequence did Low Pressure Safety Injection Train B become inoperable, if any?

After the void was discovered

at SI-134 B.

Comment: Low Pressure Safety Injection Train B remained operable after SI-1412 B, SI-1402 B and SI-133 B voids were discovered. Low Pressure Safety

Injection Train B was required to be declared

inoperable after the void was discovered at SI-134 B.

After step 3 of the listed sequence, the total gas volume for SI-1412 B and SI-133 B was 1.71 ft 3 , less than the limit of 1.802 ft 3 for that penetration.

After step 4 of the above sequence, the total gas

volume for SI-1402 B and SI-134 B was 1.459 ft 3 , above the limit of 1.229 ft 3 for that penetration.

Critical SAT / UNSAT END OF TASK

JPM A3 Revision 1 Page 5 of 5 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)

OP-903-026, Emergency Core Cooling System Va lve Lineup Verification, is in progress.

The RCA Watch has discovered voids duri ng the performance of the surveillance. After each void was discovered, actions were taken to fill that line before moving to the next location. The RCA Watch called in the following results in the order listed:

1. SI-1412 B, RC Loop 1A FCV Downstream Vent 9 inch arc
2. SI-1402 B, LPSI Header to RC Loop 1B FCV Downstream Vent 8 inch arc
3. SI-133 B, LPSI Pump B Discharge to RC Loop 2B Vent 10 inch arc
4. SI-134 B, RC Loop 1 SHDN Cooling Warm-up Line Vent 7 inch arc

A. What was the total gas volume applicable to each of the 2 penetrations?

B. At what point in the sequence did Low Pr essure Safety Injection Train B become inoperable, if any?

Record answers on this sheet.

A.

B.

Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

A4 Review a Liquid Release Permit

Applicant:

Examiner:

JPM A4 JOB PERFORMANCE MEASURE DATA PAGE Task: Review and approve a liquid release permit in accordance with OP-007-001, Boron Management.

Task Standard:

Applicant identified errors in the permit according to the key.

References:

OP-007-001, Boron Management CE-003-514, Liquid Radioactive Release Permit

EC-M84-001 Time Critical:

No Validation Time:

20 mins. K/A 2.3.6, Ability to approve releas e permits Importance Rating

3.8 Applicant

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 6 2010 NRC SRO Exam JPM A4 Revision 1 Page 3 of 6 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-007-001, Boron Management EC-M84-001

==

Description:==

This JPM is performed in the simulator and use of the Plant Monitoring Computer and the RM-11 Radiation Monitoring Computer is required. The applicant will be given a release permit for Boric Acid Condensate Tank B to authorize. The key identifies errors that the applicant must identif

y. There will be a combination of data collection errors from both the PMC and RM-11.

There are also plant conditions that are not properly

reflected in the permit. The applicant will be able to gather this information from the

control panel alignment.

READ TO APPLICANT

DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any

other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.

JPM A4 Revision 1 Page 4 of 6 2010 NRC SRO Exam Evaluator Note Provide the Boric Acid Condensate Tank B Release Permit, printed on colored paper, to the applicant.

TASK ELEMENT 1 STANDARD Review the Boric Acid Condensate Tank

B Release Permit for accuracy.

All of the following errors must be identified:

  • The data collected for Boric Acid Condensate Tank B

was incorrect. The level for Waste Condensate Tank B

was recorded instead. The tank percent and tank

volume in gallons reflect the level in Waste Condensate

Tank B.

  • The permit list that 4 Circulating Water Pumps are

running, but only 3 are running.

  • The setpoint loaded into the RM-11 computer for the

Boric Acid Condensate Radiation Monitor is reading 8.0

e-02 uCi/ml vice 6.50 e-01. This reading must be

verified from the RM-11 computer.

  • The Boric Acid Condensate Radiation Monitor is listed

as PRM-IRE-0647 on various locations of the permit.

The correct UNID number is PRM-IRE-0627 (this is not

critical).

Comment: Critical SAT / UNSAT END OF TASK

JPM A4 Revision 1 Page 5 of 6 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

Plant conditions are as you see on the Simula tor. Use of the Simulator, RM-11, and Plant Monitoring Computer is acceptable.

You are not allowed to use any network computers.

Boric Acid Condensate Tank B is ready to be released and the Release Permit is in the

Control Room for your review.

Review the Release Permit and provide any comments on this sheet.

JPM A4 Revision 1 Page 6 of 6 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS

Reset to IC-190

After all simulator generated alarms are clear, place the simulator in FREEZE.

Verify the parameters on the PMC and R M-11 match the values on the key.

Key for A4 R Type K2.33 Liquid Waste batch Release Permit Permit Number: LB2010-0062 Entergy Operations, Inc. Waterford Steam Electric Station Unit III Release Point (1) : Boric Acid Condensate Tank B Waste Volume

13,968 gal Maximum Waste Flow: 50.00 gpm Minimum Dilution Flow
5.00 e+5 gpm (2 Circ Water Pumps) Total Gamma Conc. : 1.04e-05 uCi/ml SINGLE Release Setpoint for PRM-IRE-0627 6.50 e-03 uCi/ml *** ADJUST ***
    • Concurrent with Permit Number LC2009-0043 : (22) Dry Cooling Tower Sump #1 to Circ Water
    • Concurrent with Permit Number LC2009-0044 : (23) Dry Cooling Tower Sump #21 to Circ Water
    • Concurrent with Permit Number LC2009-0045 : (24) TGB Industrial Waste Sump to Circ Water Estimated Maximum Organ Dose: 0.00 mrem for the Adult Thyroid Estimated Cumulative Maximum Organ Doses - Including this release.

31 Day Quarter - To - Date Year - To - Date Limit 0.06 mrem 1.50 mrem 3.00 mrem Organ Total Body Total Body Total Body 0.000 mrem 0.00 mrem 0.0029 mrem Special Conditions : Adjust PRM-IRE-0627 radiation monitor setpoint 6.50 e-03 uCi/ml prior to release.

PRM-IRE-0627 setpoint to 8.00 e-02 uCi/ml after release permit is closed.

Prepared By:

Reviewed By:

Approved By: S. Chemist C. Supervisor Date: 10/5/2010 Date: 10/5/2010 Date: PRM-IRE-0627 Radiation Monitor Source Check:

Channel Check:

Circ. Water Flowrate:

gpm Date Time Tank Level % Flow Integrator (gal) Release Start Release Finish

  • NET
  • min. gal / min = gpm = Average Waste Flow Rate (Flow Integrator)

(Release Time) gal / min = gpm = Average Waste Flow Rate (Plant Data Book)

(Release Time)

Radiation Monitor Readings for PRM-IRE-0627 10 minutes into release:

uCi/m l After Flush: uCi/ml Remarks: Release Completed By: Date / Time Operations Release Reviewed By:

Date / Time CRS / SM Release Reviewed By:

Date / Time HP Forman / Designee Key for A4 R Type K2.33 Liquid Waste batch Release Permit Permit Number: LB2010-0062 Entergy Operations, Inc. Waterford Steam Electric Station Unit III Release Point (1) : Boric Acid Condensate Tank B Waste Volume

14,718 gal Maximum Waste Flow: 50.00 gpm Minimum Dilution Flow
5.00 e+5 gpm (2 Circ Water Pumps) Total Gamma Conc. : 1.04e-05 uCi/ml SINGLE Release Setpoint for PRM-IRE-0647 6.50 e-03 uCi/ml *** ADJUST ***
    • Concurrent with Permit Number LC2009-0043 : (22) Dry Cooling Tower Sump #1 to Circ Water
    • Concurrent with Permit Number LC2009-0044 : (23) Dry Cooling Tower Sump #21 to Circ Water
    • Concurrent with Permit Number LC2009-0045 : (24) TGB Industrial Waste Sump to Circ Water Estimated Maximum Organ Dose: 0.00 mrem for the Adult Thyroid Estimated Cumulative Maximum Organ Doses - Including this release.

31 Day Quarter - To - Date Year - To - Date Limit 0.06 mrem 1.50 mrem 3.00 mrem Organ Total Body Total Body Total Body 0.000 mrem 0.00 mrem 0.0029 mrem Special Conditions : Adjust PRM-IRE-0647 radiation monitor setpoint to 6.50 e-03 uCi/ml prior to release.

PRM-IRE-0647 setpoint to 8.00 e-02 uCi/ml after release permit is closed.

Prepared By:

Reviewed By:

Approved By: S. Chemist C. Supervisor Date: 10/5/201 0 Date: 10/5/2010 Date: PRM-IRE-0647 Radiation Monitor Source Check:

Channel Check:

Circ. Water Flowrate:

gpm Date Time Tank Level % Flow Integrator (gal) Release Start Release Finish

  • NET
  • min. gal / min = gpm = Average Waste Flow Rate (Flow Integrator)

(Release Time) gal / min = gpm = Average Waste Flow Rate (Plant Data Book)

(Release Time)

Radiation Monitor Readings for PRM-IRE-0647 10 minutes into release:

uCi/m l After Flush: uCi/ml Remarks: Release Completed By: Date / Time Operations Release Reviewed By:

Date / Time CRS / SM Release Reviewed By:

Date / Time HP Forman / Designee

Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

A5 Classify Emergency Plan Entry Level

Applicant:

Examiner:

JPM A5 JOB PERFORMANCE MEASURE DATA PAGE Task: Classify Emergency Plan Entry Level

Task Standard:

Applicant determined corre ct Emergency Plan class and initiating condition.

References:

EP-001-001 Recognition and Classification of Emergency Conditions Time Critical:

No Validation Time:

15 mins. K/A 2.4.41, Knowledge of the emergency action Importance Rating

4.6 level

thresholds and classifications.

Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 6 2010 NRC SRO Exam JPM A5 Revision 1 Page 3 of 6 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

EP-001-001 Recognition and Classification of Emergency Conditions

==

Description:==

This JPM is performed in the simulator and use of the Plant Monitoring Computer and the RM-11 Radiation Monitoring Computer is required. The applicant will be given plant

conditions and directed to make the appropriate Emergency Plan class and initiating

condition. The applicant will have to get data off of the RM-11 or Plant Monitoring computers to properly classify the event.

READ TO APPLICANT

DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any

other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then

give the cue sheet to the applicant.

JPM A5 Revision 1 Page 4 of 6 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD Determine the correct Emergency Plan class and initiating condition.

Applicant declares an Alert based on initiating

condition AA1, any UNPLANNED release of

gaseous or liquid radioactivity to the

environment that exceeds 200 times the

radiological effluent ODCM limits for > 15

minutes, Emergency Action Level 2.

Comment: PLANT STACK Wide Range Gas Monitor PRM-IRE-0110, RE0110-4 will read > 1.51E+07 uCi/sec, the

Alert classification limit. It will be less than the Site

Area Emergency limit of 2.55E+08 uCi/sec.

Plant Stack PIG Gas Channels, PRM-IRE-0100.1S or 2S, RE0100.1-1 or RE0100.2-1 will be > 3.45E-03

uCi/cc, the Unusual Event criteria. There is no criteria

to upgrade from an Unusual Event to an Alert based

on either Plant Stack PIG Gas Channel.

Critical SAT / UNSAT

END OF TASK

JPM A5 Revision 1 Page 5 of 6 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

Plant conditions are as you see on the Simula tor. Use of the Simulator, RM-11, and Plant Monitoring Computer is acceptable.

You are not allowed to use any network computers.

A failure of the Gaseous Waste System has occurred. Conditions are as displayed on

the simulator. These conditions have existed for 30 minutes.

You are the Shift Manager / Emergency Coordinator. Determine the appropriate

Emergency Plan class and initiating condition.

Mark all of your conclusions on this sheet.

JPM A5 Revision 1 Page 6 of 6 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS

Reset to IC-190

After all simulator generated alarms are clear, place the simulator in FREEZE.

Verify the parameters on the PMC match the values on the key.

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: WATERFORD 3 Date of Examination: October 4, 2010 Exam Level SRO - Instant Operating Test No.:

NRC Control Room Systems

@ (8 for RO); (7 for SRO-I); (2 or 3 for SRO-U, including 1 ESF) System / JPM Title Type Code* Safety Function S1 001 Control Rod Drive; ATC Operator Immediate Operator Actions on 2 Dropped CEAs from OP-901-102, CEA or CEDMCS Malfunction Fault: The first and second reactor trip options do not function, requires performance of the final reactor trip contingency from EOP OP-902-000, Standard Post Trip Actions. A2.13 ATWS RO - 4.4, SRO - 4.6 A, D, P, S 1 S2 004 Chemical and Volume Control System; Perform actions associated with a faulted Pressurizer level setpoint in accordance with OP-901-110, Pressurizer Level Control Malfunction. A2.22 Mismatch of Letdown and Charging flows RO - 3.2, SRO - 3.1 A, M, S 2 S3 006 Emergency Core Cooling System; Reduce RCS pressure and use High Pressure Safety Injection Pumps to restore Pressurizer level in accordance with OP-901-112, Charging or Letdown Malfunction. A1.18 PZR level and pressure RO - 4.0, SRO - 4.3 N, S 3 S4 005 Shutdown Cooling System; Place Shutdown Cooling Train B in Service Fault: After LPSI Pump B is running, SI-405 B will fail closed, requiring the operator to take immediate operator actions IAW OP-903-130, Shutdown Cooling Malfunction, to secure LPSI Pump B. A4.01 Controls and indication for RHR pumps RO - 3.6, SRO - 3.4 A, D, L, P, S 4 - P S5 062 A.C. Electrical Distribution, Synchronize the Main Generator to the grid in accordance with OP-010-004, Power Operations. Fault: Auto Synchronization will fail to function, requiring manual synchronizing of the Generator Output Breakers. A4.07 Synchronizing and paralleling of different AC supplies RO - 3.1, SRO - 3.1 A, N, S 6 S6 012 Reactor Protection System Reset CSAS in accordance with OP-902-009, Standard Appendices, Section 5 - E A4.04 Bistable, trips, reset and test switches RO - 3.3, SRO - 3.3 D, EN, L, P, S 7 S7. 068 Liquid Radwaste System; Discharge WCT A to the Circulating Water System in accordance with OP-007-004, Liquid Waste Management System Fault: Upon initiation of flow, controller fails in raise, exceeding maximum flow allowed, requiring the operator to manually close the isolation valves. A4.03 Stoppage of release if limits exceeded RO - 3.9, SRO - 3.8 A, M, S 9 1 NRC Revision 2 ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 In-Plant Systems

@ (3 for RO; 3 for SRO-I; 3 or 2 for SRO-U)

P1 061 Emergency Feedwater System; Reset overspeed device on Emergency Feedwater Pump AB in accordance with OP-902-005, Station Blackout Recovery. A2.04 Pump failure or improper operation RO - 3.4, SRO - 3.8 D, E, L, R 4 - S P2 008 Component Cooling Water System; Restore Power to the DCT Sump Pumps Following a Loss of Off Site Power in accordance with OP-902-009, Standard Appendices G2.4.34 Knowledge of RO tasks performed outside the main control room during an emergency and the resultant operational effects.

RO - 4.2, SRO - 4.1 D, R, E 8 P3 062 A.C. Electrical Distribution Transfer SUPS 014AB from Alternate to Normal AC Power in accordance with OP-006-005, Inverters and Distribution. Fault: After alignment, voltage will not be indicated on SUPS 014 AB inverter. A3.04 Operation of inverter RO - 2.7, SRO - 2.9 A, M 6 @ All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions; all 5 SRO-U systems must serve different safety functions; in-plant systems and functions may overlap those tested in the control room.

  • Type Codes Criteria for RO /

SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 6 (C)ontrol room (D)irect from bank 9 / 8 / 4 5 (E)mergency or abnormal in-plant 1 / 1 / 1 1 (EN)gineered safety feature - / - / 1 (control room system) 1 (L)ow-Power / Shutdown 1 / 1 / 1 3 (N)ew or (M)odified from bank including 1(A) 2 / 2 / 1 5 (P)revious 2 exams 3 / 3 / 2 (randomly selected) 3 (R)CA 1 / 1 / 1 2 (S)imulator 2 NRC Revision 2 ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: WATERFORD 3 Date of Examination: October 4, 2010 Exam Level SRO - Upgrade Operating Test No.:

NRC Control Room Systems

@ (8 for RO); (7 for SRO-I); (2 or 3 for SRO-U, including 1 ESF) System / JPM Title Type Code* Safety Function S1 S2 004 Chemical and Volume Control System; Perform actions associated with a faulted Pressurizer level setpoint in accordance with OP-901-110, Pressurizer Level Control Malfunction. A2.22 Mismatch of Letdown and Charging flows RO - 3.2, SRO - 3.1 A, M, S 2 S3 S4 S5 S6 012 Reactor Protection System Reset CSAS in accordance with OP-902-009, Standard Appendices, Section 5 - E A4.04 Bistable, trips, reset and test switches RO - 3.3, SRO - 3.3 D, EN, L, P, S 7 S7. 068 Liquid Radwaste System; Discharge WCT A to the Circulating Water System in accordance with OP-007-004, Liquid Waste Management System Fault: Upon initiation of flow, controller fails in raise, exceeding maximum flow allowed, requiring the operator to manually close the isolation valves. A4.03 Stoppage of release if limits exceeded RO - 3.9, SRO - 3.8 A, M, S 9 3 NRC Revision 2 ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 In-Plant Systems

@ (3 for RO; 3 for SRO-I; 3 or 2 for SRO-U)

P1 061 Emergency Feedwater System; Reset overspeed device on Emergency Feedwater Pump AB in accordance with OP-902-005, Station Blackout Recovery. A2.04 Pump failure or improper operation RO - 3.4, SRO - 3.8 D, E, L, R 4 - S P2 P3 062 A.C. Electrical Distribution Transfer SUPS 014AB from Alternate to Normal AC Power in accordance with OP-006-005, Inverters and Distribution. Fault: After alignment, voltage will not be indicated on SUPS 014 AB inverter. A3.04 Operation of inverter RO - 2.7, SRO - 2.9 A, M 6 @ All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions; all 5 SRO-U systems must serve different safety functions; in-plant systems and functions may overlap those tested in the control room.

  • Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 3 (C)ontrol room (D)irect from bank 9 / 8 / 4 2 (E)mergency or abnormal in-plant 1 / 1 / 1 1 (EN)gineered safety feature - / - / 1 (control room system) 1 (L)ow-Power / Shutdown 1 / 1 / 1 3 (N)ew or (M)odified from bank including 1(A) 2 / 2 / 1 3 (P)revious 2 exams 3 / 3 / 2 (randomly selected) 1 (R)CA 1 / 1 / 1 1 (S)imulator 4 NRC Revision 2 ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 5 NRC Revision 2 Description of Change Revision JPM S5, Procedure title was incorrect. Changed to OP-010-004, Power Operations.

1 JPM P2 replaced 2

Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

S1 ATC Immediate Operator Actions on 2 Dropped CEAs

Applicant:

Examiner:

JPM S1 JOB PERFORMANCE MEASURE DATA PAGE Task: ATC Immediate Operator Actions on 2 Dropped CEAs

Task Standard:

Applicant tripped the r eactor using 32 A and 32 B breakers in accordance with OP-902-000 and comp leted the ATC operator's Standard Post Trip Actions.

References:

OP-901-102, CEA or CEDMCS Malfunction OP-902-000, Standard Post Trip Actions Alternate Path:

Yes Time Critical:No Validation Time:

5 mins.

K/A 001 A2.13, ATWS Importance Rating 4.4 / 4.6 RO / SRO Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 8 2010 NRC SRO Exam JPM S1 Revision 1 Page 3 of 8 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

None

==

Description:==

Applicant will position himself as the AT C operator at CP-2. CEAs 3 and 14 will drop into the core. The applicant should notice the condition, announce the condition, and trip the reactor without direction.

The normal reactor trip pushbuttons will not function. The applicant should move to the first contingency and use the Diverse

Reactor Trip pushbuttons. One of these butt ons is faulted. The DRTS alarms will come in, but the CEA MG set load contactors will not open. The applicant should then move to the second contingency, and open both 32 Bu s Feeder breakers, and reclose them 5 seconds later. The task should be stopped after the applicant completes the immediate

operator actions for the ATC position.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will

provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.

Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then

give the cue sheet to the applicant.

JPM S1 Revision 1 Page 4 of 8 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is at 100% power.

INITIATING CUES:

Respond to conditions observed. Perform actions as required by the ATC operator.

JPM S1 Revision 1 Page 5 of 8 2010 NRC SRO Exam Evaluator Note

1. All of the listed steps are from OP-901-102, CEA or CEDMCS Malfunction, and OP-902-000, Standard Post Trip Actions, but the applicant is required to perform the listed steps from memory.
2. Direct simulator operator to initiate trigger 1 when ready to begin.

TASK ELEMENT 1 STANDARD D.1. Determines 2 CEAs have dropped, attempts to trip the reactor from CP-2 or CP-8 Pushes both reactor trip

pushbuttons on CP-2 or

CP-8. Comment: Trip pushbuttons are faulted and Reactor Trip Circuit Breakers will not open. Critical SAT / UNSAT TASK ELEMENT 2 STANDARD 1.a.1.2 Attempts to trip reactor using DRTS pushbuttons on CP-2.

Pushes both DRTS pushbuttons on CP-2.

Comment: 1 DRTS pushbutton is faulted and CEA MG set load contactors will not open. Critical SAT / UNSAT TASK ELEMENT 3 STANDARD 1.a.1.3 Open BOTH the following breakers for 5 seconds and close:

  • SST B32 FEEDER Opens SST A32 FEEDER

and SST B32 FEEDER

breakers for 5 seconds and

then re-closes both

breakers.

Comment: Evaluator: If applicant stops after re-closing the A and B 32 Feeder breakers, prompt him as the CRS to perform his Standard Post Trip

Actions. Critical SAT / UNSAT

JPM S1 Revision 1 Page 6 of 8 2010 NRC SRO Exam TASK ELEMENT 4 STANDARD 1. Determine Reactivity Control acceptance criteria are met: Check reactor power is dropping. Check startup rate is negative. Check less than TWO CEAs are NOT fully inserted.

Verifies listed parameters.

Comment:

Critical SAT / UNSAT TASK ELEMENT 5 STANDARD 3. Determine RCS Inventory Control acceptance criteria are met:

Check that the following conditions exist: Pressurizer level is 7% to 60% Pressurizer level is trending to 33% to 60% Check RCS subcooling is greater than or equal to 28 ºF.

Verifies listed parameters.

Comment:

Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 4. Determine RCS Pressure Control acceptance criteria are met by checking that BOTH of the following conditions exist: Pressurizer pressure is 1750 psia to 2300 psia Pressurizer pressure is trending to 2125 psia to 2275 psia Verifies listed parameters.

Comment:

Critical SAT / UNSAT

JPM S1 Revision 1 Page 7 of 8 2010 NRC SRO Exam TASK ELEMENT 7 STANDARD 5. Determine Core Heat Removal acceptance criteria are met: Check at least one RCP is operating. Check operating loop T is less than 13 ºF. Check RCS subcooling is greater than or equal to 28 ºF.

Verifies listed parameters.

Comment:

Critical SAT / UNSAT TASK ELEMENT 8 STANDARD 6.b. Determine RCS Heat Removal acceptance criteria are met: Check RCS T COLD is 530 ºF to 550 ºF Verifies listed parameters.

Comment:

Critical SAT / UNSAT TASK ELEMENT 9 STANDARD 7. Determine Containment Isolation acceptance criteria are met: Check containment pressure is less than 16.4 psia. Check NO containment area radiation monitor alarms OR unexplained rise in activity. Check NO steam plant activity monitor alarms OR unexplained rise in activity.

Verifies listed parameters.

Comment:

Critical SAT / UNSAT

END OF TASK

JPM S1 Revision 1 Page 8 of 8 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-195

Verify the following Malfunctions: No Trigger o rp01a, RPS manual pushbutton a

o rp01b, RPS manual pushbutton b

o rp01c, RPS manual pushbutton c

o rp01d, RPS manual pushbutton d Trigger 1:

o rd02a03, drop CEA 3

o rd02a14, drop CEA 14

Verify the following Overrides: No Trigger o di-02a06s02-1, DRT pushbutton 1 of 2

Coordinate with examiner to in itiate Trigger 1 on his cue.

Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

S2 Failed Pressurizer Level Control due to Failed RCS Cold Leg Temperature Instrument

Applicant:

Examiner:

JPM S2 JOB PERFORMANCE MEASURE DATA PAGE Task: Perform actions associated with a faulted Pressurizer level setpoint in accordance with OP-901-110, Pressurizer Level Control Malfunction.

Task Standard:

Faulted Reactor Coolant Co ld Leg temperature instrument RC-IT-0111 Y was identified and removed from service in accordance with OP-901-110.

References:

OP-901-110, Pressurizer Level Control Malfunction Alternate Path:

Yes Time Critical:No Validation Time:

15 mins. K/A 004 A2.22, Mismatch of Charging and Letdown Importance Rating 3.2 / 3.1 flows RO / SRO Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 9 2010 NRC SRO Exam JPM S2 Revision 1 Page 3 of 9 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-901-110, Pressurizer Level Control Malfunction

==

Description:==

The applicant will be positioned as the ATC oper ator to start this task. The JPM will start with RCS Cold Leg temperature in strument RC-ITI-0111-Y failed high. The

cue sheet will direct the applicant to match Charging and Letdown flow. This will be

accomplished at CP-2. After the applicant r eports that Charging and Letdown flows are matched and verifications made, the applicant will be directed to assume the role of the BOP operator and select the non-selected Cold Leg instrument. This is located behind

CP-2. This selection will not function, r equiring the applicant to remove the failed instrument from service at bot h Reactor Regulating drawers.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will

provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.

Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then

give the cue sheet to the applicant.

JPM S2 Revision 1 Page 4 of 9 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

Mode 1, 15% power Main Turbine testing in planned for next shift

INITIATING CUES:

You are the ATC operator Annunciator B-1, Pressurizer Level Hi/

Lo, on Panel H has come into alarm. The CRS has entered OP-901-110, Pressu rizer Level Control Malfunction, section E2, Pressurizer Level Setpoint Malfunction The CRS has directed you to raise Letdown flow to 120 - 126 gpm to match Charging and Letdown flow in accordance with step 1.

JPM S2 Revision 1 Page 5 of 9 2010 NRC SRO Exam Evaluator Note Direct the simulator operator to place the simulator in RUN when ready to start.

TASK ELEMENT 1 STANDARD 1. Place Pressurizer Level Controller (RC-ILIC-0110) in MAN AND adjust

OUTPUT to slowly adjust letdown flow to restore Pressurizer level.

Letdown flow is raised to

120 - 126 gpm..

Comment: Critical SAT / UNSAT Evaluator Note After the applicant reports that Charging and Letdown flows are approximately matched, direct him to

perform steps 2 and 3.

TASK ELEMENT 2 STANDARD 2. Verify normal indications on ALL Safety Measurement Channel Hot

Leg AND Cold Leg temperature indicators.

Hot and Cold Leg safety

temperature indicators are

verified on CP-7.

Comment: SAT / UNSAT TASK ELEMENT 3 STANDARD 3. Determine affected channel(s) by c hecking Reactor Regulating System (RRS) T AVG recorders (RC-ITR-0111 AND RC-ITR-0121).

Both channels are identified

as affected by the failure.

Comment: SAT / UNSAT Evaluator Note Inform the applicant that the CRS has completed steps 4 through 8. The CRS has directed him to

evaluate steps 9 and 10.

The applicant may have already identified and reported t he failed instrument prior to reaching this step.

JPM S2 Revision 1 Page 6 of 9 2010 NRC SRO Exam TASK ELEMENT 4 STANDARD Procedure Note: Selecting the non-faulted channel may cause automatic actions to occur if actual level is not at program level.

Note reviewed.

Comment: SAT / UNSAT TASK ELEMENT 5 STANDARD 9. Check Reactor Regulating System (RRS) Hot Leg indicators (RC-ITI-

0111-X AND RC-ITI-0121-X) for abnormal readings.

Hot Leg temperature

indicators are verified to be

reading normally.

Comment: SAT / UNSAT TASK ELEMENT 6 STANDARD 10. Check Reactor Regulating System (RRS) Cold Leg indicators (RC-

ITI-0111-Y AND RC-ITI-0121-Y) for abnormal readings.

RC-ITI-0111-Y is identified

as failed high.

Comment: Identifying the failed instrument correctly is critical so that the correct procedure steps are performed.

Critical SAT / UNSAT Evaluator Cue Cue the applicant that he is now filling the role of the BOP operator and that another operator is filling

the role of the ATC operator.

JPM S2 Revision 1 Page 7 of 9 2010 NRC SRO Exam Evaluator Cue Direct the applicant as following based on his report: If he correctly identifies that Loop 1 Cold Leg (RC-ITI-0111-Y) is failed, then cue:

"Perform step 10.1 for TCOLD LOOP 1 selector switch located behind CP-2 and verify setpoint restoration

". o If he incorrectly identifies that Loop 1 Hot Leg (RC-ITI-0111-X) is failed, then cue:

"Perform step 9.1 and select LOOP 2 for TAVE LOOP SELECTOR on BOTH RRS local cabinets (CP-12A AND CP-12B) and verify setpoint restoration

". o If he incorrectly identifies that Loop 2 Hot Leg (RC-ITI-0121-X) is failed, then cue:

"Perform step 9.2 and select LOOP 1 for TAVE LOOP SELECTOR on BOTH RRS local cabinets (CP-12A AND CP-12B) and verify setpoint restoration

". o If he incorrectly identifies that Loop 2 Cold Leg (RC-ITI-0121-Y) is failed, then cue:

"Perform step 10.2 for TCOLD LOOP 2 selector switch located behind CP-2 and verify setpoint restoration

". Evaluator Note Positioning the selector switch in the next step will not clear the malfunction. The applicant should detect and report this additional failure/problem. The indications that are applicable include: Recorder RC-ILR-0110 Setpoint does not return to normal, ~ 33% All 3 Charging Pumps continue operating T AVE Recorders RC-ITR-0111 and 0121 do not return to normal, ~ 550 °F Pressurizer Level Hi/Lo Annunciator H B-1 does not clear

TASK ELEMENT 7 STANDARD 10.1 Select presently non-selected position (ALT OR NORM) on TCOLD

LOOP 1 selector switch located behind CP-2, Reactor Control

Loop 1 selector switch is

placed in ALT.

Comment: SAT / UNSAT

JPM S2 Revision 1 Page 8 of 9 2010 NRC SRO Exam Evaluator Note After the applicant recommends removing the failed in strument from the Reactor Regulating System, direct the applicant to remove the failed instru ment at both Reactor Regulating System panels.

TASK ELEMENT 8 STANDARD 10.1 Select LOOP 2 on BOTH RRS local cabinets (CP-12A AND CP-

12B)

LOOP 2 is selected on both

Reactor Regulating

cabinets.

Comment: CP-12 A & B are labeled Reactor Regulating System 1 and 2. The correct drawer is in the center of each panel. The correct switches are labeled TAVG Loop Selector. Critical SAT / UNSAT Evaluator Note End task after the applicant verifies setpoint has been restored to normal, ~33%.

END OF TASK

JPM S2 Revision 1 Page 9 of 9 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-196

Verify the following Malfunctions:

RC18C set at 100% failure on Trigger 1.

Verify the following Overrides:

DI-02B1S-0 overridden to Normal

Place the simulator in RUN

Initiate Trigger 1

Acknowledge panel annunciators

Place the simulator in FREEZE.

Place the simulator to RUN on direction from the evaluator.

Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

S3 Reduce RCS Pressure and Establish Pressurizer Level on a Failure of All Charging

Applicant:

Examiner:

JPM S3 JOB PERFORMANCE MEASURE DATA PAGE Task: Reduce RCS pressure with Main Spray and restore Pressurizer Level with High Pressure Safety Injection

Task Standard:

Applicant reduced RCS pressu re to below HPSI Pump shutoff head and established Safety Injection System flow in accordance with OP-901-112, Charging or Letdown Malfunction.

References:

OP-901-112, Charging or Letdown Malfunction Alternate Path:

No Time Critical:No Validation Time:

20 mins.

K/A 006 A1.18, Pressurizer level and pr essure Importance Rating 4.0 / 4.3 RO / SRO Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 8 2010 NRC SRO Exam JPM S3 Revision 1 Page 3 of 8 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-901-112, Charging or Letdown Malfunction

==

Description:==

The applicant will perform the roles of t he ATC and BOP operators for this JPM.

The initial conditions describe that the pl ant has experienced a loss of all Charging capacity. The applicable off normal procedur e directs tripping the reactor and lowering RCS pressure to < 1400 psia. The JPM begins with the reactor tripped and Standard

Post Trip Actions complete. The RCS will be at normal post trip pressure, 2250 psia.

Main Spray will be used to accomplish the pressure reduction. After RCS pressure is

below 1400 psia, a High Pressure Safety Inje ction Pump is started and flow established to restore Pressurizer level.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will

provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.

Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.

JPM S3 Revision 1 Page 4 of 8 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The crew has entered OP-901-112, Char ging or Letdown Malfunction, due to a piping weld failure downstream of CVC-209, Charging Pumps Header

Isolation. The CRS has directed a reactor trip due to the lowering Pressurizer Level. OP-902-000, Standard Post Trip Actions, have been completed.

INITIATING CUES:

The CRS directs you to perform all of the remaining portions of step 2 in sub-section E 1 , Charging Malfunction, and establish a RCS pressure of 1250 - 1350 psia and restoring Pressurizer level to 30% using HPSI

Pump A.

JPM S3 Revision 1 Page 5 of 8 2010 NRC SRO Exam Evaluator Note Direct the simulator operator to place the simulator in RUN when ready to start.

Evaluator Note The Pressurizer Pressure Low Trip setpoint will need to be reset on 2 different occasions during the

reduction of RCS pressure to < 1400 PSIA.

This step becomes applicable when either annunciator K B-16 or K C-16 alarm.

TASK ELEMENT 1 STANDARD 2.3 WHEN PZR PRESSURE LO PRETRIP annunciator alarms, THEN

reset Pressurizer Pressure Low Trip setpoint on ALL FOUR channels.

Pressurizer Pressure low

pressure setpoints are reset

prior to receiving a Safety

Injection Actuation Comment: First occurrence.

Critical SAT / UNSAT TASK ELEMENT 2 STANDARD 2.3 WHEN PZR PRESSURE LO PRETRIP annunciator alarms, THEN

reset Pressurizer Pressure Low Trip setpoint on ALL FOUR channels.

Pressurizer Pressure low

pressure setpoints are reset

prior to receiving a Safety

Injection Actuation Comment: Second occurrence.

Critical SAT / UNSAT Evaluator Note Since there is no Charging Flow, Pressurizer pressu re must be reduced using Main Spray. Controller RC-IHIC-0100 at CP-2 should be taken to MANUAL and output raised to create Main Spray flow.

JPM S3 Revision 1 Page 6 of 8 2010 NRC SRO Exam TASK ELEMENT 3 STANDARD 2.4 Reduce Pressurizer pressure to < 1400 PSIA.

Pressurizer pressure is reduced to 1250 - 1350 PSIA using Main Spray.

Comment: Critical SAT / UNSAT Evaluator Note After Pressurizer pressure is < 1400 PSIA, the Main Spray valves should be throttled closed to prevent

Pressurizer pressure from dropping below the mi nimum pressure for RCP operation, approximately 1250 PSIA.

Evaluator Note The applicant is not required to secure Reactor Coolant Pumps at 1621 PSIA in the RCS since pressure

is dropping under operator control. If the applicant dec ides to secure 2 Reactor Coolant Pumps, the control switches are located on CP-2. It is acceptable if the applicant secures 2 Reactor Coolant

Pumps.

TASK ELEMENT 4 STANDARD 2.5 Start ONE available HPSI Pump AND open associated valves as

required to restore Pressurizer level:

HPSI Pump A is running.

Comment: Critical SAT / UNSAT

JPM S3 Revision 1 Page 7 of 8 2010 NRC SRO Exam TASK ELEMENT 5 STANDARD 2.5 Start ONE available HPSI Pump AND open associated valves as required to restore Pressurizer level:

  • HPSI COLD LEG INJECTION 1A (SI 225A)
  • HPSI COLD LEG INJECTION 1B (SI 226A)
  • HPSI COLD LEG INJECTION 2A (SI 227A)
  • HPSI COLD LEG INJECTION 2B (SI 228A)

At least 1 HPSI flow control valve is throttled open and

Pressurizer level is restored

to > 25%.

Comment: Critical SAT / UNSAT END OF TASK

JPM S3 Revision 1 Page 8 of 8 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-199

There are no Malfunctions or Overrides for this JPM.

Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

S4 Place Shutdown Cooling Train A in Service

Applicant:

Examiner:

JPM S4 JOB PERFORMANCE MEASURE DATA PAGE Task: Place Shutdown Cooling Train A in Service

Task Standard: Applicant placed Shutdown Cooling Train A in service in accordance with OP-009-005 and secured Low Pressure Safety Injection Pump A after SI-405 A failed closed.

References:

OP-009-005, Shutdown Cooling OP-901-131, Shutdown Cooling Malfunction Alternate Path:

Yes Time Critical:No Validation Time:

30 mins.

K/A 005 A4.01, Controls and indication for RHR Importance Rating 3.6 / 3.4 pumps RO / SRO Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 11 2010 NRC SRO Exam JPM S4 Revision 1 Page 3 of 11 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-009-005, Shutdown Cooling

==

Description:==

This task is performed at CP-8. The applicant must place Shutdown Cooling Train A in service. The fault in this task is that SI-405 A, RC Loop 2 SDC Suction Inside Containment Isol, will fail closed, requiring the applicant to secure Low Pressure Safety Injection Pump A. The task can be stopped after LPSI Pump A is secured.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will

provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.

Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then

give the cue sheet to the applicant.

JPM S4 Revision 1 Page 4 of 11 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is in Mode 4 Protected Train is A RCS temperature is 280 °F RCS pressure is 340 PSIA Shutdown Cooling Train A has been placed in Standby in accordance with OP-009-005, Shutdown Coo ling, section 5.3.

INITIATING CUES:

The CRS has directed you to place Shutdown Cooling Train A in service in accordance with OP-009-005, section 6.1.

JPM S4 Revision 1 Page 5 of 11 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD Procedure Note: The Shutdown Cooling Train placed in service should be on the Protected Train.

Note reviewed.

Comment:

SAT / UNSAT TASK ELEMENT 2 STANDARD Procedure Caution: Following a design basis tornado event, delaying the initiation of Shutdown Cooling (SDC) for up to 7 days will be

required to ensure the Component Cooling Water System is capable

of removing Reactor Coolant System decay heat. The actual delay

time will depend on UHS damage and ambient temperature and will

be determined by engineering. Emergency Feedwater supports decay

heat removal until SDC can be initiated.

Caution reviewed.

Comment:

SAT / UNSAT TASK ELEMENT 3 STANDARD 6.1.1: Verify Shutdown Cooling Train A has been aligned to Standby

condition in accordance with Section 5.3, Alignment of Shutdown

Cooling Train A to Standby Condition.

Cue sheet lists this as

complete.

Comment:

SAT / UNSAT Evaluator Note Any Dry Fan started in SLOW must be declared inoperable and Tech Spec 3.7.4 addressed.

TASK ELEMENT 4 STANDARD 6.1.2: Verify sufficient number of Dry Cooling Tower Fans running to

accept increased heat load on CCW System.

Any fans started must be

started in FAST.

Comment: Applicant may ask the CRS how man fans he wants

running. If asked, respond to keep the fans in automatic and verify

they cycle on as required. Any number of fans started is acceptable.

SAT / UNSAT

JPM S4 Revision 1 Page 6 of 11 2010 NRC SRO Exam TASK ELEMENT 5 STANDARD Procedure Caution: CC-963A is required to be maintained open while in Mode 4 to preserve the design temperature basis of piping and

associated components at the CCW outlet of shutdown cooling heat

exchanger A. With CC-963A open, flow through Shutdown Cooling

Heat Exchanger A will be maintained above 2305 gpm.

Caution reviewed.

Comment:

SAT / UNSAT TASK ELEMENT 6 STANDARD 6.1.3: Place Shutdown HX A CCW Flow Control, CC-963A, control switch to Open.

CC-963 A is opened.

Comment:

Critical SAT / UNSAT TASK ELEMENT 7 STANDARD (1) The following Reactor Coolant System limits shall be met for Shutdown Cooling Entry:

RCS temperature limit: < 350 °F

RCS pressure limit: < 392 psia

(2) If Containment Spray Header A Isolation, CS-125 A, is open while

Shutdown Cooling Train A is operating, then Containment Spray A riser may fill and possibly spray water into Containment, due to leakage past Containment Spray Pump A discharge stop check, CS-117A. Caution reviewed.

Comment:

SAT / UNSAT

JPM S4 Revision 1 Page 7 of 11 2010 NRC SRO Exam TASK ELEMENT 8 STANDARD 6.1.4: Unlock and Open RC Loop 2 SDC Suction Outside Containment Isol, SI-407A.

SI-407 A is opened.

Comment:

Key 133 required.

Critical SAT / UNSAT TASK ELEMENT 9 STANDARD 6.1.5: Notify Radiation Protecti on Department that Shutdown Cooling Train A is being placed in service.

Call is made.

Comment:

SAT / UNSAT TASK ELEMENT 10 STANDARD 6.1.6: Start LPSI Pump A.

LPSI Pump A is started.

Comment:

Annunciator LPSI Pump A Flow Lost (Cabinet M, F-3) is expected. It

will clear when the applicant raises flow > 2900 gpm.

Critical SAT / UNSAT TASK ELEMENT 11 STANDARD 6.1.7: Raise Shutdown Cooling flow by Manually adjusting LPSI Header Flow controller 2A/2B, SI-IFIC-0307, output until Shutdown

Cooling Header A Flow indicates 4100 GPM, as indicated by RC Loop

2 Shdn Line Flow Indicator, SI-IFI-1307-A1.

Flow is raised to 4100 gpm.

Comment:

Critical SAT / UNSAT TASK ELEMENT 12 STANDARD 6.1.8: Adjust LPSI Header Flow Controller 2A/2B, SI-IFIC-0307, setpoint potentiometer to 73%, and place controller to AUTO.

Setpoint potentiometer is set

to 73%, and controller is

placed in AUTO Comment:

Critical SAT / UNSAT

JPM S4 Revision 1 Page 8 of 11 2010 NRC SRO Exam TASK ELEMENT 13 STANDARD 6.1.9: Verify LPSI Header Flow Controller 2A/2B, SI-IFIC-0307, is maintaining 4100 GPM Shutdown Cooli ng Header A flow, as indicated by RC Loop 2 Shdn Line Flow Indicator, SI-IFI-1307-A1.

Flow is verified.

Comment:

SAT / UNSAT TASK ELEMENT 14 STANDARD Procedure note: If a sample was drawn prior to shutdown and no interim shutdown has occurred where SDC was placed in service and

boron concentration could have been reduced, then sampling is not

required.

Note reviewed.

Comment:

SAT / UNSAT TASK ELEMENT 15 STANDARD 6.1.10: At SM/CRS discretion, direct Chemistry Department to sample Shutdown Cooling Train A for boron concentration.

None Comment:

Evaluator: When requested provide information to applicant that all

required Chemistry requirements are met.

SAT / UNSAT TASK ELEMENT 16 STANDARD Procedure Note: Shutdown Cooling Train A requires one operable Low Pressure Safety Injection Flow Control Valve for the train to be

operable.

Note reviewed.

Comment:

SAT / UNSAT

JPM S4 Revision 1 Page 9 of 11 2010 NRC SRO Exam TASK ELEMENT 17 STANDARD Procedure Caution: The Reactor Coolant System shall not exceed the 100 °F per hour cooldown rate of Technical Specification 3.4.8.1.

Caution reviewed.

Comment:

SAT / UNSAT TASK ELEMENT 18 STANDARD 6.1.11.1: Open the following valves: SI-139A LPSI Header to RC Loop 2A Flow Control SI-138A LPSI Header to RC Loop 2B Flow Control SI-139 A and SI-138 A are open. Comment:

Critical SAT / UNSAT TASK ELEMENT 19 STANDARD 6.1.11.2: Throttle Closed RC Loop 2 Shdn Cooling Warmup, SI-135A, until one of the following is within 100°F of Shutdown Cooling Train A

temperature, as indicated by LPSI Pump A Discharge Header

Temperature Indicator, SI-ITI-0351X:

Hot Leg 2 temperature, as indicated by RC Loop 2 Hot Leg Temperature Indicator, RC-ITI-0122-HA Temperature is within 100 °F Comment:

SI-135 A is a large gate valve with a very long stroke.

SAT / UNSAT

JPM S4 Revision 1 Page 10 of 11 2010 NRC SRO Exam TASK ELEMENT 20 STANDARD 6.1.11.3: Close RC Loop 2 Shdn Cooling Warmup, SI-135 A.

SI-135 A is closed Comment:

Critical SAT / UNSAT Evaluator Note Coordinate with the simulator operator to initiate trigger 1 to close SI-405 A.

TASK ELEMENT 21 STANDARD Secure LPSI Pump A LPSI Pump A is off.

Comment:

This is an immediate operator action in accordance with OP-901-131, Shutdown Cooling Malfunction, section D.1.

Critical SAT / UNSAT

END OF TASK

JPM S4 Revision 1 Page 11 of 11 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-197

Verify the following Malfunctions: Si23a for SI-405 A

Coordinate with the examiner so that when SI-135 A is fully closed at step 6.1.11.3, Trigger 1 is init iated to close SI-405 A.

Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

S5 Synchronize the Main Generator to the Grid

Applicant:

Examiner:

JPM S5 JOB PERFORMANCE MEASURE DATA PAGE Task: Synchronize the Main Generator to the grid in accordance with OP-010-004, Power Operations.

Task Standard: The Main Generator was synchronized to the grid with both Output Breakers closed in accordance with OP-010-004, Power Operations.

References:

OP-010-004, Power Operations Alternate Path:

Yes Time Critical:No Validation Time:

30 mins.

K/A 062 A4.07, Synchronizing and paralleli ng of Importance Rating 3.1 / 3.1 different AC supplies RO / SRO Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 14 2010 NRC SRO Exam JPM S5 Revision 1 Page 3 of 14 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-010-004, Power Operations

==

Description:==

This JPM takes place at CP-1. The applicant will start the task with all Main

Turbine testing complete and the unit running at 1800 rpm. The cue will direct the

applicant to perform an auto synchronization of the Main Generator. The auto synchronization will fail to close either Main Generator Output Breaker. The applicant will then perform a manual synchronization.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will

provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.

Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then

give the cue sheet to the applicant.

JPM S5 Revision 1 Page 4 of 14 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

Plant is in Mode 1 at 15% power following a refueling outage All Main Turbine testing has been completed.

Watch standers are standing by at the Main Transformers and the Generator Auxiliaries area. The Load Dispatcher and Southern Cont rol have been notified that we are coming on line.

INITIATING CUES:

You are directed to synchronize the Main Generator to the grid using the auto synchronization circuit in accordanc e with OP-010-004, Power Operations.

JPM S5 Revision 1 Page 5 of 14 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD Procedure Note: Monitor Main Transformer A(B) during the initial energization and loading phases of the transformer for indications of static discharging as evidenced by unusual bumping, thudding, crackling, popping, or similar noises. Notify Sy stem Engineering immediately if any unusual noises are emanating from the transformer tank.

Note reviewed.

Comment: SAT / UNSAT TASK ELEMENT 2 STANDARD 9.1.22 Close Generator Exciter Field Breaker on CP-1 to excite

Generator field.

Breaker closed.

Comment: Critical SAT / UNSAT Evaluator Note Local watchstander reports no unusual noises at the Main Transformers.

TASK ELEMENT 3 STANDARD 9.1.23 Locally verify Main Transformer Cooling System operating with no

unusual noises.

Verification complete.

Comment: SAT / UNSAT Evaluator Note Local watchstander reports Isophase Bus Duct Cooling Fan is operating normally.

JPM S5 Revision 1 Page 6 of 14 2010 NRC SRO Exam TASK ELEMENT 4 STANDARD 9.1.24 Locally verify Generator Isophase Bus Duct Cooling Fan selected to Auto has started.

Verification complete.

Comment: SAT / UNSAT TASK ELEMENT 5 STANDARD Procedure Caution: Do not leave synchronizer energized for longer than 5 minutes to prevent relay damage. Ensure that only one synchronizer circuit is energized at any time to prevent synchronizer malfunction.

Caution reviewed.

Comment: SAT / UNSAT TASK ELEMENT 6 STANDARD 9.1.25 Place Synchronizer Switch for first Generator Output Breaker to

Manual, and verify Generator Running, GEN-EM-2210A, and Incoming, GEN-EM-2210B, voltmeters indicate voltage.

First Generator Output

Breaker is placed in

MANUAL. Comment: Critical SAT / UNSAT TASK ELEMENT 7 STANDARD Procedure Note: Voltage Regulator operation should be in accordance

with Attachment 9.8, Entergy Guidelines Regarding Generator Voltage

Regulator and Abnormal Frequency Operation.

Note reviewed.

Comment: SAT / UNSAT

JPM S5 Revision 1 Page 7 of 14 2010 NRC SRO Exam TASK ELEMENT 8 STANDARD Procedure Caution: Exciter field amps shall not exceed 45 amps when matching incoming and running voltages with the base voltage adjuster.

Caution reviewed.

Comment: SAT / UNSAT TASK ELEMENT 9 STANDARD 9.1.26 Using Base Voltage Adjust Switch, raise Incoming (Generator)

voltage, GEN-EM-2210B, to match Running (Grid) voltage, GEN-EM-

2210A. Voltage adjusted.

Comment: Critical SAT / UNSAT TASK ELEMENT 10 STANDARD 9.1.27 Place Synchronizer Switch for first Generator Output Breaker in

Off. First Generator Output

Breaker is placed in OFF.

Comment: It does not matter which breaker is closed first.

Critical SAT / UNSAT TASK ELEMENT 11 STANDARD 9.1.28 Place Auto Voltage Regulator switch in Test.

Voltage Regulator switch is

in TEST. Comment: SAT / UNSAT

JPM S5 Revision 1 Page 8 of 14 2010 NRC SRO Exam TASK ELEMENT 12 STANDARD 9.1.29 Verify Voltage Regulator Balance needle deviates from zero in both directions, by rotating Voltage Regulator Adjust switch clockwise and counterclockwise.

Balance needle adjusted.

Comment: SAT / UNSAT TASK ELEMENT 13 STANDARD 9.1.30 Adjust Volt Reg Balance to zero, and place Auto Voltage Regulator switch to On.

Auto Voltage Regulator

switch is in ON.

Comment: Critical SAT / UNSAT TASK ELEMENT 14 STANDARD 9.1.31 Adjust Turbine speed to 1801-1802 RPM, at SM/CRS discretion, in accordance with OP-005-007, Main Turbine Generator.

Speed verified.

Comment: If asked, provide the value of 1802.

SAT / UNSAT TASK ELEMENT 15 STANDARD 9.1.32 Notify Load Dispatcher and Southern Control unit is ready to go

on line. Notification given in cue.

Comment: SAT / UNSAT TASK ELEMENT 16 STANDARD 9.1.33.1 Verify Auto Synchronization is disabled by placing Gen Bkr Auto Synch Switch in Disable.

Verification complete.

Comment: SAT / UNSAT

JPM S5 Revision 1 Page 9 of 14 2010 NRC SRO Exam TASK ELEMENT 17 STANDARD Procedure Note: Auto Synchronizer controls Generator voltage when an Auto Synchronizer circuit is placed in service. It may take several

revolutions (~ three) of the synchroscope before the Synch lights illuminate to allow circuit to adjust voltage and frequency.

Note reviewed.

Comment: SAT / UNSAT TASK ELEMENT 18 STANDARD 9.1.33.2 Place Synchronizer for first Generator Output Breaker to be

closed in Auto.

Switch is in AUTO.

Comment: Critical SAT / UNSAT TASK ELEMENT 19 STANDARD Procedure Note: Main Generator Voltage is matched with Switchyard

Voltage when Incoming and Running Voltage needles are opposite one another. Note reviewed.

Comment: SAT / UNSAT TASK ELEMENT 20 STANDARD 9.1.33.3 Verify proper operation of Main Generator Auto Synchronization

circuit by all of the following: Synchroscope rotating slowly in the fast direction. (< 1 rev per 10 sec) Synch check lights are illuminated between 5 till and 12 o'clock. Incoming voltage, GEN-EM-2210B, approximately equal to running voltage, GEN-EM-2210A.

Verification complete.

Comment: SAT / UNSAT

JPM S5 Revision 1 Page 10 of 14 2010 NRC SRO Exam TASK ELEMENT 21 STANDARD Procedure Note: Placing Gen Bkr Auto Synch switch in Enable allows Generator Output Breaker to close automatically. The Gen Bkr Auto

Synch must be held in Enable until GOB closes.

Note reviewed.

Comment: SAT / UNSAT TASK ELEMENT 22 STANDARD 9.1.33.4 When Synchroscope passes "15 after 12 o'clock" position and Synch Check lights are extinguished, then place and hold Gen Bkr Auto Synch switch in Enable.

Switch is in ENABLE.

Comment: Critical SAT / UNSAT Evaluator Note The fault will prevent the Generator Output Breaker from closing. The applicant should eventually

release the Auto Sync Switch and report the failure to the CRS.

Direct the applicant as the CRS to sync the Main Generator in MANUAL in accordance with step 9.1.34.

TASK ELEMENT 23 STANDARD 9.1.33.7 Turn Synchronizer to OFF.

Switch is in OFF.

Comment: Critical SAT / UNSAT TASK ELEMENT 24 STANDARD 9.1.34.1 Place Synchronizer in Manual.

Switch is in MANUAL.

Comment: Critical SAT / UNSAT

JPM S5 Revision 1 Page 11 of 14 2010 NRC SRO Exam TASK ELEMENT 25 STANDARD Procedure Note: Main Generator Voltage is matched with Switchyard Voltage when Incoming and Running voltage needles are opposite one

another. Note reviewed.

Comment: SAT / UNSAT TASK ELEMENT 26 STANDARD 9.1.34.2 Verify Incoming voltage, GE N-EM-2210B, is slightly higher than Running Voltage, GEN-EM-2210A.

Verification complete.

Comment: SAT / UNSAT TASK ELEMENT 27 STANDARD 9.1.34.3 Verify Synchroscope is rotating slowly in the fast direction.

Verification complete.

Comment: SAT / UNSAT TASK ELEMENT 28 STANDARD 9.1.34.4 Verify one complete revolution of the synchroscope every 15 seconds or greater, before attempting to close the Generator Output Breaker. Verification complete.

Comment: SAT / UNSAT TASK ELEMENT 29 STANDARD Procedure Caution: Attempt to close a generator output breaker only at

12 o'clock. Failure to do this could result in paralleling the generator out

of phase.

Caution reviewed.

Comment: SAT / UNSAT

JPM S5 Revision 1 Page 12 of 14 2010 NRC SRO Exam TASK ELEMENT 30 STANDARD 9.1.34.5 When Synchroscope reaches slightly before 12 o' clock position and Synch Check lights are On, then Close the first Generator Output Breaker. Generator Output Breaker is CLOSED.

Comment: Critical SAT / UNSAT TASK ELEMENT 31 STANDARD 9.1.34.6 Turn Synchronizer Switch to OFF.

Switch is in OFF.

Comment: Critical SAT / UNSAT TASK ELEMENT 32 STANDARD 9.1.35 Verify Generator has picked up approximately 5% load ( 62 Mwe). Verification complete.

Comment: SAT / UNSAT TASK ELEMENT 33 STANDARD Procedure Note:

Prior to closing the second Generator Output Breaker, wait at least 20 seconds after placing synchronizer in Manual to allow

Synch Check Relay to realign.

Note reviewed.

Comment: SAT / UNSAT

JPM S5 Revision 1 Page 13 of 14 2010 NRC SRO Exam TASK ELEMENT 34 STANDARD 9.1.36.1 Place Synchronizer in Manual for remaining Generator Output Breaker. Switch is in MANUAL.

Comment: Critical SAT / UNSAT TASK ELEMENT 35 STANDARD 9.1.36.2 Close the Generator Output Breaker.

Generator Output Breaker

is CLOSED.

Comment: Critical SAT / UNSAT TASK ELEMENT 36 STANDARD 9.1.36.3 Turn the Synchronizer switch to Off Switch is in OFF.

Comment: Critical SAT / UNSAT END OF TASK

JPM S5 Revision 1 Page 14 of 14 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-196

There are no Malfunctions for this JPM.

Verify the following Overrides:

o DI-01A06S08-1 overridden to OFF

(Initial/Date)

9.1 PowER

INCREASE To 100%(lnitiaI/Dat)

9.1.1 Verify

Initial Conditions as follows:__________

9.1.1.1 Reactor Power is 10%.9.1.1.2 Pressurizer pressure is being maintained at 2250 PSIA (2175-2265 PSIA).9.1.1.3 Pressurizer level is being maintained at 33%by Control Channel indication.

9.1.1.4 Steam Generator levels are being maintained between 50 to 70%NR by Main Feedwater.

9.1.1.5 Main Turbine is on Turning Gear, not latched.9.1.1.6 CEAs are positioned above Transient Insertion Limits.CAUTION (1)MAINTAINING LEVELS TOO LOW IN FEEDWATER HEATERS WHILE RAISING PLANT POWER MAY CAUSE ADVERSE PLANT EFFECTS, INCLUDING EXCESSIVE MOVEMENT OF ASSOCIATED PIPING.SYSTEM ENGINEERING SHOULD PROVIDE GUIDANCE ON APPROPRIATE FEEDWATER HEATER LEVELS TO MAINTAIN WHILE RAISING PLANT POWER,[CR-WF3-2005-02813]

(2)DKSUM (CPC PID 272), IS>51, AND PQASI (CPC PID 266)EXCEEDS THE BAND OF-0.5 TO+0.5, THEN A CPC AUX TRIP WILL OCCUR.WHILE RAISING REACTOR POWER TO 15%, PQASI SHALL BE MAINTAINED WITHIN THE BAND OF-0.48 TO+0.48.[P-15271]9.1.2 If at 10%power with PQASI within the band of-0.4 to+0.4,//O1-/continue raising Reactor power to 15%while monitoring

/DKSUM (CPC PID 272).[P-15271]9.1.3 If at 10%power with PQASI outside the band of-0.4 to+0.4, (4//O7/0 and within the band of-0.48 to+0.48, then raise power to 15%1 while monitoring DKSUM (CPC PID 272)as directed by Shift Manager.[P-15271]OP-010-004 Revision 308 Attachment 9.1 (1 of 18)19 (Initial/Date)

NOTE Avoid excessive changes in feedwater flow and Steam Generator level when adjusting Feedwater Control System.Controllers should be adjusted and placed in service slowly.9.1.4 Place Feedwater Control in Automatic as follows: 9.1.4.1 Place Startup Feedwater Regulating Valve Controllers 4i/A(B), FW-IHIC-1105(1106), in Auto by performing the following:

9.1.4.1.1 Adjust output indication equal to process indication.

9.1.4.1.2 Depress the Auto pushbutton.

9.1.4.2 Place Main Feedwater Regulating Valve Controllers A(B), L/éi fD9.4 FW-IHIC-1 111(1121), in Auto by performing the following:

I 9.1.4.2.1 Adjust output indication equal to process indication.

9.1.4.2.2 Depress the Auto pushbutton.

9.1.4.3 Place Master Controllers A(B), FW-IFIC-1 111(1121),/f 1°in Auto by performing the following:

9.1.4.3.1 Adjust setpoint potentiometer equal to indicated Steam Generator level.9.1.4.3.2 Depress Master controller Auto pushbutton.

9.1.4.4 When both FW Master Controllers are in AUTO, then/(o_71 0 Place Feedwater Pump Speed Controllers A(B), I FW-IH IC-i 107(1108)in Auto by performing the following:

9.1.4.4.1 Adjust output indication equal to process indication.

9.1.4.4.2 Depress the Auto pushbutton.

9.1.4.5 Slowly adjust FW Master Controllers setpoint to desired//Ojt Steam Generator level.9.1.5 Verify Steam Generator levels 63 to 73%NR./,o_I0 9.1.6 Verify Generator Output Breakers Open./K?.'11c 9.1.7 Verify Ground Disconnects are Open./i0')-lc'OP-010-004 Revision 308 Attachment 9.1 (2 of 18)20 (jitial/Date)

9.1.8 Verify

Manual Disconnects for Generator Output Breakers iiD-7-7 are Closed, 9.1.9 Prepare the MSR Tube Bundles for pressurization by/performing Section 6.1, MSR Cold Start Mode, of/OP-005-005, Reheat Steam System.NOTE When rolling and loading the Turbine, monitor Seal Oil temperatures.

9.1.10 Priorrolling Main Turbine, verify the following:

9.1.10.1 Turbine Cooling Water available to Exciter Coolers in accordance with OP-003-027, Turbine Closed Cooling Water System.Exciter field breaker is Open.Voltage Regulator is not in Service.The Exciter doors are Closed.All personnel are clear of Main Turbine.Verify afl Turbine Trips are clear on PMC group TGTRIP.Verify operability of the following Reverse Current Valves (RCV)by checking them Closed:*ES-ill#1 ESHdrRCV*ES-207#2 ES Hdr RCV*ES-309A(B,C)

Htr 3A(B,C)ES Hdr RCVs*ES-413A(B,C)

Htr 4A(B,C)ES Hdr Upstrm RCVs*ES-41 8A(B,C)Htr 4A(B,C)ES Hdr Dnstrm RCVs Verify 86G1 86G2 relays are reset.Electro-hydraulic Oil System is operating in accordance with OP-003-008, Electro-hydraulic Oil System.OP-010-004 Revision 308//04-10 9.1.10.2 9.1.10.3 9.1.10.4 9.1.10.5 9.1.10.6 9.1.10.7 9.1.10.8 9.1.10.9 21 Attachment 9.1 (3 of 18>

(Initial/Date) 9.1 11 Determine the following values in accordance with Attachment 9.5, Turbine Startup:*Initial HP Turbine 1st Stage Metal Temp (TUR-ITR-1820 Point3orPMC P1DA55127)

_________*Acceleration Rate____________

RPM/Mm*Initial Load to Apply___________

Mw*Mw Hold Time at Initial Load___________

Mm*Maximum Load Rate 7 Mw/Mm 9.1.12 Perform Main Turbine Startup in accordance with/OP-O05007, Main Turbine Generator.

9.1.13 Verify OP-904-003, Main Turbine Protection Devices Trip/Tests, has been completed within last 31 days.9.1.14 If y of the following conditions apply, perform/OP-904-002, Main Turbine Overspeed Test: F*The Plant Startup is being performed following a Refueling Outage.*It is the initial startup of the Main Turbine following major overhaul of the Main Turbine.*It is the initial startup of the Main Turbine following any work on the governor pedestal that may affect the Main Turbine Overspeed trip setting.9.1.15 Open Turbine Lube Oil Reseoir Heater breaker/LOG-EBKR-31 3AB-5H.9.1.16 Verify OPER AUTO light is illuminated on DEH Turbine//°Control Panel.9.1.17 Stop Bearing&Gen Seal Oil Backup Pumps.9.1.18 Verify Main Generator hydrogen pressure is 60 to 65 psig.9.1.19 Verify Generator H2 Coolers are aligned in accordance with OP-003-027, Turbine Closed Cooling Water System.9.1.20 Verity Volt Adjust Position Base indication, GEN-EM 2105,__________

is at minimum setting (-.5%position).

9.1.21 Locally verify Main Transformer Cooling System in Auto in/J(o accordance with 0 P-006-008, Transformer Operation.

[P-i 7756]OP-010O04 Revision 308 Attachment 9.1 (4 of 18)//7_tT 22 (Initial/Date)

NOTE Monitor Main Transformer A(B)during the initial energization and loading phases of the transformer for indications of static discharging as evidenced by unusual bumping, thudding, crackling, popping, or similar noises.Notify System Engineering immediately if any unusual noises are emanating from the transformer tank.9.1.22 Close Generator Exciter Field Breaker on CP-1 to excite___________

Generator field.9.1.23 Locally verify Main Transformer Cooling System operating with no unusual noises.9.1.24 Locally verify Generator Isophase Bus Duct Cooling Fan___________

selected to Auto has started.CAUTION DO NOT LEAVE SYNCHRONIZER ENERGIZED FOR LONGER THAN 5 MINUTES TO PREVENT RELAY DAMAGE.ENSURE THAT ONLY ONE SYNCHRONIZER CIRCUIT IS ENERGIZED AT ANY TIME TO PREVENT SYNCHRONIZER MALFUNCTION.

9.1.25 Place Synchronizer Switch for first Generator Output Breaker to Manual, verify Generator Running, GEN-EM-221 OA, and Incoming, GEN-EM-221 OB, voltmeters indicate voltage.NOTE Voltage Regulator operation should be in accordance with Attachment 9.8, Entergy Guidelines Regarding Generator Voltage Regulator and Abnormal Frequency Operation.

CAUTION EXCITER FIELD AMPS SHALL NOT EXCEED 45 AMPS WHEN MATCHING INCOMING AND RUNNING VOLTAGES WITH THE BASE VOLTAGE ADJUSTER.9.1.26 Using Base Voltage Adjust Switch, raise Incoming (Generator)

__________

voltage, GENEM-221OB, to match Running (Grid)voltage, GEN-EM-221 OA.OP-O1O-004 Revision 308 Attachment 9.1 (5 of 18)23 (Initial/Date) 9.1.27 Place Synchronizer Switch for first Generator Output Breaker in Off.9.1.28 Place Auto Voltage Regulator switch in Test.9.1.29 Verify Voltage Regulator Balance needle deviates from zero in both directions, by rotating Voltage Regulator Adjust switch clockwise and counterclockwise 9.1.30 Adjust Volt Reg Balance to zero, place Auto Voltage Regulator switch to On.9.1.31 Adjust Turbine speed to 1801-1802 RPM, at SM/CRS discretion, in accordance with OP-005-007, Main Turbine Generator.

9.1.32 Notify Load Dispatcher and Southern Control unit is ready to go on line.9.1.33 Auto Synchronizing of first Generator Output Breaker is desired, then perform the following:

9.1.33.1 Verify Auto Synchronization is disabled by placing Gen Bkr Auto Synch Switch in Disable.NOTE Auto Synchronizer controls Generator voltage when an Auto Synchronizer circuit is placed in service.It may take several revolutions

(-.three)of the synchroscope before the Synch lights illuminate to allow circuit to adjust voltage and frequency.

9.1.33.2 Place Synchronizer for first Generator Output Breaker to be closed in Auto.OP-010-004 Revision 308 Attachment 9.1 (6 of 18)24 (Initial/Date)

NOTE Main Generator Voltage is matched with Switchyard Voltage when Incoming jjçj Running Voltage needles are opposite one another 9.1.33.3 Verify proper operation of Main Generator Auto Synchronization circuit by ll of the following:

a Synchroscope rotating slowly in the fast direction.

(<1 rev per 10 sec).Synch check lights are illuminated between 5 till and 12 o'clock..Incoming voltage, GEN-EM-22108, approximately equal to running voltage, GEN-EM-221 OA.NOTE Placing Gen Bkr Auto Synch switch in Enable allows Generator Output Breaker to close automatically.

The Gen Bkr Auto Synch must be held in Enable until GOB closes.9.1.33.4 When Synchroscope passes"15 after 12 o'clock"position Synch Check lights are extinguished, place hold Gen Bkr Auto Synch switch in Enable.9.1.33.5 Verify selected Generator Output Breaker closes at"12 o'clock"position.9.1.33.6 When the Generator Output Breaker is closed, then release the Gen Bkr Auto Synch switch allow it to spring return to Disable.9.1.33.7 Turn Synchronizer to OFF.9.1.34 If Manual Synchronizing of the first Generator Output Breaker is desired, perform the following:

9.1.34.1 Place Synchronizer in Manual.NOTE Main Generator Voltage is matched with Switchyard Voltage when Incoming and Running voltage needles are opposite one another.9.1.34.2 Verify Incoming voltage, GEN-EM-2210B, is slightly higher than Running Voltage, GEN-EM-221 OA.9.1.34.3 Verify Synchroscope is rotating slowly in the fast direction.

OP-010-004 Revision 308 Attachment 9.1 (7 of 18)25 (Initial/Date) 9.1.34.4 Verify one complete revolution of the synchroscope every 15 seconds Q greater, before attempting to close the Generator Output Breaker.CAUTION ATTEMPT TO CLOSE A GENERATOR OUTPUT BREAKER ONLY AT 12 O'CLOCK.FAILURE TO DO THIS COULD RESULT IN PARALLELING THE GENERATOR OUT OF PHASE.9.1.34.5 When Synchroscope reaches slightly before 12 o'clock position Synch Check lights are On, then Close the first Generator Output Breaker.9.1.34.6 Turn Synchronizer Switch to OFF.9.1.35 Verify Generator has picked up approximately 5%load (62 Mwe).9.1.36 Close remaining Generator Output Breaker as follows:___________

NOTE Prior to closing the second Generator Output Breaker, wait at least 20 seconds after placing synchronizer in Manual to allow Synch Check Relay to realign.9.1.36.1 Place Synchronizer in Manual for remaining Generator Output Breaker.9.1.36.2 Close the Generator Output Breaker.9.1.36.3 Turn the Synchronizer switch to Off.9.1.37 Locally check Turbine Bearing Drain temperatures and Lube Oil Return temperatures are 110°F to 160°F.9.1.38 Monitor Turbine Lube Oil Temperature, LOG-lTl-4310, and Generator H 2 temperature, GG-ITI-091 0, on CP-1 and adjust temperature control valves as necessary.

OP.01O-OO4 Revision 308 Attachment 9.1 (8 of 18)26 NOTE UFM not in service Reactor Power 95%MSBS RAW PMC PID 024631 Reactor Power<95%and 35%FWBSRAW PMC PID 024630 Reactor Power<35%BDELT PMC PID C24104 UFM in service Reactor Power 95%MSBSRAW PMC PID 024631 Reactor Power<95%and 40%USBSRAW PMC PID C24629 Reactor Power<40%and 35%FWBSRAW PMC PID C24630 Reactor Power<35%BDELT PMC PID 024104 9.1.39 Commence power ascension by raising RCS Tavg.OP-010-004 Revision 308 Attachment 9.1 (9 of 18)BSCAL is not a good indication of instantaneous power during power maneuvers.

Additionally, once the smoothing factor is applied at approximately 98%MSBSRAW (PMC PID 024631), BSCAL becomes a time weighted average of power recorded over approximately 20 minutes.The following tables list COLSS calculated powers available during power maneuvering to monitor instantaneous power:[CR-WF3-2005-03985]

CAUTION MAINTAINING LEVELS TOO LOW IN FEEDWATER HEATERS WHILE RAISING PLANT POWER MAY CAUSE ADVERSE PLANT EFFECTS, INCLUDING EXCESSIVE MOVEMENT OF ASSOCIATED PIPING.SYSTEM ENGINEERING SHOULD PROVIDE GUIDANCE ON APPROPRIATE FEEDWATER HEATER LEVELS TO MAINTAIN WHILE RAISING PLANT POWER.[CR-WF3-2005-02813]

27 (Initial/Date) 9.1.40 When Reactor Coolant System (RCS)Tavg rises, then match___________

Tavg and Tret by raising Turbine load in accordance with OP-005-007.

Main Turbine and Generator.

9.1.41 When Generator reaches 10%load (-124 Mwe), jj Open MSR Warmup Valves in accordance with MSR Cold Start Mode section of OP-005-005, Reheat Steam System.NOTE Feedwater Heaters 3A(B, C)and 4A(B, C)may remain full and at vacuum until sufficient heat is generated in the secondary system.The heaters may therefore require venting during power ascension.

To be effective, venting may commence when generator load is between 180MW and 220 MW (-15%to-18%).9.1.42 When power is 1 5%, then vent Feedwater Heaters 3A(B, C)and 4A(B, C)as necessary.

Refer to OP-003-034, Feed Heater Vents and Drains.9.1.43 After exceeding 15%power, but jr to exceeding 20%power, verify CPC Calibrated Neutron Flux Power (CPC PID 171), CPC Thermal Power (CPC PID 177), and Actual Excore Nuclear Power (OP-b DVM)agree with Calorimetric Power within limits specified in OP-903-001, Technical Specification Surveillance Log.9.1.44 Following a Reactor Power change of>15%within a one hour__________

period, notify Chemistry Department to sample the RCS for an isotopic iodine analysis two to six hours later.[S.R.4.4.7, P-1171]I Chemist Contacted Date,Time 9.1.45 If desired, then transfer Plant Auxiliaries from Startup I Transformer to Unit Auxiliary Transformer in accordance with OP-006-001, Plant Distribution (7KV, 4KV, and SSD)Systems.9.1.46 Verify Pressurizer level tracks programmed level in accordance with Pressurizer Level Setpoint Program in the Plant Data Book.9.1.47 Verify Steam Generator levels are maintained between 63 to 73%NR.OP-0b0-004 Revision 308 Attachment 9.1 (10 of 18)28 Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

S6 Reset Containment Spray Actuation

Applicant:

Examiner:

JPM S6 JOB PERFORMANCE MEASURE DATA PAGE Task: Reset Containment Spray Actuation

Task Standard:

CSAS initiation and actuation were reset in accordance with OP-902-009, Standard Appendices, Appendix 5 - E.

References:

OP-902-009, Standar d Appendices, Appendix 5 - E OP-902-004, Excess Steam Demand Recovery Alternate Path:

No Time Critical:No Validation Time:

10 mins. K/A 012 A4.04, Bistable, trips, reset and test switches Importance Rating 3.3 / 3.3 RO / SRO Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 8 2010 NRC SRO Exam JPM S6 Revision 1 Page 3 of 8 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-902-009, Standard Appendices, Appendix 5 - E OP-902-004, Excess Steam Demand Recovery

==

Description:==

The JPM begins in an Excess Steam Demand event, after the applicable Steam Generator has blown dry. Containment Spray termination criteria are met. The

applicant will be directed to reset CSAS. Actions for this task take place at CP-8, CP-10 A through D, and CP-33.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will

provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.

Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then

give the cue sheet to the applicant.

JPM S6 Revision 1 Page 4 of 8 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

An Excess Steam Demand event has occurred. The crew is implementing OP-902-004, Excess Steam Demand Recovery Containment Spray is NOT needed for iodine removal.

INITIATING CUES:

The CRS directs you, to perform OP-902-009, Standard Appendices, Appendix 5 - E and reset CSAS.

JPM S6 Revision 1 Page 5 of 8 2010 NRC SRO Exam Evaluator Note When Applicant is ready, cue the simulator operator to place the simulator in RUN.

TASK ELEMENT 1 STANDARD 1.1 Place control switches for the following valves to CLOSE: CC-641, CCW RCP INLET OUTSIDE ISOL CC-710, CCW RCP OUTLET INSIDE ISOL CC-713, CCW RCP OUTLET OUTSIDE ISOL All 3 valve control switches are in CLOSED.

Comment: Critical SAT / UNSAT Evaluator Note To Reset CSAS Initiation relays, the following 4 steps must be performed on Channels A, B, C, and D.

TASK ELEMENT 2 STANDARD 1.2.a Place the Reset Permissive switch to "UNLK" position. (CP-10)

The applicable Reset

Permissive switch is in

UNLK. Comment: Applicant will need key 218 for this manipulation.

Critical SAT / UNSAT TASK ELEMENT 3 STANDARD 1.2.b Press CSAS Reset pushbutton.

CSAS Reset pushbutton is pressed. Comment: Critical SAT / UNSAT

JPM S6 Revision 1 Page 6 of 8 2010 NRC SRO Exam TASK ELEMENT 4 STANDARD 1.2.c Verify the initiation relay indicator lit on the ENGINEERED SAFETY FEATURES SYSTEM mimic.

Verification complete.

Comment: SAT / UNSAT TASK ELEMENT 5 STANDARD 1.2.d Place the Reset permissive switch to LK position The applicable Reset Permissive switch is in the

LK position.

Comment: This sequence must be repeated for Channels A - D.

Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 1.3.a Reset CSAS actuation logic on BOTH trains as follows: Press the CSAS Reset pushbuttons. (CP-33)

CSAS Reset pushbuttons A

& B have been de-pressed.

Comment: There are 2 buttons on CP-33 that must be pressed, 1 for Train A and 1 for Train B.

Critical SAT / UNSAT TASK ELEMENT 7 STANDARD 1.3.b Verify the actuation relay indicator lit on the ENGINEERED SAFETY FEATURES SYSTEM mimic. (CP-10)

CP-10 verification is

complete.

Comment: SAT / UNSAT

JPM S6 Revision 1 Page 7 of 8 2010 NRC SRO Exam TASK ELEMENT 8 STANDARD 1.4 Stop ONE CS pump at a time.

One Containment Spray Pump is secured.

Comment: Critical SAT / UNSAT TASK ELEMENT 9 STANDARD 1.5 IF a CS pump is operating, THEN stop the remaining CS pump.

Second Containment Spray Pump is secured.

Comment: Critical SAT / UNSAT TASK ELEMENT 10 STANDARD 1.6 Close the following Containment Spray valves: CS-125 A, CNTMT SPRAY HEADER A ISOL CS-125 B, CNTMT SPRAY HEADER B ISOL CS-125 A and CS-125 B are closed.

Comment: Control switch must be taken to OPEN and then to CLOSE.

Critical SAT / UNSAT TASK ELEMENT 11 STANDARD 1.7 Place BOTH Containment Spray pump control switches to normal position.

Both Containment Spray pump control switches are

in the normal (mid) position.

Comment: Critical SAT / UNSAT

END OF TASK

JPM S6 Revision 1 Page 8 of 8 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-198

Verify the following Malfunctions:

o Ms11b 25%

o Ch09 50%

Place the Simulator in Run on the lead examiner's cue.

Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

S7 Waste Condensate Tank Discharge

Applicant:

Examiner:

JPM S7 JOB PERFORMANCE MEASURE DATA PAGE Task: Waste Condensate Tank Discharge

Task Standard:

Applicant initiated Waste Condensate Tank release in accordance with OP-007-004, Liquid Waste M anagement System, and secured the release after the flow controller failed to maximum output.

References:

OP-007-004, Liqui d Waste Management System CE-003-514, Liquid Radioactive Waste Release Permit (Computer)

Alternate Path:

Yes Time Critical:No Validation Time:

15 mins.

K/A 068 A4.03, Stoppage of releases if limits Importance Rating 3.9 / 3.8 exceeded RO / SRO Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 7 2010 NRC SRO Exam JPM S7 Revision 1 Page 3 of 7 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-007-004, Liquid Wa ste Management System Discharge Permit for Waste Condensate Tank A

==

Description:==

The applicant will be tasked with initia ting a discharge of Waste Condensate Tank A. The cue will indicate that the operat or in the field has completed all required lineups and is standing by. When the applicant in itiates flow, the flow controller output will fail high, causing discharge flow to exc eed the 50 gpm permit flow limit. The flow controller will not be capable of securing flow. The applicant will stop discharge flow by

closing the discharge isolation valves.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will

provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.

Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then

give the cue sheet to the applicant.

JPM S7 Revision 1 Page 4 of 7 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

Waste Condensate Tank A has been prepared for discharge. The RCA Watch reports that he has comp leted step 6.10.6 in OP-007-004, Liquid Waste Management System, and that Atta chment 11.4, Waste Condensate Tank Discharge Checklist, is complete

INITIATING CUES:

The Control Room Supervisor directs you to commence discharging Waste Condensate Tank A, starting at step 6.10.7 of OP-007-004, Liquid Waste

Management System.

JPM S7 Revision 1 Page 5 of 7 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD 6.10.7 On CP-4, Reset Liquid Waste Discharge Flow Integrator to zero.

Integrator is reset to zero.

Comment: Critical SAT / UNSAT TASK ELEMENT 2 STANDARD 6.10.8 Record WCT level and Liquid Waste Discharge Integrator reading

on Liquid Release Permit.

Reading is recorded on the

Release Permit.

Comment: Critical SAT / UNSAT TASK ELEMENT 3 STANDARD 6.10.9 Verify Liquid Waste Discharge Flow Controller, LWM-IFIC-0647, in Manual with 0% output.

Verification complete.

Comment: SAT / UNSAT TASK ELEMENT 4 STANDARD Procedure Caution: If Circulating Water flow is reduced to less than that

required by the discharge permit, then discharge shall be secured

immediately.

Caution reviewed.

Comment: SAT / UNSAT

JPM S7 Revision 1 Page 6 of 7 2010 NRC SRO Exam Evaluator Note The combined control switch on CP-4 will open LWM-441 and give an open permissive to LWM-442.

LWM-442 is operated using controller LWM-IFIC-0647, also on CP-4.

Evaluator Note When flow rises above the trigger setpoint, the output of the controller will fail in the raise position. Flow will rise above the Permit limit of 50 gpm. The applicant will not be able to secure flow with the

controller. The applicant will be required to secure flow by closing LWM-441 and LWM-442 using the control switch.

TASK ELEMENT 5 STANDARD 6.10.10 To start discharging WCT, momentarily position Liquid Waste

Condensate Flow Control handswitch, LWM-441 and LWM-442, to Open and adjust flow using Liquid Waste Condensate Flow Controller, LWM-

IFIC-0647, not to exceed value specified on Liquid Release Permit.

LWM-441 is opened using

control switch.

LWM-442 is throttled open using controller.

Comment: The following step is the alternate path.

Critical SAT / UNSAT TASK ELEMENT 6 STANDARD Attempt to lower release flow using Liquid Waste Condensate Flow

Controller, LWM-IFIC-0647.

Applicant attempts to lower

flow using the lower

pushbutton.

Comment: Critical SAT / UNSAT TASK ELEMENT 6 STANDARD Position Liquid Waste Condensate Flow Control Switch for LWM-441 and

LWM-442 to Closed and verify LWM-441 and LWM-442 are closed.

LWM-441 and LWM-442

are closed.

Comment: Critical SAT / UNSAT END OF TASK

JPM S7 Revision 1 Page 7 of 7 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS If there are no gallons indicated on the LW M Flow totalizer, then reset to IC-20, discharge greater than 100 gallons of water, and then proceed with the Simulator setup.

Reset to IC-197

There are no Malfunctions for this JPM.

Verify the following Overrides:

o DI-04A3A12C-3 is overridden to PUSH

Verify the following Event Trigger settings:

Trigger 7 is set as zaowdlwmifif0647(2) > 0.2

R Type K2.33 Liquid Waste batch Release Permit Permit Number: LB2010-0052 Entergy Operations, Inc.Waterford Steam Electric Station Unit Ill______Release Point (1): Waste Condensate Tank A Waste Volume 14431 gal Maximum Waste Flow.50.00 gpm Minimum Diluhon Flow 5.00 e--5 gpm (2 Circ Water Pumps)Total Gamma Conc.: 1 04e-05 uCi, ml SINGLE Release Setpoint for PRM-IRE-0647 8.OOe-02 uCimI ADJUST**Concurrent with Permit Number LC2009-0043

(22)Dry Cooling Tower Sump#1 to Circ Water Concurrent with Permit Number LC2009-0044
(23)Dry Cooling Tower Sump#21 to Circ Water Concurrent with Permit Number LC2009-0045 (24)TGB Industrial Waste Sump to Circ Water Esttmated Maximum Organ Dose.0 00 mrem for the Adult Thyroid Estimated Cumulahve Maximum Organ Doses-Including this release.31 Day Quarter-To

-Date Year-To-Date Limit 0.06 mrem 1.50 mrem 3.00 mrem Organ Total Body Total Body Total Body 0.000 mrem 0.00 mrem 0.0029 mrem Special Conditions:

Adiust PRM-IRE-0647 radiation monitor setpoint to 8.00 e-02 uCi/mI prior to release.PRM-IRE-0647 setpoint to 6.50 e-01 uCi/mI after release permit is closed.Prepared By: Reviewed By: Approved By: S.ehi5t C.Suve'w&w'c C9L Supe'wiwt Date: IC/5/2CIC Date:!CISI2CIC Date: JC/SJ2CIC PRM-IRE-0647 Radiation Monitor Source Check: Channel Check: Circ.Water Flowrate: 750,000 gpm Date Time Tank Level%Flow Integrator (gal)Release Start__________

__________

____________________

___________________-

Release Finish__________

____________________

____________________

  • NET*mm._______________

_____________________

gall___________________

mm=_____________________

gpm=Average Waste Flow Rate (Flow Integrator)(Release Time)_____________________

gal_____________________

mm=_____________________

gpm-Average Waste Flow Rate (Plant Data Book)(Release Time)Radiation Monitor Readings for PRM-IRE-0647 10 minutes into release:_________________

uCi/m I After Flush: uCi/mI Remarks:_____________________

Release Completed By:__________________

Date/Time Operations Release Reviewed By:________________

Date/Time CRS/SM Release Reviewed By: Date/Time HP Forman/Designee BATCH RADIOACTIVE LIQUID EFFLUENT RELEASE REQUEST FORM OPERATIONS RELEASE POINT WasteCondensate Tank A]___________________________________________________

Boric Acid Condensate Tank A El B[1 C[]D El Laundry Tank A El a LI Waste Tank A[]B C El_____________

_______ACCW Basin A El El SGBD to Circ Water#1[#2{J Date/Time isolated iO//1_ofo O'700 Tank Volume BS.1°'Date/Time Placed on Recsrc 1O1/2OIO OS'oa#Circulating Pumps Running 3#Circulating Pumps Available________________

Waterbox 82 or Cl or C2 must be in operation Sat____Unsat Raci Waste Treatment System Used: Yes_____No El Action Statements Affecting Release:??on t 3O*gl4.Lf Time/Date peratio CHEMISTRY Tank Volume't, t t t 3f gal L Verified recirculation requirements have been satisfied prior to sampling for environmental analyses.F Recirculation time following tank neutralization has been satisfied prior to sampling for pH (if applicable).

n Verified all required environmental analysis parameters are within specifications.(Analysis results attached.)

I Calculated EPA Maximum Discharge Rate: EPA Maximum Discharge Rate (0.2 mg/L)x (Circ Water Flow)=_________gpm

_____________rnglL Boron Conc)1 Pump=250,000 gpm 3 Pumps=750000 gpm 2 Pumps 500,000 gpm 4 Pumps=1,000.000 gpm Maximum Discharge Rate 50 gpm (Lower of EPA Max Discharge rate or LRP Max Waste Flow)Chemistry Release Permit Number Approved by: C4 c cit1 Operat1ns CE-003-514 Revision 0 Attachment 12.1 (1 of 1)24a Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

P1 Reset Emergency Feedwater Pump AB

Applicant:

Examiner:

JPM P1 JOB PERFORMANCE MEASURE DATA PAGE Task: Reset overspeed device on Emergency Feedwater Pump AB during a Station Blackout.

Task Standard:

The overspeed device on Emergency Feedwater Pump AB was reset in accordance with OP-902-005, Station Blackout Recovery.

References:

OP-902-005, Station Blackout Recovery Alternate Path:

No Time Critical:No Validation Time:

10 mins. K/A 061 A2.04, Pump failure or improper operation Importance Rating 3.4 / 3.8 RO / SRO Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 8 2010 NRC SRO Exam JPM P1 Revision 1 Page 3 of 8 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-902-005, Station Blackout Recovery

==

Description:==

This task takes place in the RCA. The task takes place during a simulated

Station Blackout. This requires the applicant to simulate manual operation of MS-416, Emergency Feedwater Pump AB Trip Valve. All components are located on the -35

elevation. This JPM takes place in a lo cation with numerous pipes and supports that are bump hazards, but no special PPE will be r equired for this task. There are no special radiological requirements to perform this task.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All steps for this

JPM will be simulated , do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when

directed by you. Indicate to me when you understand your assigned task.

Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.

JPM P1 Revision 1 Page 4 of 8 2010 NRC Walk Through Exam APPLICANT CUE SHEET

Do Not Manipulate Any Plant Components

(TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

A Station Blackout event is in progress Emergency Feedwater Pump AB has tripped on an overspeed condition The Control Room has closed MS-401 A and MS-401 B.

INITIATING CUES:

The CRS directs you to reset Emergency Feedwater Pump AB in accordance with OP-902-005, Station Bla ckout Recovery, step 10.

JPM P1 Revision 1 Page 5 of 8 2010 NRC Walk Through Exam TASK ELEMENT 1 STANDARD 10.1.a. Close BOTH PUMP AB TURB STM SUPPLY valves: MS-401 A and MS-401 B.

Provided in the cue.

Comment: SAT / UNSAT Evaluator Note MS-407 is located at ground level against the wall when approaching EFW Pump AB.

TASK ELEMENT 2 STANDARD 10.1.b. Locally verify the steam supply header depressurized using MS-407, EFW Pump AB Drip Pot Normal Drain Bypass.

Verification complete.

Comment: Examiner cue: MS-407 fails open on a loss of power. Provide cue to the applicant that MS-407 is open (upper limit switch engaged), stem fully up, with no sound of steam flow.

There is a handwheel on MS-407. Closing MS-407 after verification is not required. If the applicant does close MS-407, provide the cue that as the handwheel is turned clockwise, the MS-407 stem moves down to the

closed position.

SAT / UNSAT

Evaluator Note MS-416 trips closed on an overpseed. In a Station Blackout, MS-416 MOV must be manually operated

in the closed direction to position the valve for reset. The physical indication as this operation is performed would be the trip bar moving from a low, tripped position up to the trip latch.

JPM P1 Revision 1 Page 6 of 8 2010 NRC Walk Through Exam Evaluator Note MS-416 in the tripped position before and after MOV is manually operated. As the applicant turns the handwheel in the clockwise direction, the bar will move from the lower position to the upper position.

TASK ELEMENT 3 STANDARD 10.1.c. Locally close MS 416, EFW Pump AB Turbine Stop Valve.

MS-416 is operated in the

closed direction.

Comment: Examiner cue: Latch bar moves from the lower position to the upper position as MS-416 handwheel is turned in the closed/clockwise

direction.

Critical SAT / UNSAT

JPM P1 Revision 1 Page 7 of 8 2010 NRC Walk Through Exam Evaluator Note The overspeed device is reset by moving the trip bar towards MS-416, by holding the rod and moving it from right to left.

The tappet nut drops down when bar is moved right to left.

TASK ELEMENT 4 STANDARD 10.1.d. Verify mechanical Overspeed reset.

Overspeed device is reset.

Comment: Examiner cue: Bar moves to the left, tappet nut drops down and stays down, bar maintains its position when released.

Critical SAT / UNSAT

JPM P1 Revision 1 Page 8 of 8 2010 NRC Walk Through Exam Evaluator Note MS-416 in the closed position and the open position, before and after the MOV is manually operated.

As the applicant turns the handwheel in the counter clockwise direction, the stem and gland assembly will move from the lower position to the upper position.

TASK ELEMENT 5 STANDARD 10.1.e. Locally open MS 416, EFW Pump AB Turbine Stop Valve.

MS-416 is manually

opened. Comment: Examiner cue: Stem and gland assembly move up as the handwheel is turned in the counter clockwise direction.

Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 10.1.f. Open BOTH PUMP AB TURB STM SUPPLY valves. MS 401A MS 401B Communication made to

the Control Room.

Comment: SAT / UNSAT END OF TASK

Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

P2 Restore Power to the DCT Sump Pumps Following a Loss of Off Site Power

Candidate:

Examiner:

JPM P2 JOB PERFORMANCE MEASURE DATA PAGE Task: Restore power to the DCT Sump Pumps following a Loss of Off Site Power.

Task Standard:

Dry Cooling Tower Sump 1 and 2 Sump Pumps are energized.

References:

OP-902-009, Standard Appendice s, Appendix 20 Operation of DCT Sump Pumps Alternate Path:

No Time Critical:No Validation Time:

10 mins. K/A 008 2.4.34 Knowledge of RO tasks performed Importance Rating 4.2 / 4.1 outside the main control room during an emergency RO / SRO and the resultant operational effects Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 6 2010 SRO NRC Exam JPM P2 Revision 1 Page 3 of 6 2010 SRO NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-902-009, Standard Appendices, Appendix 20, Operation of DCT Sump Pumps

==

Description:==

Candidate will strip non-safety loads from MCC 314 A and 314 B. The safety to non-

safety bus tie breaker will then be closed. The task is complete after the breakers

are closed to all 4 DCT Sump pumps. All el ements of this JPM are performed at the 314 A/B Switchgear area on the +1 leve l of the Fuel Handling Building.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated , do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other

actions when directed by you. Indicate to me when you understand your assigned

task.

Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then

give the cue sheet to the applicant.

JPM P2 Revision 1 Page 4 of 6 2010 SRO NRC Exam TASK ELEMENT 1 STANDARD At MCC 314A(B), place the following switches to Bypass: DCT #1 Sump Pump A Radiation Monitor bypass switch DCT #2 Sump Pump A Radiation Monitor bypass switch DCT #1 Sump Pump B Radiation Monitor bypass switch DCT #2 Sump Pump B Radiation Monitor bypass switch All 4 switches are in bypass. Comment: Evaluator: The names listed in the procedure do not exactly match the label posted on each breaker. If the candidate calls to inform the CRS, acknowledge the communication and inform the candidate to proceed.

Critical Step SAT / UNSAT TASK ELEMENT 2 STANDARD Open ALL MCC-314A nonsafety load breakers.

All breakers on the non-safety side of MCC-314 A

are open.

Comment: The non-safety side of MCC 314 A will be the right side of the tie breaker, where all of the breaker cubicle numbers are > 2.

Critical Step SAT / UNSAT TASK ELEMENT 3 STANDARD Close SSD-EBKR-314A-2M, MCC 314A Safety to Nonsafety Tie.

SSD-EBKR314 A-2M is closed. Comment: Evaluator: The green light will be lit and the green open flag will be displayed before the manipulation. The red light will be lit and the red close flag will be displayed after the manipulation.

Critical Step SAT / UNSAT

JPM P2 Revision 1 Page 5 of 6 2010 SRO NRC Exam TASK ELEMENT 4 STANDARD Close the following supply breakers: SP-EBKR-314A-4F, West Dry Cooling Tower Sump Pump A SP-EBKR-314A-5F, East Dry Cooling Tower Sump Pump A Both breakers are closed.

Comment: Critical Step SAT / UNSAT TASK ELEMENT 5 STANDARD Open ALL MCC-314B nonsafety load breakers.

All breakers on the non-safety side of MCC-314 B

are open.

Comment: The non-safety side of MCC 314 B will be the left side of the tie breaker, where all of the breaker cubicle numbers are > 2.

Critical Step SAT / UNSAT TASK ELEMENT 6 STANDARD Close SSD-EBKR-314B-2M, MCC 314B Safety to Nonsafety Tie.

SSD-EBKR314 B-2M is closed. Comment: Evaluator: The green light will be lit and the green open flag will be displayed before the manipulation. The red light will be lit and the red close flag will be displayed after the manipulation Critical Step SAT / UNSAT TASK ELEMENT 7 STANDARD Close the following supply breakers: SP-EBKR-314B-4F, West Dry Cooling Tower Sump Pump B SP-EBKR-314B-5F, East Dry Cooling Tower Sump Pump B Both breakers are closed.

Comment: Evaluator: If the candidate asks about a PMP event, inform him that there

is no PMP event.

Critical Step SAT / UNSAT END OF TASK

JPM P2 Revision 1 Page 6 of 6 2010 SRO NRC Exam APPLICANT CUE SHEET

Do Not Manipulate Any Plant Components

(TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The Plant has experienced a Loss of Offsite Power and recovery actions of OP-902-003 are being performed. Emergency Diesel Generators A and B ar e supplying power to Train A and Train B Safety Buses with both Sequencers timed out.

INITIATING CUES:

The CRS has directed you to restore power to the DCT Sump Pumps 1A, 2A, 1B, and 2B in accordance with OP-902-009, Appendix 20.

Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE

P3 SUPS 014 AB Operation

Applicant:

Examiner:

JPM P3 JOB PERFORMANCE MEASURE DATA PAGE Task: Transfer SUPS 014 AB from Alternate to Normal AC power

Task Standard:

SUPS 014 AB was transferr ed from Alternate to Normal AC alignment in accordance with OP-006-005, Inverters and Distribution.

References:

OP-006-005, Inverters and Distribution Alternate Path:

Yes Time Critical:No Validation Time:

20 mins.

K/A 062 A3.04, Operation of invert er Importance Rating 2.7 / 2.9 RO / SRO Applicant:

Time Start:

Time Finish:

Performance Time:

minutes Performance Rating:

SAT UNSAT Comments:

Examiner:

Date: Signature Revision 1 Page 2 of 11 2010 NRC SRO Exam JPM P3 Revision 1 Page 3 of 11 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-006-005, Inverters and Distribution

==

Description:==

SUPS 014 AB will be simulated in the Alternate AC power alignment. Applicant

will transfer SUPS 014 AB to the Normal AC alignment. All steps will be simulated in

Switchgear Room A. No specia l PPE will be required for this task. There is a summary of the initial break er positions and the initial meter readings before the task elements.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All steps for this

JPM will be simulated , do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when

directed by you. Indicate to me when you understand your assigned task.

Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then

give the cue sheet to the applicant.

JPM P3 Revision 1 Page 4 of 11 2010 NRC SRO Exam APPLICANT CUE SHEET

Do Not Manipulate Any Plant Components

(TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

SUPS 014 AB is in the Alternate AC alignment The inverter was isolated in a ccordance with OP-006-005, Inverters and Distribution, step 6.5.2.7.

INITIATING CUES:

The CRS directs you to place SUPS 014 AB in the Normal AC alignment in accordance with OP-006-005, Inverters and Distribution, section 6.5.3.

JPM P3 CB1M1M2M3 M6CB2CB5CB4 M7 M5 M4I-1I-2I-3I-6I-5I-4PB-2PB-3PB-1PB-4PB-5 S4BC A 13 2 1 2 34 5 6CB3 S1 S2 S3 ALTERNATE FEEDER OUTPUT TO PDPBYPASS NORMAL FEEDEREMERGENCYFEEDER TRANSFER TESTSTATIC SWITCH RETRANSFERAUTOINHIBIT Open / OffClosed / On Open / OffOpen / OffOpen / Off Revision 1 Page 5 of 11 2010 NRC SRO Exam

JPM P3 Revision 1 Page 6 of 11 2010 NRC SRO Exam Indications METERS Item Designation Comment M1 Inverter Input Voltage (0-150 VDC)

Voltage reads zero until AC power is applied to the rectifie r at step 6.5.3.1.1.

M2 Inverter Input Current (0-400 DC Amps)

Current reads zero until AC power is

applied to the rectifie r at step 6.5.3.1.1.

M3 Battery Current (400 amps discharge to 400 amps charge)

Reads as displayed throughout evolution.

M4 Battery Recharge Timer (0-30 Hours)

Reads as displayed throughout evolution.

M5 AC Voltage (0-250 VAC)

In the Inve rter position, Voltage reads zero until step 6.5.3.9.

In the UPS position, voltage reads zero until step 6.5.3.4.

M6 Frequency (57-63 Hz)

Frequency reads 60 (center) until step 6.5.3.9. M7 UPS Output Current (0-150 Amps AC)

System load current reads zero until step

6.5.3.6.

INDICATOR LIGHTS

Item Designation Indication I-1 Inverter Phase Locked I lluminates at step 6.5.3.9.

I-2 High-Low DC Voltage Illuminated at the start of the JPM, clears at step 6.5.3.1.

I-3 Inverter Output Overload Remains OFF during JPM.

I-4 Over temperature Remains OFF during JPM.

I-5 Static Switch Inhibited Illu minated at the start of the JPM, clears at step 6.5.3.3.

I-6 Static Switch On Reserve Cl ear at the start of the JPM, illuminates at step 6.5.3.4.

JPM P3 Revision 1 Page 7 of 11 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD 6.5.3.1.1 Place Normal Feeder breaker to ON.

Breaker is ON.

Examiner Cue: Breaker will be OFF on arrival, provide cue of breaker being moved from OFF to ON.

Comment: Meters M1 and M2 move to read as is after this step is performed.

Critical SAT / UNSAT TASK ELEMENT 2 STANDARD 6.5.3.1.2 Verify Inverter Input Voltage > 121 VDC, then place

Emergency Feeder breaker to ON.

Breaker is ON.

Examiner Cue: Breaker will be OFF on arrival, provide cue of breaker

being moved from OFF to ON.

Comment: Critical SAT / UNSAT TASK ELEMENT 3 STANDARD 6.5.3.1.3 Depress and release Inverter Operate pushbutton.

Pushbutton is pressed and

released.

Comment: Critical SAT / UNSAT TASK ELEMENT 4 STANDARD 6.5.3.2 Verify SUPS 014AB Static Switch Retransfer toggle switch in

INHIBIT. Verification complete. Examiner Cue: The Static Switch Retransfer toggle switch will already

be in INHIBIT.

Comment: SAT / UNSAT

JPM P3 Revision 1 Page 8 of 11 2010 NRC SRO Exam TASK ELEMENT 5 STANDARD 6.5.3.3 Place SUPS 014AB Alternate Feeder breaker to ON.

Breaker is ON.

Examiner Cue: Breaker will be OFF on arrival, provide cue of breaker being moved from OFF to ON.

Comment: The Static Switch Inhibited light goes OFF when this is performed.

Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 6.5.3.4 Depress and release SUPS 014AB Static Switch Transfer Test

pushbutton.

Test pushbutton depressed

and released.

Comment: The Static Switch On Reserve light illuminates when this is performed.

Critical SAT / UNSAT TASK ELEMENT 7 STANDARD 6.5.3.4.1 Verify Static Switch On Reserve light Illuminates.

Verification complete.

Comment: SAT / UNSAT TASK ELEMENT 8 STANDARD 6.5.3.5 Depress and release SUPS 014AB Lamp Test/Reset pushbutton.

Pushbutton depressed and

released.

Comment: Critical SAT / UNSAT

JPM P3 Revision 1 Page 9 of 11 2010 NRC SRO Exam TASK ELEMENT 9 STANDARD 6.5.3.5.1 Verify Static Switch On Reserve light remains Illuminated.

Verification complete.

Comment: SAT / UNSAT TASK ELEMENT 10 STANDARD 6.5.3.6 Place SUPS 014AB Output To PDP014AB breaker to ON.

Breaker is ON.

Examiner Cue: Breaker will be OFF on arrival, provide cue of breaker

being moved from OFF to ON.

Comment: Critical SAT / UNSAT TASK ELEMENT 11 STANDARD 6.5.3.7 Place SUPS 014AB Bypass breaker to OFF.

Breaker is OFF.

Examiner Cue: Breaker will be ON on arrival, provide cue of breaker

being moved from ON to OFF.

Comment: Critical SAT / UNSAT TASK ELEMENT 12 STANDARD 6.5.3.8 Place SUPS 014AB AC Voltage Select Switch to INVERTER.

Select Switch is verified in

INVERTER.

Examiner Cue: The AC Voltage Select Switch could be in what ever

position the last watch stander left it in.

Comment: SAT / UNSAT

JPM P3 Revision 1 Page 10 of 11 2010 NRC SRO Exam Evaluator Note When applicant observes the SUPS Output Voltage meter, provide indication of zero volts.

If the applicant presses the Operate pushbutton, prov ide the indications provided in Task Element 13.

If the applicant does not press the Operate pushbutton, t hen provide the indication that the Static Switch On Reserve light is still illuminated at Task Element 16.

TASK ELEMENT 13 STANDARD 6.5.3.9 If no voltage is indicated, then depress and release SUPS 014AB

Inverter Operate pushbutton, and verify the following: Inverter Phase Locked light Illuminated Inverter Output voltage CN ~120 VAC (118.8 to 121.2 VAC) Inverter Output voltage AN ~120 VAC (118.8 to 121.2 VAC) Inverter Output voltage BN ~120 VAC (118.8 to 121.2 VAC) Inverter Output frequency ~60 Hz (59.97 to 60.03 Hz)

Observes no voltage in any Inverter position and

presses and releases the

Operate pushbutton.

Comment: The applicant must use the multi-selector switch and move through these positions. There will be no voltage indicated in any Inverter position. If the applicant observes any UPS position, voltage will be as indicated.

Critical SAT / UNSAT

TASK ELEMENT 14 STANDARD 6.5.3.10 Place SUPS 014AB Static Switch Retransfer toggle switch to

AUTO. Toggle Switch is in Auto.

Examiner cue: Static Switch Retransfer toggle switch will be in INHIBIT

at this point, cue that the switch is moved from INHIBIT to AUTO.

Comment: Critical SAT / UNSAT

JPM P3 Revision 1 Page 11 of 11 2010 NRC SRO Exam TASK ELEMENT 15 STANDARD 6.5.3.11 After approximately 30 seconds, depress and release SUPS 014AB Lamp Test/Reset pushbutton.

Pushbutton pressed and

released.

Examiner cue: 30 seconds have elapsed. After this pushbutton is

depressed, the Static Switch On Reserve light will extinguish.

Comment: Critical SAT / UNSAT TASK ELEMENT 16 STANDARD 6.5.3.11.1 Verify Static Switch On Reserve light Extinguished.

Verification complete.

Comment: SAT / UNSAT END OF TASK

Appendix D Scenario Outline Form ES-D-1 Scenario 1 Rev 1 Facility: WATERFORD 3 Scenar io No.: 1 Op Test No.:

NRC Examiners:

Operators:

Initial Conditions: 100%, 125 EFPD, AB buses aligned to Train B Protected Train is B Emergency Diesel Generator A is out of service.

Turnover: Maintain 100 % power Event No. Malf. No.

Event Type* Event Description 1 H_105 I - ATC I - SRO Remove Reactor Power Cutback from service in accordance with OP-004-015.

2 RC22F2 TS - SRO I - SRO Pressurizer pressure instrument RC-IPI-0102 B fails low.

3 SG01B CV02C TS - SRO C - SRO C - ATC Steam Generator 2 tube leakage Charging Pump AB fails to auto start 4 N/A R- ATC N-BOP N-SRO Rapid Plant Power Reduction due to Steam Generator tube leakage.

5 RC08A RC09A RC10A C - ATC C - SRO Reactor Coolant Pump 1A seal failure, manual reactor trip 6 SG01B M-All Steam Generator #2 Tube Rupture 7 RP08C C - ATC C - SRO Containment Isolation CVC-401 fails to auto close on CIAS 8 MS11B M - All Main Steam li ne break on Steam Generator 2 inside Containment. * (N)ormal, (R)eactivi ty, (I)nstrument, (C)omponent, (M)ajor

Scenario Event Description NRC Scenario 1 Scenario 1 Rev 1 The crew assumes the shift at 100% power with instructions to maintain 100% power.

After assuming the shift, annunciator H1005, Reactor Power Cutback Single Channel Trouble, alarms and Reactor Power Cutba ck auto actuation fails. The crew will be contacted by I&C maintenance after re viewing the annunciator response procedure

describing a failure of Reactor Power Cut back, requiring Reactor Power Cutback be removed from service in accordance with OP-004-015, Reactor Power Cutback. This manipulation is performed by the ATC operator at CP-2 and CP-7.

After Reactor Power Cutback is removed from service, Pressurizer pressure instrument RC-IPI-0102 B fails low. The AT C operator will receive the annunc iators for this failure. The CRS should evaluate Tech Specs and enter Tech Spec 3.3.1 and 3.3.2 and determine that Plant Protection System bistable 6 for low Pressurizer pressure must be bypassed within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> on C hannel B. Tech Spec 3.

3.3.5 and 3.3.3.6 should be referenced but not entered. Plant Monito ring Computer group SPD S indication of Pressurizer pressure is affected by this failure.

After the CRS evaluates Tech Specs but before bistable 6 is bypassed, a Steam Generator tube leak develops in Steam Generator 2. Charging Pump AB will be aligned as the first backup Charging Pump and it will fail to auto start on the lowering

Pressurizer level. The ATC operator should make this diagnosis and start Charging Pump AB. The CRS should enter OP-901-202, Steam Generator Tube Leakage or High Activity. The size of the leak will require entering OP-901-212, Rapid Plant Power Reduction. For the power reduction, the ATC will perform Direct Boration to the RCS as well as Pressurizer boron equalization and ASI control with CEAs. The BOP will manipulate the controls to reduce Main Turbine load. The CRS should enter Tech Spec

3.4.5.2 for Steam Generator 2 leakage. The CRS may consider declaring Charging Pump AB inoperable due to it's failure to auto start, but no Tech Spec entry is required.

Once the crew has commenced the power reduc tion and lowered power to ~ 90%, or at the lead examiner's cue, RCP 1a will develop multiple seal failures. The second and third seal failures will occur after the crew has entered the appropriate off normal. The crew should enter off no rmal procedure OP-901-130, Reactor Coolant Pump Malfunction, before the subsequent seals fail. With the second and third seals failing, the crew will be required to trip the reactor.

When the reactor is tripped, the Steam Genera tor tube leak will degr ade to a rupture. The CRS should direct the ATC to initiate Sa fety Injection and Containment Isolation.

Containment Isolation valve CVC-401 at CP-4 will fail to close on the CIAS, requiring

the ATC operator to close the valve.

Scenario Event Description NRC Scenario 1 Scenario 1 Rev 1 After the crew completes OP-902-000, Standard Post Trip Actions and the CRS diagnoses into OP-902-007, Steam Generator Tube Rupture Recovery, the CRS should direct a rapid RCS cooldown to less than 520 °F T HOT. After this direction is given, a Main Steam Line break will develop on Stea m Generator 2 inside Containment. The CRS should exit OP-902-007 and enter OP-902-008, Functional Recovery Procedure.

Prioritization in OP-902-008 should result in Containment Isolation being priority 1. The crew should address Containment Isolation by using the steps in the Heat Removal section to isolate Steam Generator 2.

The scenario can be terminated after Steam G enerator 2 is isolat ed, or at the lead examiners discretion.

Scenario Event Description NRC Scenario 1 Scenario 1 Rev 1 Critical Tasks

1. Trip any RCP not satisfying RCP operating limits.

This task is satisfied by securing all RCPs within 3 minutes of loss of CCW flow. The required task becomes applicable after Containment Spray has been actuated. The time requirement of 3 minutes is based on the RCP operating limit of 3 minutes without CCW cooling.

2. Prevent Opening the Main Steam Safety Valves.

This task is satisfied by the crew taking action to maintain Steam Generator #2 pressure below the safety valve setpoint by taking action to reduce RCS pressure to < 945 psia.

Scenario Quantitative Attributes

1. Total malfunctions (5-8) 8 2. Malfunctions after EOP entry (1-2) 2 3. Abnormal events (2-4) 3 4. Major transients (1-2) 2 5. EOPs entered/requiring substantive actions (1-2) 2 6. EOP contingencies requiring substantive actions (0-2) 1 7. Critical tasks (2-3) 2

NRC Scenario 1 Scenario 1 Rev 1 Scenario Notes:

A. Reset Simulator to IC-191.

B. Verify the following Scenario Malfunctions are loaded:

1. rc22f2 for Pressurizer le vel instrument RC-ILI-0102 B
2. sg01B for Steam Generator #2 tube leak
3. cv02c for Charging Pump AB
4. rc08a, 09a, and 10a for RCP 1A
5. rp08c for CVC-401
6. ms11b for Steam Generat or #2 steam line break
7. eg10a for EDG A overspeed device C. Verify the following remotes
1. egr27 for EDG B local alarm acknowledgement D. Verify the following overrides
1. di-08a05s14-1 for closing FP-601 A set to trigger 9
2. di-08a05s19-1 for closi ng IA-909 set to trigger 9
3. di-04a04s10-1 for closing CVC-109 set to trigger 9
4. di-02a05a2s34-0 for Reactor Power Cutback out of service set to trigger 1.
5. di-02a05a2s30-0 for Reactor Power Cutback lamp test.

E. Verify the following under Event Triggers:

1. zdirpciastrp(4).eq.1 is set on trigger 9 F. Verify the following C ontrol Board Conditions:
1. Danger tag placed on EDG A control switch
2. Danger tag placed on EDG A Output Breaker G. Verify EDG A output breaker is racked out and place danger tags on EDG A and its output breaker.

H. Ensure Protected Train B sign is placed in SM office window.

I. Verify EOOS is 8.5 Yellow

J. Complete the simulator setup checklist.

K. Start DCS, Record Data, select file PlantParameters.txt.

NRC Scenario 1 Scenario 1 Rev 1 Simulator Booth Instructions Event 1 Reactor Power Cutback Failure

1. On Lead Examiner's cue, initiate Event Trigger 1.
2. After the annunciator response procedure is referenced, call the CRS as the on shift I&C technician. R eport that during planned data collection, the Reactor Power Cutback Channel A has locked up and will not respond to any commands or signals.
3. If Work Week Manager is called, inform the caller that a work package will be assembled and a team will be sent to the Control Room.

Event 2 Pressurizer Pressure Instru ment RC-IPI-0102 B Fails Low

1. On Lead Examiner's cue, initiate Event Trigger 2.
2. If Work Week Manager or I&C is called, inform the ca ller that a work package will be assembled and a team will be sent to the Control Room.
3. If sent to LCP-43, report RCS pressu re indications are reading normal on all channels except for Channel B.

Event 3 / 4 Steam Generator #2 Tube Leak / Charging Pump AB Fails to Start / Rapid Plant Power Reduction

1. On Lead Examiner's cue, initiate Event Trigger 3.
2. If Chemistry or HP is called, acknowledge S/G tube leak and need to carry out the actions of UNT-005-032, Steam Gener ator Primary to Secondary Leakage.
3. If called as TGB watch to monitor Condensate System Polisher pressure, acknowledge and remove Polisher Vessel from service if necessary.
4. If called as the RCA Watch to check C harging Pump AB, report that it looks normal locally.

Event 5 Reactor Coolant Pump 1A seal failure

1. On Lead Examiner's cue, initiate Event Trigger 5.
2. If Engineering is called, acknowledge communication and report that engineering will investigate the RCP 1A failure.
3. If called as the RAB Watch to check RCP vibration in Switchgear room B, acknowledge communication, no report is necessary.
4. Initiate Event Trigger 12 after the crew has entered OP-901-130.

NRC Scenario 1 Scenario 1 Rev 1 Event 4 Steam Generator #2 Tube Rupture

1. On Lead Examiner's cue, initiate change the severity of malfunction SG01B to 7% and ramp it in over a 1 minute period.
2. If called as RAB watch to check Emergen cy Diesel Generator B, initiate Trigger 16, after EDG B Trouble alarm clear, report it is running satisfactorily.

Event 5 Steam Generator #2 Steam Line Break

1. After the crew has entered OP-902-007 and commenced the rapid cooldown and on the Lead Examiner's cue, in itiate Event Trigger 7.

At the end of the scenario, before resetting, complete data collection by stopping recording and saving the file as 2010 SRO Scenario1.cdf NRC Scenario 1 Scenario 1 Rev 1 Scenario Timeline: Event Malfunction Severity Ramp HH:MM:SS Delay Trigger 1 H_L05 N/A N/A N/A 1 Remove Reactor Power Cutback from service 1 DI-02A05A2S34-0 N/A N/A N/A 1 Reactor Power Cutback Auto Actuate 1 DI-02A05A2S30-0 N/A N/A N/A 1 Remove Reactor Power Cutback Lamp Test 2 RC22F2 N/A N/A N/A 2 Pressurizer pressure instru ment RC-IPI-0102 B fails low 3 SG01 B 0.6 % 00:3:00 NA 3 Steam Generator #2 Tube Leak 4 CV02C N/A N/A N/A N/A Charging Pump AB fails to auto start 5 RC08 RC09 RC10 A 100 % 00:30 00:30 00:30 N/A 5 12 12 Reactor Coolant Pump 1A seal failures 6 SG01 B 7.0 % 00:01:00 N/A N/A Steam Generator #2 Tube Rupture 7 RP08C N/A N/A N/A N/A CVC-401 fails to close on CIAS 8 MS11B 12 % 03:00 N/A 8 Main Steam Line Break S/G 2

NRC Scenario 1 Scenario 1 Rev 1

REFERENCES:

Event Procedures 1 OP-004-015, Reactor Power Cutback System 2 OP-009-007, Plant Protection System Tech Spec 3.3.1 and 3.3.2 3 OP-901-202, Steam Generator Tube Leakage or High Activity Tech Spec 3.4.5.2 4 OP-901-212, Rapid Plant Power Reduction Tech Spec 3.1.3.6 Regulating an d Group P CEA Insertion Limits 5 OP-901-130, Reactor C oolant Pump Malfunction 6 OP-902-000, Standard Post Trip Actions OP-902-007, Steam Generator Tube Rupture Recovery OP-902-009, Standard Appendices, Append ix 1, Diagnostic Flow Chart 8 OP-902-008, Safety Function Recovery Procedure OP-902-009, Standard Appendic es, Appendix 13, Stabilize RCS Temperature

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 Page 1 of 24 Event

Description:

Remove Reactor Power Cutback from Service Time Position Applicant's Actions or Behavior ATC Recognize and report indications of failed Cutback Channel.

Alarms: Reactor Pwr Cutback Single Chnl Trouble (Cabinet H, L-5)

Indications:

Reactor Power Cutback AUTO ACTUATE OUT OF SERVICE pushbutton illuminated on CP-2 ATC Annunciator response OP-500-008 will direct reference to OP-004-015, Reactor Power Cutback System.

CRS Refers to and directs the actions of OP-004-015, Reactor Power Cutback System. CRS After receiving phone call from I&C Maintenance, directs ATC to remove Reactor Power Cutback from service.

BOP Step 8.1.2.1 Verify 65% bistable lamps on all four Nuclear Instrumentation Test Drawers Illuminated.

Lamps are located behind the main panels on CP-10 A - D.

ATC Step 8.1.2.2 On CP-7, verify all four LOSS OF TURB BYPASS keyswitches in BYPASS and all four red BYPASS lamps Illuminated.

ATC Step 8.1.2.3 On CP-2, place LOSS OF TURBINE TRIP keyswitch to ENABLE. ATC Step 8.1.2.4 On CP-7, place all four LOSS OF TURB BYPASS keyswitches to OFF and verify all four green OFF lamps Illuminate.

BOP Step 8.1.2.5 On Steam Bypass Control System Cabinet (IC-ECP-05), verify Reactor Power Cutback lamps Extinguished.

Lamps are located behind the main panels on CP-05, which is not modeled. Coach surrogate on this report.

If the ATC turns over to the BOP and performs this step himself, cue the ATC operator when he gets behind the panel that all Reactor Power Cutback lamps are extinguished.. Scenario 1, Revision 1 Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 Page 2 of 24 Event

Description:

Remove Reactor Power Cutback from Service Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 ATC Step 8.1.2.6 On CP-2, place LOSS OF LOAD keyswitch to TURBINE TRIP.

CRS Step 8.1.2.7 Notify the Duty Plant Manager that Loss of Turbine Trip has been placed in service.

Examiner Note This event is complete after the ATC operator addresses the AUTO ACTUATE OUT OF SERVICE pushbutton at step 8.1.2.7.

Or As directed by the Lead Evaluator

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 2 Page 3 of 24 Event

Description:

Pressurizer pressure instrument RC-IPI-0102 B fails low.

Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 ATC Recognize and report indications of failed channel.

Alarms: RPS CHANNEL TRIP PZR PRESSURE LOW (Cabinet K, A-16)

PZR PRESSURE LO PRETRIP B/D (Cabinet K, C-16)

RPS CHANNEL B TROUBLE (Cabinet K, F-18)

Indications Pressurizer pressure instrument RC-IPI-0102 B on CP-7 and CP-2 and CP-4 indicate pegged low.

Pressurizer pressure indication on the Plant Monitoring Computer mimic SPDS averages the failed indicator with valid pressure indication.

Pressurizer Pressure Lo trip and pre-trip lamps lit on CP-7 Channel B.

CRS Review Tech Specs based on the failed instrument.

Refer to Tech Spec 3.3.3.5 and 3.3.3.6.

Enter Tech Spec 3.3.1 (item 5) and 3.3.2 (items 1 and 3)

Direct bypassing Channel B bistable 6 for Lo Pressurizer Pressure. This is a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> action.

Note OP-903-013, Monthly Channel Checks, does list this instrument for Tech Spec 3.3.3.5 and 3.3.3.6 applicability. Entry is not required, however, because the minimum channel requirements will still be met after the failure.

Examiner Note This event is complete after the CRS evaluates Tech Specs Or As directed by the Lead Evaluator

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 4 of 24 Event

Description:

Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 ATC Recognize and report indications of Steam Generator Tube Leakage.

Alarms: RAD MONITORING SYS ACTIVITY HI-HI (Cabinet L, A-9)

VACUUM PUMPS EXHAUST ACTIVITY HI (Cabinet E, C-3)

Indications RM-11 Rad Monitor indication will display rising activity on Main Steam Rad Monitor #2, Steam Generator #2 N-16 Rad Monitor, Main Condenser Vacuum Pumps WRGM, and the Blowdown radiation monitor. Steam Generator tube leakage indication rising as indicated on PMC Group PSLR (PMC PID C48304).

CRS Enter and direct the implementation of OP-901-202, Steam Generator Tube Leakage or High Activity.

Examiner Note The following steps are from OP-901-202, Steam Generator Tube Leakage or High Activity.

CRS 1. IF Pressurizer level CAN NOT be maintained with available Charging Pumps, THEN perform the following: 1.1 Manually trip Reactor. 1.2 Manually initiate Safety Injection Actuation (SIAS)

AND Containment Isolation Actuation (CIAS).

1.3 GO TO OP-902-000, STANDARD POST TRIP ACTIONS.

CRS Procedure NOTE (1) The calculated Primary to Secondary Leak Rate values must be considered valid, unless the reading can be quickly diagnosed as incorrect due to an obvious malfunction of the PMC or AE Discharge Rad Monitor. (2) The AE Discharge Rad Monitor is considered the primary Rad Monitor which has the sensitivity to measure small Primary to Secondary Leakage. The AE Discharge Rad Monitor reading inputs into the Primary to Secondary Leak Calculation on PMC Group PLSR. The MS Line N16 Rad Monitors may be used as verification of AE Discharge Rad Monitor or as primary indication if the AE Discharge Rad Monitor is OOS.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 5 of 24 Event

Description:

Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 CRS 2. Determine RCS leak rate using ANY of the following: Calculated Steam Generator leakage displayed on PMC Group PSLR (PMC PID C48304) Calculated Steam Generator leakage displayed on PMC PID C48251 (RE5501 CH1 LEAK RATE) and C48252 (RE5501 CH2 LEAK RATE) Approximate RCS leak rate by subtracting total of Letdown flow AND RCP CBO flow from Charging Flow Calculated Charging / Letdown Mismatch displayed on PMC Group Leakrate (PMC PID S13001) RCS Leak Rate calculation in accordance with OP-903-024, REACTOR COOLANT SYSTEM WATER INVENTORY BALANCE Calculated steam generator leakage based upon chemistry sample, per CE-003-705, Determination Of Primary-To-Secondary Leak Rate CRS Procedure NOTE Any rise >30 GPD/HR followed by a subsequent lowering of the rate of change would indicate a spike and a rapid power reduction is not required.

CRS 3. IF Primary to Secondary Leakage in any Steam Generator is 75 GPD (~0.05 GPM)

AND the rate of change is rising by 30 GPD/HR (~0.02 GPM/HR), THEN perform the following: 3.1 Commence a rapid plant shutdown in accordance with OP-901-212, RAPID PLANT POWER REDUCTION, AND concurrently with this Procedure, reduce Plant Power to 50% within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

3.2 WHEN Plant Power is 50%, THEN in accordance with OP-901-212, RAPID PLANT POWER REDUCTION, AND concurrently with this Procedure, be in Mode 3 within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> AND Mode 5 in the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />. These conditions will be met. The CRS should enter OP-901-212 and perform it concurrently with OP-901-202. Steps 1 through 15 of Steam Generator Tube Leakage or High Activity are listed here. The CRS should begin the steps of Rapid Plant Power Reduction before working these steps. The steps of OP-901-212, Rapid Plant Power Reduction follow step 15 of OP-901-202.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 6 of 24 Event

Description:

Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 CRS 7. Notify Chemistry Depar tment to perform the following: 7.1 Provide current Plant status including the following: Primary to Secondary Leakrate Primary to Secondary Leakage Rate of Change Plant action(s) Operations is OR will be implementing (example: plant shutdown, rapid plant shutdown, monitoring) 7.2 Carry out actions in accordance with UNT-005-032, STEAM GENERATOR PRIMARY-TO-SECONDARY LEAKAGE. 7.3 Begin sampling Steam Generators for activity. 7.4 Quantify Steam Generator Tube leakage.

CRS 8. Notify Radiation Protection to carry out the actions of UNT-005-032, STEAM GENERATOR PRIMARY-TO-SECONDARY LEAKAGE.

CRS / BOP 9. Verify BD-303, DISCHARGE TO WASTE, Locked Closed.

CRS / BOP 10. Verify BD-1162, BD FLASH TANK VENT, Closed.

CRS / BOP 11. Verify CD-145, CD DUMP TO WASTE POND, Closed. 11.1 Notify Chemistry prior to dumping Condensate from the Condenser Hotwell to the CST.

Crew 12. Establish AND monitor a PMC Trend of the following PMC points: C48304 PRI TO SEC LEAKAGE C48305 PRI TO SEC LEAK RATE CHANGE (GPD/HR) C48251 RE5501 CH1 LEAK RATE C48252 RE5501 CH2 LEAK RATE CRS Procedure NOTE Until arrangements are made for disposal of radioactively contaminated resin, Condensate Polisher Vessels should NOT be placed in service with resin loaded in the vessel.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 7 of 24 Event

Description:

Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 CRS 15. Remove from service ANY Condensate Polisher Vessels which are loaded with resin in accordance with OP-003-031, CONDENSATE POLISHER/BACKWASH TREATMENT. 15.1 Do not place in service any condensate polisher vessel loaded with resin without the coordination of Chemistry.

Examiner Note For the failure of Charging Pump AB failing to auto start on lowering level, this malfunction may occur before or after the Rapid Power Reduction is started, depending on the pace of the crew. Charging Pump AB would have auto started at ~ 53%, depending on power level.

ATC Recognize and report indications of Charging Pump AB Auto Start Failure.

Alarm (This alarm only comes in if Pressurizer Level drops to 3.9% below the Pressurizer Level Setpoint. If the ATC starts Charging Pump AB before this level, this alarm will not come in):

PRESSURIZER LEVEL HI/LO (Cabinet H, B-1)

Indications Pressurizer level drops more than 2.5% below Pressurizer Level Setpoint and Charging Pump AB does not start.

ATC Start Charging Pump AB by taki ng the control switch on CP-2 to ON.

Examiner Note The following steps are from OP-901-212, Rapid Plant Power Reduction.

CRS NOTE (1) A rapid power reduction is defined as approximately 30 MW/minute load reduction on the main turbine. (2) Power Reduction may be stopped at any point.

(3) Some Steps of this procedure may not be applicable due to plant conditions. In these cases SM/CRS may NA the step. (4) Steps within this procedure may be performed concurrently or out of sequence with SM/CRS concurrence.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 8 of 24 Event

Description:

Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 ATC Begin RCS Boration by either of the following methods as directed by the CRS: Direct Boration Emergency Boration using one Charging Pump CRS Step 1: Begin RCS Boration by one of the following methods:

up to 340 EFPD: Direct Boration

or Emergency Boration using one Charging Pump ATC Steps for Direct Boration:

CAUTION (1) This section affects reactivity. This evolution should be crosschecked and completed prior to leaving CP-4. (2) At least one reactor coolant pump in each loop should be operating prior to performing direct boration operations to ensure proper chemical mixing.

6.7.1 Inform

SM/CRS that this Section is being performed.

NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level 1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD) 1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD) 1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD) 1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be added on Attachment 11.6, Calculation of Boric Acid Volume for Direct Boration or VCT Borate Makeup Mode. Should use Reactor Engineering Reactivity Worksheet 6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Acid desired. 6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desired Boric Acid Makeup Pump A(B).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 9 of 24 Event

Description:

Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 1

6.7.5 Place

Direct Boration Valve, BAM-143, control switch to AUTO.

6.7.6 Place

Makeup Mode selector switch to BORATE.

6.7.7 Verify

selected Boric Acid Makeup Pump A(B) Starts.

6.7.8 Verify

Direct Boration Valve, BAM-143, Opens.

NOTE The Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is most accurate in the range of 10 - 25 GPM.

6.7.9 If manual control of Boric Acid flow is desired, then perform the following:

6.7.9.1 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual.

6.7.9.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, output to >3 GPM flow rate.

6.7.11 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate or Open. 6.7.12 Observe Boric Acid flow rate for proper indication.

Note This manipulation is performed at CP-4. The ATC should use the Reactivity Worksheet to recommend a boron quantity to the CRS.

ATC Perform Boron Equalization as follows:

Place available Pressurizer Pressure Backup Heater Control Switches to ON. Reduce Pressurizer Spray Valve Controller (RC-IHIC-0100) setpoint potentiometer to establish spray flow and maintain RCS pressure 2250 PSIA (2175 - 2265).

This manipulation is performed at CP-2.

ATC Operate CEAs to maintain ASI using CEA Reg. Group 6 or Group P Control Element Assemblies. Operate CEAs in Manual Group mode as follows:

6.7.1 Verify

Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 10 of 24 Event

Description:

Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 1

6.7.2 Position

Group Select switch to desired group.

6.7.3 Place

Mode Select switch to MG and verify the following: White lights Illuminated on Group Selection Matrix for selected group MG light Illuminates

6.7.4 Operate

CEA Manual Shim switch to INSERT group to desired height while monitoring the following: CEA Position Indicator selected CEA group is moving in desired direction If Reactor is critical, then monitor the following: Reactor Power Reactor Coolant System (RCS) temperature Axial Shape Index (ASI)

NOTE The Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when the Mode Select switch is not in OFF.

6.7.5 When desired set of moves have been completed, then place Mode Select switch to OFF.

Note CEA Group P should be used first to a low limit of 120 inches, followed by CEA Group 6 to a low limit of 120 inches to comply with Tech Spec 3.1.3.6.

This manipulation is performed at CP-2.

CRS Notify the Load Dispatcher (Woodlands) that a rapid power reduction is in progress.

CRS Announce to Station Personnel over the Plant Paging System that a rapid plant power reduction is in progress.

Crew Maintain RCS Cold Leg Temperature 536°F to 549°F.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 11 of 24 Event

Description:

Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 BOP Commence Turbine load reduction by performing the following:

Depress LOAD RATE MW/MIN pushbutton.

Set selected rate in Display Demand Window.

Depress ENTER pushbutton.

Depress REFERENCE pushbutton.

Set desired load in Reference Demand Window.

Depress ENTER pushbutton.

Depress GO pushbutton.

This manipulation is performed at CP-1. The BOP will set up the Main Turbine controls. The ATC will direct the BOP when to commence unloading the Main Turbine based on the drop in RCS Cold Leg temperature.

CRS When Reactor Power consistently indicates less than 98% power, as indicated on PMC PID C24631 [MAIN STEAM RAW POWER (MSBSRAW)],

or an alternate point provided by Reactor Engineering, then verify the value of C24648 [BSCAL SMOOTHING VAL. APPLD (DUMOUT17)] automatically changes to 1.

Examiner Note This event is complete after power has been reduced to the satisfaction of the Lead Evaluator.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 5 Page 12 of 24 Event

Description:

Reactor Coolant Pump 1A Seal Failure Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 ATC / BOP Recognize and report indications of RCP 1A seal failure.

Indications RCP 1A seal bleed off flow and temperature rising on the Plant Monitoring Computer and CP-2.

RCP 1A seal pressures rising on the Plant Monitoring Computer and CP-2. CRS Enter and direct the implementation of OP-901-130, Reactor Coolant Pump Malfunction.

CRS IF Reactor Coolant Pump Seal has failed, THEN GO TO section E1, Seal Failure. Examiner Note Coordinate with the booth operator to insert subsequent seal failures after entry into OP-901-130. The intent is for the crew to enter the off normal but not spend much time with the procedure after entry.

Crew Procedure Note 1. RCP Seal pressure and Control Bleedoff temperature and flow are normally as follows (assuming normal operating RCS temperature and pressure): Vapor Seal pressure: 25 to 45 PSIG Upper Seal pressure: 585 to 915 PSIG Middle Seal pressure: 1237 to 1815 PSIG CBO temperature: 135° to 190°F CBO flow: 1.2 to 1.8 GPM 2. (If only one Reactor Coolant Pump Seal has failed on a Reactor Coolant Pump, THEN pump operation may continue provided the seal package is monitored for further degradation.

Crew 1. Inform System Engineer of Reactor Coolant Pump Seal failure.

Crew Procedure Caution (1) CCW TEMPERATURES OF <75 °F COULD LEAD TO ESSENTIAL CHILLER TRIPS ON EVAPORATOR LOW REFRIGERANT PRESSURE. (2) CCW TEMPERATURE SHOULD BE CHANGED AT A RATE OF 10 °F IN ONE HOUR TO PREVENT DEGREDATION OF THE REACTOR COOLANT PUMP SEALS.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 5 Page 13 of 24 Event

Description:

Reactor Coolant Pump 1A Seal Failure Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 CRS / BOP 2. IF Controlled Bleedoff temperature is rising, THEN lower Component Cooling Water temperature by ANY of the following: Start Dry Cooling Tower Fans. Start Auxiliary Component Cooling Water Pump(s) AND associated Wet Cooling Tower Fans. Start Auxiliary Component Cooling Water Pump(s) AND lower ACC-126A(B) setpoint.

3. IF TWO OR MORE seals fail in rapid succession, (within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />) THEN perform the following:

ATC 3.1 Trip the Reactor.

ATC 3.2 Secure affected Reactor Coolant Pump.

Control switch is on CP-2.

Crew 3.3 GO TO OP-902-000, STANDARD POST TRIP ACTIONS.

Examiner Note This event is complete after the ATC operator trips the reactor. The severity of the SGTL should be updated upon reactor trip.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6 / 7 Page 14 of 24 Event

Description:

Steam Generator Tube Rupture / CVC-401 Fails to Close Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 ATC / BOP Recognize and report indications of Steam Generator Tube Rupture.

Alarms PRESSURIZER LEVEL HI/LO (Cabinet H, B-1)

Indications Pressurizer level lowering > Charging Pump capacity.

Lowering Pressurizer pressure.

Charging Pump A auto-starts if not already started.

ATC If directed by CRS, trip Reactor using 2 Reactor Trip pushbuttons at CP-2.

ATC If directed by CRS, initiate Safety Injection Actuation (SIAS) and Containment Isolation Actuation (CIAS) at CP-7.

ATC Close CVC-401 after Containment isolation This component is on CP-4 and receives a CIAS closure signal. This step becomes applicable after the CIAS is actuated.

CRS Direct ATC and BOP to carry out Standard Post trip Actions.

ATC Determine Reactivity Control acceptance criteria are met: Check reactor power is dropping. Check startup rate is negative. Check less than TWO CEAs are NOT fully inserted.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6 / 7 Page 15 of 24 Event

Description:

Steam Generator Tube Rupture / CVC-401 Fails to Close Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 BOP Determine Maintenance of Vital Auxiliaries acceptance criteria are met: Check the Main Turbine is tripped: Governor valves closed Throttle valves closed BOP Check the Main Generator is tripped: GENERATOR BREAKER A tripped GENERATOR BREAKER B tripped EXCITER FIELD BREAKER tripped BOP Check station loads are energized from offsite electrical power as follows:

Train A A1, 6.9 KV non safety bus A2, 4.16 KV non safety bus A3, 4.16 KV safety bus A-DC electrical bus A or C vital AC Instrument Channel Train B B1, 6.9 KV non safety bus B2, 4.16 KV non safety bus B3, 4.16 KV safety bus B-DC electrical bus B or D vital AC Instrument Channel ATC Determine RCS Inventory Control acceptance criteria are met: Check that the following conditions exist: Pressurizer level is 7% to 60% Pressurizer level is trending to 33% to 60% Check RCS subcooling is greater than or equal to 28ºF.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6 / 7 Page 16 of 24 Event

Description:

Steam Generator Tube Rupture / CVC-401 Fails to Close Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 ATC Determine RCS Pressure Control acceptance criteria are met by checking that BOTH of the following conditions exist: Pressurizer pressure is 1750 psia to 2300 psia Pressurizer pressure is trending to 2125 psia to 2275 psia IF pressurizer pressure is less than 1684 psia, THEN verify the following have initiated.

  • CIAS ATC Determine Core Heat Removal acceptance criteria are met: Check at least one RCP is operating. Check operating loop T is less than 13ºF. Check RCS subcooling is greater than or equal to 28ºF.

BOP Determine RCS Heat Removal acceptance criteria are met: Check that at least one steam generator has BOTH of the following: Steam generator level is 5% to 80% NR Main Feedwater is available to restore level within 50%-70% NR.

ATC Check RCS T C is 530 ºF to 550 ºF BOP Check steam generator pressure is 885 psia to 1040 psia.

BOP Check Feedwater Control in Reactor Trip Override: MAIN FW REG valves are closed STARTUP FW REG valves are 13% to 21% open Operating main Feedwater pumps are 3800 rpm to 4000 rpm BOP Reset moisture separator reheaters, and check the temperature control valves closed.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6 / 7 Page 17 of 24 Event

Description:

Steam Generator Tube Rupture / CVC-401 Fails to Close Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 ATC Determine Containment Isolation acceptance criteria are met: Check containment pressure is less than 16.4 psia. Check NO containment area radiation monitor alarms OR unexplained rise in activity. Check NO steam plant activity monitor alarms OR unexplained rise in activity.

BOP Determine Containment Temperature and Pressure Control acceptance criteria are met: Check containment temperature is less than or equal to 120ºF. Check containment pressure is less than 16.4 psia.

BOP Secure AH-12 A or B on CRS direction after initiation of SIAS at CP-18.

CRS After review of Standard Post Trip Actions, use Appendix 1, Diagnostic Flow Chart of OP-902-009 to select appropriate optimal recovery procedure. Proper use of chart will result in use of OP-902-007, Steam Generator Tube Rupture Recovery CRS Enter and direct the implementation of OP-902-007, Steam Generator Tube Rupture Recovery.

CRS 1. Confirm diagnosis of a SGTR: a. Check Safety Function Status Check acceptance criteria are satisfied.

b. IF steam generator sample path is available, THEN direct Chemistry to sample BOTH steam generators for activity.

Crew 2. Announce a Steam Generator Tube Rupture is in progress using the plant page. CRS 3. Advise the Shift Manager to REFER TO EP-001-001, "Recognition & Classification of Emergency Condition", and implement the Emergency Plan.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6 / 7 Page 18 of 24 Event

Description:

Steam Generator Tube Rupture / CVC-401 Fails to Close Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 CRS 4. IF power has been interrupted to either 3A or 3B safety buses, THEN perform Appendix 20, "Operation of DCT Sump Pumps".

Step is not applicable.

CRS 5. REFER TO Section 6.0, "Placekeeper", and record the time of the reactor trip. CRS 6. IF Pressurizer pressure is less than 1684 psia, THEN verify SIAS has initiated.

CRS 7. IF SIAS has initiated, THEN: a. Verify safety injection pumps have started. b. Check safety injection flow is within the following:

  • Appendix 2-E, "HPSI Flow Curve"
  • Appendix 2-F, "LPSI Flow Curve" c. Verify ALL available charging pumps are operating.

CRS / ATC

8. IF Pressurizer pressure is less than 1621 psia, AND SIAS is actuated, THEN: a. Verify no more than two RCPs are operating.
b. IF Pressurizer pressure is less than the minimum RCP NPSH of Appendix 2A-D, "RCS Pressure and Temperature Limits", THEN stop ALL RCPs. Step is not applicable.

CRS / BOP

9. IF RCPs are operating, THEN: a. Verify CCW available to RCPs.
b. IF a CSAS is initiated, THEN stop ALL RCPs. c. IF RCS TC is less than 382ºF, THEN verify no more than two RCPs are operating.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6 / 7 Page 19 of 24 Event

Description:

Steam Generator Tube Rupture / CVC-401 Fails to Close Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 BOP 10. Check a CCW pump is operating for each energized 4.16 KV safety bus.

CRS / BOP 11. Commence a rapid RCS cooldown to less than 520 °F T Hot using the steam bypass valves.

Since the Main Condenser is available at this point in the scenario, the CRS should direct the BOP to open 1 Steam Bypass Valve to 50% open to commence this rapid cooldown. If the crew initiated a Main Steam Isolation Signal prior to this point, the rapid cooldown would be initiated by opening both Atmospheric Dump Valves 100% open.

ATC 13. IF MSIS is NOT present, THEN lower the automatic initiation setpoints as the cooldown and depressurization proceed for MSIS (low SG Pressure).

The CRS should direct the ATC to perform this action during the rapid cooldown to < 520 THOT. Reset MSIS setpoints on all 4 channels at CP-7.

Examiner Note This event is complete after commencing the rapid cooldown.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 20 of 24 Event

Description:

Main Steam Line Break / Function Recovery Procedure Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 ATC / BOP Recognize and report indications of Main Steam Line Break.

Alarms Containment Water Leakage Hi (Cabinet N, L-20)

Containment Water Leakage Hi-Hi (Cabinet N, K-20)

Containment Pressure Hi / Lo (Cabinet M, H-4)

Containment Pressure Hi / Lo (Cabinet N, H-14)

Indications Lowering Pressurizer level.

Lowering Pressurizer pressure.

Rising Containment pressure.

Lowering Steam Generator #2 pressure.

CRS Recognize the second event in progress. Exit OP-902-007 and enter OP-902-008, Functional Recovery procedure.

Crew 1. Announce that the Functional Recovery Procedure is in progress using the plant page.

CRS 2. Advise the Shift Manager to REFER TO EP-001-001, "Recognition & Classification of Emergency Condition" and implement the Emergency Plan.

CRS 3. REFER TO the "Placekeeper" and record the time of the reactor trip.

ATC 4. IF pressurizer pressure is less than 1621 psia, AND SIAS is actuated, THEN: a. Verify no more than two RCPs are operating.

b. IF pressurizer pressure is less than the minimum RCP NPSH of Appendix 2A-D, "RCS Pressure and Temperature Limits", THEN stop ALL RCPs. ATC 5. IF RCPs are operating, THEN: a. IF a CSAS is initiated, THEN stop ALL RCPs. b. Verify CCW available to RCPs.
c. IF RCS TC is less than 382ºF [384ºF], THEN verify no more than two RCPs are operating.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 21 of 24 Event

Description:

Main Steam Line Break / Function Recovery Procedure Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 Critical Task Trip any RCP not satisfying RCP operating limits.

This task is satisfied by securing all RCPs within 3 minutes of loss of CCW flow / CSAS.

ATC Following initiation of CSAS (auto or manual) secure all running Reactor Coolant Pumps as follows: Place each RCP control switch to stop at CP-2 CRS 6. Direct Chemistry to sample BOTH steam generators for activity and boron. CRS 7. IF power is lost to both 3A and 3B safety buses and NOT expected to be restored within 30 minutes, THEN perform the following:

This step is not applicable due to no power loss.

CRS 8. IF power is lost to both 3A and 3B safety buses and NOT expected to be restored within 30 minutes, THEN perform the following to reduce unnecessary station loads:

This step is not applicable due to no power loss.

CRS 9. IF power has been interrupted to either 3A or 3B safety buses, THEN perform Appendix 20, "Operation of DCT Sump Pumps".

This step is not applicable due to no power loss.

BOP 10. Place Hydrogen Analyzers in service as follows:

Train A o Place Train A H2 ANALYZER CNTMT ISOL VALVE keyswitch to OPEN. o Place H2 ANALYZER A POWER to ON.

o Check H2 ANALYZER A Pumps indicate ON.

Train B o Place Train B H2 ANALYZER CNTMT ISOL VALVE keyswitch to OPEN. o Place H2 ANALYZER B POWER to ON.

o Check H2 ANALYZER B Pumps indicate ON.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 22 of 24 Event

Description:

Main Steam Line Break / Function Recovery Procedure Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 CRS 11. Identify success paths to be used to satisfy each safety function using BOTH of the following: Resource Assessment Trees Safety Function Tracking Sheet Note The CRS will perform the prioritization using the Reso urce Assessment Trees. The STA would use the Safety Function Tracking Sheets.

Proper prioritization will result in Containment Isolation being priority 1 and RCS Inventory Control being priority 2. The CRS may request plant data from the ATC and BOP operators during his prioritization. The CRS may ask for the BOP to verify Safety Injection Pumps are meeting the flow curves of OP-902-009, Appendix 2. Both High and Low Pressure Safety Injection Pumps are meeting their flow curves. The Containment Isolation section of OP-902-008 will direct the CRS to carry out the actions in the Heat Removal section, HR-2, steps 16-28. These steps will direct reducing RCS pressure and Isolating S/G #2.

BOP 16.1 Commence a rapid RCS cooldown to less than 520 °F T HOT using Steam Bypass valves.

The CRS should have already ordered this step in OP-902-007. Since the Main Steam Line Break is inside Containment, the Main Steam Isolation valves will now be closed. The CRS should now order the BOP to open both Atmospheric Dump Valves 100% to re-commence the rapid cooldown. RCS temperature may already be < 520 °F due to the Excess Steam Demand. In that case, this step is not applicable.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 23 of 24 Event

Description:

Main Steam Line Break / Function Recovery Procedure Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 Critical Task Prevent opening the Main Steam Safety Valves This task is satisfied by taking action to lower RCS pressure in accordance with step 17.

ATC 17. Depressurize the RCS by performing ALL of the following:

a. Maintain pressurizer pressure within ALL of the following criteria: Less than 945 psia [915 psia] Within 50 psi of the most affected steam generator pressure Within Appendix 2A-D, "RCS Pressure and Temperature Limits" IF RCPs are operating, greater than the minimum RCP NPSH of Appendix 2A-D, "RCS Pressure and Temperature Limits" b. Operate main or auxiliary pressurizer spray.
c. IF HPSI throttle criteria are met, THEN perform ANY of the following:
  • Control charging and letdown flow
  • Throttle HPSI flow Note The ATC operator should receive direction from the CRS to perform this step. He should evaluate plant conditions and decide on a minimum RCS pressure. The critical task is satisfied when the applicant takes action to start reducing RCS pressure (< 945 PSIA does not need to be reached in the scenario). Auxiliary Spray will be required since all RCPs will be secured. HPSI throttle criteria will not be met at this point.

BOP IF RCS T HOT is less than 520 °F, THEN isolate the most affected SG:

BOP a. Place the ADV setpoint to 980 psig and verify controller in AUTO.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 24 of 24 Event

Description:

Main Steam Line Break / Function Recovery Procedure Time Position Applicant's Actions or Behavior Scenario 1, Revision 1 BOP b. Verify the MSIV is closed.

BOP c. Verify the MFIV is closed.

BOP d. IF EFAS-2 is NOT initiated, THEN close EFW Isolation Valves: EFW 228B (SG 2 PRIMARY) EFW 229B (SG 2 BACKUP)

BOP e. Place EFW Flow Control Valves in MAN and close: EFW 224B, SG 2 PRIMARY EFW 223B, SG 2 BACKUP BOP f. Close MS 401B, PUMP AB TURB STM SUPPLY SG 2.

BOP g. Close Main Steam Line 2 Drains: MS 120B NORMAL MS 119B BYPASS BOP h. Close Steam Generator Blowdown isolation valves: BD 103B STM GEN 2 (OUT) BD 102B STM GEN 2 (IN)

BOP i. Check main steam safety valves are closed.

Examiner Note This event is complete after the CRS has directed Steam Generator #2 to be isolated AND The ATC operator has commenced reducing RCS pressure Or As directed by the Lead Evaluator.

Appendix D Scenario Outline Form ES-D-1 Scenario 3 Rev 1 Facility: WATERFORD 3 Scenar io No.: 3 Op Test No.:

NRC Examiners:

Operators:

Initial Conditions: Mode 2 with 2 Charging Pumps in operation Protected Train is B AB Bus is aligned to Train B Reactor power is 1%

Turnover: Dilute to 5-15% power Event No. Malf. No. Event Type*

Event Description 1 N/A R - ATC N - SRO Dilute to 5-10% power, perform 100 gallon PMU addition.

2 CB08B1 TS - SRO Containment pressure instrument CB-IPI-6702-SMC C fails high.

3 CV35A CVR101 C - ATC C - BOP C - SRO During dilution, PMU counter fails to secure flow OP-901-104, Inadvertent Positive Reactivity Addition 4 CC02A TS - SRO Auxiliary Component Cooling Water Pump A trip 5 RX14A I - ATC I - SRO Pressurizer Pressure RC-IPR-0100 X fails high, Main Spray Valves open 6 RC23A M - ALL Small break loss of coolant accident 7 RP05 A3, B3, C3, D3 I - ATC I - SRO Containment Spray fails to actuate

  • (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Scenario Event Description NRC Scenario 3 Scenario 3 Rev 1 The crew assumes the shift with the reactor at 1% power following a forced outage. The turnover will include instructions to perform RCS dilution to 5 - 15% power.

The reactivity plan will include instructions to dilute in multiple PMU batches. The initial batch will be 100 gallons of PMU. Each subsequent batch will be 50 gallons of PMU.

This will allow for an observable power rise without concern for a reactor trip on the PMU failure.

After the first 100 gallons of PMU are added, Containment pr essure instrument CB-IPI-6702-SMC Channel C input to Containment Spray Actuation fails high. The CRS should enter Tech Spec 3.3.2 and direct bypassing high Containment Pressure - Hi Hi bistable on Channel C.

During the second dilution, the Primary Water counter will fail to secure dilution. The ATC should attempt to secure Primar y Water Flow by operating PMU-144 and CVC-510. Neither of these acti ons will secure flow. The CRS should enter OP-901-104, Inadvertent Positive Reactivity Additi on, and secure Primary Makeup Pump A.

After these actions are completed, Auxiliary Component Cooling Water Pump A will trip. The crew should verify Component Cooling Water temperature is being controlled by Dry Cooling Tower Fans. The SRO should declare ACCW Pump A inoperable and enter a 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> action for Tech Spec 3.7.3 as well as cascading Tech Specs. The SRO should address the need to accomplish surv eillance OP-903-066, Electrical Breaker Alignment Checks, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to comply with Tech Spec 3.8.1.1.b. They must also address the need to accomplish the requirements of Tech Spec 3.8.1.1.d within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.

After the Tech Specs are evaluated, Pre ssurizer pressure instrument RC-IPR-0100 X fails high. This causes both Main Spray valves to open. The SRO should enter OP-

901-120, Pressurizer Pressure Malfunction. The ATC will align the non-faulted Pressurizer pressure channel.

After the Pressurizer Pressure Control Channel Y is selected, a small break LOCA event will occur. Containment Spray Actuation will fail requi ring manual actuation. All Reactor Coolant Pumps will be required to be secured after the CSAS.

After the crew has completed OP-902-000, St andard Post Trip Actions, the CRS should diagnose into OP-902-002, Loss of Coolant Accident Recovery. The scenario can be

terminated after the crew has commenced an RCS cooldown using Atmospheric Dump Valves.

NRC Scenario 3 Scenario 3 Rev 1 Critical Tasks

1. Establish Containment temperature and pressure control This task is satisfied by manually actuating Containment Spray prior to completing the review of step 8 in OP-902-000, Standard Post Trip Actions, or before completing the review of step 15 in OP-902-002, Loss of Coolant Accident Recovery, if OP-902-000 is exited before Containment pressure exceeds 17.7 psia.
2. Trip any RCP not satisfying RCP operating limits.

This task is satisfied by securing all RCPs within 3 minutes of loss of CCW flow. The required task becomes applicable after Containment Spray has been actuated. The time requirement of 3 minutes is based on the RCP operating limit of 3 minutes without CCW cooling.

Scenario Quantitative Attributes

1. Total malfunctions (5-8) 6 2. Malfunctions after EOP entry (1-2) 1 3. Abnormal events (2-4) 2 4. Major transients (1-2) 1 5. EOPs entered/requiring substantive actions (1-2) 1 6. EOP contingencies requiring substantive actions (0-2) 0 7. Critical tasks (2-3) 2

NRC Scenario 3 Scenario 3 Rev 1 Scenario Notes:

A. Reset Simulator to IC-193.

1. Use keys 165 - 168 for S/G high level bypass setup.

B. Verify the following Scenario Malfunctions:

1. cv35a for the PMU Dilution counter
2. rx14-A for Pressurizer pressure instrument RC-IPT-0100 X
3. cb08b1 for Containment Pressu re instrument CB-IPI-6702-SMC
4. cc02a for Auxiliary Component Cooling Water Pump A
5. rc23a for RCS break
6. rp05a3, b3, c3, d3 for C ontainment Spray failure C. Verify the following Remotes:
1. cvr101 set at 2% for PMU-140
2. anr04h for EDG A local alarm acknowledgement.
3. anr04i for EDG B loca l alarm acknowledgement.

D. Verify the following Event Trigger

1. zdifwpmuecs1357(1).eq.1 sets irf cvr101 0.

E. Ensure Protected Train B sign is placed in SM office window.

F. Verify EOOS is 10.0 Green

G. Complete the simulator setup checklist.

H. Remove Caution Tag from PMU-141.

I. Remove PMC point D39502 from scan.

J. Start DCS, Record Data, select file PlantParameters.txt.

NRC Scenario 3 Simulator Booth Instructions Event 1 Dilute to 5-10% power, Perf orm 100 gallon PMU addition

1. No communications should occur for this evolution.

Event 2 Containment pressure instrum ent CB-IPi-6702 SMC fails high

1. After the first 100 gallon addition is co mpleted, or on Lead Examiner's cue, initiate Event Trigger 2.
2. If Work Week Manager or I&C is called, inform the ca ller that a work package will be assembled and a team will be sent to the Control Room.

Event 3 PMU flow malfunction

1. After the Containment Pressure instru ment has failed, the crew should make their second PMU addition. Insert Event Trigger 3 after the ATC has established PMU flow.
2. If called to operate valves listed in OP-901-104, acknowledge communication and report that you will work on valve list.

Event 4 Auxiliary Component Cooling Water Pump A trip

1. After PMU Pump A is secured and on the Lead Examiner's cue, initiate Event Trigger 4.
2. If called as the watchstander and sent to ACCW Pump A, report that the pump looks normal locally.
3. If called as the watchstander and sent to ACCW Pump A breaker, report that the breaker indicates open and that there are various breaker parts on the floor of the cubicle.
4. If Work Week Manager or I&C is called, inform the ca ller that a work package will be assembled and a team will be sent to the Control Room.

Event 5 Pressurizer pressure instrum ent RC-IPR-0100 X fails high

1. After Tech Specs for Event 4 are addresse d, or on Lead Examiner's cue, initiate Event Trigger 5.
2. If Work Week Manager or I&C is called, inform the ca ller that a work package will be assembled and a team will be sent to the Control Room.

Scenario 3 Rev 1 NRC Scenario 3 Event 6 Loss of Coolant Accident

1. After the actions in OP-901-120 are complete and on the Lead Examiner's cue, initiate Event Trigger 6.
2. If called as RAB watch to check EDG A & B, initiate Trigger 10, and when the EDG A & B Trouble alarms are clear, report that they are running satisfactorily.

Event 7 Containment Spray fails to actuate

1. No communications should occur for this malfunction.

At the end of the scenario, before resetting, complete data collection by stopping recording and saving the file as 2010 SRO Scenario3.cdf

Scenario 3 Rev 1 NRC Scenario 3 Scenario Timeline: Event Malfunction Severity Ramp HH:MM:SS Delay Trigger 1 N/A N/A N/A N/A N/A Dilute to critical boron concentration 2 CH08 B1 N/A N/A N/A 2 Containment Pressure Instrument CB-IPI-6702-SMC fails high 3 CVR101 2% N/A N/A 3 PMU - 140 throttled open 3 CV35 A N/A N/A N/A 3 PMU counter fails to secure dilution 4 CC02 A N/A N/A N/A 4 Auxiliary Component Cooling Water Pump A trips 5 RX14 A 100% N/A N/A 5 Pressurizer pressure instru ment RC-IPR-0100 X fails high 6 RC23 A 0.05% 5:00 N/A 6 Small Break LOCA 7 RP05 A3, B3, C3, D3 N/A N/A N/A N/A Containment Spray fails to actuate Scenario 3 Rev 1 NRC Scenario 3 Scenario 3 Rev 1

REFERENCES:

Event Procedures 1 OP-010-003, Plant Startup OP-002-005, Chemical and Volume Control 2 OP-009-007, Plant Protection System OP-903-013, Monthl y Channel Checks Tech Spec 3.3.2 3 OP-901-104, Inadvertent Positive Reactivity Addition 4 Tech Spec 3.7.3 OP-100-014 5 OP-901-120, Pressurizer Pressure Control Malfunction Tech Spec 3.2.8 6 OP-902-000, Standard Post Trip Actions OP-902-009, Standard Appendices, Append ix 1, Diagnostic Flow Chart OP-902-002, Loss of Coolant Accident Recovery 7 OP-902-000, Standard Post Trip Actions OI-038-000, Emergency Operat ing Procedures Operations Expectations /

Guidance 8 OP-902-000, Standard Post Trip Actions OI-038-000, Emergency Operat ing Procedures Operations Expectations /

Guidance Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 1 of 17 Event

Description:

Dilute from 5x10 -4% to 5 - 10% Power Time Position Applicant's Actions or Behavior ATC Aligns for 100 gallon Primary Makeup Water Addition in accordance with OP-002-005, Chemical and Volume Control.

Procedure Caution THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSSCHECKED AND COMPLETED PRIOR TO LEAVING CP-4.

6.9.1 Inform

SM/CRS that this Section is being performed.

Procedure Note When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level 1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD) 1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD) 1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD) 1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.9.2 At SM/CRS discretion, calculate volume of Primary Makeup water to be added on Attachment 11.7, Calculation of Primary Makeup Water Volume for Direct Dilution or VCT Dilute Makeup Mode.

Not applicable, reactivity plan gives required volume.

6.9.3 Set Primary Makeup Water Ba tch Counter to volume of Primary Makeup water desired.

Procedure does not give specific steps to set the counter. Counter is set by pressing the: UP arrow button ENTER button the side arrow button to move the cursor the raise button to enter 10 since the counter counts in multiple of 10 gallons ENTER RESET. Scenario 3, Revision 1 Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 2 of 17 Event

Description:

Dilute from 5x10 -4% to 5 - 10% Power Time Position Applicant's Actions or Behavior Scenario 3, Revision 1

6.9.4 Place

Makeup Mode selector switch to DILUTE.

6.9.5 Open VCT Makeup Valve, CVC-510.

Procedure Note The Dilution Flow Totalizer will not register below 5 GPM. The Dilution Flow Totalizer is most accurate at >10 GPM.

Procedure Caution DILUTION SHALL IMMEDIATELY BE STOPPED IF PRE-POWER DEPENDENT INSERTION LIMIT (H-9, CABINET H) ALARM IS INITIATED OR ANY UNEXPECTED REACTI VITY CHANGE OCCURS.

6.9.6.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Manual. 6.9.6.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, output to >5 GPM flow rate.

6.9.8 Verify

Primary Makeup Water Control Valve, PMU-144, Intermediate or Open. 6.9.9 Observe Primary Makeup water flow rate for proper indication.

6.9.10 Operate VCT Inlet/Bypass to Holdup Tanks, CVC-169 Control Switch to BMS/Auto positions as necessary to maintain VCT pressure and level within normal operating bands.

6.9.11 When Primary Makeup Water Batch Counter has counted down to desired value, then verify Primary Makeup Water Control Valve, PMU-144, Closed. Procedure Note Step 6.9.12 may be repeated as necessary to achieve desired total Primary Makeup Water addition for plant conditions.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 3 of 17 Event

Description:

Dilute from 5x10 -4% to 5 - 10% Power Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 6.9.12 If additional Primary Makeup Water addition is required and with SM/CRS permission, then perform the following:

The reactivity plan describes that additional PMU additions will be required. The CRS may or may not use this option. It is acceptable if the crew chooses to leave this aligned.

6.9.13 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Manual. 6.9.14 Verify both Primary Makeup Water Flow controller, PMU-IFIC-0210X, output and setpoint potentiometer set to zero.

6.9.15 Close VCT Makeup Valve, CVC-510.

6.9.16 Place Makeup Mode selector switch to MANUAL.

6.9.17 Verify VCT Inlet/Bypass To Holdup Tanks, CVC-169, aligned to the VCT and control switch in AUTO.

Examiner Note This event is complete after the crew has Added 100 gallons of Primary Makeup Or As directed by the Lead Evaluator

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 4 of 17 Event

Description:

Containment Pressure Instrument Fails High Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 ATC Recognize and report indications of failed channel.

Alarms: ESFAS CHANNEL TRIP CNTMT PRESS HI-HI (Cabinet K, L-18)

CNTMT PRESS HI-HI ESFAS PRETRIP A/C (Cabinet K, M-18)

RPS CHANNEL C TROUBLE (Cabinet K, G-18)

Indications Containment pressure instrument CB-IPI-6702 SMC on CP-7 indicates pegged high.

Containment pressure Hi Hi bistable on Channel C pre-trip and trip indication illuminated.

CRS Review Tech Specs based on the failed instrument.

Enter Tech Spec 3.3.2.

Review OP-903-013, Monthly Channel Checks, and determine Tech Spec 3.3.3.5 and 3.3.3.6 are not applicable.

Direct bypassing Channel B bistables 17 for Hi Hi Containment Pressure ESFAS. This is a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> action.

Examiner Note This event is complete when Tech Spec 3.3.2 has been addressed Or As directed by the Lead Evaluator

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 5 of 17 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 ATC Aligns for 50 gallon Primary Makeup Water Addition in accordance with OP-002-005, Chemical and Volume Control.

Procedure Caution THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSSCHECKED AND COMPLETED PRIOR TO LEAVING CP-4.

6.9.1 Inform

SM/CRS that this Section is being performed.

Procedure Note When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level 1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD) 1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD) 1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD) 1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.9.2 At SM/CRS discretion, calculate volume of Primary Makeup water to be added on Attachment 11.7, Calculation of Primary Makeup Water Volume for Direct Dilution or VCT Dilute Makeup Mode.

Not applicable, reactivity plan gives required volume.

6.9.3 Set Primary Makeup Water Ba tch Counter to volume of Primary Makeup water desired.

Procedure does not give specific steps to set the counter. Counter is set by pressing the: UP arrow button ENTER button the side arrow button to move the cursor the raise button to enter 5 since the counter counts in multiple of 10 gallons ENTER RESET. 6.9.4 Place Makeup Mode selector switch to DILUTE.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 6 of 17 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 6.9.5 Open VCT Makeup Valve, CVC-510.

Procedure Note The Dilution Flow Totalizer will not register below 5 GPM. The Dilution Flow Totalizer is most accurate at >10 GPM.

Procedure Caution DILUTION SHALL IMMEDIATELY BE STOPPED IF PRE-POWER DEPENDENT INSERTION LIMIT (H-9, CABINET H) ALARM IS INITIATED OR ANY UNEXPECTED REACTI VITY CHANGE OCCURS.

6.9.6.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Manual. 6.9.6.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, output to >5 GPM flow rate.

6.9.8 Verify

Primary Makeup Water Control Valve, PMU-144, Intermediate or Open. 6.9.9 Observe Primary Makeup water flow rate for proper indication.

6.9.10 Operate VCT Inlet/Bypass to Holdup Tanks, CVC-169 Control Switch to BMS/Auto positions as necessary to maintain VCT pressure and level within normal operating bands.

6.9.11 When Primary Makeup Water Batch Counter has counted down to desired value, then verify Primary Makeup Water Control Valve, PMU-144, Closed.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 7 of 17 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 Examiner Note On this 50 gallon water addition, the PMU Batch Counter will fail to secure PMU flow.

Indications PMU flow does not change as the PMU Batch Counter reaches 0 gallons PMU Batch Counter counts through 0 and continues counting with negative numbers.

Dilution Flow Totalizer continues counting up ATC Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, output to 0% output.

This action will reduce flow, but flow will continue at ~ 7 gpm.

CRS Enter and direct the implementation of OP-901-104, Inadvertent Positive Reactivity Addition, section E 1, Actions During Startup, Power Operation, and Shutdown ATC 1. Verify REACTOR MAKE UP PRI WTR CONTR VA (PMU 144) Closed.

BOP 2. Stop both Primary Makeup Water Pumps A and B.

CRS / ATC 3. Verify only one Charging Pump operating.

ATC 4. Bypass or secure Purification Ion Exchangers as follows: 4.1 Place LETDOWN TO ION EXCHA NGER BYPASS valve (CVC 140) to BYPASS. CRS 5. If dilution still in progress, then Close PMU Hdr to Dilution Tee and Chem Add Tank Isol, PMU 135 (RAB-4 5A&J).

PMU flow will go to 0 gpm after PMU Pump A is secured.

6. Borate as necessary to maintain stable plant conditions.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 8 of 17 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 Examiner Note Crew may wait to see the effect of the extra PMU prior to performing boration. The steps for Direct Boration and CEA insertion are included in this section. It is not necessary to hold at this point for either action ATC Steps for Direct Boration:

CAUTION (1) This section affects reactivity. This evolution should be crosschecked and completed prior to leaving CP-4. (2) At least one reactor coolant pump in each loop should be operating prior to performing direct boration operations to ensure proper chemical mixing.

6.7.1 Inform

SM/CRS that this Section is being performed.

NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level 1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD) 1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD) 1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD) 1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be added on Attachment 11.6, Calculation of Boric Acid Volume for Direct Boration or VCT Borate Makeup Mode. Should use Reactor Engineering Reactivity Worksheet 6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Acid desired. 6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desired Boric Acid Makeup Pump A(B).

6.7.5 Place

Direct Boration Valve, BAM-143, control switch to AUTO.

6.7.6 Place

Makeup Mode selector switch to BORATE.

6.7.7 Verify

selected Boric Acid Makeup Pump A(B) Starts.

6.7.8 Verify

Direct Boration Valve, BAM-143, Opens.

NOTE The Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is most accurate in the range of 10 - 25 GPM.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 9 of 17 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 6.7.9 If manual control of Boric Acid flow is desired, then perform the following:

6.7.9.1 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual.

6.7.9.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, output to >3 GPM flow rate.

6.7.11 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate or Open. 6.7.12 Observe Boric Acid flow rate for proper indication.

Steps for CEA insertion ATC Operate CEAs to maintain ASI using CEA Reg. Group 6 or Group P Control Element Assemblies. Operate CEAs in Manual Group mode as follows:

6.7.1 Verify

Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer.

6.7.2 Position

Group Select switch to desired group.

6.7.3 Place

Mode Select switch to MG and verify the following: White lights Illuminated on Group Selection Matrix for selected group MG light Illuminates

6.7.4 Operate

CEA Manual Shim switch to INSERT group to desired height while monitoring the following: CEA Position Indicator selected CEA group is moving in desired direction If Reactor is critical, then monitor the following: Reactor Power Reactor Coolant System (RCS) temperature Axial Shape Index (ASI)

NOTE The Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when the Mode Select switch is not in OFF.

6.7.5 When desired set of moves have been completed, then place Mode Select switch to OFF.

Examiner Note This event is complete after the crew has entered OP-901-104 and secured PMU Pump A Or As directed by the Lead Evaluator

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 4 Page 10 of 17 Event

Description:

Auxiliary Component Cooling Water Pump A Trip Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 BOP Recognize and report indications of failed channel.

Alarms: AUX CCW PUMP A TRIP/TROUBLE (Cabinet B, H-9)

AUX CCW SYS A PRESS LO JOCKEY PUMP TRIP/TROUBLE (Cabinet B, K-9)

Indications Amber light on ACCW Pump A control Switch.

Dry Cooling Tower Fans sequencing on as CCW temperature rises.

CRS Review Tech Specs based on the pump failure.

Enter Tech Spec 3.7.3 and cascading Tech Specs.

Review OP-100-014, Technical Specification and Technical Requirements Compliance.

Direct performing OP-903-066, Electrical Breaker Alignment Check, to comply with 3.8.1.1.b. This is a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> action.

Direct verification of Train B safety equipment and EFW Pump AB in accordance with 3.8.1.1.d. This is a 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> action.

Examiner Note This event is complete when Tech Specs have been addressed Or As directed by the Lead Evaluator Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 11 of 17 Event

Description:

Pressurizer Pressure Instrument Fails High Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 ATC Recognize and report indications of failed pressure instrument.

Alarms PRESSURIZER PRESSURE HI/LO (Cabinet H, E-1)

PRESSURIZER PRESS SIGNAL DEVIATION (Cabinet H, F-1)

Indications Recorder RC-IPR-0100 red pen fails Hi.

Controller RC-IPIC-0100 process fails Hi.

Controller RC-IPIC-0100 output goes to 100%.

All Pressurizer Proportional and Backup Heaters secure.

Both Pressurizer Main Spray Valves go full open.

Pressurizer Pressure drops rapidly due to the full Main Spray.

ATC Place Pressurizer Spray Controller RC-IHIC-0100 to MAN and close the Main Spray Valves.

This action is not in OP-901-120. Operations procedures include allowances for taking manual control of components when their automatic function is not controlling. The CRS should direct this action prior to entering off normal procedure OP-901-120.

CRS Enter and direct the implementation of OP-901-120, Pressurizer Pressure Malfunction, and use sub-section E1, Pressurizer Pressure Control Channel Instrument Failure.

CRS Procedure Caution Steam Generator pressures dropping concurrently with dropping Pressurizer level may be indicative of an excess steam demand.

CRS 1. IF Pressurizer Pressure and Level are dropping concurrently, OR RCS leakage is otherwise indicated, THEN GO TO OP-901-111, Reactor Coolant System Leak.

CRS 2. IF PRESSURIZER PRESSURE CHANNEL X/Y recorder (RC-IPR-0100) indicates a Pressurizer Pressure Control Channel instrument has failed, THEN GO TO Subsection E1, Pressurizer Pressure Control Channel Instrument Failure.

ATC 1. Verify control channel instrument failure by checking PRESSURIZER PRESSURE CHANNEL X/Y recorder (RC-IPR-0100).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 12 of 17 Event

Description:

Pressurizer Pressure Instrument Fails High Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 ATC 2. Transfer Pressurizer pressure control to operable channel using Pressurizer Pressure Channel Selector control switch.

Position Y should be selected.

ATC 3. IF Pressurizer Pressure control channel is failed high, THEN perform the following:

a. Transfer Pressurizer Lo Level Heater Cutout selector switch to the Operable Pressurizer Pressure control channel.
b. Reset Proportional Heater Banks #1 & #2.

ATC 4. Verify proper operation of Pressurizer Pressure controller (RC-IPIC-0100) AND Pressurizer Pressure controlling OR being restored to 2250 PSIA.

CRS Refer to Technical Specification 3.2.8.

Entry required if RCS pressure drops below 2125 PSIA, but the Tech Spec is only applicable in Mode 1. Power should still be < 5% at this point. Pressure should drop below 2125 PSIA. Pressure will recover to > 2125 PSIA after Channel Y is selected and Pressurizer Heaters are energized.

ATC Place Pressurizer Spray Controller RC-IHIC-0100 to Auto.

The CRS should direct this after Channel Y has been selected for Pressurizer pressure control.

Examiner Note This event is complete when Pressurizer Pressure Control has been transferred to Channel Y.

Or As directed by the Lead Evaluator.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 / 7 Page 13 of 17 Event

Description:

Loss of Coolant Accident / Failure of Containment Spray to Actuate Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 ATC / BOP Recognize and report indications of Loss of Coolant Accident Alarms Containment Water Leakage Hi (Cabinet N, L-20)

Containment Water Leakage Hi-Hi (Cabinet N, K-20)

Class 1E Rad Monitoring Sys Ac tivity Hi-Hi (Cabinet SA, K-4)

Indications Lowering Pressurizer level.

Lowering Pressurizer pressure.

Backup Charging Pumps auto-start until all 3 Charging Pumps are running. ATC If directed by CRS, trip Reactor using 2 Reactor Trip pushbuttons at CP-2.

ATC If directed by CRS, initiate Safety Injection Actuation (SIAS) and Containment Isolation Actuation (CIAS) at CP-7.

CRS Direct ATC and BOP to carry out Standard Post trip Actions.

ATC Determine Reactivity Control acceptance criteria are met: Check reactor power is dropping. Check startup rate is negative. Check less than TWO CEAs are NOT fully inserted.

BOP Determine Maintenance of Vital Auxiliaries acceptance criteria are met: Check the Main Turbine is tripped: Governor valves closed Throttle valves closed BOP Check the Main Generator is tripped: GENERATOR BREAKER A tripped GENERATOR BREAKER B tripped EXCITER FIELD BREAKER tripped

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 / 7 Page 14 of 17 Event

Description:

Loss of Coolant Accident / Failure of Containment Spray to Actuate Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 BOP Check station loads are energized from offsite electrical power as follows:

Train A A1, 6.9 KV non safety bus A2, 4.16 KV non safety bus A3, 4.16 KV safety bus A-DC electrical bus A or C vital AC Instrument Channel Train B B1, 6.9 KV non safety bus B2, 4.16 KV non safety bus B3, 4.16 KV safety bus B-DC electrical bus B or D vital AC Instrument Channel ATC Determine RCS Inventory Control acceptance criteria are met: Check that the following conditions exist: Pressurizer level is 7% to 60% Pressurizer level is trending to 33% to 60% Check RCS subcooling is greater than or equal to 28ºF.

ATC Determine RCS Pressure Control acceptance criteria are met by checking that BOTH of the following conditions exist: Pressurizer pressure is 1750 psia to 2300 psia Pressurizer pressure is trending to 2125 psia to 2275 psia IF pressurizer pressure is less than 1684 psia, THEN verify the following have initiated.

  • CIAS ATC Determine Core Heat Removal acceptance criteria are met: Check at least one RCP is operating. Check operating loop T is less than 13ºF. Check RCS subcooling is greater than or equal to 28ºF.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 / 7 Page 15 of 17 Event

Description:

Loss of Coolant Accident / Failure of Containment Spray to Actuate Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 BOP Determine RCS Heat Removal acceptance criteria are met: Check that at least one steam generator has BOTH of the following: Steam generator level is 5% to 80% NR Main Feedwater is available to restore level within 50%-70% NR.

ATC Check RCS T C is 530ºF to 550ºF BOP Check steam generator pressure is 885 psia to 1040 psia.

BOP Check Feedwater Control in Reactor Trip Override: MAIN FW REG valves are closed STARTUP FW REG valves are 13% to 21% open Operating main Feedwater pumps are 3800 rpm to 4000 rpm Note With MSIS in, MAIN FW REG valves and STARTUP FW REG valves will be closed. BOP Reset moisture separator reheaters, and check the temperature control valves closed.

ATC Determine Containment Isolation acceptance criteria are met: Check containment pressure is less than 16.4 psia. Check NO containment area radiation monitor alarms OR unexplained rise in activity. Check NO steam plant activity monitor alarms OR unexplained rise in activity.

IF containment pressure is greater than or equal to 17.1 psia, THEN verify the following:

  • CIAS is initiated
  • MSIS is initiated BOP Determine Containment Temperature and Pressure Control acceptance criteria are met: Check containment temperature is less than or equal to 120ºF. Check containment pressure is less than 16.4 psia.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 / 7 Page 16 of 17 Event

Description:

Loss of Coolant Accident / Failure of Containment Spray to Actuate Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 IF containment pressure is greater than or equal to 17.7 psia, THEN verify ALL of the following:

  • ALL RCPs are secured Critical Task Establish Containment temperature and pressure control.

This task is satisfied by manually initiating Containment Spray prior to completing the review of the Containment Temperature and Pressure Control Safety Function of OP-902-000, Standard Post Trip Actions, or prior to completing the Safety Function Status review of OP-902-002, Loss of Coolant Accident Recovery, if Containment pressure exceeds 17.7 PSIA after the crew transitions to OP-902-002.

ATC Manually initiate CSAS from CP-7. The setpoint for CSAS is Containment pressure 17.7 PSIA.

Critical Task Trip any RCP not satisfying RCP operating limits.

This task is satisfied by securing all RCPs within 3 minutes of loss of CCW flow.

ATC Following initiation of CSAS, secure all running Reactor Coolant Pumps as follows: Place each RCP control switch at CP-2 to stop.

BOP Secure AH-12 A or B on CRS direction after initiation of SIAS at CP-18.

CRS After review of Standard Post Trip Actions, use Appendix 1, Diagnostic Flow Chart of OP-902-009 to select appropriate optimal recovery procedure. Proper use of chart will result in use of OP-902-002, Loss of Coolant Accident Recovery Crew When Containment Temperature rises above 200 F, update crew on need to use bracketed parameters due to harsh environment in Containment.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 / 7 Page 17 of 17 Event

Description:

Loss of Coolant Accident / Failure of Containment Spray to Actuate Time Position Applicant's Actions or Behavior Scenario 3, Revision 1 CRS During brief in OP-902-002, should discuss necessary strategy of using Steam Generators to cool RCS.

CRS 1. Confirm diagnosis of a LOCA:

a. Check Safety Function Status Check Acceptance criteria are satisfied.
b. IF Steam Generator sample path is available, THEN direct Chemistry to sample BOTH Steam Generators for activity.

Crew 2. Announce a Loss of Coolant Accident is in progress using the plant page.

CRS 3. Advise the Shift Manager to REFER TO EP-001-001, "Recognition & Classification of Emergency Condition" and implement the Emergency Plan.

CRS 5. REFER TO Section 6.0, "Placekeeper" and record the time of the reactor trip. This is the location most appropriate for a Shift Brief. In the brief, the CRS should discuss the need to perform a RCS cooldown with the Atmospheric Dump Valves.

CRS 19.1 Cooldown the RCS to less than 350ºF T Hot or CET temperature using the Atmospheric Dump Valves.

This step can be pulled forward by the CRS. Both Atmospheric Dump Valves should be used for this cooldown.

Examiner Note This event is complete after the crew addresses the RCS cooldown Or As directed by the Lead Evaluator.

ES-301 Simulator Scenario Quality Checklist Form ES-301-5 Facility: Waterford 3 Date of Exam:

October 4, 2010 Operating Test No.NRC A P P L I C A N T E V E N T T Y P

E Scenarios 1 2 3 T O T A L M I N I M U M(*) CREW POSITION CREW POSITION CREW POSITION CREW POSITION S A T C B O P S R O A T C B O P S R O A T C B O P S R O A T C B O P R O R I U SRO-I 1 Name RX 4 1 1 1 0 NOR 1 1 1 1 1 I/C 1,3,5, 7 3,5,7 7 4 4 2 MAJ 6,8 6 3 2 2 1 TS 2,4 2 0 2 2 SRO-I 2 Name RX 4 1 1 1 0 NOR 1 1 1 1 1 I/C 1,3,5, 7 3,5,7 7 4 4 2 MAJ 6,8 6 3 2 2 1 TS 2,4 2 0 2 2 SRO-I 3 Name RX 1 1 1 1 0 NOR 4 1 1 1 1 I/C 1,3,5, 7 3,5,7 7 4 4 2 MAJ 6,8 6 3 2 2 1 TS 2,3 2 0 2 2 SRO-U Name RX 1 1 1 1 0 NOR 4 1 1 1 1 I/C 1,3,5, 7 3,5,7 7 4 4 2 MAJ 6,8 6 3 2 2 1 TS 2,3 2 0 2 2 Spare RX 3 NOR 3 I/C 1,4,5, 7 1,4,5 MAJ 4,6 4,6 TS 1,2 NRC Revision 2 NRC Revision 2 Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the "at-the-controls (ATC)" and "balance-of-plant (BOP)" positions; Instant SROs must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.
2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.
3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicant's competence count toward the minimum requirements specified for the applicant's license level in the right-hand columns.

E S-301 Competencies Checklist Form ES-301-6 Facility: Waterford 3 Date of Exam: October 4, 2010 Operating Test No.: NRC Competencies APPLICANTS

CRS

ATC

SCENARIO SCENARIO SCENARIO 1 2 3 1 2 3 Interpret/Diagnose Events and Conditions 1, 2, 3, 5, 6, 8 1, 2, 3, 4, 5, 6, 7 2, 3, 4, 5, 6, 7 1, 3, 5, 6, 7, 8 1, 4, 5, 6 3, 5, 6, 7 Comply With and Use Procedures (1)

All 1, 3, 4, 5, 6, 8 1, 3, 4, 5, 6 1, 3, 5, 6, 7 Operate Control Boards (2)

N/A 1, 3, 4, 5, 6, 7 1, 3, 4, 5 1, 3, 5, 6, 4 Communicate and Interact All 1, 2, 3, 4, 5, 6, 7, 8 1, 3, 4, 5, 6 1, 2, 3, 5, 6, 7 Demonstrate Supervisory Ability (3)

All N/A N/A Comply With and Use Tech. Specs. (3) 2,3 1,2 2,4 N/A N/A Notes: (1) Includes Technical Specification compliance for an RO. (2) Optional for an SRO-U. (3) Only applicable to SROs.

Instructions:

Check the applicants' license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.

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