ML20282A534

Title:

CALCULATE SUBCOOLING MARGIN JPM Number: A1 Revision Number: 1 Task Number and

Title:

CRO-24850, Respond to a loss of QDPS.

K/A Number and Importance: G2.1.19 3.9/3.8 Suggested Testing Environment: Simulator Control Room In-Plant Other Alternate Path: Yes No Task Designed For: SRO Only RO/SRO AO/RO/SRO Time Critical: Yes No Level of Difficulty: 3 Reference(s): Lesson LOT202.44, QDPS Actual Testing Environment: Simulator Control Room In-Plant Other Testing Method: Simulate Perform Estimated Time to Complete: 10 minutes Actual Time Used: minutes Critical Steps (*) 1 Evaluation Summary:

Were all the Critical Steps performed satisfactorily? Yes No The operators performance was evaluated against standards contained within this JPM and has been determined to be: Satisfactory Unsatisfactory Comments:

Evaluators Name:

(Print)

Evaluators Signature: Date:

Page 6 of 8

Student Handout INITIAL CONDITIONS A Safety Injection was manually initiated due to indications of RCS leakage. The Crew is performing the actions of 0POP05-EO-EO10, Loss of Reactor or Secondary Coolant, and is currently at step 15 to determine if SI flow should be terminated.

QDPS currently indicates Bad Data for RCS subcooling INITIATING CUE The Unit Supervisor directs you to calculate RCS subcooling using the same inputs used by QDPS on the given T/C QUAD TEMP screen.

Page 7 of 8

Student Handout T/C QUAD TEMP 07/13/20 10:20:57 Th W/R Th W/R 590 F 585 F Loop Loop D A Tc W/R Tc W/R 557 F 561 F QUAD D QUAD A MAX 587 F MAX 588 F AVG 572 AVG 574 MIN 567 MIN 568 RCS PRESS 1765 PSIG SUBCOOL XXXXB F QUAD C QUAD B MAX 588 F MAX 589 F AVG 573 AVG 577 Tc W/R MIN 567 MIN 569 Tc W/R 560 F 560 F Loop C Loop B

Th W/R Th W/R 592 F 588 F Page 8 of 8

STPNOC 11B Job Performance Measure 0B CALCULATE TIME TO BOIL IN THE RCS 1B JPM Number: NRC A2 2B Revision Number: 1 3B Date: 07/13/2020 N/A N/A 4B Developed By:

Instructor (Print/Sign) Date N/A N/A 6B Approved By:

Training Supervisor (Print/Sign) Date N/A N/A 8B Approved By:

Line Management (Print/Sign) Date 10B NOTE: N/A signature blocks if this JPM is being used on an NRC LOT Exam.

NRC A2 - Rev 1 Revision Record (Summary)

Revision 0; Drafted JPM for use on the LOT 24 NRC exam.

Revision 1; Updated for Final Submittal on the LOT 24 NRC exam.

Page 2 of 7

NRC A2 - Rev 1 SIMULATOR SETUP INSTRUCTIONS

1. This is an Admin JPM.

Page 3 of 7

NRC A2 - Rev 1 INITIAL CONDITIONS:

Unit 1 is in day 34 of a Refueling Outage.

The Operating Crew is in 0POP03-ZG-0009, Mid-Loop Operation.

Current RCS level is 33.

Current RCS temperature is 104ºF.

INITIATING CUE:

Subsequently all RHR is lost.

The Unit Supervisor directs you to calculate the time it will take for saturated conditions to occur in the RCS per 0POP03-ZG-0009, Mid-Loop Operation.

Fill in the JPM Start Time when the student acknowledges the Initiating Cue.

Information For Evaluators Use:

UNSAT requires written comments on respective step.

Denotes critical steps.

If Time Critical, estimated time is the Time Critical time.

Number any comments in the Comment Number column on the following pages. Then annotate that comment in the Comments section. The comment section should be used to document: the reason that a step is marked as unsatisfactory, marginal performance relating to management expectations, or problems the examinee had while performing the JPM.

Comments relating to procedural or equipment issues should be entered and tracked using the sites appropriate tracking system.

Some operations that are performed from outside of the control room may require multiple steps. These items may be listed as individual steps in this JPM. It is acceptable for the candidate to direct the local operator to perform groups of procedure steps instead of calling for each individual item to be performed.

The timeclock starts when the candidate acknowledges the initiating cue.

Task Standard:

Using Addendum 4 of 0POP03-ZG-0009, Mid-Loop Operation, correctly calculates the time that saturated conditions would occur in the RCS is 37.6 to 39.6 minutes. (38.6 + or - 1 minute)

Page 4 of 7

NRC A2 - Rev 1 JPM Start Time:

Comment STEP ELEMENT STANDARD SAT UNSAT Number NOTE Provide Initial Cue Sheet and Student HO of 0POP03-ZG-0009, Mid-Loop Operation.

When the student has reviewed the Initial Cue and they have indicated they are ready to begin the JPM, then record the start time for the JPM.

A KEY is provided showing the correct time on Addendum 4 of 0POP03-ZG-0009, Mid-Loop Operation.

1 With the given information from Calculates the amount of time ___ ___ ___

the Initiating Cue, the operator for the RCS to boil on a loss of calculates the amount of time all RHR to be 38.6 minutes.

for the RCS to boil from a loss of all RHR using the chart in NOTE:

Addendum 4 of 0POP03-ZG- The Addendum 4 graph does 0009, Mid-Loop Operation. not give an RCS initial (0POP03-ZG-0009, Add #4) temperature of 104ºF. The Operator will need to interpolate. To allow for interpolation of 104ºF an answer of 37.6 to 39.6 minutes will be allowed.

CUE This JPM is completed JPM Stop Time:

Page 5 of 7

NRC A2 - Rev 1 JPM

SUMMARY

Operators Name: Job

Title:

Title:

CALCULATE TIME TO BOIL IN THE RCS JPM Number: NRC A2 Revision Number: 1 Task Number and

Title:

32350, Monitor the RCS K/A Number and Importance: 2.1.25 3.9/4.2 Suggested Testing Environment: Simulator Control Room In-Plant Other Alternate Path: Yes No Task Designed For: SRO Only RO/SRO AO/RO/SRO Time Critical: Yes No Level of Difficulty: 3 Reference(s): 0POP03-ZG-0009, Mid-Loop Operation, Rev 68 Actual Testing Environment: Simulator Control Room In-Plant Other Testing Method: Simulate Perform Estimated Time to Complete: 10 minutes Actual Time Used: minutes Critical Steps (*) 1 Evaluation Summary:

Were all the Critical Steps performed satisfactorily? Yes No The operators performance was evaluated against standards contained within this JPM and has been determined to be: Satisfactory Unsatisfactory Comments:

Evaluators Name: ______

(Print)

Evaluators Signature: Date:

Page 6 of 7

Student Handout INITIAL CONDITIONS:

Unit 1 is in day 34 of a Refueling Outage.

The Operating Crew is in 0POP03-ZG-0009, Mid-Loop Operation.

Current RCS level is 33.

Current RCS temperature is 104ºF.

INITIATING CUE:

Subsequently all RHR is lost.

The Unit Supervisor directs you to calculate the time it will take for saturated conditions to occur in the RCS per 0POP03-ZG-0009, Mid-Loop Operation.

Provide Answer Below:

Calculated time in minutes = _________________________________

Page 7 of 7

0POP03-ZG-0009 Rev. 68 Page 67 of 116 Mid-Loop Operation Addendum 4 Reactor Vessel Time to Boil Following Loss of RHR Page 1 of 1 During Mid-Loop Operation Ref 2.20 REACTOR VESSEL TIME-TO-BOIL FOLLOWING LOSS OF RHR COOLING DURING MID-LOOP OPERATION Chart NOT Cycle Specific. Chart NOT applicable to vacuum fill conditions.

45 RCS initially at 100 F 104 degrees F Answer RCS initially at 120 F Interpolated 40 38.6 minutes (+

RCS initially at 140 F or - 1 minute) 35 Time to Boil (Minutes) 30 25 20 15 10 KEY 5

0 5 10 15 20 25 30 35 40 34 Time After Shutdown (Days)

STPNOC 11B Job Performance Measure 0B PREPARE AN ECO FOR A MAIN TURBINE LUBE OIL COOLER 1B JPM Number: NRC A3 2B Revision Number: 1 3B Date: 07/13/2020 4B Developed By: N/A N/A Instructor (Print/Sign) Date N/A 6B Approved By: N/A Training Supervisor (Print/Sign) Date 8B Approved By: N/A N/A Line Management (Print/Sign) Date 10B NOTE: N/A signature blocks if this JPM is being used on an NRC LOT Exam.

NRC A3 - rev 1 Revision Record (Summary)

Revision 0, Drafted JPM for use on the LOT 24 NRC exam.

Revision 1; Updated for Final Submittal on the LOT 24 NRC exam.

Page 2 of 9

NRC A3 - rev 1 SIMULATOR SETUP INSTRUCTIONS This is an Admin JPM - No simulator setup instructions required.

Page 3 of 9

NRC A3 - rev 1 INITIAL CONDITIONS Unit 1 is at 100% power.

Main Turbine Lube Oil Cooler #11 had indications of tube blockage and has been removed from service. Main Turbine Lube Oil Cooler #12 was placed in service.

INITIATING CUE The Unit Supervisor directs you to prepare an ECO to control LO System Configuration and isolate Main Turbine Lube Oil Cooler #11 to perform initial venting and draining based on the ECO request received from Mechanical Maintenance.

NOTE:

The Oracle ECO Database is unavailable.

ECO Form 3, Pages 1 and 2 of 3, are already filled out.

Page 4 of 9

NRC A3 - rev 1 Fill in the JPM Start Time when the student acknowledges the Initiating Cue.

Information For Evaluators Use:

UNSAT requires written comments on respective step.

Denotes critical steps.

If Time Critical, estimated time is the Time Critical time.

Number any comments in the Comment Number column on the following pages. Then annotate that comment in the Comments section. The comment section should be used to document: the reason that a step is marked as unsatisfactory, marginal performance relating to management expectations, or problems the examinee had while performing the JPM.

Comments relating to procedural or equipment issues should be entered and tracked using the sites appropriate tracking system.

Some operations that are performed from outside of the control room may require multiple steps. These items may be listed as individual steps in this JPM. It is acceptable for the candidate to direct the local operator to perform groups of procedure steps instead of calling for each individual item to be performed.

The timeclock starts when the candidate acknowledges the initiating cue.

Task Standard:

Correctly prepares an ECO which will isolate and drain the Open Loop ACW side of Main Turbine Lube Oil Cooler #11 AND control Lube Oil flow to Cooler #12 in accordance with 0PGP03-ZO-EC01A, Equipment Clearance Order Instructions.

In JPM Step #1 the following valves are correctly identified and positioned:

LT-0049 (LO Cooler Transfer Valve) Position - Cooler 12; Boundary - No

OC-0025 (Isolation Valve) Position - Closed; Boundary - Yes

OC-0029 (Isolation Valve) Position - Closed; Boundary - Yes

OC-0223 (Drain Valve) Position - Open; Boundary - No

OC-0217 (Vent Valve) OR OC-0219 (Vent Valve) OR OC-0224 (Vent Valve) Position -

Open; Boundary - No NOTE:

In addition; All items should identify a D in the Type column, Hang in the Action column and Y in the Verification Required column.

Also see the KEY supplied with JPM.

Page 5 of 9

NRC A3 - rev 1 JPM Start Time:

Comment STEP ELEMENT STANDARD SAT UNSAT Number NOTE Provide the following Student Handouts:

HO1 - ECO request completed by maintenance

HO2 - Blank copy of 0PGP03-ZO-ECO1A

HO3 - Blank copy of 0POP02-LT-0001

HO4 - Blank copy of 0POP02-OC-0001

HO5 - Main Turbine Lube Oil P&ID

HO6 - Open Loop Aux Cooling Water P&ID

HO7 - ECO Form 3 with Pages 1 and 2 filled out The student should also use Form 9, ECO Preparation Checklist, but it is not required for this JPM.

Page 6 of 9

NRC A3 - rev 1 Comment STEP ELEMENT STANDARD SAT UNSAT Number

1 Completes Page 3 of Form 3 Identifies and enters the ___ ___ ___

following:

LT-0049 (LO Cooler Transfer Valve)

Position - Cooler 12 Boundary - No

OC-0025 (Isolation Valve)

Position - Closed Boundary - Yes

OC-0029 (Isolation Valve)

Position - Closed Boundary - Yes

OC-0223 (Drain Valve)

Position - Open Boundary - No

OC-0217 (Vent Valve)

OR OC-0219 (Vent Valve)

OR OC-0224 (Vent Valve)

Position - Open Boundary - No NOTE:

All items should identify a D in the Type column, Hang in the Action column and Y in the Verification Required column.

Also see the KEY CUE This JPM is complete JPM Stop Time:

Page 7 of 9

NRC A3 - rev 1 JPM

SUMMARY

Operators Name: Job

Title:

Title:

PREPARE AN ECO FOR A MAIN TURBINE LUBE OIL COOLER JPM Number: A3 Revision Number: 1 Task Number and

Title:

CRO-68950, Prepare Equipment Clearances K/A Number and Importance: 2.2.13 4.1/4.3 Suggested Testing Environment: Simulator Control Room In-Plant Other Alternate Path: Yes No Task Designed For: SRO Only RO/SRO AO/RO/SRO Time Critical: Yes No Level of Difficulty: 4 Reference(s): 0PGP03-ZO-ECO1A, Equipment Clearance Order Instructions, Rev. 31; 9F00033#1; 9F20010#1 Actual Testing Environment: Simulator Control Room In-Plant Other Testing Method: Simulate Perform Estimated Time to Complete: 20 minutes Actual Time Used: minutes Critical Steps (*) 1 Evaluation Summary:

Were all the Critical Steps performed satisfactorily? Yes No The operators performance was evaluated against standards contained within this JPM and has been determined to be: Satisfactory Unsatisfactory Comments:

Evaluators Name:

(Print)

Evaluators Signature: Date:

Page 8 of 9

Student Handout INITIAL CONDITIONS Unit 1 is at 100% power.

Main Turbine Lube Oil Cooler #11 had indications of tube blockage and has been removed from service. Main Turbine Lube Oil Cooler #12 was placed in service.

INITIATING CUE The Unit Supervisor directs you to prepare an ECO to control LO System Configuration and isolate Main Turbine Lube Oil Cooler #11 to perform initial venting and draining based on the ECO request received from Mechanical Maintenance.

NOTE:

The Oracle ECO Database is unavailable.

ECO Form 3, Pages 1 and 2 of 3, are already filled out.

Page 9 of 9

0PGP03-ZO-ECO1A Rev. 31 Page 93 of 119 Equipment Clearance Order Instructions Form 3 (Rev. 1) Equipment Clearance Order Form Page 1 of 3 ECO Number: 1 2020 11111

________-_______-_____________ Unit: 1 2 Page _1_ of _3_

Unit Year Number HAZARDOUSE ENERGY? Yes No Notify Fire Protection? Yes No Notify Security? Yes No What Is Being Tagged? _MTLO Cooler #11__ TPNS# __7T111MHX002A__

Work

Description:

Remove MTLO Cooler #11 end bell and clean tubes Operator should sign and date ECO Operator Signs and Dates for 'Prepared By:'

Prepared By: _________________________________ ___________ __________

Signature Date Time However, this is NOT Critical Tech Review By: _________________________________ ___________ __________

Signature Date Time Approved By: _________________________________ ___________ __________

Signature Date Time Notes:

Operator may mark in this area that this is an EXCEPTIONAL ECO due to single valve protection to Hazardous Energy.

However, this is NOT Critical.

THIS FORM, WHEN COMPLETE, SHALL BE RETAINED FOR A MINIMUM OF 5 YEARS. RMS Z10.03

0PGP03-ZO-ECO1A Rev. 31 Page 94 of 119 Equipment Clearance Order Instructions Form 3 (Rev. 2) Equipment Clearance Order Form (Job Additions) Page 2 of 3 ECO Number: 1 2020 11111

________-________-___________ Page 2 of 3 Unit Year Number Job Ready for Work Document Work Group Work Group Job Work Addition Work T WAN / CR / Sign ON Sign OFF(Print, Sign, Date Number Group Group S Procedure Add SRO (Print, Sign, Date Time) Time)

Acceptance 114260 MM

( Work Description ) Control LO Configuration and isolate MTLO Cooler #11 to perform initial venting and draining in preparation of end bell removal and tube cleaning.

( Work Description )

THIS FORM, WHEN COMPLETE, SHALL BE RETAINED FOR A MINIMUM OF 5 YEARS. RMS Z10.03

0PGP03-ZO-ECO1A Rev. 31 Page 95 of 119 Equipment Clearance Order Instructions Form 3 (Rev. 1) Equipment Clearance Order Form (Line Items) Page 3 of 3 ECO Number: 1 2020 11111

________-_______-_____________ Page 3 of __3__

Unit Year Number Line Number BOUNDARY Performed By Verification Exe. Seq Verified By Component ID Type Or Action Required Position Required?

Instructions 1-LT-0049 1 D LO COOLER TRANSFER Y Hang 1 Cooler 12 VALVE B 1-OC-0025 2 D TURBINE LO COOLER 11 Y Hang 2 Closed INLET ISOL 1-OC-0029 3 D B TURBINE LO COOLER 11 Y Hang 2 Closed OUTLET ISOL 1-OC-0223 TURBINE LUBE OIL 4 D Y Hang 3 Open COOLER 11 OPEN LOOP ACW DRAIN VALVE 1-OC-0217 OR 1-OC-0219 5 D OR Y Hang 4 Open 1-OC-0224 TURBINE LO COOLER 11 VENT VALVES Critical Items NOTE: 1-OC-0223 and 1-OC-0224 are located on the end bell being removed, however, they would be used for initial venting and draining. A revision to the ECO would be made to remove tags from these valves after venting and draining to remove the end bell.

NOTE THIS FORM, WHEN COMPLETE, SHALL BE RETAINED FOR A MINIMUM OF 5 YEARS. RMS Z10.03 1-LT-0063, LO Cooler Interchange Valve, is a bypass valve around 1-LT-0049, LO Cooler Transfer Valve. The Operator may identify this valve as being needed for the ECO but it is NOT required.

7 COOLERS (2)

SGFP TURBINE V V O> PSV u

FY l""'I 67 62 X

LUBE OIL COOLERS C6l 9316

<O N

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FO m

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or 0

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=;=-

D E-....f------1 ZLP 3"0C1048WY7 Close both isolation valves:

/

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TEMP BUL B MOU N TED 1-OC-0029 oc WL !ai'ui y

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DISCH.SEE REF 2 ... u Ill C O C 0093 8 X O> FY IF C

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t 7T 1 11MHX003A 1F 0003 2 SHT5 NOTES:

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PUMPS 11, 12 8, COOR ' D . E-8 D1H_ _____J TO 13 OC0222 3"X1" : - t*E **E /PS_L, 1. EACH SGFP L UBE OIL COOLER IS RA TED FOR 100Y. HEAT LOAD.

OC03 2 3 IF FT T THIS DWG F-1 )

3"0C1044 I- u 675 3 1/

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,.,_ IF 7T 2 41MJX68 I ZL P I I A ,ITEM 15 , f.-J 3"X1" OC030 3 H 50 10. DELETED

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67 75 WY 7 L7 ITEM 12 NOTE 4 6753

- 14 . FOR STEAM GENERA TO R FEED PUMP LUBE OI L

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18"X16"

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( TYPI

\

6775 FO J"X1 " 15. THE CONICAL SECTION ON F LOW ORIFICE F0*6754A WAS

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T F RO M TY-605 0 675 3 10"X8"

--- T HE SAME SIZE AS T HE I N SI DE DIAMETE R OF T HE PIPE.

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STPNOC 10B Job Performance Measure 0B DETERMINE RWP REQUIREMENTS FOR WORK IN RRA (SFP) 1B JPM Number: NRC A4 2B Revision Number: 1 3B Date: 07/23/2020 4B Developed By:

Instructor (Print/Sign) Date 6B Approved By:

Training Supervisor (Print/Sign) Date 8B Approved By:

Line Management (Print/Sign) Date

NRC A4 - rev 1 Revision Record (Summary)

Revision 0, Drafted JPM for use on LOT 24 NRC Exam.

Revision 1; Updated for Final Submittal on the LOT 24 NRC exam.

Page 2 of 7

NRC A4 - rev 1 SIMULATOR SETUP INSTRUCTIONS This is an Admin JPM - No simulator setup instructions required.

Page 3 of 7

NRC A4 - rev 1 INITIAL CONDITIONS You have been directed to move Fuel Assemblies from Region 1 to Region 2 per approved Fuel Transfer Forms.

INITIATING CUE This activity will require you to work in a Radiological Restricted Area. Given a Radiological Work Permit (RWP) and Survey Map of the FHB, you are to determine the following:

What are the MINIMUM dress requirements for performing this work per the RWP and Survey Map?

How long will you be able to perform the task per the RWP and Survey Map?

Fill in the JPM Start Time when the student acknowledges the Initiating Cue.

Information For Evaluators Use:

UNSAT requires written comments on respective step.

Denotes critical steps.

If Time Critical, estimated time is the Time Critical time.

Number any comments in the Comment Number column on the following pages. Then annotate that comment in the Comments section. The comment section should be used to document: the reason that a step is marked as unsatisfactory, marginal performance relating to management expectations, or problems the examinee had while performing the JPM.

Comments relating to procedural or equipment issues should be entered and tracked using the sites appropriate tracking system.

Some operations that are performed from outside of the control room may require multiple steps. These items may be listed as individual steps in this JPM. It is acceptable for the candidate to direct the local operator to perform groups of procedure steps instead of calling for each individual item to be performed.

The timeclock starts when the candidate acknowledges the initiating cue.

Task Standard:

Operator determines the following per the RWP and Survey Map:

MINIMUM dress requirements are one full set of protective clothing and surgeons gloves to be used for the outer set of gloves when handling fuel handling machine tools.

AND

The task can be performed for 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months and then the maximum setpoint (10 mrem) will be reached on the alarming dosimeter.

Page 4 of 7

NRC A4 - rev 1 JPM Start Time:

Comment STEP ELEMENT STANDARD SAT UNSAT Number NOTE Provide Student Handout of Initiating Cue and Student Handout of the RWP & Survey Map.

When the student has reviewed the Initial Conditions & Initiating Cue and they have indicated they are ready to begin the JPM, then record the start time for the JPM.

A KEY is provided for the Examiner.

Determines the following:

1 Reviews RWP and Survey Map ___ ___ ___

to determine the following:

MINIMUM dress requirements are one full set

MINIMUM dress of protective clothing and requirements per the RWP surgeons gloves to be used and Survey Map.

for the outer set of gloves

How long the task can be when handling fuel handling performed per the RWP and machine tools.

Survey Map.

AND

The task can be performed for 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months and then the maximum setpoint (10 mrem) will be reached on the alarming dosimeter.

Note:

See TASK STANDARD and answer KEY provided.

CUE This JPM is complete JPM Stop Time:

Page 5 of 7

NRC A4 - rev 1 JPM

SUMMARY

Operators Name: Job

Title:

Title:

DETERMINE RWP REQUIREMENTS FOR WORK IN RRA (SFP)

JPM Number: NRC A4 Revision Number: 1 Task Number and

Title:

T67500, Operate the Spent Fuel Handling Machine/Bridge Hoist.

K/A Number and Importance: G2.3.7 3.5/3.6 Suggested Testing Environment: Simulator Control Room In-Plant Other Alternate Path: Yes No Task Designed For: SRO Only ; RO/SRO ; AO/RO/SRO Time Critical: Yes No Level of Difficulty: 3 Reference(s): Radiation Work Permit with Survey Map Actual Testing Environment: Simulator Control Room In-Plant Other Testing Method: Simulate Perform Estimated Time to Complete: 10 minutes Actual Time Used: minutes Critical Steps (*) 1 Evaluation Summary:

Were all the Critical Steps performed satisfactorily? Yes No The operators performance was evaluated against standards contained within this JPM and has been determined to be: Satisfactory Unsatisfactory Comments:

Evaluators Name:

(Print)

Evaluators Signature: Date:

Page 6 of 7

Student Handout INITIAL CONDITIONS You have been directed to move Fuel Assemblies from Region 1 to Region 2 per approved Fuel Transfer Forms.

INITIATING CUE This activity will require you to work in a Radiological Restricted Area. Given a Radiological Work Permit (RWP) and Survey Map of the FHB, you are to determine the following:

What are the MINIMUM dress requirements for performing this work per the RWP?

How long will you be able to perform the task per the RWP and Survey Map?

Provide Answer below:

Page 7 of 7

KEY STP SOUTH TEXAS PROJECT PERMT/RWP ELECTRIC GENERATING STATION U10 RADIATION WORK PERMIT 2020-1-0071 PERFORM FUEL MOVEMENT ACTIVITIES IN FHB REVISION 0 WHITE RCA Entry Card Required ACTIVE 05/01/2020 00:00 TERMINATION 12/31/2020 23:59 JOB DESCRIPTION PERFORM FUEL MOVEMENT IN FHB MOVE FUEL FROM REGION 1 TO REGION 2 SUPPORT WORK RADIOLOGICAL DATA CONTAMINATION DOSE RATES ALARM SETPOINTS GA: 1000 dpm/100cm2 GA: < 1 mrem/hr ALARM SETPOINT: 10 mrem WORK: 100000 dpm/100cm2 WORK: 1-5 mrem/hr ALARM RATE: 25 mrem/hr AIRBORNE: < 1 DAC The area in the circle is the alarming dosimeter setpoint. This setpoint is compared RESTRICTIONS to the dose readings on

NO ENTRY INTO POSTED LOCKED theHIGH Survey Map where RADIATION the operator AREAS will

NO ENTRY INTO POSTED HIGH RADIATION AREAS be working. The operator

NO ENTRY INTO POSTED AIRBORNE should compare the AREAS RADIOACTIVITY dose levels on (EXCLUDING NOBLE GAS)

NO CONTAMINATED BREACH ALLOWED the Survey Map (2 mrem/hr) to the alarm set point (10 mrem) on the CHANGE OUT OF UNDERWATER FILTERS IN NOT ALLOWED ON THIS RADIATION WORK PERMIT RWP.

THIS RADIATION WORK PERMIT DOES NOT ALLOW MOVEMENT IF IRRADIATED MATERIAL KNOWN TO BE GREATER THAN 10 rem/hr WITHThe amount TOOLS of time the THAT OR EQUIPMENT operator ARE NOT CONTROLLED BY TOOL can perform the task per the RWP LENGTH OR LIMIT SWITCHES THAT WOULD ALLOW UNRESTRICTED MOVEMENT OF THE MATERIAL PAST THE SURFACE OF THE WATER.and Survey Map would calculate to 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months .

REQUIREMENTS DOSIMETRY RESPIRATORY PROTECTION RAD. PROT. COVERAGE WB TLD NONE INTERMITTENT EPD SIGNATURES TOMEK, MICHAEL K 05/07/2020 09:34 Approved By Date/Time Terminated By Date/Time This document when completed, SHALL be retained in accordance with the Documents Type List. Page 1 KEY

KEY STP SOUTH TEXAS PROJECT PERMT/RWP ELECTRIC GENERATING STATION U10 RADIATION WORK PERMIT 2020-1-0071 PERFORM FUEL MOVEMENT ACTIVITIES IN FHB REVISION 0 WHITE RCA Entry Card Required Entry Requirements PRE-JOB BRIEFING REQUIRED WITH RADIATION PROTECTION PRIOR TO FUEL MOVEMENT Dress Requirements FOR REMOVING ITEMS COMPLETELY FROM WATER:

One full set protective clothing FOR ENTRY INTO A POSTED CONTAMINATION AREA One full set protective clothing For work over water, surgeons cap may be substituted for hood provided life vest used for floatation does not touch neck.

Surgeons gloves are to be used for the outer set of gloves when handling fuel handling machine tool.

FOR ENTRY INTO POSTED HIGH CONTAMINATION AREA One full set of protective clothing Second set of coveralls, second set of shoe covers and second set of glovesFor moving gloves (surgeons fuel assemblies allowed with permission from radiation protection) from Region 1 to Region 2 Water repellent protective clothing may be substituted for second set of coveralls the operator for wetwillwork.

be working in a contaminated area per Additional Requirements the Survey Map.

FOR PARTIAL REMOVAL OF ITEMS FROM WATER As per instructions/guidance from RP MINIMUM dress FOR REMOVING ITEMS COMPLETELY FROM WATER requirements would be one Due to high contamination levels and the potential for high dose rates, allfull itemssetremoved from clothing of protective the spent fuel pool shall be surveyed by RP and wiped and/or rinsed with demin water as items are AND surgeons gloves as the being removed. NOTE: PERMISSION FROM MAIN CONTROL ROOM IS REQUIRED outer setPRIOR TO ADDING of gloves when DEMIN WATER TO THE SPENT FUEL POOL handling the fuel handling Items shall be lowered back into the water immediately if radiation monitor on bridge machine tool.alarms.

Permission from RP supervisor/designee required to continue activities if dose rates at the surface of the water exceed 100 mrem/hr. NOTE: Both of the above are Cautions/ALARA Notes required for this task, Do not attempt to retrieve any debris or trash observed floating in the water. however, NotifyaRP surgeons for surveycap is and retrival. optional.

An area radiation monitor (ARM) set to alarm at 3 mrem/hr shall be placed on fuel handling bridge prior to movement of fuel. If monitor alarms put the work in a safe condition, leave the area and notify RP.

Movement of irradiated material or fuel within 5 feet of the southwest spent fuel pool cask canal gate or the transfer canal gate, if the transfer canal is drained, requires specific approval from the radiation protection supervisor responsible for the fuel handling building.

This document when completed, SHALL be retained in accordance with the Documents Type List. Page 2 KEY

KEY The area in the circle is the SFP and is made up of Region 1 and Region 2. This is the area where the operator would be working. The operator should compare the dose levels in this area (2 mrem/hr) to the alarm set point (10 mrem) on the RWP.

The amount of time the operator can perform the task per the RWP and Survey Map would calculate to 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months .

This Survey Map also indicates that this area is a Contaminated Area and is used to determine dress requirements from the RWP.

KEY

STPNOC 11B Job Performance Measure 0B CALCULATE SUBCOOLING MARGIN AND APPLY TECH SPECS 1B JPM Number: NRC A5 2B Revision Number: 1 3B Date: 07/13/2020 N/A N/A 4B Developed By:

Instructor (Print/Sign) Date N/A N/A 6B Approved By:

Training Supervisor (Print/Sign) Date 8B Approved By: N/A N/A Line Management (Print/Sign) Date 10B NOTE: N/A signature blocks if this JPM is being used on an NRC LOT Exam.

NRC A5 - rev 1 Revision Record (Summary)

Revision 0; Drafted JPM for use on the LOT 24 NRC exam.

Revision 1; Updated for Final Submittal on the LOT 24 NRC exam.

Page 2 of 9

NRC A5 - rev 1 SIMULATOR SETUP INSTRUCTIONS

1. This is an Admin JPM.

JPM Administration:

1. Materials needed:

Clean copy of Steam Tables

Calculator

Technical Specifications Page 3 of 9

NRC A5 - rev 1 INITIAL CONDITIONS A Safety Injection was manually initiated due to indications of RCS leakage. The Crew is performing the actions of 0POP05-EO-EO10, Loss of Reactor or Secondary Coolant, and is currently at step 15 to determine if SI flow should be terminated.

QDPS DPUs A and C currently indicate Bad Data for RCS subcooling INITIATING CUE Calculate RCS subcooling using the same inputs used by QDPS on the given T/C QUAD TEMP screen and determine if any Technical Specification actions apply.

Fill in the JPM Start Time when the student acknowledges the Initiating Cue.

Information For Evaluators Use:

UNSAT requires written comments on respective step.

Denotes critical steps.

If Time Critical, estimated time is the Time Critical time.

Number any comments in the Comment Number column on the following pages. Then annotate that comment in the Comments section. The comment section should be used to document: the reason that a step is marked as unsatisfactory, marginal performance relating to management expectations, or problems the examinee had while performing the JPM.

Comments relating to procedural or equipment issues should be entered and tracked using the sites appropriate tracking system.

Some operations that are performed from outside of the control room may require multiple steps. These items may be listed as individual steps in this JPM. It is acceptable for the candidate to direct the local operator to perform groups of procedure steps instead of calling for each individual item to be performed.

The timeclock starts when the candidate acknowledges the initiating cue.

Task Standard:

Subcooling margin is calculated to be 43oF +/- 1oF. Determines one channel of Subcooling Monitoring must be restored within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or the plant placed in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . TS 3.3.3.6 Function 12, Action 36.b.

Page 4 of 9

NRC A5 - rev 1 JPM Start Time:

Comment STEP ELEMENT STANDARD SAT UNSAT Number NOTE The applicant will need a clean copy of Steam Tables to perform this task.

A key is not supplied for this JPM. See additional information in the step standards below.

1 Calculate RCS subcooling using Calculates RCS subcooling ___ ___ ___

the same inputs used by QDPS. using the RCS pressure and the maximum average quadrant temperature given on the student handout.

NOTE: From Steam Tables, saturation temperature for 1765 psig (1780 psia) is 619.5oF.

Subtracting 577oF (Maximum Quadrant TC average) from 619.5oF yields a subcooling margin of 42.5oF. QDPS would round up to 43oF. So Task Standard is 43oF + or - 1oF.

Page 5 of 9

NRC A5 - rev 1 Comment STEP ELEMENT STANDARD SAT UNSAT Number

2 Determine Technical Determines that at least one Specification applicability for the channel of Subcooling given RCS Subcooling Margin Monitoring must be restored to Monitor conditions operable status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or the plant placed in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

NOTE: TS 3.3.3.6 Function 12 requires a total number of channels of two, with a minimum number of channels required of one. Action 36.b states that with the number of operable channels less than minimum, one inoperable channel must be restored within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

CUE This JPM is complete JPM Stop Time:

Page 6 of 9

NRC A5 - rev 1 JPM

SUMMARY

Operators Name: Job

Title:

Title:

CALCULATE SUBCOOLING MARGIN AND APPLY TECH SPECS JPM Number: A5 Revision Number: 1 Task Number and

Title:

SRO-10300, Interpret Technical Specications K/A Number and Importance: G2.2.40 3.4/4.7 Suggested Testing Environment: Simulator Control Room In-Plant Other Alternate Path: Yes No Task Designed For: SRO Only RO/SRO AO/RO/SRO Time Critical: Yes No Level of Difficulty: 3 Reference(s): Lesson LOT202.44, QDPS; Technical Specification 3.3.3.6 Actual Testing Environment: Simulator Control Room In-Plant Other Testing Method: Simulate Perform Estimated Time to Complete: 15 minutes Actual Time Used: minutes Critical Steps (*) 1 Evaluation Summary:

Were all the Critical Steps performed satisfactorily? Yes No The operators performance was evaluated against standards contained within this JPM and has been determined to be: Satisfactory Unsatisfactory Comments:

Evaluators Name:

(Print)

Evaluators Signature: Date:

Page 7 of 9

Student Handout INITIAL CONDITIONS A Safety Injection was manually initiated due to indications of RCS leakage. The Crew is performing the actions of 0POP05-EO-EO10, Loss of Reactor or Secondary Coolant, and is currently at step 15 to determine if SI flow should be terminated.

QDPS DPUs A and C currently indicate Bad Data for RCS subcooling INITIATING CUE Calculate RCS subcooling using the same inputs used by QDPS on the given T/C QUAD TEMP screen and determine if any Technical Specification actions apply.

Page 8 of 9

Student Handout T/C QUAD TEMP 07/13/20 10:20:57 Th W/R Th W/R 590 F 585 F Loop Loop D A Tc W/R Tc W/R 557 F 561 F QUAD D QUAD A MAX 588 F MAX 589 F AVG 573 AVG 575 MIN 568 MIN 567 RCS PRESS 1765 PSIG SUBCOOL XXXXB F QUAD C QUAD B MAX 588 F MAX 587 F AVG 573 AVG 577 Tc W/R MIN 568 MIN 565 Tc W/R 560 F 560 F Loop C Loop B

Th W/R Th W/R 592 F 588 F Page 9 of 9

STPNOC 11B Job Performance Measure 0B REVIEW RCS INVENTORY AND DETERMINE TS APPLICABILITY 1B JPM Number: NRC A6 2B Revision Number: 1 3B Date: 07/13/2020 N/A N/A 4B Developed By:

Instructor (Print/Sign) Date N/A N/A 6B Approved By:

Training Supervisor (Print/Sign) Date N/A N/A 8B Approved By:

Line Management (Print/Sign) Date 10B NOTE: N/A signature blocks if this JPM is being used on an NRC LOT Exam.

NRC A6 - Rev 1 Revision Record (Summary)

Revision 0; Drafted JPM for use on the LOT 24 NRC exam.

Revision 1; Updated for Final Submittal on the LOT 24 NRC exam.

Page 2 of 8

NRC A6 - Rev 1 SIMULATOR SETUP INSTRUCTIONS

1. This is an Admin JPM.

Page 3 of 8

NRC A6 - Rev 1 INITIAL CONDITIONS:

Unit 1 is at 100% steady state power. Due to issues performing 0PSP03-RC-0006, Reactor Coolant Inventory, 0PSP03-RC-0006A, Alternate Reactor Coolant Inventory, has just been completed using a manual calculation.

INITIATING CUE:

You are the Unit Supervisor and 0PSP03-RC-0006A, Alternate Reactor Coolant Inventory, has been forwarded to you for review. Report all conclusions and determine applicable TS LCOs, if any, based on your review.

You are to take the following into account during your review:

Chemistry has determined Primary to Secondary leakage is 13 gpd.

Fill in the JPM Start Time when the student acknowledges the Initiating Cue.

Information For Evaluators Use:

UNSAT requires written comments on respective step.

Denotes critical steps.

If Time Critical, estimated time is the Time Critical time.

Number any comments in the Comment Number column on the following pages. Then annotate that comment in the Comments section. The comment section should be used to document: the reason that a step is marked as unsatisfactory, marginal performance relating to management expectations, or problems the examinee had while performing the JPM.

Comments relating to procedural or equipment issues should be entered and tracked using the sites appropriate tracking system.

Some operations that are performed from outside of the control room may require multiple steps. These items may be listed as individual steps in this JPM. It is acceptable for the candidate to direct the local operator to perform groups of procedure steps instead of calling for each individual item to be performed.

The timeclock starts when the candidate acknowledges the initiating cue.

Task Standard:

The Senior Reactor Operator determines the following:

A transposition error caused a miscalculation of the UNIDENTIFIED LEAK RATE. The UNIDENTIFIED LEAK RATE should have been recorded as 1.057 gpm. (1.05 to 1.065 gpm is acceptable)

Identifies that the UNIDENTIFIED LEAK RATE does NOT meet the Acceptance Criteria of 0PSP03-RC-0006A, Alternate Reactor Coolant Inventory, Step 7.1 (does NOT exceed 1.0 gpm) and that TS 3.4.6.2 applies.

Page 4 of 8

NRC A6 - Rev 1 JPM Start Time:

Comment STEP ELEMENT STANDARD SAT UNSAT Number NOTE Provide Initial Cue Sheet, Student HO1 of 0PSP03-RC-0006A, Alternate Reactor Coolant Inventory, Student HO2 of Plant Curve 10.8 for PRT and Student HO3 of Plant Curve 10.9 for RCDT.

When the student has reviewed the Initial Cue and they have indicated they are ready to begin the JPM, then record the start time for the JPM.

A KEY is provided showing the transposition error and what the correct unidentified RCS leakage should be.

1 The Senior Reactor Operator The Senior Reactor Operator ___ ___ ___

reviews the completed determines that a transposition surveillance 0PSP03-RC- error caused a miscalculation of 0006A, Alternate Reactor the RCS UNIDENTIFIED Coolant Inventory. LEAKAGE Rate. The UNIDENTIFIED LEAKAGE RATE should have been 1.057 gpm.

NOTE:

A calculated value for RCS unidentified leakage of 1.05 to 1.065 gpm will be acceptable.

Page 5 of 8

NRC A6 - Rev 1 Comment STEP ELEMENT STANDARD SAT UNSAT Number

2 The Senior Reactor Operator The Senior Reactor Operator ___ ___ ___

applies the correct Technical determines that Technical Specification. Specification 3.4.6.2 applies to CUE: the unidentified RCS leakage being greater than 1.0 gpm.

If the Operator only reports that the acceptance criteria is NOT met, then ask them to identify why the acceptance criteria is not met and the specific TS that applies.

CUE This JPM is completed JPM Stop Time:

Page 6 of 8

NRC A6 - Rev 1 JPM

SUMMARY

Operators Name: Job

Title:

Title:

REVIEW RCS INVENTORY AND DETERMINE TS APPLICABILITY JPM Number: NRC A6 Revision Number: 0 Task Number and

Title:

SRO - 12000, Authorize the Start of and Review Surveillance Tests K/A Number and Importance: G2.1.7 4.4/4.7 Suggested Testing Environment: Simulator Control Room In-Plant Other Alternate Path: Yes No Task Designed For: SRO Only RO/SRO AO/RO/SRO Time Critical: Yes No Level of Difficulty: 3 Reference(s): 0PSP03-RC-0006A, Alternate Reactor Coolant Inventory, Rev 12 Actual Testing Environment: Simulator Control Room In-Plant Other Testing Method: Simulate Perform Estimated Time to Complete: 10 minutes Actual Time Used: minutes Critical Steps (*) 1 Evaluation Summary:

Were all the Critical Steps performed satisfactorily? Yes No The operators performance was evaluated against standards contained within this JPM and has been determined to be: Satisfactory Unsatisfactory Comments:

Evaluators Name: ______

(Print)

Evaluators Signature: Date:

Page 7 of 8

Student Handout INITIAL CONDITIONS:

Unit 1 is at 100% steady state power. Due to issues performing 0PSP03-RC-0006, Reactor Coolant Inventory, 0PSP03-RC-0006A, Alternate Reactor Coolant Inventory, has just been completed using a manual calculation.

INITIATING CUE:

You are the Unit Supervisor and 0PSP03-RC-0006A, Alternate Reactor Coolant Inventory, has been forwarded to you for review. Report all conclusions and determine applicable TS LCOs, if any, based on your review.

You are to take the following into account during your review:

Chemistry has determined Primary to Secondary leakage is 13 gpd.

Page 8 of 8

0PSP03-RC-0006A Rev. 12 Page 9 of 26 Alternate Reactor Coolant Inventory NOTE

This test should be performed over a two hour period unless steady conditions cannot be maintained. A test period of one hour is sufficient to satisfy the surveillance test. The test period may be specified at the discretion of the Shift Manager/Unit Supervisor.

Although makeup to the VCT for Tave control during the data collection period does not invalidate the test results, plant conditions should be established, when possible, such that this activity is not be required during the test period. IF a makeup is required, THEN sufficient time for plant stabilization should be allowed prior to obtaining stop time data.

Steps 4.8 and 4.9 direct data recording requirements when Makeup Totalizer FQI-0111B is NOT functional.

KEY 5.5 WHEN determined test period has elapsed, THEN PERFORM the following:

5.5.1 ENSURE Stop time Reactor Power is within 1% of Start time Reactor Power. _____

5.5.2 ENSURE Stop time PRZR pressure is within 10 psig of Start time PRZR pressure. (IF <1700 psig PRZR pressure and utilizing stable RCS pressure, THEN ENSURE STOP time RCS pressure is within 10 psig of START time QDPS RCS pressure.) _____

5.5.3 WHEN Reactor Power and Pressure data are within above limits, THEN RECORD STOP data on Data Sheet 1. _____

5.6 DETERMINE PRT level in gallons from percent using the Plant Curve Book, Figure 10.8, PZR Relief Tank. _____

5.7 DETERMINE RCDT level in gallons from percent using the Plant Curve Book, Figure 10.9, RC Drain Tank. _____

This value is calculated 5.8 PERFORM Pressurizer level correction factor calculation:correctly, however, it was transposed to Data Sheet 1 2241 68.3 + 0.023 (2235 - _________ 68.162 gal/% as 6.8162. (off by a factor psig) = _______ _____

of Stop Press 10) 5.9 PERFORM temperature correction factor calculation:

5.9.1 IF pressure is approximately 400 psig AND Stop Temperature is between 240 and 400F, THEN PERFORM the following:

N/A 32 + 0.147 (________ o N/A F - 240) = ________ gal/oF Stop Temp N/A 5.9.2 IF pressure is approximately 2235 psig AND Stop Temperature is between 500 and 600oF, THEN USE Addendum 1. _____

0PSP03-RC-0006A Rev. 12 Page 10 of 26 Alternate Reactor Coolant Inventory This is an error 5.10 PERFORM Gross Leakage Rate calculation:

carried forward and 5.10.1 SUM changes in VCT, PRZR, TEMP and Makeup. should be 184.765 This value is off by a factor of 10 due _______

-41.7 14.314 gal + _______

gal + _______ 63 20.325 gal + _______ 55.939 gal gal = _______

to the transposition VCT PRZR TEMP Makeup Total error described This is an error 5.10.2 above. This valvue DIVIDE the sum by the elapsed time: carried forward and should be 143.14 should be 1.349.

55.939 gal _______

_______ 137 0.408 min = ___________ gpm gallons.

Total Time GROSS Leakage Rate 5.11 PERFORM Identified Leakage Rate calculation:

KEY 5.11.1 SUM data from the PRT and RCDT: _____

0.0

________ 38.6 gal + _______ 38.6 gal = _______ gal PRT RCDT Total 5.11.2 DIVIDE the sum by the elapsed time: _____

38.6

________ gal ________

137 0.282 min = _________________ gpm Total Time Contained Leak Rate 5.11.3 OBTAIN Primary-to-Secondary Leak Rate (gpd) from ONE of the following and Record in Step AND RECORD in Step 5.11.4.

(Reference 8.4.4, 8.4.5)

(Preferred) RECORD from RM-11 Grid 3 1427(2427) Trend.

(Monitor RT-8027) _____

(Alternate) RECORD from ICS COMPUTER POINT RARM8027D (Monitor RT-8027) N/A

(Alternate) RECORD from CP-023, RT-8027 GPD illuminated, (CHANNEL 4) (Monitor RT-8027) N/A

(Alternate) REQUEST Chemistry to determine Primary-to-Secondary Leak Rate per 0PCP09-ZR-0005, Determination of Primary to Secondary Leak Rate. N/A 5.11.4 DIVIDE leak rate by 1440 to determine leak rate in gallons per minute.

13

________ 0.01 gpd (1440 min/day) = ________ gpm _____

Primary-to-Secondary Leakage Rate

0PSP03-RC-0006A Rev. 12 Page 11 of 26 Alternate Reactor Coolant Inventory NOTE

Uncontained RCS Leakage may be determined using computer generated data when available or Form 1, Uncontained Identified Leakage Rate.

IF the Uncontained Identified Leakage Rate is less than 0.001 gpm, THEN zero (0) may be entered in Step 5.11.5.

5.11.5 ENTER the Uncontained Identified RCS Leak Rate as determined by Form 1, Uncontained Identified Leakage Rate, or approved computer program. _____

Uncontained Identified Leakage Rate: 0.0

_________ gpm KEY NOTE IDENTIFIED LEAKAGE Rate Acceptance Criteria is less than or equal to 10 gpm.

AC 5.12 DETERMINE IDENTIFIED LEAKAGE Rate by SUMMING Contained, Primary-to-Secondary and Uncontained Leakage Rates.

0.282 gpm + _______

_______ 0.01 gpm + _______ 0.292 0.0 gpm = _________________ gpm (5.11.2) (5.11.4) (5.11.5) IDENTIFIED LEAKAGE Rate Contained Leak Primary - Secon Uncontained Rate dary Leakage Leak Rate Rate 5.12.1 VERIFY the leakage recorded in Step 5.12 satisfies the Acceptance Criteria of Section 7.0. _____

0PSP03-RC-0006A Rev. 12 Page 12 of 26 Alternate Reactor Coolant Inventory NOTE

UNIDENTIFIED LEAKAGE Rate Acceptance Criteria is less than or equal to 1 gpm.

Due to uncertainties in determining Gross and Identified Leakage, the value for Unidentified Leakage may be negative. IF the Unidentified Leakage result is negative, THEN data collected during the test period should be reviewed for errors.

AC 5.13 DETERMINE UNIDENTIFIED LEAKAGE Rate by subtracting IDENTIFIED Error carried forward. It should LEAKAGE Rate from GROSS Leakage Rate. be 1.057 gpm which is outside 0.408 gpm - _______

_______ 0.292 gpm = ____________

0.116 gpm the acceptance Criteria per the (5.10.2) (5.12) UNIDENTIFIED LEAKAGE Note above.

Rate KEY Error carried 5.13.1 Verify the Leakage recorded in Step 5.13 satisfies the Acceptance forward from Criteria of Section 7.0. _____

5.11.2. It should be 1.349. 5.14 IF the UNIDENTIFIED Leakage is less than -0.1 gpm, THEN RE-PERFORM Reactor Coolant Inventory one additional time. N/A 5.15 IF repeated results for UNIDENTIFIED Leakage indicate less than -0.1 gpm, THEN PERFORM the following:

5.15.1 EVALUATE RCS for in-leakage. N/A 5.15.2 NOTE evaluation in Note section of DATA Sheet 1. N/A 5.16 ENSURE all applicable data has been transcribed to Data Sheet 1. _____

5.17 OBTAIN an independent verification that the manual calculations and data transcriptions are correct. _____

5.18 ENSURE all performers and verifiers sign/initial on Data Sheet 1. _____

5.19 DETERMINE test results by using Acceptance Criteria, Section 7.0 AND sign Test Performed by. _____

5.20 NOTIFY Shift Manager/Unit Supervisor of test results and completion. _____

5.21 ENTER the UNIDENTIFIED LEAKAGE result in the Enhanced Unidentified Leak Rate Program. (Refer to Addendum 2) _____

0PSP03-RC-0006A Rev. 12 Page 24 of 26 Alternate Reactor Coolant Inventory Data Sheet 1 Alternate Leak Rate Data Package Page 1 of 2 Unit Number: Test Interval: Technical Specifications Plant MODE:

(TS Credit) - Per the Surveillance

Reference:

1 Database 4.4.6.2.1.c 1,2,3, or 4 Reason for Test:

x Periodic Surveillance Test x For Surveillance Credit Test Results:

Technical Specifications Allowable Value Exceeded: x NO YES (explain in Remarks) x Acceptable (All AS LEFT data within tolerance)

Unacceptable (Any AS LEFT data NOT within tolerance) (explain in Remarks)

Test Performed by: Jack Snow Today 25 minutes ago Reactor Operator Date Time KEY Data Transcription and Bubba Smith _______

Today

_ 15 minutes_ ago Calculations Verified By: Reactor Operator Date Time Plant Ops Review:

Potential Reportable Occurrence: Yes No LCO Action Statement Entered? Yes No Reviewed By:

Shift Manager/Unit Supervisor Date Time Operations Surveillance Coordinator Review:

Reviewed By: _ _ _

Operations Surveillance Coordinator Date Time Performers and Verifiers:

Name (Print) Signature Initials Jack Snow Jack Snow JS Bubba Smith Bubba Smith BS Remarks: None This Data Sheet, when completed, shall be retained for 5 years.

0PSP03-RC-0006A Rev. 12 Page 25 of 26 Alternate Reactor Coolant Inventory Data Sheet 1 Alternate Leak Rate Data Package Page 2 of 2 NOTE

Computer generated data should be used whenever possible.

In all cases the same instrument must be used for STOP data that was used for START data.

IF indicated instrument is unavailable, THEN annotate in remarks instrument used.

Steps 4.8 and 4.9 direct data recording requirements when Makeup Totalizer FQI-0111B is NOT functional.

IF Makeup Totalizer FQI-0111B is NOT functional, THEN data may be substituted for Makeup Totalizer FQI-0111B data per Step 4.8 or 4.9.

KEY Step 5.4 Step 5.5 Correction Instrument Start Stop Factor (CF) Calculation Result Time N/A 167 minutes ago

_________ 30_________

minutes ago N/A STOP - START 137

_______ min.

Reactor Power -0.01 < 1.0%

U1169 99.93 % 99.92 % _____

_______ _______ _______ N/A STOP - START SAT/UNSAT This value has been PRZR/RCS QDPS transposed incorrectly This value is off by a Pressure PT0456

_______ 2239 psig 2.0 < 10 psig from_______

step is2241 5.8 and _______off psig N/Afactor ofSTOP - START 10 due to the _____

SAT/UNSAT by a factor of 10. It transposition error. It VCT L0112 or 43.55 44.78 % -41.7 gal Level _______ _______

should %

be 68.162. _______ 33.9 should(START - STOP)CF be 143.14. _______

PRZR Level LE0465

_______ 55.60

_______ % 53.50 %

_______ 6.8162

_______ (START - STOP)CF 14.314 gal (1)

RCS TA0412A

_______ 591.75 F

_______ 592.00 F 81.3 (STOP - START)CF 20.325 gal Tavg/Tcold (2 or 3)

Makeup 43665 gal 63 FQI-0111B or 43602 gal

_______ _______ N/A STOP - START _______ gal Totalizer PRT L0485 or 71.0

_______ % 71.0 N/A STOP - START 0

_______ gal Level _______

11528 gal

_______ 11528

________ gal RCDT L4901 or _______

40 % 50 Level _______ N/A STOP - START _______

38.6 gal 148.7

_______ gal 187.3 gal From step 5.13 should be 1.349GROSS ___________ 0.408 0.292 gpm - IDENTIFIED ___________ gpm = UNIDENTIFIED ___________0.116 gpm gpm. (4) (5) (6)

IDENTIFIED includes (Primary - to - Secondary) _______ 0.01 gpm and (Other) _______0 gpm (7) (8)

From step 5.13 should be 1.057 gpm. (1.05 to 1.065 gpm is (1) Step 5.8 (2) Step 5.9.1 The SRO(3) acceptable) Step 5.9.2 should identify that(4) Acceptance Step 5.10.2 (5) Stepfrom Criteria 5.12 (6) Step 5.13 (7) Step 5.11.4 (8) Step 5.11.5 step 7.1 is NOT met for UNIDENTIFIED LEAKAGE (the unidentified leakage exceeds 1.0 gpm) and that Tech Spec 3.4.6.2 applies.

This Data Sheet, when completed, shall be retained for 5 years.

0PGP03-ZO-ECO1A Rev. 31 Page 93 of 119 Equipment Clearance Order Instructions Form 3 (Rev. 1) Equipment Clearance Order Form Page 1 of 3 1 2020 11111 ECO Number: ________-_______-_____________ Unit: 1 2 Page _1_ of _3_

Unit Year Number HAZARDOUSE ENERGY? Yes No Notify Fire Protection? Yes No Notify Security? Yes No What Is Being Tagged? _MTLO Cooler #11__ TPNS# __7T111MHX002A__

Work

Description:

Remove MTLO Cooler #11 end bell and clean tubes Red Duke Today Now Prepared By: _________________________________ ___________ __________

Signature Date Time Tech Review By: _________________________________ ___________ __________

Signature Date Time Approved By: _________________________________ ___________ __________

Signature Date Time Notes:

Exceptional ECO Due to Single Valve Protection to Hazardous Energy THIS FORM, WHEN COMPLETE, SHALL BE RETAINED FOR A MINIMUM OF 5 YEARS. RMS Z10.03

0PGP03-ZO-ECO1A Rev. 31 Page 94 of 119 Equipment Clearance Order Instructions Form 3 (Rev. 2) Equipment Clearance Order Form (Job Additions) Page 2 of 3 ECO Number: 1 2020 11111

________-________-___________ Page 2 of 3 Unit Year Number Job Ready for Work Document Work Group Work Group Job Work Addition Work T WAN / CR / Sign ON Sign OFF(Print, Sign, Date Number Group Group S Procedure Add SRO (Print, Sign, Date Time) Time)

Acceptance 114260 MM Control LO Configuration and isolate MTLO Cooler #11 to perform initial venting and draining in preparation of end bell removal and tube cleaning.

( Work Description )

THIS FORM, WHEN COMPLETE, SHALL BE RETAINED FOR A MINIMUM OF 5 YEARS. RMS Z10.03

0PGP03-ZO-ECO1A Rev. 31 Page 95 of 119 Equipment Clearance Order Instructions Form 3 (Rev. 1) Equipment Clearance Order Form (Line Items) Page 3 of 3 1 2020 99909 ECO Number: ________-_______-_____________ Page 3 of __3__

Unit Year Number Line Number BOUNDARY Performed By Verification Exe. Seq Verified By Component ID Type Or Action Required Position Required?

Instructions 1-LT-0049 1 D LO COOLER TRANSFER Y Hang 1 Cooler 11 VALVE 1-OC-0025 2 D B TURBINE LO COOLER 11 Y Hang 2 Closed INLET ISOL 1-OC-0092 3 D B TURBINE LO COOLER 11 Y Hang 2 Closed OUTLET ISOL 1-OC-0223 TURBINE LUBE OIL 4 D Y Hang 3 Open COOLER 11 OPEN LOOP ACW DRAIN VALVE 1-OC-0217 5 D TURBINE LO COOLER 11 Y Hang 4 Open OUTLET VENT Valve number should be 1OC Required position for 1LT0049 0029 (1OC0092 is a SGFP 12 should be Cooler 12 (this lines up lube oil cooler outlet valve) oil flow through Cooler 12)

Two other vent valves can be NOTE listed but only one is required.

1-OC-0223 and 1-OC-0224 are located on the end bell being 1OC0219 OR 1OC0224 removed, however, they would be used for initial venting and draining. A revision to the ECO would be made to remove tags from This is NOT critical. these valves after venting and draining to remove the end bell.

NOTETHIS FORM, WHEN COMPLETE, SHALL BE RETAINED FOR A MINIMUM OF 5 YEARS. RMS Z10.03 1-LT-0063, LO Cooler Interchange Valve, is a bypass valve around 1-LT-0049, LO Cooler Transfer Valve. The Operator may identify this valve as missing but it is NOT required for this ECO

7 COOLERS (2)

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REFERENCES:

1. V EN DOR DW G NO. 40031 J-0142 4WT.

====== ========== ==========

DWG N O. 4010--il1006WP.

== ===E=1=3=3

2. \j/1 V E N DO R

=3 DISCHARGE PIPING f t SOUTH TEXAS PROJECT PIPING Allo 1NSTRU11ENTATION 01AGR A11

:= E= ==

61 7-11 -19 INCORP. DCN 1 9001 46. C}I! :?fh,9 NIAN/AN/A 60 7-24-14 REVISED PER CR# 1 4 - 1 0932. JGL ON ILE OPENLOOP AUXILlftRY COOLING ,w 2 59 10-15-12 INCORP. DCN 12 01 3 90 AND REVISED PER CR 12-218- 496.

D R 22 .

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STPNOC 10B Job Performance Measure REVIEW AN ECO FOR A MAIN TURBINE LUBE OIL COOLER 0B JPM Number: NRC A7 1B Revision Number: 1 2B Date: 07/23/2020 N/A N/A 3B Developed By:

Instructor (Print/Sign) Date N/A N/A 5B Approved By:

Training Supervisor (Print/Sign) Date N/A N/A 7B Approved By:

Line Management (Print/Sign) Date 9B NOTE: N/A signature blocks if this JPM is being used on an NRC LOT Exam.

NRC A7 - rev 1 Revision Record (Summary)

Revision 0, Drafted JPM for use on the LOT 24 NRC exam.

Revision 1; Updated for Final Submittal on the LOT 24 NRC exam.

Page 2 of 9

NRC A7 - rev 1 SIMULATOR SETUP INSTRUCTIONS

1. This is an Admin JPM - No simulator setup instructions required.

Page 3 of 9

NRC A7 - rev 1 INITIAL CONDITIONS Unit 1 is at 100% power.

Main Turbine Lube Oil Cooler #11 had indications of tube blockage and has been removed from service. Main Turbine Lube Oil Cooler #12 was placed in service. An ECO has been prepared for Main Turbine Lube Oil Cooler #11 to control LO System Configuration and isolate Main Turbine Lube Oil Cooler #11 to perform initial venting and draining.

INITIATING CUE As the Unit Supervisor, you are to review the ECO for Main Turbine Lube Oil Cooler #11 based on the ECO request received from Mechanical Maintenance.

NOTE:

The Oracle ECO Database is unavailable.

Review the equipment clearance order in its entirety.

If no errors are found then sign for the Tech Review By and turn in to the examiner.

If errors are found then document all errors prior to turning into the examiner.

Page 4 of 9

NRC A7 - rev 1 Fill in the JPM Start Time when the student acknowledges the Initiating Cue.

Information For Evaluators Use:

UNSAT requires written comments on respective step.

Denotes critical steps.

If Time Critical, estimated time is the Time Critical time.

Number any comments in the Comment Number column on the following pages. Then annotate that comment in the Comments section. The comment section should be used to document: the reason that a step is marked as unsatisfactory, marginal performance relating to management expectations, or problems the examinee had while performing the JPM.

Comments relating to procedural or equipment issues should be entered and tracked using the sites appropriate tracking system.

Some operations that are performed from outside of the control room may require multiple steps. These items may be listed as individual steps in this JPM. It is acceptable for the candidate to direct the local operator to perform groups of procedure steps instead of calling for each individual item to be performed.

The timeclock starts when the candidate acknowledges the initiating cue.

Task Standard:

Reviews an ECO which isolates and drains the Open Loop side of Main Turbine Lube Oil Cooler #11 in accordance with 0PGP03-ZO-EC01A, Equipment Clearance Order Instructions.

Identifies two errors.

1-LT-0049, LO Cooler Transfer Valve, Required Position is correct. The position listed is for LO HX #11. It should be LO HX #12.

1-OC-0092, Turbine LO Cooler 11 Outlet Isolation Valve, is NOT the correct isolation valve.

It should be 1-OC-0029.

JPM Step #3.

Page 5 of 9

NRC A7 - rev 1 JPM Start Time:

Comment STEP ELEMENT STANDARD SAT UNSAT Number NOTE Provide the following Student Handouts:

HO1 - ECO request completed by maintenance

HO2 - Prepared ECO

HO3 - Blank copy of 0PGP03-ZO-ECO1A

HO4 - Blank copy of 0POP02-LT-0001

HO5 - Blank copy of 0POP02-OC-0001

HO6 - Main Turbine Lube Oil P&ID

HO7 - Open Loop Aux Cooling Water P&ID The student should also use Form 10, ECO Technical Reviewer Checklist, but it is not required for this JPM.

1 Reviews Page 1 of Form 3: Reviews the form: ___ ___ ___

ECO Number (1-2020-11111)

Unit 1 (circled)

Hazardous System - NO

Notify Fire Protection - NO

Notify Security - NO

What is being tagged? -

Main Turbine Lube Oil Cooler #11

TPNS - #7T111MHX002A

Work Description - Filled in

Prepared By - Signed

Notes - Marked as Exceptional ECO due to single valve protection to Hazardous Energy.

2 Reviews Page 2 of Form 3: Reviews the form: ___ ___ ___

ECO Number (1-2020-11111)

WAN - 114260

Work Group - MM

Work Description - Filled in Page 6 of 9

NRC A7 - rev 1 Comment STEP ELEMENT STANDARD SAT UNSAT Number

3 Review page 3 of Form 3: Determines ECO has two ___ ___ ___

errors:

ECO Line #1 LT-0049, LO Cooler Transfer Valve, is positioned for LO HX #11. It should be position to LO HX

12.

ECO Line #3 OC-0092 is NOT the correct isolation valve. It should be 1-OC-0029.

NOTE:

See Task Standard and KEY provided.

CUE This JPM is complete JPM Stop Time:

Page 7 of 9

NRC A7 - rev 1 JPM

SUMMARY

Operators Name: Job

Title:

Title:

REVIEW AN ECO FOR A MAIN TURBINE LUBE OIL COOLER JPM Number: NRC A7 Revision Number: 1 Task Number and

Title:

148210 (SRO), Authorize Equipment Clearances K/A Number and Importance: 2.2.13 4.1/4.3 Suggested Testing Environment: Simulator Control Room In-Plant Other Alternate Path: Yes No Task Designed For: SRO Only ; RO/SRO ; AO/RO/SRO Time Critical: Yes No Level of Difficulty: 4 Reference(s): 0PGP03-ZO-ECO1A, Equipment Clearance Order Instructions, Rev. 31; 9F00033#1; 9F20010#1 Actual Testing Environment: Simulator Control Room In-Plant Other Testing Method: Simulate Perform Estimated Time to Complete: 25 minutes Actual Time Used: minutes Critical Steps (*) 3 Evaluation Summary:

Were all the Critical Steps performed satisfactorily? Yes No The operators performance was evaluated against standards contained within this JPM and has been determined to be: Satisfactory Unsatisfactory Comments:

Evaluators Name:

(Print)

Evaluators Signature: Date:

Page 8 of 9

Student Handout INITIAL CONDITIONS Unit 1 is at 100% power.

Main Turbine Lube Oil Cooler #11 had indications of tube blockage and has been removed from service. Main Turbine Lube Oil Cooler #12 was placed in service. An ECO has been prepared for Main Turbine Lube Oil Cooler #11 to control LO System Configuration and isolate Main Turbine Lube Oil Cooler #11 to perform initial venting and draining.

INITIATING CUE As the Unit Supervisor, you are to review the ECO for Main Turbine Lube Oil Cooler #11 based on the ECO request received from Mechanical Maintenance.

NOTE:

The Oracle ECO Database is unavailable.

Review the equipment clearance order in its entirety.

If no errors are found then sign for the Tech Review By and turn in to the examiner.

If errors are found then document all errors prior to turning into the examiner.

Page 9 of 9

STPNOC 11B Job Performance Measure 0B DETERMINE EMERGENCY EXPOSURE LIMITS 1B JPM Number: NRC A8 2B Revision Number: 1 3B Date: 07/13/2020 4B Developed By: N/A Instructor (Print/Sign) Date 6B Approved By: N/A Training Supervisor (Print/Sign) Date 8B Approved By: N/A Line Management (Print/Sign) Date 10B NOTE: N/A signature blocks if this JPM is being used on an NRC LOT Exam.

NRC A8 - rev 1 Revision Record (Summary)

Revision 0, Drafted JPM for use on the LOT 24 NRC exam.

Revision 1; Updated for Final Submittal on the LOT 24 NRC exam.

Page 2 of 8

NRC A8 - rev 1 SIMULATOR SETUP INSTRUCTIONS This is an Admin JPM - No simulator setup instructions required.

Page 3 of 8

NRC A8 - rev 1 INITIAL CONDITIONS Unit 1 is in a Site Area Emergency (SAE) due to an RCS Loss of Coolant Accident (LOCA) and Loss of Containment Integrity.

In an attempt to protect company assets, a Plant Operator will be required to go into a radiation area. The Plant Operator has worked at STP for a short time and previously worked as a radiation worker at another facility during this same calendar year.

INITIATING CUE Determine the MAXIMUM amount of exposure the Plant Operator can be authorized for and the Approval Authority in accordance with 0ERP01-ZV-IN06, Radiological Exposure Guidelines, for the situation given in the INITITIAL CONDITIONS.

The Plant Operators current calendar year radiation exposure is provided.

Provide the following data below to complete the JPM:

The Plant Operators current exposure used to determine Emergency Exposure Approval.

__________ REM TEDE

The MAXIMUM amount of exposure that can be authorized for the specified Plant Operator for the situation given in the INITIAL CONDITIONS.

__________ REM TEDE

MAXIMUM Exposure Limit for the situation given in the INITIAL CONDITIONS.

__________ REM TEDE

Approval Authority for the exposure:

Page 4 of 8

NRC A8 - rev 1 Fill in the JPM Start Time when the student acknowledges the Initiating Cue.

Information For Evaluators Use:

UNSAT requires written comments on respective step.

Denotes critical steps.

If Time Critical, estimated time is the Time Critical time.

Number any comments in the Comment Number column on the following pages. Then annotate that comment in the Comments section. The comment section should be used to document: the reason that a step is marked as unsatisfactory, marginal performance relating to management expectations, or problems the examinee had while performing the JPM.

Comments relating to procedural or equipment issues should be entered and tracked using the sites appropriate tracking system.

Some operations that are performed from outside of the control room may require multiple steps. These items may be listed as individual steps in this JPM. It is acceptable for the candidate to direct the local operator to perform groups of procedure steps instead of calling for each individual item to be performed.

The timeclock starts when the candidate acknowledges the initiating cue.

Task Standard:

Determines the following:

The Plant Operators current exposure used to determine Emergency Exposure Approval.

___0.770___ REM TEDE

The MAXIMUM amount of exposure that can authorize for the specified Plant Operator for the situation given in the INITIAL CONDITIONS.

___9.230___ REM TEDE

MAXIMUM Exposure Limit for the situation given in the INITIAL CONDITIONS.

___10_____ REM TEDE

Approval Authority:

__Emergency Director___

Page 5 of 8

NRC A8 - rev 1 JPM Start Time:

Comment STEP ELEMENT STANDARD SAT UNSAT Number Note Provide Student Handout of Initiating Cue and Student Handouts HO1, HO2 & HO3.

A KEY is not needed with this JPM. See TASK STANDARD below.

1 Determines Emergency Determines the following based ___ ___ ___

Exposure in accordance with on the Initiating Cue:

0ERP01-ZV-IN06, Radiological Exposure Guidelines.

The Plant Operators current exposure used to determine Emergency Exposure Approval. (Add exposure from STP AND Diablo Canyon - 0.050 + 0.720 =

0.770)

___0.770___ REM TEDE

The MAXIMUM amount of exposure that can authorize for the specified Plant Operator for the situation given in the INITIAL CONDITIONS. (Maximum Exposure Limit minus Current Exposure 0.770 = 9.230)

___9.230___ REM TEDE

MAXIMUM Exposure Limit for the situation given in the INITIAL CONDITIONS. (See Add 1 of 0ERP01-ZV-IN06)

___10_____ REM TEDE

Approval Authority:

__Emergency Director__

CUE This JPM is complete JPM Stop Time:

Page 6 of 8

NRC A8 - rev 1 JPM

SUMMARY

Operators Name: Job

Title:

Title:

DETERMINE EMERGENCY EXPOSURE LIMITS JPM Number: A8 Revision Number: 1 Task Number and

Title:

SRO-12800, Activate the Emergency Plan K/A Number and Importance: G2.3.4 3.2/3.7 Suggested Testing Environment: Simulator Control Room In-Plant Other Alternate Path: Yes No Task Designed For: SRO Only RO/SRO AO/RO/SRO Time Critical: Yes No Level of Difficulty: 3 Reference(s): 0ERP01-ZV-IN06, Radiological Exposure Guidelines, Rev 8 Actual Testing Environment: Simulator Control Room In-Plant Other Testing Method: Simulate Perform Estimated Time to Complete: 15 minutes Actual Time Used: minutes Critical Steps (*) 1 Evaluation Summary:

Were all the Critical Steps performed satisfactorily? Yes No The operators performance was evaluated against standards contained within this JPM and has been determined to be: Satisfactory Unsatisfactory Comments:

Evaluators Name:

(Print)

Evaluators Signature: Date:

Page 7 of 8

Student Handout INITIAL CONDITIONS Unit 1 is in a Site Area Emergency (SAE) due to an RCS Loss of Coolant Accident (LOCA) and Loss of Containment Integrity.

In an attempt to protect company assets, a Plant Operator will be required to go into a radiation area. The Plant Operator has worked at STP for a short time and previously worked as a radiation worker at another facility during this same calendar year.

INITIATING CUE Determine the MAXIMUM amount of exposure the Plant Operator can be authorized for and the Approval Authority in accordance with 0ERP01-ZV-IN06, Radiological Exposure Guidelines, for the situation given in the INITITIAL CONDITIONS.

The Plant Operators current calendar year radiation exposure is provided.

Provide the following data below to complete the JPM:

The Plant Operators current exposure used to determine Emergency Exposure Approval.

__________ REM TEDE

The MAXIMUM amount of exposure that can be authorized for the specified Plant Operator for the situation given in the INITIAL CONDITIONS.

__________ REM TEDE

MAXIMUM Exposure Limit for the situation given in the INITIAL CONDITIONS.

__________ REM TEDE

Approval Authority for the exposure:

Page 8 of 8

STPNOC 11B Job Performance Measure 0B DECLARE EMERGENCY ACTION LEVELS 1B JPM Number: NRC A9 2B Revision Number: 1 3B Date: 07/13/2020 N/A N/A 4B Developed By:

Instructor (Print/Sign) Date N/A N/A 6B Approved By:

Training Supervisor (Print/Sign) Date 8B Approved By: N/A N/A Line Management (Print/Sign) Date 10B NOTE: N/A signature blocks if this JPM is being used on an NRC LOT Exam.

NRC A9 - rev 1 Revision Record (Summary)

Revision 0; Drafted JPM for use on the LOT 24 NRC exam.

Revision 1; Updated for Final Submittal on the LOT 24 NRC exam.

Page 2 of 7

NRC A9 - rev 1 SIMULATOR SETUP INSTRUCTIONS

1. This is an Admin JPM.

JPM Administration:

1. Setup an area with a copy of the following references:

0ERP01-ZV-SH01, Shift Manager, with an extra copy of Checklists 1 - 4

0ERP01-ZV-IN01, Emergency Classification

Laminated Emergency Classification Charts (Fission Product Barriers, Hot Modes, All Modes, and Cold Modes)

2. Check and clean the laminated charts.

3. Inform the student this JPM is time critical.

4. Read the cue to the student and fill in the JPM Start Time when the student acknowledges the Initiating Cue.

Page 3 of 7

NRC A9 - rev 1 INITIAL CONDITIONS Both Units are at 100% power.

A tornado touched down in the Oily Waste Area causing minor structural damage. The tornado then damaged the ECW Intake Structure. The Unit 1 B train watertight door was physically separated from the building and is lying next to the ECW Intake Structure.

INITIATING CUE You are the Emergency Director and you are to classify the event at its MINIMUM Emergency Classification Level including the corresponding Initiating Condition and specific Emergency Action Level (EAL).

THIS JPM IS TIME CRITICAL.

Fill in the JPM Start Time when the student acknowledges the Initiating Cue.

Information For Evaluators Use:

UNSAT requires written comments on respective step.

Denotes critical steps.

If Time Critical, estimated time is the Time Critical time.

Number any comments in the Comment Number column on the following pages. Then annotate that comment in the Comments section. The comment section should be used to document: the reason that a step is marked as unsatisfactory, marginal performance relating to management expectations, or problems the examinee had while performing the JPM.

Comments relating to procedural or equipment issues should be entered and tracked using the sites appropriate tracking system.

Some operations that are performed from outside of the control room may require multiple steps. These items may be listed as individual steps in this JPM. It is acceptable for the candidate to direct the local operator to perform groups of procedure steps instead of calling for each individual item to be performed.

The timeclock starts when the candidate acknowledges the initiating cue.

Task Standard:

An ALERT (Emergency Classification) is declared on SA9 (Initiating Condition) EAL1 - a AND b.2 (specific EAL). Also see KEY provided.

Page 4 of 7

NRC A9 - rev 1 JPM Start Time:

Comment STEP ELEMENT STANDARD SAT UNSAT Number NOTE Use a binder, if available, for the Student Handouts for this JPM.

Provide a copy of 0ERP01-ZV-IN01, Emergency Classification, and/or laminated copies of the Emergency Classification Charts from Addendum 4, 5, 6 and 7.

The ALERT classification is based on SA9 EAL1 - a AND b2 (Hazardous event affecting a SAFETY SYSTEM needed for the current operating mode. The event has caused VISIBLE DAMAGE to a SAFETY SYSTEM component or structure needed for the current operating mode.)

1 Classify the event in Classifies the event at the ___ ___ ___

accordance with Addendum 1 in MINIMUM Emergency 0ERP01-ZV-IN01. Classification Level including the corresponding Initiating Condition and specific Emergency Action Level (EAL).

ALERT based on SA9 EAL1 - a AND b.2 Time Critical Stop Time _____

2 Implement 0ERP01-ZV-SH01, 0ERP01-ZV-SH01, Shift ___ ___ ___

Shift Manager. Manager, is implemented.

CUE This JPM is complete (Must be completed within 15 minutes.)

JPM Stop Time:

Page 5 of 7

NRC A9 - rev 1 JPM

SUMMARY

Operators Name: Job

Title:

Title:

DECLARE EMERGENCY ACTION LEVELS JPM Number: A9 Revision Number: 1 Task Number and

Title:

SRO-12800, Activate the Emergency Plan K/A Number and Importance: G2.4.41 2.9/4.6 Suggested Testing Environment: Simulator Control Room In-Plant Other Alternate Path: Yes No Task Designed For: SRO Only RO/SRO AO/RO/SRO Time Critical: Yes No Level of Difficulty: 4 Reference(s): 0ERP01-ZV-IN01, Emergency Classification, Rev. 10 0ERP01-ZV-SH01, Shift Manager, Rev. 32 Actual Testing Environment: Simulator Control Room In-Plant Other Testing Method: Simulate Perform Estimated Time to Complete: 15 minutes Actual Time Used: minutes Critical Steps (*) 1 Evaluation Summary:

Were all the Critical Steps performed satisfactorily? Yes No The operators performance was evaluated against standards contained within this JPM and has been determined to be: Satisfactory Unsatisfactory Comments:

Evaluators Name:

(Print)

Evaluators Signature: Date:

Page 6 of 7

Student Handout INITIAL CONDITIONS Both Units are at 100% power.

A tornado touched down in the Oily Waste Area causing minor structural damage. The tornado then damaged the ECW Intake Structure. The Unit 1 B train watertight door was physically separated from the building and is lying next to the ECW Intake Structure.

INITIATING CUE You are the Emergency Director and you are to classify the event at its MINIMUM Emergency Classification Level including the corresponding Initiating Condition and specific Emergency Action Level (EAL).

THIS JPM IS TIME CRITICAL.

Record MINIMUM Emergency Classification Level including the corresponding Initiating Condition and specific EAL below:

Emergency Classification Level ______________________________

Initiating Condition ___________

Specific EAL ______________________

Page 7 of 7

0ERP01-ZV-IN01 Rev. 10 Page 67 of 179 Emergency Classification Addendum 1 Emergency Classification Tables Page 53 of 159 ALERT Initiating Condition Hazardous event affecting a SAFETY SYSTEM needed for the current operating mode.

SA9 Emergency Action Levels (1) Operating Mode Applicability: 1,2,3,4 Notes:

None EAL-1

a. The occurrence of ANY of the following hazardous events listed in Table S3:

Table S3: Hazardous Events Seismic event (earthquake)

Internal or external flooding event High winds or tornado strike FIRE EXPLOSION Predicted or actual breach of Main Cooling Reservoir retaining dike along North Wall.

Other events with similar hazard characteristics as determined by the Shift Manager AND

b. EITHER of the following:

1. Event damage has caused indications of degraded performance in at least one train of a SAFETY SYSTEM needed for the current operating mode.

OR

2. The event has caused VISIBLE DAMAGE to a SAFETY SYSTEM component or structure needed for KEY the current operating mode.

0ERP01-ZV-IN01 Rev. 10 Page 68 of 179 Emergency Classification Addendum 1 Emergency Classification Tables Page 54 of 159 Basis:

This IC addresses a hazardous event that causes damage to a SAFETY SYSTEM, or a structure containing SAFETY SYSTEM components, needed for the current operating mode. This SA9 B condition significantly reduces the margin to a loss or potential loss of a fission product barrier, and therefore represents an actual or potential substantial degradation of the level of safety of the plant.

EAL# 1.b.1- addresses damage to a SAFETY SYSTEM train that is in service/operation since indications for it will be readily available. The indications of degraded performance should be significant enough to cause concern regarding the operability or reliability of the SAFETY SYSTEM train.

EAL# 1.b.2- addresses damage to a SAFETY SYSTEM component that is not in service/operation or readily apparent through indications alone, or to a structure containing SAFETY SYSTEM components.

Operators will make this determination based on the totality of available event and damage report information.

This is intended to be a brief assessment not requiring lengthy analysis or quantification of the damage.

Escalation of the EMERGENCY CLASSIFICATION LEVEL would be via IC FS1 or RS1.

EAL SELECTION BASES The listed hazards are from NEI 99-01 Rev.6 with the exception of the Main Cooling Reservoir breach along the north wall which was included because it is a credible hazard and analyzed in the STPEGS UFSAR.

KEY

0ERP01-ZV-IN01 Rev. 10 Page 177 of 179 Emergency Classification Addendum 5 Hot Modes Chart Page 1 of 1 KEY

Rev. 2 ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: South Texas Project Date of Examination: 7-13-20 Exam Level: RO SRO-I SRO-U Operating Test No.: LOT 24 NRC Control Room Systems:* 8 for RO, 7 for SRO-I, and 2 or 3 for SRO-U Safety System / JPM Title Type Code*

Function

a. (S1) Recover a Mis-Aligned Control Rod KA: 001 A4.06 (2.9/3.2) M,S 1

b. (S2) Manually Load an ESF Bus KA: 064 A4.06 (3.9/3.9) A,E,EN,M,S 6

c. (S3) Depress RCS during SGTR KA: 010 A2.02 (3.9/3.9) A,D,E,L,S 3

d. (S4) Loss of Circulating Water Pump KA: 075 A2.02 (2.5/2.7) A,N,S 8

e. (S5) Containment Spray Pump Performance Test KA: 026 M,S 5 A2.08 (3.2/3.7)

f. (S6) Transfer MFW Control from LPFRV to MFRV KA: 059 D,S 4S A4.08 (3.0/2.9)

g. (S7) Respond to RCB Rad Monitor Alarm KA: 073 A4.01 A,D,S 7 (3.9/3.9)

h. (S8) Lower SI Accumulator Level KA: 006 A1.13 (3.5/3.7) D,EN,S 2 In-Plant Systems:* 3 for RO, 3 for SRO-I, and 3 or 2 for SRO-U

i. (P1) MCC Power Restoration per 0POP04-ZO-0001 KA: 062 E,L,N 6 A4.04 (2.6/2.7)

j. (P2) Place RWST on Recirc followed by an SI KA: 006 A4.02 A,D,R 2 (4.0/3.8)

k. (P3) Verify Containment Isolation Phase B KA: 103 A2.03 D,E,L,R 5 (3.5/3.8)

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, and 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 (C)ontrol Room (D)irect from Bank 9/ 8/4 (E)mergency or abnormal in-plant 1/ 1/1 (EN) gineered Safety Features 1/ 1 / 1 (control room system)

(L)ow-Power / Shutdown 1/ 1/1 (N)ew or (M)odified from bank including 1(A) 2/ 2/1 (P)revious 2 exams 3/ 3 / 2 (randomly selected)

(R)CA 1/ 1/1 (S)imulator Page 1 of 5

Rev. 2 ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: South Texas Project Date of Examination: 7-13-20 Exam Level: RO SRO-I SRO-U Operating Test No.: LOT 24 NRC Control Room Systems:* 8 for RO, 7 for SRO-I, and 2 or 3 for SRO-U Safety System / JPM Title Type Code*

Function

a. (S1) Recover a Mis-Aligned Control Rod KA: 001 A4.06 (2.9/3.2) M,S 1

b. (S2) Manually Load an ESF Bus KA: 064 A4.06 (3.9/3.9) A,E,EN,M,S 6

c. (S3) Depress RCS during SGTR KA: 010 A2.02 (3.9/3.9) A,D,E,L,S 3

d. (S4) Loss of Circulating Water Pump KA: 075 A2.02 (2.5/2.7) A,N,S 8

e. (S5) Containment Spray Pump Performance Test KA: 026 M,S 5 A2.08 (3.2/3.7)

f. (S6) Transfer MFW Control from LPFRV to MFRV KA: 059 D,S 4S A4.08 (3.0/2.9)

g. (S7) Respond to RCB Rad Monitor Alarm KA: 073 A4.01 A,D,S 7 (3.9/3.9) h.

In-Plant Systems:* 3 for RO, 3 for SRO-I, and 3 or 2 for SRO-U

i. (P1) MCC Power Restoration per 0POP04-ZO-0001 KA: 062 E,L,N 6 A4.04 (2.6/2.7)

j. (P2) Place RWST on Recirc followed by an SI KA: 006 A4.02 A,D,R 2 (4.0/3.8)

k. (P3) Verify Containment Isolation Phase B KA: 103 A2.03 D,E,L,R 5 (3.5/3.8)

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, and 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 (C)ontrol Room (D)irect from Bank 9/ 8/4 (E)mergency or abnormal in-plant 1/ 1/1 (EN) gineered Safety Features 1/ 1 / 1 (control room system)

(L)ow-Power / Shutdown 1/ 1/1 (N)ew or (M)odified from bank including 1(A) 2/ 2/1 (P)revious 2 exams 3/ 3 / 2 (randomly selected)

(R)CA 1/ 1/1 (S)imulator Page 2 of 5

Rev. 2 ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: South Texas Project Date of Examination: 7-13-20 Exam Level: RO SRO-I SRO-U Operating Test No.: LOT 24 NRC Control Room Systems:* 8 for RO, 7 for SRO-I, and 2 or 3 for SRO-U Safety System / JPM Title Type Code*

Function

a. (S1) Recover a Mis-Aligned Control Rod KA: 001 A4.06 (2.9/3.2) M,S 1

b. (S2) Manually Load an ESF Bus KA: 064 A4.06 (3.9/3.9) A,E,EN,M,S 6

c. (S3) Depress RCS during SGTR KA: 010 A2.02 (3.9/3.9) A,D,E,L,S 3 d.

e.

f.

g.

h.

In-Plant Systems:* 3 for RO, 3 for SRO-I, and 3 or 2 for SRO-U i.

j. (P2) Place RWST on Recirc followed by an SI KA: 006 A4.02 A,D,R 2 (4.0/3.8)

k. (P3) Verify Containment Isolation Phase B KA: 103 A2.03 D,E,L,R 5 (3.5/3.8)

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, and 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 (C)ontrol Room (D)irect from Bank 9/ 8/4 (E)mergency or abnormal in-plant 1/ 1/1 (EN) gineered Safety Features 1/ 1 / 1 (control room system)

(L)ow-Power / Shutdown 1/ 1/1 (N)ew or (M)odified from bank including 1(A) 2/ 2/1 (P)revious 2 exams 3/ 3 / 2 (randomly selected)

(R)CA 1/ 1/1 (S)imulator Page 3 of 5

Rev. 2 STP LOT-24 NRC Systems JPM Description Control Room Systems JPMs (S1) Recover a Mis-Aligned Control Rod Demonstrate the ability to control reactor core reactivity while recovering a mis-aligned control rod in accordance with 0POP04-RS-0001, Control Rod Malfunction.

(S2) Manually Load an ESF Bus Demonstrate the ability to ensure equipment has properly loaded on to an ESF 4.16KV Bus in accordance with 0POP04-AE-0001, First Response to Loss of any or all 13.8KV or 4.16KV Bus. This is an Alternate Path JPM.

(S3) Depress RCS During SGTR Demonstrate the ability to depress the RCS after a SGTR in accordance with 0POP05-EO-EO30, Steam Generator Tube Rupture. This is an Alternate Path JPM.

(S4) Loss of Circulating Water Pump Demonstrate the ability to operate the Circulating Water System after a trip of a Circulating Water Pump in accordance with 0POP04-CW-0001, Loss of Circulating Water Flow. This is an Alternate Path JPM.

(S5) Containment Spray Pump Performance Test Demonstrate the ability to operate the Containment Spray Pumps in accordance with 0POP07-CS-0001, Containment Spray Pump 1A(2A) Functional Test.

(S6) Transfer MFW Control from LPFRV to MFRV Demonstrate the ability to operate Main Feedwater control valves in accordance with 0POP03-ZG-0005, Plant Startup to 100%.

(S7) Respond to RCB Rad Monitor Alarm Demonstrate the ability to operate the RCB Supplemental Purge System after a Radiation Monitor high alarm in accordance with 0POP04-RA-0001, Radiation Monitoring System Alarm Response. This is an Alternate Path JPM.

(S8) Lower Safety Injection Accumulator Level Demonstrate the ability lower Safety Injection Accumulator level in accordance with 0POP02-SI-0001, Safety Injection Accumulators.

NOTE: All Control Room JPMs will be performed dynamically in the Simulator. JPMs will be performed in pairs; S1 & S2 together, S3 & S7 together, S5 & S6 together and S4 & S8 together.

Page 4 of 5

Rev. 2 STP LOT-24 NRC Systems JPM Description In Plant Systems JPMs (P1) MCC Power Restoration per 0POP04-ZO-0001, Control Room Evacuation Demonstrate the ability to restore power to vital MCCs after a control room evacuation in accordance with 0POP04-ZO-0001, Control Room Evacuation.

(P2) Place RWST on Recirc followed by an Safety Injection Demonstrate the ability to monitor the Safety Injection System alignments in order to prevent equipment damage in accordance with 0POP02-FC-0001, Spent Fool Pool Cooling and Cleanup System. This is an Alternate Path JPM.

(P3) Verify Containment Isolation Phase B Demonstrate the ability to locally close Component Cooling Water valves associated with Containment Isolation Phase B in accordance with 0POP05-EO-EC00, Loss of all AC Power.

Page 5 of 5

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 1 of 38 LOT 24 NRC EXAM SIMULATOR OPERATING TEST SCENARIO #1 Revision 1 Week of 07/13/2020

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 2 of 38 SCENARIO OUTLINE Facility: South Texas Project Scenario No.: 1 Op-Test No.: LOT 24 NRC Examiners: Operators:

Initial Conditions: Critical Tasks:

Mode 1 at 100% Power, MOL

E6 - CT13; Manually Trip Main Turbine

25-30 & 120-150 GPM Letdown Orifices are

E7 - CT46; Establish RCS Bleed and Feed in service.

Turnover:

AFW Pump #11 is out of service.

Event Malf. Event Event No. No. Type* Description 1 RO (N)

(0 min) N/A Close the 25-30 GPM Letdown Orifice.

2 CM_RT804 SRO (TS (10 min) 6TVCLRP ONLY) SG 1A Main Steam Radiation Monitor RT-8046 failure.

1 3 04-03-02 (20 min) RO (C) RCP 1B Thermal Barrier Isolation Valve goes closed after a CCW 0 SRO (C) System perturbation.

05-12-04 4 0 BOP (I) SG 1D Controlling NR level channel fails low. LT-0549 (33 min) SRO (I & TS) 5 08-28-01 (43 min) BOP (C) LPHD Pump #11 Trip True SRO (C) 6 Multiple Main Generator Output Breaker trips open causing an automatic or (52 min) All (M) manual RX Trip.

7 Multiple On the RX Trip the Main Turbine fails to auto trip and there is an (N/A) RO (C)

SRO (C) inadvertent FWI.

(Critical Task) 8 10-11-02 (N/A) RO (C) Train B 4160V bus lockout. (On Reactor Trip)

True SRO (C) 9 Multiple Loss of Heat Sink and entry into FRH1.

(N/A) All (M)

(Critical Task)

(AFW Pump 11 OOS, Pump 12 No Power, Pump 13 Trips, Pump 14 overspeeds.)

10 08-02-01 AFW Pump 14 has an overspeed trip.

(N/A) BOP (C) 1 SRO (C) 11 08-03-06 AFW Pump 13 trips on overcurrent.

(N/A) BOP (C) 1 SRO (C)

Lot* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS) Technical Specification Total Estimated Time: 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , 10 minutes

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 3 of 38 Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Malfunctions after EOP entry (1-2) 3

2. Abnormal events (2-4) 4

3. Major transients (1-2) 2

4. EOPs entered/requiring substantive actions (1-2) 1

5. Entry into a contingency EOP with substantive actions (>1 per scenario 1 set)

6. Preidentified critical tasks (>2) 2 SCENARIO MISCELLANEOUS INFORMATION INSTRUCTOR NOTES:

Critical Tasks are indicated by "CT-##" in the position column and indicated in bold type. In some instances, an

will indicate that only a portion of the task listed is considered critical.

Shaded cells indicate procedural entry points.

RECORDED PARAMETERS:

Recorded parameters will be determined during NRC Validation week.

The parameters identified for recording may be of value in evaluating crew performance. Once the scenario is complete for each crew, printout the recorded parameters and label the printout with date, time, crew number and scenario number.

See Scenario Instructions section for further details on how to save the Recorded Parameters.

Core Exit T/C

Pressurizer Level

SG 1D Narrow Range Level

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 4 of 38 SCENARIO OBJECTIVES Event 1 Objective

Operate alternate Charging and Letdown flowpaths per 0POP02-CV-0004, Chemical Volume Control System Subsystem.

Event 2 Objective

Respond to Radiation System Monitoring alarms per 0POP04-RA-0001, Radiation Monitoring System Alarm Response.

Event 3 Objective

Respond to a Reactor Coolant Pump abnormal condition per 0POP04-RC-0002, Reactor Coolant Pump Off Normal.

Event 4 Objective

Respond to a loss of feedwater flow or control per 0POP04-FW-0001, Loss of Steam Generator Level Control.

Event 5 Objective

Respond to feedwater heater vent and drip alarms per 0POP04-CD-0001, Loss of Condensate Flow.

Event 6 and 7 Objective

Respond to a Main Turbine and Reactor Trip per 0POP05-EO-EO00, Reactor Trip or Safety Injection.

Event 8 Objective

Respond to a loss of power to a 4.16KV ESF Bus during a reactor trip per 0POP04-AE-0001, First Response to Loss of Any or All 13.8KV of 4.16KV Bus.

Event 9, 10 and 11 Objective

Respond to Loss of Heat Sink per 0POP05-EO-FRH1, Response to Loss of Secondary Heat Sink.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 5 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 1 Event

Description:

Close the 25-30 GPM Letdown Orifice.

Time Position Required Operator Actions Notes SRO Directs Operator to perform 0POP02-CV-0004, Chemical and Volume Control System Subsystem, Section 10.0, Removing a Second or Third Letdown Orifice from Service with the RCS Pressurized.

RO NOTIFY Health Physics of pending changes in the letdown or charging flow paths to ensure they can survey the area that has changed.

(Step 10.1)

RO ENSURE demineralizers bypassed per Section 7.0.

(Step 10.2)

RO NOTIFY Health Physics of pending changes in the letdown or charging flow paths to ensure they can survey the area that has changed.

(Step 7.1)

RO ENSURE DIVERT TCV-0143 in the VCT position to bypass the CVCS Demineralizers.

(Step 7.2)

RO NOTIFY Chemistry that the CVCS Demineralizers are bypassed.

(Step 7.3)

RO will go back to step 10.3.

RO PLACE PRESS CONT PCV-0135 in MAN.

(Step 10.3)

RO ADJUST PRESS CONT PCV-0135 to obtain a letdown pressure of 400 psig as indicated on OUTLET PRESS PI-0135.

(Step 10.4)

During this evolution a procedure NOTE instructs the Operator to monitor letdown pressure to ensure PSV-3100 LETDOWN LINE RELIEF TO PRT does not lift. (600 psig)

The Operator may also have to adjust CHG FLOW CONT FK-0205 for PZR level control.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 6 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 1 Event

Description:

Close the 25-30 GPM Letdown Orifice.

Time Position Required Operator Actions Notes RO CLOSE the appropriate letdown orifice isolation valve.

25-30 GPM MOV-0014 ORIF ISOL VLV (Step 10.5)

RO WHEN the letdown orifice isolation valve is full closed, THEN ADJUST PRESS CONT PCV-0135 to obtain a letdown pressure between 350 psig and 380 psig as indicated on OUTLET PRESS PI-0135.

(Step 10.6)

RO PLACE PRESS CONT PCV-0135 in AUTO.

(Step 10.7)

(Event 2 can be triggered on request from the lead examiner.)

RO ENSURE demineralizers in service per Section 7.0, as desired.

(Step 10.7)

The Operator will go to step 7.4.1 to place CVCS demineralizers back in service.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 7 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 1 Event

Description:

Close the 25-30 GPM Letdown Orifice.

Time Position Required Operator Actions Notes RO ENSURE the CVCS Demineralizer meets ALL of the following conditions, OTHERWISE N/A this step and PLACE the CVCS Demineralizer in service per the applicable Sections:

CVCS Bed Demineralizer has been previously flushed and sampled.

(Modes 1, 2, 3 and 4 ONLY) CVCS Bed Demineralizer has been isolated for less than 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

Current RCS Boron within + 25 ppm from the RCS Boron WHEN the CVCS Bed Demineralizer was last in service (Boron Meter or samples).

IF the current RCS Boron is less than or equal to 25 ppm, THEN the effluent of the CVCS Bed Demineralizer [WHEN it was last in service (Boron Meter or samples)] is less than or equal to the current RCS Boron concentration.

(Step 7.4.1)

The Operator will continue with step 7.4.2 as ALL of the conditions are met for the CVCS demineralizer being placed back in service.

RO ENSURE that the demineralizer being restored to service is the same demineralizer that was in service at the time it was bypassed, OTHERWISE PLACE the demineralizer in service per Section 34.0, 37.0, 39.0, or 63.0as appropriate.

(Step 7.4.2)

RO PLACE DIVERT TCV-0143 in the DEMIN position.

(Step 7.4.2)

RO NOTIFY Chemistry that the CVCS Demineralizers are in service.

(Step 7.4.2)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 8 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 2 (Examiner Trigger)

Event

Description:

SG 1A Main Steam Radiation Monitor RT-8046 failure.

Time Position Required Operator Actions Notes BOP Acknowledges RM-11 alarm.

SRO Determines RM-11 alarm is a High Alarm on RT-BOP 8046, SG 1A Main Steam Radiation Monitor.

SRO Directs actions of 0POP04-RA-0001, Radiation Monitor System Alarm Response.

NOTE: Steps 1 to 6 of 0POP04-RA-0001, Radiation Monitor System Alarm Response, can be performed as Skill of the Craft per Conduct of Operations, Chapter 2.

BOP Uses 0POP04-RA-0001, Radiation Monitor System Alarm Response, Addendum 19, to respond to the high alarm indicated for RT-8046.

BOP CHECK ALERT Or HIGH Alarm Exists On One Or More Of The Following Radiation Monitors:

RT-8046

RT-8047

RT-8048

RT-8049 (ADD 19, Step 1)

BOP CHECK For Increased Readings On The Following Radiation Monitors:

RT-8010B

RT-8022

RT-8023

RT-8024

RT-8025

RT-8027

RT-8043

RT8130A

RT-8131A

RT-8132A

RT-8133A (ADD 19, Step 2)

Increased readings on these radiation monitors would validate a high reading on RT-8046.

However, they are all reading normal and the Operator will go to the RNO for step 2.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 9 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 2 (Examiner Trigger)

Event

Description:

SG 1A Main Steam Radiation Monitor RT-8046 failure.

Time Position Required Operator Actions Notes SRO PERFORM the following:

IF RT-8027 is secured, THEN EVALUATE if chemistry should place RT-8027 inservice.

CONFIRM alarm condition by sample analysis.

IF sample analysis confirms the alarm condition is valid, THEN GO TO Step 3.0 of this Addendum.

IF sample analysis confirms the alarm condition is invalid, THEN GO TO procedure and step in effect.

(ADD 19, Step 2 RNO)

The Operator will determine that no confirmation exists to validate the alarm on RT-8046 is valid.

The SRO will declare RT-8046 INOPERABLE and enter TS 3.3.3.6. See TS details below.

(Event 3 can be triggered after SRO has announce TSs or on request from the lead examiner.)

TS 3.3.3.6, Function 16, Action 40a With the number of OPERABLE channels less than the Minimum Channels OPERABLE requirements and with a functional diverse channel, restore at least one inoperable channel to OPERABLE status within 30 days, or submit a Special Report within the next 14 days outlining the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the inoperable instrumentation channels to OPERABLE status.

NOTE: SG 1A Blowdown Radiation Monitor, RT-8022, is a functional diverse channel.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 10 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 3 (Examiner Trigger)

Event

Description:

RCP 1B Thermal Barrier Isolation Valve goes closed after a CCW System perturbation.

Time Position Required Operator Actions Notes RO Acknowledges and announces the following annunciators from 04M7 & 02M3:

04M7 - RCP 1B THERM BAR CCW FLOW/TEMP/TRBL (D-4)

02M3 - CCW HX 1A OUTL FLOW HI/LO (C-5)

NOTE: The CCW perturbation is caused by Train A RHR HX, CC-FV-4531 failing open. This will cause CCW Pump 1C to start on system low pressure. The crew will look at associated ARPs for this part of the event but no actions will be taken including TSs because CC-FV-4531 fails in the required ESF position. The CCW alignment would have to remain as is until repairs could be made to CC-FV-4531.

SRO/RO Determines CCW THERM BAR ISOL MOV-0374 has closed.

SRO Directs actions of 0POP09-AN-04M7 - D4, RCP 1B THERM BAR CCW FLOW/TEMP/TRBL RO CHECK the following RCP 1B thermal barrier Plant Computer Points:

FD4625, RCP 1B THERM BAR CCW DISCH FLOW (flow greater than 60 gpm)

FD4626, RCP 1B THERM BAR CCW DISCH FLOW (flow less than 30 gpm)

TD4626, RCP 1B THERM BAR CCW DISCH TEMP (temperature greater than 187°F)

T0182, RCP 1B SEAL 1 WTR INLET TEMP (temperature less than 230°F)

(Step 1)

RO IF RCP 1B thermal barrier CCW flow is high (greater than 60 gpm) OR thermal barrier CCW discharge temperature is high (greater than 187°F), THEN ENSURE CCW THERM BAR ISOL MOV-0374 closed.

(Step 2)

NOTE: CC-MOV-0374 is already closed.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 11 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 3 (Examiner Trigger)

Event

Description:

RCP 1B Thermal Barrier Isolation Valve goes closed after a CCW System perturbation.

Time Position Required Operator Actions Notes RO IF CCW THERM BAR ISOL MOV-0374 closed due to CCW flow perturbations as determined by the Shift Manager/Unit Supervisor, THEN GO TO 0POP04-RC-0002, Reactor Coolant Pump Off Normal, Addendum 1, Establishing Normal RCP Seal Cooling.

(Step 3)

NOTE: The US should make the decision to go to 0POP04-RC-0002, Reactor Coolant Pump Off Normal, Addendum 1, Establishing Normal RCP Seal Cooling.

SRO Directs actions of 0POP04-RC-0002, Reactor Coolant Pump Off Normal, Addendum 1, Establishing Normal RCP Seal Cooling.

RO CHECK RCP Seal Cooling - ANY SOURCE SUPPLYING COOLING FLOW

RCP thermal barrier CCW flow OR

RCP seal injection flow (Add 1, Step 1)

RO CHECK RCP Seal 1 Inlet Temperatures On Plant Computer Display RC-010 or RC-011 - ALL LESS THAN 230°F

T0181 RCP 1A

T0182 RCP 1B

T0183 RCP 1C

T0184 RCP 1D (Add 1, Step 2)

RO CHECK RCP Thermal Barrier CCW Flow - LOST (Add 1, Step 3)

NOTE: Flow is lost for RCP 1B RO CHECK CCW Pumps - AT LEAST ONE RUNNING (Add 1, Step 4)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 12 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 3 (Examiner Trigger)

Event

Description:

RCP 1B Thermal Barrier Isolation Valve goes closed after a CCW System perturbation.

Time Position Required Operator Actions Notes RO CHECK Running CCW Pump Common Header Supply And Return Valves - OPEN (Add 1, Step 5)

RO CHECK CCW To RCP Inlet And Outlet Thermal Barrier Containment Isolation Valves - OPEN

"INL OCIV MOV-0318"

"INL OCIV MOV-0291"

"OUTL ICIV MOV-0542"

"OUTL ICIV MOV-0403"

"OUTL OCIV MOV-0404"

"OUTL OCIV FV-4493" (Add 1, Step 6)

RO CHECK RCP Thermal Barrier CCW Outlet Valves

- OPEN

RCP 1B(2B) "CCW THERM BAR ISOL MOV-0374" (Add 1, Step 7)

RO OPEN RCP thermal barrier CCW outlet valves for RCP(s) WITH seal 1 inlet temperatures LESS THAN 230°F.

RCP 1B(2B) "CCW THERM BAR ISOL MOV-0374" (Add 1, Step 7 RNO)

RO CHECK RCP Seal Injection Flow - LOST (Add 1, Step 8)

RO RETURN TO Procedure step in effect.

(Add 1, Step 8 RNO)

(Event 4 can be triggered on request from the lead examiner.)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 13 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 4 (Examiner Trigger)

Event

Description:

SG 1D Controlling NR level channel fails low. LT-0549 Time Position Required Operator Actions Notes BOP Acknowledges and announces the following annunciators on 06M4:

SG 1D LVL DEV HI/LO (B6)

SG 1D LVL LO-LO ALERT (D-6)

NOTE: If the crew is slow to diagnose this condition, then alarms will come in on SG 1D with the rising SG level.

SRO Determines SG 1D Controlling Narrow Range BOP Channel LT-0549 is failed low. Performs immediate actions of 0POP04-FW-0001, Loss of Steam Generator Level Control:

PLACE any SG Feedwater Regulating Valve(s) not properly responding in MANUAL AND ADJUST as necessary to restore affected SG NR level(s) to between 68% and 74%.

SRO Enters 0POP04-FW-0001, Loss of Steam Generator Level Control.

BOP CHECK SG Feedwater Regulating Valve(s) -

RESPONDING IN AUTOMATIC (See previous immediate action step)

(Step 1, an immediate action step.)

BOP CHECK SGFP Speed Controllers -

RESPONDING IN AUTOMATIC (Step 2, an immediate action step, however, SGFP speed control in automatic is not affected.)

BOP CHECK Main Feedwater Regulating Valves:

CHECK Main Feedwater Regulating Valve(s) -

IN SERVICE

SG 1A "NORM FCV-0551"

SG 1B "NORM FCV-0552"

SG 1C "NORM FCV-0553"

SG 1D "NORM FCV-0554"

CHECK Main Feedwater Regulating Valve(s) -

ANY IN MANUAL

CHECK Affected Main Feedwater Regulating Valve(s) - RESPONDING IN MANUAL (Step 3)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 14 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 4 (Examiner Trigger)

Event

Description:

SG 1D Controlling NR level channel fails low. LT-0549 Time Position Required Operator Actions Notes BOP CHECK Low Power Feedwater Regulating Valves:

CHECK Low Power Feedwater Regulating Valve(s) - IN SERVICE RNO GO TO Step 5.0.

(Step 4)

BOP CHECK SGFP Master Speed Controller - IN MANUAL RNO GO TO Step 7.0.

(Step 5)

BOP CHECK Individual SGFP Speed Controllers -

ANY IN MANUAL RNO GO TO Step 9.0.

(Step 7)

BOP MONITOR Feedwater/Steam Header DP -

GREATER THAN OR EQUAL TO DP REQUIRED BY Addendum 1 OR

SGFP Master Speed Controller At 100%

Demand In Auto (Step 9)

BOP RESTORE Affected SG NR Level(s) To Between 68% And 74%

(Step 10)

BOP MONITOR SG NR Levels - GREATER THAN 20%

(Step 11)

BOP MONITOR SG NR Levels - LESS THAN 87.5%

(Step 12)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 15 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 4 (Examiner Trigger)

Event

Description:

SG 1D Controlling NR level channel fails low. LT-0549 Time Position Required Operator Actions Notes BOP CHECK SG NR Level Indicators - ALL OPERABLE RNO PERFORM the following:

SELECT the operable SG level channel for affected SG(s) level control. LT-0574

CHECK status of "QDPS ALARM SGWLCS" Annunciator Lampbox 6M03, Window A-8.

IF Annunciator Lampbox 6M03, Window A-8 is illuminated, THEN DETERMINE the alarming channels(s) using the QDPS DETAIL DATA Menu, Page 5 display.

(Step 13)

NOTE: SG 1D NR Level Indicator LT-0549 is failed low.

BOP CHECK Feedwater Flow Transmitters - ALL OPERABLE (Step 14)

BOP CHECK Steam Flow Transmitters - ALL OPERABLE (Step 15)

BOP CHECK Steam Pressure Transmitters - ALL OPERABLE (Step 16)

BOP CHECK SG NR Levels - BETWEEN 68% And 74%

(Step 17)

BOP CHECK Main Feedwater Regulating And Low Power Feedwater Regulating Valves Automatic Control - OPERABLE (Step 18)

NOTE: Automatic control has not been affected.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 16 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 4 (Examiner Trigger)

Event

Description:

SG 1D Controlling NR level channel fails low. LT-0549 Time Position Required Operator Actions Notes BOP CHECK Main Feedwater Regulating OR Low Power Feedwater Regulating Valve(s) - IN AUTO

SG 1D "NORM FCV-0554" RNO WHEN SG levels return to between 68% and 74%, THEN PERFORM the following:

PLACE in-service Feedwater Regulating Valve(s) with operable Automatic Control in Auto.

MONITOR proper operation of Feedwater Regulating Valve(s) in Auto.

(Step 19)

BOP CHECK SGFP Master Speed Controller - IN AUTO (Step 20)

SRO TAKE Appropriate Actions Per Technical Specifications 3.3.1, 3.3.2, 3.3.3.6 and TRM 3.7.1.7 (Step 21)

See TS details below.

TS 3.3.1, Function 14, Action 6; and TS 3.3.2, Function 5.b, Action 20 and 3.3.2, Function 6.d, Action 20 With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. For Functional Units with installed bypass test capability, the inoperable channel may be placed in bypass, and must be placed in the tripped condition within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

Note: A channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing per Specification 4.3.1.1, provided no more than one channel is in bypass at any time.

b. For Functional Units with no installed bypass test capability,

1. The inoperable channel is placed in the tripped condition within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , and

2. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels per Specification 4.3.1.1. (4.3.2.1)

SRO NOTIFY I&C To Place The Affected Channel In Trip Or Bypass. REFER TO Addendum 2, Procedure List For The Appropriate Procedure (Step 22)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 17 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 4 (Examiner Trigger)

Event

Description:

SG 1D Controlling NR level channel fails low. LT-0549 Time Position Required Operator Actions Notes SRO INITIATE Corrective Actions For Failed Component (Step 23)

(Event 5 can be triggered after SRO has announce TSs or on request from the lead examiner.)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 18 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 5 (Examiner Trigger)

Event

Description:

LPHDP #11 Trip Time Position Required Operator Actions Notes BOP Acknowledges and announces the following annunciator from 08M3:

LP HDP TRIP (A-4)

SRO Reports that Heater Drip Pump #11 has tripped.

BOP Refers to Annunciator Response Procedure (ARP).

(The ARP will direct the crew to go to 0POP04-CD-0001, Loss of Condensate Flow.)

SRO Enters and directs the actions of 0POP04-CD-0001, Loss of Condensate Flow.

BOP CHECK Required number of Condensate Pumps Running:

LESS THAN 50% RTP - One Condensate Pump

GREATER THAN 50% RTP - Two Condensate Pumps (Step 1)

BOP ENSURE Discharge Valve Of Any Secured/Tripped Condensate Pump Is CLOSED (Steps 2)

BOP MONITOR ICS Parameters For Running Condensate Pumps:

Motor winding temperatures < 266ºF

Pump thrust bearing temperatures < 200 ºF (Steps 3)

(Condensate Pumps are operating normally)

BOP CHECK LPHD Pump Status - All Running RNO IF LPHD Pump(s) tripped, THEN GO TO Addendum 2, LPHD Pump Trip (Step 4)

BOP CHECK FWH 15(25) & 16(26) Strings -

INSERVICE (Addendum 2, Step 1)

BOP CHECK DA Level Controller at 100% Demand (Addendum 2, Step 2)

(Demand will be at 100%)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 19 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 5 (Examiner Trigger)

Event

Description:

LPHDP #11 Trip Time Position Required Operator Actions Notes BOP START Third Condensate Pump Per Addendum 1, Condensate Pump Start That Requires Venting Prior To Start (Addendum 2, Step 3)

BOP Checks if SGFPT SEAL WTR DP LO Annunciators lit.

If so, DA Level Control valve is throttled closed to clear SGFPT SEAL WTR DP LO alarms (3) on CP-006.

(Addendum 1, Steps 1 and 2)

(Condensate Pump 13 will be started.)

BOP VERIFY Miniflow Recirc Line Is Full By Dispatching An Operator To Vent The COND PUMP MINIFLOW RECIRC VENT For Pump To Be Started:

Pump 13 1-CD-0786 (Addendum 1, Step 3)

AO (The TGB watch will report back that the recirc line has been vented.)

BOP Dispatch an operator to ENSURE 1-CD-0801, COND PUMPS DISCH COMMON VENT LINE ISOL VALVE Is OPEN AND to OPEN 1-CD-0802 COND PUMP 13 DISCH COMMON VENT LINE ISOL VALVE (Addendum 1, Steps 4 and 5)

AO (The TGB watch will report back that CD-801 and CD-802 are open.)

BOP START The Selected Condensate Pump:

COND PUMP 13 (Addendum 1, Step 6)

BOP Dispatch an Operator to CLOSE 1-CD-0802 COND PUMP 13 DISCH COMMON VENT LINE ISOL VALVE (Addendum 1, Step 7)

AO (The TGB watch will report back that CD-802 has been closed.)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 20 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 5 (Examiner Trigger)

Event

Description:

LPHDP #11 Trip Time Position Required Operator Actions Notes BOP PLACE DA Level Controller In Manual AND LOWER Demand To < 80%

(Addendum 1, Step 8)

(Will reduce the chance of a CP Bypass.)

BOP OPEN Condensate PUMP DISCH ISOL Valve For Condensate Pump Started To Place Pump In Service:

PUMP 13 MOV-0088 (Addendum 1, Step 9)

(With 3 CD Pumps aligned and running there is a chance for a CP Bypass to occur.)

BOP CONTROL DA Level Control Valve To Restore DA Level (Addendum 1, Step 10)

(Last step of this addendum, the SRO should go to Addendum 2, Step 5.)

(Event #6 can occur after this point at the discretion of the Lead Examiner.)

BOP RETURN To Procedure And Step In Effect (Addendum 1, Step 11)

(Last step of this addendum, the SRO should go back to Addendum 2, Step 5.)

BOP CHECK Affected Flash Tank High Level Dump Valve Is Maintaining Flash Tank Level (Addendum 2, Step 5)

BOP PERFORM The Following For The Affected LPHD Flash Tank:

PLACE the flash tank level control valve controller in manual

CLOSE the flash tank level control valve

DISPATCH An Operator To Investigate The Cause For LPHD Pump Trip (Addendum 2, Step 6)

(Since the cause of the LPHD Pump 11 trip is unknown the crew will wait for maintenance investigation prior to trying a restart.)

(The crew will mark their place in Addendum 2 and GO TO procedure step 12.0.)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 21 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 6 & 7 (Examiner Trigger Event 6)

Event

Description:

Event 6 - Main Generator Output Breaker trips open, Main Turbine fails to auto trip and inadvertent FWI.

Event 7 - On the RX Trip the Main Turbine fails to auto trip and there is an inadvertent FWI. (CT - 13)

Event 8 - Train B 4160V bus lockout. (On Reactor Trip)

Time Position Required Operator Actions Notes ALL Notice RCS temperature and pressure rising, SG Levels and Feedwater flows lowering and several annunciator alarms.

(NOTE: If the crew is slow to diagnose this condition, the reactor may automatically trip.)

SRO Directs a Reactor Trip SRO Enters 0POP05-EO-EO00, Reactor Trip or Safety Injection, and ensures immediate actions are performed.

RO Completes immediate actions of 0POP05-EO-EO00 and determines:

CT-13

Reactor is tripped (Step 1)

Turbine is NOT tripped (Step 2)

VERIFY all turbine throttle valves -

CLOSED RNO

Manually TRIP turbine

If turbine will NOT trip (UNIT TRIP light NOT lit), THEN

*PLACE EH pumps in PULL TO LOCK

Manually RUNBACK turbine

AC ESF Busses are energized except for Train B (Step 3)

Train B 4.16KV ESF Bus has an over-current lockout. The operator must trip ESF DG #12 because the diesel is running with no cooling water. (Event 8)

Check SI status (Step 4)

(RO will complete immediate actions.

BOP Operator will monitor the plant and make an announcement of the Reactor trip.)

(During a pause between performing immediate actions and verifying immediate actions, the BOP should notice and announce that only AFW Pump #13 is running. (AFW Pump #11 is OOS,

12 has no power and AFW Pump #14 tripped on overspeed.)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 22 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 6 & 7 (Examiner Trigger Event 6)

Event

Description:

Event 6 - Main Generator Output Breaker trips open, Main Turbine fails to auto trip and inadvertent FWI.

Event 7 - On the RX Trip the Main Turbine fails to auto trip and there is an inadvertent FWI. (CT - 13)

Event 8 - Train B 4160V bus lockout. (On Reactor Trip)

Time Position Required Operator Actions Notes SRO Directs/ensures the immediate actions of EO00, Reactor Trip/SI have been completed by performing a procedure read through of them.

During the read through of the immediate actions of EO00 the operator will notice that AFW Pump #13 has now tripped and there is no AFW flow.

If a Safety Injection has actuated, then the SRO will continue with 0POP05-EO-EO00.

If a Safety Injection has NOT actuated, then the SRO will transition straight to 0POP05-EO-FRH1, Response to Loss of Secondary Heat Sink.

(See Actions FRH1 on page 24.)

BOP VERIFY Proper SI Equipment Operation Per ADDENDUM 5, VERIFICATION OF SI EQUIPMENT OPERATION (Step 5)

(See Actions on pages 26-28)

RO MONITOR If Containment Spray Is Required:

Containment pressure GREATER THAN 9.5 PSIG (QDPS)

(RNO)

PERFORM the following:

CHECK Containment pressure - HAS EXCEEDED 9.5 PSIG

"PRESS PR-0934"

"EXTD RNG PRESS PR-9759"

IF containment pressure HAS EXCEEDED 9.5 PSIG, THEN GO TO Step 6.b.

IF containment pressure HAS REMAINED LESS THAN 9.5 PSIG, THEN GO TO Step 7.

(Step 6)

(Containment pressure will be less than 9.5 psig and the crew will GO TO Step 7)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 23 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 6 & 7 (Examiner Trigger Event 6)

Event

Description:

Event 6 - Main Generator Output Breaker trips open, Main Turbine fails to auto trip and inadvertent FWI.

Event 7 - On the RX Trip the Main Turbine fails to auto trip and there is an inadvertent FWI. (CT - 13)

Event 8 - Train B 4160V bus lockout. (On Reactor Trip)

Time Position Required Operator Actions Notes RO VERIFY Total AFW Flow - GREATER THAN 576 GPM RNO PERFORM the following:

IF SG NR Level GREATER THAN 14%

[34%] in any SG, THEN Control feed flow to maintain SG NR level.

IF NR Level LESS THAN 14% [34%] in ALL SGs, THEN manually START pumps AND ALIGN valves.

IF TOTAL AFW Flow CANNOT be established GREATER THAN 576 GPM AND SG NR Level in ALL SGs are LESS THAN 14% [34%], THEN GO TO 0POP05-EO-FRH1, RESPONSE TO LOSS OF SECONDARY HEAT SINK, Step 1.

(Step 7)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 24 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 8 Event

Description:

Event 9 - Loss of Heat Sink and entry into FRH1. (CT - 46)

Event 10 - AFW Pump 14 has an overspeed trip.

Event 11 - AFW Pump 13 trips on overcurrent.

Time Position Required Operator Actions Notes SRO Enters 0POP05-EO-FRH1, Response to Loss of Secondary Heat Sink.

RO CHECK If Secondary Heat Sink Is Required:

RCS pressure - GREATER THAN ANY NON-FAULTED SG PRESSURE

RCS wide range hot leg temperatures -

GREATER THAN 350°F (Step 1)

RO RCS BLEED AND FEED CRITERIA AFTER CT-46 STEP 1:

WITH a heat sink required per STEP 1, IF SG wide range levels on any TWO SGs are LESS THAN 50% [73%] OR pressurizer pressure is GREATER THAN OR EQUAL TO 2335 PSIG due to loss of secondary heat sink, THEN PERFORM the following:

*TRIP RCPs*

GO TO Step 11 to initiate bleed and feed to prevent core damage.

(CIP)

NOTE: At least 3 SG WR levels will probably be less than 50% when this procedure is entered, and the crew will trip all RCPs and go to Step 11.

RO ACTUATE SI (Step 11)

(Actuating SI will start HHSI Pumps)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 25 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: 8 Event

Description:

Event 9 - Loss of Heat Sink and entry into FRH1. (CT - 46)

Event 10 - AFW Pump 14 has an overspeed trip.

Event 11 - AFW Pump 13 trips on overcurrent.

Time Position Required Operator Actions Notes RO VERIFY RCS Feed Path:

CT-46

CHECK CCP pump status - at least one running

Maximum Charging Flow ESTABLISHED

RNO - If SI had actuated then the oerator will have to reset Phase A and open the Charging OCIV, CV-MOV-0025.

Establish Maximum Charging ( 150 gpm)

CHECK HHSI pumps - (at least 2 for CT)

CHECK valve alignment for operating HHSI pumps:

HHSI pumps suction from RWST OPEN

HHSI pumps discharge valves OPEN

HHSI cold leg injection valves - OPEN (Step 12)

RO ESTABLISH RCS Bleed Path:

CT-46

VERIFY power to BOTH pressurizer PORV isolation valves - AVAILABLE (RC-MOV-0001B will not have power but the valve was open when power was lost.)

VERIFY both pressurizer PORV isolation valves - OPEN

OPEN both pressurizer PORVs (Step 13)

(Terminate Scenario)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 26 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: N/A Event

Description:

0POP05-EO-EO00, Addendum 5, Actions if SI actuated.

Time Position Required Operator Actions Notes BOP VERIFY FW isolation:

SGFPTs - TRIPPED

SU SGFP - TRIPPED

VERIFY the following valves -CLOSED o FWIVs o FWIBs o FW preheater bypass valves o FW regulating valves o Low power FW regulating valves o SG blowdown isolation valves o SG sample isolation valves (EO00 Addendum 5, Step 1)

(0POP05-EO-EO00, Reactor Trip or Safety Injection, Addendum 5, Verification of Equipment Operation.)

(This addendum is performed in parallel with Steps 5 to 15 of 0POP05-EO-EO00, Reactor Trip or Safety Injection.)

BOP CHECK if main steamline should be isolated:

CHECK for any of the following conditions:

o Containment pressure - GREATER THAN OR EQUAL TO 3 PSIG OR o SG pressure (without low steamline pressure SI blocked) - LESS THAN OR EQUAL TO 735 PSIG OR o SG pressure (with low steamline pressure SI blocked) - LOWERING AT A RATE GREATER THAN OR EQUAL TO 100 PSI/SEC, BY OBSERVANCE OF THE STEAMLINE PRESSURE RATE BISTABLES RNO

GO TO Step 3 of this Addendum (Step 2)

BOP VERIFY AFW system status:

Motor-driven pump - RUNNING

Turbine-driven pump - RUNNING (Step 3)

BOP VERIFY AFW valve alignment - PROPER EMERGENCY ALIGNMENT (Step 4)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 27 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: N/A Event

Description:

0POP05-EO-EO00, Addendum 5, Actions if SI actuated.

Time Position Required Operator Actions Notes BOP VERIFY total AFW Flow - GREATER THAN 576 GPM (Step 5)

BOP VERIFY containment isolation phase A:

Phase A - ACTUATED (Step 6)

BOP VERIFY ECW status:

ECW pumps - RUNNING

ECW pump discharge isolation valves -

OPEN (Step 7)

BOP VERIFY CCW pumps - RUNNING (Step 8)

BOP VERIFY RCFC status:

RCFCs - RUNNING

Cooling water - TRANSFERRED TO CCW (Step 9)

BOP VERIFY SI pump status:

HHSI pumps - RUNNING

LHSI pumps - RUNNING (Step 10)

BOP VERIFY SI valve alignment - PROPER EMERGENCY ALIGNMENT (Step 11)

BOP VERIFY SI flow:

RCS pressure - LESS THAN 1745 PSIG (RNO)

GO TO Step 13 of this Addendum.

(Step 12)

BOP VERIFY containment ventilation isolation:

Containment atmosphere radiation monitor isolation valves - CLOSED

Normal purge supply and exhaust fans -

STOPPED

Supplemental purge supply and exhaust fans

- STOPPED

Purge Dampers - CLOSED (Step 13)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 28 of 38 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 1 Event No.: N/A Event

Description:

0POP05-EO-EO00, Addendum 5, Actions if SI actuated.

Time Position Required Operator Actions Notes BOP VERIFY ventilation actuation:

Control room HVAC - OPERATING IN EMERGENCY RECIRC

EAB HVAC - OPERATING IN EMERGENCY RECIRC

FHB HVAC - OPERATING IN EMERGENCY MODE

FHB Exhaust Fans - ONLY TWO TRAINS OPERATING o Exhaust booster fans o Main exhaust fans (RNO)

PERFORM the following:

o IF three trains FHB exhaust fans running, THEN PLACE one train FHB exhaust fans in PULL TO LOCK.

(Back to A/ER)

SECURE one FHB filter train by PERFORMING the following:

o PLACE the outlet damper Controller in manual o Manually close the outlet damper o VERIFY proper operation of filter train in service

Essential chilled water pumps - RUNNING

Essential chillers - RUNNING

ECCS pump room fan coolers - RUNNING

AFW pump cubicle fans - RUNNING

FHB truck bay doors - CLOSED (Step 14)

BOP NOTIFY Unit Supervisor that Addendum 5 is COMPLETE (Step 15)

SRO IMPLEMENT Functional Restoration Procedures as required (Step 16)

SRO RETURN TO procedure step in effect.

(Step 17)

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 29 of 38 CRITICAL TASK

SUMMARY

EXPECTED SAT/

POSITION ACCEPTANCE CRITERIA RESPONSE UNSAT SRO/RO CT-13 Manually trip the main turbine before a severe MANUALLY TRIP THE (Orange Path) challenge develops to either MAIN TURBINE the Subcriticality or Integrity CSF OR before transition to 0POP05-EO-EC21, whichever

_ Place EHC Pumps happens first.

in PTL - Pump SAFETY SIGNIFICANCE -- Failure to trip the indication green main turbine under the postulated plant lights lit and pump conditions causes challenges to CSFs EHC discharge beyond those irreparably introduced by the pressure slowly postulated conditions. Additionally, such an lowering to main omission constitutes a failure by the crew to turbine trip demonstrate the ability to take one or more setpoint.

actions that would prevent a challenge to plant safety. Thus, failure to manually trip the main turbine under the postulated conditions can result in challenges to the following CSFs:

Integrity

Subcriticality

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 30 of 38 CRITICAL TASK

SUMMARY

EXPECTED SAT/

POSITION ACCEPTANCE CRITERIA RESPONSE UNSAT SRO/RO CT-46 Initiate RCS Bleed and Feed so that the RCS INITIATE RCS BLEED depressurizes sufficiently for HHSI pump injection AND FEED to occur prior to CET temperature reaching 708ºF or an Orange Path on Core Cooling.

_ Trip the RCPs -

SAFETY SIGNIFICANCE for HP Plants:

Pump indication For the HP plants, failure to initiate RCS bleed and green lights lit. feed results in significant and sustained core

_ Ensure at least one uncovery. If bleed and feed is successfully CCP running - initiated, then core uncovery is prevented or Pump indication red minimized. Acceptance criterion used in WCAP-16902-P, Loss of Secondary light lit.

Heat Sink Upgrade Analysis for Emergency

_ Maximum charging Response Guideline FR-H.1, for successful bleed flow - Charging flow and feed cooling of the RCS is that the core exit 150 gpm. vapor temperature does not exceed 1200°F on the average fuel rod channel, which is considered

_ HHSI Pumps appropriate for a beyond design basis event.

running (at least 2) - Analysis showed that when this criterion is met, Pump indication red long term core cooling is sustained through RCS lights lit and HHSI bleed and feed heat removal. Stopping all RCPs is cold leg flow to RCS included as an element of this critical task. If the crew fails to trip the RCPs as instructed by FR-indicated.

H.1, then pump heat from the RCPs continues to

_ Open both PZR be transferred into the RCS, leading to earlier PORVs - Valve dryout of the SGs. SG dryout results in all decay indication green heat being absorbed by the RCS, which causes lights lit. RCS pressure to rise rapidly. When the PZR PORVs open (due either to automatic operation on high system pressure or to manual actuation by the crew during establishment of RCS bleed and feed cooling), the higher system pressure (higher than if RCPs had been manually tripped per instruction) results in a higher rate of RCS inventory depletion and reduced SI flow. The acceptable results for RCS bleed and feed cooling obtained in the loss of secondary heat sink analyses of WCAP-16902-P are predicated upon manually tripping all RCPs prior to CET temperature reaching 708ºF or an Orange Path on Core Cooling.

NOTE: (Per NUREG-1021, Appendix D)

If an operator or the Crew significantly deviates from or fails to follow procedures that affect the maintenance of basic safety functions, those actions may form the basis of a CT identified in the post-scenario review.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 31 of 38 EXPECTED BOOTH COMMUNICATIONS EVENT 1:

As Chemistry and Health Physics, acknowledge that CVCS alignment will be changing.

EVENT 2:

As a Plant Operator, if asked, CCW Pump 1C is running SAT.

As I&C Maintenance or the Duty Maintenance Supervisor, if notified of the failure of RT-8046, report that an I&C maintenance crew is being assembled for support. No further action is necessary.

As Operations Manager, acknowledge the failure of RT-8046. No further action is necessary.

EVENT 3:

As the Duty Maintenance Supervisor, if notified of the failure of Train A RHR HX, CC-FV-4531, report that a maintenance crew is being assembled for support. No further action is necessary.

As Operations Manager, acknowledge the failure of Train A RHR HX, CC-FV-4531. No further action is necessary.

EVENT 4:

As I&C Maintenance or the Duty Maintenance Supervisor, if notified of the failure of SG 1D NR level transmitter, LT-0549, report that an I&C maintenance crew is being assembled for support. No further action is necessary.

As Operations Manager, acknowledge the failure of SG 1D NR level transmitter, LT-0549.

No further action is necessary.

EVENT 5:

As a Plant Operator, if asked, LPHD Pump #11 has an overcurrent indicated.

As a Plant Operator, if asked, the TGB watch will report the following

CD Pump #13 recirc line is vented.

CD-0801 and CD-0802 are open and then that CD-0802 is reclosed after pump has started.

13.8 KV Switchgear room is clear and CD Pump #13 is good to start.

As Mechanical Maintenance or the Duty Maintenance Supervisor, if notified of the trip of LPHD Pump #11 report that a maintenance crew is being assembled for support. No further action is necessary.

As Operations Manager, acknowledge the trip of LPHD Pump #11. No further action is necessary.

EVENT 6 and 7:

There are no Booth Communications expected for Events 6 & 7.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 32 of 38 EXPECTED BOOTH COMMUNICATIONS (contd.)

EVENT 8:

If asked, as a plant operator, report that 4.16KV ESF Bus Train B has over current flags actuated.

EVENT 9, 10 and 11:

If asked, as a plant operator, report that AFW Pump #13 has an acrid smell at the motor and the breaker has an over current flag actuated.

If asked, as a plant operator, report that AFW Terry Turbine has tripped on overspeed and attempts are being made to reset the overspeed trip device. Report that Mechanical Maintenance assistance may be needed.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 33 of 38 EXPECTED BOOTH ACTIONS

1. If asked to open the Deaerator High Level Dump Bypass Valves, then trigger the step for DA HLD Bypass Valves FW-486 & FW-487.

2. If asked to fill the AFWST, then trigger the step for AFWST Makeup.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 34 of 38 SIMULATOR SETUP NOTE ALL Annunciator Response Procedures (ARPs) must be checked if this scenario is the first to be run on this day. Setup for subsequent runs of this scenario only requires those ARPs that were actually marked in to be checked.

Instructors running the scenario must keep track of which ARPs these are, otherwise, all will have to be checked for subsequent scenarios as well.

Each time before running the scenario check and/or clean the following:

Specific Scenario Procedures 1st Peer 2nd Peer 3rd Peer 4th Peer After Last Scenario 0POP02-CV-0004, Chemical and Volume Control System Subsystem 0POP04-RA-0001, Radiation Monitor System Alarm

Response

0POP09-AN-04M7 - D4, RCP 1B THERM BAR CCW FLOW/TEMP/TRBL 0POP04-RC-0002, Reactor Coolant Pump Off Normal, Addendum 1, Establishing Normal RCP Seal Cooling 0POP04-FW-0001, Loss of Steam Generator Level Control 0POP04-CD-0001, Loss of Condensate Flow 0POP05-EO-EO00, Reactor Trip or Safety Injection 0POP05-EO-FRH1, Response to Loss of Secondary Heat Sink Other Procedures Used By Students 1st Peer 2nd Peer 3rd Peer 4th Peer After Last Scenario During Scenario Including POP09s.

Miscellaneous Items to Restore 1st Peer 2nd Peer 3rd Peer 4th Peer After Last Scenario STA ICS Screens to PD Menu All ICS Trends to normal (not scenario specific)

Student Selected ICS Points changed to U1118 Control Panel ICS Screens to Normal RM 11 History and Screens RM 23 - No Alarm Indications

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 35 of 38 SIMULATOR SETUP (contd.)

NOTE SIMULATOR SETUP (contd.)

The Scenario Lesson Plan MUST be run from the left most Instructor Station in Simulator Log into Instructor Workstation as lotnrc user, open Orchid (nstps server), then Booth.

Unlock Initial Conditions Group lotnrc.

For LOT 24 the Simulator Configuration must be set to:

wsTrain_Sep2021/Train_Sep2021 Log into Instructor Workstation as lotnrc user, open Orchid (nstps server), then Unlock Initial Conditions Group lotnrc.

Reset to IC #201 and perform the following:

Switch Check Ensure red light on end of CP-010 off Ensure ICS Annunciators have stopped counting up Go to RUN and perform the following:

Ensure Simulator is ready by performing applicable checkoffs from LOR-GL-0006, LOR Conduct of Simulator Training Guidelines, Addendum 5, Simulator Readiness Checklist.

Ensure VCT Makeup Integrators are set as follows:

Momentarily place RC M/U CONT to STOP and then START to reset BA BATCH/GALLONS and TOT M/U BATCH/GALLONS counters to zero.

Reset BA BATCH/GALLONS setpoint to 0 gallons and reset TOT M/U BATCH/GALLONS setpoint to 10 gallons.

Verify BA Controller Pot setting is 2.50 Place ECO Tag on AFW Pump #11 Open lesson plan for Scenario 1 in lotnrc directory for LOT 24, then EXECUTE lesson plan. These actions will set up any initial conditions for the scenario.

If this scenario IC has changing conditions (i.e. Xenon is changing, etc.), then place the simulator in FREEZE, otherwise it is OK to leave in RUN.

Run the scenario in accordance with the next section, Scenario Instructions.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 36 of 38 SCENARIO INSTRUCTIONS NOTE Steps 1 to 4 below can be performed in the LOR Debrief Room prior to the crew coming into the Simulator provided exam security measures are taken.

1. Provide Shift Turnover sheets to the crew and review the information.

2. Have the Crew perform a Pre-Job Brief closing the 85-100 gpm letdown orifice. Ensure the crew doesnt have any other questions about the Shift Turnover.

3. Ensure the Beacon book from the simulator is available to the crew if they are in the LOR Debrief Room.

4. Review the Simulator Differences list with the crew if needed.

5. When signaled by Simulator Staff, have the crew perform their board walkdown and inform the floor instructor when ready to take the watch.

6. Ensure the simulator is in RUN and verify simulator clock is set correctly. Note the time that the Crew takes the watch. ________________ Start Time.

NOTE Malfunction Step and/or Lesson Plan Steps (Events) are triggered upon the Lead Examiners signal during the scenario unless an agreed upon time is discussed with the examiner prior to the start of the scenario.

Always TRIGGER events in the Simulator Scenario Lesson Plans. This way delays associated with events will take place as intended.

Refer to EXPECTED BOOTH COMMUNCATIONS and EXPECTED BOOTH ACTIONS Sections for instructions for Instructor actions during the scenario.

7. Trigger the step titled Start Chart and ensure specified Recorded Parameters for the scenario begin recording as the scenario runs. If the chart speed is NOT set to 5400 seconds (90 minutes) then perform the following:

Under CHARTS click on SET TIME In the dialog box enter 5400 seconds (90 minutes)

Click OK.

8. The crew will close the 25-30 gpm letdown orifice - Event #1

9. When signaled by Lead Examiner, trigger MALFUNCTION STEP - This will insert Step #1, Event #2.

10. When signaled by Lead Examiner, trigger STEP 2 - Event #3

11. When signaled by Lead Examiner, trigger STEP 3 - Event #4

12. When signaled by Lead Examiner, trigger STEP 4 - Event #5

13. When signaled by Lead Examiner, trigger STEP 5 - Event #6

14. Place simulator in FREEZE when cued by the Lead Examiner to terminate scenario.

15. DO NOT RESET simulator until the steps on the next page are completed and all Examiners have completed Follow-Up Questioning.

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 37 of 38 SCENARIO INSTRUCTIONS (contd.)

NOTE Some scenarios will have more than one chart. For these, each chart file must be separately saved with a unique filename.

16. Saving Recorded Parameters Data Click on the Charts icon on the left side of the screen Select Pause icon, then select All Click on the Print Chart icon, then select All This will bring up a window in the TASK BAR called PRIMOPDF.

Click on Create PDF This will bring up a File Save As window.

Save to folder c:\Users\lotnrc\Desktop\LOT24 Charts. The file name will be LOT24 Scenario 1 followed by a name that identifies the crew (e.g. Crew A).

Save the new file. It will be saved in a folder already on the desktop. LOT24 Charts.

17. Saving Scenario SAM (Simulator Action Monitor)

Under TOOLS click on SAM In the dialog box that comes up click on SAVE TO Save as a TEXT FILE to folder c:\Users\lotnrc\Desktop\LOT24 Charts. The file name will be LOT24 SAM INFO Scenario 1 followed by a name that identifies the crew (e.g. Crew A).

LOT 24 NRC OP-TEST SCENARIO #1 Rev 1 Page 38 of 38 SCENARIO - 01 0POP01-ZQ-0022 Plant Operations Shift Routines For Training Only Shift Turnover Checklist Page 1 of 1 PART I - To be completed prior to shift turnover.

Unit: 1 Off- Going Shift: Days / Nights Date: Today Mode: 1 Dilution Boration Control Rods Current 1% Pwr 1° F Current 1% Pwr 1° F Current 1% Pwr 1° F Setpoint Change Change Setpoint Change Change Position Change Change 10 0 240 263 flushing with 36 39 227 9 9 As Required As Required As Required I Target Channel RCS Boron

-3.73% U1144 880 Unit 1 Status

Mode 1, 100% Power

Core burnup is 10,000 MWD / MTU, MOL

AFW Pump #11 is Out of Service.

Load Reduction:

100-90%/1hr = 173

100-80%/10min = 408

100-75%/30min = 471

100-60%/1hr = 454

100-50%/10min = 727 Information:

The crew will close the 25-30 gpm letdown orifice per 0POP02-CV-0004, Chemical and Volume Control System Subsystem, Section 10.0, Removing a Second or Third Letdown Orifice from Service with the RCS Pressurized. A satisfactory PMT was performed on the 25-30 gpm letdown orifice on the previous shift.

BAT 1A & 1B Concentrations are 7300 ppm

Fuel Handling Building truck bay doors are closed

No personnel are in containment

Ron Gibbs has the duty

The NLO compliment is 5 watch standers and a head operator ECO/LCO/RAsCAL:

TS 3.7.1.2 for AFW Pump #11, Action a. With one motor-driven auxiliary feedwater pump inoperable, within 28 days restore the pump to OPERABLE status or apply the requirements of the CRMP or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 1 of 42 LOT 24 NRC EXAM SIMULATOR OPERATING TEST SCENARIO #2 Revision 1 Week of 07/13/2020

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 2 of 42 SCENARIO OUTLINE Facility: South Texas Project Scenario No.: 2 Op-Test No.: LOT 24 NRC Examiners: Operators:

Initial Conditions: Critical Tasks:

Mode 1 at 78% Power

E5 - CT17; Isolate the faulted/ruptured SG.

Turnover:

E5 - CT34; Begin Cooldown of RCS.

AFW Pump #11 is out of service.

Event Malf. Event Event No. No. Type* Description 02-20-01 RO (I) 1 SRO (I, TS) PZR level channel LT-0465 fails high.

(1 min) 1.0 05-17-01 BOP (I) 2 1A SG PORV pressure transmitter (PT-7411) fails high.

1.0 SRO (I, TS)

(11 min) 3 08-23-01 BOP (C) Condensate Pump #11 Trips (16 min) True SRO (C)

Multiple 4 RO (R) Main Generator Stator Cooling DT Alarm due to high DT across Stator (21 min) BOP (R) Bars 36B and 36T. Including GCM alarm that leads to fast load SRO (R) reduction.

50-SA-11 ALL (M) 5 0.25 Faulted and Ruptured SG 1B. Faulted on MS Line in IVC.

(35 min) 50-HB-10 (2 Critical Tasks) 0.1 6 10-09-03 RO (C) Loss of power to ESF 4.16KV E1C. (Integral to Scenario)

(N/A) True BOP (C)

SRO (C) 7 Multiple RO (C) OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of (N/A) power to ESF 4.16KV E1C.

SRO (C) (Integral to Scenario) 8 SD-59 BOP (C) SG 1B Blowdown Isolation valve fails to close on the SI. Crew will (N/A) 1.0 SRO (C) have to close the SG 1B Blowdown Flow Control valve.

(Integral to Scenario) (Part of Critical Task for isolating SG 1B)

Lot* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS) Technical Specification Total Estimated Time: 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , 20 minutes

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 3 of 42 Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Malfunctions after EOP entry (1-2) 3

2. Abnormal events (2-4) 4

3. Major transients (1-2) 1

4. EOPs entered/requiring substantive actions (1-2) 2

5. Entry into a contingency EOP with substantive actions (>1 per scenario 1 set)

6. Preidentified critical tasks (>2) 2 SCENARIO MISCELLANEOUS INFORMATION INSTRUCTOR NOTES:

Critical Tasks are indicated by "CT-##" in the position column and indicated in bold type. In some instances, an

will indicate that only a portion of the task listed is considered critical.

Shaded cells indicate procedural entry points.

RECORDED PARAMETERS:

Recorded parameters will be determined during NRC Validation week.

The parameters identified for recording may be of value in evaluating crew performance. Once the scenario is complete for each crew, printout the recorded parameters and label the printout with date, time, crew number and scenario number.

See Scenario Instructions section for further details on how to save the Recorded Parameters.

Pressurizer Level

SG 1A Pressure

SG 1A Steam Flow

SG 1B Steam Flow

SG 1B Feedwater Flow

SG 1B Main Steam Rad Monitor, RT-8047

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 4 of 42 SCENARIO OBJECTIVES Event 1 Objective

Respond to a pressurizer level control malfunction in accordance with per 0POP04-RP-0002, Loss of Automatic Pressurizer Level Control.

Event 2 Objective

Respond to an excessive steam demand per 0POP04-MS-0001, Excessive Steam Demand.

Event 3 Objective

Respond to a Condensate Pump trip per 0POP04-CD-0001, Loss of Condensate Flow.

Event 4 Objective

Respond to Main Generator Alarms per 0POP09-AN-07M3, Annunciator Response.

Event 5 Objective

Respond to a Faulted and ruptured Steam Generator per 0POP05-EO-EO00, Reactor Trip or Safety Injection, 0POP05-EO-EO20, Faulted Steam Generator, 0POP05-EO-EO30, Steam Generator Tube Rupture and 0POP05-EO-EC31, SGTR with Loss of Reactor Coolant - Subcooled Recovery Desired.

Event 6 Objective

Respond to a loss of power to a 4.16KV ESF Bus during a reactor trip per 0POP04-AE-0001, First Response to Loss of Any or All 13.8KV of 4.16KV Bus.

Event 7 & 8 Objective

Respond to equipment failures during a reactor trip per 0POP05-EO-EO00, Reactor Trip or Safety Injection.

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 5 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 1 Event

Description:

PZR level channel LT-0465 fails high.

Time Position Required Operator Actions Notes RO Acknowledges and announces the following annunciators on 04M8:

PRZR LEVEL HI RX TRIP ALERT (A-6)

PRZR LEVEL DEV HI B/U HTRS ON (C-6)

CHG FLOW HI/LO (F-3)

(NOTE: Other alarms may come in as the event progresses.)

SRO/RO Determines that Pressurizer Level Channel LT-0465 failed high.

Performs immediate actions of 0POP04-RP-0002:

PLACES CHG FLOW CONT FK-0205 in Manual and controls PZR Level on Program.

(Immediate Action of 0POP04-RP-0002, Loss of Automatic Pressurizer Level Control.)

SRO Directs action of 0POP04-RP-0002, Loss of Automatic Pressurizer Level Control.

RO PLACE "CHG FLOW CONT FK-0205" Controller In MANUAL (Step 1 immediate action)

RO ADJUST "CHG FLOW CONT FK-0205" To Maintain Pressurizer Program Level (Step 2 immediate action)

RO VERIFY Letdown - IN SERVICE (Step 3)

(Letdown will still be in service.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 6 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 1 Event

Description:

PZR level channel LT-0465 fails high.

Time Position Required Operator Actions Notes RO CHECK All Pressurizer Level Channels -

OPERABLE (RNO)

PERFORM the following:

POSITION Pressurizer level control selector switch to remove failed channel from service:

Failed Channel Select RC-LT-0465 L467/466 RC-LT-0466 L465/467 RC-LT-0467 L465/466

POSITION Pressurizer level recorder selector switch to an operable channel.

PLACE Pressurizer HTR CONT GRP 1C to ON.

IF normal letdown has isolated, THEN PLACE excess letdown in service as necessary per Addendum 3 to maintain Pressurizer level on Pressurizer Program Level.

NOTIFY I&C to bypass or trip the Pressurizer low level for the failed channel, using plant surveillance procedure listed in Addendum 4.

(Step 4)

(Selects channel L467/466)

RO CHECK All Tavg Channels - OPERABLE (Step 5)

RO CHECK Tavg - WITHIN 1.5°F OF Tref (Step 6)

RO CHECK Pressurizer Level - GREATER THAN 17%

(Step 7)

RO CHECK Normal Letdown - IN SERVICE (Step 8)

RO CHECK "CHG FLOW CONT FK-0205" -

OPERABLE (Step 9)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 7 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 1 Event

Description:

PZR level channel LT-0465 fails high.

Time Position Required Operator Actions Notes RO CHECK PZR Level Controller:

CHECK PZR Level Controller LK- 0665 "LEVEL CONT." - OPERABLE

PLACE PZR Level Controller LK- 0665 "LEVEL CONT." in MANUAL AND ADJUST output to match "CHG FLOW CONT FK-0205" output

PLACE PZR Level Controller LK- 0665 "LEVEL CONT." in AUTO (Step 10)

RO CHECK PZR Level Controller LK- 0665 "LEVEL CONT." Output Is Stable (Step 11)

RO PLACE "CHG FLOW CONT FK-0205" In Automatic (Step 12)

RO CHECK Pressurizer Level - MAINTAINED ON PRESSURIZER PROGRAM LEVEL (Step 13)

RO CHECK Excess Letdown - ISOLATED (Step 14)

RO REFER TO Addendum 7 For Applicable Technical Specifications (Step 15)

(TS 3.3.1, Function 12, Action 6 - Place the failed channel in the tripped condition within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . See below for details.)

TS 3.3.1, Function12, Action 6 With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. For Functional Units with installed bypass test capability, the inoperable channel may be placed in bypass, and must be placed in the tripped condition within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

Note: A channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing per Specification 4.3.1.1, provided no more than one channel is in bypass at any time.

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 8 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 1 Event

Description:

PZR level channel LT-0465 fails high.

Time Position Required Operator Actions Notes RO INITIATE Corrective Action for Failed Component (Step 16)

(Event 2 can be triggered after SRO has announce TSs or on request from the lead examiner.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 9 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 2 (Examiner Trigger)

Event

Description:

1A SG PORV pressure transmitter (PT-7411) fails high.

Time Position Required Operator Actions Notes BOP Acknowledges and reports annunciator 6M03-A1, SG PORV NOT CLOSE.

SRO Diagnoses that 1A SG PORV is open.

BOP SRO Directs/ensures the actions of 0POP04-MS-0001, Excessive Steam Demand.

BOP CHECK Reactor Power - LESS THAN OR EQUAL TO 100%

(Step 1 Immediate Action Step)

(Reactor Power is already < 100%)

BOP IDENTIFY And ISOLATE Steam Leak:

CHECK Condenser Steam Dump Valves -

CLOSED

CHECK Steam Generator PORVs - CLOSED (RNO)

ENSURE SG PORVs are responding to control SG pressures to LESS THAN OR EQUAL to 1225 psig.

IF Steam Generator pressures are LESS THAN 1225 psig, THEN PERFORM the following:

PLACE affected Steam Generator PORV(s) IN MAN AND CLOSE on MCB controller {CP006}:

PORV PV-7411

REFER TO Technical Specifications 3.3.5.1, 3.7.1.6 TS 3.3.5.1 Action 2a (Auto Actuation)

TS 3.7.1.6 Action a (SG 1A PORV)

GO to Step 3.0 (Step 2)

(Event 3 can be triggered after SRO has announce TSs or on request from the lead examiner.)

(See TS details on next page.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 10 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 2 (Examiner Trigger)

Event

Description:

1A SG PORV pressure transmitter (PT-7411) fails high.

Time Position Required Operator Actions Notes TS 3.3.5.1, Automatic Actuation Control Channels, Action 2a With one less than the required number of OPERABLE channels, within 7 days restore the inoperable channel to OPERABLE status or apply the requirements of the CAMP; or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

TS 3.7.1.6, Atmospheric Steam Relief Valves, Action a With one less than the required atmospheric steam relief valves OPERABLE, within 7 days restore the required atmospheric steam relief valves to OPERABLE status or apply the requirements of the CRMP; or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and place the required RCS/RHR loops in operation for decay heat removal.

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 11 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 3 (Examiner Trigger)

Event

Description:

Condensate Pump #11 Trip.

Time Position Required Operator Actions Notes BOP Acknowledges and announces the following annunciator on 9M01 COND PMP TRIP (A-1).

SRO Diagnoses that Condensate Pump (CD) #11 has BOP tripped and closes CD Pump #11 discharge valve.

(Annunciator Response Step 1)

AO (If called, the Plant Operator will report that there are no visible signs of trouble with the pump, however, the breaker has an over current indicated.)

SRO Directs performance of 0POP04-CD-0001, Loss of Condensate Flow.

BOP CHECK Required number of Condensate Pumps Running:

GREATER THAN 50% RTP - Two Condensate Pump RNO IF a Standby Condensate Pump is available AND DOES NOT require venting prior to start, THEN PERFORM the following:

START Standby Condensate Pump (CD Pump

13)

OPEN Condensate "PUMP DISCH ISOL" Valve for Condensate Pump started to place pump in service:

PUMP 13 "MOV--0088"

CONTROL DA level control valve to restore DA level (Step 1 and Step 1 RNO)

(DA level will be lowering slowly and operator may make manual adjustments with DA level controller as level is restored to the DA.)

BOP ENSURE Discharge Valve of any secured/tripped Condensate Pump is CLOSED (CD Pump #11)

(Step 2)

(This step may have been performed earlier using the Annunciator Response procedure.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 12 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 3 (Examiner Trigger)

Event

Description:

Condensate Pump #11 Trip.

Time Position Required Operator Actions Notes RO MONITOR ICS parameters for running Condensate Pumps:

Motor Winding temperature LESS THAN 266ºF.

Pump Thrust Bearing temperature LESS THAN 200ºF.

(Step 3)

(Event 4 can be triggered on request from the lead examiner.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 13 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 4 (Examiner Trigger)

Event

Description:

Main Generator Stator Cooling DT Alarm due to high DT across Stator Bars 36B and 36T. Including GCM alarm that leads to fast load reduction.

Time Position Required Operator Actions Notes BOP Acknowledges and announces the following annunciators from 07M3:

STATR COIL WTR DIFF TEMP HI/TEMP HI (A-5)

SRO Determines a high Stator Cooling Water BOP differential temperature between Stator Bars 36B and 36T.

SRO Directs actions of 0POP09-AN-07M3, Window A-5, STATR COIL WTR DIFF TEMP HI/TEMP HI.

BOP CHECK the following ICS Trends for an indication of stator coil water differential temperature greater than 14.4(17.0)°F [U5524 Top Coil], 14.4°F [U5525 Bottom Coil] OR stator coil water temperature greater than 174°F

[U5520 or U5521]:

a) Generator Monitoring Global Trend - 63 b) Stator Coil Cooling Water Status Graphic -

GC-011P (07M3 - A5, Step 1)

(Stator bar 36T will slowly rise over a 3-minute ramp causing a deltaT of 20.5°F with the rest of the top bars.)

BOP IDENTIFY the affected thermocouples (ICS points T6112-T6154 & T6156-T6184) from ICS Point Groups 190 through 196 OR Custom Graphic GC-011P Stator Coil Cooling Status.

(07M3 - A5, Step 2)

BOP IF alarm is caused by TCV-6100 cycling OR otherwise malfunctioning, THEN BYPASS TCV-6100 per 0POP02-GC-0001, Generator Stator Cooling.

(07M3 - A5, Step 3)

AO (If asked, a plant operator will report that TCV-6100 is not cycling.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 14 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 4 (Examiner Trigger)

Event

Description:

Main Generator Stator Cooling DT Alarm due to high DT across Stator Bars 36B and 36T. Including GCM alarm that leads to fast load reduction.

Time Position Required Operator Actions Notes BOP IF the problem indication is Failed (Failed high, low or erratic), THEN GO TO Step 10.

(07M3 - A5, Step 4)

(Will determine that temperature instruments are not failed.)

BOP IF the alarm is caused by a differential temperature alarm that is being driven by one lowering thermocouple temperature, THEN GO TO Step 10.

(07M3 - A5, Step 5)

(Will determine Stator Bar 36T is NOT lowering.)

BOP IF either of the following conditions exist;

Stator coil water differential temperature (U5524 or U5525) is greater than or equal to 21.5°F

High stator coil water temperature (U5520 or U5521) is greater than or equal to 194°F THEN PERFORM the following:

1. IF Reactor Power is greater than P-9 (50%),

THEN PERFORM the following:

a) TRIP the Reactor.

b) TRIP the Main Turbine.

c) GO TO 0POP05-EO-EO00, Reactor Trip or Safety Injection.

2. IF Reactor Power is less than P-9 (50%),

THEN PERFORM the following:

a) TRIP the Main Turbine.

GO TO 0POP04-TM-0003, Turbine Trip Below P-9.

(07M3 - A5, Step 6)

(At about this time annunciator window 0POP09-AN-07M3, Window A-4, GEN CONDITION MON ALARM, will come in.)

SRO Directs actions of 0POP09-AN-07M3, Window A-4, GEN CONDITION MON ALARM.

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 15 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 4 (Examiner Trigger)

Event

Description:

Main Generator Stator Cooling DT Alarm due to high DT across Stator Bars 36B and 36T. Including GCM alarm that leads to fast load reduction.

Time Position Required Operator Actions Notes BOP IF BD6023 GCM VERIFIED ALARM is in ALARM on the plant computer (ICS), THEN PERFORM the following:

REDUCE load at a rate of 2% to 5% Per Minute in accordance with 0POP04-TM-0005, Fast Load Reduction.

WHEN below P9 (50%), THEN TRIP the turbine AND ENTER 0POP04-TM-0003, Turbine Trip Below P-9.

WHEN resources permit, THEN MONITOR ICS point A6028 GM GCM MONITOR for diagnostic data (expect less than 50% for verified GCM alarm).

(07M3 - A4, Step 1)

(ICS point BD6023 will be in ALARM and the crew will begin a Fast Load Reduction.)

BOP IF BD6023 GCM VERIFIED ALARM is NOT in ALARM on the plant computer (ICS), THEN PERFORM the following:

DISPATCH Operator to check local GCM alarm indication panel N1GMAIT6028 inside ZLP-952 (TGB 55 Rm 203, Exciter Rm).

IF local GCM alarm panel VERIFIED ALARM is lit, THEN PERFORM 0POP04-TM-0005, Fast Load Reduction, to reduce load at a rate of 2% to 5% Per Minute until the unit is offline.

WHEN resources permit, THEN MONITOR ICS point A6028 GM GCM MONITOR for diagnostic data (expect less than 50% for verified GCM alarm).

(07M3 - A4, Step 1)

AO (If asked, a Plant Operator will report that the local GCM VERIFIED ALARM is lit.)

SRO Directs actions of 0POP04-TM-0005, Fast Load Reduction, due to the GENERATOR CONDITION MON ALARM.

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 16 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 4 (Examiner Trigger)

Event

Description:

Main Generator Stator Cooling DT Alarm due to high DT across Stator Bars 36B and 36T. Including GCM alarm that leads to fast load reduction.

Time Position Required Operator Actions Notes RO PERFORM The Following To Reduce Turbine BOP Load: NOTIFY STP Co-Owners Using The EMS Website That Load Reduction Is Commencing

DETERMINE Amount Of Boric Acid To Add To Reduce Reactor Power To Desired Level AND COMMENCE RCS Boration (about 200 to 300 gallons of Boric Acid)

CHECK Rod Control System - IN AUTOMATIC

ENERGIZE Pressurizer Heaters For Boron Equalization

PERFORM The Following To Lower Turbine Load:

CHECK Main Turbine - IN THE IMPULSE PRESSURE FEEDBACK MODE IMP IN

PLACE Main Steam to DA valves in MOD position and return to AUTO

STM TO DEAER SPLY VLV PV-7174 and PV-7174A (A single handswitch controls both valves)

REDUCE Turbine Load At A Rate Of Less Than Or Equal To 5% Per Minute Using Operator Auto (Step 1)

(The above steps can be performed in any order)

BOP MAINTAIN Main Generator Reactive Load (VARs) Within The Following:

Less than 450 MVARs

Guidelines of The Plant Curve Book, Figure 7.1.

(Step 2)

BOP MONITOR Rod Control System Responding To RCS TAVG/TREF Deviation By Ensuring The Following:

Control Rods Are Responding AND RCS Tavg trending to within 3°F of Tref OR

RCS Tavg within 3°F of Tref (Step 3)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 17 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 4 (Examiner Trigger)

Event

Description:

Main Generator Stator Cooling DT Alarm due to high DT across Stator Bars 36B and 36T. Including GCM alarm that leads to fast load reduction.

Time Position Required Operator Actions Notes RO MAINTAIN Pressurizer Level Within The Following: REFER TO Addendum 4, Pressurizer Level Table

Trending to Program Level OR

At Program Level (Step 4)

BOP MAINTAIN Pressurizer Pressure Within The Following:

Trending to between 2220 psig and 2250 psig OR

Between 2220 psig and 2250 psig (Step 5)

BOP MAINTAIN Steam Generator NR Level Within The Following:

Trending to between 68% and 74%

OR

Between 68% and 74%

(Step 6)

(Event 5 can be triggered when crew performance has been evaluated for the event and on request from the lead examiner.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 18 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes RO Multiple annunciator alarms will be received on BOP primary and secondary panels indicating issues with primary and secondary temperature, pressure and flow control.

ALL Determine that SG 1B is Faulted and Ruptured.

(If asked, a plant operator will report that a large AO amount of steam is coming from Train B Isolation Valve Cubicle (IVC).

(At this time the crew may only diagnose as a SGTR.)

SRO Directs a Reactor Trip, safety Injection and Main Steam Line Isolation. Enters and directs the actions of 0POP05-EO-EO00, Reactor Trip and Safety Injection.

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 19 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes RO Completes immediate actions of 0POP05-EO-EO00 and determines:

Reactor is tripped (Step 1)

Main Turbine is Tripped (Step 2)

AC ESF Busses are energized except for Train C (Step 3)

ENSURE ESF DG #13 Started and loaded.

ENSURE SPLY and OUTP breakers for 4.16KV/480V XFMR(s) -

CLOSED (Event 6 and 7)

Check SI status (Step 4)

(RO will complete immediate actions.

BOP BOP Operator will monitor the plant and make an announcement of the Reactor trip.)

(During a pause between performing immediate actions and verifying immediate actions:

The SRO will direct the BOP to place AFW Pump #12 in PTL as part of isolating SG 1B per the CIP and throttle the other AFW pump flows to limit the RCS cool down By:

Resetting the AFW Reg Valves

Throttling the AFW Reg to lower total AFW flow.

Total AFW flow must remain above 576 gpm until at least one SG level is >14% NR {34% for adverse containment})

SRO Directs/Ensures the immediate actions of EO00, Reactor Trip/SI have been completed by performing a procedure read through of them.

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 20 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes BOP VERIFY Proper SI Equipment Operation Per ADDENDUM 5, VERIFICATION OF SI EQUIPMENT OPERATION (Step 5)

(See Actions on pages 31 to 33)

RO MONITOR If Containment Spray Is Required:

Containment pressure GREATER THAN 9.5 PSIG (QDPS)

(RNO)

PERFORM the following:

CHECK Containment pressure - HAS EXCEEDED 9.5 PSIG

"PRESS PR-0934"

"EXTD RNG PRESS PR-9759"

IF containment pressure HAS EXCEEDED 9.5 PSIG, THEN GO TO Step 6.b.

IF containment pressure HAS REMAINED LESS THAN 9.5 PSIG, THEN GO TO Step 7.

(Step 6)

(Containment pressure will be less than 9.5 psig and the crew will GO TO Step 7)

RO VERIFY Total AFW Flow - GREATER THAN 576 GPM (Step 7)

(BOP will have throttled AFW flow.)

RO CHECK RCP Seal Cooling:

ENSURE seal injection flow between 6 and 13 gpm (Step 8)

(RO may have to adjust seal injection.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 21 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes RO MONITOR RCS Temperatures

WITH ANY RCP RUNNING, RCS TAVG STABLE AT OR TRENDING TO 567°F OR

WITHOUT ANY RCP RUNNING, RCS TCOLD STABLE AT OR TRENDING TO 567°F (Step 9)

(Because of the faulted SG 1B Main Steam will already be isolated and the crew will continue to next step.)

RO CHECK Pressurizer Status:

PORVs CLOSED

Normal pressurizer spray valves - CLOSED

Auxiliary spray valve - CLOSED

Excess letdown isolation valves - CLOSED (Step 10)

RO MONITOR If RCPs Should Be Stopped:

HHSI pump - AT LEAST ONE RUNNING

RCS pressure - LESS THAN 1430 PSIG (RNO)

GO TO Step 12.

(Step 11)

(Crew may or may not have to stop RCPs.)

RO VERIFY The Following Containment Isolation Valve - CLOSED

Seal return isolation valves

Containment atmosphere radiation monitor isolation valves (Step 12)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 22 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes RO CHECK If SG Secondary Pressure Boundary Intact:

CHECK pressures in all SGs -

CONTROLLED OR RISING

GREATER THAN CONTAINMENT PRESSURE (RNO)

IF any faulted SG is NOT isolated, AND is NOT needed for RCS cooldown, THEN PERFORM the following:

GO TO 0POP05-EO-EO20, Faulted Steam Generation Isolation, Step 1.

MONITOR Critical Safety Functions.

WHEN Addendum 5 of this procedure is complete, THEN Functional Restoration Procedures may be IMPLEMENTED.

(Step 13)

SRO Enters 0POP05-EO-EO20, Faulted Steam Generator Isolation.

BOP Checks MSIVs and MSIBs closed.

(Step 1, 0POP05-EO-EO20, Faulted SG Isolation)

(MSIVs and MSIBs will already be closed.)

BOP CHECK If Any SG Secondary Pressure Boundary Intact:

CHECK pressures in all SGs - ANY SG PRESSURE CONTROLLED OR RISING (Step 2)

(SGs A, C and D pressures are controlled.

SG B pressure is NOT controlled.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 23 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes BOP IDENTIFY Faulted SG(s):

CHECK pressure in all SGs -

ANY SG PRESSURE LOWERING IN AN UNCONTROLLED MANNER OR

ANY SG COMPLETELY DEPRESSURIZED (Step 3)

(SG 1B is faulted)

SRO Isolates the faulted SG (1B)

Verifies all FWIVs closed.

CT17

Verifies all FWIBs closed.

Verifies all FW Preheater bypass valves closed.

Verifies all FW Regulating and Low Power FW Regulating Valves closed.

Isolates AFW flow to B SG

Resets SI*

Resets ESF load sequencers*

Resets SG LO-LO level AFW actuations*

Checks SG 1D intact

Closes B SG AFW OCIV, AF-MOV-0065*

Verifies SG B PORV closed

Verifies SG B Blowdown isolation valves closed. (SB-FV-4152 will not close)

RNO

IF valve(s) can NOT be closed, THEN CLOSE SG blowdown flow control valve(s) for faulted SG* (Event 8 -

Operator will close SB-FV-4156 on CP018)

A/ER

Verifies SG B sample isolation valves closed (Step 4)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 24 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes BOP Check Secondary Radiation:

Resets SI

Resets SG LO-LO level AFW actuations

Resets SG Blowdown and Sampling Isolations

Notifies Chemistry to sample all SGs hourly for activity.

Checks the following Rad Monitors:

o Main Steamline o SG Blowdown o CARS Pump RNO

GO TO 0POP05-EO-EO30, Steam Generator Tube Rupture Step 1.)

(Step 5)

(The first 2 resets have already been done so the operator will just check that they are still reset.)

(Main Steam Line and SG Blowdown Radiation Monitors will indicate a tube Rupture on SG 1B.)

SRO Enters 0POP05-EO-EO30, Steam Generator Tube Rupture.

RO MONITOR If RCPs Should Be Stopped:

HHSI pump - AT LEAST ONE RUNNING

RCS pressure - LESS THAN 1430 PSIG (RNO)

GO TO Step 2.

(Step 1)

(Crew should not have to stop RCPs.)

BOP IDENTIFY Ruptured SG(s)

(Step 2)

(Crew has already determined that SG 1B is the ruptured SG.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 25 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes BOP ISOLATE Flow From Ruptured SG(s):

ADJUST ruptured SG(s) PORV controller setpoint to BETWEEN 1260 PSIG AND 1265 PSIG (QDPS PRI/SEC)

CHECK ruptured SG(s) PORV controller - IN AUTO

CHECK ruptured SG(s) PORV CLOSED

VERIFY blowdown isolation valve(s) from ruptured SG(s) CLOSED

CHECK SG 1D - RUPTURED RNO

GO TO Step 3.h.

A/ER

CLOSE ruptured SG(s) MSIV(s) and MSIB(s)

(Step 3)

BOP MONITOR Ruptured SG(s) Level:

NR level - GREATER THAN 14% [34%]

STOP AFW flow to ruptured SG(s):

RESET SI

RESET SG LO-LO level AFW actuations

CLOSE AFW OCIV (Step 4)

(SG 1B AFW OCIV was already closed inn 0POP05-EO-EO20.)

BOP CHECK Ruptured SG(s) Pressure GREATER THAN 468 PSIG RNO GO TO 0POP05-EO-EC31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED, Step 1.

(Step 5)

(SG 1B pressure will be < 468 psig.

SRO Enters 0POP05-EO-EC31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED.

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 26 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes RO RESET SI (Step 1)

RO RESET SI AUTO RECIRC (Step 2)

RO RESET ESF Load Sequencers (Step 3)

RO RESET Containment Isolation Phase A (Step 4)

RO RESET Containment Isolation Phase B (Step 5)

RO ENERGIZE MCCs And Distribution Panels Per ADDENDUM 1, MCC POWER RESTORATION (Step 6)

AO (Addendum will be performed by plant operator and they will report back when addendum complete.)

RO RESET ESF Load Sequencers Mode I Logic Per ADDENDUM 2, RESETTING ESF SEQUENCER MODE I LOGIC (Step 7)

AO (Addendum will be performed by plant operator and they will report back when addendum complete.)

RO ESTABLISH IA To Containment:

IA pressure - GREATER THAN 95 PSIG

OPEN IA OCIV (Step 8)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 27 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes RO ENSURE SFPC In Service Within 2.5 HOURS Of Loss Of SFPC:

CHECK CCW pumps - AT LEAST TWO RUNNING

ALIGN CCW flow to SFPC heat exchanger(s)

CHECK SFPC pump - RUNNING (Step 9)

(SRO may hold off on this step because they have 2.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months to complete.)

RO VERIFY All 13.8KV And 4.16KV AC Busses -

ENERGIZED BY OFFSITE POWER (Step 10)

RO TURN OFF All Pressurizer Heaters:

PLACE group "C" pressurizer heater control switch to PULL TO LOCK

PLACE all other pressurizer heater switches to OFF

CONSULT TSC Staff for a recommended minimum indicated pressurizer water level that will ensure heaters are covered.

(Step 11)

RO MONITOR If Containment Spray Should Be Stopped:

Spray pumps - RUNNING RNO

GO TO Step 13, OBSERVE CAUTION prior to Step 13.

(Step 12)

RO MONITOR Ruptured SG(s) Level:

NR level -GREATER THAN 14% [34%]

STOP AFW flow to ruptured SG(s)

(Step 13)

(AFW Flow has already been stopped to the ruptured SG.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 28 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes RO MONITOR If LHSI Pumps Should Be Stopped:

CHECK RCS pressure:

Pressure - GREATER THAN 415 PSIG

Pressure - STABLE OR RISING

STOP LHSI pumps and PLACE in AUTO (Step 14)

RO INITIATE Evaluation Of Plant Status:

CHECK MAB and FHB radiation NORMAL

NOTIFY Chemistry to collect post-event samples in accordance with the following procedures, as necessary:

0PCP07-ZS-0001, SAMPLING AT PRIMARY SAMPLE PANEL ZLP-131

0PCP08-AP-0003, POST-ACCIDENT SAMPLING OF LIQUIDS AND RCB ATMOSPHERE AT PASS

ENSURE the following ventilation systems in service:

At least two CRDM ventilation fans -

RUNNING

At least one Reactor cavity and supports supply fan - RUNNING

At least one Reactor cavity and supports exhaust fan - RUNNING (Step 15)

(If CRDM vent fans and reactor cavity supply &

exhaust fans have not been started yet they will be started here.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 29 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes RO CHECK If Charging Flow Has Been Established:

CCPs - AT LEAST ONE RUNNING

Charging flow - ESTABLISHED RNO

CLOSE charging flow control valve.

ENSURE CCP discharge valves open.

ENSURE normal or alternate charging isolation valve open.

ENSURE charging OCIV open A/ER

VERIFY pressurizer level GREATER THAN 22% [50%]

RNO

CONTROL charging flow control valve to establish maximum charging flow.

WHEN pressurizer level is restored to GREATER THAN 22% [50%], THEN CONTROL charging to maintain pressurizer level.

(Step 16)

BOP CHECK If SG Secondary Pressure Boundary Intact:

CHECK pressures in all SGs

CONTROLLED OR RISING

GREATER THAN CONTAINMENT PRESSURE RNO

IF any faulted SG, NOT needed for RCS cooldown, is unisolated, THEN GO TO 0POP05-EO-EO20, FAULTED STEAM GENERATOR ISOLATION, Step 1.

(Step 17)

(Only SG 1B is depressurized and it has already been isolated.)

LOT 24 NRC OP-TEST SCENARIO #2 Rev 1 Page 30 of 42 OPERATOR ACTIONS Op-Test No.: 1 Scenario No.: 2 Event No.: 5, 6, 7, 8 (Examiner Trigger)

Event

Description:

Event 5: Faulted and Ruptured SG 1B. Faulted on MS Line in IVC. (2 Critical Tasks)

Event 6: Loss of power to ESF 4.16KV E1C.

Event 7: OUTP BKR, E1C/2A to LC E1C2, fails to Auto Close during loss of power to ESF 4.16KV E1C.

Event 8: SG 1B Blowdown Isolation valve fails to close on the SI. Crew will have to close the SG 1B Blowdown Flow Control valve.

Time Position Required Operator Actions Notes BOP MONITOR INTACT SG Levels:

NR levels - GREATER THAN 14% [34%]

CONTROL AFW flow to maintain NR levels BETWEEN 25% [34%] and 50%

(Step 18)

(Operators will be controlling SG levels to prepare for the plant cooldown in the next step.)

RO INITIATE RCS Cooldown To Cold Shutdown: