ML20091R539
| ML20091R539 | |
| Person / Time | |
|---|---|
| Site: | Comanche Peak  |
| Issue date: | 06/05/1984 |
| From: | TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC) |
| To: | |
| Shared Package | |
| ML20091R532 | List: |
| References | |
| TRA-299, NUDOCS 8406150161 | |
| Download: ML20091R539 (34) | |
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COMANCHE PEAK STEAM ELECTRIC STATION e TRAINING MANUAL ERll/ESR/#T/uQ/ty n
SHIFT ADVISOR TRAINING AND QUALIFICATIONS O
PROCEDURE NO. TRA-299 REVISION NO. 0 XDh-SAFE Y-EfD S - - ,T: er am ADMINISTRATIVE SUPE INTENDENT
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CPSES ISSUE DATE PROCEDURE NO.
TRAINING MANUAL p g.y D'l lJ04 TRA-299 4 \
SHIFT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 2 0F 20 1.0 Purpose This procedure describes the Qualifications and Training Requirements for Shift Advisors.
e 2.0 Applicability This procedure is applicable to individuals assigned as Shift Advisors to the Operations Department and becomes pffective upon issuance.
3.0 Definitions 3.1 Shift Advisor - That individual who acts as an operations advisor on shift, and recommends appropriate actions (including shutdown) to the Shift Supervisor. The responsibilities of the Shift Advisors are delineated in ODA-102, " Shift Complement, Responsibilities And Authorities".
4.0 Instructions 4.1 Qualifications (3
(_) At the time of initial fuel loading, Shift Advisors shall have the following qualifications.
4.1.1 Four (4) years of power plant experience.
4.1.2 Two (2) years of Nuclear Power Plant Experience.
4.1.3 0.te (1) year of experience as an on-shif t licensed senior operator at an operating PWR plant.
4.2 Training l
Shift Advisor Training is divided into the following areas:
General Training, Procedure Training, Specialty Tra!ning, and Recurrent Training.
4.2.1 General Training: This area includes subjects which are general in nature and may be a requirement for station SCCess.
4.2.1.1 The Shif t Advisor must complete the tr aining requirements for unescorted access into the
' Protected Area in accordance with TRA-101,
" General Employee Tra:ining".
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l l
s CPSES ISSUE DATE PROCEDURE NO.
TRAINING MANUAL Q 7 M4 TRA-299
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SHIFT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 3 0F 20 ,
4.2.1.2 The Shift Advisor must complete the training requirements for unescorted access into Radiation Controlled Areas in accordance with TRA-102,
" Radiation Worker Training".
4.2.1.3 The Shift Advisor may complete the training requirements for the use of respiratory
. protection equipment in accordance with TRA-103,
" Respiratory Protection Training".
4.2.2 Procedure Training: This area includes training in station procedures and programs. The procedure training checklist is contained in Attachment 1.
4.2.3 Specialty Training: This area consists of formal classroom training, informal training obtained by reading applicable material, on-shift training or attending special seminars or meetings as necessary. The curriculum for formal classroom training is described in Attachment
- 2. Attachment 3 is typical schedule for classroom training.
O- 4.2.4 Recurrent Training Shift Advisors shall attend the Operator Proficiency Lecture Series as described in paragraph 4.2.2 of CPSES Procedure, TRA-204, " Licensed Operator Requalification Training Program". This lecture series includes the following topics:
4.2.4.1 Administrative Procedures, Conditions, and Limitations, including Technical Specifications.
4.2.4.2 Major Operational Evolutions 4.2.4.3 Facility Design and License Changes 4.2.4.4 Procedures - Normal, Abnormal. Emergency Operating, and Radiological Control 4.2.4.5 Operating History and Problems 4.2.4.6 Related Nuclear Industry Operating Experience 4.2.4.7 Procedure Changes 4.2.4.8 Reportable Occurrences O
1
-r CPSES ISSUE DATE PROCEDURE NO.
TRAINING MANUAL })pg 07 }S84 TRA-299 L
SHIFT ADVISOR TRAINING AND QUAI.IFICATIONS REVISION NO. O PAGE 4 0F 20 .
4.2.5 Exemptions Exemptions from certain courses may be allowed for appropriately qualified individuals. Exemptions shall,be justified, documented and approved by the Operations .
Supervisor or the Operations Superintendent.
4.3 Examinations And Verification 4.3.1 Examinations may be written or oral as specified by the course description. Some courses may require attendance only for successful completion. Procedure reviews require the reviewers signature and a verification signature by the Operations Superintendent or Operations Supervisor.
4.3.2 An oral review will be conducted with each Shift Advisor to ensure that their responsibilities, duties and training
~
requirements are understood.
4.3.2.1 The review shall be conducted by any three of the following members of plant management, all of whom should be qualified at the SRO level:
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4.3.2.1.1 Operations Superintendent 4.3.2.1.2 Operations Supervisor 4.3.2.1.3 Operations Engineer 4.3.2.1.4 Shift Supervisor 4.3.2.1.5 Assistant Shift Supervisor 4.3.2.2 The review shall include the areas listed in Attachment 4.
4.3.2.3 Attachment 4 shall be utilized to document the review.
4.3.3 Shift Advisors should successfully complete written or oral examinations covering the topics listed in section 4.2.4, " Recurrent Training" . The examinations are normally administered at the conclusion of each recurrent training cycle.
4.4 Program Evaluation s 4.4.1 The Shift Advisor training may be periodically evaluated as
- part of the Operations Department Training Program in accordance with CPSES Procedure, NOT-110 " Evaluating the Effectiveness of Training".
l CPSES ISSUE DATE PROCEDURE NO.
TRAINING MANUAL ~ pg g 7 ]304 j TRA-299 SHIFT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 5 0F 20 4.4.2 The Operations Supervisor shall evaluate the effectiveness of training by using individual Shif t Advisor performance on shift as the basis. He shall specify the need for re-training or additional training.
4.5 Documentation Training shall be documented in accordance with CPSES Procedure, NOT-104, " Training Records". '
5.0 References 5.1 CPSES Procedure TRA-101, " General Employee Training" 5.2 CPSES Procedure TRA-102, "Ra'diation Worker Training" 5.3 CPSES Procedure TRA-103, " Respiratory Protection Training" 5.4 CPSES Procedure TRA-204, " Licensed Operator Requalification Training Program"
/ ;
5.5 CPSES Procedure NOT-104, " Training Records" 5.6 CPSES Procedure NOT-110. " Evaluating the Effectiveness of Training" 5.7 CPSES Procedure ODA-102, " Shift Complement, Responsibilities and Authorities.
6.0 Attachments 6.1 Shift Advisor Procedure Training, Attachment 1 6.2 Shift Advisor Classroom Training, Attachment 2 6.3 Shif t Advisor Training Schedule (Typical), Attachment 3
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3 CPSES ISSUE DATE PROCEDURE NO.
TRAINING MANUAL - J{Jg-$f1904 TRA-299
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SHIFT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 6 0F 20 ATTACHMENT 1 PAGE 1 0F 8 SHIFT ADVISOR PROCEDURE TRAINING .
PROCEDURE NUMBER -
TITLE SIGNATURE /DATE STA-204 Temporary Procedures
'STA-205 Temporary Changes to Procedures STA-207 Special Orders, Night Orders, and Management Memorandums STA-403 Identification of Safety-Related Equipment STA-501 Reporting of Operating Information to the NRC STA-503 Reporting of Operating Information to Regulatory Agencies other Than NRC STA-504 Problem Report Authority for Equipment Operations
(^) STA-601 STA-602 Temporary Modifications and Bypassing of Safety Functions STA-605 Clearance and Safety Tagging, STA-606 Maintenance Action Requests STA-610 Secondary Water Chemistry Control STA-615 Staff Work Hours STA-616 Control Room and Observation Area Access STA-702 Surveillance Test Program STA-703 ISI Program
-0DA-101 Operations Department Organization and Responsibilities ODA-102 Shift Complement, Responsibilities, and Authorities ODA-104 Operations Department Document Control ODA-107 Reporting of Operational Incidents
-0DA-301 Operating Logs ODA-302 Relief of Personnel ODA-303 Conduct of Personnel in Control Room ODA-401 Disabling of Control Panel Annunciators / Instruments EPP-104 Drills and Exercises EPP-109 Duties of the Emergency Coordinator VERIFIED: DATE:
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'- SIGNATURE / TITLE i TRA-299-1
1 l
- \
CPSES ISSUE DATE PROCEDURE NO. l TRAINING ME -
m-M
. f % } 7 iqhd SHIFT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 7 0F 20 .
l ATTACHMENT 1 PAGE 2 0F 8 SHIFT ADVISOR PROCEDURE TRAINING ,,
PROCEDURE NUMBER - TITLE SIGNATURE /DATE EPP-112 Duties of Emergency Response Personnel EPP-201 Assessment of Emergency Action Levels and Plan Activation EPP-203 Emergency Notification and Communications EPP-204 Emergency Facility Activation EPP-305 Personnel Dosimetry for Emergency Condition FIR-101 Fire Protection Program FIR-102 Fire Emergency Plan FIR-103 Fire Reporting -
[~) FIR-104 Fire Brigade
Control of Transient Combuscables FIR-107 -
and Ignition Sources FIR-109 Fire Watches HPA-101 ALARA Program HPA-108 Radiation Incident Identification and Repcrting HPA-112 Radiation Work Permits HPA-115 Control of Contaminated Spilla RFO-101 Refueling Organization RFO-102 Refueling Operation RFO-103 Fuel Handling Emergencies RFO-301 Handling of New Fuel and Shipping ,
Containers During F,uel Receipt Operations RFO-302 Handling of Fuel Assemblies During Refueling Operations RFO-303 Handling of Rod Cluster Control Assemblies rad Core Components OPT-104 Operations Weekly Routine Tests OPT-106A Control Rod Excerise OPT-107A Seismic Monitoring Instrumentation Check OPT-108A Remote Shutdown Instrument Channel Check VERIFIED: DATE:
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\_ SIGNATURE / TITLE TRA-299-la
E ,
CPSES ISSUE DATE PROCEDURE NO.
-y TRAINING MANUAL ggy M TRA-299 L.;
SHIFT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 8 0F 20 ATTACHMENT 1 PAGE 3 0F 8 SHIFT ADVISOR PROCEDURE TRAINING .
PROCEDURE NUMBER TITLE SIGNATURE /DATE OPT-109A PORV and Block Valve Operability Test OPT-110A RCP Controlled Leakage Measurement OPT-111A Accumulator Isolation Valve Breaker Check OPT-112A Accident Monitoring Instrument Channel Check OPT-113A Containment Purge Supply and Exhaust Position Check OPT-201A/B Charging System Operability OPT-202A/B Boration System Operability '
,q OPT-203A/B Residual Heat Removal Syatem V OPT-204A/B Operability Safety Injection System Operability OPT-205A/B Containment Spray System Operability OPT-206A/B ,. Auxiliary Feedwater System Operability OPT-207A/S Service Water System Operability OPT-208A Component Cooling Water System Operability OPT-210A/B Control Room Emergency Air Cleanup System Operability Test OPT-213A/B ESF Exhaust Air Cleanup System Operebility Test OPT-214A/B Diesel Generator Operability OPT-215A/B Preferred AC Source Operability OPT-217A Main Turbine Stop and Control Valve Test OPT-218A/B Containment Isolation Valve Operability (Testable during Operation)
OPT-219A Containment Penetration Non-Automatic Isolation Valve Position Verification (IRC)
OPT-220A Fire Suppression Water and Sprinkler System Operability Test OPT-301 Reactor Shutdown Margin Verification OPT-302 Calculating Pcwer Tilt Ratio OPT-303 Reactor Coolant System Water Invantory V VERIFIED: DATE:
SIGNATURE /TilLE TRA-299-lb
CPSES ISSUE DATE PROCEDURE NO.
TRAINING MANUAL TRA-299 '
mJM J7 M; (m.-) REVISION NO. O PAGE 9 0F 20 SHIFT ADVISOR TRAINING AND QUALIFICATIONS ..,.
ATTACHMENT 1 l PAGE 4 0F 8 SHIFT ADVISOR PROCEDURE TRAINING PROCEDURE NUMBER TITLE SIGNATURE /DATE OPT-304 Leak Test of Reactor Coolant System After Opening OPT-305 Inspection Following Containment Maintenance OPT-306 Containment Sump Inspection OPT-307A/B Residual Heat Removal System Isolation OPT-308 Calculating Estimated Critical Condition OPT-309 Unit Calorimetric __
OPT-401A Reactor Coolart System Temperature Verification
(~ OPT-402A Shutdown Rod Surveillance
( ,3/ OPT-403A Axiel Flux Difference OPT-400A Final Actuation Devico Test OPT-407A Reactor Coolant System Heatup/ Cool-down Limitations Verification OPT-408A Containment Integrity Verification OPT-409A Steam Generator Low Temperature Limitation Verification OPT-410A Turbine Trip Checks - Startup Mode OPT-411A Refueling Water Level Check TRA-203 Replacement License Training TRA-204 Licensed Operator Requalification Training Program TRA-299 Shift Advisor Training and Qualifications E0P-0.0 Reactor Trip or Safety Injection EOS-0.1 Reactor Trip Recovery EOS-0.2 Natural Circulation Cooldown EOS-0.3 SI Termination Following Spurious SI EOS-0.4 Natural Circulation Cooldown with Steam Void in Vessel Upper Hand E0P-1.0 Loss of Reactor Coolant (LOCA) <
EOS-1.1 S1 Termination Following LOCA E05-1.2 Post-LOCA Cooldown and Depressurization EOS-1.3 Transfer to Cold Leg Recirculation Tollowing LOCA
() VERIFlu):
SIGNATURE / TITLE DATE:
TRA-299-Ic
.l CPSES ISSUE DATE PROCEDURE NO.
TRAINING MANUAL- ]W$ 7 ISO 4 TRA-299 SHIFT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 10 0F 20 .
ATTACHMENT 1 PAGE 5 0F 8 A SHIFT ADVISOR PROCEDURE TRAINING c PROCEDURE NUMBER -
TITLE SIGNATURE /DATE
.EOS-1.4 Transfer to Hot Leg Recirculation Loss of Secondary Coolant (LOSC)
~
- E0P-2.0 EOS-2.1 SI Termination Following LOSC EOS-2.2 Transfer to Cold Leg Recirculation Following LOSC E0P-3.0 Steam Generator Tube Rupture (SGTR)
EOS-3.1 SI Termination Following SGTR EOS-3.2 SGTR Alternate Cooldown By Backfilling RCS
. EOS-3.3 SGTR with Secondary Depressurization ECA-1.0 Anticipated Transient Without Trip 2= (ATWT)
ECA-2.0 Loss of All AC Power ECA-2.1 Loss of All AC Power Recovery Without SI Required ECA-2.2 Loss of All AC Power Recovery With SI Required EC..-3. 0 SGTR Contingencies j ECA-4 Response to Multiple Steam Generator
- Depressurization i' ECA-5 Loss of Emergency Coolant i Recirculation ECA-6 Secondary High Energy Line Rupture with Loss of SI Function ECA-7 Combined SGTR and LOCA
, ECA-8' Unisolable SGTR ECA-9 SGTR Without Pressurizer Pressure Control FRS-0.1 Response to Nuclear Power Generation FRS-0.2 Response to Loss of Core Shutdown FRC-0.1 Response to Inadequate Core Cooling FRC-0.2 Response to Degraded Core Cooling FRC-0.3 Response to Potential Loss of Core Cooling FRC-0.4 Response to Saturated Core Cooling Conditions
. VERIFIED: DATE:
'O sicuituater11ts TRA-299-1d
CPSES ISSUE DATE PROCEDURE NO.
TRAINING MANUAL TRA-299
,f3 ~' M 0 7 19(H
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lv SHIFT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 11 0F 20 ATTACHMENT 1 t PAGE 6 0F 8 SHIFT ADVISOR PROCEDURE TRAINING j PROCEDURE NUMBER TITLE SIGNATURE /DATE FRP-0.1 ~ Response to Imminent Pressurized 4 Thermal Shock Conditions FRP-0.2 Response to Anticipated Pressurized Thermal Shock Conditions FRH-0.1 Response to Loss of Secondary Heat Sink
.FRH-0.2 Response to Steam Generator Overpressure FRH-0.3 Response to Steam Generator High Level j FRH-0.4 Response to Steam Generator Low Level.
FRN-0.5 Response to Loss of Steam Generator PORV's and Condenser Dump Valves
.() .FRZ-0.1 FRZ-0.2 Response to Containment High Pressure Response to High Containment Sump Level FRZ-0.3 Response to High Containment Radiation Level FRI-0.1 Response to Pressurizer Flooding FRI-0.2 Response to Low System Inventory FRI-0.3 Response to Voids in Reactor Vessel-ABN-101 Reactor Coolant Pump Trip / Mal-functions l ABN-102 High Reactor Coolant Activity ABN-103 Excessive Reactor Coolant Leakage ABN-104 Residual Heat Removal System Mal-
- function ABN-105 Chemical and Volume Control System Malfunctions ABN-106 High Secondary Activity ABN-301 Instrument Air System Malfunction ABN-302 Feedwater, Condensate Heater Drain System Malfunction ABN-304 Main Condenser and Circulating Water System Malfunction ABN-401 Main Turbine - Generator Malfunctions ABN-501 Station Service Water System l
Malfunction DATE:
O VERIFIED:
SIGNATURE / TITLE TRA-299-le j
4
CPSES ISSUE DATE PROCEDURE NO.
g TRAINING MANUAL p jg g TRA-299 b
SHIFT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 12 0F 20 ATTACHMENT 1 PAGE 7 0F 8 SHIFT ADVISOR PROCEDURE TRAINING PROCEDURE NUMBER ,
TITLE SIGNATURE /DATE ABN-502 Component Cooling Water System Malfunction ABN-601 138/345 KV High Voltage Interruption ABN-70L Source Range Instrumentation Malfunction ABN-702 Intermediate Range Instrumentation Malfunction ABN-703 Power Range Instrumentation Malfunction ABN-704 T /N-16 Instrumentation Malfunction ABN-705 PEessurizer Pressure Instrumentation Malfunction
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ABN-706 Pressurizer Level Instrumentation Malfunction ABN-707 Steam Flow Instrumentation Malfunction ABN-708 Fn.edwater Flow Instrumentation
- halfunction ABN-709 S/G Pressure, Steam Hender Pressure, and Turbine 1st Stage Pressure Instrumentation Malfunction ABN-710 Steam Generator Level Instrumentation Malfunction ABN-711 Loss of Protection and/or Instrument Bus ABN-712 Rod Control System Malfunction ABN-901 Fire Protection System Malfunctions ABN-902 Accidental Release of Radioactive Gas ABN-903 Accidental Release of Radioactive Liquid ABN-904 Accidental Release of Chlorine Gas ABN-905 Loss of Control Room Habitability ABN-906 Loss of P2500 Computer ABN-907 Acts of Nature ABN-908 Fuel Handling Accident VERIFIED: DATE:
SIGNATURE / TITLE
CPSES ISSUE DATE PROCEDURE NO.
TRA-299 TRAINING MANUAL 3NIJ7 W4 V
091FT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 13 0F 20 .
ATTACHMENT 1
[
PAGE 8 0F 8 SHIFT ADVISOR PROCEDURE TRAINING .
PROCEDURE NUMBER TITLE SIGNATURE /DATE IPO-001 Plant Startup from Cold Shutdown to Hot Standby IPO-002 Plant Startup from Hot Standby to MJnimum Load IPO-003 Power Operations IPO-004 Plant Shutdown from Minimum Load to Hot Standby IPO-005 Plant Shutdown from Hot Standby to Cold Shutdown IPO-007 Maintaining Hot Standby __
IPO-008 Plant Shutdown from Hot Standby to Cold Shutdown Outside of Control
- Room VERIFIED
- DATE:
SIGNATURE /IITLE TRA-299-1g
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CPSES e ISSUE DATE PROCEDURE NO.
TRAINING MANUAL TRA-299
. . . .QW 071984
%J SHIFT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 14 0F 20 ATTACHMENT 2 PAGE 10F 2 SHIFT ADVISOR CLASSROOM TRAINING ,,
Subject Approximate Classroom Hours Turbine / generator EHC 6 Steam Generator 2 Reactor Coolant Pump 2 Steam Generator Water Hammer Interlocks 2 Steam Generator Water Level Control 2 Pressurizer Pressure and Level 4 Steam Duup 2 Excore Instruments 4 Incore Instruments 3 Loose Parts Monitoring 1 1
N-16 Power / Flow RCS Temperature 1 Upgrade Protection Package 2 Rod Control 5 f~') Rod Position Indication and Rod Insertion Limits 3
Subcooled Margin Monitoring 1 Seismic Monitoring 1 Plant Lomputer 2 ,
Reactor Protection 5 Control Logic 2 Control System Failure Analysis 5 Abnormal Procedures 5 Emergency Operating Procedures 5 Integrated Plant Operating Procedures 4 Technical Specifications 6 Technical Data Book 2 Industry Transients 3 Accident Analysis 3 Increase Heat Removal 2 1
Decrease Heat Removal Decrease Flow Rate 2 Reactivity Anomalies . 2 Decrease Inventory 2 Increase Inventory 1 Radioactive Release 2 ATWI 3 Forced Flow 2 Natural Circulation 2 ERG 7 ECA 2 5
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CPSES ISSUE DATE PROCEDURE NO.
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TRAINING MANUAL 07198j TRA-299 s'
SHIFT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 15 0F 20 .:
ATTACHMENT 2 PAGE 2 0F 2 SHIFT ADVISOR CLASSROCM TRAINING ,.
Subject Approximate Classroom Hours Hydrogen Gas 2 Containment Response 2 Radiological Consideration 2 Instrumentation 3 Review 5 Exam 10 0
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O CPSES ISSUE DATE PROCEDURE NO.
TRAINING MANUAL TRA-299 JUN 0 71984.
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CPSES ISSUE DATE PROCEDURE NO.
73 TRAINING MANUAL RN I)719 TRA-299 V
i SHIFT ADVISOR TRAINING AND QUALIFICATIONS REVISION NO. O PAGE 20 0F 20 .i ATTACHMENT 4 PAGE 1 0F 1 COMANCHE PEAK STEAM ELECTRIC STATION ,.
SHIFT ADVISOR ORAL REVIEW AND CERTIFICATION .
SHIFT ADVISOR R Qualifications confirmed
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Operations Superintendent Date
[ Ceneral Training Complete l l General Employee Training C Respiratory Protection Training (Optional) l l Radiation Worker Training
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Director, Nuclear Training Date
[ Specialty Training Complete /
Director Nuclear Training Date U Procedure Training Complete /
Operatione Supervisor Data f I l Oral Review U Understands responsibilities and authorities (ODA-102)
C Understands initial and recurrent training requirements (TRA-299)
Cosmaants ( Additional comment pages attached:)
Certification of Qualifications and Training Completion
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Signature Title Date
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Signature Title Date O / /
Signature Title Date TRA-299-2
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Attachment 5 5.hift Advisor. Examinations 4'- and Examination Results
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EXAM KEY COURSE NAME SHIFT ADVISOR TRAINING EXAM 1 Date MAY 11, 1984 TOTAL POINTS 39.0 1
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SUBMITTED BY : -
DATE : d //M I7 APPROVED BY : i N DATE : ~# I
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i i NOT-105-1 Form C Rev. O
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'. s 5 MCD 3 Q. List at least six precautions or (3) limitations referenced in EOS-1.1 for starting a reactor coolant pump. ,-
6 MCD 3 A. 1. Ensure steam bubble in Pzr
(.5 each) 2. ' Starting duty requirements
- a. Not more than once per 30 minutes
- b. Three starts maximum in a 2-hour period
- 3. Seal injection temp less than 130*F
. 4. If CCW lost, RCP stopped if bearing temp increases to 200*F'
- 5. No more than 6 starts per day throughout. life of RCP motor
- 6. Only one RCP started at any one time
- 7. Start RCP after oil lift pump operation for 2 minutes; continue oil lift pump for 50 sec after start
- 8. Min differential pressure of 200 psid across #1 seal
- 9. Component cooling to RCP's maintained at or below 105 F
- 10. Various alarms cleared:
VCT pressure HI/LO RCP seal leakoff flow high RCP oil reservoir HI/LO RCP standpipe level HI/LO CCW to RCP alarms (several)
(L RES Pressow >325fs s
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- 1* SG 1 Q. Describe the path of water flowing (4) through the steam generator. List each component the water encounters and the,, function or purpose of that components. Include the recircu-la' tion water flow.
2' SG 1 A. - Water enters:through thermal sleeve near.the bottom of the SG. Enters the preheater section, flows to the middle of the tube bundle, through flow slots which direct most of the flow up and a little down. The
. upward flow is forced to crossflow the tubes by the preheater baffles.
. r Boiling occurs when the water leaves the.preheater, mixes with
. recirculated water from other side
- of tube bundle and-flows through tube bundle passing through drilled holes in tube support plates.
Exits tube bundle and flows-through 12 pipes containing swirlvane moisture separators which force the heavier water out of the steam and ,
return it-to the downcomer. The partially-dried steam enters the 1 dryer box which consists of many "
chevron vanes which force the steam to make a torturous path through.
the dryer box. The. moisture cannot make the sudden direction changes and is separated and returned to tha downcomer via J-tuEes. The steam leaves out the tope of the SG through flow restrictor venturis.-
The water separated from the moisture separators flows down the
!- -annulus region (downcomer) between
[. the tube bundle wrapper plate and the SG shell and flows under the wrapper, across the tube sheet and then up through the flow distribu-tion baffle and into the tube bundle.
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s 9 SGLC' 5 Q. List all inputs to the steam gener-
-(1.5) ator level control system, in-cluding. bypass control and feed pump sp'eed control.
10 SGLC 5 A. Steam Flow Feed Flow
-Narrow range ~ level Programmed level Auctioneered nuclear power Steam pressure Feed pressure 5 MF 3 Q. What conditions must be met-(or (2) satisfied) before the water hammer permissive circuits will allow the feed isolation valve (FIV) to open?
Which valves open with.the FIV?
Which valves would be' closed?
'6 MF 3 A. Flow greater'than 2%. (.25)
Feed temperature greater than 200*
and AT in feed line less than 5*.
(.5)
S/G level above lo-level setpoint.
(.25)
S/G pressure above minimum setpoint. (.25)
FIBV open. (optional)
FBTV opens with FIV. (.25)
FIBV and FPBV close when FIV opens.
(.5) l
- e 25* MT 13 Q. List all the different fluid cir-(3) cuits of the turbine hydraulic control system. _ List what each
-circuit',does.
26 MT 13 'A. a. Startup-fluid--sequences the HP and LP stop valves opening sequence during startup; or it operates the test valves for the HP and LP stop valves to open then during startup.
- b. Aux startup fluid--resets the main trip. valve and mechanical trips.
- d. Aux trip fluid--holds the main trip valve open,
- e. Secondary fluid--supplies a variable fluid pressure to the control valves to vary their position.
- f. Aux secondary fluid--fluid pressure signal supplied to EH convertor from the MHC; or
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this pressure determines the position of the EH convertor
- follow-up pistons.
.1 SD 1 Q. Describe the arrangement and-(1) number of valves in the steam dump system.
2 SD 1 A. 4 banks of valves with three dump valves per bank.
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- 9. SD 5 Q. Describe the P-12 interlock in the i
. (2) steam dump system and the reason for it. . Can this interlock be blocked or bypassed? When? Why?
10 - SD 5 A. At 553*F Tavg the P-12 interlock will block the steam dump valves from opening (and shut any open valves). This prevents excessive-primary plant cooldown with the steam dump. (1)
P-12 may be blocked when Tave is below 553*F to allow normal plant
'cooldown using only 3 of the 12 steam dump valves. (1) 3 INC 2 Q. With only using 6 incore detectors, (2)- we are able to monitor 58 different.
core subassemblies. Briefly des-cribe how we are able to do this.
4 INC 2 A. Each detector can be sent through a 5 path transfer device. In the
" normal" position-of this.5 path device it is sent to its 10 path transfer device. The output of each 10 path can go to 10 different core locations. 6 detectors x 10
. paths per detector-implies 60 locations (actually 58).
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- t 3 SMM. 2 12 a. What inputs are used in the (1.5) subcooling margin monitor?
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-b. The subcooling margin is based on'what inputs?
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4' SMM 2 A. a.- Wide range pressure (PT-405)
, Pressurizer pressure (PT-455)
Wide range loop RTD's Selected core exit thermocouples
- b. Highest thermocouple or RTD
- Lowest pressure 1 PCOM. 1 Q.. - What are-the two types of Trending
, (2) functions available on the Plant Computer? Give a brief description of each type.
2 PCOM- 1 A. Analog Trend--allows. trending of up to '4 points on 2 MCB mounted strip charts.
Printer' Block. Trend--allows trending of a group or block of-points on one of the output devices.
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4w 25 ROD 13 Q. List any rod stops or blocks that (3) affect rod control. Include the number of the block, coincidence, setpoint and whether the block'is effective in manual, auto or both.
4 26 ROD 13 A. a. C1 - IRN 1 high 20% 1/2, blocked manually
- b. C2 - PRN 1 high 103% 1/4, 1 channel can be blocked
- c. C3, OTN16, -3% 2/4, Turbine runback
'd. C4, OPN16, -3% 2/4, Turbine runback
- e. C5, lo pwr interlock <l5%
Tur Pimp
- f. Cll, control D only 228 steps
- g. F & E in auto only
.s 27 ABN 14 Q. - The plant is at 100%-power with all (2) control systems in automatic and normal operating plant parameters.
The pressurizer pressure control selector switch is in the PT-455/456 position when PT-455 fails high. (ABN-705A)
Describe:
- 1. ' Automatic control actions that will occur.
- 2. Effects on the plant (with no
. operator-action).
- 3. Operator actions which will mitigate this transient.
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28 ABN 14 A. Both spray valves open, variable control heaters receive minimum power and PORV-455 opens. RCS pressur'e. drops rapidly until 2185 psig. At this pressure, channel 458 will send a "CLOSE" signal to PORV-455. -Pressure will continue to. drop due to sprays. With no operator action, a reactor trip will occur on OTN-16 or low pressurizer pressure and a low pressure SI wil) occur at 1810 psig. (1.5)
Operator response (2 required) (.5)
- 1. Select position 456/457 on control selector switch.
- 2. Take manual control of master pressure controller to shut sprays and'PORV-455.
- 3. Shut PORV-455 block valve.
- 4. Take manual-control of individual spray controllers to shut spray valves.
- 5. Turn on all pressurizer heaters to restore pressure (once PORV and sprays are shut).
- 6. Run turbine-generator back to reduce steam flow and reactor power (aids in the prevention of DNB condition).
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-29 ABN 15 Q. With the plant at 100% power and (2) control rods in AUTO, one power range channel fails HIGH. Describe the AUT this co,OMATIC plant response ndition (assuming no to operator action) and describe what operator-actions should be taken.
< (ABN-703A) t 30 ABN 15 A. Automatic response (1)
- 1. Rods step in (rate mismatch)
- 2. Reactor power drops
- 3. Tave drops
'4. Steam pressure drops
- 5. Pressurizer pressure drops
- 6. Pressurizer level drops
- 7. Turbine control valves open to maintain load
- 8. Tave - Tref mismatch occurs and offsets rate mismatch which causes rods to stop stepping in. (Rods will not step out due to C-2.)
Operator response (1)
- 1. Rods to manual
- 2. Restore Tave - Tref
- 3. Refer to ABN's
- 4. Refer to Technical Specifications
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'7 'RPI 4 Q. a. Why do we have a rod insertion (3) limit?
- b. Whit are the inputs used to calculate the Rod Insertion Limits? '
- c. How do we know when we reach our rod insertion limit?
8 RPI 4 A. a. 1. Minimize ejected rod .
worth
- 2. Minimize radial flux peaking (or FAH}
- 3. . Maintain adequate ,
- b. 'RIL~= K y (Tave) . +K 2
(N 16 I+
K, (not required).. Auction-eered High N a eered High Tkhe,nd. auction-
- c. Low-low insertion limit alarm occurs-
- 47 .TAA 24 Q. Concerning the overtemperature N-16
.(3.5) reactor trip circuitry:
- a. What is the normal trip setpoint?. ,
- b. What. plant parameters are input to the setpoint calculation?
- c. What protection is provided by this-reactor trip?
48 TAA' 24 A. a. 111% + credits (1)
- penalties
- b. Loop Tc (.5)
Pzr Pressure Delta Flux c .- Protects against (1) exceeding DNB h
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'1031 bCII 52 Q. a, 'What is subcooling margin?
'. ( 1. 5 )
( 0 .' 5 )
- b. Ca'1culate the subcooling ma'rgin at 50% power assuming normal plant conditions.
(1.0) 3
- 10'4 MCD 52 A. a.- Subcooling margin is the margin that actual RCS' temper-ature is below saturation temperature for RCS pressure.
- b. At 50% power Tavg =-572.5*F AT = 32*F TH = 572.5'F + 16*F = 588.5'F T
pIfh=forPzrPressureof2235 653'F 653*F -'588.5 = 64~.'5'F subcooling margin 5 LPMS- 3 Q. Describe the physical process (1) called the piezoelectric effect and how it results in an output; signal from=an accelerometer in the-LPMS.
s 6- LPMS- 3- A. The piezoelectriu effect refers to
- the electric' potential generated by certain crystals when they are subjected-to a-~ mechanical deforma-
_ tion. -The amount of signal-is~-
directly proportional to-the amount of deformation, which~can be direct mechanical-deformation or stress induced deformation due.to acoust-ical waves. The output of the LPMS detector is_ generated by acoustical-wave effects on the detector crystal.
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p 5 SMS 3 Q. Define " safe shutdown earthquake" (1) and discuss its relationship to the structural design requirements of category.I structures. ,
6 SMS 3 A. Safe Shutdown Earthquake is that earthquake which is based upon an evaluation of the maximum earth-quake potential for a specific area. It is the earthquake which produces the maximum vibratory ground motion for which certain structures, systems and components are designed to remain functional, i.e. category I structures. The structural design of a category I structure is therefore different at different locations around the country.
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_TRAlheNG DEPARTMENT USE Penewed ty Director, Nefear Troening or Training supervisar -
- NITIAL.S k 'CATE h [ g MNNG SESSION NOT-104-3 For:: 3 Rev.,0 .
TO: Training Supervisor FROM: L. G. Barnes
SUBJECT:
Training Session TOPIC Shift Advisor Uograde Training (Week 1)
DATE May 7 - 11, 1984 (Actual Wk 1 training week)
CONDUCTED 3Y Self-Study DURATION ^8 needed I. Attendees David Campbell II. Material Covered
- 1. Main Turbine EHC - Reproduce a list of the following EHC fluid systems, state their functions, and briefly describe how they interface with each other.
- a. Startup Fluid
- b. Auxiliary Startup Fluid
- c. Trip Fluid
- d. Auxiliary trip fluid
- 2. List the inputs to the Subcooled Margin Monitor.
- 3. Rod Control System - List all interlocks associated with either manual or automatic rod control.
- 4. RCS Temperature and N-16 Power - Describe how the OTN-16 trip setpoint is calculated, including all parameter inputs.
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NOT-104-3 For : 3