ML103080005
| ML103080005 | |
| Person / Time | |
|---|---|
| Site: | Waterford  |
| Issue date: | 11/04/2010 |
| From: | Apger G Operations Branch IV |
| To: | Entergy Operations |
| References | |
| 50-382/10-302 50-382/10-302 | |
| Download: ML103080005 (177) | |
Text
Attachment 10 Page 1 of 3 OBDI 202 - IOLE Process WT-2010-10 DRAFT OPERATING TEST COMMENTS ADMIN JPMS JPM# 6. Explanation (See below for instructions) SRO (A5) See markups on draft submittal.
SRO (A6) See markups on draft submittal.
SRO (A7) See markups on draft submittal.
SRO (A8) See markups on draft submittal.
SRO (A9) See markups on draft submittal.
Instructions for Completing Matrix This form is not contained in or required by NUREG-1021. Utilities are not required or encouraged to use it. The purpose of this form is to enhance regional consistency in reviewing operating tests. Additional information on these areas may be found in Exam ination Good Practices Appendix D. Check or mark any item(s) requiring comment and explain the issue in the space provided.
- 1. Determine whether the task is dynamic (D) or static (S). A dynamic task is one that involves continuous monitoring and response to varying parameters. A static task is basically a system reconf iguration or realignment. 2. Determine level of difficulty (LOD) using established 1-5 rating scale. Levels 1 and 5 represent inappropriate (low or high) discriminatory level fo r the license being tested. 3. Check the appropriate box when an attribute weakness is identified: The initiating cue is not sufficiently clear to ensure the operator understands the task and how to begin. The JPM does not contain sufficient c ues that are objective (not leading). All critical steps (elements) have not been properly identified. Scope of the task is either too narrow (N) or too broad (B). Excessive overlap with other part of operating test or wr itten examination. 4. Check the appropriate box when a job content error is identified: Topics not linked to job content (e.g., di sguised task, not required in real job). Task is trivial and without safety significance. 5. Based on the reviewer
=s judgment, is the JPM as written (U)na cceptable (requiring repair or replacement), in need of (E)ditorial enhancement, or (S)atisfactory? 6. Provide a brief description of any U or E rating in the explanation column. 7. Save initial review comments as normal black text; indicate how comments were resolved using blue text so that each JPM used on the exam is reflected by a (S)atisfactory resolution on this form.
Attachment 10 Page 2 of 3 OBDI 202 - IOLE Process WT-2010-10 DRAFT OPERATING TEST COMMENTS CONTROL ROOM/IN-PLANT SYSTEMS JPMS JPM# 6. Explanation (See below for instructions) S1 One minor edit of JPM cue sheet. Also move this sheet to the end of the JPM. S2 See markups on draft submittal. S3 See markups on draft submittal. S4 See markups on draft submittal. S5 See markups on draft submittal. S6 See markups on draft submittal. S7 See markups on draft submittal. GENERIC COMMENT: Need examiner cues for in-plants. P1 See markups on draft submittal. P2 See markups on draft submittal. Have another JPM for FPC system as indicated on the JPM markup. P3 See markups on draft submittal. Examiner cues can be inferred from standards. No separate cues needed.
Instructions for Completing Matrix This form is not contained in or required by NUREG-1021. Utilities are not required or encouraged to use it. The purpose of this form is to enhance regional consistency in reviewing operating tests. Additional information on these areas may be found in Exam ination Good Practices Appendix D. Check or mark any item(s) requiring comment and explain the issue in the space provided.
- 1. Determine whether the task is dynamic (D) or static (S). A dynamic task is one that involves continuous monitoring and response to varying parameters. A static task is basically a system reconf iguration or realignment. 2. Determine level of difficulty (LOD) using established 1-5 rating scale. Levels 1 and 5 represent inappropriate (low or high) discriminatory level fo r the license being tested. 3. Check the appropriate box when an attribute weakness is identified:
$ The initiating cue is not sufficiently clear to ensure the operator understands the task and how to begin.
$ The JPM does not contain sufficient c ues that are objective (not leading).
$ All critical steps (elements) have not been properly identified.
$ Scope of the task is either too narrow (N) or too broad (B).
$ Excessive overlap with other part of operating test or wr itten examination. 4. Check the appropriate box when a job content error is identified: Topics not linked to job content (e.g., di sguised task, not required in real job). Task is trivial and without safety significance. 5. Based on the reviewer
=s judgment, is the JPM as written (U)na cceptable (requiring repair or replacement), in need of (E)ditorial enhancement, or (S)atisfactory? 6. Provide a brief description of any U or E rating in the explanation column. 7. Save initial review comments as normal black text; indicate how comments were resolved using blue text so that each JPM used on the exam is reflected by a (S)atisfactory resolution on this form.
Attachment 10 Page 3 of 3 OBDI 202 - IOLE Process WT-2010-10 DRAFT OPERATING TEST COMMENTS SCENARIOS Scenario Set 10. Explanation (See below for instructions) 1 See markups on draft submittal. Minor edits. 2 Minimal scenario that may be the ba ckup. See markups on draft submittal. Minor edits on page 10 of 16 on D2. 3 No Comments Instructions for Completing Matrix This form is not contained in or required by NUREG-1021. Utilities are not required or encouraged to use it. The purpose of this form is to enhance regional consistency in reviewing operating test scenario sets. Additional information on these areas may be found in Ex amination Good Practices Appendix D. Check or mark any item(s) requiring comment and explain the iss ue in the space provided. 1. ES: ES-301 checklists 4, 5, & 6 satisfied.
- 2. TS: Set includes SRO TS actions for each SRO, with required actions explicitly detailed. 3. Crit: Each manipulation or evolution has explicit success criteria documented in Form ES-D-2. 4. IC: Out of service equipment and other initial conditions reasonably consistent between scenarios and not predictive of scen ario events and actions. 5. Pred: Scenario sequence and other factors avoid predictability issues. 6. TL: Time line constructed, including ev ent and process triggered conditions, such t hat scenario can run without routine exam iner cuing. 7. L/C: Length and complexity for each scenario in the set is reasonable for the crew mix being examined, such that all applicants have reasonably sim ilar exposure and events are needed for evaluation purposes. 8. Eff: Sequence of events is reasonably efficient for examination purposes, especially with respect to long delays or interact ions. 9. Based on the reviewer
=s judgment, rate the scenario set as (U)nacceptable (requiring r epair or replacement), in need of (E)ditorial enhancement, or (S)atisfactory. 10. Provide a brief description of problem in the explanation column. 11. Save initial review comments as normal black text; indicate how comments were resolved using blue text so that each JPM used on the exam is reflected by a (S)atisfactory resolution on this form.
Waterford 3 2010 NRC SRO Exam
A1 Review Completed Surveillance for Approval EXAMINER REVIEW COMMENTS IN RED
Applicant:
Examiner:
JPM A1 Revision 0 Page 2 of 6 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Review and approve surveill ance OP-903-117, Emergency Diesel Generator Fuel Oil Transfer Pump Operability Check.
Task Standard:
Applicant's review discovered three error s as identified in the key
., and Applicant also the applicant correctly evaluated Tech Specs in accordance with as identified in the key.
References:
OP-903-117, Emergency Diesel Generator Fuel Oil Transfer Pump Operability Check Time Critical: No Validation Time:15 mins.
K/A 2.1.23, Ability to perform specific system and Importance Rating 4.4 integrated plant procedures during all modes of plant operation.
Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature JPM A1 Revision 0 Page 3 of 6 2010 NRC SRO Exam
JPM A1 Revision 0 Page 4 of 6 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-903-117, Emergency Diesel Generator Fuel Oil Transfer Pump Operability Check
==
Description:==
This JPM is performed in the simulator, but use of the simulator is not required. The applicant will be given a completed OP-903-117, Attachment 1 for EDG Fuel Oil Transfer Pump A. The key identifies indicates the error s that the applicant must identify. One of the error s will make EDG Fuel Oil Transfer Pump A inoperable. The applicant will be required to identify the correct Tech Spec.
READ TO APPLICANT
DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any
other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM A1 Revision 0 Page 5 of 6 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD Review Attachment 10.1 for accuracy.
The following errors must be identified:
- The vibration meter and probe are past their calibration dates.
- Pump differential pressure was calculated incorrectly.
The corrected pressure is below the low limit of 70.7
PSID.
- The flow calculation for EGF-109 A, Fuel Oil Transfer Pump A Discharge Check, was performed incorrectly.
The corrected flow is greater than the required 30 gpm.
Comment: Critical SAT / UNSAT TASK ELEMENT 2 STANDARD Determine applicable Tech Spec
associated with EDG Fuel Oil Transfer
Pump A being inoperable.
Tech Spec 3.8.1.1 b and d must be entered.
Actions include:
- Restore EDG A within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD
SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
- Restoration within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> may be extended to 10 days if a temporary emergency diesel generator is verified
available.
- Complete OP-903-066, Electrical Breaker Alignment Check, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, and at least every 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />
thereafter.
The following must be satisfied within 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />s:
- All required systems, subsystems, trains, components, and devices that depend on the remaining OPERABLE
diesel generator as a source of emergency power must
be OPERABLE
Comment: Critical SAT / UNSAT END OF TASK
JPM A1 Revision 0 Page 6 of 6 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
Emergency Diesel Generator A Fuel O il Transfer Pump IST has been completed in accordance with OP-903-117, Emergency Diesel Generator Fuel Oil Transfer Pump Operability Check. The completed attachment for the surveillance has been reviewed and is ready for SM/CRS review.
INITIATING CUES:
Review the provided surveillance the attachment. Mark and provide any comments on this sheet
.
Waterford 3 2010 NRC SRO Exam
A2 Review COLSS Constant Calculation in accordance with OP-004-005, Core Operating Limits Supervisory System Operation
Applicant:
Examiner:
EXAMINER REVIEW COMMENTS IN RED JPM A2 Revision 0 Page 2 of 7 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Review COLSS constant calcul ation in accordance with OP-004-005, Core Operating Limits Supervisory System Operation Task Standard: Applicant identified errors as identified in the key for Attachment 11.6, Calculation of Charging and Letdown Parameters.
References:
OP-004-005, Core Operating Limits Supervisory System Operation Time Critical: No Validation Time:15 mins.
K/A 2.1.20, Ability to interpret and execute. Importance Rating 3.0 4.6 procedure steps Change 301-1 Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature JPM A2 Revision 0 Page 3 of 7 2010 NRC SRO Exam
JPM A2 Revision 0 Page 4 of 7 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
Simulator / Plant Monitoring Computer OP-004-005, Core Operating Limits Supervisory System Operation
==
Description:==
This JPM is performed in the simulator and use of the Plant Monitoring Computer is required. The applicant will be given a co mpleted OP-004-005, Attachment 11.6 for COLSS Charging and Letdown Constants. The ke y identifies errors that the applicant must identify. There will be a combinati on of data collection and procedure execution errors.
READ TO APPLICANT
DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any
other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM A2 Revision 0 Page 5 of 7 2010 NRC SRO Exam Evaluator Note Provide the completed Attachment 11.6 on colored paper to the applicant.
TASK ELEMENT 1 STANDARD Review Attachment 11.6 for accuracy.
The following errors must be identified:
- The data collected for PMC point A39103 was incorrect.
307.0 °F from point A39104 was recorded vice 354.38
°F. This affects the value of step 11.6.2.1. The correct
value for step 11.6.2.1 is 329.0484.
- Step 11.6.2.2 was calculated incorrectly. The parentheses were not used properly when the
calculation was performed. The correct value for step
11.6.2.2 is 43705.72.
- Step 11.6.2.4 was calculated incorrectly. The value 0.000031 was entered with too few characters. The
correct value for step 11.6.2.4 is 0.021127.
Comment: Critical SAT / UNSAT
END OF TASK
JPM A2 Revision 0 Page 6 of 7 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
Plant conditions are as you see on the Simula tor. Use of the Simulator, RM-11, and Plant Monitoring Computer is acceptable.
You are not allowed to use any network computers.
Plant configuration was changed from 1 Char ging Pump running to 2 Charging Pumps running.
You are the CRS and have been given a comple ted Attachment 11.6, Calculation of Charging and Letdown Parameters, from OP-004-005, Core Operating Limits Supervisory System Operation, to review.
Perform this review and mark any comments on this sheet.
JPM A2 Revision 0 Page 7 of 7 2010 NRC SRO Exam Place this page before the JPM CUE sheet so that the page count does not confuse the applicant.
SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-190
After all simulator generated alarms are clear, place the simulator in FREEZE.
Verify the parameters on the PMC match the values on the key.
Waterford 3 2010 NRC SRO Exam JOB PERFORMANCE MEASURE
A3 Evaluate Low Pressure Safety Injection Train B Operability
Applicant:
Examiner:
EXAMINER REVIEW COMMENTS IN RED
JPM A3 Revision 0 Page 2 of 5 2010 NRC Walk Through Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Evaluate the operability of Low Pr essure Safety Injection Train B during the performance of OP-903-026, Emergency Core Cooling System Valve Lineup Verification.
Task Standard: Applicant determined the total gas volume for each of the 2 penetrations and determined that L PSI Train B became inoperable after the void was discovered at SI-134 B.
References:
OP-903-026, Emergency Co re Cooling System Valve Lineup Verification Time Critical: No Validation Time:20 mins.
K/A 2.2.40, Ability to apply Technical Importance Rating 4.7 Specifications for a system Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM A3 Revision 0 Page 3 of 5 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-903-026, Emergency Core Cooling System Valve Lineup Verification
==
Description:==
This JPM is performed in the simulator, but use of the simulator is not required. The applicant will be provided information describing the results of surveillance OP-903-026, Emergency Core Cooling System Valve Lineup Verification. He , and will be required to evaluate void size and location to determine what the total gas volume was in the 2 locations of importance
. The applicant will also be required to determine when in the testing sequence Low Pressure Safety Injection Train B became inoperable.
READ TO APPLICANT
DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any
other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM A3 Revision 0 Page 4 of 5 2010 NRC SRO Exam Evaluator Note The simulator is not required for this JPM. Provide the applicant with the colored cue sheet.
TASK ELEMENT 1 STANDARD A. What was the total gas volume applicable to each of the 2 penetrations?
Penetration 36, for SI-1412 B and SI-133 B = 1.71 ft 3 Penetration 37, for SI-1402 B and SI-134 B = 1.459 ft 3 Comment: Critical SAT / UNSAT TASK ELEMENT 2 STANDARD B. At what point in the sequence did Low Pressure Safety Injection Train B become
inoperable, if any?
After the void was discovered at SI-134 B.
Comment: Low Pressure Safety Injection Train B remained operable after SI-1412 B, SI-1402 B and SI-133 B voids were discovered. Low Pressure Safety
Injection Train B was required to be declared
inoperable after the void was discovered at SI-134 B.
After step 3 of the listed sequence, the total gas volume for SI-1412 B and SI-133 B was 1.71 ft 3 , less than the limit of 1.802 ft 3 for that penetration.
After step 4 of the above sequence, the total gas volume for SI-1402 B and SI-134 B was 1.459 ft 3 , above the limit of 1.229 ft 3 for that penetration.
Critical SAT / UNSAT END OF TASK
JPM A3 Revision 0 Page 5 of 5 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
OP-903-026, Emergency Core Cooling System Va lve Lineup Verification, is in progress.
The RCA Watch has discovered voids duri ng the performance of the surveillance.
After each void was discovered, actions were taken to fill that line before moving to the next location. The RCA Watch called in t he following results in the order listed:
- 1. SI-1412 B, RC Loop 1A FCV Downstream Vent 9 inch arc 2. SI-1402 B, LPSI Header to RC Loop 1B FCV Downstream Vent 8 inch arc 3. SI-133 B, LPSI Pump B Discharge to RC Loop 2B Vent 10 inch arc 4. SI-134 B, RC Loop 1 SHDN Cooling Warm-up Line Vent 7 inch arc
A. What was the total gas volume applicable to each of the 2 penetrations?
B. At what point in the sequence did Low Pr essure Safety Injection Train B become inoperable, if any?
Record answers on this sheet.
A.
B.
Waterford 3 2010 NRC SRO Exam
A4 Review a Liquid Release Permit
Applicant:
Examiner:
EXAMINER REVIEW COMMENTS IN RED
JPM A4 Revision 0 Page 2 of 6 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Review and approve a liquid release permit in accordance with OP-007-001, Boron Management.
Task Standard:
Applicant identified error s in the permit according to the key.
References:
OP-007-001, Boron Management CE-003-514, Liquid Radioactive Release Permit
EC-M84-001 Time Critical: No Validation Time:20 mins.
K/A 2.3.6, Ability to approve release permits Importance Rating 3.8 Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM A4 Revision 0 Page 3 of 6 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-007-001, Boron Management EC-M84-001
==
Description:==
This JPM is performed in the simulator and use of the Plant Monitoring Computer and the RM-11 Radiation Monitoring Computer is required. The applicant will be given a release permit for Boric Acid Condensate Tank B to authorize. The key identifies errors that the applicant must identif
- y. There will be a combination of data collection errors from both the PMC and RM-11.
There are also plant conditi ons that are not properly reflected in the permit. The applicant will be able to gather this information from the
control panel alignment.
READ TO APPLICANT
DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any
other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM A4 Revision 0 Page 4 of 6 2010 NRC SRO Exam Evaluator Note Provide the Boric Acid Condensate Tank B Release Permit, printed on colored paper, to the applicant.
TASK ELEMENT 1 STANDARD Review the Boric Acid Condensate Tank
B Release Permit for accuracy.
The 3 All of the [space] following errors must be identified:
- The data collected for Boric Acid Condensate Tank B was incorrect. The level for Waste Condensate Tank B
was recorded instead. The tank percent and tank
volume in gallons reflect the level in Waste Condensate
Tank B.
- The permit list that 4 Circulating Water Pumps are running, but only 3 are running.
- The setpoint for the Boric Acid Condensate Radiation Monitor is reading 8.0 e-02 uCi/ml vice 6.50 e-01. This
reading must be verified from the RM-11 computer.
- The Boric Acid Condensate Radiation Monitor is listed as PRM-IRE-0647 on various locations of the permit.
The correct UNID number is PRM-IRE-0627.
Comment: Critical SAT / UNSAT END OF TASK
JPM A4 Revision 0 Page 5 of 6 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
Plant conditions are as you see on the Simula tor. Use of the Simulator, RM-11, and Plant Monitoring Computer is acceptable.
You are not allowed to use any network computers.
Boric Acid Condensate Tank B is ready to be released and the Release Permit is in the
Control Room for your review.
Perform this reviewReview the Release Permit and mark provide any comments on this sheet.
JPM A4 Revision 0 Page 6 of 6 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS
Reset to IC-190
After all simulator generated alarms are clear, place the simulator in FREEZE.
Verify the parameters on the PMC and R M-11 match the values on the key.
PLACE THIS SHEET BEFORE THE APPLICANT CUE SHEET TO PREVENT PAGE SEQUENCE CONFUSION.
Waterford 3 2010 NRC SRO Exam
A5 Classify Emergency Plan Entry Level
Applicant:
Examiner:
EXAMINER REVIEW COMMENTS IN RED.
JPM A5 Revision 0 Page 2 of 6 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Classify Emergency Plan Entry Level
Task Standard: Applicant determined corre ct Emergency Plan class and initiating condition.
References:
EP-001-001 Recognition and Classification of Emergency Conditions Time Critical: No Validation Time:15 mins.
K/A 2.4.41, Knowledge of the emergency action Importance Rating 4.6 level thresholds and classifications.
Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM A5 Revision 0 Page 3 of 6 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
EP-001-001 Recognition and Classification of Emergency Conditions
==
Description:==
This JPM is performed in the simulator and use of the Plant Monitoring Computer and the RM-11 Radiation Monitoring Computer is required. The applicant will be given plant conditions and directed to make the appropriate Emergency Plan class and initiating
condition. The applicant will have to get data off of the RM-11 or Plant Monitoring computers to properly classify the event.
READ TO APPLICANT
DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any
other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM A5 Revision 0 Page 4 of 6 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD Determine the correct Emergency Plan class and initiating condition.
Applicant declares an Alert based on initiating condition AA1, any UNPLANNED release of
gaseous or liquid radioactivity to the
environment that exceeds 200 times the
radiological effluent ODCM limits for > 15
minutes. Comment: PLANT STACK Wide Range Gas Monitor PRM-IRE-0110, RE0110-4 will read > 1.51E+07 uCi/sec, the
Alert classification limit. It will be less than the Site
Area Emergency limit of 2.55E+08 uCi/sec.
Plant Stack PIG Gas Channels, PRM-IRE-0100.1S or 2S, RE0100.1-1 or RE0100.2-1 will be > 3.45E-03
uCi/cc, the Unusual Event criteria. There is no criteria
to upgrade from an Unusual Event to an Alert based
on either Plant Stack PIG Gas Channel.
Critical SAT / UNSAT
END OF TASK
JPM A5 Revision 0 Page 5 of 6 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
Plant conditions are as you see on the Simula tor. Use of the Simulator, RM-11, and Plant Monitoring Computer is acceptable.
You are not allowed to use any network computers.
A failure of the Gaseous Waste System has occurred. Conditions are as displayed on
the simulator. These conditions have existed for 30 minutes.
You are the Shift Manager / Emergency C oordinator. Determine the appropriate Emergency Plan class and initiating condition.
Mark all of your conclusions on this sheet.
JPM A5 Revision 0 Page 6 of 6 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS
Reset to IC-190
After all simulator generated alarms are clear, place the simulator in FREEZE.
Verify the parameters on the PMC match the values on the key.
PLACE BEFORE APPLICANT CUE SHEET TO ELIMINATE PAGE SEQUENCE CONFUSION.
Waterford 3 2010 NRC SRO Exam
S1 ATC Immediate Operator Actions on 2 Dropped CEAs
Applicant:
Examiner:
JPM S1 Revision 0 Page 2 of 8 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: ATC Immediate Operator Actions on 2 Dropped CEAs Task Standard: Applicant tripped the r eactor using 32 A and 32 B breakers in accordance with OP-902-000 and comp leted the ATC operator's Standard Post Trip Actions.
References:
OP-901-102, CEA or CEDMCS Malfunction OP-902-000, Standard Post Trip Actions Alternate Path: Yes Time Critical:No Validation Time: 5 mins.
K/A 001 A2.13, ATWS Importance Rating 4.4 / 4.6 RO / SRO Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM S1 Revision 0 Page 3 of 8 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
None
==
Description:==
Applicant will position himself as the AT C operator at CP-2. CEAs 3 and 14 will drop into the core. The applicant should notice the condition, announce the condition, and trip the reactor without direction.
The normal reactor trip pushbuttons will not function. The applicant should move to the first contingency and use the Diverse
Reactor Trip pushbuttons. One of these butt ons is faulted. The DRTS alarms will come in, but the CEA MG set load contactors will not open. The applicant should then move to the second contingency, and open both 32 Bu s Feeder breakers, and reclose them 5 seconds later. The task should be stopped after the applicant completes the immediate
operator actions for the ATC position.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will
provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM S1 Revision 0 Page 4 of 8 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The plant is at 100% power.
INITIATING CUES:
Respond to conditions observed. Perform actions as required by the ATC operator.
JPM S1 Revision 0 Page 5 of 8 2010 NRC SRO Exam Evaluator Note 1. All of the listed steps are from OP-901-102, CEA or CEDMCS Malfunction, and OP-902-000, Standard Post Trip Actions, but the applicant is required to perform the listed steps from memory. 2. Direct simulator operator to initiate trigger 1 when ready to begin.
TASK ELEMENT 1 STANDARD D.1. Determines 2 CEAs have dropped, attempts to trip the reactor from CP-2 or CP-8 Pushes both reactor trip pushbuttons on CP-2 or
CP-8. Comment: Trip pushbuttons are faulted and Reactor Trip Circuit Breakers will not open.
Critical SAT / UNSAT TASK ELEMENT 2 STANDARD 1.a.1.2 Attempts to trip reactor using DRTS pushbuttons on CP-2.
Pushes both DRTS pushbuttons on CP-2.
Comment: 1 DRTS pushbutton is faulted and CEA MG set load contactors will not open.
Critical SAT / UNSAT TASK ELEMENT 3 STANDARD 1.a.1.3 Open BOTH the following breakers for 5 seconds and close:
- SST A32 FEEDER
breakers for 5 seconds and
then re-closes both
breakers.
Comment: Evaluator: If applicant stops after re-closing the A and B 32 Feeder breakers, prompt him as the CRS to perform his Standard Post Trip
Actions.
Critical SAT / UNSAT
JPM S1 Revision 0 Page 6 of 8 2010 NRC SRO Exam TASK ELEMENT 4 STANDARD 1. Determine Reactivity Control acceptance criteria are met: Check reactor power is dropping. Check startup rate is negative. Check less than TWO CEAs are NOT fully inserted.
Verifies listed parameters.
Comment:
Critical SAT / UNSAT TASK ELEMENT 5 STANDARD 3. Determine RCS Inventory Control acceptance criteria are met:
Check that the following conditions exist: Pressurizer level is 7% to 60% Pressurizer level is trending to 33% to 60% Check RCS subcooling is greater than or equal to 28 ºF.
Verifies listed parameters.
Comment:
Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 4. Determine RCS Pressure Control acceptance criteria are met by checking that BOTH of the following conditions exist: Pressurizer pressure is 1750 psia to 2300 psia Pressurizer pressure is trending to 2125 psia to 2275 psia Verifies listed parameters.
Comment:
Critical SAT / UNSAT
JPM S1 Revision 0 Page 7 of 8 2010 NRC SRO Exam TASK ELEMENT 7 STANDARD 5. Determine Core Heat Removal acceptance criteria are met: Check at least one RCP is operating. Check operating loop T is less than 13 ºF. Check RCS subcooling is greater than or equal to 28 ºF.
Verifies listed parameters.
Comment:
Critical SAT / UNSAT TASK ELEMENT 8 STANDARD 6.b. Determine RCS Heat Removal acceptance criteria are met: Check RCS T COLD is 530 ºF to 550 ºF Verifies listed parameters.
Comment:
Critical SAT / UNSAT TASK ELEMENT 9 STANDARD 7. Determine Containment Isolation acceptance criteria are met: Check containment pressure is less than 16.4 psia. Check NO containment area radiation monitor alarms OR unexplained rise in activity. Check NO steam plant activity monitor alarms OR unexplained rise in activity.
Verifies listed parameters.
Comment:
Critical SAT / UNSAT
END OF TASK
JPM S1 Revision 0 Page 8 of 8 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-195
Verify the following Malfunctions: No Trigger o rp01a, RPS manual pushbutton a o rp01b, RPS manual pushbutton b o rp01c, RPS manual pushbutton c o rp01d, RPS manual pushbutton d Trigger 1:
o rd02a03, drop CEA 3 o rd02a14, drop CEA 14
Verify the following Overrides: No Trigger o di-02a06s02-1, DRT pushbutton 1 of 2
Coordinate with examiner to in itiate Trigger 1 on his cue.
Waterford 3 2010 NRC SRO Exam
S2 Failed Pressurizer Level Control due to Failed RCS Cold Leg Temperature Instrument and Pressurizer Level Control
Applicant:
Examiner:
JPM S2 Revision 0 Page 2 of 9 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Perform actions associated with a faulted Pressurizer level setpoint in accordance with OP-901-110, Pressurizer Level Control
Malfunction.
Task Standard: Faulted Reactor Coolant Cold Leg temperature instrument was removed from service in accordance with OP-901-110.
References:
OP-901-110, Pressurizer Level Control Malfunction Alternate Path: Yes Time Critical:No Validation Time: 15 mins.
K/A 004 A2.22, Mismatch of Charging and Letdown Importance Rating 3.2 / 3.1 flows RO / SRO Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM S2 Revision 0 Page 3 of 9 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-901-110, Pressurizer Level Control Malfunction
==
Description:==
The applicant will be positioned as the ATC oper ator to start this task. The JPM will start with RCS Cold Leg temperature in strument RC-ITI-0111-Y failed high. The cue sheet will direct the applicant to match Charging and Letdown flow. This will be
accomplished at CP-2. After the applicant r eports that Charging and Letdown flows are matched and verifications made, the applicant will be directed to assume the role of the BOP operator and select the non-selected Cold Leg instrument. This is located behind CP-2. This selection will not function, r equiring the applicant to remove the failed instrument from service at bot h Reactor Regulating drawers.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will
provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM S2 Revision 0 Page 4 of 9 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
Mode 1, 15% power Main Turbine testing in planned for next shift
INITIATING CUES:
You are the ATC operator Annunciator B-1, Pressurizer Level Hi/
Lo, on Panel H has come into alarm. The CRS has entered OP-901-110, Pressu rizer Level Control Malfunction, section E2, Pressurizer Level Setpoint Malfunction The CRS has directed you to raise Letdown flow to 120 - 126 gpm to match Charging and Letdown flow in accordance with step 1.
JPM S2 Revision 0 Page 5 of 9 2010 NRC SRO Exam Evaluator Note Direct the simulator operator to place the simulator in RUN when ready to start.
TASK ELEMENT 1 STANDARD 1. Place Pressurizer Level Controller (RC-ILIC-0110) in MAN AND adjust
OUTPUT to slowly adjust letdown flow to restore Pressurizer level.
Letdown flow is raised to 120 - 126 gpm..
Comment: Critical SAT / UNSAT Evaluator Note After the applicant reports that Charging and Letdown flows are approximately matched, direct him to perform steps 2 and 3.
TASK ELEMENT 2 STANDARD 2. Verify normal indications on ALL Safety Measurement Channel Hot
Leg AND Cold Leg temperature indicators.
Hot and Cold Leg safety temperature indicators are
verified on CP-7.
Comment: SAT / UNSAT TASK ELEMENT 3 STANDARD 3. Determine affected channel(s) by c hecking Reactor Regulating System (RRS) T AVG recorders (RC-ITR-0111 AND RC-ITR-0121).
Both channels are identified as affected by the failure.
Comment: SAT / UNSAT Evaluator Note Inform the applicant that the CRS has completed steps 4 through 8. The CRS has directed him to
evaluate steps 9 and 10.
The applicant may have already identified and reported t he failed instrument prior to reaching this step.
JPM S2 Revision 0 Page 6 of 9 2010 NRC SRO Exam TASK ELEMENT 4 STANDARD Procedure Note: Selecting the non-faulted channel may cause automatic actions to occur if actual level is not at program level.
Note reviewed.
Comment: SAT / UNSAT TASK ELEMENT 5 STANDARD 9. Check Reactor Regulating System (RRS) Hot Leg indicators (RC-ITI-
0111-X AND RC-ITI-0121-X) for abnormal readings.
Hot Leg temperature indicators are verified to be
reading normally.
Comment: SAT / UNSAT TASK ELEMENT 6 STANDARD 10. Check Reactor Regulating System (RRS) Cold Leg indicators (RC-
ITI-0111-Y AND RC-ITI-0121-Y) for abnormal readings.
RC-ITI-0111-Y is identified as failed high.
Comment: This is critical to identify failed instrument so that the correct procedure is performed.
Critical SAT / UNSAT Evaluator Cue Cue the applicant that he is now filling the role of the BOP operator and that another operator is filling
the role of the ATC operator.
JPM S2 Revision 0 Page 7 of 9 2010 NRC SRO Exam Evaluator Cue Direct the applicant as following based on his report: If he correctly identifies that Loop 1 Cold Leg (RC-ITI-0111-Y) is failed, then cue:
"Perform step 10.1 on for TCOLD LOOP 1 selector switch located behind CP-2 and verify setpoint restoration
". o If he incorrectly identifies that Loop 1 Hot Leg (RC-ITI-0111-X) is failed, then cue:
"Perform step 9.1 and select LOOP 2 for TAVE LOOP SELECTOR on BOTH RRS local cabinets (CP-12A AND CP-12B) and verify setpoint restoration
". o If he incorrectly identifies that Loop 2 Hot Leg (RC-ITI-0121-X) is failed, then cue:
"Perform step 9.2 and select LOOP 1 for TAVE LOOP SELECTOR on BOTH RRS local cabinets (CP-12A AND CP-12B) and verify setpoint restoration
". o If he incorrectly identifies that Loop 2 Cold Leg (RC-ITI-0121-Y) is failed, then cue:
"Perform step 10.2 on for TCOLD LOOP 2 selector switch located behind CP-2 and verify setpoint restoration
". Evaluator Note Positioning the selector switch in the next step will not affect clear the malfunction. The applicant should detect and report this additional failure/problem. The indications that are applicable include: Recorder RC-ILR-0110 Setpoint does not return to normal, ~ 33% All 3 Charging Pumps continue operating T AVE Recorders RC-ITR-0111 and 0121 do not return to normal, ~ 550 °F Pressurizer Level Hi/Lo Annunciator H B-1 does not clear TASK ELEMENT 7 STANDARD 10.1 Select presently non-selected position (ALT OR NORM) on TCOLD
LOOP 1 selector switch located behind CP-2, Reactor Control
Loop 1 selector switch is placed in ALT.
Comment: THIS STEP IS NOT CRITICAL Critical SAT / UNSAT
JPM S2 Revision 0 Page 8 of 9 2010 NRC SRO Exam Evaluator Note The applicant should recommend removing the failed in strument at both Reactor Regulating panels.
Request this recommendation if it has not already been made.
Once recommended, direct th e applicant to carry out this action.
After the applicant recommends removing the failed instruments from the RRS, direct the applicant to remove the failed instrument at both RRS panels.
TASK ELEMENT 8 STANDARD 10.1 Select LOOP 2 on BOTH RRS local cabinets (CP-12A AND CP-
12B)
LOOP 2 is selected on both Reactor Regulating
cabinets.
Comment: Critical SAT / UNSAT Evaluator Note End task after the applicant verifies setpoint has been restored to normal, ~33%.
END OF TASK
JPM S2 Revision 0 Page 9 of 9 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-196
Verify the following Malfunctions:
RC18C set at 100% failure on Trigger 1.
Verify the following Overrides:
DI-02B1S-0 overridden to Normal
Place the simulator in RUN
Initiate Trigger 1
Acknowledge panel annunciators
Place the simulator in FREEZE.
Place the simulator to RUN on direction from the evaluator.
Waterford 3 2010 NRC SRO Exam
S3 Reduce RCS Pressure and Establish Pressurizer Level on a Failure of All Charging
Applicant:
Examiner:
JPM S3 Revision 0 Page 2 of 7 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Reduce RCS pressure with Main Spray and restore Pressurizer Level with High Pressure Safety Injection Task Standard: Applicant reduced RCS pressu re to below HPSI Pump shutoff head and established Safety Injection System flow in accordance with OP-
901-112, Charging or Letdown Malfunction.
References:
OP-901-112, Charging or Letdown Malfunction Alternate Path: No Time Critical:No Validation Time: 20 mins.
K/A 006 A1.18, Pressurizer level and pressure Importance Rating 4.0 / 4.3 RO / SRO Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM S3 Revision 0 Page 3 of 7 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-901-112, Charging or Letdown Malfunction
==
Description:==
The applicant will perform the roles of t he ATC and BOP operators for this JPM.
The initial conditions describe that the pl ant has experienced a loss of all Charging capacity. The applicable off normal procedur e directs tripping the reactor and lowering RCS pressure to < 1400 psia. The JPM begins with the reactor tripped and Standard
Post Trip Actions complete. The RCS will be at normal post trip pressure, 2250 psia.
Main Spray will be used to accomplish the pressure reduction. After RCS pressure is
below 1400 psia, a High Pressure Safety Inje ction Pump is started and flow established to restore Pressurizer level.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will
provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM S3 Revision 0 Page 4 of 7 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The crew has entered OP-901-112, Char ging or Letdown Malfunction, due to a piping weld failure downstream of CVC-209, Charging Pumps Header
Isolation. The CRS has directed a reactor trip due to the lowering Pressurizer Level. OP-902-000, Standard Post Trip Actions, have been completed.
INITIATING CUES:
The CRS directs you to perform all of the remaining portions of step 2 in sub-section E 1 , Charging Malfunction, and establish a RCS pressure of 1250 - 1350 psia and restoring Pressurizer level to 30% using HPSI
Pump A.
JPM S3 Revision 0 Page 5 of 7 2010 NRC SRO Exam Evaluator Note Direct the simulator operator to place the simulator in RUN when ready to start.
Evaluator Note The Pressurizer Pressure Low Trip setpoint will need to be reset on 2 different occasions during the reduction of RCS pressure to < 1400 PSIA. There is only 1 occasion listed.
This step becomes applicable when either annunciator K B-16 or K C-16 alarm.
TASK ELEMENT 1 STANDARD 2.3 WHEN PZR PRESSURE LO PRETRIP annunciator alarms, THEN
reset Pressurizer Pressure Low Trip setpoint on ALL FOUR channels.
Pressurizer Pressure low pressure setpoints are reset
prior to receiving a Safety
Injection Actuation Comment: Critical SAT / UNSAT Evaluator Note Since there is no Charging Flow, Pressurizer pressu re must be reduced using Main Spray. Controller RC-IHIC-0100 at CP-2 should be taken to MANUAL and output raised to create Main Spray flow.
TASK ELEMENT 2 STANDARD 2.4 Reduce Pressurizer pressure to < 1400 PSIA.
Pressurizer pressure is reduced to 1250 - 1350 PSIA using Main Spray.
Comment: Critical SAT / UNSAT
JPM S3 Revision 0 Page 6 of 7 2010 NRC SRO Exam Evaluator Note After Pressurizer pressure is < 1400 PSIA, the Main Spray valves should be throttled closed to prevent Pressurizer pressure from dropping below the mi nimum pressure for RCP operation, approximately 1250 PSIA.
TASK ELEMENT 2 STANDARD 2.5 Start ONE available HPSI Pump AND open associated valves as
required to restore Pressurizer level:
HPSI Pump A is running.
Comment: Critical SAT / UNSAT TASK ELEMENT 3 STANDARD 2.5 Start ONE available HPSI Pump AND open associated valves as
required to restore Pressurizer level:
- HPSI Train A
At least 1 HPSI flow control valve is throttled open and
Pressurizer level is restored
to > 25%.
Comment: Critical SAT / UNSAT END OF TASK
JPM S3 Revision 0 Page 7 of 7 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-199
There are no Malfunctions or Overrides for this JPM.
Waterford 3 2010 NRC SRO Exam
S4 Place Shutdown Cooling Train A in Service
Applicant:
Examiner:
JPM S4 Revision 0 Page 2 of 11 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Place Shutdown Cooling Train A in Service Task Standard: Applicant placed Shutdown Coo ling Train A in service in accordance with OP-009-005 and secured Low Pressure Safety Injection Pump
A after SI-405 A failed closed.
References:
OP-009-005, Shutdown Cooling OP-901-131, Shutdown Cooling Malfunction Alternate Path: Yes Time Critical:No Validation Time: 30 mins.
K/A 005 A4.01, Controls and indication for RHR Importance Rating 3.6 / 3.4 pumps RO / SRO Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM S4 Revision 0 Page 3 of 11 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-009-005, Shutdown Cooling
==
Description:==
This task is performed at CP-8. The applicant must place Shutdown Cooling Train A in service. The fault in this task is that SI-405 A, RC Loop 2 SDC Suction Inside Containment Isol, will fail closed, requiring the applicant to secure Low Pressure Safety Injection Pump A. The task can be stopped after LPSI Pump A is secured.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will
provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM S4 Revision 0 Page 4 of 11 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The plant is in Mode 4 Protected Train is A RCS temperature is 280 °F RCS pressure is 340 PSIA Shutdown Cooling Train A has been placed in Standby in accordance with OP-009-005, Shutdown Coo ling, section 5.3.
INITIATING CUES:
The CRS has directed you to place Shutdown Cooling Train A in service in accordance with OP-009-005, section 6.1.
JPM S4 Revision 0 Page 5 of 11 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD Procedure Note: The Shutdown Cooling Train placed in service should be on the Protected Train.
Note reviewed.
Comment:
SAT / UNSAT TASK ELEMENT 2 STANDARD Procedure Caution: Following a design basis tornado event, delaying the initiation of Shutdown Cooling (SDC) for up to 7 days will be
required to ensure the Component Cooling Water System is capable
of removing Reactor Coolant System decay heat. The actual delay
time will depend on UHS damage and ambient temperature and will
be determined by engineering. Emergency Feedwater supports decay
heat removal until SDC can be initiated.
Caution reviewed.
Comment:
SAT / UNSAT TASK ELEMENT 3 STANDARD 6.1.1: Verify Shutdown Cooling Train A has been aligned to Standby
condition in accordance with Section 5.3, Alignment of Shutdown
Cooling Train A to Standby Condition.
Cue sheet lists this as complete.
Comment:
SAT / UNSAT Evaluator Note Any Dry Fan started in SLOW must be declared inoperable and Tech Spec 3.7.4 addressed.
TASK ELEMENT 4 STANDARD 6.1.2: Verify sufficient number of Dry Cooling Tower Fans running to
accept increased heat load on CCW System.
Any fans started must be started in FAST.
Comment: Applicant may ask the CRS how man fans he wants
running. If asked, respond to keep the fans in automatic and verify
they cycle on as required. Any number of fans started is acceptable.
SAT / UNSAT
JPM S4 Revision 0 Page 6 of 11 2010 NRC SRO Exam TASK ELEMENT 5 STANDARD Procedure Caution: CC-963A is required to be maintained open while in Mode 4 to preserve the design temperature basis of piping and
associated components at the CCW outlet of shutdown cooling heat
exchanger A. With CC-963A open, flow through Shutdown Cooling
Heat Exchanger A will be maintained above 2305 gpm.
Caution reviewed.
Comment:
SAT / UNSAT TASK ELEMENT 6 STANDARD 6.1.3: Place Shutdown HX A CCW Flow Control, CC-963A, control switch to Open.
CC-963 A is opened.
Comment:
Critical SAT / UNSAT TASK ELEMENT 7 STANDARD (1) The following Reactor Coolant System limits shall be met for Shutdown Cooling Entry:
RCS temperature limit: < 350 °F
RCS pressure limit: < 392 psia
(2) If Containment Spray Header A Isolation, CS-125 A, is open while
Shutdown Cooling Train A is operating, then Containment Spray A riser may fill and possibly spray water into Containment, due to
leakage past Containment Spray Pump A discharge stop check, CS-
117A. Caution reviewed.
Comment:
SAT / UNSAT
JPM S4 Revision 0 Page 7 of 11 2010 NRC SRO Exam TASK ELEMENT 8 STANDARD 6.1.4: Unlock and Open RC Loop 2 SDC Suction Outside Containment Isol, SI-407A.
SI-407 A is opened.
Comment: Key 133 required.
Critical SAT / UNSAT TASK ELEMENT 9 STANDARD 6.1.5: Notify Radiation Protecti on Department that Shutdown Cooling Train A is being placed in service.
Call is made.
Comment:
SAT / UNSAT TASK ELEMENT 10 STANDARD 6.1.6: Start LPSI Pump A. LPSI Pump A is started.
Comment:
Annunciator LPSI Pump A Flow Lost (Cabinet M, F-3) is expected. It
will clear when the applicant raises flow > 2900 gpm.
Critical SAT / UNSAT TASK ELEMENT 11 STANDARD 6.1.7: Raise Shutdown Cooling flow by Manually adjusting LPSI Header Flow controller 2A/2B, SI-IFIC-0307, output until Shutdown
Cooling Header A Flow indicates 4100 GPM, as indicated by RC Loop
2 Shdn Line Flow Indicator, SI-IFI-1307-A1.
Flow is raised to 4100 gpm.
Comment:
Critical SAT / UNSAT TASK ELEMENT 12 STANDARD 6.1.8: Adjust LPSI Header Flow Controller 2A/2B, SI-IFIC-0307, setpoint potentiometer to 73%, and place controller to AUTO.
Setpoint potentiometer is set to 73%, and controller is
placed in AUTO Comment:
Critical SAT / UNSAT
JPM S4 Revision 0 Page 8 of 11 2010 NRC SRO Exam TASK ELEMENT 13 STANDARD 6.1.9: Verify LPSI Header Flow Controller 2A/2B, SI-IFIC-0307, is maintaining 4100 GPM Shutdown Cooli ng Header A flow, as indicated by RC Loop 2 Shdn Line Flow Indicator, SI-IFI-1307-A1.
Flow is verified.
Comment:
SAT / UNSAT TASK ELEMENT 14 STANDARD Procedure note: If a sample was drawn prior to shutdown and no interim shutdown has occurred where SDC was placed in service and
boron concentration could have been reduced, then sampling is not
required.
Note reviewed.
Comment:
SAT / UNSAT TASK ELEMENT 15 STANDARD 6.1.10: At SM/CRS discretion, direct Chemistry Department to sample Shutdown Cooling Train A for boron concentration.
None Comment:
Evaluator: When requested provide information to applicant that all
required Chemistry requirements are met.
SAT / UNSAT TASK ELEMENT 16 STANDARD Procedure Note: Shutdown Cooling Train A requires one operable Low Pressure Safety Injection Flow Control Valve for the train to be
Note reviewed.
Comment:
SAT / UNSAT
JPM S4 Revision 0 Page 9 of 11 2010 NRC SRO Exam TASK ELEMENT 17 STANDARD Procedure Caution: The Reactor Coolant System shall not exceed the 100 °F per hour cooldown rate of Technical Specification 3.4.8.1.
Caution reviewed.
Comment:
SAT / UNSAT TASK ELEMENT 18 STANDARD 6.1.11.1: Open the following valves: SI-139A LPSI Header to RC Loop 2A Flow Control SI-138A LPSI Header to RC Loop 2B Flow Control SI-139 A and SI-138 A are open. Comment:
Critical SAT / UNSAT TASK ELEMENT 19 STANDARD 6.1.11.2: Throttle Closed RC Loop 2 Shdn Cooling Warmup, SI-135A, until one of the following is within 100°F of Shutdown Cooling Train A
temperature, as indicated by LPSI Pump A Discharge Header
Temperature Indicator, SI-ITI-0351X:
Hot Leg 2 temperature, as indicated by RC Loop 2 Hot Leg
Temperature Indicator, RC-ITI-0122-HA Temperature is within 100 °F Comment:
SI-135 A is a large gate valve with a very long stroke.
SAT / UNSAT
JPM S4 Revision 0 Page 10 of 11 2010 NRC SRO Exam TASK ELEMENT 20 STANDARD 6.1.11.3: Close RC Loop 2 Shdn Cooling Warmup, SI-135 A. SI-135 A is closed Comment:
Critical SAT / UNSAT Evaluator Note Coordinate with the simulator operator to initiate trigger 1 to close SI-405 A.
TASK ELEMENT 21 STANDARD Secure LPSI Pump A LPSI Pump A is off.
Comment:
This is an immediate operator action IAW OP-901-131 D.1 Critical SAT / UNSAT
END OF TASK
JPM S4 Revision 0 Page 11 of 11 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-197
Verify the following Malfunctions: Si23a for SI-405 A
Coordinate with the examiner so that when SI-135 A is fully closed at step 6.1.11.3, Trigger 1 is init iated to close SI-405 A.
Waterford 3 2010 NRC SRO Exam
S5 Synchronize the Main Generator to the Grid
Applicant:
Examiner:
JPM S5 Revision 0 Page 2 of 14 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Synchronize the Main Generator to the grid in accordance with OP-010-004, Power Operations.
Task Standard: The Main Generator was synch ronized to the grid with both Output Breakers closed in accordance with OP-010-004, Power Operations.
References:
OP-010-004, Power Operations Alternate Path: Yes Time Critical:No Validation Time: 30 mins.
K/A 062 A4.07, Synchronizing and paralleling of Importance Rating 3.1 / 3.1 different AC supplies RO / SRO Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM S5 Revision 0 Page 3 of 14 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-010-004, Power Operations
==
Description:==
This JPM takes place at CP-1. The applicant will start the task with all Main
Turbine testing complete and the unit running at 1800 rpm. The cue will direct the
applicant to perform an auto synchronization of the Main Generator. The auto synchronization will fail to close either Main Generator Output Breaker. The applicant will then perform a manual synchronization.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will
provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM S5 Revision 0 Page 4 of 14 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
Plant is in Mode 1 at 15% power following a refueling outage All Main Turbine testing has been completed. Watch standers are standing by at the Main Transformers and the Generator Auxiliaries area. The Load Dispatcher and Southern Cont rol have been notified that we are coming on line.
INITIATING CUES:
You are directed to synchronize the Main Generator to the grid using the auto synchronization circuit in accordanc e with OP-010-004, Power Operations.
JPM S5 Revision 0 Page 5 of 14 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD Procedure Note: Monitor Main Transformer A(B) during the initial energization and loading phases of the transformer for indications of static discharging as evidenced by unusual bumping, thudding, crackling, popping, or similar noises. Notify Sy stem Engineering immediately if any unusual noises are emanating from the transformer tank.
Note reviewed.
Comment: SAT / UNSAT TASK ELEMENT 2 STANDARD 9.1.22 Close Generator Exciter Field Breaker on CP-1 to excite
Generator field.
Breaker closed.
Comment: Critical SAT / UNSAT Evaluator Note Local watchstander reports no unusual noises at the Main Transformers.
TASK ELEMENT 3 STANDARD 9.1.23 Locally verify Main Transformer Cooling System operating with no
unusual noises.
Verification complete.
Comment: SAT / UNSAT Evaluator Note Local watchstander reports Isophase Bus Duct Cooling Fan is operating normally.
JPM S5 Revision 0 Page 6 of 14 2010 NRC SRO Exam TASK ELEMENT 4 STANDARD 9.1.24 Locally verify Generator Isophase Bus Duct Cooling Fan selected to Auto has started.
Verification complete.
Comment: SAT / UNSAT TASK ELEMENT 5 STANDARD Procedure Caution: Do not leave synchronizer energized for longer than 5 minutes to prevent relay damage. Ensure that only one synchronizer circuit is energized at any time to prevent synchronizer malfunction.
Caution reviewed.
Comment: SAT / UNSAT TASK ELEMENT 6 STANDARD 9.1.25 Place Synchronizer Switch for first Generator Output Breaker to
Manual, and verify Generator Running, GEN-EM-2210A, and Incoming, GEN-EM-2210B, voltmeters indicate voltage.
First Generator Output Breaker is placed in
MANUAL. Comment: Critical SAT / UNSAT TASK ELEMENT 7 STANDARD Procedure Note: Voltage Regulator operation should be in accordance
with Attachment 9.8, Entergy Guidelines Regarding Generator Voltage
Regulator and Abnormal Frequency Operation.
Note reviewed.
Comment: SAT / UNSAT
JPM S5 Revision 0 Page 7 of 14 2010 NRC SRO Exam TASK ELEMENT 8 STANDARD Procedure Caution: Exciter field am ps shall not exceed 45 amps when matching incoming and running voltages with the base voltage adjuster.
Caution reviewed.
Comment: SAT / UNSAT TASK ELEMENT 9 STANDARD 9.1.26 Using Base Voltage Adjust Switch, raise Incoming (Generator)
voltage, GEN-EM-2210B, to match Running (Grid) voltage, GEN-EM-
2210A. Voltage adjusted.
Comment: Critical SAT / UNSAT TASK ELEMENT 10 STANDARD 9.1.27 Place Synchronizer Switch for first Generator Output Breaker in
Off. First Generator Output Breaker is placed in OFF.
Comment: It does not matter which breaker is closed first.
Critical SAT / UNSAT TASK ELEMENT 11 STANDARD 9.1.28 Place Auto Voltage Regulator switch in Test.
Voltage Regulator switch is in TEST. Comment: WHY IS THIS CRITICAL??? IF deviation already at zero then not performing this will not affect the JPM outcome.
Critical SAT / UNSAT
JPM S5 Revision 0 Page 8 of 14 2010 NRC SRO Exam TASK ELEMENT 12 STANDARD 9.1.29 Verify Voltage Regulator Balance needle deviates from zero in both directions, by rotating Voltage Regulator Adjust switch clockwise and counterclockwise.
Balance needle adjusted.
Comment: SAT / UNSAT TASK ELEMENT 13 STANDARD 9.1.30 Adjust Volt Reg Balance to zero, and place Auto Voltage Regulator switch to On.
Auto Voltage Regulator switch is in ON.
Comment: Critical SAT / UNSAT TASK ELEMENT 14 STANDARD 9.1.31 Adjust Turbine speed to 1801-1802 RPM, at SM/CRS discretion, in accordance with OP-005-007, Main Turbine Generator.
Speed verified.
Comment: IF asked- provide a specific value SAT / UNSAT TASK ELEMENT 15 STANDARD 9.1.32 Notify Load Dispatcher and Southern Control unit is ready to go
on line. Notification given in cue.
Comment: SAT / UNSAT TASK ELEMENT 16 STANDARD 9.1.33.1 Verify Auto Synchronization is disabled by placing Gen Bkr Auto Synch Switch in Disable.
Verification complete.
Comment: SAT / UNSAT
JPM S5 Revision 0 Page 9 of 14 2010 NRC SRO Exam TASK ELEMENT 17 STANDARD Procedure Note: Auto Synchronizer controls Generator voltage when an Auto Synchronizer circuit is placed in service. It may take several
revolutions (~ three) of the synchroscope before the Synch lights illuminate to allow circuit to adjust voltage and frequency.
Note reviewed.
Comment: SAT / UNSAT TASK ELEMENT 18 STANDARD 9.1.33.2 Place Synchronizer for first Generator Output Breaker to be
closed in Auto.
Switch is in AUTO.
Comment: Critical SAT / UNSAT TASK ELEMENT 19 STANDARD Procedure Note: Main Generator Voltage is matched with Switchyard
Voltage when Incoming and Running Voltage needles are opposite one another. Note reviewed.
Comment: SAT / UNSAT TASK ELEMENT 20 STANDARD 9.1.33.3 Verify proper operation of Main Generator Auto Synchronization
circuit by all of the following: Synchroscope rotating slowly in the fast direction. (< 1 rev per 10 sec) Synch check lights are illuminated between 5 till and 12 o'clock. Incoming voltage, GEN-EM-2210B, approximately equal to running voltage, GEN-EM-2210A.
Verification complete.
Comment: SAT / UNSAT
JPM S5 Revision 0 Page 10 of 14 2010 NRC SRO Exam TASK ELEMENT 21 STANDARD Procedure Note: Placing Gen Bkr Auto Synch switch in Enable allows Generator Output Breaker to close automatically. The Gen Bkr Auto
Synch must be held in Enable until GOB closes.
Note reviewed.
Comment: SAT / UNSAT TASK ELEMENT 22 STANDARD 9.1.33.4 When Synchroscope passes "15 after 12 o'clock" position and Synch Check lights are extinguished, then place and hold Gen Bkr Auto Synch switch in Enable.
Switch is in ENABLE.
Comment: Critical SAT / UNSAT Evaluator Note The fault will prevent the Generator Output Breaker from closing. The applicant should eventually
release the Auto Sync Switch and report the failure to the CRS.
Direct the applicant as the CRS to sync the Main Generator in MANUAL in accordance with step 9.1.34. TASK ELEMENT 23 STANDARD 9.1.33.7 Turn Synchronizer to OFF. Switch is in OFF.
Comment: Critical SAT / UNSAT TASK ELEMENT 24 STANDARD 9.1.34.1 Place Synchronizer in Manual. Switch is in MANUAL.
Comment: Critical SAT / UNSAT
JPM S5 Revision 0 Page 11 of 14 2010 NRC SRO Exam TASK ELEMENT 25 STANDARD Procedure Note: Main Generator Voltage is matched with Switchyard Voltage when Incoming and Running voltage needles are opposite one
another. Note reviewed.
Comment: SAT / UNSAT TASK ELEMENT 26 STANDARD 9.1.34.2 Verify Incoming voltage, GE N-EM-2210B, is slightly higher than Running Voltage, GEN-EM-2210A.
Verification complete.
Comment: SAT / UNSAT TASK ELEMENT 27 STANDARD 9.1.34.3 Verify Synchroscope is rotating slowly in the fast direction. Verification complete.
Comment: SAT / UNSAT TASK ELEMENT 28 STANDARD 9.1.34.4 Verify one complete revolution of the synchroscope every 15 seconds or greater, before attempting to close the Generator Output Breaker. Verification complete.
Comment: SAT / UNSAT TASK ELEMENT 29 STANDARD Procedure Caution: Attempt to close a generator output breaker only at
12 o'clock. Failure to do this could result in paralleling the generator out
of phase.
Caution reviewed.
Comment: SAT / UNSAT
JPM S5 Revision 0 Page 12 of 14 2010 NRC SRO Exam TASK ELEMENT 30 STANDARD 9.1.34.5 When Synchroscope reaches slightly before 12 o' clock position and Synch Check lights are On, then Close the first Generator Output Breaker. Generator Output Breaker is CLOSED.
Comment: Critical SAT / UNSAT TASK ELEMENT 31 STANDARD 9.1.34.6 Turn Synchronizer Switch to OFF. Switch is in OFF.
Comment: Critical SAT / UNSAT TASK ELEMENT 32 STANDARD 9.1.35 Verify Generator has picked up approximately 5% load ( 62 Mwe). Verification complete.
Comment: SAT / UNSAT TASK ELEMENT 33 STANDARD Procedure Note: Prior to closing the second Generator Output Breaker, wait at least 20 seconds after placing synchronizer in Manual to allow
Synch Check Relay to realign.
Note reviewed.
Comment: SAT / UNSAT TASK ELEMENT 34 STANDARD 9.1.36.1 Place Synchronizer in Manual for remaining Generator Output
Breaker. Switch is in MANUAL.
Comment: Critical SAT / UNSAT
JPM S5 Revision 0 Page 13 of 14 2010 NRC SRO Exam TASK ELEMENT 35 STANDARD 9.1.36.2 Close the Generator Output Breaker.
Generator Output Breaker is CLOSED.
Comment: Critical SAT / UNSAT TASK ELEMENT 36 STANDARD 9.1.36.3 Turn the Synchronizer switch to Off Switch is in OFF.
Comment: Is this critical (i.e. damage to equipment)??
Critical SAT / UNSAT END OF TASK
JPM S5 Revision 0 Page 14 of 14 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-196
There are no Malfunctions for this JPM.
Verify the following Overrides:
o DI-01A06S08-1 overridden to OFF
Waterford 3 2010 NRC SRO Exam
S6 Reset Containment Spray Actuation
Applicant:
Examiner:
JPM S6 Revision 0 Page 2 of 8 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Reset Containment Spray Actuation
Task Standard: CSAS initiation and actuation were reset in accordance with OP-902-009, Standard Appendices, Appendix 5 - E.
References:
OP-902-009, Standar d Appendices, Appendix 5 - E OP-902-004, Excess Steam Demand Recovery Alternate Path: No Time Critical:No Validation Time: 10 mins.
K/A 012 A4.04, Bistable, trips, reset and test switches Importance Rating 3.3 / 3.3 RO / SRO Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM S6 Revision 0 Page 3 of 8 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-902-009, Standard Appendices, Appendix 5 - E OP-902-004, Excess Steam Demand Recovery
==
Description:==
The JPM begins in an Excess Steam Demand event, after the applicable Steam
Generator has blown dry. Containment Spray termination criteria are met. The applicant will be directed to reset CSAS. Actions for this task take place at CP-8, CP-10 A through D, and CP-33.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will
provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM S6 Revision 0 Page 4 of 8 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
An Excess Steam Demand event has occurred
. The crew is implementing OP-902-004, Excess Steam Demand Recovery The conditions of step 44 of OP
-902-004 have been verified to be met
. Do not give this. If the applicant wants, he can verify it in the control room using plant conditions (Step 27, not 44).
Containment Spray is NOT needed for iodine removal
.
INITIATING CUES:
The CRS directs you , the BOP operator, to perform OP-902-009, Standard Appendices, Appendix 5 - E and reset CSAS.
JPM S6 Revision 0 Page 5 of 8 2010 NRC SRO Exam Evaluator Note When Applicant is ready, cue the simulator operator to place the simulator in RUN.
TASK ELEMENT 1 STANDARD 1.1 Place control switches for the following valves to CLOSE: CC-641, CCW RCP INLET OUTSIDE ISOL CC-710, CCW RCP OUTLET INSIDE ISOL CC-713, CCW RCP OUTLET OUTSIDE ISOL All 3 valve control switches are in CLOSED.
Comment: Critical SAT / UNSAT Evaluator Note To Reset CSAS Initiation relays, the following 4 steps must be performed on Channels A, B, C, and D.
TASK ELEMENT 2 STANDARD 1.2.a Place the Reset Permissive switch to "UNLK" position. (CP-10)
The applicable Reset Permissive switch is in
UNLK. Comment: Applicant will need key 218 for this manipulation.
Critical SAT / UNSAT TASK ELEMENT 3 STANDARD 1.2.b Press CSAS Reset pushbutton.
CSAS Reset pushbutton is pressed. Comment: Critical SAT / UNSAT
JPM S6 Revision 0 Page 6 of 8 2010 NRC SRO Exam TASK ELEMENT 4 STANDARD 1.2.c Verify the initiation relay indicator lit on the ENGINEERED SAFETY FEATURES SYSTEM mimic.
Verification complete.
Comment: SAT / UNSAT TASK ELEMENT 5 STANDARD 1.2.d Place the Reset permissive switch to LK position The applicable Reset Permissive switch is in the
LK position.
Comment: This sequence must be repeated for Channels A - D.
Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 1.3.a Reset CSAS actuation logic on BOTH trains as follows: Press the CSAS Reset pushbuttons. (CP-33)
CSAS Reset pushbuttons A
& B have been de-pressed.
Comment: There are 2 buttons on CP-33 that must be pressed, 1 for Train A and 1 for Train B.
Critical SAT / UNSAT TASK ELEMENT 7 STANDARD 1.3.b Verify the actuation relay indicator lit on the ENGINEERED SAFETY FEATURES SYSTEM mimic. (CP-10)
CP-10 verification is complete.
Comment: SAT / UNSAT
JPM S6 Revision 0 Page 7 of 8 2010 NRC SRO Exam TASK ELEMENT 8 STANDARD 1.4 Stop ONE CS pump at a time.
One Containment Spray Pump is secured.
Comment: Critical SAT / UNSAT TASK ELEMENT 9 STANDARD 1.5 IF a CS pump is operating, THEN stop the remaining CS pump.
Second Containment Spray Pump is secured.
Comment: Critical SAT / UNSAT TASK ELEMENT 10 STANDARD 1.6 Close the following Containment Spray valves: CS-125 A, CNTMT SPRAY HEADER A ISOL CS-125 B, CNTMT SPRAY HEADER B ISOL CS-125 A and CS-125 B are closed.
Comment: Control switch must be taken to OPEN and then to CLOSE.
Critical SAT / UNSAT TASK ELEMENT 11 STANDARD 1.7 Place BOTH Containment Spray pump control switches to normal position.
Both Containment Spray pump control switches are
in the normal position.
Comment: Critical SAT / UNSAT
END OF TASK
JPM S6 Revision 0 Page 8 of 8 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-198
Verify the following Malfunctions:
o Ms11b 25%
o Ch09 50%
Place the Simulator in Run on the lead examiner's cue.
Waterford 3 2010 NRC SRO Exam
S7 Waste Condensate Tank Discharge
Applicant:
Examiner:
JPM S7 Revision 0 Page 2 of 7 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Waste Condensate Tank Discharge
Task Standard: Applicant initiated Waste Condensate Tank release in accordance with OP-007-004, Liquid Waste M anagement System, and secured the release after the flow controller failed to maximum output.
References:
OP-007-004, Liqui d Waste Management System CE-003-514, Liquid Radioactive Waste Release Permit (Computer)
Alternate Path: Yes Time Critical:No Validation Time: 15 mins.
K/A 068 A4.03, Stoppage of releases if limits Importance Rating 3.9 / 3.8 exceeded RO / SRO Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM S7 Revision 0 Page 3 of 7 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-007-004, Liquid Wa ste Management System Discharge Permit for Waste Condensate Tank A
==
Description:==
The applicant will be tasked with initia ting a discharge of Waste Condensate Tank A. The cue will provide indicate that the operator in the field has completed all required lineups and is standing by. When the app licant initiates flow, the flow controller output will fail high, causing discharge flow to exceed the 50 gpm permit flow limit. The flow controller will not be capable of securing flow. The applicant will stop discharge
flow by closing the discharge isolation valves.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state t he task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will
provide initiating cues and reports on other ac tions when directed by you. Indicate to me when you understand your assigned task.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM S7 Revision 0 Page 4 of 7 2010 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
Waste Condensate Tank A has been prepared for discharge. The RCA Watch reports that he has completed step 6.10.6 of OP-007-004, Liquid Waste Management System, and that Attachment 11.4, Waste Condensate Tank Discharge Checklist, is complete.
INITIATING CUES:
The RCA Watch reports that he has completed step 6.10.6 in OP
-007-004, Liquid Waste Management System, and that Attachment 11.4, Waste Condensate Tank Discharge Checklist , is complete.
The Control Room Supervisor directs you to commence discharging Waste Condensate Tank A , starting at step 6.10.7 of OP-007-004 LWMS.
JPM S7 Revision 0 Page 5 of 7 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD 6.10.7 On CP-4, Reset Liquid Waste Discharge Flow Integrator to zero. Integrator is reset to zero.
Comment: Critical SAT / UNSAT TASK ELEMENT 2 STANDARD 6.10.8 Record WCT level and Liquid Waste Discharge Integrator reading
on Liquid Release Permit.
Reading is recorded on the Release Permit.
Comment: Critical SAT / UNSAT TASK ELEMENT 3 STANDARD 6.10.9 Verify Liquid Waste Discharge Flow Controller, LWM-IFIC-0647, in Manual with 0% output.
Verification complete.
Comment: SAT / UNSAT TASK ELEMENT 4 STANDARD Procedure Caution: If Circulating Water flow is reduced to less than that
required by the discharge permit, then discharge shall be secured
immediately.
Caution reviewed.
Comment: SAT / UNSAT
JPM S7 Revision 0 Page 6 of 7 2010 NRC SRO Exam Evaluator Note The combined control switch on CP-4 will open LWM-441 and give an open permissive to LWM-442.
LWM-442 is operated using controller LWM-IFIC-0647, also on CP-4.
What about LWM-315 A(B) in the procedure step 6.10.10.1??
Evaluator Note When flow rises above the trigger setpoint, the output of the controller will fail in the raise position. Flow will rise above the Permit limit of 50 gpm. The applicant will not be able to secure flow with the
controller. The applicant will be required to secure flow by closing LWM-441 and LWM-442 using the control switch.
TASK ELEMENT 5 STANDARD 6.10.10 To start discharging WCT, momentarily position Liquid Waste
Condensate Flow Control handswitch, LWM-441 and LWM-442, to Open
and adjust flow using Liquid Waste Condensate Flow Controller, LWM-IFIC-0647, not to exceed value specified on Liquid Release Permit.
LWM-441 is opened using control switch.
LWM-442 is throttled open using controller.
?? Procedure states: use LWM-315 A(B) as necessary to achieve desired flow.
Comment: The following step is the alternate path.
Critical SAT / UNSAT Additional step: Attempt to stop flow using IFIC-0647 TASK ELEMENT 6 STANDARD Position Liquid Waste Condensate Flow Control Switch for LWM-441 and LWM-442 to Closed and verify LWM-441 and LWM-442 are closed.
LWM-441 and LWM-442 are closed.
Comment: Critical SAT / UNSAT END OF TASK
JPM S7 Revision 0 Page 7 of 7 2010 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-197
There are no Malfunctions for this JPM.
Verify the following Overrides:
o DI-04A3A12C-3 is overridden to PUSH
Verify the following Event Trigger settings:
Trigger 7 is set as zaowdlwmifif0647(1)>0.2
Waterford 3 2010 NRC SRO Exam
P1 Reset Emergency Feedwater Pump AB
Applicant:
Examiner:
JPM P1 Revision 0 Page 2 of 7 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Reset overspeed device on Emergency Feedwater Pump AB during a Station Blackout.
Task Standard: The overspeed device on Emergency Feedwater Pump AB was reset in accordance with OP-902-005, Station Blackout Recovery.
References:
OP-902-005, Station Blackout Recovery Alternate Path: No Time Critical:No Validation Time: 10 mins.
K/A 061 A2.04, Pump failure or improper operation Importance Rating 3.4 / 3.8 RO / SRO Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM P1 Revision 0 Page 3 of 7 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-902-005, Station Blackout Recovery
==
Description:==
This task takes place in the RCA. The task takes place during a simulated
Station Blackout. This requires the applicant to simulate manual operation of MS-416, Emergency Feedwater Pump AB Trip Valve.
All components are located on the -35 elevation. This JPM takes place in a lo cation with numerous pipes and supports that are bump hazards, but no special PPE will be r equired for this task. There are no special radiological requirements to perform this task.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated , do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when
directed by you. Indicate to me when you understand your assigned task.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM P1 Revision 0 Page 4 of 7 2010 NRC Walk Through Exam APPLICANT CUE SHEET
Do Not Manipulate Any Plant Components
(TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
A Station Blackout event is in progress Emergency Feedwater Pump AB has tripped on an overspeed condition The Control Room has closed MS-401 A and MS-401 B. The Control Room has cycled MS-407 Open and Closed to depressurize the steam header.
Remove this bullet if this step is done locally per 10.1.b.
INITIATING CUES:
The CRS directs you to reset Emergency Feedwater Pump AB in accordance with OP-902-005, Step 10 RNO.
JPM P1 Revision 0 Page 5 of 7 2010 NRC Walk Through Exam TASK ELEMENT 1 STANDARD 10.1.a. Close BOTH PUMP AB TURB STM SUPPLY valves: MS-401 A and MS-401 B.
Provided in the cue.
Comment: SAT / UNSAT TASK ELEMENT 2 STANDARD 10.1.b. Locally verify the steam supply header depressurized using MS-407, EFW Pump AB Drip Pot Normal Drain Bypass.
Provided in cue.
Comment: 10.1.b states locally. Should this be done locally by the applicant?? Provide examiner cue-SAT / UNSAT Evaluator Note MS-416 trips closed on an overpseed. In a Station Blackout, MS-416 MOV must be manually operated
in the closed direction to position the valve for reset.
The physical indication as this operation is performed would be the trip bar moving from a low, tripped position up to the trip latch.
Evaluator Note MS-416 in the tripped position before and after MOV is manually operated:
JPM P1 Revision 0 Page 6 of 7 2010 NRC Walk Through Exam TASK ELEMENT 3 STANDARD 10.1.c. Locally close MS 416, EFW Pump AB Turbine Stop Valve.
MS-416 is operated in the closed direction. EXAMINER CUE: Valve latching mechanism is full up.
Comment: Critical SAT / UNSAT Evaluator Note The overspeed device is reset by moving the trip bar towards MS-416.
TASK ELEMENT 4 STANDARD 10.1.d. Verify mechanical Overspeed reset. Overspeed device is reset. EXAMINER CUE: A cue to give to applicant for this task. OR A PICTURE. Comment: Critical SAT / UNSAT
JPM P1 Revision 0 Page 7 of 7 2010 NRC Walk Through Exam TASK ELEMENT 5 STANDARD 10.1.e. Locally open MS 416, EFW Pump AB Turbine Stop Valve.
MS-416 is manually opened. EXAMINER CUE: Valve is fully CCW and valve stem is up.
Comment: Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 10.1.f. Open BOTH PUMP AB TURB STM SUPPLY valves. MS 401A MS 401B Communication made to the Control Room.
Comment: SAT / UNSAT END OF TASK
Waterford 3 2010 NRC SRO Exam
P2 Aligning Spent Fuel Pool Purification
Applicant:
Examiner:
THIS JPM DOES NOT SEEM DISCRIMINATING AND HAS A LOW IR.
PLEASE HAVE ANOTHER JPM AVAILABLE TO REPLACE THIS (SECURE FROM RWSP PURIFICATION OR PLACE FPC IN RWSP PURIFICATION). WE WILL RUN THIS AND THE REPLACEMENT DURING VALIDATION.
JPM P2 Revision 0 Page 2 of 8 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Place the Spent Fuel Pool on purification in accordance with OP-002-006, Fuel Pool Cooling and Purification Task Standard: The Spent Fuel Pool was a ligned for purification in accordance with OP-002-006, Fuel Pool Cooling and Purification.
References:
OP-002-006, Fuel Pool Cooling and Purification Alternate Path: No Time Critical:No Validation Time: 15 mins.
K/A 033 K4.02, Maintenance of Spent Fuel Pool Importance Rating 2.5 / 2.7 cleanliness RO / SRO Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM P2 Revision 0 Page 3 of 8 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-002-006, Fuel Pool Cooling and Purification
==
Description:==
This task takes place in the RCA, specific to the Fuel Handling Building. All
components are located on the +1 elevation of the Fuel Handling Building. No special PPE will be required for this task. There are no special radiological requirements to perform this task.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated , do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when
directed by you. Indicate to me when you understand your assigned task.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM P2 Revision 0 Page 4 of 8 2010 NRC SRO Exam APPLICANT CUE SHEET
Do Not Manipulate Any Plant Components
(TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
Refueling Water Storage Pool Purification has been in service for 2 days. Refueling Water Storage Pool Purification was secured 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> ago.
INITIATING CUES:
The CRS directs you to place the Spent Fuel Pool on purification. No system venting is required.
JPM P2 Revision 0 Page 5 of 8 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD 6.4.1 Verify Refueling Water Storage Pool Purification is secured in accordance with Section 6.7, Securing RWSP Purification.
Provided in cue.
Comment: SAT / UNSAT TASK ELEMENT 2 STANDARD 6.4.2 Throttle Fuel Pool Purif Pump Discharge Isolation, FS-318, to 2 turns Open.
FS-318 is throttled 2 turns open. EXAMINER CUE: Valve fully clockwise and then CCW 2 turns.
Comment: Critical SAT / UNSAT TASK ELEMENT 3 STANDARD 6.4.3 Close Fuel Pool Purification Pump breaker, FS-EBKR-314A-5D. Breaker is closed.
EXAMINER CUE: Breaker ON (or up etc.)
Comment: The 314 A Bus is located on the +1 elevation of the Fuel Handling Building.
Critical SAT / UNSAT TASK ELEMENT 4 STANDARD Procedure Note.
(1) Fuel Pool Purification Pump will not start if Fuel Pool level is <41' 6".
(2) Fuel Pool Purification com ponents should be bypassed as necessary to maintain differential pressures less than or equal to the Maximum DP
limit listed below. Chemistry Department should be notified when any of
these components are bypassed (refer to Limitation 3.2.6 for applicable
bypass valves): Fuel Pool Purification Filter DP: 25 PSID Fuel Pool Ion Exchanger Outlet Header Strainer DP: 10 PSID Combined DP of Fuel Pool Ion Exchanger and Fuel Pool Ion Exchanger Outlet Header Strainer (aligned to sense differential
pressure across both): 25 PSID Note reviewed.
JPM P2 Revision 0 Page 6 of 8 2010 NRC SRO Exam Comment: SAT / UNSAT
JPM P2 Revision 0 Page 7 of 8 2010 NRC SRO Exam TASK ELEMENT 5 STANDARD Procedure caution.
If the Spent Fuel Pool temper ature (PMC PIDs A47004 and A47005) rises to >
135 F at any time during purification, then the Fuel Pool Purification Pump must be stopped or Fuel Pool ion exchanger resin
damage may occur.
Caution reviewed.
Comment: SAT / UNSAT TASK ELEMENT 6 STANDARD 6.4.4 Start the Fuel Pool Purification Pump. Pump started. EXAMINER CUE: Red light ON, pump amps, flow, noise etc.
Comment: The control switch for the Fuel Pool Purification Pump is located in the Fuel Pool Purification cubicle.
Critical SAT / UNSAT TASK ELEMENT 7 STANDARD 6.4.5 If venting is required, then vent from the following valves: FS-319 Fuel Pool Purif Pump Discharge Header Vent FS-324 Fuel Pool Purif Filter Vent FS-344 Fuel Pool Ion E xchanger Outlet Header Vent Provided in the cue.
Comment: SAT / UNSAT TASK ELEMENT 8 STANDARD 6.4.6 Open Fuel Pool Purif Pump Discharge Isolation, FS-318. FS-318 is full open. EXAMINER CUE: Fully clockwise Comment: Critical SAT / UNSAT
JPM P2 Revision 0 Page 8 of 8 2010 NRC SRO Exam END OF TASK Waterford 3 2010 NRC SRO Exam
P3 SUPS 014 AB Operation
Applicant:
Examiner:
JPM P3 Revision 0 Page 2 of 9 2010 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Transfer SUPS 014 AB from Alternate to Normal AC power
Task Standard: SUPS 014 AB was transferr ed from Alternate to Normal AC alignment in accordance with OP-006-005, Inverters and Distribution.
References:
OP-006-005, Inverters and Distribution Alternate Path: Yes Time Critical:No Validation Time: 20 mins.
K/A 062 A3.04, Operation of inverter Importance Rating 2.7 / 2.9 RO / SRO Applicant:
Time Start: Time Finish:
Performance Time: minutes
Performance Rating: SAT UNSAT Comments:
Examiner: Date: Signature
JPM P3 Revision 0 Page 3 of 9 2010 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-006-005, Inverters and Distribution
==
Description:==
SUPS 014 AB will be simulated in the Alternate AC power alignment. Applicant
will transfer SUPS 014 AB to the Normal AC alignment. All steps will be simulated in
Switchgear Room A. No specia l PPE will be required for this task.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated , do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when
directed by you. Indicate to me when you understand your assigned task.
Read the Initial Condition and Cues from t he colored Applicant Cue Sheet, and then give the cue sheet to the applicant.
JPM P3 Revision 0 Page 4 of 9 2010 NRC SRO Exam APPLICANT CUE SHEET
Do Not Manipulate Any Plant Components
(TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
SUPS 014 AB is in the Alternate AC alignment The inverter was isolated in accordance with OP-006-005, Inverters and Distribution, steps Step 6.5.2.7.
INITIATING CUES:
The CRS directs you to place SUPS 014 AB in the Normal AC alignment in accordance with OP-006-005, Inverters and Distribution, section 6.5.3.
PLACE THIS SHEET AT END OF JPM JPM P3 Revision 0 Page 5 of 9 2010 NRC SRO Exam TASK ELEMENT 1 STANDARD 6.5.3.1.1 Place Normal Feeder breaker to ON. Breaker is ON.
Comment: Critical SAT / UNSAT TASK ELEMENT 2 STANDARD 6.5.3.1.2 Verify Inverter Input Voltage > 121 VDC, then place Emergency Feeder breaker to ON.
Breaker is ON.
Comment: Critical SAT / UNSAT TASK ELEMENT 3 STANDARD 6.5.3.1.3 Depress and release Inverter Operate pushbutton.
Pushbutton is pressed and released.
Comment: Critical SAT / UNSAT TASK ELEMENT 4 STANDARD 6.5.3.2 Verify SUPS 014AB Stat ic Switch Retransfer toggle switch in INHIBIT.
Verification complete.
Comment: SAT / UNSAT
JPM P3 Revision 0 Page 6 of 9 2010 NRC SRO Exam TASK ELEMENT 5 STANDARD 6.5.3.3 Place SUPS 014AB Al ternate Feeder breaker to ON. Breaker is ON.
Comment: Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 6.5.3.4 Depress and releas e SUPS 014AB Static Switch Transfer Test pushbutton.
Test pushbutton depressed and
released.
Comment: Critical SAT / UNSAT TASK ELEMENT 7 STANDARD 6.5.3.4.1 Verify Static Switch On Reserve light Illuminates. Verification complete.
Comment: SAT / UNSAT TASK ELEMENT 8 STANDARD 6.5.3.5 Depress and release SUPS 014AB Lamp Test/Reset pushbutton.
Pushbutton depressed and released.
Comment: Critical SAT / UNSAT
JPM P3 Revision 0 Page 7 of 9 2010 NRC SRO Exam TASK ELEMENT 9 STANDARD 6.5.3.5.1 Verify Static Switch On Reserve light remains Illuminated.
Verification complete.
Comment: Critical SAT / UNSAT TASK ELEMENT 10 STANDARD 6.5.3.6 Place SUPS 014AB Ou tput To PDP014AB breaker to ON. Breaker is ON.
Comment: Critical SAT / UNSAT TASK ELEMENT 11 STANDARD 6.5.3.7 Place SUPS 014AB Bypass breaker to OFF. Breaker is OFF.
Comment: Critical SAT / UNSAT TASK ELEMENT 12 STANDARD 6.5.3.8 Place SUPS 014AB AC Voltage Select Switch to INVERTER.
Select Switch is in INVERTER.
Comment: Critical SAT / UNSAT
JPM P3 Revision 0 Page 8 of 9 2010 NRC SRO Exam Evaluator Note When applicant observes the SUPS Output Voltage meter, provide indication of zero volts.
If the applicant presses the Operate pushbutton, prov ide the indications provided in Task Element 13.
If the applicant does not press the Operate pushbu tton, then provide the indication that the Static Swit ch On Reserve light is still illuminated at Task Element 16.
TASK ELEMENT 13 STANDARD 6.5.3.9 If no voltage is indi cated, then depress and release SUPS 014AB Inverter Operate pushbutton, and verify the following: Inverter Phase Locked light Illuminated Inverter Output voltage CN ~120 VAC (118.8 to 121.2 VAC) Inverter Output voltage AN ~120 VAC (118.8 to 121.2 VAC) Inverter Output voltage BN ~120 VAC (118.8 to 121.2 VAC) Inverter Output frequency ~60 Hz (59.97 to 60.03 Hz)
Observes no voltage and presses and
releases the Operate
pushbutton.
Comment: Critical SAT / UNSAT TASK ELEMENT 14 STANDARD 6.5.3.10 Place SUPS 014AB Stat ic Switch Retransfer toggle switch to AUTO.
Toggle Switch is in Auto. Comment: Critical SAT / UNSAT
JPM P3 Revision 0 Page 9 of 9 2010 NRC SRO Exam TASK ELEMENT 15 STANDARD 6.5.3.11 After approximately 30 seconds, depress and release SUPS 014AB Lamp Test/Reset pushbutton.
Pushbutton pressed and released.
Comment: Critical SAT / UNSAT TASK ELEMENT 16 STANDARD 6.5.3.11.1 Verify Static Switch On Reserve light Extinguished.
Verification complete.
Comment: Critical SAT / UNSAT END OF TASK
Appendix D Scenario Outline Form ES-D-1 Scenario 1 Rev 1 Facility: WATERFORD 3 Scenario No.: 1 Op Test No.:
NRC Examiners: Operators: Initial Conditions: 100%, 125 EFPD, AB buses aligned to Train B Protected Train is B Emergency Diesel Generator A is out of service.
Turnover: Maintain 100 % power Event No. Malf. No. Event Type* Event Description 1 H_105 I - ATC I - SRO Remove Reactor Power Cutback from service in accordance with OP-004-015. 2 RC22F2 TS - SRO I - SRO Pressurizer pressure instrument RC-IPI-0102 B fails low.
3 SG01B CV02C TS - SRO C - SRO C - ATC Steam Generator 2 tube leakage Charging Pump AB fails to auto start 4 N/A R- ATC N-BOP N-SRO Rapid Plant Power Reduction due to Steam Generator tube leakage.
5 RC08A RC09A RC10A C - ATC C - SRO Reactor Coolant Pump 1A seal failure, manual reactor trip 6 SG01B M-All Steam G enerator Tube Rupture 7 RP08C C - ATC C - SRO Containment Isolation CVC-401 fails to auto close on CIAS 8 MS11B M - All Main Steam li ne break on Steam Generator 2 inside Containment. * (N)ormal, (R)eactivi ty, (I)nstrument, (C)omponent, (M)ajor
Scenario Event Description NRC Scenario 1 Scenario 1 Rev 1 The crew assumes the shift at 100% power with instructions to maintain 100% power.
After assuming the shift, annunciator H1005, Reactor Power Cutback Single Channel Trouble, alarms and Reactor Power Cutba ck auto actuation fails. The crew will be contacted by I&C maintenance after re viewing the annunciator response procedure describing a failure of Reactor Power Cut back, requiring Reactor Power Cutback be removed from service in accordance with OP-004-015, Reactor Power Cutback. This manipulation is performed by the ATC operator at CP-2 and CP-7.
After Reactor Power Cutback is removed from service, Pressurizer pressure instrument RC-IPI-0102 B fails low. The AT C operator will receive the annunc iators for this failure. The CRS should evaluate Tech Specs and enter Tech Spec 3.3.1 and 3.3.2 and determine that Plant Protection System bistable 6 for low Pressurizer pressure must be bypassed within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> on C hannel B. Tech Spec 3.
3.3.5 and 3.3.3.6 should be referenced but not entered. Plant Monito ring Computer group SPD S indication of Pressurizer pressure is affected by this failure.
After the CRS evaluates Tech Specs but before bistable 6 is bypassed, a Steam Generator tube leak develops in Steam Generator 2. Charging Pump AB will be aligned as the first backup Charging Pump and it will fail to auto start on the lowering Pressurizer level. The ATC operator should make this diagnosis and start Charging Pump AB. The CRS should enter OP-901-202, Steam Generator Tube Leakage or High Activity. The size of the leak will require entering OP-901-212, Rapid Plant Power Reduction. For the power reduction, the ATC will perform Direct Boration to the RCS as well as Pressurizer boron equalization and ASI control with CEAs. The BOP will manipulate the controls to reduce Main Turbine load. The CRS should enter Tech Spec 3.4.5.2 for Steam G enerator 2 leakage. The CRS ma y consider declaring Charging Pump AB inoperable due to it's failure to auto start, but no Tech Spec entry is required.
Once the crew has commenced the power reduc tion and lowered power to ~ 90%, or at the lead examiner's cue, RCP 1a will develop multiple seal failures. The second and third seal failures will be timed to occur 3 minutes after the initial seal failure. The crew should have time to get out off normal pr ocedure OP-901-130, Reactor Coolant Pump Malfunction, before the subsequent seals fail. With the second and third seals failing, the crew will be required to trip the reactor.
When the reactor is tripped, the Steam Genera tor tube leak will degr ade to a rupture. The CRS should direct the ATC to initiate Sa fety Injection and Containment Isolation.
Containment Isolation valve CVC-401 at CP-4 will fail to close on the CIAS, requiring the ATC operator to close the valve.
Scenario Event Description NRC Scenario 1 Scenario 1 Rev 1 After the crew completes OP-902-000, Standard Post Trip Actions and the CRS diagnoses into OP-902-007, Steam Generator Tube Rupture Recovery, the CRS should direct a rapid RCS cooldown to less than 520 °F T HOT. After this direction is given, a Main Steam Line break will develop on Stea m Generator 2 inside Containment. The CRS should exit OP-902-007 and enter OP-902-008, Functional Recovery Procedure.
Prioritization in OP-902-008 should result in Containment Isolation being priority 1. The crew should address Containment Isolation by using the steps in the Heat Removal section to isolate Steam Generator 2.
The scenario can be terminated after Steam G enerator 2 is isolat ed, or at the lead examiners discretion.
Scenario Event Description NRC Scenario 1 Scenario 1 Rev 1 Critical Tasks
This task is satisfied by securing all RCPs within 3 minutes of loss of CCW flow. The required task becomes applicable after Containment Spray has been actuated. The time requirement of 3 minutes is based on the RCP operating limit of 3 minutes without CCW cooling.
- 2. Prevent Opening the Main Steam Safety Valves.
This task is satisfied by the crew taking action to maintain Steam Generator #2 pressure below the safety valve setpoint by taking action to reduce RCS pressure to < 945 psia.
Scenario Quantitative Attributes 1. Total malfunctions (5-8) 8 2. Malfunctions after EOP entry (1-2) 2 3. Abnormal events (2-4) 3 4. Major transients (1-2) 2 5. EOPs entered/requiring substantive actions (1-2) 2 6. EOP contingencies requiring substantive actions (0-2) 1 7. Critical tasks (2-3) 2 NRC Scenario 1 Scenario 1 Rev 1 Scenario Notes:
A. Reset Simulator to IC-191. B. Verify the following Scenario Malfunctions are loaded: 1. rc22f2 for Pressurizer le vel instrument RC-ILI-0102 B 2. sg01B for Steam Generator #2 tube leak
- 3. cv02c for Charging Pump AB
- 4. rc08a, 09a, and 10a for RCP 1A
- 5. rp08c for CVC-401
- 6. ms11b for Steam Generat or #2 steam line break 7. eg10a for EDG A overspeed device C. Verify the following remotes 1. egr27 for EDG B local alarm acknowledgement D. Verify the following overrides 1. di-08a05s14-1 for closing FP-601 A set to trigger 9 2. di-08a05s19-1 for closi ng IA-909 set to trigger 9 3. di-04a04s10-1 for closing CVC-109 set to trigger 9 4. di-02a05a2s34-0 for Reactor Power Cutback out of service set to trigger 1. 5. di-02a05a2s30-0 for Reactor Power Cutback lamp test. E. Verify the following under Event Triggers: 1. zdirpciastrp(4).eq.1 is set on trigger 9 F. Verify the following C ontrol Board Conditions: 1. Danger tag placed on EDG A control switch
- 2. Danger tag placed on EDG A Output Breaker G. Verify EDG A output breaker is rack ed out and place danger tags on EDG A and its output breaker. H. Ensure Protected Train B sign is placed in SM office window.
I. Verify EOOS is 8.5 Yellow J. Complete the simulator setup checklist.
NRC Scenario 1 Scenario 1 Rev 1 Simulator Booth Instructions Event 1 Reactor Power Cutback Failure
- 1. On Lead Examiner's cue, initiate Event Trigger 1.
- 2. After the annunciator response procedure is referenced, call the CRS as the on shift I&C technician. R eport that during planned data collection, the Reactor Power Cutback Channel A has locked up and will not respond to any commands
or signals. 3. If Work Week Manager is called, inform the caller that a work package will be assembled and a team will be sent to the Control Room.
Event 2 Pressurizer Pressure Inst rument RC-IPI-0102 B Fails Low
- 1. On Lead Examiner's cue, initiate Event Trigger 2.
- 2. If Work Week Manager or I&C is called, inform the ca ller that a work package will be assembled and a team will be sent to the Control Room. 3. If sent to LCP-43, report RCS pressu re indications are reading normal on all channels except for Channel B.
Event 3 / 4 Steam Generator #2 Tube Leak / Chargi ng Pump AB Fails to Start / Rapid Plant Power Reduction
- 1. On Lead Examiner's cue, initiate Event Trigger 3.
- 2. If Chemistry or HP is called, acknowledge S/G tube leak and need to carry out the actions of UNT-005-032, Steam Gener ator Primary to Secondary Leakage. 3. If called as TGB watch to monitor Condensate System Polisher pressure, acknowledge and remove Polisher Vessel from service if necessary. 4. If called as the RCA Watch to check C harging Pump AB, report that it looks normal locally.
Event 5 Reactor Coolant Pump 1A seal failure
- 1. On Lead Examiner's cue, initiate Event Trigger 5.
- 2. If Engineering is called, acknowledge communication and report that engineering will investigate the RCP 1A failure. 3. If called as the RAB Watch to check RCP vibration in Switchgear room B, acknowledge communication, no report is necessary.
NRC Scenario 1 Scenario 1 Rev 1 Event 4 Steam Generator #2 Tube Rupture
- 1. On Lead Examiner's cue, initiate change the severity of malfunction SG01B to 7% and ramp it in over a 1 minute period. 2. If called as RAB watch to check Emergen cy Diesel Generator B, initiate Trigger 16, after EDG B Trouble alarm clear, report it is running satisfactorily.
Event 5 Steam Generator #2 Steam Line Break
- 1. After the crew has entered OP-902-007 and commenced the rapid cooldown and on the Lead Examiner's cue, in itiate Event Trigger 7.
Event 6 High Pressure Safety Injection Pump A fails to start
- 1. If called to check the HPSI Pump A breaker, report all indications are normal. 2. If called to check the HPSI Pump A locally, report all indications are normal.
NRC Scenario 1 Scenario 1 Rev 1 Scenario Timeline: Event Malfunction Severity Ramp HH:MM:SS Delay Trigger 1 H_L05 N/A N/A N/A 1 Remove Reactor Power Cutback from service 1 DI-02A05A2S34-0 N/A N/A N/A 1 Reactor Power Cutback Auto Actuate 1 DI-02A05A2S30-0 N/A N/A N/A 1 Remove Reactor Power Cutback Lamp Test 2 RC22F2 N/A N/A N/A 2 Pressurizer pressure instru ment RC-IPI-0102 B fails low 3 SG01 B 0.6 % 00:3:00 NA 3 Steam Generator #2 Tube Leak 4 CV02C N/A N/A N/A N/A Charging Pump AB fails to auto start 5 RC08 RC09 RC10 A 100 % 00:30 00:30 00:30 N/A 03:00 03:15 5 Reactor Coolant Pump 1A seal failures 6 SG01 B 7.0 % 00:01:00 N/A N/A Steam Generator #2 Tube Rupture 7 RP08C N/A N/A N/A N/A CVC-401 fails to close on CIAS 8 MS11B 12 % 03:00 N/A 8 Main Steam Line Break S/G 2
NRC Scenario 1 Scenario 1 Rev 1
REFERENCES:
Event Procedures 1 OP-004-015, Reactor Power Cutback System 2 OP-009-007, Plant Protection System Tech Spec 3.3.1 and 3.3.2 3 OP-901-202, Steam Generator Tube Leakage or High Activity Tech Spec 3.4.5.2 4 OP-901-212, Rapid Plant Power Reduction Tech Spec 3.1.3.6 Regulating an d Group P CEA Insertion Limits 5 OP-901-130, Reactor C oolant Pump Malfunction 6 OP-902-000, Standard Post Trip Actions OP-902-007, Steam Generator Tube Rupture Recovery OP-902-009, Standard Appendices, Appendix 1, Diagnostic Flow Chart 8 OP-902-008, Safety Function Recovery Procedure OP-902-009, Standard Appendic es, Appendix 13, Stabilize RCS Temperature
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 Page 1 of 23 Event
Description:
Remove Reactor Power Cutback from Service Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 ATC Recognize and report indications of failed Cutback Channel. Alarms:
Reactor Pwr Cutback Single Chnl Trouble (Cabinet H, L-5) Indications:
Reactor Power Cutback AUTO ACTUATE OUT OF SERVICE pushbutton illuminated on CP-2 CRS After receiving phone call from I&C Maintenance, directs ATC to remove Reactor Power Cutback from service. BOP Step 8.1.2.1 Verify 65% bistable lamps on all four Nuclear Instrumentation Test Drawers Illuminated.
Lamps are located behind the main panels on CP-10 A - D. ATC Step 8.1.2.2 On CP-7, verify all four LOSS OF TURB BYPASS keyswitches in BYPASS and all four red BYPASS lamps Illuminated. ATC Step 8.1.2.3 On CP-2, place LOSS OF TURBINE TRIP keyswitch to ENABLE. ATC Step 8.1.2.4 On CP-7, place all four LOSS OF TURB BYPASS keyswitches to OFF and verify all four green OFF lamps Illuminate. BOP Step 8.1.2.5 On Steam Bypass Control System Cabinet (IC-ECP-05), verify Reactor Power Cutback lamps Extinguished.
Lamps are located behind the main panels on CP-05, which is not modeled. Coach surrogate on this report. ATC Step 8.1.2.6 On CP-2, place LOSS OF LOAD keyswitch to TURBINE TRIP. CRS Step 8.1.2.7 Notify the Duty Plant Manager that Loss of Turbine Trip has been placed in service. Examiner Note This event is complete after the ATC operator addresses the AUTO ACTUATE OUT OF SERVICE pushbutton at step 7.1.2 Or As directed by the Lead Evaluator
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 2 Page 2 of 23 Event
Description:
Pressurizer Pressure Instrument Failure Match title with D-1 Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 ATC Recognize and report indications of failed channel. Alarms:
RPS CHANNEL TRIP PZR PRESSURE LOW (Cabinet K, A-16)
PZR PRESSURE LO PRETRIP B/D (Cabinet K, C-16)
RPS CHANNEL B TROUBLE (Cabinet K, F-18) Indications Pressurizer pressure instrument RC-IPI-0102 B on CP-7 indicates pegged low.
Pressurizer pressure indication on the Plant Monitoring Computer mimic SPDS averages the failed indicator with valid pressure indication.
Pressurizer Pressure Lo trip and pre-trip lamps lit on CP-7 Channel B. CRS Review Tech Specs based on the failed instrument.
Refer to Tech Spec 3.3.3.5 and 3.3.3.6.
Enter Tech Spec 3.3.1 (item 5) and 3.3.2 (items 1 and 3)
Direct bypassing Channel B bistable 6 for Lo Pressurizer Pressure. This is a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> action. Note OP-903-013, Monthly Channel Checks, does list this instrument for Tech Spec 3.3.3.5 and 3.3.3.6 applicability. Entry is not required, however, because the minimum channel requirements will still be met after the failure. Examiner Note This event is complete after the CRS evaluates Tech Specs Or As directed by the Lead Evaluator
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 3 of 23 Event
Description:
Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 ATC Recognize and report indications of Steam Generator Tube Leakage. Alarms:
RAD MONITORING SYS ACTIVITY HI-HI (Cabinet L, A-9)
VACUUM PUMPS EXHAUST ACTIVITY HI (Cabinet E, C-3) Indications RM-11 Rad Monitor indication will display rising activity on Main Steam Rad Monitor #2, Steam Generator #2 N-16 Rad Monitor, Main Condenser Vacuum Pumps WRGM, and the Blowdown radiation monitor. Steam Generator tube leakage indication rising as indicated on PMC Group PSLR (PMC PID C48304). CRS Enter and direct the implementation of OP-901-202, Steam Generator Tube Leakage or High Activity. Examiner Note The following steps are from OP-901-202, Steam Generator Tube Leakage or High Activity. CRS 1. IF Pressurizer level CANNOT be maintained with available Charging Pumps, THEN perform the following: 1.1 Manually trip Reactor. 1.2 Manually initiate Safety Injection Actuation (SIAS) AND Containment Isolation Actuation (CIAS).
1.3 GO TO OP-902-000, STANDARD POST TRIP ACTIONS. CRS Procedure NOTE (1) The calculated Primary to Secondary Leak Rate values must be considered valid, unless the reading can be quickly diagnosed as incorrect due to an obvious malfunction of the PMC or AE Discharge Rad Monitor. (2) The AE Discharge Rad Monitor is considered the primary Rad Monitor which has the sensitivity to measure small Primary to Secondary Leakage. The AE Discharge Rad Monitor reading inputs into the Primary to Secondary Leak Calculation on PMC Group PLSR. The MS Line N16 Rad Monitors may be used as verification of AE Discharge Rad Monitor or as primary indication if the AE Discharge Rad Monitor is OOS.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 4 of 23 Event
Description:
Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 CRS 2. Determine RCS leak rate using ANY of the following: Calculated Steam Generator leakage displayed on PMC Group PSLR (PMC PID C48304) Calculated Steam Generator leakage displayed on PMC PID C48251 (RE5501 CH1 LEAK RATE) and C48252 (RE5501 CH2 LEAK RATE) Approximate RCS leak rate by subtracting total of Letdown flow AND RCP CBO flow from Charging Flow Calculated Charging / Letdown Mismatch displayed on PMC Group Leakrate (PMC PID S13001) RCS Leak Rate calculation in accordance with OP-903-024, REACTOR COOLANT SYSTEM WATER INVENTORY BALANCE Calculated steam generator leakage based upon chemistry sample, per CE-003-705, Determination Of Primary-To-Secondary Leak Rate CRS Procedure NOTE Any rise >30 GPD/HR followed by a subsequent lowering of the rate of change would indicate a spike and a rapid power reduction is not required. CRS 3. IF Primary to Secondary Leakage in any Steam Generator is 75 GPD (~0.05 GPM) AND the rate of change is rising by 30 GPD/HR (~0.02 GPM/HR), THEN perform the following: 3.1 Commence a rapid plant shutdown in accordance with OP-901-212, RAPID PLANT POWER REDUCTION, AND concurrently with this Procedure, reduce Plant Power to 50% within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. 3.2 WHEN Plant Power is 50%, THEN in accordance with OP-901-212, RAPID PLANT POWER REDUCTION, AND concurrently with this Procedure, be in Mode 3 within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> AND Mode 5 in the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />. These conditions will be met. The CRS should enter OP-901-212 and perform it concurrently with OP-901-202. Steps 1 through 15 of Steam Generator Tube Leakage or High Activity are listed here. The CRS should begin the steps of Rapid Plant Power Reduction before working these steps. The steps of OP-901-212, Rapid Plant Power Reduction follow step 15 of OP-901-202.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 5 of 23 Event
Description:
Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 CRS 7. Notify Chemistry Depar tment to perform the following: 7.1 Provide current Plant status including the following: Primary to Secondary Leakrate Primary to Secondary Leakage Rate of Change Plant action(s) Operations is OR will be implementing (example: plant shutdown, rapid plant shutdown, monitoring) 7.2 Carry out actions in accordance with UNT-005-032, STEAM GENERATOR PRIMARY-TO-SECONDARY LEAKAGE. 7.3 Begin sampling Steam Generators for activity. 7.4 Quantify Steam Generator Tube leakage. CRS 8. Notify Radiation Protection to carry out the actions of UNT-005-032, STEAM GENERATOR PRIMARY-TO-SECONDARY LEAKAGE. CRS / BOP 9. Verify BD-303, DISCHARGE TO WASTE, Locked Closed. CRS / BOP 10. Verify BD-1162, BD FLASH TANK VENT, Closed. CRS / BOP 11. Verify CD-145, CD DUMP TO WASTE POND, Closed. 11.1 Notify Chemistry prior to dumping Condensate from the Condenser Hotwell to the CST. Crew 12. Establish AND monitor a PMC Trend of the following PMC points: C48304 PRI TO SEC LEAKAGE C48305 PRI TO SEC LEAK RATE CHANGE (GPD/HR) C48251 RE5501 CH1 LEAK RATE C48252 RE5501 CH2 LEAK RATE CRS Procedure NOTE Until arrangements are made for disposal of radioactively contaminated resin, Condensate Polisher Vessels should NOT be placed in service with resin loaded in the vessel.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 6 of 23 Event
Description:
Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 CRS 15. Remove from service ANY Condensate Polisher Vessels which are loaded with resin in accordance with OP-003-031, CONDENSATE POLISHER/BACKWASH TREATMENT. 15.1 Do not place in service any condensate polisher vessel loaded with resin without the coordination of Chemistry. Examiner Note For the failure of Charging Pump AB failing to auto start on lowering level, this malfunction may occur before or after the Rapid Power Reduction is started, depending on the pace of the crew. Charging Pump AB would have auto started at ~ 53%, depending on power level. ATC Recognize and report indications of Charging Pump AB Auto Start Failure. Alarm (This alarm only comes in if Pressurizer Level drops to 3.9% below the Pressurizer Level Setpoint. If the ATC starts Charging Pump AB before this level, this alarm will not come in):
PRESSURIZER LEVEL HI/LO (Cabinet H, B-1) Indications Pressurizer level drops more than 2.5% below Pressurizer Level Setpoint and Charging Pump AB does not start. ATC Start Charging Pump AB by taki ng the control switch on CP-2 to ON. Examiner Note The following steps are from OP-901-212, Rapid Plant Power Reduction. CRS NOTE (1) A rapid power reduction is defined as approximately 30 MW/minute load reduction on the main turbine. (2) Power Reduction may be stopped at any point.
(3) Some Steps of this procedure may not be applicable due to plant conditions. In these cases SM/CRS may NA the step. (4) Steps within this procedure may be performed concurrently or out of sequence with SM/CRS concurrence.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 7 of 23 Event
Description:
Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 ATC Begin RCS Boration by either of the following methods as directed by the CRS: Direct Boration Emergency Boration using one Charging Pump CRS Step 1: Begin RCS Boration by one of the following methods:
up to 340 EFPD: Direct Boration or Emergency Boration using one Charging Pump ATC Steps for Direct Boration:
CAUTION (1) This section affects reactivity. This evolution should be crosschecked and completed prior to leaving CP-4. (2) At least one reactor coolant pump in each loop should be operating prior to performing direct boration operations to ensure proper chemical mixing.
6.7.1 Inform SM/CRS that this Section is being performed.
NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change. 1.2.1.1 Power Defect Vs Power Level 1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD) 1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD) 1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD) 1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD) 6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be added on Attachment 11.6, Calculation of Boric Acid Volume for Direct Boration or VCT Borate Makeup Mode. Should use Reactor Engineering Reactivity Worksheet 6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Acid desired. 6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desired Boric Acid Makeup Pump A(B).
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 8 of 23 Event
Description:
Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 6.7.5 Place Direct Boration Valve, BAM-143, control switch to AUTO.
6.7.6 Place Makeup Mode selector switch to BORATE.
6.7.7 Verify selected Boric Acid Makeup Pump A(B) Starts.
6.7.8 Verify Direct Boration Valve, BAM-143, Opens.
NOTE The Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is most accurate in the range of 10 - 25 GPM.
6.7.9 If manual control of Boric Acid flow is desired, then perform the following:
6.7.9.1 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual.
6.7.9.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, output to >3 GPM flow rate.
6.7.11 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate or Open. 6.7.12 Observe Boric Acid flow rate for proper indication. Note This manipulation is performed at CP-4. The ATC should use the Reactivity Worksheet to recommend a boron quantity to the CRS. ATC Perform Boron Equalization as follows:
Place available Pressurizer Pressure Backup Heater Control Switches to ON. Reduce Pressurizer Spray Valve Controller (RC-IHIC-0100) setpoint potentiometer to establish spray flow and maintain RCS pressure 2250 PSIA (2175 - 2265). This manipulation is performed at CP-2. ATC Operate CEAs to maintain ASI using CEA Reg. Group 6 or Group P Control Element Assemblies. Operate CEAs in Manual Group mode as follows:
6.7.1 Verify Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 9 of 23 Event
Description:
Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 6.7.2 Position Group Select switch to desired group.
6.7.3 Place Mode Select switch to MG and verify the following: White lights Illuminated on Group Selection Matrix for selected group MG light Illuminates 6.7.4 Operate CEA Manual Shim switch to INSERT group to desired height while monitoring the following: CEA Position Indicator selected CEA group is moving in desired direction If Reactor is critical, then monitor the following: Reactor Power Reactor Coolant System (RCS) temperature Axial Shape Index (ASI)
NOTE The Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when the Mode Select switch is not in OFF.
6.7.5 When desired set of moves have been completed, then place Mode Select switch to OFF. Note CEA Group P should be used first to a low limit of 120 inches, followed by CEA Group 6 to a low limit of 120 inches to comply with Tech Spec 3.1.3.6.
This manipulation is performed at CP-2. CRS Notify the Load Dispatcher (Woodlands) that a rapid power reduction is in progress. CRS Announce to Station Personnel over the Plant Paging System that a rapid plant power reduction is in progress. Crew Maintain RCS Cold Leg Temperature 536°F to 549°F.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 / 4 Page 10 of 23 Event
Description:
Steam Generator Tube Leakage / Charging Pump AB Fails to start / Rapid Plant Power Reduction Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 BOP Commence Turbine load reduction by performing the following:
Depress LOAD RATE MW/MIN pushbutton.
Set selected rate in Display Demand Window.
Depress ENTER pushbutton.
Depress REFERENCE pushbutton.
Set desired load in Reference Demand Window.
Depress ENTER pushbutton.
Depress GO pushbutton. This manipulation is performed at CP-1. The BOP will set up the Main Turbine controls. The ATC will direct the BOP when to commence unloading the Main Turbine based on the drop in RCS Cold Leg temperature. CRS When Reactor Power consistently indicates less than 98% power, as indicated on PMC PID C24631 [MAIN STEAM RAW POWER (MSBSRAW)],
or an alternate point provided by Reactor Engineering, then verify the value of C24648 [BSCAL SMOOTHING VAL. APPLD (DUMOUT17)] automatically changes to 1. Examiner Note This event is complete after power has been reduced to the satisfaction of the Lead Evaluator.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 5 Page 11 of 23 Event
Description:
Reactor Coolant Pump 1A Seal Failure Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 ATC / BOP Recognize and report indications of RCP 1A seal failure. Indications RCP 1A seal bleed off flow and temperature rising on the Plant Monitoring Computer and CP-2.
RCP 1A seal pressures rising on the Plant Monitoring Computer and CP-2. CRS Enter and direct the implementation of OP-901-130, Reactor Coolant Pump Malfunction. CRS IF Reactor Coolant Pump Seal has failed, THEN GO TO section E1, Seal Failure. Crew Procedure Note 1. RCP Seal pressure and Control Bleedoff temperature and flow are normally as follows (assuming normal operating RCS temperature and pressure): Vapor Seal pressure: 25 to 45 PSIG Upper Seal pressure: 585 to 915 PSIG Middle Seal pressure: 1237 to 1815 PSIG CBO temperature: 135° to 190°F CBO flow: 1.2 to 1.8 GPM 2. (If only one Reactor Coolant Pump Seal has failed on a Reactor Coolant Pump, THEN pump operation may continue provided the seal package is monitored for further degradation. Crew 1. Inform System Engineer of Reactor Coolant Pump Seal failure. Crew Procedure Caution (1) CCW TEMPERATURES OF <75~ F COULD LEAD TO ESSENTIAL CHILLER TRIPS ON EVAPORATOR LOW REFRIGERANT PRESSURE. (2) CCW TEMPERATURE SHOULD BE CHANGED AT A RATE OF 10 °F IN ONE HOUR TO PREVENT DEGREDATION OF THE REACTOR COOLANT PUMP SEALS.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 5 Page 12 of 23 Event
Description:
Reactor Coolant Pump 1A Seal Failure Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 CRS / BOP 2. IF Controlled Bleedoff temperature is rising, THEN lower Component Cooling Water temperature by ANY of the following: Start Dry Cooling Tower Fans. Start Auxiliary Component Cooling Water Pump(s) AND associated Wet Cooling Tower Fans. Start Auxiliary Component Cooling Water Pump(s) AND lower ACC-126A(B) setpoint. Examiner Note Seals are timed such that the second seal will fail 3 minutes after the first. 3. IF TWO OR MORE seals fail in rapid succession, (within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />) THEN perform the following: ATC 3.1 Trip the Reactor. ATC 3.2 Secure affected Reactor Coolant Pump.
Control switch is on CP-2. Crew 3.3 GO TO OP-902-000, STANDARD POST TRIP ACTIONS. Examiner Note This event is complete after the ATC operator trips the reactor. The severity of the SGTL should be updated upon reactor trip.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6 / 7 Page 13 of 23 Event
Description:
Steam Generator Tube Rupture / CVC-401 Fails to Close Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 ATC / BOP Recognize and report indications of Steam Generator Tube Rupture.
Alarms PRESSURIZER LEVEL HI/LO (Cabinet H, B-1) Indications Pressurizer level lowering > Charging Pump capacity.
Lowering Pressurizer pressure.
Charging Pump A auto-starts if not already started.
ATC If directed by CRS, trip Reactor using 2 Reactor Trip pushbuttons at CP-2.
ATC If directed by CRS, initiate Safety Injection Actuation (SIAS) and Containment Isolation Actuation (CIAS) at CP-7.
ATC Close CVC-401 after Containment isolation This component is on CP-4 and receives a CIAS closure signal. This step becomes applicable after the CIAS is actuated.
BOP Start High Pressure Safety Injection Pump A This component is on CP-8 and receives a SIAS start signal. This step becomes applicable after the SIAS is actuated.
CRS Direct ATC and BOP to carry out Standard Post trip Actions. ATC Determine Reactivity Control acceptance criteria are met: Check reactor power is dropping. Check startup rate is negative. Check less than TWO CEAs are NOT fully inserted.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6 / 7 Page 14 of 23 Event
Description:
Steam Generator Tube Rupture / CVC-401 Fails to Close Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 BOP Determine Maintenance of Vital Auxiliaries acceptance criteria are met: Check the Main Turbine is tripped: Governor valves closed Throttle valves closed BOP Check the Main Generator is tripped: GENERATOR BREAKER A tripped GENERATOR BREAKER B tripped EXCITER FIELD BREAKER tripped BOP Check station loads are energized from offsite electrical power as follows:
Train A A1, 6.9 KV non safety bus A2, 4.16 KV non safety bus A3, 4.16 KV safety bus A-DC electrical bus A or C vital AC Instrument Channel Train B B1, 6.9 KV non safety bus B2, 4.16 KV non safety bus B3, 4.16 KV safety bus B-DC electrical bus B or D vital AC Instrument Channel ATC Determine RCS Inventory Control acceptance criteria are met: Check that the following conditions exist: Pressurizer level is 7% to 60% Pressurizer level is trending to 33% to 60% Check RCS subcooling is greater than or equal to 28ºF.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6 / 7 Page 15 of 23 Event
Description:
Steam Generator Tube Rupture / CVC-401 Fails to Close Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 ATC Determine RCS Pressure Control acceptance criteria are met by checking that BOTH of the following conditions exist: Pressurizer pressure is 1750 psia to 2300 psia Pressurizer pressure is trending to 2125 psia to 2275 psia IF pressurizer pressure is less than 1684 psia, THEN verify the following have initiated.
- CIAS ATC Determine Core Heat Removal acceptance criteria are met: Check at least one RCP is operating. Check operating loop T is less than 13ºF. Check RCS subcooling is greater than or equal to 28ºF. BOP Determine RCS Heat Removal acceptance criteria are met: Check that at least one steam generator has BOTH of the following: Steam generator level is 5% to 80% NR Main Feedwater is available to restore level within 50%-70% NR.
ATC Check RCS T C is 530 ºF to 550 ºF BOP Check steam generator pressure is 885 psia to 1040 psia. BOP Check Feedwater Control in Reactor Trip Override: MAIN FW REG valves are closed STARTUP FW REG valves are 13% to 21% open Operating main Feedwater pumps are 3800 rpm to 4000 rpm BOP Reset moisture separator reheaters, and check the temperature control valves closed.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6 / 7 Page 16 of 23 Event
Description:
Steam Generator Tube Rupture / CVC-401 Fails to Close Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 ATC Determine Containment Isolation acceptance criteria are met: Check containment pressure is less than 16.4 psia. Check NO containment area radiation monitor alarms OR unexplained rise in activity. Check NO steam plant activity monitor alarms OR unexplained rise in activity. BOP Determine Containment Temperature and Pressure Control acceptance criteria are met: Check containment temperature is less than or equal to 120ºF. Check containment pressure is less than 16.4 psia.
BOP Secure AH-12 A or B on CRS direction after initiation of SIAS at CP-18.
CRS After review of Standard Post Trip Actions, use Appendix 1, Diagnostic Flow Chart of OP-902-009 to select appropriate optimal recovery procedure. Proper use of chart will result in use of OP-902-007, Steam Generator Tube Rupture Recovery CRS Enter and direct the implementation of OP-902-007, Steam Generator Tube Rupture Recovery.
CRS 1. Confirm diagnosis of a SGTR: a. Check Safety Function Status Check acceptance criteria are satisfied.
- b. IF steam generator sample path is available, THEN direct Chemistry to sample BOTH steam generators for activity.
Crew 2. Announce a Steam Generator Tube Rupture is in progress using the plant page. CRS 3. Advise the Shift Manager to REFER TO EP-001-001, "Recognition & Classification of Emergency Condition", and implement the Emergency Plan.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6 / 7 Page 17 of 23 Event
Description:
Steam Generator Tube Rupture / CVC-401 Fails to Close Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 CRS 4. IF power has been interrupted to either 3A or 3B safety buses, THEN perform Appendix 20, "Operation of DCT Sump Pumps".
Step is not applicable.
CRS 5. REFER TO Section 6.0, "Placekeeper", and record the time of the reactor trip. CRS 6. IF Pressurizer pressure is less than 1684 psia, THEN verify SIAS has initiated.
CRS 7. IF SIAS has initiated, THEN: a. Verify safety injection pumps have started. b. Check safety injection flow is within the following:
- Appendix 2-E, "HPSI Flow Curve"
- Appendix 2-F, "LPSI Flow Curve" c. Verify ALL available charging pumps are operating.
IF Pressurizer pressure is less than 1621 psia, AND SIAS is actuated, THEN: a. Verify no more than two RCPs are operating.
- b. IF Pressurizer pressure is less than the minimum RCP NPSH of Appendix 2A-D, "RCS Pressure and Temperature Limits", THEN stop ALL RCPs. Step is not applicable.
IF RCPs are operating, THEN: a. Verify CCW available to RCPs.
- b. IF a CSAS is initiated, THEN stop ALL RCPs. c. IF RCS TC is less than 382ºF, THEN verify no more than two RCPs are operating.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6 / 7 Page 18 of 23 Event
Description:
Steam Generator Tube Rupture / CVC-401 Fails to Close Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 BOP 10. Check a CCW pump is operating for each energized 4.16 KV safety bus.
CRS / BOP 11. Commence a rapid RCS cooldown to less than 520 °F T Hot using the steam bypass valves.
Since the Main Condenser is available at this point in the scenario, the CRS should direct the BO P to open Steam Bypass Valve #1 50% open to commence this rapid cooldown. If the crew initiated a Main Steam Isolation Signal prior to this point, the rapid cooldown would be initiated by opening both Atmospheric Dump Valves 100% open.
ATC 13. IF MSIS is NOT present, THEN lower the automatic initiation setpoints as the cooldown and depressurization proceed for MSIS (low SG Pressure).
The CRS should direct the ATC to perform this action during the rapid cooldown to < 520 THOT. Reset MSIS setpoints on all 4 channels at CP-7.
Examiner Note This event is complete after commencing the rapid cooldown.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 19 of 23 Event
Description:
Main Steam Line Break / Function Recovery Procedure Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 ATC / BOP Recognize and report indications of Main Steam Line Break.
Alarms Containment Water Leakage Hi (Cabinet N, L-20)
Containment Water Leakage Hi-Hi (Cabinet N, K-20)
Containment Pressure Hi / Lo (Cabinet M, H-4)
Containment Pressure Hi / Lo (Cabinet N, H-14) Indications Lowering Pressurizer level.
Lowering Pressurizer pressure.
Rising Containment pressure.
Lowering Steam Generator #2 pressure. CRS Recognize the second event in progress. Exit OP-902-007 and enter OP-902-008, Functional Recovery procedure. Crew 1. Announce that the Functional Recovery Procedure is in progress using the plant page. CRS 2. Advise the Shift Manager to REFER TO EP-001-001, "Recognition & Classification of Emergency Condition" and implement the Emergency Plan. CRS 3. REFER TO the "Placekeeper" and record the time of the reactor trip. ATC 4. IF pressurizer pressure is less than 1621 psia, AND SIAS is actuated, THEN: a. Verify no more than two RCPs are operating.
- b. IF pressurizer pressure is less than the minimum RCP NPSH of Appendix 2A-D, "RCS Pressure and Temperature Limits", THEN stop ALL RCPs. ATC 5. IF RCPs are operating, THEN: a. IF a CSAS is initiated, THEN stop ALL RCPs. b. Verify CCW available to RCPs. c. IF RCS TC is less than 382ºF [384ºF], THEN verify no more than two RCPs are operating.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 20 of 23 Event
Description:
Main Steam Line Break / Function Recovery Procedure Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 Critical Task Trip any RCP not satisfying RCP operating limits.
This task is satisfied by securing all RCPs within 3 minutes of loss of CCW flow / CSAS.
ATC Following initiation of CSAS (auto or manual) secure all running Reactor Coolant Pumps as follows: Place each RCP control switch to stop at CP-2 CRS 6. Direct Chemistry to sample BOTH steam generators for activity and boron. CRS 7. IF power is lost to both 3A and 3B safety buses and NOT expected to be restored within 30 minutes, THEN perform the following:
This step is not applicable due to no power loss. CRS 8. IF power is lost to both 3A and 3B safety buses and NOT expected to be restored within 30 minutes, THEN perform the following to reduce unnecessary station loads:
This step is not applicable due to no power loss. CRS 9. IF power has been interrupted to either 3A or 3B safety buses, THEN perform Appendix 20, "Operation of DCT Sump Pumps".
This step is not applicable due to no power loss. BOP 10. Place Hydrogen Analyzers in service as follows:
Train A o Place Train A H2 ANALYZER CNTMT ISOL VALVE keyswitch to OPEN. o Place H2 ANALYZER A POWER to ON.
o Check H2 ANALYZER A Pumps indicate ON.
Train B o Place Train B H2 ANALYZER CNTMT ISOL VALVE keyswitch to OPEN. o Place H2 ANALYZER B POWER to ON.
o Check H2 ANALYZER B Pumps indicate ON.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 21 of 23 Event
Description:
Main Steam Line Break / Function Recovery Procedure Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 CRS 11. Identify success paths to be used to satisfy each safety function using BOTH of the following: Resource Assessment Trees Safety Function Tracking Sheet Note The CRS will perform the prioritization using the Reso urce Assessment Trees. The STA would use the Safety Function Tracking Sheets. Proper prioritization will result in Containment Isolation being priority 1 and RCS Inventory Control being priority 2. The CRS may request plant data from the ATC and BOP operators during his prioritization. The CRS may ask for the BOP to verify Safety Injection Pumps are meeting the flow curves of OP-902-009, Appendix 2. Both High and Low Pressure Safety Injection Pumps are meeting
their flow curves. The Containment Isolatio n section of OP-902-008 will direct the CRS to carry out the actions in the Heat Removal section, HR-2, steps 16-28. These steps will direct reducing RCS pressure and Isolating S/G #2.
BOP 16.1 Commence a rapid RCS cooldown to less than 520 °F T HOT using Steam Bypass valves.
The CRS should have already ordered this step in OP-902-007. Since the Main Steam Line Break is inside Containment, the Main Steam Isolation valves will now be closed. The CRS should now order the BOP to open both Atmospheric Dump Valves 100% to re-commence the rapid cooldown. RCS temperature may already be < 520 °F due to the Excess Steam Demand. In that case, this step is not applicable.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 22 of 23 Event
Description:
Main Steam Line Break / Function Recovery Procedure Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 Critical Task Prevent opening the Main Steam Safety Valves This task is satisfied by taking action to lower RCS pressure in accordance with step 17.
ATC 17. Depressurize the RCS by performing ALL of the following:
- a. Maintain pressurizer pressure within ALL of the following criteria: Less than 945 psia [915 psia] Within 50 psi of the most affected steam generator pressure Within Appendix 2A-D, "RCS Pressure and Temperature Limits" IF RCPs are operating, greater than the minimum RCP NPSH of Appendix 2A-D, "RCS Pressure and Temperature Limits" b. Operate main or auxiliary pressurizer spray.
- c. IF HPSI throttle criteria are met, THEN perform ANY of the following:
- Control charging and letdown flow
- Throttle HPSI flow Note The ATC operator should receive direction from the CRS to perform this step. He should evaluate plant conditions and decide on a minimum RCS pressure. The critical task is satisfied when the applicant takes action to start reducing RCS pressure (< 945 PSIA does not need to be reached in the scenario). Auxiliary Spray will be required since all RCPs will be secured. HPSI throttle criteria will not be met at this point.
BOP IF RCS T HOT is less than 520 °F, THEN isolate the most affected SG: BOP a. Place the ADV setpoint to 980 psig and verify controller in AUTO.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 23 of 23 Event
Description:
Main Steam Line Break / Function Recovery Procedure Time Position Applicant's Actions or Behavior Scenario 1, Revision 0 BOP b. Verify the MSIV is closed.
BOP c. Verify the MFIV is closed.
BOP d. IF EFAS-2 is NOT initiated, THEN close EFW Isolation Valves: EFW 228B (SG 2 PRIMARY) EFW 229B (SG 2 BACKUP)
BOP e. Place EFW Flow Control Valves in MAN and close: EFW 224B, SG 2 PRIMARY EFW 223B, SG 2 BACKUP BOP f. Close MS 401B, PUMP AB TURB STM SUPPLY SG 2.
BOP g. Close Main Steam Line 2 Drains: MS 120B NORMAL MS 119B BYPASS BOP h. Close Steam Generator Blowdown isolation valves: BD 103B STM GEN 2 (OUT) BD 102B STM GEN 2 (IN) BOP i. Check main steam safety valves are closed. Examiner Note This event is complete after the CRS has directed Steam Generator #2 to be isolated AND The ATC operator has commenced reducing RCS pressure Or As directed by the Lead Evaluator.
Appendix D Scenario Outline Form ES-D-1 Scenario 2 Rev 1 Facility: WATERFORD 3 Scenario No.: 2 Op Test No.:
NRC Examiners: Operators: Initial Conditions: 100%, 125 EFPD, AB buses aligned to Train B.
Protected Train is B Emergency Diesel Generator A is tagged out for planned maintenance.
Turnover: Maintain 100 % power Severe Thunderstorm Warning and Tornado Watch and in effect Event No. Malf. No. Event Type* Event Description 1 CV01B TS - SRO C - ATC C - SRO Charging Pump B trips 2 N/A TS - SRO Dry Cooling Tower Fan 8A reported with no oil in sight glass.
3 FW27M FW28M R - ATC N - BOP N - SRO Heater 5 and 6 A isolate on high level.
Normal plant power reduction to < 72%. 4 RC04C RD24 A,B,E,F M - All I - ATC I - SRO RCP 2A Shaft Shear with aut omatic trip initiated but correct alignment of trip breakers do not open.
Manual reactor trip.
5 RD11A-44 RD11A-74 RD11A-68 C-ATC C - SRO 3 CEAs stick out on trip requiring Emergency Boration 6 ED01 A, B, C, D M-All Loss of Off Site Power 7 EG08B C- BOP C - SRO EDG B fails to auto-start
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Scenario Event Description NRC Scenario 2 Scenario 2 Rev 1 The crew assumes the shift at 100% power with instructions to maintain 100% power.
Emergency Diesel Generator A is out of service due to a cracked lube oil strainer valve. Tech Spec 3.8.1.1 b and d hav e been entered. The turnover will include that the site is under a Severe Thunderstorm Warning and a Tornado Watch. All of the necessary actions of OP-901-521, Severe Weather and Flooding, have been accomplished.
After taking the shift, Charging Pump B will trip on motor overload. The crew should start Charging Pump AB or A and enter OP-901-112, Charging or Letdown Malfunction. The CRS should enter Tech Spec 3.1.2.4 and TRM 3.1.2.4. Additi onally, the crew will no longer be in compliance with Tech Spec 3.
8.1.1 d, requiring ac tion within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. The CRS should direct the ATC to align Ch arging Pump AB to replace Charging Pump B and exit Tech Spec 3.1.2.4, comply with Tech Spec 3.8.1.1.b, and remain in TRM 3.1.2.4.
After the ATC aligns Charging Pump AB or at the lead examiners direction, the Outside Watch will call and report that during his rounds in the Dry Cooling Tower Area, he has discovered Dry Cooling Tower Fan 8A has a cracked oil housing and no oil is visible in the sight glass. The CRS should declare Dry Cooling Tower Fan 8A inoperable and enter Tech Spec 3.7.4 action c, which, due to the tornado watch, requires a shutdown if not restored in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
After the CRS identifies the co rrect Tech Spec, Heater 5A Normal Level Control Valve will fail closed. The rising level will caus e Heaters 5A and 6A to isolate. Based on guidance from OP-003-034, Feed Heater Vents and Drains, the crew should determine the need to commence a normal plant shutdown in accordance with OP-010-005, Plant Shutdown, to lower Main Generator load to less than 893 MWe, 72% power. The ATC will perform Pressurizer boron equalization, di rect Boration to the RCS, as well as ASI control with CEAs. The BOP will manipulate the Main Turbine controls to reduce load.
Once the crew has commenced the power reduc tion and lowered power to ~ 90%, or at the lead examiner's discretion, Reactor Coolant Pump 2A will have a sheared shaft failure. The Plant Protection System will actuat e, but 4 Reactor Trip Breakers will fail to open automatically. The crew should manua lly trip the reactor using the Diverse Reactor Trip System. After t he reactor trip, 3 CEAs will fail to insert. The ATC should commence Emergency Boration in accordance with OP-901-103, Emergency Boration.
The crew will carry out the i mmediate operator actions of OP-902-000, Standard Post Trip Actions.
During the review of Standard Post Trip Acti ons, a Loss of Off Site Power will occur.
EDG B will fail to automatically start and have to be started manually by the BOP operator. The CRS should enter OP-902-003, Loss of Off Site Power/Loss of Forced Circulation Recovery. Once in OP-902-003, the CRS should direct the performance of OP-902-009, Standard Appendices, Appendix 20, Operation of DCT Sump Pumps. The scenario can be terminated after the CRS orders the performance of OP-902-009 Appendix 20 or at the l ead examiners discretion.
Scenario Event Description NRC Scenario 2 Scenario 2 Rev 1 Critical Tasks
- 1. Manually trip the Reactor.
This task is satisfied by manually tripping the reactor within 1 minute of the failure of the automatic trip. The required task becomes applicable after the annunciators are received associated with the RCP 2A sheared shaft.
- 2. Establish reactivity control.
This task is satisfied by establishing Emergency Boration prior to completing Standard Post Trip Actions Reactivity Control verification. The required task becomes applicable after the Reactor is tripped and 2 CEAs remain stuck out following event 5.
- 3. Energize at least one vital electrical AC bus.
This task is satisfied by starting Emergency Diesel Generator B. This task becomes applicable following the loss of off site power triggered in event 7.
Scenario Quantitative Attributes 1. Total malfunctions (5-8) 6 2. Malfunctions after EOP entry (1-2) 2 3. Abnormal events (2-4) 2 4. Major transients (1-2) 2 5. EOPs entered/requiring substantive actions (1-2) 1 6. EOP contingencies requiring substantive actions (0-2) 1 7. Critical tasks (2-3) 3 NRC Scenario 2 Scenario 2 Rev 1 Scenario Notes:
A. Reset Simulator to IC-192. B. Verify the following Scenario Malfunctions: 1. cv01b for Charging Pump B trip
- 2. rc04c for RCP 2A sheared shaft
- 3. rd24a for Reactor Trip Cir cuit Breaker 1 fail to open 4. rd24b for Reactor Trip Cir cuit Breaker 2 fail to open 5. rd24efor Reactor Trip Cir cuit Breaker 5 fail to open 6. rd24f for Reactor Trip Cir cuit Breaker 6 fail to open 7. rd11a44 for CEA 44 stuck
- 8. rd11a68 for CEA 68 stuck
- 9. ed01a for Off Site Feeder Breaker 7172 trip
- 10. ed01b for Off Site Feeder Breaker 7176 trip
- 11. ed01c for Off Site Feeder Breaker 7182 trip
- 12. ed01d for Off Site Feeder Breaker 7186 trip
- 14. eg08b for EDG B fail to auto start
- 15. fw27m for Heater 5A NLCV
- 16. fw28m for Heater 5A ALCV C. Verify the following Annunciators 1. b_e07 for Dry Cooling Tower 1 level high
- 2. b_e08 for Dry Cooling Tower 2 level high D. Verify the following Overrides 1. egr27 for EDG B local alarm acknowledgement E. Verify the following C ontrol Board Conditions: 1. Danger tag placed on EDG A control switch 2. Danger tag placed on EDG A Output Breaker F. Verify EDG A output breaker is racked out and place danger tags on EDG A and its output breaker. G. Ensure Protected Train B sign is placed in SM office window.
H. Complete the simulator setup checklist.
NRC Scenario 2 Scenario 2 Rev 1 Simulator Booth Instructions
Event 1 Charging Pump A Trips
- 1. On Lead Examiner's cue, initiate Event Trigger 1.
- 2. If called, the RCA should report a sc ent of burnt electrical components at Charging Pump B. 3. If Work Week Manager is called, info rm the caller that a work package will be assembled and a team will be sent to the Control Room.
Event 2 Dry Cooling Tower Fan 8A Failure
- 1. On Lead Examiner's cue, call 4100 and report indication of a cracked oil housing on DCT Fan 8A reduction gear an d that there is no oil visi ble in the sight glass. 2. If Work Week Manager is called, info rm the caller that a work package will be assembled and a team will be sent to the Control Room.
Event 3 Heater 5A NLCV Failure / Normal Plant Power Reduction
- 1. On Lead Examiner's cue, initiate Event Trigger 3.
- 2. When called, have the TGB Watch report that Heater 5A NLCV is closed and that you do not know why. You wil l investigate and report back. 3. If Work Week Manager or I&C is called, inform the ca ller that a work package will be assembled and a team will be sent to the Control Room.
Event 4 Reactor Coolant Pump 2A S heared Shaft / Trip Failure
- 1. On Lead Examiner's cue, initiate Event Trigger 4.
- 2. If the Work Week Manager or Duty Plant Manager is called, inform the caller that they will make the necessary calls.
Event 5 CEA 74 and 68 Fail to Insert / Emergency Boration
- 1. No calls for this malfunction should occur.
NRC Scenario 2 Scenario 2 Rev 1 Event 6 Loss of Off Site Power
- 1. After the crew has completed Standard Post Tip Actions and on the Lead Examiner's cue, initiate Event Trigger 6. 2. If called as OSW watch report that a steady rain has been falling all shift. 3. If called to come to th e Control Room to get a copy of OP-902-009, Appendix 20 for aligning the DCT Sump Pumps, repor t that you have a copy at the 314 Bus.
Event 8 Emergency Diesel Generator B fails to start
- 1. If called as RAB watch to check EDG B, initiate Trigger 9, and when the EDG B Trouble alarm is clear, report that it is running satisfactorily.
NRC Scenario 2 Scenario 2 Rev 1 Scenario Timeline: Event Malfunction Severity Ramp HH:MM:SS Delay Trigger EPR09 A 1.5 N/A N/A N/A Precipitation at 1.
5 inches per hour EGR29 A N/A NA NA N/A EDG A output breaker racked out EG10 A N/A NA NA N/A EDG A overspeed device pulled 1 CV01 B N/A N/A N/A 1 Charging Pump B trip 2 N/A N/A N/A N/A N/A Dry Cooling Tower Fan 8A failure 3 FW27 FW28 M M 0% 35% N/A N/A 3 Isophase Bus Fan failure 4 RC04 C N/A N/A N/A 4 RCP 2A Sheared Shaft 4 RD24 A, B, E, F N/A N/A N/A N/A Reactor Trip Breakers 1, 2, 5, & 6 fail to open 5 RD11A 44 N/A N/A N/A N/A CEA 44 stuck out after reactor trip 5 RD11A 68 N/A N/A N/A N/A CEA 68 stuck out after trip 6 ED01 A, B, C, D N/A N/A N/A 6 Loss of Off Site Power 7 EG08 B N/A N/A N/A N/A EDG B Fail to Auto-start B_E07 B_E08 N/A N/A 00:02:30 00:04:00 6 Dry Cooling Tower 1 & 2 high level alarm NRC Scenario 2 Scenario 2 Rev 1
REFERENCES:
Event Procedures 1 OP-901-112, Charging or Letdown Malfunction Tech Spec 3.1.2.4, 3.8.1.1
TRM 3.1.2.4 2 Tech Spec 3.7.4 3 OP-003-034, Feed Heater Vents and Drains OP-500-001, Annunciator Response for Control Room Cabinet A
OP-010-005, Plant Shutdown 4 OP-902-000, Standard Post Trip Actions OP-902-009, Standard Appendices, Appendix 1, Diagnostic Flow Chart 5 OP-901-103, Emergency Boration 6 OP-902-003, Loss of Off Site Power/Loss of Forced Flow OP-902-009, Standard Appendic es, Appendix 20, Operat ion of Dry Cooling Tower Sump Pumps
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 Page 1 of 16 Event
Description:
Charging Pump B Trip Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 Note All controls for the Charging manipulations are on CP-4 ATC Recognize and report indications of Charging Pump B trip. Alarms:
Charging Pump B Trip/Trouble (Cabinet G, B-6)
Charging Pumps Header Flow Lo (Cabinet G, H-5)
Charging Pump B Not Available (Cabinet G, A-6) Indications:
Charging flow and Charging Header pressure drop Charging Pump B control switch indicates stop Examiner Note There are steps in off normal OP-901-112, Charging or Letdown Malfunction, to manually start a standby Charging Pump after verifying a suction path. It is acceptable for the CRS to direct this action prior to entering OP-901-112 to avoid isolating the Charging and Letdown system on high temperature. If this is directed, the CRS should still enter OP-901-112 even after a Charging Pump is running. CRS Enter and direct the implementation of OP-901-112, Charging or Letdown Malfunction. CRS 1. Stop turbine load changes. CRS 3. IF a Charging Malfunction is indicated, THEN go to Subsection E 1 , Charging Malfunction. CRS should evaluate E 0 and go to sub-section E
- 1. CRS Procedure Note If all Charging Pumps are secured, then LETDOWN STOP VALVE (CVC 101) will close on high REGEN HX TUBE OUTLET temperature if RCS is 470°F. This condition is applicable to the plant conditions. Regen Heat Exchanger temperature will rise to the 470 °F setpoint. Time is available for the crew to take action prior to isolation.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 Page 2 of 16 Event
Description:
Charging Pump B Trip Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 CRS Procedure Caution THE REACTOR COOLANT SYSTEM WILL BE BORATED IF A CHARGING PUMP IS STARTED WITH THE RWSP AS THE MAKEUP WATER SOURCE. ATC 1. IF Charging Pumps have tripped, THEN perform the following: 1.1 Verify open EITHER VCT DISCH VALVE (CVC 183) OR RWSP TO CHARGING PUMP (CVC 507). 1.2 IF Letdown has NOT isolated, THEN attempt to restart Charging Pump(s). 1.3 IF the Charging Pump can NOT be restarted, THEN verify closed LETDOWN STOP VALVE (CVC 101). 1.4 IF the reason for the Charging pump trip is corrected AND Pressurizer level is in normal operating band, THEN place Charging and Letdown in service in accordance with OP-002-005, CHEMICAL AND VOLUME CONTROL. The ATC operator should verify a Charging Pump suction path via CVC-183 prior to starting another Charging Pump. Either Charging Pump A or AB can be started. This action is typically directed by the CRS.
If the crew does not start another Charging Pump prior to Letdown isolating at 470 °F, then the crew should reestablish Charging and Letdown in accordance with OP-002-005. CRS 2. IF normal Charging flow can NOT be established AND Pressurizer level falls below minimum Pressurizer level for operation in accordance with , Pressurizer Level Versus Tave Curve, THEN perform the following: This step should not be applicable due to the duration of the malfunction. Crew 3. IF the PMC is available, THEN display PMC Group CVCS and monitor Charging System parameters to determine cause of Charging malfunction. This data can be retrieved by any member of the crew. PMC point D39704, CVCS CHG PMP MTR B OVLD TRIP and D39702, CVCS CHG PMP MTR B TRP/TRBL will provide indication of the electrical failure of Charging Pump B.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 Page 3 of 16 Event
Description:
Charging Pump B Trip Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 CRS Evaluates Tech Spec and TRM 3.1.2.4 and enters both. Additionally, with Emergency Diesel A out of service, the crew will no longer be in compliance with Tech Spec 3.8.1.1.d. Tech Spec 3.1.2.4 can be exited and 3.8.1.1.d complied with by aligning Charging Pump AB to replace B for SIAS. The CRS should remain in TRM 3.1.2.4 after this operation. ATC Align Charging Pump AB to replace B on SIAS by aligning the Pump AB Assignment switch to the B position on CP-4. CRS Exit Tech Spec 3.1.2.4 and determine compliance with Tech Spec 3.8.1.1.d. Crew must remain in TRM 3.1.2.4. Examiner Note This event is complete after Charging Pump AB is aligned to replace Charging Pump B Or As directed by the Lead Evaluator
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 2 Page 4 of 16 Event
Description:
Dry Cooling Tower Dry Fan 8A failure Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 This failure is called in by the Outside Watch for the purpose of evaluating Tech Spec 3.7.4. The simulator operator will call the CRS on cue from the Lead Examiner. CRS On receiving information regarding DCT Fan 8A, evaluates Tech Spec 3.7.4. Crew A member of the crew should determine that DCT Fan 8A is under the missile shield. CRS Determine that with a fan under the missile shield inoperable during a tornado watch (provided during the turnover), entry into Tech Spec 3.7.4.c is required. This is a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> shutdown action. The tornado watch will not expire before this action is required. The crew will not perform a shutdown before the next malfunction is inserted. Examiner Note This event is complete when the CRS has completed addressing Tech Specs Or As directed by the Lead Evaluator
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page 5 of 16 Event
Description:
5A Normal Level Control Valve Failure / Plant shutdown Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 BOP Recognize and report indications of Heater 5A Normal Level Control Valve failure. Alarms:
Heater 5A Level Hi-Hi (Cabinet A, B-8)
Heater 5A Level Hi/Lo (Cabinet A, C-8)
Heater 5A Alt Drain Vlv Open (Cabinet A, D-8) Indications:
Heater 5A level rising on the Plant Monitoring Computer Heater 5A & 6A isolate when CD-189 A and CD-175 A close on CP-13 Examiner Note The annunciator response refers to OP-003-034, Feed Heater Vents and Drains. It directs a power reduction to 893 MWe, 72% power. BOP Report guidance from OP-500-001, Annunciator Response for Control Room Panel A: 1.4 Review OP-003-034, Feed Heater Vents and Drains, for Power Limitations associated with FHD Heater Strings out of service. CRS Refer to OP-003-034, Feed Heater Vents and Drains. CRS Limitation 3.2.1 Utilize the following table to determine the maximum allowed power level with the listed FW Heater(s) out of service. OOS Condition Bypass Open Bypass Closed Any Single IP or LP Heater (Note 1) 893 MWe (72%) 893 MWe (72%)
CRS should conclude a power reduction to 72% is required.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page 6 of 16 Event
Description:
5A Normal Level Control Valve Failure / Plant shutdown Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 CRS Enters OP-010-005, Plant Shutdown. CRS Procedure Note (1) Because of the absence of adequate airflow across the installed thermocouples while in this alignment, computer points A58010, A58011, and A58012 should not be used to monitor Isophase Bus return air for temperature. Utilize a Pyrometer or equivalent to measure Isophase Bus Air exhaust temperature. (2) Isophase Bus return air temperature should not be allowed to rise above 158 °F. Note The CRS should direct the TGB Watch to perform steps 1.2 through 1.6. The watch will acknowledge the or der and reply that he will get the procedure and start walking down the evolution. This task will not get accomplished during the scenario. Crew 9.1.2 Prior to commencing power reduction, notify Load Dispatcher. Crew 9.1.3 Announce to Station Personnel that a power reduction is in progress over the Plant Paging System. Crew 9.1.4 Maintain RCS Cold Leg Temperature 536 °F to 549 °F. ATC 9.1.5 Perform Boron Equalization as follows:
Place available Pressurizer Pressure Backup Heater Control Switches to ON. Reduce Pressurizer Spray Valve Controller (RC-IHIC-0100) setpoint potentiometer to establish spray flow and maintain RCS pressure 2250 PSIA (2175 - 2265). This manipulation is performed at CP-2. Note There is a procedure note describing what power indications are preferred for certain power ranges. The CRS should review this note, but the power reduction will not be carried out long enough to see this exercised.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page 7 of 16 Event
Description:
5A Normal Level Control Valve Failure / Plant shutdown Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 ATC Begin Direct Boration as follows: 6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be added on Attachment 11.6, Calculation of Boric Acid Volume for Direct Boration or VCT Borate Makeup Mode. These manipulations are performed at CP-4. The ATC should use the Reactivity Worksheet to recommend a boron quantity to the CRS. 6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Acid desired. The steps for setting the Boric Acid counter are not contained in this step. The ATC operator should press the UP arrow button, the ENTER button, enter the quantity of acid desired, press the ENTER button, and press the RESET button. 6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desired Boric Acid Makeup Pump A(B). 6.7.5 Place Direct Boration Valve, BAM-143, control switch to AUTO. 6.7.6 Place Makeup Mode selector switch to BORATE. 6.7.7 Verify selected Boric Acid Makeup Pump A(B) Starts. 6.7.8 Verify Direct Boration Valve, BAM-143, Opens. Procedure Note The Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is most accurate in the range of 10 - 25 GPM. 6.7.9.1 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual. 6.7.9.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, output to >3 GPM flow rate. 6.7.11 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate or Open. 6.7.12 Observe Boric Acid flow rate for proper indication.
BOP Commence Turbine load reduction by performing the following:
6.2.1.1 Depress LOAD/RATE MW/MIN pushbutton.
6.2.1.2 Depress appropriate numerical pushbuttons for desired load rate.
6.2.1.3 Depress ENTER pushbutton.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page 8 of 16 Event
Description:
5A Normal Level Control Valve Failure / Plant shutdown Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 Procedure Note Prior to changing Reference Demand, Main Turbine load must not be changing.
6.2.2.1 Depress REF pushbutton.
6.2.2.2 Depress appropriate numerical pushbuttons for desired MW load.
6.2.2.3 Depress ENTER pushbutton.
6.2.2.4 Depress GO pushbutton.
6.2.2.5 Verify Turbine load change stops at the desired MW load. This manipulation is performed at CP-1. These steps are from OP-005-007, Main Turbine and Generator. The BOP will set up the Main Turbine controls. The ATC will direct the BOP when to commence unloading the Main Turbine based on the drop in RCS Cold Leg temperature.
CRS / ATC Procedure Caution CONTROL RODS SHOULD NEVER BE WITHDRAWN OR MANUALLY INSERTED EXCEPT IN A DELIBERATE CAREFULLY CONTROLLED MANNER WHILE CLOSELY MONITORI NG THE REACTOR'S RESPONSE.
ATC Operate CEAs to maintain ASI using CEA Reg. Group 6 or Group P Control Element Assemblies. Steps are contained in OP-004-005, Control Element Drive. Group P should be used first to a low limit of 120 inches, followed by CEA Group 6 to a low limit of 120 inches to comply with Tech Spec 3.1.3.6. This manipulation is performed at CP-2.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page 9 of 16 Event
Description:
5A Normal Level Control Valve Failure / Plant shutdown Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 Operate CEAs in Manual Group mode as follows: 6.7.1 Verify Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer. 6.7.2 Position Group Select switch to desired group. 6.7.3 Place Mode Select switch to MG and verify the following: White lights Illuminated on Group Selection Matrix for selected group MG light Illuminates 6.7.4 Operate CEA Manual Shim switch to INSERT group to desired height while monitoring the following: CEA Position Indicator selected CEA group is moving in desired directionIf Reactor is critical, then monitor the following: Reactor Power Reactor Coolant System (RCS) temperature Axial Shape Index (ASI) Procedure Note The Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when the Mode Select switch is not in OFF. 6.7.5 When desired set of moves have been completed, then place Mode Select switch to OFF. Crew 9.1.9 When reactor power consistently indicates less than 98% power, as indicated on computer point C24631, MAIN STEAM RAW POWER (MSBSRAW), or an alternate point provided by Reactor Engineering, then verify the value of C24648, BSCAL SMOOTHING VAL. APPLD (DUMOUT17), automatically changes to 1.
Examiner Note This event is complete when the desired power reduction has been accomplished Or As directed by the Lead Evaluator Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 / 5 Page 10 of 16 Event
Description:
RCP Shaft Shear with ATWS / Manual Reactor Trip / 2 CEAs Fail to Insert on Trip Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 ATC Recognize and report indications of Reactor Coolant Pump 2A shaft shear and failure of the automatic trip. Alarms:
RCP 2A Vibration Hi (Cabinet H, A-8)
RCP 2A Lube Oil Pressure Lo (Cabinet H, E-7)
RPS Channel Trip Local Power Density Hi (Cabinet K, A-11)
RPS Channel Trip DNBR Lo (Cabinet K, A-12)
RPS Channel Trip Coolant Flow Lost (Cabinet K, D-12) Indications:
RCP 2A pressure and amps dropping All CEAs withdrawn 4 Reactor Trip Circuit Breakers closed Critical Task Manually trip the Reactor.
This task is satisfied by establishing manually tripping the reactor within 1 minute of the failure of the automatic trip.
. ATC Trip the Reactor using Diverse Reactor Trip pushbuttons at CP-2 The CRS may direct this operation, but the ATC operator should not request permission or wait for direction to perform this action. ATC Recognize and report indications of 2 CEAs failure to insert. Indications:
CEA 74 and CEA 68 rod bottom lights not illuminated CEA 74 and CEA 68 upper electrical limit lights illuminated Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 / 5 Page 11 of 16 Event
Description:
RCP Shaft Shear with ATWS / Manual Reactor Trip / 2 CEAs Fail to Insert on Trip Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 CRS Direct direct ATC and BOP to carry out Standard Post trip Actions.
ATC Determine Reactivity Control acceptance criteria are met: Check reactor power is dropping. Check startup rate is negative. Check less than TWO CEAs are NOT fully inserted. Critical Task Establish reactivity control.
This task is satisfied by establishing Emergency Boration prior to completing Standard Post Trip Actions Reactivity Control verification.
ATC Determine 2 CEAs are stuck out and commence Emergency Boration:
- 1. Place Makeup Mode selector switch to MANUAL.
- 2. Align borated water source by performing one of the following:
- a. Initiate Emergency Boration using Boric Acid Pump as follows:
Open Emergency Boration Valve, BAM-133.
Start one Boric Acid Pump.
Close recirc valve for Boric Acid Pump started:
o BAM-126A Boric Acid Makeup Pump Recirc Valve A o BAM-126B Boric Acid Makeup Pump Recirc Valve B OR b. Initiate Emergency Boration using Gravity Feed as follows:
Open the following Boric Acid Makeup Gravity Feed valves:
o BAM-113A Boric Acid Makeup Gravity Feed Valve A o BAM-113B Boric Acid Makeup Gravity Feed Valve B 3. Close VCT Disch Valve, CVC-183. 4. Verify at least one Charging Pump operating and Charging Header flow 40 GPM.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 / 5 Page 12 of 16 Event
Description:
RCP Shaft Shear with ATWS / Manual Reactor Trip / 2 CEAs Fail to Insert on Trip Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 BOP Determine Maintenance of Vital Auxiliaries acceptance criteria are met: Check the Main Turbine is tripped: Governor valves closed Throttle valves closed BOP Check the Main Generator is tripped: GENERATOR BREAKER A tripped GENERATOR BREAKER B tripped EXCITER FIELD BREAKER tripped BOP Check station loads are energized from offsite electrical power as follows:
Train A A1, 6.9 KV non safety bus A2, 4.16 KV non safety bus A3, 4.16 KV safety bus A-DC electrical bus A or C vital AC Instrument Channel
Train B B1, 6.9 KV non safety bus B2, 4.16 KV non safety bus B3, 4.16 KV safety bus B-DC electrical bus B or D vital AC Instrument Channel ATC Determine RCS Inventory Control acceptance criteria are met: Check that the following conditions exist: Pressurizer level is 7% to 60% Pressurizer level is trending to 33% to 60% Check RCS subcooling is greater than or equal to 28ºF.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 / 5 Page 13 of 16 Event
Description:
RCP Shaft Shear with ATWS / Manual Reactor Trip / 2 CEAs Fail to Insert on Trip Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 ATC Determine RCS Pressure Control acceptance criteria are met by checking that BOTH of the following conditions exist: Pressurizer pressure is 1750 psia to 2300 psia Pressurizer pressure is trending to 2125 psia to 2275 psia ATC Determine Core Heat Removal acceptance criteria are met: Check at least one RCP is operating. Check operating loop T is less than 13ºF. Check RCS subcooling is greater than or equal to 28ºF. BOP Determine RCS Heat Removal acceptance criteria are met: Check that at least one steam generator has BOTH of the following: Steam generator level is 5% to 80% NR Main Feedwater is available to restore level within 50%-70% NR.
ATC Check RCS T C is 530ºF to 550ºF BOP Check steam generator pressure is 885 psia to 1040 psia. BOP Check Feedwater Control in Reactor Trip Override: MAIN FW REG valves are closed STARTUP FW REG valves are 13% to 21% open Operating main Feedwater pumps are 3800 rpm to 4000 rpm BOP Reset moisture separator reheaters, and check the temperature control valves closed.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 / 5 Page 14 of 16 Event
Description:
RCP Shaft Shear with ATWS / Manual Reactor Trip / 2 CEAs Fail to Insert on Trip Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 ATC Determine Containment Isolation acceptance criteria are met: Check containment pressure is less than 16.4 psia. Check NO containment area radiation monitor alarms OR unexplained rise in activity. Check NO steam plant activity monitor alarms OR unexplained rise in activity. BOP Determine Containment Temperature and Pressure Control acceptance criteria are met: Check containment temperature is less than or equal to 120ºF. Check containment pressure is less than 16.4 psia.
CRS After review of Standard Post Trip Actions, use Diagnostic Flow Chart of OP-902-009 to select appropriate optimal recovery procedure. Proper use of chart will resu lt in use of OP-902-001 Examiner Note This event is complete when the ATC and BOP operators report that they have completed Standard Post Trip Actions and when the CRS commences the review Or As directed by the Lead Evaluator.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 6 / 7 Page 15 of 16 Event
Description:
Loss of Off Site Power / Failure of Emergency Diesel Generator B to Auto Start Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 Crew Alarms Multiple alarms associated with Loss of Off Site Power Indications Numerous alarms come in, all lights go off except for Control Room emergency lighting.
Emergency Diesel Generator B control switch remains green.
Critical Task Energize at least one vital electrical AC bus.
This task is satisfied by starting Emergency Diesel Generator B.
BOP Start Emergency Diesel Generator B at CP-1. CRS Complete OP-902-009, Attachment 1, Diagnostic Flowchart. Proper use of chart will result in use of OP-902-003, Loss of Off Site Power/Loss of Forced Flow Recovery. Crew 1. Confirm diagnosis of a Loss of Offsite Power or a Loss of Forced Circulation by checking Safety Function Status Check Acceptance Criteria are satisfied. Crew 2. Announce a Loss of Offsite Power or a Loss of Forced Circulation is in progress using the plant page. CRS 3. Advise the Shift Manager to REFER TO EP-001-001, "Recognition & Classification of Emergency Condition" and implement the Emergency Plan. CRS 4. IF power has been interrupted to either 3A or 3B safety buses, THEN perform Appendix 20, "Operation of DCT Sump Pumps" CRS should direct this action to a non-licensed operator.
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 6 / 7 Page 16 of 16 Event
Description:
Loss of Off Site Power / Failure of Emergency Diesel Generator B to Auto Start Time Position Applicant's Actions or Behavior Scenario 2, Revision 0 BOP 6. IF offsite power has been lost, THEN verify the sequencer has timed out for at least one 4.16KV safety bus. BOP 7. Check a CCW pump is operating for each energized 4.16KV safety bus. CRS / BOP
- 8. IF offsite power has been lost, THEN: a. Verify MSIVs are closed.
- b. Verify following steam generator blowdown isolation valves are closed: BD 102A, SG BLOWDOWN ISOL STM GEN 1 (IN) BD 102B, SG BLOWDOWN ISOL STM GEN 2 (IN) BD 103A, SG BLOWDOWN ISOL STM GEN 1 (OUT) BD 103B, SG BLOWDOWN ISOL STM GEN 2 (OUT) This step is marked such that the CRS can move this forward at his discretion. This step could be performed prior to directing the restoration of the Dry Cooling Tower Sump Pumps. Examiner Note This event is complete after directing performance of Appendix 20 to restore the Dry Cooing Tower Sump Pumps Or As directed by the Lead Evaluator.