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| issue date = 09/14/2015
| issue date = 09/14/2015
| title = 2015-09 Draft Operating Test and Revised Outlines
| title = 2015-09 Draft Operating Test and Revised Outlines
| author name = Gaddy V G
| author name = Gaddy V
| author affiliation = NRC/RGN-IV/DRS/OB
| author affiliation = NRC/RGN-IV/DRS/OB
| addressee name =  
| addressee name =  
Line 15: Line 15:


=Text=
=Text=
{{#Wiki_filter:Waterford 3 2015 RO NRC Exam JOB PERFORMANCE MEASURE A1  Determine Spent Fuel Pool (SFP) level by alternate monitoring and calculate time to reach 212°F in the SFP per OP-901-513, SFP Cooling Malfunction Applicant:
{{#Wiki_filter:}}
Examiner:
 
JPM A1  Revision 0 Page 2 of 6 2015 RO NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Determine Spent Fuel Pool (SFP) level by alternate monitoring and calculate time to reach 212°F in the SFP per OP-901-513, SFP Cooling Malfunction Task Standard: Determined Spent Fuel Pool (SFP) level by alternate monitoring and calculated time to boil in the SFP per OP-901-513, SFP Cooling Malfunction.
 
==References:==
OP-901-513, revision 14 Alternate Path:
No Time Critical:
No Validation Time:
10 mins. K/A 2.1.25 Ability to interpret reference materials,  Importance Rating 3.9  such as graphs, curves, tables, etc.
RO        Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM A1  Revision 0 Page 3 of 6 2015 RO NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-901-513, revision 14
 
== Description:==
 
This JPM requires the applicant to determine Spent Fuel Pool (SFP) level by alternate monitoring and calculate time to reach 212°F in the SFP per OP-901-513, SFP Cooling Malfunction READ TO APPLICANT DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
  (Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM A1  Revision 0 Page 4 of 6 2015 RO NRC Exam Evaluator Note The applicant will determine Spent Fuel Pool (SFP) level by alternate monitoring and calculate time to boil in the SFP per OP-901-513, SFP Cooling Malfunction. (all required data to perform the two calculations is supplied on the cue sheet)
TASK ELEMENT 1 STANDARD Determines Spent Fuel Pool level using the data provided on the applicant cue sheet along with the guidance and table located in Attachment 2 of OP-901-513, Spent Fuel Pool Cooling Malfunction. 42.7 feet Comment: The applicant will use Spent Fuel Pool temperature and suction pressure from Fuel Pool Pump A to determine Spent Fuel Pool level in accordance with the table in Attachment 2, Alternate SFP Parameter Monitoring. Note: Critical SAT  /  UNSAT TASK ELEMENT 2 STANDARD Determines time to reach 212°F in the Spent Fuel Pool using the data provided on the applicant cue sheet along with the curves provided in Attachment 3 of OP-901-513, Spent Fuel Pool Cooling Malfunction. 55 to 58 hours Comment: The applicant will use Spent Fuel Pool temperature, knowledge of the SFP gates removed, and the date provided in the cue sheet to determine time to reach 212°F in the SFP using Graph B in Attachment 3, Spent Fuel Pool Level Graphs. The applicant will interpolate between the 110 and 120 °F lines and the time since the last refueling shutdown to determine the correct answer. Critical SAT  /  UNSAT END OF TASK JPM A1  Revision 0 Page 5 of 6 2015 RO NRC Exam SIMULATOR OPERATOR INSTRUCTIONS None.
JPM A1  Revision 0 Page 6 of 6 2015 RO NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The date is 9/10/2015  A loss of AC power has rendered Fuel Pool Pumps and Fuel Pool level annunciators in the Control Room unavailable. The crew has entered OP-901-513, Spent Fuel Pool Cooling Malfunction  The Spent Fuel Pool Gates are removed. Spent Fuel Pool temperature is 115°F. The suction pressure reading from FS-102A (Fuel Pool Pump A suction drain) is 17.9 psig.
INITIATING CUES:
The CRS directs you to determine Spent Fuel Pool level by alternate monitoring and calculate time to reach 212°F in the Spent Fuel Pool per OP-901-513, SFP Cooling Malfunction. Document the results on this cue sheet.
Spent Fuel Pool level:  _______________
Time to reach 212°F:  _______________
 
Off Normal ProcedureOP-901-513Spent Fuel Pool Cooling MalfunctionRevision 015 E 0 GENERAL (CONT'D)9 PLACEKEEPERSTART DONEN/ANOTE(1) If monitoring of SFP level and temperature by normal means (PMC and localindications) is not possible, then refer to Attachment 2, Alternate SFP ParameterMonitoring, to implement alternate monitoring methods.[INPO IER 11-2 Recommendation 4](2) Attachment 3 contains graphs specific to the current cycle or Refueling outage duringReactor Core Off-load.6. If SFP Cooling is unavailable, then implementcontinuous monitoring of SFP level and temperature.6.1 Based on SFP configuration; determine SFP boil-off times using the applicable graph in Attachment3, Spent Fuel Pool Level Graphs.[INPO IER 11-2 Recommendation 1]
O f f N o r m a l P r o c e d u r e O P-9 0 1-5 1 3 S p e n t F u e l P o o l C o o l i n g M a l f u n c t i o n R e v i s i o n 0 1 5 P a g e 1 o f 3 2 0 A T T A C H M E N T 2 A L T E R N A T E S F P P A R A M E T E R M O N I T O R I N G[I N P O I E R 1 1-2 R e c o m m e n d a t i o n 4]1.A l t e r n a t e S F P L e v e l M o n i t o r i n g N O T E (1)T h e f o l l o w i n g a l t e r n a t e m e t h o d o l o g y o f m o n i t o r i n g S F P L e v e l c a n b e u s e d i f a l o s s o f A C p o w e r h a s r e n d e r e d F u e l P o o l P u m p s a n d C o n t r o l R o o m A n n u n c i a t o r s H 1 0 0 2 (F u e l P o o l L e v e l L o)a n d H 0 9 0 2 (F u e l P o o l L e v e l H i)u n a v a i l a b l e , a n d S F P l e v e l c a n n o t b e m o n i t o r e d l o c a l l y o n t h e F H B+4 6 (2)T h i s m o n i t o r i n g m e t h o d o l o g y i s n o t a c c u r a t e f o r e i t h e r o f t h e f o l l o w i n g c o n d i t i o n s: S F P L e v e l i s b e l o w t h e s u c t i o n o f t h e F u e l P o o l P u m p s (4 0.5'M S L).T h e F H B+4 6 a r e a a t m o s p h e r e b e c o m e s p r e s s u r i z e d (w i l l c a u s e a f a l s e h i g h l e v e l r e a d i n g)1.1 A t t a c h a d i g i t a l p r e s s u r e g a g e a t e i t h e r F S-1 0 2 A (F U E L P O O L P U M P A S U C T I O N D R A I N)o r F S-1 0 2 B (F U E L P O O L P U M P B S U C T I O N D R A I N).1.2 O p e n a p p l i c a b l e d r a i n v a l v e F S-1 0 2 A (F U E L P O O L P U M P A S U C T I O N D R A I N)o r F S-1 0 2 B (F U E L P O O L P U M P B S U C T I O N D R A I N).1.3 B a s e d o n c u r r e n t S F P T e m p e r a t u r e a n d t h e r e a d i n g o n t h e i n s t a l l e d p r e s s u r e g a g e a t F S-1 0 2 A (B), d e t e r m i n e S F P L e v e l u s i n g t h e t a b l e o n p a g e 2 o f 3 o f t h i s a t t a c h m e n t (S p e n t F u e l P o o l L e v e l i n F e e t B a s e d o n P r e s s u r e R e a d i n g a t F S-1 0 2 A (B)a n d B u l k T e m p e r a t u r e).1.4 I f R a d i a t i o n M o n i t o r i n g S y s t e m i s n o t f u n c t i o n i n g , t h e n d i r e c t R a d i a t i o n P r o t e c t i o n P e r s o n n e l t o m o n i t o r r a d i a t i o n l e v e l s l o c a l l y u s i n g h a n d h e l d r a d i a t i o n m o n i t o r s i n a c c o r d a n c e w i t h H P-0 0 1-1 2 3 , P l a n t C o n d i t i o n s a n d R a d i o l o g i c a l C o n c e r n s.
O f f N o r m a l P r o c e d u r e O P-9 0 1-5 1 3 S p e n t F u e l P o o l C o o l i n g M a l f u n c t i o n R e v i s i o n 0 1 5 P a g e 2 o f 3 2 1 A T T A C H M E N T 2 A L T E R N A T E S F P P A R A M E T E R M O N I T O R I N G (C O N T'D)
O f f N o r m a l P r o c e d u r e O P-9 0 1-5 1 3 S p e n t F u e l P o o l C o o l i n g M a l f u n c t i o n R e v i s i o n 0 1 5 P a g e 3 o f 3 2 2 A T T A C H M E N T 2 A L T E R N A T E S F P P A R A M E T E R M O N I T O R I N G (C O N T'D)2.A l t e r n a t e S F P T e m p e r a t u r e M o n i t o r i n g 2.1 M&T E m a y b e u s e d p e r t h e b e l o w t a b l e t o m o n i t o r S p e n t F u e l P o o l T e m p e r a t u r e o n a l o s s o f t h e P M C.2.2 F l u k e i n s t r u m e n t s m a y b e o b t a i n e d f r o m t h e P M I S h o p , M e t L a b , C o n t r o l R o o m o r E O F.N o t e l i m i t a t i o n s l i s t e d i n t h e t a b l e f o r u s e o f e a c h i n s t r u m e n t.I n s t r u m e n t D e s c r i p t i o n P o w e r S o u r c e N o r m a l R e a d o u t L o s s o f P o w e r C o n t i n g e n c y L i m i t a t i o n s F S I T E 2 0 0 0-1 F U E L P O O L W A T E R T E M P E R A T U R E 1 2 0 V A C P D P 3 4 5 A B c k t 1 6 P M C-A 4 7 0 0 4 C o n n e c t F l u k e M e t e r s e t f o r T y p e E t h e r m o c o u p l e a t C P-5 0 , t e r m i n a l s o n V L L C a r d S l o t 0 4 3 1 (c a b l e 3 0 6 3 1 P).N o n e F S I T E 2 0 0 0-2 F U E L P O O L W A T E R T E M P E R A T U R E 1 2 0 V A C P D P 3 4 5 A B c k t 1 6 P M C-A 4 7 0 0 5 C o n n e c t F l u k e M e t e r s e t f o r T y p e E t h e r m o c o u p l e a t M u x F H 0 1 0 1 , T e r m i n a l s F 0 6-0 7 , H&L.N o n e F S I T E 2 0 1 0 F U E L P O O L W A T E R T O F U E L P O O L P U M P S T E M P E R A T U R E 1 2 0 V A C P D P 3 4 5 A B c k t 1 6 P M C-A 4 7 0 0 2 C o n n e c t F l u k e M e t e r s e t f o r T y p e E t h e r m o c o u p l e a t M u x F H 0 1 0 1 , T e r m i n a l s F 0 6-0 5 , H&L.O n l y a c c u r a t e i f a F u e l P o o l P u m p i s r u n n i n g F S I T E 2 0 2 0 F U E L P O O L H E A T E X C H A N G E R O U T L E T H D R T E M P E R A T U R E 1 2 0 V A C P D P 3 4 5 A B c k t 1 6 P M C-A 4 7 0 0 3 C o n n e c t F l u k e M e t e r s e t f o r T y p e E t h e r m o c o u p l e a t M u x F H 0 1 0 1 , T e r m i n a l s F 0 6-0 4 , H&L.O n l y a c c u r a t e i f a F u e l P o o l P u m p i s r u n n i n g O f f N o r m a l P r o c e d u r e O P-9 0 1-5 1 3 S p e n t F u e l P o o l C o o l i n g M a l f u n c t i o n R e v i s i o n 0 1 5 P a g e 1 o f 7 2 3 A T T A C H M E N T 3 S P E N T F U E L P O O L L E V E L G R A P H S T h e p u r p o s e o f t h e s e g r a p h s i s t o p r o v i d e e s t i m a t e d s p e n t f u e l p o o l l e v e l b a s e d o n s p e n t f u e l p o o l l o a d i n g a n d w h e t h e r t h e s p e n t f u e l p o o l g a t e s a r e i n s t a l l e d o r n o t.T h e G r a p h s a r e c a l c u l a t e d t o s h o w S p e n t F u e l P o o l L e v e l t o t h r e e p o s i t i o n s , T i m e t o 2 0 0 F , T i m e t o 2 1 2 F a n d T i m e t o T o p o f S p e n t F u e l A s s e m b l i e s.G r a p h A , T i m e t o 2 0 0 F , L e n g t h o f C y c l e , G a t e s R e m o v e d G r a p h B , T i m e t o 2 1 2 F , L e n g t h o f C y c l e , G a t e s R e m o v e d G r a p h C , T i m e t o t o p o f F u e l A s s e m b l i e s , L e n g t h o f C y c l e , G a t e s R e m o v e d G r a p h D , T i m e t o 2 0 0 F , L e n g t h o f C y c l e , G a t e s I n s t a l l e d G r a p h E , T i m e t o 2 1 2 F , L e n g t h o f C y c l e , G a t e s I n s t a l l e d G r a p h F , T i m e t o t o p o f F u e l A s s e m b l i e s , L e n g t h o f C y c l e , G a t e s I n s t a l l e d L e n g t h o f C y c l e i s a p p l i c a b l e d u r i n g O p e r a t i n g C y c l e u n t i l R F 2 0 C o r e O f f l o a d b e g i n s.A p p l i c a b l e a s s o o n a s t h e l a s t F u e l A s s e m b l y h a s b e e n t r a n s f e r r e d t o t h e R e f u e l i n g C a v i t y f o r t h e O p e r a t i n g C y c l e 2 0 C o r e l o a d a n d a l l d u r i n g O p e r a t i n g C y c l e 2 0 u n t i l R e f u e l 2 0 C o r e O f f l o a d b e g i n s.
O f f N o r m a l P r o c e d u r e O P-9 0 1-5 1 3 S p e n t F u e l P o o l C o o l i n g M a l f u n c t i o n R e v i s i o n 0 1 5 P a g e 3 o f 7 2 5 G R A P H B , T I M E T O 2 1 2 F , L E N G T H O F C Y C L E , G A T E S R E M O V E D 1 5 2 5 3 5 4 5 5 5 6 5 7 5 8 5 9 5 1 0 5 1 1 5 1 2 5 1 3 5 1 4 5 1 5 5 1 6 5 1 7 5 1 8 5 1 9 5 2 0 5 2 1 5 2 2 5 2 3 5 2 4 5 2 5 5 2 6 5 2 7 5 2 8 5 2 9 5 3 0 5 3 1 5 3 2 5 3 3 5 3 4 5 3 5 5 3 6 5 3 7 5 3 8 5 3 9 5 4 0 5 4 1 5 4 2 5 4 3 5 4 4 5 4 5 5 4 6 5 4 7 5 4 8 5 4 9 5 5 0 5 5 1 5 5 2 5 5 3 5 5 4 5 5 5 5 5 6 5 T i m e f r o m C o o l i n g F a i l u r e t o R e a c h 2 1 2°F (t 2 1 2), H o u r s 4/2 8/2 0 1 4 5/8/2 0 1 4 5/1 8/2 0 1 4 5/2 8/2 0 1 4 6/7/2 0 1 4 6/1 7/2 0 1 4 6/2 7/2 0 1 4 7/7/2 0 1 4 7/1 7/2 0 1 4 7/2 7/2 0 1 4 8/6/2 0 1 4 8/1 6/2 0 1 4 8/2 6/2 0 1 4 9/5/2 0 1 4 9/1 5/2 0 1 4 9/2 5/2 0 1 4 1 0/5/2 0 1 4 1 0/1 5/2 0 1 4 1 0/2 5/2 0 1 4 1 1/4/2 0 1 4 1 1/1 4/2 0 1 4 1 1/2 4/2 0 1 4 1 2/4/2 0 1 4 1 2/1 4/2 0 1 4 1 2/2 4/2 0 1 4 1/3/2 0 1 5 1/1 3/2 0 1 5 1/2 3/2 0 1 5 2/2/2 0 1 5 2/1 2/2 0 1 5 2/2 2/2 0 1 5 3/4/2 0 1 5 3/1 4/2 0 1 5 3/2 4/2 0 1 5 4/3/2 0 1 5 4/1 3/2 0 1 5 4/2 3/2 0 1 5 5/3/2 0 1 5 5/1 3/2 0 1 5 5/2 3/2 0 1 5 6/2/2 0 1 5 6/1 2/2 0 1 5 6/2 2/2 0 1 5 7/2/2 0 1 5 7/1 2/2 0 1 5 7/2 2/2 0 1 5 8/1/2 0 1 5 8/1 1/2 0 1 5 8/2 1/2 0 1 5 8/3 1/2 0 1 5 9/1 0/2 0 1 5 9/2 0/2 0 1 5 9/3 0/2 0 1 5 1 0/1 0/2 0 1 5 1 0/2 0/2 0 1 5 1 0/3 0/2 0 1 5 Waterford 3 2015 NRC Exam JOB PERFORMANCE MEASURE A2  Perform OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data Applicant:
Examiner:
 
JPM A2  Revision 0 Page 2 of 6 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Perform OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data Task Standard: Applicant correctly calculates new values for Core Protection Calculator constants KCAL, TCREF, and TPC.
 
==References:==
OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data Alternate Path:
No Time Critical: No Validation Time: 15 mins. K/A 2.1.18 Ability to make accurate, clear, and  Importance Rating 3.6 concise logs, records, status boards, and RO  reports.      Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM A2  Revision 0 Page 3 of 6 2015 NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data
 
== Description:==
Applicant will use given values for PMC and Core Protection Calculator B to input data and calculate CPC constants KCAL, TCREF, and TPC. The procedure has provisions to collect 5 sets of data and average them over a 5 minute period, but it is optional at the supervisor's request. The applicants will not have to collect 5 sets of data. The applicants will not have to change the constants, just perform the calculations.
READ TO APPLICANT DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
  (Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM A2  Revision 0 Page 4 of 6 2015 NRC Exam TASK ELEMENT 1 STANDARD Complete OP-903-001, Attachment 11.18 according to key. Student must record values given in correct places and Determine new values correctly for KCAL, TCREF, and TPC. Comment: Data entry and calculations are displayed on the key. Information that would be N/A is not critical. Critical SAT  /  UNSAT END OF TASK
 
JPM A2  Revision 0 Page 5 of 6 2015 NRC Exam SIMULATOR OPERATOR INSTRUCTIONS None.
JPM A2  Revision 0 Page 6 of 6 2015 NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
: 1. COLSS is Operable. 2. The UFM is in service. 3. The plant is at steady state operation. 4. Channel B CPC and applicable PMC readings are as follows:  TPC, CPC PID 064 = 0.84399  KCAL, CPC PID 065 = 1.0070  PCALIB, CPC PID 104 = 100  TC 1, CPC PID 160 = 543.59  TC 2, CPC PID 161 = 543.46  PHICAL, CPC PID 171 = 99.96  BDT, CPC PID 177 = 99.82  TCORF, CPC PID 180 = 0.99902  BSCAL, C24230 = 99.87  BDELT, C24104 = 99.78  BTSFP, C24101 = 99.50 INITIATING CUES:
The CRS directs you to complete the following calculations for Channel B on Attachment 11.18:
step 11.10.6 for KCAL and TCREF  step 11.10.7 for TPC Linear potentiometer data collection is not required for this task.
Data collection from CP-10 is not required for this task.
The CRS directs you to fill in required data once for column "0", averaging columns 0 through 4 is not required.
This task is complete when you reach step 11.10.8.
A2 KeyOP-903-001  Revision 061Attachment 11.18 (1 of 3) 14711.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATADATE _______________    CHANNEL UNDER ADJUSTMENT: A B    C    D11.10.3.1Calculate and record the averages of each parameter in the spaceprovided.0 1 2 3 4Average AdjustedBSCALPMC PID-C24230 99.87HI LINEAR POWERBISTABLE 1 VOLTS N/AHIGH LINEAR POWER %VOLT X 20 N/APHICAL.(Calibrated Neutron Flux Power)CPC PID 171 99.96 BDT(Static Thermal Power)CPC PID 177 99.82Calculations Performed by:Verified by:SignatureSignature  Refer to attachment 11.1 Note 9.1 to determine appropriate power indication if linearpower is not35% steady state. Document indication used in Remarks. If COLSS is Inoperable, then use NE-005-201, Heat Balance Calculations, to determineSecondary Calorimetric Power substitute when PMC or CORE POWER is specified.Adjusted is the average value plus 8.5% (8% to10%) if adjustments are being made toPHICAL and/or BDT as listed in Notes above steps 11.10.6 or 11.10.7 (refer to Attachment11.1 Note 9.8). Otherwise N/A this block.Use theAverage value, not the Adjusted value, forDVM calculation.11.10.4 Record the following for channel under adjustment:TPC (Thermal Power Calibration Constant)CPC PID 064 ...................................................0.84399KCAL (Neutron Flux Power Cal. Constant)CPC PID 065 ...................................................1.0070PCALIB (Secondary Calorimetric Power Used inLatest CPC Power Calibration) CPC PID 104 100TC 1 (Loop 1 Cold Leg Temperature)CPC PID 160 ...................................................543.59TC 2 (Loop 2 Cold Leg Temperature)CPC PID 161 ...................................................543.46TCORF (Temp Shadowing Correction Factor)CPC PID 180 ...................................................0.99902EXCORE LINEAR POWER CALIBRATEPOTENTIOMETER POSITION ROM ..............N/A A2 KeyOP-903-001  Revision 061Attachment 11.18 (2 of 3) 14811.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONT'D)11.10.5 Calculate the new DVM reading or new potentiometer position as follows:DVM (new) =Avg. Core Power (Step 11.10.3.1)*
=N/A 20 20* Use theAverage value from the table of step 11.10.3.1, not the Adjusted value.DVM (new) =N/A orPotentiometer position (new) =Avg. Core Power % (Step 11.10.3.1)* X Old Potentiometer Setting (Step 11.10.4)Avg. Linear Power % (Step 11.10.4)N/A XN/AN/A* Use theAverage value from the table of step 11.10.3.1, not the Adjusted value.Potentiometer position (new) =______N/A_______Performed by:N/A IV by:N/A(Initials)(Initials)11.10.6.1Calculate KCAL (new):
KCAL(new)=(Step 11.10.3.1)* (step 11.10.4)  (step 11.10.4)Avg. Core Power (%)
x KCAL x TCORFAvg. PHICAL(step 11.10.3.1)
* AnAdjusted value may be required. Refer to Note preceding step 11.10.6.
KCAL(new)=99.87 x1.0070 x.9990299.96 KCAL(new)=1.0051KCAL (new) =1.005 1(CPC PID 065)11.10.6.3New TCREF (CPC PID 098) = Minimum TC from step 11.10.4:TC 1 (CPC PID 160) or  TC 2 (CPC PID 161).TCREF (new) =543.46(CPC PID 098)Performed by:
IV by:(Initials)(Initials)
A2 KeyOP-903-001  Revision 061Attachment 11.18 (3 of 3) 14911.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONT'D)11.10.7 Calculate TPC (CPC PID 064):TPC (new)=Avg. Core Power % (Step 11.10.3.1)* XTPC (Step 11.10.4)Avg. BDT (Step 11.10.3.1)
* AnAdjusted value may be required. Refer to Note preceding step 11.10.7.TPC (new)=
99.87 X 0.84399 99.82TPC (new) =
0.84441(CPC PID 064).Performed by:
I V by:(Initials)(Initials)11.10.11.1 Record the following: Applicable CORE POWER PMC .................................... ___________ PCALIB CPC PID 104  .............................................. ___________ HI LINEAR POWER BISTABLE 1 VOLTS ..................... ___________ HI LINEAR POWER % VOLTS x 20 .............................. ___________ PHICAL CPC PID 171  .............................................. ___________ BDT CPC PID 177 .............................................. ___________11.10.11.2.1Record answers: HI LINEAR POWER %, VOLTS X 20 .................... YES/NO ________ PHICAL, CPC PID 171  ..................................... YES/NO ________ BDT, CPC PID 177 ..................................... YES/NO ________11.10.12 Performed by:
I V by:(Initials)(Initials)11.10.13  Reviewed by:_________________________  _________________SM/CRSDate/Time A2 Student OP-903-001  Revision 061 Attachment 11.18 (1 of 3) 145 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA DATE _______________    CHANNEL UNDER ADJUSTMENT: A B      C      D  11.10.3.1 Calculate and record the averages of each parameter in the space provided.
0 1 2 3 4 Average Adjusted BSCAL  PMC PID-C24230 HI LINEAR POWER BISTABLE 1 VOLTS N/A      HIGH LINEAR POWER % VOLT X 20 N/A      PHICAL. (Calibrated Neutron Flux Power) CPC PID 171 BDT (Static Thermal Power) CPC PID 177 Calculations Performed by:
Verified by:
Signature Signature  Refer to attachment 11.1 Note 9.1 to determine appropriate power indication if linear power is not 35% steady state. Document indication used in Remarks. If COLSS is Inoperable, then use NE-005-201, Heat Balance Calculations, to determine Secondary Calorimetric Power substitute when PMC or CORE POWER is specified. Adjusted is the average value plus 8.5% (8% to10%) if adjustments are being made to PHICAL and/or BDT as listed in Notes above steps 11.10.6 or 11.10.7 (refer to Attachment 11.1 Note 9.8). Otherwise N/A this block. Use the Average value, not the Adjusted value, for DVM calculation.
11.10.4 Record the following for channel under adjustment:
TPC (Thermal Power Calibration Constant) CPC PID 064...................................................
KCAL (Neutron Flux Power Cal. Constant) CPC PID 065...................................................
PCALIB (Secondary Calorimetric Power Used in Latest CPC Power Calibration) CPC PID 104 TC 1 (Loop 1 Cold Leg Temperature) CPC PID 160...................................................
TC 2 (Loop 2 Cold Leg Temperature) CPC PID 161...................................................
TCORF (Temp Shadowing Correction Factor) CPC PID 180...................................................
EXCORE LINEAR POWER CALIBRATE POTENTIOMETER POSITION ROM..............
N/A A2 Student OP-903-001  Revision 061 Attachment 11.18 (2 of 3) 146 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONT'D) 11.10.5 Calculate the new DVM reading or new potentiometer position as follows:
Avg. Core Power (Step 11.10.3.1)* N/A DVM (new) =
20 = 20
* Use the Average value from the table of step 11.10.3.1, not the Adjusted value. DVM (new) = N/A or  Potentiometer position (new) =
Avg. Core Power % (Step 11.10.3.1)* X Old Potentiometer Setting (Step 11.10.4) Avg. Linear Power % (Step 11.10.4)
N/A        X                          N/A N/A
* Use the Average value from the table of step 11.10.3.1, not the Adjusted value. Potentiometer position (new) = ______N/A_______
Performed by: N/A Verified by: N/A  (Initials)
(Initials) 11.10.6.1 Calculate KCAL (new):
(Step 11.10.3.1)*  (step 11.10.4)  (step 11.10.4) Avg. Core Power (%)
x KCAL x TCORF Avg. PHICAL KCAL (new)  = (step 11.10.3.1)
* An Adjusted value may be required. Refer to Note preceding step 11.10.6.
x  x  KCAL (new) =  KCAL (new) =  KCAL (new) =
  (CPC PID 065) 11.10.6.3 New TCREF (CPC PID 098) = Minimum TC from step 11.10.4:
TC 1 (CPC PID 160) or TC 2 (CPC PID 161).
TCREF (new) =
  (CPC PID 098)
Performed by:
IV by:  (Initials)
(Initials)
A2 Student OP-903-001  Revision 061 Attachment 11.18 (3 of 3) 147 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONT'D) 11.10.7 Calculate TPC (CPC PID 064):
Avg. Core Power % (Step 11.10.3.1)* X TPC (Step 11.10.4) TPC (new)=
Avg. BDT (Step 11.10.3.1)
* An Adjusted value may be required. Refer to Note preceding step 11.10.7.
X  TPC (new)=
TPC (new) =
  (CPC PID 064).
Performed by:
IV by:  (Initials)
(Initials) 11.10.11.1 Record the following:  Applicable CORE POWER PMC....................................___________  PCALIB CPC PID 104 ..............................................___________  HI LINEAR POWER BISTABLE 1 VOLTS.....................___________  HI LINEAR POWER % VOLTS x 20..............................___________  PHICAL CPC PID 171 ..............................................___________  BDT CPC PID 177 ..............................................___________ 11.10.11.2.1 Record answers:  HI LINEAR POWER %, VOLTS X 20....................YES/NO ________  PHICAL, CPC PID 171 .....................................YES/NO ________  BDT, CPC PID 177 .....................................YES/NO ________
11.10.12 Performed by:
IV by:  (Initials)
(Initials) 11.10.13  Reviewed by:  _________________________  _________________
SM/CRS  Date/Time
 
OP-903-001  Revision 061Attachment 11.10 (1 of 10) 11411.10 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION INSTRUCTIONDATE ______________      CHANNEL UNDER ADJUSTMENT:  A B    C    DNOTEDuring physics testing, Note 2 of TS Table 4.3-1 applies and allows the suspension of thisadjustment until the next power plateau is reached. The assigned Shift Test Director shouldbe notified during testing prior to making any adjustments per this attachment.11.10.1 If a non-conservative adjustment (indicated power is lowered) is required to bemade on CPC and Excore Nuclear Instrumentation, then verify that both of thefollowing conditions are met: BDELT (C24104) is within 2% of BTFSP (C24101) The average of BDELT (C24104) and BTFSP (C24101) is within 2% ofCalorimetric Power11.10.1.1 If either of these conditions cannot be met, then notify Reactor Engineering(RE) for further evaluation prior to making any adjustment.11.10.2 If either of the following conditions are not met, then use the applicable power forCORE POWER PMC as specified in Note 9.1 of Attachment 11.1. UFM is in service Plant is in steady state operationNOTEAverages are recommended for accuracy, but are not required.11.10.3 Record the following data at approximately one minute intervals onAttachment 11.18: BSCAL- PMC PID C24230 HI LINEAR POWERBISTABLE 1 VOLTS HIGH LINEAR POWER % VOLT X 20 PHICAL (Calibrated Neutron Flux Power) CPC PID 171 BDT (Static Thermal Power) CPC PID 17711.10.3.1 Calculate and record averages of each parameter on Attachment 11.18.
OP-903-001  Revision 061Attachment 11.10 (2 of 10) 11511.10.4 Record the following data for channel under adjustment on Attachment 11.18: TPC (Thermal Power Calibration Constant) CPC PID 064 KCAL (Neutron Flux Power Cal. Constant) CPC PID 065 PCALIB (Secondary Calorimetric Power Used in Latest CPC PowerCalibration) CPC PID 104 TC 1 (Loop 1 Cold Leg Temperature) CPC PID 160 TC 2 (Loop 2 Cold Leg Temperature) CPC PID 161 TCORF (Temp Shadowing Correction Factor) CPC PID 180 EXCORE LINEAR POWER CALIBRATE POTENTIOMETER POSITION ROM(may be N/A'd if not using in step 11.10.5)11.10.5 If Hi Linear Power requires adjustment, then calculate the new DVM reading ornew potentiometer position on Attachment 11.18
.
OP-903-001  Revision 061Attachment 11.10 (3 of 10) 116NOTEUnder the following conditions, PHICAL (CPC PID 171) must be adjusted to between +8.0%and +10.0% above the calorimetric power indication (refer to Note 9.8 on Attachment 11.1).This is performed by adding 8.5% (8% to10%) to the average core power value onAttachment 11.18 to obtain anAdjusted value that will be used as the Avg. Core Power valuein the KCAL (new) calculation (this requirement does not apply during initial power ascensionto <80% RTP following refueling):[CR-WF3-2006-03726] Calorimetric power is between 15% RTP and 80% RTP.and PHICAL is greater than 10.0% above Calorimetric power.11.10.6 If KCAL (PHICAL) requires adjustment, then perform the following.11.10.6.1 Calculate KCAL (new) on Attachment 11.18.
CAUTIONCPC PID 065 (KCAL) limit is 0.7 to 2.0.[CR-WF3-1998-00919]11.10.6.2 If KCAL (new) is 0.8, then then perform the following:[CR-WF3-1998-00919, CR-WF3-2015-02641] Generate a Condition Report. Notify RXE to complete NE-002-010, Linear Power Subchannel GainAdjustment. Notify PMI that adjustment will be required on the affected channel(PMID 2806).11.10.6.3 Document new TCREF(CPC PID 098) on Attachment 11.18.
OP-903-001  Revision 061Attachment 11.10 (4 of 10) 117NOTEUnder the following conditions, BDT (CPC PID 177) must be adjusted to between +8.0% and+10.0% above the calorimetric power indication (refer to Note 9.8 on Attachment 11.1). Thisis performed by adding 8.5% (8% to10%) to the average core power value on Attachment11.18 to obtain anAdjusted value that will be used as the Avg. Core Power value in the TPCcalculation (this requirement does not apply during initial power ascension to <80% RTPfollowing refueling):[CR-WF3-2006-03726] Calorimetric power is between 15% RTP and 80% RTP.and BDT is greater than 10.0% above Calorimetric power.11.10.7 If BDT requires adjustment, then Calculate TPC (CPC PID 064) on Attachment11.18.
OP-903-001  Revision 061Attachment 11.18 (1 of 3) 14711.18 ADJUSTMENT OFCPC AND EXCORE NUCLEAR INSTRUMENTATION DATADATE _______________    CHANNEL UNDER ADJUSTMENT: A B    C    D11.10.3.1Calculate and record the averages of each parameter in the spaceprovided.0 1 2 3 4Average AdjustedBSCALPMC PID-C24230HI LINEAR POWERBISTABLE 1 VOLTSHIGH LINEAR POWER %VOLT X 20PHICAL.(Calibrated Neutron Flux Power)CPC PID 171 BDT(Static Thermal Power)CPC PID 177Calculations Performed by:Verified by:SignatureSignature  Refer to attachment 11.1 Note 9.1 to determine appropriate power indication if linearpower is not35% steady state. Document indication used in Remarks. If COLSS is Inoperable, then use NE-005-201, Heat Balance Calculations, to determineSecondary Calorimetric Power substitute when PMC or CORE POWER is specified.Adjusted is the average value plus 8.5% (8% to10%) if adjustments are being made toPHICAL and/or BDT as listed in Notes above steps 11.10.6 or 11.10.7 (refer to Attachment11.1 Note 9.8). Otherwise N/A this block.Use theAverage value, not the Adjusted value, forDVM calculation.11.10.4 Record the following for channel under adjustment:TPC (Thermal Power Calibration Constant)CPC PID 064 ...................................................KCAL (Neutron Flux Power Cal. Constant)CPC PID 065 ...................................................PCALIB (Secondary Calorimetric Power Used inLatest CPC Power Calibration) CPC PID 104TC 1 (Loop 1 Cold Leg Temperature)CPC PID 160 ...................................................TC 2 (Loop 2 Cold Leg Temperature)CPC PID 161 ...................................................TCORF (Temp Shadowing Correction Factor)CPC PID 180 ...................................................
EXCORE LINEAR POWER CALIBRATEPOTENTIOMETER POSITION ROM ..............
OP-903-001  Revision 061Attachment 11.18 (2 of 3) 14811.18 ADJUSTMENT OFCPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONT'D)11.10.5 Calculate the new DVM reading or new potentiometer position as follows:DVM (new) =Avg. Core Power (Step 11.10.3.1)*
=20 20* Use theAverage value from the table of step 11.10.3.1, not the Adjusted value.DVM (new) =
orPotentiometer position (new) =Avg. Core Power % (Step 11.10.3.1)* X Old Potentiometer Setting (Step 11.10.4)Avg. Linear Power % (Step 11.10.4)
X* Use theAverage value from the table of step 11.10.3.1, not the Adjusted value.Potentiometer position (new) = ________________Performed by:
IV by: (Initials)(Initials)11.10.6.1Calculate KCAL (new):KCAL (new)=(Step 11.10.3.1)* (step 11.10.4)  (step 11.10.4)Avg. Core Power (%)
xKCAL x TCORFAvg. PHICAL(step 11.10.3.1)* AnAdjusted value may be required. Refer to Note preceding step 11.10.6.KCAL (new)=x xKCAL (new)=KCAL (new) =(CPC PID 065)11.10.6.3New TCREF (CPC PID 098) = Minimum TC from step 11.10.4:TC 1 (CPC PID 160) or  TC 2 (CPC PID 161).TCREF (new) =(CPC PID 098)Performed by:
IV by: (Initials)(Initials)
OP-903-001  Revision 061Attachment 11.18 (3 of 3) 14911.18 ADJUSTMENT OFCPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONT'D)11.10.7 Calculate TPC (CPC PID 064):TPC (new)=Avg. Core Power % (Step 11.10.3.1)* XTPC (Step 11.10.4)Avg. BDT (Step 11.10.3.1)* AnAdjusted value may be required. Refer to Note preceding step 11.10.7.TPC (new)=
XTPC (new) =(CPC PID 064).Performed by:
IV by: (Initials)(Initials)11.10.11.1 Record the following: Applicable CORE POWER PMC .................................... ___________ PCALIB CPC PID 104  .............................................. ___________ HI LINEAR POWER BISTABLE 1 VOLTS ..................... ___________ HI LINEAR POWER % VOLTS x 20 .............................. ___________ PHICAL CPC PID 171  .............................................. ___________ BDT CPC PID 177 .............................................. ___________11.10.11.2.1Record answers: HI LINEAR POWER %, VOLTS X 20 .................... YES/NO ________ PHICAL, CPC PID 171  ..................................... YES/NO ________ BDT, CPC PID 177 ..................................... YES/NO ________11.10.12 Performed by:
IV by: (Initials)(Initials)11.10.13  Reviewed by:_________________________  _________________
SM/CRSDate/Time Waterford 3 2015 RO NRC Exam JOB PERFORMANCE MEASURE A3  Determine Acceptability of Containment Temperature In Accordance With OP-903-001 Applicant:
Examiner:
 
JPM A3  Revision 0 Page 2 of 6 2015 RO NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Determine Acceptability of Containment Temperature In Accordance With OP-903-001 Task Standard: Determined Containment Average Temperature does not meet acceptance criteria with instrument error accounted for and Tech Spec 3.6.1.5 entry is required.
 
==References:==
OP-903-001, revision 49; TS 3.6.1.5; TS Bases 3/4.6 Alternate Path:
No Time Critical:
No Validation Time:
15 mins. K/A 2.2.12, Knowledge of surveillance  Importance Rating 3.7  procedures.
RO        Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM A3  Revision 0 Page 3 of 6 2015 RO NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-903-001, Attachment 11.1 MODES 1-4 Technical Specification Surveillance Logs, revision 61  OP-903-001, Attachment 11.20 MODES 1-4 PMC Technical Specification Surveillance Logs  revision 61  Waterford 3 Technical Specifications
 
== Description:==
 
This JPM requires the candidate to use Containment temperature readings from the PMC (provided on the cue sheet), calculate the average temperature using 3 of the 4 readings, and determine compliance with TS 3.6.1.5 and OP-903-001. Based on the readings of the 3 running CFC intake temperatures and tighter acceptance criteria of OP-903-001 (based on instrument error) TS 3.6.1.5 ACTION a must be complied with.
READ TO APPLICANT DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
  (Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM A3  Revision 0 Page 4 of 6 2015 RO NRC Exam Evaluator Note The candidate will determine Containment Average Temperature using Containment  Fan Cooler inlet temperatures from the PMC, Containment Fan Coolers running, and reactor power (all provided on the cue sheet)
TASK ELEMENT 1 STANDARD Determines Containment Average Temperature 98.3F -99.7 F Comment: 1. The applicant will use the provided CFC temperatures and average the 3 running CFC temperatures (A, C and D). The average will be 98.7 F. Note: Averaging the 3 running CFC temperatures is preferred but not required. Any 3 can be used. The range given covers the various combinations that can be averaged. Critical SAT  /  UNSAT TASK ELEMENT 2 STANDARD Determines Average Containment Temperature does NOT meet Acceptance Criteria. Determined that acceptance criteria is not met and TS 3.6.1.5 entry is required. Comment: If the candidate just compares the temperature to the 3.6.1.5 LCO they will determine that no action is required and acceptance criteria is met. However, Tech Spec 3.6.1.5 does not take into account  instrument uncertainties. and notes 2.0 - 2.3 of OP-903-001, Attachment 11.1 should be reviewed to determine acceptability of Containment Temperature. Critical SAT  /  UNSAT END OF TASK JPM A3  Revision 0 Page 5 of 6 2015 RO NRC Exam SIMULATOR OPERATOR INSTRUCTIONS None.
JPM A3  Revision 0 Page 6 of 6 2015 RO NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
Reactor power is at 100%  I & C has just completed calibration of CFC Air Intake temperature loops  Containment Fan Coolers A, C, and D are operating  Primary Containment Average Air temperatures are as follows:  PID A51115, CFC A Air Inlet Temp reads 97 F  PID A51119, CFC B Air Inlet Temp reads 100 F  PID A51123, CFC C Air Inlet Temp reads 101 F  PID A51127, CFC D Air Inlet Temp reads 98 F    INITIATING CUES:
The CRS directs you to determine compliance of Containment Average Temperature per OP-903-001. Document results and actions required, if any, on OP-903-001, Attachment 11.20. 
 
OP-903-001  Revision 061Attachment 11.1 (17 of 37) 38Modes 1-4 Technical Specification Surveillance Log Notes1.0 With RCS Temperature greater than or equal to 539F determine SHUTDOWNMARGIN using OP-903-090, Shutdown Margin or using OP-004-019, EstimatedCritical Configuration. If NE-002-020, CEA Insertion Time Measurement is inprogress, then verify SDM in accordance with NE-002-020. During Plant Startup inaccordance with OP-010-003, control of SHUTDOWN MARGIN is transferred fromOP-903-090 to OP-004-019 by verifying both of the following: Actual RCS boron concentration is no more than 20 ppm below the Critical BoronConcentration of OP-004-019, Column F on Attachment 1and The question "Allowable CEA Range is verified to be above Transient InsertionLimit for critical operations (Group 5 60 inches)" is answered YES.NA if RCS Temperature less than 539 F. Determine SHUTDOWN MARGIN within 1hour using OP-903-090 for Modes 1-5 in all cases involving Inoperable CEAs. Attachdocumentation to Attachment 11.1.[CR-WF3-1998-00970, CR-WF3-2001-00209]1.1 With RCS Temperature less than 539F determine SHUTDOWN MARGIN usingOP-903-090, Shutdown Margin. Refer to Technical Specification 3.1.1.2.NA if RCS Temperature 539F. Determine SHUTDOWN MARGIN within 1 hourusing OP-903-090 for Modes 1-5 in all cases involving Inoperable CEAs. Attachdocumentation to Attachment 11.1.[CR-WF3-1998-00970, CR-WF3-2001-00209]2.0 Containment Average Air Temperature shall be the average of temperatures taken atany three CFC Air Intake locations. The preferred instruments used should be on theoperating CFC's, but this is not a requirement.Containment Average Air Temperature limits are as follows: Technical Specification limits are 95 F and 120F. The lower limit of 95 Fdoes not apply70% Rated Thermal Power.Maintaining Containment Average Air Temperature >100F by PMC indication (PMCPIDs A51115, A51119, A51123, and A51127) ensures Peak Clad Temperatureaccident analysis remains bounding for a LOCA/Emergency Core Cooling Condition.With Containment Average Air Temperature <100 F or >115F, comply with theactions of TS 3.6.1.5.[ECI92-003, EC-6785]
OP-903-001  Revision 061Attachment 11.1 (18 of 37) 392.1 If PMC indication is not available, then the following indicators (within listedtemperature range requirements) may be used to meet the Surveillance Requirement: QSPDS 2 Page 102 indicationThe average of three indications shall be 100.5 F and 114.5 F to comply withTechnical Specification 3.6.1.5. The following temperature recorders:CFC Fan A - CCSITR5150ACFC Fan B - CCSITR5150BCFC Fan C - CCSITR5155ACFC Fan D - CCSITR5155BThe average of three indications shall be 100.7 F and 114.3F to comply withTechnical Specification 3.6.1.5.[ECI92-003, EC-6785]2.2 Reducing the peak linear heat generation rate limit in accordance with the COLR tocomply with Technical Specification 3.6.1.5 LCO Action a., may be accomplished bychanging COLSS Constant T42 (PMC PID K24409), Linear Heat Rate limit adjustmentfactor, to 0.984 in accordance with OP-004-005, Core Operating Limits SupervisorySystem Operation. COLSS Constant T42 should be restored to the value 1.000 uponexiting Technical Specification 3.6.1.5 LCO Action a.2.3 Prior to Containment Average Air Temperature lowering below specification, thenperform the following: Operate a Boric Acid Concentrator in Recirculation Mode in accordance withOP-007-001, Boron Management System (to arrest lowering of CCW Systemtemperature). If three Containment Fan Coolers are in service, then secure one ContainmentFan Cooler in accordance with OP-008-003, Containment Cooling System.3.0 If either Boron Dilution alarm is Inoperable, then verify Primary Makeup to Dilution Teeand Chem Add Tank, PMU-136, Locked Closed or power removed from all ChargingPumps. N/A if both Boron Dilution alarms are Operable, or in Modes 1 and 2.3.1 In Mode 3 and 4, verify plant conditions comply with TS. 3.1.2.9.a.2  or  3.1.2.9.b.2 atleast once per 24 hours. NA if not in Modes 3 or 4.4.0 Containment Spray Riser Level is not applicable in Mode 4 with RCS Pressure 400 PSIA.5.0 Verify that RCP(s) are in operation and circulating RCS flow by checking the following: RCP is drawing amperage. RCP indicates a differential pressure (If a RCP is secured, then the operatingRCP(s) differential pressure shall indicate higher than the secured RCP(s)). NA ifnot applicable.
O P-9 0 3-0 0 1 R e v i s i o n 0 6 1 A t t a c h m e n t 1 1.2 0 (1 o f 1 6)1 5 1 1 1.2 0 M O D E S 1-4 P M C T E C H N I C A L S P E C I F I C A T I O N S U R V E I L L A N C E L O G S (t y p i c a l)D A T E D E S C R I P T I O N N O T E M O D E T.S.C O M P#L I M I T U N I T S 0 0 0 0 1 2 0 0 A C C W T e m p e r a t u r e: 3 6.0 1-4 4.7.4.a P M C A T r a i n A 4 6 2 0 1 8 9 F B T r a i n A 4 6 3 0 1 8 9 F U H S M e t e o r o l o g y 1-4 P M C D r y B u l b T e m p e r a t u r e 5 7.0 C 4 8 5 1 7<9 2&deg;F W e t B u l b T e m p e r a t u r e 4 5.0 C 4 8 5 2 1 4 0 F P r i m a r y C o n t a i n m e n t A v e r a g e A i r T e m p: 2.0 1-4 4.6.1.5 P M C C F C A A i r I n l e t T e m p 2.1 A 5 1 1 1 5 N/A F C F C B A i r I n l e t T e m p 2.1 A 5 1 1 1 9 N/A F C F C C A i r I n l e t T e m p 2.1 A 5 1 1 2 3 N/A F C F C D A i r I n l e t T e m p 2.1 A 5 1 1 2 7 N/A F A v e r a g e C F C I n l e t T e m p 2.0 , 2.1 , 2.2 , 2.3 N/A 1 0 0 t o 1 1 5 F C O N T A I N M E N T S U M P F L O W 1 6.0 1-4 4.4.5.1.b C 4 2 6 1 4<1 I n c r e a s e G P M A x i a l S h a p e I n d e x: 1 9.0 1 ,>2 0%4.2.7 P M C C O L S S O p e r a b l e 5 0 1 9.1 C 2 4 0 0 3-0.1 6 t o+0.1 6 N/A C O L S S O p e r a b l e<5 0 1 9.2 C 2 4 0 0 3-0.2 6 t o+0.2 6 N/A R E M A R K S:
AMENDMENT NO. 27
,CHANGE NO. 2,8,17,38
, 54WATERFORD - UNIT 3B 3/4 6-2 CONTAINMENT SYSTEMSBASES3/4.6.1.4  INTERNAL PRESSUREThe limitations on containment internal pressure ensure that (1) the containmentstructure is prevented from exceeding its design negative pressure differential with respect tothe annulus atmosphere of 0.65 psid, (2) the containment peak pressure does not exceed thedesign pressure of 44 psig during either LOCA or steam line break conditions, and (3) theminimum pressure of the ECCS performance analysis (BTP CSB 61) is satisfied.The limit of +27 inches water (approximately 1.0 psig) for initial positivecontainment pressure is consistent with the limiting containment pressure and temperatureresponse analyses inputs and assumptions.The limit of 14.275 psia for initial negative containment pressure ensures that theminimum containment pressure is consistent with the ECCS performance analysis ensuringcore reflood under LOCA conditions, thus ensuring peak cladding temperature and claddingoxidation remain within limits. The 14.275 psia limit also ensures the containment pressure willnot exceed the containment design negative pressure differential with respect to the annulusatmosphere in the event of an inadvertent actuation of the containment spray system.3/4.6.1.5  AIR TEMPERATURE(DRN 04-1243, Ch. 38;EC-7193, Am. 54
)The limitation on containment minimum average air temperature ensures that the ECCSis capable of maintaining a peak clad temperature (PCT) less than or equal to 2200F underLOCA conditions. A lower containment average air temperature results in a lower post accidentcontainment pressure, a lower reflood rate, and therefore a higher PCT. The containmentminimum average air temperature limit is only applicable above 70% rated thermal power. Atpower levels of 70% or below and a containment minimum average air temperature of less than 95F, ECCS is capable of maintaining the peak clad temperature (PCT) less than or equal to2200F under LOCA conditions.Core Operating Limits Report (COLR) requires that the linearheat rate be reduced by 0.2 kw/ft when the containment air temperature is less than 95&deg;F butgreater than or equal to 90&deg;F.(DRN 04-1243, Ch. 38;EC-7193, Am. 54
)The limit of 120F on high average containment temperature is consistent with thelimiting containment pressure and temperature response analyses inputs and assumptions. Thelimits currently adopted by Waterford 3 are 269.3F during LOCA conditions and 413.5F duringMSLB conditions.
(DRN 02-1904
; 04-1243, Ch. 38;EC-7193, Am. 54
)The 95F minimum and 120F maximum indicated values specified in the TS are thevalues used in the accident analysis.(DRN 02-1904; 04-1243, Ch. 38;EC-7193, Am. 54
)3/4.6.1.6  CONTAINMENT VESSEL STRUCTURAL INTEGRITYThis limitation ensures that the structural integrity of the containment steel vessel willbe maintained comparable to the original design standards for the life of the facility. Structuralintegrity is required to ensure that the containment vessel will withstand the maximum pressureresulting from the design basis LOCA and main steam line break accident. A visual inspection inconjunction with Type A leakage test is sufficient to demonstrate this capability.
Waterford 3 2015 RO NRC Exam JOB PERFORMANCE MEASURE A4  Calculate Stay Times Based on Dose Rates Applicant:
Examiner:
 
JPM A4  Revision 0 Page 2 of 6 2015 RO NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Calculate Stay Times Based on Dose Rates Task Standard: Applicant correctly calculated the allowed stay time to complete the described tagout without exceeding his yearly Waterford 3 administrative radiation dose limits.
 
==References:==
UNT-001-016, Radiation Protection Alternate Path:
No Time Critical: No Validation Time: 15 mins. K/A 2.3.4, Knowledge of radiation exposure limits Importance Rating 3.2 under normal and emergency conditions.
RO        Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM A4  Revision 0 Page 3 of 6 2015 RO NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
None 
 
== Description:==
 
This JPM requires the applicant to correctly calculate the allowed stay time to complete the described tagout without exceeding his yearly Waterford 3 administrative radiation dose limits.
READ TO APPLICANT DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
  (Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM A4  Revision 0 Page 4 of 6 2015 RO NRC Exam TASK ELEMENT STANDARD Calculate stay time based on dose rate and Waterford 3 yearly TEDE limits. Applicant calculated the stay time as 8.8 to 8.824 minutes. Comment:  Waterford 3 administrative TEDE limit: 2000 mrem Dose for the year:
1875 mrem Remaining dose for the year:  125 mrem  Time allowed in room:
125 mrem / 850 mrem/hour 0.147 hour or 8.8 minutes Critical SAT  /  UNSAT END OF TASK
 
JPM A4  Revision 0 Page 5 of 6 2015 RO NRC Exam SIMULATOR OPERATOR INSTRUCTIONS None.
JPM A4  Revision 0 Page 6 of 6 2015 RO NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
You have been assigned to verify a 5 valve tagout on the -11 Elevation in Containment.
Your yearly dose to date is 1875 mrem TEDE for the year. The dose rate in that area is 850 mrem/hour.
Based on Waterford 3 yearly administrative limits, what is your maximum allowed stay time in the room?
Do all of your calculations on this sheet.
 
Waterford 3 2015 NRC SRO Exam JOB PERFORMANCE MEASURE A5  Review DNBR and LPD Limits Associated with OP-901-501, PMC or COLSS Malfunction Applicant:
Examiner:
 
JPM A5  Revision 0 Page 2 of 6 NRC SRO Exam 2015 JOB PERFORMANCE MEASURE DATA PAGE Task: Review DNBR and LPD Limits Associated with OP-901-501, PMC or COLSS Malfunction Task Standard: Applicant reviews completed OP-901-501 paperwork discovers errors on Attachments 2 and Attachment 3.
 
==References:==
OP-901-501, PMC or COLSS Malfunction Technical Specification 3.2.4 and COLR 3.2.4 Alternate Path:
No Time Critical:
No Validation Time:
25 mins. K/A 2.1.20, Ability to interpret and execute  Importance Rating
 
===4.6 procedure===
steps.
SRO        Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM A5  Revision 0 Page 3 of 6 NRC SRO Exam 2015 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-901-501, PMC or Core Operating Limit Supervisory System Malfunction
 
== Description:==
 
This JPM requires the applicant to review completed OP-901-501 paperwork and discover errors on Attachments 2 and Attachment 3.
READ TO APPLICANT DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
  (Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM A5  Revision 0 Page 4 of 6 NRC SRO Exam 2015 TASK ELEMENT STANDARD Applicant discovers that all 4 CPC LPD limits calculated on Attachment 2 were done with the calculation in step 5 vice step 4. Corrected CPC LPD limits to 12.12, 11.91, 12.11, and 13.41 for Channels A through D. Comment:  Critical SAT  /  UNSAT TASK ELEMENT STANDARD OP-901-501 Attachment 3 LPD limit lists correct value. Applicant corrected the 4 CPC LPD limits on Attachment 3. Comment:    SAT  /  UNSAT TASK ELEMENT STANDARD Applicant discovers that the BOP operator filled in No for DNBR within limits of Tech Spec 3.2.4 on any operable CPC Channel. Applicant determined Channel A or Channel B meet the limits of Tech Spec 3.2.4, using COLR figure 8A on page 3/4-2-6B. Comment:  Critical SAT  /  UNSAT END OF TASK
 
JPM A5  Revision 0 Page 5 of 6 NRC SRO Exam 2015 SIMULATOR OPERATOR INSTRUCTIONS None.
JPM A5  Revision 0 Page 6 of 6 NRC SRO Exam 2015 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
100% power  Both CEACs are operable  250 EFPD  Containment temperature is 102 &deg;F  The Plant Monitoring Computer failed at 1900 on 9/14/2015. You have entered OP-901-501, PMC or Core Operating Limit Supervisory System Malfunction.
INITIATING CUES:
The BOP operator has completed Attachment 1, CPC DNBR Limit Calculation, Attachment 2, CPC LPD Limit Calculation , and Attachment 3, 15 Minute Log, of OP-901-501. He has also informed you that the plant is not in compliance with Tech Spec 3.2.4 as a result of his calculations. Review the attached paperwork for accuracy and document any errors or discrepancies identified.
 
Off Normal Procedure OP-901-501 PMC or Core Operating Limit Supervisory System Malfunction Revision 015 Page 1 of 1 Transmit with OP-903-001, Technical Specification Surveillance Logs. 1 A5 Key  ATTACHMENT 1: CPC DNBR LIMIT CALCULATION
: 1. Record CPC DNBR in column (1) and CPC PHICAL in column (3) using data from CPC's. 2. Record COLSS DNBR POL in column (2) using last valid value for COLSS DNBR POL, PMC PID C24560 as found on dedicated trend pen recorder.
: 3. Perform CPC DNBR Limit calculation for each CPC Channel with data from applicable column using the formula shown below. Record results in column (4).
[(2) - (3)] X 0.03 = (4)
: 4. If available DNBR margin
> 0.15, then perform the following calculation. Record results in column (5).
(1) - 0.1 = (5)
: 5. If available DNBR margin  0.15, then perform the following calculation. Record results in column (5).
(1) - (4) = (5) Available DNBR Limit CPC  Channel (1)  CPC DNBR  PID 406 (2)  COLSS DNBR POL (3)  CPC PHICAL PID 171 (4)  Available Margin (5)  CPC DNBR Limit A 2.17 109 100.7 0.249 2.07 B 2.13 109 100.5 0.255 2.03 C 2.17 109 100.5 0.255 2.07 D 2.13 109 100.9 0.243 2.03  Performed ___
jhmendoza________________________  Date/Time__9/14/15 1905 Verified ___joe operator_______________________  Date/Time__9/14/15 1910 SM/CRS _______________________________________  Date/Time___________
 
Off Normal Procedure OP-901-501 PMC or Core Operating Limit Supervisory System Malfunction Revision 015 Page 1 of 1 Transmit with OP-903-001, Technical Specification Surveillance Logs. 2 A5 KEY ATTACHMENT 2: CPC LPD LIMIT CALCULATION
: 1. Record CPC LPD in column (1) and CPC PHICAL in column (3) using data from CPC's. 2. Record COLSS KW/FT POL (2) using last valid value for COLSS KW/FT POL, PMC PID C24561 as found on dedicated trend pen recorder.
: 3. Perform CPC KW/FT Limit calculation for each CPC Channel with data from applicable column using the formula shown below. Record results in column (4).
: 4. If available LPD margin > 0.4, then perform the following calculation. Record results in column (5). (1) + 0.25 = (5)
: 5. If available LPD margin  0.4, then perform the following calculation. Record results in column (5). (1) + (4) = (5) (Incorrect LPD limit calculated) Available LPD Margin Limit CPC  Channel (1)  CPC LPD  PID 179 (2)  COLSS KW/FT POL (3)  CPC PHICAL PID 171 (4)  Available Margin (5)  CPC LPD Limit A 11.87 113 100.7 0.683 12.55 B 11.66 113 100.5 0.694 12.35 C 11.86 113 100.5 0.694 12.55 D 13.16 113 100.9 0.672 13.83  Performed _____
jhemdoza________________________  Date/Time_9/14/15 1905 Verified _____joe operator______________________  Date/Time_9/14/15 1910 SM/CRS ________________________________________Date/Time_________
)()()(4 18 3 2 Off Normal Procedure OP-901-501 PMC or Core Operating Limit Supervisory System Malfunction Revision 015 Page 7 of 7 A5 KEY ATTACHMENT 3: 15 MINUTE L OG [P-461, P-13445, P-13446, P-20634] (Incorrect limits for LPD from Attachment 2) TIME: 1915 1930    CPC Channel A Limits LPD PID 179 11.87 11.87    LPD =    _12.55
___ DNBR PID 406 2.17 2.15 (COLR met, 2.11 required) DNBR = ____2.07
_ ASI PID 268 0.01 0.01    CPC Channel B Limits LPD PID 179 11.66 11.67    LPD =    __12.35
__ DNBR PID 406 2.13 2.12 (COLR met, 2.09 required) DNBR = ___2.03
_ ASI PID 268 -0.02 -0.02    CPC Channel C Limits LPD PID 179 11.86 11.85    LPD =    __12.55
__ DNBR PID 406 2.10 2.06 (COLR not met , 2.10 required) DNBR = ____2.07
_ ASI PID 268 -0.005 -0.01    CPC Channel D Limits LPD PID 179 13.16 13.17    LPD =    __13.83
__ DNBR PID 406 2.07 2.04 (COLR not met, 2.10 required) DNBR = ___2.03
__ ASI PID 268 -0.01 -0.015    CPC LPD < CPC LPD LIMIT ON ALL "OPERABLE" CPC CHANNELS              (Y/N) Y Y    LPD WITHIN LIMITS OF T.S. 3.2.1 ON ANY "OPERABLE" CPC CHANNEL.                        (Y/N)
Note (1) and (2)
Y Y    CPC DNBR > CPC DNBR LIMIT ON ALL "OPERABLE" CPC CHANNELS              (Y/N) Y N    DNBR WITHIN LIMITS OF T.S. 3.2.4 ON ANY "OPERABLE" CPC CHANNEL                  (Y/N) **
Y N (Should be a "Y")
ASI ACCEPTABLE                            (Y/N) ***
Y Y    PERFORMED BY (INITIALS) jho jho    Note (1) IF LPD is not within the limits of T.S. 3.2.1 on any "operable" CPC Channel, then enter Technical Specification 3.2.1. Note (2) If complying with the applicable action of Technical Specification 3.6.1.5 due to low Containment temperatures, then apply the action in the COLR 3.2.1 for reducing LPD. This requirement for Containment temperature is applicable when > 70% power. (Due to instrument inaccuracies, OP-903-001 applies the minimum temperature of 100  F vice 95F.)  ** If DNBR is not within the limits of T.S. 3.2.4 on any "operable" CPC Channel, then enter Technical Specification 3.2.4.
*** ASI is acceptable IF within limits of Technical Specification 3.2.7. Performed by: joe  operator  9/14/15  (Signature)
(Date) SM/CRS Review: 
/  (Signature)
(Date/Time)
 
Off Normal Procedure OP-901-501 PMC or Core Operating Limit Supervisory System Malfunction Revision 015 Page 1 of 1 Transmit with OP-903-001, Technical Specification Surveillance Logs. 1 A5 Student ATTACHMENT 1: CPC DNBR LIMIT CALCULATION
: 1. Record CPC DNBR in column (1) and CPC PHICAL in column (3) using data from CPC's. 2. Record COLSS DNBR POL in column (2) using last valid value for COLSS DNBR POL, PMC PID C24560 as found on dedicated trend pen recorder.
: 3. Perform CPC DNBR Limit calculation for each CPC Channel with data from applicable column using the formula shown below. Record results in column (4).
[(2) - (3)] X 0.03 = (4)
: 4. If available DNBR margin
> 0.15, then perform the following calculation. Record results in column (5).
(1) - 0.1 = (5)
: 5. If available DNBR margin  0.15, then perform the following calculation. Record results in column (5).
(1) - (4) = (5) Available DNBR Limit CPC  Channel (1)  CPC DNBR  PID 406 (2)  COLSS DNBR POL (3)  CPC PHICAL PID 171 (4)  Available Margin (5)  CPC DNBR Limit A 2.17 109 100.7 0.249 2.07 B 2.13 109 100.5 0.255 2.03 C 2.17 109 100.5 0.255 2.07 D 2.13 109 100.9 0.243 2.03  Performed ___
jhmendoza________________________  Date/Time__9/14/15 1900 Verified ___joe operator_______________________  Date/Time__9/14/15 1910 SM/CRS _______________________________________  Date/Time___________
 
Off Normal Procedure OP-901-501 PMC or Core Operating Limit Supervisory System Malfunction Revision 015 Page 1 of 1 Transmit with OP-903-001, Technical Specification Surveillance Logs. 2 ATTACHMENT 2: CPC LPD LIMIT CALCULATION
: 1. Record CPC LPD in column (1) and CPC PHICAL in column (3) using data from CPC's. 2. Record COLSS KW/FT POL (2) using last valid value for COLSS KW/FT POL, PMC PID C24561 as found on dedicated trend pen recorder.
: 3. Perform CPC KW/FT Limit calculation for each CPC Channel with data from applicable column using the formula shown below. Record results in column (4).
: 4. If available LPD margin > 0.4, then perform the following calculation. Record results in column (5). (1) + 0.25 = (5)
: 5. If available LPD margin  0.4, then perform the following calculation. Record results in column (5). (1) + (4) = (5) Available LPD Margin Limit CPC  Channel (1)  CPC LPD  PID 179 (2)  COLSS KW/FT POL (3)  CPC PHICAL PID 171 (4)  Available Margin (5)  CPC LPD Limit A 11.87 113 100.7 0.683 12.55 B 11.66 113 100.5 0.694 12.35 C 11.86 113 100.5 0.694 12.55 D 13.16 113 100.9 0.672 13.83  Performed _____
jhemdoza________________________  Date/Time_9/14/15 1900 Verified _____joe operator______________________  Date/Time_9/14/15 1910 SM/CRS ________________________________________Date/Time_________
)()()(4 18 3 2 Off Normal Procedure OP-901-501 PMC or Core Operating Limit Supervisory System Malfunction Revision 015 Page 7 of 7 ATTACHMENT 3: 15 MINUTE L OG [P-461, P-13445, P-13446, P-20634] TIME: 1915 1930    CPC Channel A Limits LPD PID 179 11.87 11.87    LPD =    _12.55
___ DNBR PID 406 2.17 2.15    DNBR = ____2.07
_ ASI PID 268 0.01 0.01    CPC Channel B Limits LPD PID 179 11.66 11.67    LPD =    __12.35
__ DNBR PID 406 2.13 2.12    DNBR = ___2.03
_ ASI PID 268 -0.02 -0.02    CPC Channel C Limits LPD PID 179 11.86 11.85    LPD =    __12.55
__ DNBR PID 406 2.10 2.06    DNBR = ____2.07
_ ASI PID 268 -0.005 -0.01    CPC Channel D Limits LPD PID 179 13.16 13.17    LPD =    __13.83
__ DNBR PID 406 2.07 2.04    DNBR = ___2.03
__ ASI PID 268 -0.01 -0.015    CPC LPD < CPC LPD LIMIT ON ALL "OPERABLE" CPC CHANNELS              (Y/N) Y Y    LPD WITHIN LIMITS OF T.S. 3.2.1 ON ANY "OPERABLE" CPC CHANNEL.                        (Y/N)
Note (1) and (2)
Y Y    CPC DNBR > CPC DNBR LIMIT ON ALL "OPERABLE" CPC CHANNELS              (Y/N) Y N    DNBR WITHIN LIMITS OF T.S. 3.2.4 ON ANY "OPERABLE" CPC CHANNEL                  (Y/N) **
Y N    ASI ACCEPTABLE                            (Y/N) ***
Y Y    PERFORMED BY (INITIALS) jho jho    Note (1) IF LPD is not within the limits of T.S. 3.2.1 on any "operable" CPC Channel, then enter Technical Specification 3.2.1. Note (2) If complying with the applicable action of Technical Specification 3.6.1.5 due to low Containment temperatures, then apply the action in the COLR 3.2.1 for reducing LPD. This requirement for Containment temperature is applicable when > 70% power. (Due to instrument inaccuracies, OP-903-001 applies the minimum temperature of 100  F vice 95F.)  ** If DNBR is not within the limits of T.S. 3.2.4 on any "operable" CPC Channel, then enter Technical Specification 3.2.4.
*** ASI is acceptable IF within limits of Technical Specification 3.2.7. Performed by: joe  operator  9/14/15  (Signature)
(Date) SM/CRS Review:
  /  (Signature)
(Date/Time)
 
WATERFORD 3COLR 3/4 2-6BCYCLE 20 REVISION 1Subset of Allowable DNBR with Any CEAC Operable(COLSS Out of Service)1.501.752.002.252.502.753.003.253.503.754.00-0.2-0.10.0 0.10.2Core Average ASI(COLR Figure 8A)1.501.752.002.252.502.753.003.253.503.754.00Unacceptable OperationAcceptable Operation  95% Power 100%Acceptable Operation  70% Power 100%(+0.12, 2.81)Acceptable Operation  80% Power 100%Acceptable Operation  90% Power 100%(+0.03, 3.33)(-0.12, 2.04)(-0.12, 3.12)(+0.12, 3.33)(-0.12, 2.62)(+0.12, 2.17)(+0.07, 2.81)(-0.12, 2.22)(+0.12, 2.37)(+0.08, 2.37)DNBR = (0.542 x ASI) + 2.105DNBR = (0.750 x ASI) + 2.310DNBR = (1.000 x ASI) + 2.740DNBR = (1.400 x ASI) + 3.288 Waterford 3 2015 NRC SRO Exam JOB PERFORMANCE MEASURE A6  Review and Approve OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data.
Applicant:
Examiner:
 
JPM A6  Revision 0 Page 2 of 6 2015 SRO NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Review and approve OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data.
Task Standard: Applicant discovers 3 errors on the surveillance affecting power calibrations in accordance with the JPM key.
 
==References:==
OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data Alternate Path:
No Time Critical: No Validation Time: 20 mins. K/A 2.1.18, Ability to make accurate, clear, and  Importance Rating 3.8 concise logs, records, status boards, and SRO  reports    Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM A6  Revision 0 Page 3 of 6 2015 SRO NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data
 
== Description:==
Applicant will review a completed set of calculations for CPC constants KCAL, TCREF, and TPC.
READ TO APPLICANT DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
  (Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM A6  Revision 0 Page 4 of 6 2015 SRO NRC Exam TASK ELEMENT 1 STANDARD Review and approve OP-903-001, Attachment 11.18. Applicant must identify 3 errors that were committed performing the surveillance in accordance with the A6 Key. Comment: Error 1:  Step 11.10.6.1, In the KCAL calculation, BDT power was recorded instead of PHICAL. Error 2:  Step 11.10.6.1, Error 1 caused an error to be carried forward in the calculation of KCAL. Error 3:  Step 11.10.6.3, the minimum Tc was not selected. PID 161 should have been selected instead of PID 160.
Critical SAT  /  UNSAT END OF TASK
 
JPM A6  Revision 0 Page 5 of 6 2015 SRO NRC Exam SIMULATOR OPERATOR INSTRUCTIONS None JPM A6  Revision 0 Page 6 of 6 2015 SRO NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
Reactor power is 100% and steady  The UFM is in service. OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data, has been completed for Channel B. Data collection from CP-10 and for the Linear Power Potentiometer is not required for this task.  "N/A" has been placed on the surveillance for those items.
INITIATING CUES:
Review and approve the provided surveillance  The previous CRS directed the reactor operator to gather required data once for column "0", averages were not required.
 
A6 KeyOP-903-001  Revision 061Attachment 11.18 (1 of 3) 14711.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATADATE _______________    CHANNEL UNDER ADJUSTMENT: A B    C    D11.10.3.1Calculate and record the averages of each parameter in the spaceprovided.0 1 2 3 4Average AdjustedBSCALPMC PID-C24230 99.87HI LINEAR POWERBISTABLE 1 VOLTS N/AHIGH LINEAR POWER %VOLT X 20 N/APHICAL.(Calibrated Neutron Flux Power)CPC PID 171 99.96 BDT(Static Thermal Power)CPC PID 177 99.82Calculations Performed by:joe operatorVerified by:jane operatorSignatureSignature  Refer to attachment 11.1 Note 9.1 to determine appropriate power indication if linearpower is not35% steady state. Document indication used in Remarks. If COLSS is Inoperable, then use NE-005-201, Heat Balance Calculations, to determineSecondary Calorimetric Power substitute when PMC or CORE POWER is specified.Adjusted is the average value plus 8.5% (8% to10%) if adjustments are being made toPHICAL and/or BDT as listed in Notes above steps 11.10.6 or 11.10.7 (refer to Attachment11.1 Note 9.8). Otherwise N/A this block.Use theAverage value, not the Adjusted value, forDVM calculation.11.10.4 Record the following for channel under adjustment:TPC (Thermal Power Calibration Constant)CPC PID 064 ...................................................0.84399KCAL (Neutron Flux Power Cal. Constant)CPC PID 065 ...................................................1.0070PCALIB (Secondary Calorimetric Power Used inLatest CPC Power Calibration) CPC PID 104 100TC 1 (Loop 1 Cold Leg Temperature)CPC PID 160 ...................................................543.59TC 2 (Loop 2 Cold Leg Temperature)CPC PID 161 ...................................................543.46TCORF (Temp Shadowing Correction Factor)CPC PID 180 ...................................................0.99902EXCORE LINEAR POWER CALIBRATEPOTENTIOMETER POSITION ROM ..............N/A A6 KeyOP-903-001  Revision 061Attachment 11.18 (2 of 3) 14811.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONT'D)11.10.5 Calculate the new DVM reading or new potentiometer position as follows:DVM (new) =Avg. Core Power (Step 11.10.3.1)*
=N/A 20 20* Use theAverage value from the table of step 11.10.3.1, not the Adjusted value.DVM (new) =N/A orPotentiometer position (new) =Avg. Core Power % (Step 11.10.3.1)* X Old Potentiometer Setting (Step 11.10.4)Avg. Linear Power % (Step 11.10.4)N/A XN/AN/A* Use theAverage value from the table of step 11.10.3.1, not the Adjusted value.Potentiometer position (new) =______N/A_______Performed by:N/AVerified by:N/A(Initials)(Initials)11.10.6.1Calculate KCAL (new):
KCAL(new)=(Step 11.10.3.1)* (step 11.10.4)  (step 11.10.4)Avg. Core Power (%)
x KCAL x TCORFAvg. PHICAL(step 11.10.3.1)
* AnAdjusted value may be required. Refer to Note preceding step 11.10.6.
KCAL(new)=99.87 x1.0070 x.9990299.96(99.82, selected BDT instead of PHICAL - ERROR 1)
KCAL(new)=1.0051(1.0065, error carriedforward - ERROR 2)KCAL (new) =1.005 1(1.0065, error carried forward ERROR 2)(CPC PID 065)11.10.6.3New TCREF (CPC PID 098) = Minimum TC from step 11.10.4:TC 1 (CPC PID 160) or  TC 2 (CPC PID 161).TCREF (new) =543.46(543.59, not the min Tc ERROR 3)(CPC PID 098)Performed by:joe operatorVerified by:jane operarator(Initials)(Initials)
A6 KeyOP-903-001  Revision 061Attachment 11.18 (3 of 3) 14911.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONT'D)11.10.7 Calculate TPC (CPC PID 064):TPC (new)=Avg. Core Power % (Step 11.10.3.1)* XTPC (Step 11.10.4)Avg. BDT (Step 11.10.3.1)
* AnAdjusted value may be required. Refer to Note preceding step 11.10.7.TPC (new)=
99.87 X 0.84399 99.82TPC (new) =
0.84441(CPC PID 064).Performed by:joe operator IV by:jane operarator(Initials)(Initials)11.10.11.1 Record the following: Applicable CORE POWER PMC .................................... ___________ PCALIB CPC PID 104  .............................................. ___________ HI LINEAR POWER BISTABLE 1 VOLTS ..................... ___________ HI LINEAR POWER % VOLTS x 20 .............................. ___________ PHICAL CPC PID 171  .............................................. ___________ BDT CPC PID 177 .............................................. ___________11.10.11.2.1Record answers: HI LINEAR POWER %, VOLTS X 20 .................... YES/NO ________ PHICAL, CPC PID 171  ..................................... YES/NO ________ BDT, CPC PID 177 ..................................... YES/NO ________11.10.12 Performed by:
IV by:(Initials)(Initials)11.10.13  Reviewed by:_________________________  _________________SM/CRSDate/Time A6 StudentOP-903-001  Revision 061Attachment 11.18 (1 of 3) 14711.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATADATE __Today_____    CHANNEL UNDER ADJUSTMENT: A B    C    D11.10.3.1Calculate and record the averages of each parameter in the spaceprovided.0 1 2 3 4Average AdjustedBSCALPMC PID-C24230 99.87HI LINEAR POWERBISTABLE 1 VOLTS N/AHIGH LINEAR POWER %VOLT X 20 N/APHICAL.(Calibrated Neutron Flux Power)CPC PID 171 99.96 BDT(Static Thermal Power)CPC PID 177 99.82Calculations Performed by:Verified by:SignatureSignature  Refer to attachment 11.1 Note 9.1 to determine appropriate power indication if linearpower is not35% steady state. Document indication used in Remarks. If COLSS is Inoperable, then use NE-005-201, Heat Balance Calculations, to determineSecondary Calorimetric Power substitute when PMC or CORE POWER is specified.Adjusted is the average value plus 8.5% (8% to10%) if adjustments are being made toPHICAL and/or BDT as listed in Notes above steps 11.10.6 or 11.10.7 (refer to Attachment11.1 Note 9.8). Otherwise N/A this block.Use theAverage value, not the Adjusted value, forDVM calculation.11.10.4 Record the following for channel under adjustment:TPC (Thermal Power Calibration Constant)CPC PID 064 ...................................................0.84399KCAL (Neutron Flux Power Cal. Constant)CPC PID 065 ...................................................1.0070PCALIB (Secondary Calorimetric Power Used inLatest CPC Power Calibration) CPC PID 104 100TC 1 (Loop 1 Cold Leg Temperature)CPC PID 160 ...................................................543.59TC 2 (Loop 2 Cold Leg Temperature)CPC PID 161 ...................................................543.46TCORF (Temp Shadowing Correction Factor)CPC PID 180 ...................................................0.99902EXCORE LINEAR POWER CALIBRATEPOTENTIOMETER POSITION ROM ..............N/A A6 StudentOP-903-001  Revision 061Attachment 11.18 (2 of 3) 14811.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONT'D)11.10.5 Calculate the new DVM reading or new potentiometer position as follows:DVM (new) =Avg. Core Power (Step 11.10.3.1)*
=N/A 20 20* Use theAverage value from the table of step 11.10.3.1, not the Adjusted value.DVM (new) =N/A orPotentiometer position (new) =Avg. Core Power % (Step 11.10.3.1)* X Old Potentiometer Setting (Step 11.10.4)Avg. Linear Power % (Step 11.10.4)N/A XN/AN/A* Use theAverage value from the table of step 11.10.3.1, not the Adjusted value.Potentiometer position (new) =______N/A_______Performed by:N/AVerified by:N/A(Initials)(Initials)11.10.6.1Calculate KCAL (new):
KCAL(new)=(Step 11.10.3.1)* (step 11.10.4)  (step 11.10.4)Avg. Core Power (%)
x KCAL x TCORFAvg. PHICAL(step 11.10.3.1)
* AnAdjusted value may be required. Refer to Note preceding step 11.10.6.
KCAL(new)=99.87 x1.0070 x.99902 99.82 KCAL(new)=1.0065KCAL (new) =1.00 65(CPC PID 065)11.10.6.3New TCREF (CPC PID 098) = Minimum TC from step 11.10.4:TC 1 (CPC PID 160) or  TC 2 (CPC PID 161).TCREF (new) =543.59(CPC PID 098)Performed by:
POVerified by:
VO(Initials)(Initials)
A6 StudentOP-903-001  Revision 061Attachment 11.18 (3 of 3) 14911.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONT'D)11.10.7 Calculate TPC (CPC PID 064):TPC (new)=Avg. Core Power % (Step 11.10.3.1)* XTPC (Step 11.10.4)Avg. BDT (Step 11.10.3.1)
* AnAdjusted value may be required. Refer to Note preceding step 11.10.7.TPC (new)=
99.87 X 0.84399 99.82TPC (new) =
0.84441(CPC PID 064).Performed by:
PO IV by: VO(Initials)(Initials)11.10.11.1 Record the following: Applicable CORE POWER PMC .................................... ___________ PCALIB CPC PID 104  .............................................. ___________ HI LINEAR POWER BISTABLE 1 VOLTS ..................... ___________ HI LINEAR POWER % VOLTS x 20 .............................. ___________ PHICAL CPC PID 171  .............................................. ___________ BDT CPC PID 177 .............................................. ___________11.10.11.2.1Record answers: HI LINEAR POWER %, VOLTS X 20 .................... YES/NO ________ PHICAL, CPC PID 171  ..................................... YES/NO ________ BDT, CPC PID 177 ..................................... YES/NO ________11.10.12 Performed by:
IV by:(Initials)(Initials)11.10.13  Reviewed by:_________________________  _________________SM/CRSDate/Time
 
OP-903-001  Revision 061Attachment 11.10 (1 of 10) 11411.10 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION INSTRUCTIONDATE ______________      CHANNEL UNDER ADJUSTMENT:  A B    C    DNOTEDuring physics testing, Note 2 of TS Table 4.3-1 applies and allows the suspension of thisadjustment until the next power plateau is reached. The assigned Shift Test Director shouldbe notified during testing prior to making any adjustments per this attachment.11.10.1 If a non-conservative adjustment (indicated power is lowered) is required to bemade on CPC and Excore Nuclear Instrumentation, then verify that both of thefollowing conditions are met: BDELT (C24104) is within 2% of BTFSP (C24101) The average of BDELT (C24104) and BTFSP (C24101) is within 2% ofCalorimetric Power11.10.1.1 If either of these conditions cannot be met, then notify Reactor Engineering(RE) for further evaluation prior to making any adjustment.11.10.2 If either of the following conditions are not met, then use the applicable power forCORE POWER PMC as specified in Note 9.1 of Attachment 11.1. UFM is in service Plant is in steady state operationNOTEAverages are recommended for accuracy, but are not required.11.10.3 Record the following data at approximately one minute intervals onAttachment 11.18: BSCAL- PMC PID C24230 HI LINEAR POWERBISTABLE 1 VOLTS HIGH LINEAR POWER % VOLT X 20 PHICAL (Calibrated Neutron Flux Power) CPC PID 171 BDT (Static Thermal Power) CPC PID 17711.10.3.1 Calculate and record averages of each parameter on Attachment 11.18.
OP-903-001  Revision 061Attachment 11.10 (2 of 10) 11511.10.4 Record the following data for channel under adjustment on Attachment 11.18: TPC (Thermal Power Calibration Constant) CPC PID 064 KCAL (Neutron Flux Power Cal. Constant) CPC PID 065 PCALIB (Secondary Calorimetric Power Used in Latest CPC PowerCalibration) CPC PID 104 TC 1 (Loop 1 Cold Leg Temperature) CPC PID 160 TC 2 (Loop 2 Cold Leg Temperature) CPC PID 161 TCORF (Temp Shadowing Correction Factor) CPC PID 180 EXCORE LINEAR POWER CALIBRATE POTENTIOMETER POSITION ROM(may be N/A'd if not using in step 11.10.5)11.10.5 If Hi Linear Power requires adjustment, then calculate the new DVM reading ornew potentiometer position on Attachment 11.18
.
OP-903-001  Revision 061Attachment 11.10 (3 of 10) 116NOTEUnder the following conditions, PHICAL (CPC PID 171) must be adjusted to between +8.0%and +10.0% above the calorimetric power indication (refer to Note 9.8 on Attachment 11.1).This is performed by adding 8.5% (8% to10%) to the average core power value onAttachment 11.18 to obtain anAdjusted value that will be used as the Avg. Core Power valuein the KCAL (new) calculation (this requirement does not apply during initial power ascensionto <80% RTP following refueling):[CR-WF3-2006-03726] Calorimetric power is between 15% RTP and 80% RTP.and PHICAL is greater than 10.0% above Calorimetric power.11.10.6 If KCAL (PHICAL) requires adjustment, then perform the following.11.10.6.1 Calculate KCAL (new) on Attachment 11.18.
CAUTIONCPC PID 065 (KCAL) limit is 0.7 to 2.0.[CR-WF3-1998-00919]11.10.6.2 If KCAL (new) is 0.8, then then perform the following:[CR-WF3-1998-00919, CR-WF3-2015-02641] Generate a Condition Report. Notify RXE to complete NE-002-010, Linear Power Subchannel GainAdjustment. Notify PMI that adjustment will be required on the affected channel(PMID 2806).11.10.6.3 Document new TCREF(CPC PID 098) on Attachment 11.18.
OP-903-001  Revision 061Attachment 11.10 (4 of 10) 117NOTEUnder the following conditions, BDT (CPC PID 177) must be adjusted to between +8.0% and+10.0% above the calorimetric power indication (refer to Note 9.8 on Attachment 11.1). Thisis performed by adding 8.5% (8% to10%) to the average core power value on Attachment11.18 to obtain anAdjusted value that will be used as the Avg. Core Power value in the TPCcalculation (this requirement does not apply during initial power ascension to <80% RTPfollowing refueling):[CR-WF3-2006-03726] Calorimetric power is between 15% RTP and 80% RTP.and BDT is greater than 10.0% above Calorimetric power.11.10.7 If BDT requires adjustment, then Calculate TPC (CPC PID 064) on Attachment11.18.
OP-903-001  Revision 061Attachment 11.18 (1 of 3) 14711.18 ADJUSTMENT OFCPC AND EXCORE NUCLEAR INSTRUMENTATION DATADATE _______________    CHANNEL UNDER ADJUSTMENT: A B    C    D11.10.3.1Calculate and record the averages of each parameter in the spaceprovided.0 1 2 3 4Average AdjustedBSCALPMC PID-C24230HI LINEAR POWERBISTABLE 1 VOLTSHIGH LINEAR POWER %VOLT X 20PHICAL.(Calibrated Neutron Flux Power)CPC PID 171 BDT(Static Thermal Power)CPC PID 177Calculations Performed by:Verified by:SignatureSignature  Refer to attachment 11.1 Note 9.1 to determine appropriate power indication if linearpower is not35% steady state. Document indication used in Remarks. If COLSS is Inoperable, then use NE-005-201, Heat Balance Calculations, to determineSecondary Calorimetric Power substitute when PMC or CORE POWER is specified.Adjusted is the average value plus 8.5% (8% to10%) if adjustments are being made toPHICAL and/or BDT as listed in Notes above steps 11.10.6 or 11.10.7 (refer to Attachment11.1 Note 9.8). Otherwise N/A this block.Use theAverage value, not the Adjusted value, forDVM calculation.11.10.4 Record the following for channel under adjustment:TPC (Thermal Power Calibration Constant)CPC PID 064 ...................................................KCAL (Neutron Flux Power Cal. Constant)CPC PID 065 ...................................................PCALIB (Secondary Calorimetric Power Used inLatest CPC Power Calibration) CPC PID 104TC 1 (Loop 1 Cold Leg Temperature)CPC PID 160 ...................................................TC 2 (Loop 2 Cold Leg Temperature)CPC PID 161 ...................................................TCORF (Temp Shadowing Correction Factor)CPC PID 180 ...................................................
EXCORE LINEAR POWER CALIBRATEPOTENTIOMETER POSITION ROM ..............
OP-903-001  Revision 061Attachment 11.18 (2 of 3) 14811.18 ADJUSTMENT OFCPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONT'D)11.10.5 Calculate the new DVM reading or new potentiometer position as follows:DVM (new) =Avg. Core Power (Step 11.10.3.1)*
=20 20* Use theAverage value from the table of step 11.10.3.1, not the Adjusted value.DVM (new) =
orPotentiometer position (new) =Avg. Core Power % (Step 11.10.3.1)* X Old Potentiometer Setting (Step 11.10.4)Avg. Linear Power % (Step 11.10.4)
X* Use theAverage value from the table of step 11.10.3.1, not the Adjusted value.Potentiometer position (new) = ________________Performed by:
IV by: (Initials)(Initials)11.10.6.1Calculate KCAL (new):KCAL (new)=(Step 11.10.3.1)* (step 11.10.4)  (step 11.10.4)Avg. Core Power (%)
xKCAL x TCORFAvg. PHICAL(step 11.10.3.1)* AnAdjusted value may be required. Refer to Note preceding step 11.10.6.KCAL (new)=x xKCAL (new)=KCAL (new) =(CPC PID 065)11.10.6.3New TCREF (CPC PID 098) = Minimum TC from step 11.10.4:TC 1 (CPC PID 160) or  TC 2 (CPC PID 161).TCREF (new) =(CPC PID 098)Performed by:
IV by: (Initials)(Initials)
OP-903-001  Revision 061Attachment 11.18 (3 of 3) 14911.18 ADJUSTMENT OFCPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONT'D)11.10.7 Calculate TPC (CPC PID 064):TPC (new)=Avg. Core Power % (Step 11.10.3.1)* XTPC (Step 11.10.4)Avg. BDT (Step 11.10.3.1)* AnAdjusted value may be required. Refer to Note preceding step 11.10.7.TPC (new)=
XTPC (new) =(CPC PID 064).Performed by:
IV by: (Initials)(Initials)11.10.11.1 Record the following: Applicable CORE POWER PMC .................................... ___________ PCALIB CPC PID 104  .............................................. ___________ HI LINEAR POWER BISTABLE 1 VOLTS ..................... ___________ HI LINEAR POWER % VOLTS x 20 .............................. ___________ PHICAL CPC PID 171  .............................................. ___________ BDT CPC PID 177 .............................................. ___________11.10.11.2.1Record answers: HI LINEAR POWER %, VOLTS X 20 .................... YES/NO ________ PHICAL, CPC PID 171  ..................................... YES/NO ________ BDT, CPC PID 177 ..................................... YES/NO ________11.10.12 Performed by:
IV by: (Initials)(Initials)11.10.13  Reviewed by:_________________________  _________________
SM/CRSDate/Time Waterford 3 2015 NRC SRO Exam JOB PERFORMANCE MEASURE A7  Review of Containment Pressure Calculation Applicant:
Examiner:
 
JPM A7  Revision 0 Page 2 of 7 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Review of Containment pressure calculation Task Standard: Applicant reviewed a calculation for containment pressure in accordance with OP-903-001, Technical Specification Surveillance Logs. The results conform to the answer key. The applicant identified that Tech Spec 3.6.1.4 entry is required and identified the applicable Tech Spec action.
 
==References:==
OP-903-001, Technical Specification Surveillance Logs Technical Specification 3.6.1.4 Alternate Path:
No Time Critical: No Validation Time: 15 mins. K/A 2.2.12 Knowledge of Surveillance    Importance Rating
 
===4.1 procedures===
 
SRO        Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM A7  Revision 0 Page 3 of 7 2015 NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-903-001, Technical Specification Surveillance Logs  Copy of Attachment 11.15, Containment Pressure Calculation (performed by the ATC)  Calculator
 
== Description:==
 
This JPM requires the applicant to verify a containment pressure calculation performed by the ATC.
READ TO APPLICANT DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
  (Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM A7  Revision 0 Page 4 of 7 2015 NRC Exam TASK ELEMENT 1 STANDARD 11.15.1 Barometric Pressure as measured by PMC (PID C48516). If local reading used, then add 0.05 INHG to obtain a value equivalent to Met Tower PMC point.                        BP=___________ INHG    11.15.1.2 Record M&TE data on TS Logs Remarks and WR, if    applicable  Verified 29.44 entered. Comment: Applicant should not add .05 INHG because the PMC is operable. If he adds .05 INHG, the final value of this calculation will be greater than the TS limit.
SAT  /  UNSAT TASK ELEMENT 2 STANDARD 11.15.2 Containment to Ambient Differential Pressure              (PMC PID-A51000)              C/A=____________ INWC Verified -5.4 entered Comment: Value is from initial conditions SAT  /  UNSAT TASK ELEMENT 3 STANDARD 11.15.3 Convert Barometric Pressure (BP) from INHG to PSIA by performing the following:                BP(PSIA) = [BP(INHG) x 0.4912 PSIA/INHG]                BP(PSIA) = [______________ INHG x 0.4912 PSIA/INHG]                BP(PSIA) = _______________ PSIA Verified BP (PSIA) in the range of 14.46 to 14.461. Comment: 14.46 is rounded from 14.460928.
SAT  /  UNSAT TASK ELEMENT 4 STANDARD 11.15.4 Convert Containment to Ambient Differential pressure (C/A) from INWC to PSIA by performing the following:                C/A(PSIA) = [CA(INWC) x 0.0361 PSIA/INWC]                C/A(PSIA) = [______________ INWC x 0.0361 PSIA/INWC]                C/A(PSIA) = _______________ PSIA Recognize the wrong number inserted Comment: -.195 is rounded from -.19494. The applicant should indentify that a positive number has been inserted and calculated for this step. The number is correct but the value should be negative. If this error is not identified, the final value of this calculation will be within TS limits. Critical SAT  /  UNSAT
 
JPM A7  Revision 0 Page 5 of 7 2015 NRC Exam TASK ELEMENT 5 STANDARD 11.15.5 Calculate Absolute Containment Internal Pressure (CP) by performing the following:                CP(PSIA) = BP(PSIA) + C/A(PSIA)                CP(PSIA) = ______________ PSIA + _______________ PSIA                CP(PSIA) = _______________ PSIA Recognized the error carried forward from the previous step. Corrected value should be 14.265 (14.26-14.27) Comment: CP(PSIA) should be 14.265 when corrected. This number is below the minimum TS limit. Critical SAT  /  UNSAT TASK ELEMENT 6 STANDARD The applicant should identify the corrected value is less than the Technical Specification 3.6.14 limit for containment pressure (14.275 PSIA) and the actions for Technical Specification 3.6.1.4 are required. Identified corrected value is less than 14.275 PSIA. Identified TS 3.6.1.4 entry and the correct action required. Comment: The action for TS 3.6.1.4 is to restore the internal pressure to within the limits within 1 hour or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. Note: If applicant does not provide the action for TS 3.6.1.4, ask what the action is. Critical SAT  /  UNSAT END OF TASK
 
JPM A7  Revision 0 Page 6 of 7 2015 NRC Exam SIMULATOR OPERATOR INSTRUCTIONS None.
JPM A7  Revision 0 Page 7 of 7 2015 NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The plant is at 100% power. Containment pressure reduction was secured during the previous shift. Containment Pressure is -5.4 INWC (PMC Point A51000). Barometric Pressure reading is 29.44 INHG as indicated on the PMC (Point C48516). INITIATING CUE:
Verify the containment pressure calculation performed by the ATC using OP-903-001, Technical Specification Surveillance Logs and identify any TS actions required, if any.
 
A7 KEY OP-903-001  Revision 061 Attachment 11.15 (1 of 1) 144 11.15 CONTAINMENT PRESSURE CALCULATION 11.15.1 Barometric Pressure as measured by PMC (PID C48516).
If local reading used, then add 0.05 INHG to obtain a  value equivalent to Met Tower PMC point. BP = ______29.44 INHG 11.15.1.2 Record M&TE data on TS Logs Remarks and WR, if applicable. 11.15.2 Containment to Ambient Differential Pressure (PMC PID-A51000 or CAPIDPI5171 if PID is bad)      C/A = ____-5.4___ INWC 11.15.3 Convert Barometric Pressure (BP) from INHG to PSIA by performing the following:
BP(PSIA) = [BP (INHG) X 0.4912 PSIA/INHG]
BP(PSIA) = [ ______29.44_______ INHG X 0.4912 PSIA/INHG]
BP(PSIA) =  ____14.46_________ PSIA 11.15.4 Convert Containment to Ambient Differential Pressure (C/A) from INWC to PSIA by performing the following:
C/A(PSIA) = [C/A (INWC) X 0.0361 PSIA/INWC]
C/A(PSIA) = [ __5.4_____(-5.4)_____ INWC X 0.0361 PSIA/INWC]
C/A(PSIA) =  __
.195_____(-.195)____ PSIA 11.15.5 Calculate Absolute Containment Internal Pressure (CP) by performing the following:
CP(PSIA) = BP(PSIA) + C/A(PSIA)
CP(PSIA) = ________14.46_______ PSIA + _
.195_(-.195)___ PSIA  CP(PSIA) = __14.655
__(14.265)__ PSIA 11.15.6 Attach this Attachment to Attachment 11.1, Mode 1-4 Technical Specification Surveillance Log.
A7 Student OP-903-001  Revision 061 Attachment 11.15 (1 of 1) 144 11.15 CONTAINMENT PRESSURE CALCULATION 11.15.1 Barometric Pressure as measured by PMC (PID C48516).
If local reading used, then add 0.05 INHG to obtain a  value equivalent to Met Tower PMC point. BP = ___29.44__
INHG 11.15.1.2 Record M&TE data on TS Logs Remarks and WR, if applicable. 11.15.2 Containment to Ambient Differential Pressure (PMC PID-A51000 or CAPIDPI5171 if PID is bad)  C/A = ____-5.4___ INWC 11.15.3 Convert Barometric Pressure (BP) from INHG to PSIA by performing the following:
BP(PSIA) = [BP (INHG) X 0.4912 PSIA/INHG]
BP(PSIA) = [ ______29.44_______ INHG X 0.4912 PSIA/INHG]
BP(PSIA) =  ____14.46_________ PSIA 11.15.4 Convert Containment to Ambient Differential Pressure (C/A) from INWC to PSIA by performing the following:
C/A(PSIA) = [C/A (INWC) X 0.0361 PSIA/INWC]
C/A(PSIA) = [ _______5.4_______ INWC X 0.0361 PSIA/INWC]
C/A(PSIA) =  _____0.195____ PSIA 11.15.5 Calculate Absolute Containment Internal Pressure (CP) by performing the following:
CP(PSIA) = BP(PSIA) + C/A(PSIA)
CP(PSIA) = ________14.46_______ PSIA + ______0.195___ PSIA  CP(PSIA) = _________14.655___ PSIA 11.15.6 Attach this Attachment to Attachment 11.1, Mode 1-4 Technical Specification Surveillance Log. 
 
O P-9 0 3-0 0 1 R e v i s i o n 0 6 1 A t t a c h m e n t 1 1.1 (1 o f 3 7)2 2 1 1.1 M O D E S 1-4 T E C H N I C A L S P E C I F I C A T I O N S U R V E I L L A N C E L O G S D A T E D E S C R I P T I O N N O T E M O D E T.S.C O M P#L I M I T U N I T S 0 0 0 0 1 2 0 0 W e t T o w e r A&B F a n s 1-4 4 5.0 C P-3 3 A U T O o r O F F A U T O , O F F , N A W e t T o w e r A&B F a n s 5-8 4 5.0 C P-3 3 A U T O o r O F F A U T O , O F F , N A C N T M T I n t e r n a l P r e s s: 1-4 4.6.1.4 A 5 1 0 0 0/C P-1 8 C a l c u l a t e d C N T M T P r e s s 2 6.1 S t e p 1 1.1 5.5>1 4.2 7 5 P S I A S/D M a r g i n V e r i f i c a t i o n 2*, 3-4 R C S T e m p 5 3 9 F 1.0 4.1.1.1.1.c 4.1.1.1.1.e 4.1.1.2 O P-9 0 3-0 9 0 o r O P-0 0 4-0 1 9 S e e A p p l i c a b l e P r o c e d u r e R C S T e m p<5 3 9 F 1.1 4.1.1.2 O P-9 0 3-0 9 0 C O L R L i m i t D E S C R I P T I O N N O T E M O D E T.S.C O M P#L I M I T U n i t s S E T P O I N T C N T M T L i q u i d L e a k R a t e 1 6.0 1-4 4.4.5.1.b S P-I F R-6 7 1 0 1 b e l o w s e t p o i n t G P M R E M A R K S:*M o d e 2 w i t h t h e R e a c t o r n o t C r i t i c a l.
OP-903-001  Revision 061Attachment 11.1 (27 of 37) 4820.0 Individual CEA positions can be obtained by one of the following methods:(NA if not in Mode 1 or 2) PMC hard copy printout Attachment 11.8, Technical Specification Addendum Logsheet Satisfactory indication of CEA positions via the Excel spreadsheet (Att. 11.20)If one of the above methods is not available, then record all CEA positions from allthree indicating channels on Attachment 11.5, CEA Positions.21.0 In Modes 1 and 2, two of the three CEA position indicator channels are required to beOperable. Verify all CEA Position Indicator channels are Operable by verifying that forthe same CEA, the position indicator channels agree within 5 inches of each other.Position Indicator channels are the RSPT #1 and #2 (CEACs) and the CEA PulseCounting position indicator channel (PMC). NA if not in Mode 1 or 2.22.0 N/A if not in Modes 1 or 2. Verify the position of each CEA within 7 inches (indicatedposition) of all CEAs in its group. If either or both CEACs are Inoperable then verifyindividual CEA positions at least once per 4 Hours. If both CEACs are Inoperable,then comply with T.S. 3.2.4.b or T.S. 3.2.4.d.23.0 N/A if not in Modes 1 or 2. Verify each S/D CEA is withdrawn to 145 inches.24.0 N/A if not in Modes 1 or 2. Verify CEA Group P withdrawal within the TransientInsertion Limits of the COLR when in Mode 1, or Mode 2 with Keff  once per 8 hours,or with PDIL alarm Inoperable once per 4 hours. Per the COLR, Group P CEAposition is unrestricted at <20% power. If withdrawn between the Long Term SteadyState and Transient Insertion Limits, then document per Attachment 11.7, RegulatingGroup and Group P Insertion Limits.[TS 3.1.3.6]25.0 N/A if not in Modes 1 or 2. Verify CEA group withdrawal within the Transient InsertionLimits of the COLR when in Mode 1, or Mode 2 with Keff 1 once per 8 hours, or withPDIL alarm Inoperable once per 4 hours. In Mode 2 with Keff < 1, verify EstimatedCritical Position is within the limits of the COLR within 4 hours prior to achievingReactor Criticality. If withdrawn between the Long Term Steady State and TransientInsertion Limits, then document per Attachment 11.7, Regulating Group and Group P CEA Insertion Limits.[TS 3.1.3.6]26.0 Verify Containment Pressure within limits of 0 to24.2 INWC by PMC PID A51000 or 0 to23.2 INWC by CP-18 indication in Modes 1-4. If Containment to AmbientDifferential Pressure is < 0 INWC, then refer to Note 26.1 and N/A this reading.26.1 Perform Attachment 11.15, Containment Pressure Calculation.  (NA if Containment toAmbient Differential Pressure is 0 INWC.)27.0 Verify Containment Purge Isolation Valves Open <90 Hours in the previous 365 Days,while in Modes 1-4.
OP-903-001  Revision 061Attachment 11.15 (1 of 1) 14411.15 CONTAINMENT PRESSURE CALCULATION11.15.1 Barometric Pressure as measured by PMC (PID C48516).If local reading used, then add 0.05 INHG to obtain avalue equivalent to Met Tower PMC point.BP = ____________ INHG11.15.1.2 Record M&TE data on TS Logs Remarks and WR, if applicable.11.15.2 Containment to Ambient Differential Pressure(PMC PID-A51000 or CAPIDPI5171 if PID is bad).C/A = __________INWC11.15.3 Convert Barometric Pressure (BP) from INHG to PSIAby performing the following: BP(PSIA) = [BP (INHG) X 0.4912 PSIA/INHG] BP(PSIA) = [ __________________ INHG X 0.4912 PSIA/INHG] BP(PSIA) =__________________ PSIA11.15.4 Convert Containment to Ambient Differential Pressure (C/A) from INWC to PSIAby performing the following: C/A(PSIA) = [C/A (INWC) X 0.0361 PSIA/INWC] C/A(PSIA) = [ __________________ INWC X 0.0361 PSIA/INWC] C/A(PSIA) =__________________ PSIA11.15.5 Calculate Absolute Containment Internal Pressure (CP) by performing thefollowing: CP(PSIA) = BP(PSIA) + C/A(PSIA) CP(PSIA) = ____________________ PSIA + ___________________ PSIA CP(PSIA) = ____________________ PSIA11.15.6 Attach this Attachment to Attachment 11.1, Mode 1-4 Technical SpecificationSurveillance Log.
 
Waterford 3 2015 NRC SRO Exam JOB PERFORMANCE MEASURE A8  Authorize Emergency Exposure as the Emergency Coordinator Applicant:
Examiner:
 
JPM A8 Revision 0 Page 2 of 6 2015 NRC SRO Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Authorize Emergency Exposure as the Emergency Director Task Standard: Correctly determined that authorization is not appropriate
 
==References:==
EP-002-030, Emergency Radiation Exposure Guidelines and Controls, Rev 10 Alternate Path:
No Time Critical: No Validation Time: 10 mins. K/A 2.3.4, Knowledge of radiation exposure limits Importance Rating 3.7 under normal or emergency conditions.
SRO        Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM A8 Revision 0 Page 3 of 6 2015 NRC SRO Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
EP-002-030, Emergency Radiation Exposure Guidelines and Controls
 
== Description:==
 
The applicant will review a situation where an event is in progress where a ruptured pipe is required to be isolated and there is a high dose rate present. The applicant should determine based on the given information and the requirements in EP-002-030, Emergency Radiation Exposure Guidelines and Controls that the task would result in exceeding established limits and not authorize the task.
READ TO APPLICANT DIRECTION TO APPLICANT:
Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
  (Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM A8 Revision 0 Page 4 of 6 2015 NRC SRO Exam TASK ELEMENT STANDARD Emergency Director reviews EP-002-030, Emergency Exposure Guidelines & Controls, and authorizes emergency exposure if criteria is met. Candidate determines that emergency exposure limit of 10 REM TEDE would be exceeded (actual calculation would be 13.5 REM TEDE) and does not authorize emergency exposure. Comment:  EXAMINER NOTE:  Candidate may state that he could authorize Emergency Exposure if the job could be split between two personnel.
Critical SAT  /  UNSAT END OF TASK
 
JPM A8 Revision 0 Page 5 of 6 2015 NRC SRO Exam SIMULATOR OPERATOR INSTRUCTIONS None.
JPM A8 Revision 0 Page 6 of 6 2015 NRC SRO Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
A ruptured pipe must be isolated in a high radiation area with dose rates of 18 REM/Hour. The job will take 45 minutes. The only available person to do this task is Joe Operator, SSN # 123-12-4567, Badge # 0303, with Operations. Radiation Protection has reported that they can take no action to reduce the dose rate. You are the Emergency Coordinator  This is for Accident mitigation purposes and there are currently NO life saving activities occurring.
INITIATING CUE:
Evaluate authorizing Emergency Exposure as Emergency Director.
Document all work and results on this sheet.
 
Waterford 3 2015 NRC Exam JOB PERFORMANCE MEASURE A9  Classify an Emergency Event Applicant:
Examiner:
 
JPM A9  Revision 0 Page 2 of 7 2015 SRO NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Classify an Emergency event Task Standard: Event classified correctly and declared within 15 minutes of JPM start. 
 
==References:==
EP-001-001, Recognition and Classification of Emergency Conditions Rev 30 Alternate Path:
No Time Critical: Yes Validation Time: 10 mins. K/A 2.4.41, Knowledge of the emergency action  Importance Rating
 
===4.6 level===
thresholds and classifications SRO        Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
15 minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM A9  Revision 0 Page 3 of 7 2015 SRO NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
EP-001-001, Recognition and Classification of Emergency Conditions
 
== Description:==
 
This JPM requires the applicant to determine the emergency action level from the initial conditions within 15 minutes IAW EP-001-001. The Declaration/Initiating Condition will be FA1 "ANY loss or ANY potential loss of EITHER fuel clad or RCS". The appropriate EAL can be either RCB2 or RCB3. The JPM will be performed in the classroom using given data obtained from the Initial Conditions.
READ TO APPLICANT DIRECTION TO APPLICANT:
This is a Time Critical Task Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.
Provide all answers on the sheets provided.
  (Read the Initial Condition and Cues from the colored Applicant cue Sheet, and then give the cue sheet and a copy of EP-001-001 to applicant)
 
JPM A9  Revision 0 Page 4 of 7 2015 SRO NRC Exam EXAMINER NOTE This JPM will be performed in the classroom using data obtained from the cue sheet provided. Ensure that the applicant turns in all paperwork prior to releasing.
Time Start:
TASK ELEMENT 1 STANDARD 5.2 Classification 5.2.1 Verify the off-normal event to ensure that the event is real. Determined Event is Real by initial conditions Comment:  SAT  /  UNSAT TASK ELEMENT 2 STANDARD 5.2.2 Match the off-normal event with one of the following six emergency categories: 5.2.2.1 Abnormal Radiation Levels/Radiological Effluents TAB A 5.2.2.2 Cold Shutdown/Refueling System Malfunction TAB C 5.2.2.3 ISFSI Malfunction TAB E 5.2.2.4 Fission Product Barrier Degradation TAB F 5.2.2.5 Hazards and Other Conditions Affecting Plant Safety TAB H 5.2.2.6 System Malfunction TAB S Determined Tab F is applicable Comment:  SAT  /  UNSAT TASK ELEMENT 3 STANDARD 5.2.3 Refer to Attachment 7.1 Emergency Categories, under the category TAB selected in step 5.2.2 above; match the off-normal condition with the appropriate IC to determine the emergency classification. Determined RCS Barrier Loss/Potential loss (FA1)
Critical SAT  /  UNSAT
 
JPM A9  Revision 0 Page 5 of 7 2015 SRO NRC Exam TASK ELEMENT 4 STANDARD 5.2.4 If an event or condition existed which met or exceeded an IC but no emergency was declared the basis for the emergency classification no longer exists at the time of the discovery (rapidly concluded event, missed classification or misclassified event), then do not classify the emergency or make offsite notifications. 5.2.4.1 Notify the NRC within one hour of the discovery of the undeclared or misclassified event in accordance with UNT-006-010. Determined step is N/A Comment:  SAT  /  UNSAT TASK ELEMENT 5 STANDARD Procedure Note: The effects of combinations of initiating conditions that individually constitute a lower classification may be considered as a possibly higher emergency classification. Note reviewed Comment:  SAT  /  UNSAT TASK ELEMENT 6 STANDARD 5.2.5 Declare the highest emergency classification for which an IC has been met or exceeded Declared Alert based on FA1; EAL RCB3 or RCB2 within 15 minutes of JPM start Comment:  Time Complete:
Examiner Note: TIME CRITICAL STEP Critical SAT  /  UNSAT END OF TASK
 
JPM A9  Revision 0 Page 6 of 7 2015 SRO NRC Exam SIMULATOR OPERATOR INSTRUCTIONS None.
JPM A9  Revision 0 Page 7 of 7 2015 SRO NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
Plant was operating at 100% when a Steam Generator Tube Rupture occurred. Plant conditions:
o Steam Generator Tube leakage is 180 gpm o RCS Pressure = 1200 PSIA and dropping o The Condenser Exhaust WRGM reached a release rate of 4 E+2 Ci/sec for 10 minutes and now is trending down.
o The only manual actions taken by the crew was tripping the reactor.
INITIATING CUES:
You are directed to classify and declare this event in accordance with EP-001-001, Recognition and Classification of Emergency Conditions  This is a time critical task  Write your Declaration (include Emergency Classification, Initiating Condition and Emergency Action Level(s) ) on this sheet Declaration ____________________________________________________
 
Waterford 3 2015 NRC RO/SRO Exam JOB PERFORMANCE MEASURE S1  ATC Immediate Operator Actions on 2 Dropped CEAs      Applicant:
Examiner:
 
JPM S1  Revision 0 Page 2 of 7 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: ATC Immediate Operator Actions on 2 Dropped CEAs Task Standard: Applicant tripped the reactor using 32 A and 32 B breakers in accordance with OP-902-000, 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:
2 mins. K/A 001 A2.13, ATWS  Importance Rating 4.4 / 4.6 RO / SRO  Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM S1  Revision 0 Page 3 of 7 2015 NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
None
 
== Description:==
Applicant will position himself as the ATC operator at CP-2. CEAs 79 and 86 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 buttons 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 Bus 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 the 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 actions when directed by you. Indicate to me when you understand your assigned task.
(Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM S1  Revision 0 Page 4 of 7 2015 NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The plant is at 100% power.
INITIATING CUES:
Respond to conditions observed. Perform actions as required by the ATC operator.
 
JPM S1  Revision 0 Page 5 of 7 2015 NRC 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 OP-901-102 D.1. If in Mode 1 and two or more Control Element Assemblies drop or are misaligned by > 19 inches, then manually trip the Reactor and go to OP-902-00, Standard Post Trip Actions. Pushes both reactor trip pushbuttons on CP-2 or CP-8. Comment: Trip pushbuttons are faulted and Reactor Trip Circuit Breakers will not open. Applicant determines 2 CEAs have dropped, attempts to trip the reactor from CP-2 or CP-8 Critical SAT  /  UNSAT TASK ELEMENT 2 STANDARD OP-902-000 1.a.1.2  Manually initiate DIVERSE REACTOR TRIP. Pushes both DRTS pushbuttons on CP-2. Comment: One DRTS pushbutton is faulted and CEA MG set load contactors will not open. Critical SAT  /  UNSAT TASK ELEMENT 3 STANDARD OP-902-000 1.a.1.3  Open BOTH the following breakers for 5 seconds and close: A32 FEEDER B32 FEEDER Opens SST A32 FEEDER and SST B32 FEEDER breakers for 5 seconds and then re-closes both breakers. Comment: Evaluator:  If applicant stops after re-closing the A and B 32 Feeder breakers, prompt him as the CRS to perform his Standard Post Trip Actions. Critical SAT  /  UNSAT
 
JPM S1  Revision 0 Page 6 of 7 2015 NRC 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: Evaluator:  Notify the applicant that the JPM is complete after the Reactivity Control Acceptance criteria is complete.
SAT  /  UNSAT END OF TASK
 
JPM S1  Revision 0 Page 7 of 7 2015 NRC Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-164 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 o M_K04  Fail off Trigger 1:
o RD02A79, dropped CEA 79 o RD02A86, dropped CEA 86 Verify the following Overrides:  No Trigger o DI-02A06S02-1, DRT pushbutton 1 of 2 to "OFF" Coordinate with examiner to initiate Trigger 1 on his cue.
 
Off Normal ProcedureOP-901-102CEA or CEDMCS MalfunctionRevision 302 8 DIMMEDIATE OPERATOR ACTIONS 1.If in Mode 1 and two or more Control Element Assemblies drop or aremisaligned by >19 inches, then manually trip the Reactor and go toOP-902-000, Standard Post Trip Actions.
STANDARD POST TRIP ACTIONSOP-902-000Revision15 Page 5 of 15WATERFORD 3 SES4.0INSTRUCTIONS/CONTINGENCY ACTIONSINSTRUCTIONSCONTINGENCY ACTIONSVerify Reactivity Control___1.Determine Reactivity Controlacceptance criteria are met:___a.Check reactor power is dropping.___b.Check startup rate is negative.___c.Check less than TWO CEAs are NOT fully inserted.a.1Perform the following asnecessary to insert CEAs:1)Manually trip the reactor.2)Manually initiate DIVERSE REACTOR TRIP.3)OpenBOTH the followingbreakers for 5 seconds and close:SST A32 FEEDERSST B32 FEEDERc.1Commence emergency boration.
Waterford 3 2015 NRC RO Exam JOB PERFORMANCE MEASURE S2  Charging to the RCS via the HPSI Header Applicant:
Examiner:
 
JPM S2  Revision 1 Page 2 of 8 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: ATC aligns Charging to HPSI Header A Task Standard: Applicant establishes charging flow to HPSI header A in accordance with OP-901-112, Charging or Letdown Malfunction
 
==References:==
OP-901-112, Charging or Letdown Malfunction, revision 6 Alternate Path:
No Time Critical:
No Validation Time:
9 mins. K/A 004 A4.08, Charging  Importance Rating 3.8 / 3.4 RO / SRO  Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM S2  Revision 1 Page 3 of 8 2015 NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-901-112, Charging or Letdown Malfunction
 
== Description:==
This task is performed at CP-8 and CP-4. The operator aligns charging flow to High Pressure Safety Injection (HPSI) Header A due to a rupture of the charging line inside containment. The operator will perform step 6 of section E1 (Charging Malfunction) of OP-901-112, Charging or Letdown Malfunction.
This JPM is to be performed concurrently with JPM S8.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state the 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 actions when directed by you. Indicate to me when you understand your assigned task.
(Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM S2  Revision 0 Page 4 of 8 2015 NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The plant is in Mode 3  The normal charging path is not available due to a break downstream of CVC-209. The crew is responding in accordance with OP-901-112, Charging or Letdown Malfunction. Letdown Stop Valve (CVC-101) is closed and all Charging Pumps are in OFF in accordance with Section E1, step 5, Charging or Letdown Malfunction. Tech Spec implications for this event have already been addressed.
INITIATING CUES:
The CRS has directed you to align Charging to the RCS via the HPSI Header in accordance with OP-901-112, Charging or Letdown Malfunction, sect. E1 step 6. Once Charging is aligned to the HPSI Header, you are directed to maintain pressurizer level 33%-35%.
 
JPM S2  Revision 0 Page 5 of 8 2015 NRC Exam Evaluator Note 1. Cue the Simulator Operator to place the Simulator in RUN.
TASK ELEMENT 1 STANDARD Procedure Caution:
IF HPSI PUMPS ARE OPERATING, THEN CHARGING PUMPS SHOULD NOT BE ALIGNED TO HPSI HEADER. Caution reviewed and HPSI pumps are verified to be not operating. Comment:    SAT  /  UNSAT TASK ELEMENT 2 STANDARD Procedure Note: Aligning Charging to HPSI Train A renders HPSI train A INOPERABLE and Charging Pumps INOPERABLE. Enter TS 3.5.2 and 3.1.2.4. Refer to TS 3.5.3. Note reviewed. Comment: Examiner Note: Initial conditions states that TS have already been addressed.
SAT  /  UNSAT
: 6. IF flow can NOT be established through the normal Charging Pump discharge path, THEN align Charging Pumps to discharge through HPSI Header A as follows:
TASK ELEMENT 3 STANDARD 6.1 Locally open CHARGING HEADER XCONN TO HPSI HEADER A ISOLATION (SI 504)  (-35 Wing Area, Col. 6A & L). Directs NAO to open SI-504. Comment: Examiner Note: Cue the booth operator to initiate trigger 2 to open SI-504 Examiner Cue: Inform the applicant that SI-504, Charging Header Xconn to HPSI Header A Isolation, has been opened.
Critical SAT  /  UNSAT
 
JPM S2  Revision 0 Page 6 of 8 2015 NRC Exam TASK ELEMENT 4 STANDARD 6.2 Open ONE of the following Train A HPSI COLD LEG INJECTION valves:  1A (SI 225A)  1B (SI 226A)  2A (SI 227A)  2B (SI 228A)
Applicant opens one of the listed Train A HPSI Cold Leg Injection valves. Comment:    Critical SAT  /  UNSAT TASK ELEMENT 5 STANDARD 6.3 Locally open CHARGING PUMPS DISCHARGE TO HPSI ISOLATION (CVC 199)  (Charging Pump Room A). Directs the NAO to open CVC-199 Comment: Examiner Note: Cue the booth operator to initiate trigger 3 to close CVC-199. Examiner Cue: Inform the applicant that CHARGING PUMPS DISCHARGE TO HPSI ISOLATION (CVC 199) is closed.
Critical SAT  /  UNSAT TASK ELEMENT 6 STANDARD Procedure Note: Charging Header flow will not indicate with CHARGING PUMPS HEADER ISOLATION VALVE (CVC 209) closed. Reviewed note Comment:    SAT  /  UNSAT TASK ELEMENT 7 STANDARD 6.4 Close Charging Pumps Header Isolation Valve (CVC 209). Applicant closes CVC 209. Comment:    Critical SAT  /  UNSAT
 
JPM S2  Revision 0 Page 7 of 8 2015 NRC Exam TASK ELEMENT 8 STANDARD 6.5 Operate Charging Pumps as necessary to maintain Pressurizer level within the limits of Attachment 1, Pressurizer Level Versus Tave Curve. Applicant starts at least one Charging Pump Comment: Examiner Note: The applicant may ask the CRS if he desires the seal package running before starting the Charging Pump. Inform the applicant it is not required to start the seal package. Examiner Note: Loop 1A, 1B, 2A or 2B INJ LINE CHECK VLV LEAKAGE on Cabinet M or Cabinet N is an expected alarm depending on which HPSI FCV was opened. Examiner Note: The JPM is complete when at least one Charging Pump has been started. If applicant asks which Charging pump should be started, inform applicant to start Charging pump B.
Critical SAT  /  UNSAT END OF TASK
 
JPM S2  Revision 0 Page 8 of 8 2015 NRC Exam SIMULATOR OPERATOR INSTRUCTIONS
: 1. Reset to IC-165 2. For 2015 NRC Exam, JPM S8 is performed concurrently. 3. Verify the following Malfunction: a. CV16 10% severity inserted (active) 4. Verify the following Overrides: b. None 5. Verify the following Remotes c. SIR05 for SI-504 on event Trigger 2 d. CVR 27 for CVC-199 on event Trigger 3 Setup with specific IC unavailable or for non NRC/AUDIT exams:
: 1. Reset the simulator to an IC in Mode 3 2. Insert malfunction CV16 with a 10% severity 3. Place all Charging pumps in OFF and close CVC-101 4. Allow simulator to run until all conditions stabilize 5. Acknowledge annunciators 6. Place simulator in freeze and save IC
 
Off Normal Procedure OP-901-112 Charging or Letdown Malfunction Revision 006 E 1 CHARGING MALFUNCTION (CONT'D) 11  CAUTION IF HPSI PUMPS ARE OPERATING, THEN CHARGING PUMPS SHOULD NOT BE ALIGNED TO HPSI HEADER.
NOTE Aligning Charging to HPSI Train A renders HPSI train A INOPERABLE and Charging Pumps INOPERABLE. Enter TS 3.5.2 and 3.1.2.4. Refer to TS 3.5.3.
PLACEKEEPER START DONE N/A 6. IF flow can NOT be established through the normal Charging Pump discharge path, THEN align Charging Pumps to discharge through HPSI Header A as follows:
 
===6.1 Locally===
open CHARGING HEADER XCONN TO HPSI HEADER A ISOLATION (SI 504)  (-35 Wing Area, Col. 6A & L).
6.2 Open ONE of the following Train A HPSI COLD LEG INJECTION valves:  1A (SI 225A)  1B (SI 226A)  2A (SI 227A)  2B (SI 228A)
 
===6.3 Locally===
open CHARGING PUMPS DISCHARGE TO HPSI ISOLATION (CVC 199)  (Charging Pump Room A).
 
Off Normal Procedure OP-901-112 Charging or Letdown Malfunction Revision 006 E 1 CHARGING MALFUNCTION (CONT'D) 12  PLACEKEEPER START DONE N/A  NOTE Charging Header flow will not indicate with CHARGING PUMPS HEADER ISOLATION VALVE (CVC 209) closed.
 
===6.4 Close===
Charging Pumps Header Isolation Valve (CVC 209).
 
===6.5 Operate===
Charging Pumps as necessary to maintain Pressurizer level within the limits of Attachment 1, Pressurizer Level Versus Tave Curve.
: 7. WHEN repairs have been completed to the Charging Header, THEN restore Charging Pumps discharge alignment to normal as follows:
7.1 Stop ALL Charging Pumps.
 
===7.2 Restore===
HPSI Header as follows:
 
====7.2.1 Locally====
close CHARGING HEADER XCONN TO HPSI HEADER A ISOLATION  (SI 504) (-35 Wing Area, Col. 6A & L).
 
====7.2.2 Verify====
closed the following Train A HPSI COLD LEG INJECTION valves:  1A (SI 225A)  1B (SI 226A)  2A (SI 227A)  2B (SI 228A)
 
====7.2.3 Locally====
close CHARGING PUMP DISCHARGE TO HPSI ISOLATION  (CVC 199) (Charging Pump Room A).
 
Off Normal ProcedureOP-901-112Charging or Letdown MalfunctionRevision 006 E 1 CHARGING MALFUNCTION (CONT'D)11CAUTIONIF HPSI PUMPS ARE OPERATING, THEN CHARGING PUMPS SHOULD NOT BEALIGNED TO HPSI HEADER.NOTEAligning Charging to HPSI Train A renders HPSI train A INOPERABLE and Charging PumpsINOPERABLE. Enter TS 3.5.2 and 3.1.2.4. Refer to TS 3.5.3.
PLACEKEEPERSTART DONEN/A6. IF flow can NOT be established through the normalCharging Pump discharge path, THEN align ChargingPumps to discharge through HPSI Header A as follows:6.1 Locally open CHARGING HEADER XCONN TOHPSI HEADER A ISOLATION (SI 504)(-35 Wing Area, Col. 6A & L).6.2 Open ONE of the following Train A HPSI COLDLEG INJECTION valves: 1A (SI 225A) 1B (SI 226A) 2A (SI 227A) 2B (SI 228A)6.3 Locally open CHARGING PUMPS DISCHARGETO HPSI ISOLATION (CVC 199)(Charging Pump Room A).
Off Normal ProcedureOP-901-112Charging or Letdown MalfunctionRevision 006 E 1 CHARGING MALFUNCTION (CONT'D)12 PLACEKEEPERSTART DONEN/ANOTECharging Header flow will not indicate with CHARGING PUMPS HEADER ISOLATIONVALVE (CVC 209) closed.6.4 Close Charging Pumps Header Isolation Valve (CVC 209).6.5 Operate Charging Pumps as necessary to maintainPressurizer level within the limits of Attachment 1,Pressurizer Level Versus Tave Curve.7. WHEN repairs have been completed to the ChargingHeader, THEN restore Charging Pumps dischargealignment to normal as follows:7.1 Stop ALL Charging Pumps.7.2 Restore HPSI Header as follows:7.2.1 Locally close CHARGING HEADER XCONNTO HPSI HEADER A ISOLATION  (SI 504)(-35 Wing Area, Col. 6A & L).7.2.2 Verify closed the following Train A HPSICOLD LEG INJECTION valves: 1A (SI 225A) 1B (SI 226A) 2A (SI 227A) 2B (SI 228A)7.2.3 Locally close CHARGING PUMPDISCHARGE TO HPSI ISOLATION(CVC 199) (Charging Pump Room A).
Waterford 3 2015 NRC RO Exam JOB PERFORMANCE MEASURE S3  Place Shutdown Cooling Train B in Service Applicant:
Examiner:
 
JPM S3  Revision 0 Page 2 of 12 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Place Shutdown Cooling Train B in Service Task Standard: Applicant places Shutdown Cooling Train B in service in accordance with OP-009-005 and secures Low Pressure Safety Injection Pump B after SI-405B fails closed.
 
==References:==
OP-009-005, Shutdown Cooling OP-901-131, Shutdown Cooling Malfunction Alternate Path:
Yes Time Critical:
No Validation Time:
20 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 Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM S3  Revision 0 Page 3 of 12 2015 NRC 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 B in service. The fault in this task is that SI-405B, RC Loop 2 SDC Suction Inside Containment Isol, will fail closed, requiring the applicant to secure Low Pressure Safety Injection Pump B. The task can be stopped after LPSI Pump B is secured.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state the 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 actions when directed by you. Indicate to me when you understand your assigned task.
(Read the Initial Condition and Cues from the colored Applicant Cue Sheet (next page), and then give the cue sheet to the applicant.)
 
JPM S3  Revision 0 Page 4 of 12 2015 NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The plant is in Mode 4  Protected Train is B  RCS temperature is approximately 322 &deg;F  RCS pressure is approximately 370 PSIA  Shutdown Cooling Train A is in service. SDC Train B suction penetration piping has been manually vented in accordance with Attachment 11.7, Manual Venting of SDC Train Suction Penetration Piping. Shutdown Cooling Train B has been placed in Standby in accordance with OP-009-005, Shutdown Cooling, section 5.4.
INITIATING CUE:
The CRS has directed you to place Shutdown Cooling Train B in service in accordance with OP-009-005, section 6.2.
 
JPM S3  Revision 0 Page 5 of 12 2015 NRC Exam TASK ELEMENT 1 STANDARD Procedure Caution: THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY. Caution reviewed. Comment:    SAT  /  UNSAT TASK ELEMENT 2 STANDARD Procedure Note:  (1)The Shutdown Cooling Train placed in service should be on the Protected Train. (2) The SDC loop may be removed from operations for up to one hour per 8-hour period during the performance of Core Alterations in the vicinity of the reactor pressure vessel hot legs, provided no operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the minimum required boron concentration of Technical Specification 3.9.1.
Notes reviewed. Comment: Protected Train is B as given in initial conditions.
SAT  /  UNSAT TASK ELEMENT 3 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 4 STANDARD 6.2.1: Verify Shutdown Cooling Train B has been aligned to Standby condition in accordance with Section 5.4, Alignment of Shutdown Cooling Train B to Standby Condition. Notes Section 5.4 is complete and continues in procedure. Comment: Cue sheet lists this as complete.
SAT  /  UNSAT
 
JPM S3  Revision 0 Page 6 of 12 2015 NRC Exam TASK ELEMENT 5 STANDARD 6.2.2: Verify sufficient number of Dry Cooling Tower Fans running to accept increased heat load on CCW System. Continues in procedure after cue. Comment:
EVALUATOR CUE:  Inform the applicant to leave the Dry Cooling Tower Fans in automatic and allow Auxiliary Component Cooling Water to pick up the heat load.
SAT  /  UNSAT TASK ELEMENT 6 STANDARD Procedure Caution:  (1)CC-963B 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 B. With CC-963B open, flow through Shutdown Cooling Heat Exchanger A will be maintained above 2305 gpm. (2) Shutdown Heat Exchanger B CCW Flow Control, CC-963B, is also required to remain open if LPSI pump B discharge flow control, SI-129B has been forced closed per OP-009-008 following a loss of instrument air. Caution reviewed. Comment:    SAT  /  UNSAT TASK ELEMENT 7 STANDARD 6.2.3: Place Shutdown HX B CCW Flow Control, CC-963B, control switch to Open. CC-963 B control switch taken to the open position. Comment:
Critical SAT  /  UNSAT
 
JPM S3  Revision 0 Page 7 of 12 2015 NRC Exam TASK ELEMENT 8 STANDARD Procedure Caution: (1)  The following Reactor Coolant System limits shall be met for Shutdown Cooling Entry:  RCS temperature limit: < 350 &deg;F  RCS pressure limit: < 392 psia  If Containment harsh environment conditions (>200&deg;F) have been exceeded then RCS pressure limit: <358 Psia (2)  If Containment Spray Header B Isolation, CS-125 B, is open while Shutdown Cooling Train B is operating, then Containment Spray B riser may fill and possibly spray water into Containment, due to leakage past Containment Spray Pump A discharge stop check, CS-117B. Caution reviewed. Comment:    SAT  /  UNSAT TASK ELEMENT 9 STANDARD 6.2.4: To minimize the effect of air introduction to a LPSI pump Verify RC Loop 2 SDC suction piping meets one of the following conditions:  The SDC Train is placed in-service with RCS pressure >
100 PSIA by PMC indication (PIDs A12203, A12204, A12222) or >
110 PSIA by board indication (RC-IPI0103,-0104,-0105,-0106).
or  The SDC Train's suction penetration has been manually vented. Venting should be accomplished through SI-4051B using RCS/Cavity as water source in accordance with Attachment 11.7, Manual Venting of SDC Train Suction Penetration Piping.
or  The SDC Train was previously in-service since the unit has been shutdown. One of the conditions is verified. Cue sheet lists SDC Train B suction penetration has been manually vented in accordance with Attachment 11.7 (satisfies second bullet). Comment:  SAT  /  UNSAT TASK ELEMENT 10 STANDARD 6.2.5: Unlock and Open RC Loop 1 SDC Suction Outside Containment Isol, SI-407B. SI-407 B is open. Comment: Key 142 required.
Critical SAT  /  UNSAT
 
JPM S3  Revision 0 Page 8 of 12 2015 NRC Exam TASK ELEMENT 11 STANDARD 6.2.6: Inform Radiation Protection Department that Shutdown Cooling Train B is being placed in service. Call is made. Comment:
SAT  /  UNSAT TASK ELEMENT 12 STANDARD 6.2.7: Start LPSI Pump B. LPSI Pump B is started. Comment:  Annunciator LPSI Pump B Flow Lost (Cabinet N, F-13) is expected. It will clear when the applicant raises flow > 2900 gpm.
Critical SAT  /  UNSAT TASK ELEMENT 13 STANDARD Procedure Note: If Instrument Air is unavailable, LPSI Pump B Discharge Flow Control, SI-129B, will need to be operated locally per OP-009-008. If the safeguards rooms are inaccessible (post RAS), LPSI Pump B Discharge Flow Control, SI-129B, must be remotely forced closed per OP-009-008. In this case, SDC flow/temperature will need to be controlled using Shutdown Cooling HX B Temperature Control, SI-415B. Note reviewed. Comment:
SAT  /  UNSAT TASK ELEMENT 14 STANDARD 6.2.8: Raise Shutdown Cooling flow by Manually adjusting LPSI Header Flow controller 1A/1B, SI-IFIC-0306, output until Shutdown Cooling Header B Flow indicates 4100 GPM, as indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1. Flow is raised to ~ 4100 GPM. Comment:
Critical SAT  /  UNSAT
 
JPM S3  Revision 0 Page 9 of 12 2015 NRC Exam TASK ELEMENT 15 STANDARD 6.2.9: Adjust LPSI Header Flow Controller 1A/1B, SI-IFIC-0306, setpoint potentiometer to 73%, and place controller to AUTO. Setpoint potentiometer is ~ 73%, and controller is in AUTO Comment:
Critical SAT  /  UNSAT TASK ELEMENT 16 STANDARD 6.2.10: Verify LPSI Header Flow Controller 1A/1B, SI-IFIC-0306, is maintaining 4100 GPM Shutdown Cooling Header A flow, as indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1. Flow is verified. Comment:
SAT  /  UNSAT TASK ELEMENT 17 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 18 STANDARD 6.2.11: At SM/CRS discretion, direct Chemistry Department to sample Shutdown Cooling Train B for boron concentration.
None Comment:
EVALUATOR CUE:  When requested provide information to applicant that all required Chemistry requirements are met.
SAT  /  UNSAT
 
JPM S3  Revision 0 Page 10 of 12 2015 NRC Exam TASK ELEMENT 19 STANDARD Procedure Note: Shutdown Cooling Train B requires one operable Low Pressure Safety Injection Flow Control Valve for the train to be operable. Note reviewed. Comment:
SAT  /  UNSAT TASK ELEMENT 20 STANDARD Procedure Caution: The Reactor Coolant System shall not exceed the 100 &deg;F per hour cooldown rate of Technical Specification 3.4.8.1. Caution reviewed. Comment:
Examiner Note: If asked, state that another operator is tracking cooldown rates.
SAT  /  UNSAT 6.2.12 Raise Shutdown Cooling Train B temperature to within 100 &deg;F of Reactor Coolant Hot temperature as follows:
TASK ELEMENT 21 STANDARD 6.2.12.1: Open the following valves:  SI-139B LPSI Header to RC Loop 1A Flow Control  SI-138B LPSI Header to RC Loop 1B Flow Control SI-139 B and SI-138 B are open. Comment:
Critical SAT  /  UNSAT TASK ELEMENT 21 STANDARD 6.2.12.2:  Throttle Closed RC Loop 1 Shdn Cooling Warmup, SI-135B, until one of the following is within 100&deg;F of Shutdown Cooling Train B temperature, as indicated by LPSI Pump B Discharge Header Temperature Indicator, SI-ITI-0352X:
Hot Leg 1 temperature, as indicated by RC Loop 1 Hot Leg Temperature Indicator, RC-ITI-0112-HB or  Hot Leg 2 temperature, as indicated by RC Loop 2 Hot Leg Temperature Indicator, RC-ITI-0122-HA Temperature is within 100 &deg;F Comment:
SI-135 B is a large gate valve with a very long stroke. Critical SAT  /  UNSAT
 
JPM S3  Revision 0 Page 11 of 12 2015 NRC Exam TASK ELEMENT 22 STANDARD 6.2.12.3: Close RC Loop 2 Shdn Cooling Warmup, SI-135 B. SI-135 B is closed Comment:
Critical SAT  /  UNSAT Evaluator Note Coordinate with the simulator operator to initiate trigger 1 to close SI-405 B.
TASK ELEMENT 23 STANDARD Secure LPSI Pump B LPSI Pump B is off. Comment:
This is an immediate operator action in accordance with OP-901-131, Shutdown Cooling Malfunction, section D.1.
Critical SAT  /  UNSAT END OF TASK
 
JPM S3  Revision 0 Page 12 of 12 2015 NRC Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-167 Verify the following Malfunctions:  SI23B for SI-405B on Trigger 1 Coordinate with the examiner so that when SI-135 B is fully closed at step 6.2.12.3, Trigger 1 is initiated to close SI-405B. (Use Extreme View to monitor SI-135B position)
 
System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 5 3.0 PRECAUTIONS AND LIMITATIONS 3.1 PRECAUTIONS 3.1.1 The maximum temperature for Purification Ion Exchanger(s) is 140 F. 3.1.2 If Letdown to Ion Exchangers Inlet/Bypass, CVC-140, is in AUTO then Purification Ion Exchangers will automatically bypass at 140 F. 3.1.3 The following applies to Shutdown Cooling flow:
3.1.3.1 A total minimum Shutdown Cooling flow necessary to remove decay heat and prevent boron stratification should be maintained at all times.
3.1.3.2 When considering the minimum Shutdown Cooling flow required to adequately remove decay heat and prevent boron stratification, then the flow from the operating Shutdown Cooling train or the combined flow of both operating Shutdown Cooling trains may be used.
3.1.3.3 The required minimum Shutdown Cooling flow for Modes 5 and 6 are as follows:  TIME AFTER SHUTDOWN (HOURS) REQUIRED FLOW (GPM) 0 - <175 hours  4000 GPM 175 - <375 hours  3000 GPM  375 hours  2000 GPM  If the Reactor has been shutdown <175 hours, then Shutdown Cooling flow may be reduced to 3000 GPM, if RCS temperature is verified to be
<135 F at least once per hour.
3.1.3.4 Changes to the Shutdown Cooling flow rate will cause the Alternate Shutdown Cooling Purification flow rate to change with SI-424 throttled or full open. For example, with Alternate Shutdown Cooling Purification in service via SI-424, if Shutdown Cooling flow rate is lowered, then the Alternate Shutdown Cooling Purification flow rate will increase due to increased LPSI Discharge Header pressure. This change in flow rate may require readjustment of SI-424 so the 250 GPM limit is not exceeded.
3.1.3.5 The maximum Shutdown Cooling Flow rate to prevent vortexing for one train operating at RCS Midloop condition is 3130 gpm. Refer to Attachment 11.6, SDC Maximum Flowrates to Prevent Vortexing (Per Train), for additional flow rates.  [ECM98-007]
System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 6 3.1.3.6 The SDC loop may be removed from operations for up to one hour per 8-hour period during the performance of Core Alterations in the vicinity of the reactor pressure vessel hot legs, provided no operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the minimum required boron concentration of Technical Specification 3.9.1.
3.1.4 LPSI pumps shall not be run for >3 hours in any 24 hour period on recirculation flow only. 3.1.5 If LPSI Pump flow is limited to >100 gpm and <2000 gpm for 3 consecutive hours, then contact the System Engineer for guidance on LPSI Pump monitoring. [CR-W3-2000-1376]
3.1.6 To minimize a hydraulic transient that could challenge the integrity of SI-406A(B) during the opening of SI-405A(B), one of the following conditions shall be met prior to opening SI-405A(B).  [ EC-14765, ECN-25944]
Piping between SI-407A(B) and SI-405A(B) is pressurized through SI-4052A(B) with SI-401A(A) open.
or  The SDC Train's suction penetration piping has been manually vented. Venting should be accomplished in accordance with Attachment 11.7, Manual Venting of SDC Train suction penetration piping.
or  The SDC Train was previously in-service since the unit has been shutdown.
or  If RC Loop 2(1) SDC Suct Hdr Press Equalizing and Insd Cntmnt Isol, SI-4052A(B) fails to open, RCS pressure is <213 psia by PMC indication (PIDs A12203, A12204, A12221, A12222) or <203 psia by control board indication (RC-IPI0103, -0104, -0105, -0106). [ EC-14765, ECN-25944]
3.1.7 The preferred pressure indication to use for entering shutdown cooling is  RC-IPI-0103, RC-IPI-0104, RC-IPI-0105, and RC-IPI-0106 or the associated PMC PIDs A12203, A12204, A12221, and A12222. The highest indication on functioning instrumentation should be used to make the entry decision. Low Range RCS pressure indication is preferred because at shutdown cooling entry conditions this pressure instrumentation is the least affected by instrument uncertainties. 3.1.8 A RCS pressure limitation is established for SDC entry if Containment Harsh Environment Conditions (>200&deg;F) have been exceeded. This limitation is to prevent lifting SDC suction thermal relief valves SI-408A or SI-408B.
System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 7 3.2 LIMITATIONS
 
====3.2.1 Shutdown====
Cooling shall not be initiated until Reactor Coolant System (RCS) temperature <350 F and RCS Pressure <392 PSIA.  [P-4055] 3.2.2 If Containment Harsh Environment Conditions (>200&deg;F) have been exceeded then SDC shall not be initiated until RCS Pressure <358 PSIA.  [CR-WF3-2012-1036]
3.2.3 RCS temperature changes shall be limited by the following:  A maximum heatup rate of 60F per hour  A maximum cooldown rate of 100 F per hour 3.2.4 RCS temperature and pressure shall be limited in accordance with the limit lines shown on Technical Specification Figures 3.4-2 and 3.4-3 with instrument uncertainty incorporated for pressure and temperature as follows: [ER-W3-2004-00439]
Subtract 30F from indicated temperature  Add 35 PSI to the indicated pressure from the following instruments: CP-2  RC IPI0103 (100-750 PSIA)  RC IPI0104 (100-750 PSIA) CP-4  RC IPI0105 (100-750 PSIA)  RC IPI0106 (100-750 PSIA) CP-7  RC IPI0101A(B,C,D) (1500-2500 PSIA) LCP-43  RC IPI0105-1 (100-750 PSIA)  RC IPI0106-1 (100-750 PSIA)  Add 110 PSI to the indicated pressure from the following instruments: CP-2  RC IPI0102A3 (B3) (0-3000 PSIA) CP-4  RC IPI0102A2 (B2) (0-3000 PSIA) CP-7  RC IPI0102A (B,C,D) (0-3000 PSIA) LCP-43  RC IPI0102A1 (B1,C1,D1) (0-3000 PSIA)
System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 8 3.2.5 Maximum flow through a Purification Ion Exchanger is 126 GPM. 3.2.6 When RCS is in Mode 4 and any RCS Cold Leg temperature is <230 F or in Mode 5 or Mode 6 with Reactor Vessel Head on, then Low Temperature Overpressure Protection (Tech. Spec. 3.4.8.3) shall be provided by one of the following:  [P-5804]  Both Shutdown Cooling Suction Header Relief Valves aligned to RCS or  RCS depressurized with an RCS vent  5.6 in 2 3.2.7 In Mode 4 with RCS pressure >400 PSIA, Both Containment Spray Trains shall be operable in accordance with Tech Spec 3.6.2.1. 3.2.8 The Shutdown Cooling Train placed in service should be on the Protected Train. 3.2.9 Scaffolding will be required to Vent CS Header A, when restoring CS to operation after securing Shutdown Cooling. 3.3.10 Shutdown Cooling requires one Operable Low Pressure Safety Injection Flow Control Valve per train for Shutdown Cooling to be Operable. 3.3.11 The Shutdown Cooling suction line piping upstream of SI-407A(B) should not be filled from an external water source due to the potential to cause thermal binding of SI-405A(B). There is a possibility of air intrusion into and voiding of the Shutdown Cooling suction line piping upstream of SI-407A(B) following a period of operation in Modes 1 - 4, when the Safety Injection and Containment Spray Systems are aligned for the normal injection mode. This condition has been evaluated and is described in the Design Basis Document for the Safety Injection System (W3-DBD-001). The Safety Injection System retains the capability of performing its design safety function with the described voiding and no actions are required to fill the subject section of piping. [ER-W3-2002-0283-002, CR-WF3-2004-01300, ECM03-003, W3-DBD-01]
 
System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 9 3.2.12 Each pump start stresses motor windings both thermally and mechanically. A start means motor comes up to rated speed. Starts for LPSI pumps should be limited as follows: 3.2.12.1 LPSI Pump A: 3.2.12.1.1 With motor at ambient temperature, do not attempt more than 6 consecutive starts. 3.2.12.1.2 With motor at operating temperature, do not attempt more than 4 consecutive starts. 3.2.12.1.3 Allowed time between additional starts is 15 minutes with motor at operating temperature or 30 minutes with motor at ambient temperature. 3.2.12.2 LPSI Pump B: 3.2.12.2.1 With motor at ambient temperature, do not attempt more than 2 consecutive starts. 3.2.12.2.2 With motor at operating temperature, do not attempt more than 1 consecutive start. 3.2.12.2.3 Allowed time between additional starts is 15 minutes with motor at operating temperature or 45 minutes with motor at ambient temperature. 3.2.13 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.  [EC-530]
System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 10 3.2.14 To assure that the RCS does not drop to the minimum RCS bolt up Temperature indicated on TS figures 3.4-2 and 3.4-3, the limits on the following instruments apply:  Instrument Description Min Value Location SI IT7114 / SI IT7115 RWSP Temperature 67.3&deg;F PMC SI IT0351 X / SI IT0352 X LPSI Pump Outlet Temperature 66.09&deg;F QSPDS CS IT0303 X AND Y Shutdown Cooling Outlet Temperature 66.09&deg;F QSPDS 3.2.15 When Alternate Shutdown Cooling Purification is aligned with parallel Purification Ion Exchangers and SI-424 is throttled or full open, then
:  A maximum Total Shutdown Cooling Purification flow of 250 GPM should not be exceeded. A minimum Total Shutdown Cooling Purification flow of 50 GPM should be minimized. If Total Shutdown Cooling Purification flow is to be <50 GPM, then single  Purification Ion Exchanger operation is required. PMC PID S39205, SDC/LD Purification Full Range Flow is the only available indication when Letdown flow is >150 GPM.
System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 30 RX  CAUTION THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY.
[INPO 06-006]
 
===6.2 PLACING===
SHUTDOWN COOLING TRAIN B I N SERVICE  NOTE (1) The Shutdown Cooling Train placed in service should be on the Protected Train. (2) The SDC loop may be removed from operations for up to one hour per 8-hour period during the performance of Core Alterations in the vicinity of the reactor pressure vessel hot legs, provided no operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the minimum required boron concentration of Technical Specification 3.9.1.
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.  [EC-530] 6.2.1 Verify Shutdown Cooling Train B has been aligned to Standby condition in accordance with Section 5.4, Alignment of Shutdown Cooling Train B to Standby Condition. 6.2.2 Verify sufficient number of Dry Cooling Tower Fans running to accept increased heat load on CCW System.
System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 31  CAUTION (1) CC-963B 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 B. WITH CC-963B OPEN, FLOW THROUGH SHUTDOWN COOLING HEAT EXCHANGER B WILL BE MAINTAINED ABOVE 2305 GPM.  [EC-738] [EC-30976] (2) SHUTDOWN HEAT EXCHANGER B CCW FLOW CONTROL, CC-963B, IS ALSO REQUIRED TO REMAIN OPEN IF LPSI PUMP B DISCHARGE FLOW CONTROL, SI-129B HAS BEEN FORCED CLOSED PER OP-009-008 FOLLOWING A LOSS OF INSTRUMENT AIR. 6.2.3 Place Shutdown HX B CCW Flow Control, CC-963B, control switch to Open.
CAUTION 1) THE FOLLOWING REACTOR COOLANT SYSTEM LIMITS SHALL BE MET FOR SHUTDOWN COOLING ENTRY:  RCS TEMPERATURE LIMIT: <350 F  RCS PRESSURE LIMIT: <392 PSIA  IF CONTAINMENT HARSH ENVIRONMENT CONDITIONS (>200&deg;F) HAVE BEEN EXCEEDED THEN RCS PRESSURE LIMIT: <358 PSIA (2) IF CONTAINMENT SPRAY HEADER B ISOLATION, CS-125B, IS OPEN WHILE SHUTDOWN COOLING TRAIN B IS OPERATING, THEN CONTAINMENT SPRAY B RISER MAY FILL AND POSSIBLY SPRAY WATER INTO CONTAINMENT, DUE TO LEAKAGE PAST CONTAINMENT SPRAY PUMP B DISCHARGE STOP CHECK, CS-117B. 6.2.4 To minimize the effect of air introduction to a LPSI Pump Verify RC Loop 2 SDC suction piping meets one of the following conditions:  The SDC Train is placed in-service with RCS pressure 100 PSIA by PMC indication (PIDs A12203, A12204, A12221, A12222) or 110 PSIA by board indication (RC-IPI0103, -0104, -0105, -0106).
or  The SDC Train's suction penetration piping has been manually vented. Venting should be accomplished through SI-4051B using RCS/Cavity as water source in accordance with Attachment 11.7, Manual Venting of SDC Train Suction Penetration Piping.
System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 32 or  The SDC Train was previously in-service since the unit has been shutdown. 6.2.5 Unlock and Open RC Loop 1 SDC Suction Outside Containment Isol, SI-407B. 6.2.6 Inform Radiation Protection Department that Shutdown Cooling Train B is being placed in service. 6.2.7 Start LPSI Pump B.
NOTE If Instrument Air is unavailable, LPSI Pump B Discharge Flow Control, SI-129B, will need to be operated locally per OP-009-008. If the Safeguards rooms are inaccessible (post RAS), LPSI Pump B Discharge Flow Control, SI-129B, must be remotely forced closed per OP-009-008. In this case, SDC flow/ temperature will need to be controlled using Shutdown Cooling HX B Temperature Control, SI-415B.  [EC-30976]
 
====6.2.8 Raise====
Shutdown Cooling flow by Manually adjusting LPSI Header Flow Controller 1A/1B, SI-IFIC-0306, output until Shutdown Cooling Header B flow indicates 4100 GPM, as indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1. 6.2.9 Adjust LPSI Header Flow controller 1A/1B, SI-IFIC-0306, setpoint potentiometer to 73%, and place controller to AUTO. 6.2.10 Verify LPSI Header Flow Controller 1A/1B, SI-IFIC-0306, is maintaining 4100 GPM Shutdown Cooling Header B flow, as indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1.
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. 6.2.11 At SM/CRS discretion, direct Chemistry Department to sample Shutdown Cooling Train B for boron concentration. 6.2.11.1 When Chemical Analysis results indicate that Shutdown Cooling Train B boron concentration is greater than Reactor Coolant boron concentration or 2050 PPM (required for Mode 6), then proceed to next step.
System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 33 RX  NOTE Shutdown Cooling Train B requires one operable Low Pressure Safety Injection Flow Control Valve for the train to be operable.
CAUTION THE REACTOR COOLANT SYSTEM SHALL NOT EXCEED THE 100 F PER HOUR COOLDOWN RATE OF TECHNICAL SPECIFICATION 3.4.8.1. 6.2.12 Raise Shutdown Cooling Train B temperature to within 100F of Reactor Coolant Hot Leg temperature as follows: 6.2.12.1 Open the following valves:  SI-139B LPSI Header to RC Loop 1A Flow Control  SI-138B LPSI Header to RC Loop 1B Flow Control System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 34 6.2.12.2 Throttle Closed RC Loop 1 Shdn Cooling Warmup, SI-135B, until one of the following is within 100F of Shutdown Cooling Train B temperature, as indicated by LPSI Pump B Discharge Header Temperature Indicator, SI-ITI-0352X:  [P-23174]  Hot Leg 1 temperature, as indicated by RC Loop 1 Hot Leg Temperature Indicator, RC-ITI-0112-HB or  Hot Leg 2 temperature, as indicated by RC Loop 2 Hot Leg Temperature Indicator, RC-ITI-0122-HA 6.2.12.3 Close RC Loop 1 Shdn Cooling Warmup, SI-135B.
CAUTION THE FOLLOWING APPLIES TO SHUTDOWN COOLING FLOW: (1) A TOTAL MINIMUM SHUTDOWN COOLING FLOW NECESSARY TO REMOVE DECAY HEAT AND PREVENT BORON STRATIFICATION SHOULD BE MAINTAINED AT ALL TIMES. (2) WHEN CONSIDERING THE MINIMUM SHUTDOWN COOLING FLOW REQUIRED TO ADEQUATELY REMOVE DECAY HEAT AND PREVENT BORON STRATIFICATION, THE FLOW OF BOTH OPERATING SHUTDOWN COOLING TRAINS MAY BE USED. (3) THE REQUIRED MINIMUM SHUTDOWN COOLING FLOW FOR MODES 5 AND 6 ARE AS FOLLOWS:
TIME AFTER SHUTDOWN (HOURS) REQUIRED FLOW (GPM)
<175 HOURS
* 4000 GPM  175 HOURS  3000 GPM  375 HOURS  2000 GPM
* IF THE REACTOR HAS BEEN SHUTDOWN <175 HOURS, THEN SHUTDOWN COOLING FLOW MAY BE REDUCED TO 3000 GPM IF RCS TEMPERATURE IS VERIFIED TO BE <135F AT LEAST ONCE PER HOUR. 6.2.13 Adjust LPSI Header Flow controller 1A/1B, SI-IFIC-0306, setpoint potentiometer to obtain desired Shutdown Cooling Train B flow, as indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1.
System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 35 RX  CAUTION (1) THE REACTOR COOLANT SYSTEM SHALL NOT EXCEED THE 100 F PER HOUR COOLDOWN RATE OF TECHNICAL SPECIFICATION 3.4.8.1. (2) CC-963B 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 B. WITH CC-963B OPEN, FLOW THROUGH SHUTDOWN COOLING HEAT EXCHANGER B WILL BE MAINTAINED ABOVE 2305 GPM.  [EC-738] [EC-30976] (3)    SHUTDOWN HEAT EXCHANGER B CCW FLOW CONTROL, CC-963B, IS ALSO REQUIRED TO REMAIN OPEN IF LPSI PUMP B DISCHARGE FLOW CONTROL, SI-129B HAS BEEN FORCED CLOSED PER OP-009-008 FOLLOWING A LOSS OF INSTRUMENT AIR. 6.2.14 Maintain RCS temperature control as follows: 6.2.14.1 Throttle Open Shutdown Cooling HX B Temperature Control, SI-415B, as required. 6.2.14.2 Place Shutdown HX B CCW Flow Control, CC-963B, to Open or Setpoint, as required.
NOTE Once activated the SHUTDOWN COOLING TROUBLE annunciator (Window H-18 on cabinet N) will alarm since the Low Flow setpoints are initially failed High. 6.2.15 Verify Computer Point PID B43800, SDCS Alarm Processing, set to ACTIVE state in accordance with OP-004-012, Plant Computer System. 6.2.16 Verify Computer Point PID K43201, SDCS/LPSI PMP B LOW FLOW LIM, set to approximately 200 gpm below the established Shutdown Cooling Train B flow, as indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1. 6.2.17 If Shutdown Cooling Train A is not in service, then set Computer Point PID K43101 SDCS/LPSI PMP A LOW FLOW LIM, to Zero in accordance with OP-004-012, Plant Computer System. 6.2.18 If CETs from QSPDS Channel 1(2) are not available, then set PID C26417(C26510), TRCET Representative CET, to Zero. 6.2.19 Verify SHUTDOWN COOLING TROUBLE annunciator (WINDOW H-18 ON CABINET N) is Clear.
System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 36  NOTE (1) Due to thermal expansion, the Shutdown Cooling Heat Exchanger A Outlet Stop Check, CS-117A, must be re-tightened in the Closed direction approximately 3 hours after Shutdown Cooling Train A is placed in service. (2) To ensure CS-117A(B) properly seats when the valve reaches the closed position, it is necessary to apply sufficient torque in the closed direction, approximately 100 lbf on the installed handwheel, until the torque-limiter slips. 6.2.20 Verify Closed Shutdown Cooling Heat Exchanger B Stop Check, CS-117B, approximately 3 hours after Shutdown Cooling Train B is placed in service. 6.2.21 If splitting of CCW Trains is necessary as directed by the SM/CRS, then go to Section 6.13, Splitting Out CCW Trains when on Shutdown Cooling. 
 
System Operating ProcedureOP-009-005Shutdown CoolingRevision 035 30 RXCAUTIONTHE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY.[INPO 06-006]6.2 PLACING SHUTDOWN COOLING TRAIN BI N SERVICENOTE(1) The Shutdown Cooling Train placed in service should be on the Protected Train.(2) The SDC loop may be removed from operations for up to one hour per 8-hour periodduring the performance of Core Alterations in the vicinity of the reactor pressure vesselhot legs, provided no operations are permitted that would cause introduction into theRCS, coolant with boron concentration less than required to meet the minimum requiredboron concentration of Technical Specification 3.9.1.CAUTIONFOLLOWING A DESIGN BASIS TORNADO EVENT, DELAYING THE INITIATION OFSHUTDOWN COOLING (SDC) FOR UP TO 7 DAYS WILL BE REQUIRED TO ENSURETHE COMPONENT COOLING WATER SYSTEM IS CAPABLE OF REMOVING REACTORCOOLANT SYSTEM DECAY HEAT. THE ACTUAL DELAY TIME WILL DEPEND ON UHSDAMAGE AND AMBIENT TEMPERATURE AND WILL BE DETERMINED BYENGINEERING. EMERGENCY FEEDWATER SUPPORTS DECAY HEAT REMOVALUNTIL SDC CAN BE INITIATED.[EC-530]6.2.1 Verify Shutdown Cooling Train B has been aligned to Standby condition inaccordance with Section 5.4, Alignment of Shutdown Cooling Train B to StandbyCondition.6.2.2 Verify sufficient number of Dry Cooling Tower Fans running to accept increasedheat load on CCW System.
System Operating ProcedureOP-009-005Shutdown CoolingRevision 035 31CAUTION(1) CC-963B IS REQUIRED TO BE MAINTAINED OPEN WHILE IN MODE 4 TOPRESERVE THE DESIGN TEMPERATURE BASIS OF PIPING AND ASSOCIATEDCOMPONENTS AT THE CCW OUTLET OF SHUTDOWN COOLING HEATEXCHANGER B. WITH CC-963B OPEN, FLOW THROUGH SHUTDOWN COOLINGHEAT EXCHANGER B WILL BE MAINTAINED ABOVE 2305 GPM.  [EC-738] [EC-30976](2) SHUTDOWN HEAT EXCHANGER B CCW FLOW CONTROL, CC-963B, IS ALSOREQUIRED TO REMAIN OPEN IF LPSI PUMP B DISCHARGE FLOW CONTROL,SI-129B HAS BEEN FORCED CLOSED PER OP-009-008 FOLLOWING A LOSS OFINSTRUMENT AIR.6.2.3 Place Shutdown HX B CCW Flow Control, CC-963B, control switch to Open.CAUTION1) THE FOLLOWING REACTOR COOLANT SYSTEM LIMITS SHALL BE MET FORSHUTDOWN COOLING ENTRY: RCS TEMPERATURE LIMIT: <350 F RCS PRESSURE LIMIT: <392 PSIA IF CONTAINMENT HARSH ENVIRONMENT CONDITIONS (>200&deg;F) HAVE BEENEXCEEDED THEN RCS PRESSURE LIMIT: <358 PSIA(2) IF CONTAINMENT SPRAY HEADER B ISOLATION, CS-125B, IS OPEN WHILESHUTDOWN COOLING TRAIN B IS OPERATING, THEN CONTAINMENT SPRAY BRISER MAY FILL AND POSSIBLY SPRAY WATER INTO CONTAINMENT, DUE TOLEAKAGE PAST CONTAINMENT SPRAY PUMP B DISCHARGE STOP CHECK,CS-117B.6.2.4 To minimize the effect of air introduction to a LPSI Pump Verify RC Loop 2 SDCsuction piping meets one of the following conditions: The SDC Train is placed in-service with RCS pressure100 PSIA by PMCindication (PIDs A12203, A12204, A12221, A12222) or110 PSIA by boardindication (RC-IPI0103, -0104, -0105, -0106).
or The SDC Train's suction penetration piping has been manually vented.Venting should be accomplished through SI-4051B using RCS/Cavity as watersource in accordance with Attachment 11.7, Manual Venting of SDC TrainSuction Penetration Piping.
System Operating ProcedureOP-009-005Shutdown CoolingRevision 035 32 or The SDC Train was previously in-service since the unit has been shutdown.6.2.5 Unlock and Open RC Loop 1 SDC Suction Outside Containment Isol, SI-407B.6.2.6 Inform Radiation Protection Department that Shutdown Cooling Train B is beingplaced in service.6.2.7 Start LPSI Pump B.NOTEIf Instrument Air is unavailable, LPSI Pump B Discharge Flow Control, SI-129B, will need tobe operated locally per OP-009-008. If the Safeguards rooms are inaccessible (post RAS),LPSI Pump B Discharge Flow Control, SI-129B, must be remotely forced closed perOP-009-008. In this case, SDC flow/ temperature will need to be controlled using ShutdownCooling HX B Temperature Control, SI-415B.[EC-30976]6.2.8 Raise Shutdown Cooling flow by Manually adjusting LPSI Header Flow Controller1A/1B, SI-IFIC-0306, output until Shutdown Cooling Header B flow indicates4100 GPM, as indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1.6.2.9 Adjust LPSI Header Flow controller 1A/1B, SI-IFIC-0306, setpoint potentiometer to73%, and place controller to AUTO.6.2.10 Verify LPSI Header Flow Controller 1A/1B, SI-IFIC-0306, is maintaining 4100 GPMShutdown Cooling Header B flow, as indicated by RC Loop 1 Shdn Line FlowIndicator, SI-IFI-1306-B1.NOTEIf a sample was drawn prior to shutdown and no interim shutdown has occurred where SDCwas placed in service and boron concentration could have been reduced, then sampling isnot required.6.2.11 At SM/CRS discretion, direct Chemistry Department to sample Shutdown CoolingTrain B for boron concentration.6.2.11.1 When Chemical Analysis results indicate that Shutdown Cooling Train Bboron concentration is greater than Reactor Coolant boron concentration or2050 PPM (required for Mode 6), then proceed to next step.
System Operating ProcedureOP-009-005Shutdown CoolingRevision 035 33 RXNOTEShutdown Cooling Train B requires one operable Low Pressure Safety Injection Flow ControlValve for the train to be operable.CAUTIONTHE REACTOR COOLANT SYSTEM SHALL NOT EXCEED THE 100 F PER HOURCOOLDOWN RATE OF TECHNICAL SPECIFICATION 3.4.8.1.6.2.12 Raise Shutdown Cooling Train B temperature to within 100F of Reactor CoolantHot Leg temperature as follows:6.2.12.1 Open the following valves:
SI-139BLPSI Header to RC Loop 1A Flow Control SI-138BLPSI Header to RC Loop 1B Flow Control System Operating ProcedureOP-009-005Shutdown CoolingRevision 035 346.2.12.2 Throttle Closed RC Loop 1 Shdn Cooling Warmup, SI-135B, until one of thefollowing is within 100F of Shutdown Cooling Train B temperature, asindicated by LPSI Pump B Discharge Header Temperature Indicator,SI-ITI-0352X:[P-23174] Hot Leg 1 temperature, as indicated by RC Loop 1 Hot Leg TemperatureIndicator, RC-ITI-0112-HB or Hot Leg 2 temperature, as indicated by RC Loop 2 Hot Leg TemperatureIndicator, RC-ITI-0122-HA6.2.12.3 Close RC Loop 1 Shdn Cooling Warmup, SI-135B.CAUTIONTHE FOLLOWING APPLIES TO SHUTDOWN COOLING FLOW:(1) A TOTAL MINIMUM SHUTDOWN COOLING FLOW NECESSARY TO REMOVEDECAY HEAT AND PREVENT BORON STRATIFICATION SHOULD BE MAINTAINEDAT ALL TIMES.(2) WHEN CONSIDERING THE MINIMUM SHUTDOWN COOLING FLOW REQUIRED TOADEQUATELY REMOVE DECAY HEAT AND PREVENT BORON STRATIFICATION,THE FLOW OF BOTH OPERATING SHUTDOWN COOLING TRAINS MAY BE USED.(3) THE REQUIRED MINIMUM SHUTDOWN COOLING FLOW FOR MODES 5 AND 6ARE AS FOLLOWS:TIME AFTER SHUTDOWN (HOURS)REQUIRED FLOW (GPM)<175 HOURS
* 4000 GPM 175 HOURS 3000 GPM 375 HOURS 2000 GPM* IF THE REACTOR HAS BEEN SHUTDOWN <175 HOURS, THEN SHUTDOWNCOOLING FLOW MAY BE REDUCED TO3000 GPM IF RCS TEMPERATURE ISVERIFIED TO BE <135F AT LEAST ONCE PER HOUR.6.2.13 Adjust LPSI Header Flow controller 1A/1B, SI-IFIC-0306, setpoint potentiometer toobtain desired Shutdown Cooling Train B flow, as indicated by RC Loop 1 ShdnLine Flow Indicator, SI-IFI-1306-B1.
System Operating ProcedureOP-009-005Shutdown CoolingRevision 035 35 RXCAUTION(1) THE REACTOR COOLANT SYSTEM SHALL NOT EXCEED THE 100 F PER HOURCOOLDOWN RATE OF TECHNICAL SPECIFICATION 3.4.8.1.(2) CC-963B IS REQUIRED TO BE MAINTAINED OPEN WHILE IN MODE 4 TOPRESERVE THE DESIGN TEMPERATURE BASIS OF PIPING AND ASSOCIATEDCOMPONENTS AT THE CCW OUTLET OF SHUTDOWN COOLING HEATEXCHANGER B. WITH CC-963B OPEN, FLOW THROUGH SHUTDOWN COOLINGHEAT EXCHANGER B WILL BE MAINTAINED ABOVE 2305 GPM.[EC-738][EC-30976](3)    SHUTDOWN HEAT EXCHANGER B CCW FLOW CONTROL, CC-963B, IS ALSOREQUIRED TO REMAIN OPEN IF LPSI PUMP B DISCHARGE FLOW CONTROL,SI-129B HAS BEEN FORCED CLOSED PER OP-009-008 FOLLOWING A LOSS OFINSTRUMENT AIR.6.2.14 Maintain RCS temperature control as follows:6.2.14.1 Throttle Open Shutdown Cooling HX B Temperature Control, SI-415B, asrequired.6.2.14.2 Place Shutdown HX B CCW Flow Control, CC-963B, to Open or Setpoint, asrequired.NOTEOnce activated the SHUTDOWN COOLING TROUBLE annunciator (Window H-18 oncabinet N) will alarm since the Low Flow setpoints are initially failed High.6.2.15 Verify Computer Point PID B43800, SDCS Alarm Processing, set to ACTIVE statein accordance with OP-004-012, Plant Computer System.6.2.16 Verify Computer Point PID K43201, SDCS/LPSI PMP B LOW FLOW LIM, set toapproximately 200 gpm below the established Shutdown Cooling Train B flow, asindicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1.6.2.17 If Shutdown Cooling Train A is not in service, then set Computer Point PIDK43101 SDCS/LPSI PMP A LOW FLOW LIM, to Zero in accordance withOP-004-012, Plant Computer System.6.2.18 If CETs from QSPDS Channel 1(2) are not available, then set PIDC26417(C26510), TRCET Representative CET, to Zero.6.2.19 Verify SHUTDOWN COOLING TROUBLE annunciator (WINDOW H-18 ONCABINET N) is Clear.
System Operating ProcedureOP-009-005Shutdown CoolingRevision 035 36NOTE(1) Due to thermal expansion, the Shutdown Cooling Heat Exchanger A Outlet Stop Check,CS-117A, must be re-tightened in the Closed direction approximately 3 hours afterShutdown Cooling Train A is placed in service.(2) To ensure CS-117A(B) properly seats when the valve reaches the closed position, it isnecessary to apply sufficient torque in the closed direction, approximately 100 lbf on theinstalled handwheel, until the torque-limiter slips.6.2.20 Verify Closed Shutdown Cooling Heat Exchanger B Stop Check, CS-117B,approximately 3 hours after Shutdown Cooling Train B is placed in service.6.2.21 If splitting of CCW Trains is necessary as directed by the SM/CRS, then go toSection 6.13, Splitting Out CCW Trains when on Shutdown Cooling.
 
Off Normal ProcedureOP-901-131Shutdown Cooling MalfunctionRevision 304 6 D.IMMEDIATE OPERATOR ACTIONS 1.IF ANY of the following Shutdown Cooling Loop Suction Isolation valves closeon the operating Shutdown Cooling train, THEN secure LPSI Pump: For LPSI Pump A: SDCS LOOP 2 SUCTION ISOL UPSTREAM INSIDE (SI 401A) SDCS LOOP 2 SUCTION ISOL DOWNSTREAM INSIDE (SI 405A) SDCS LOOP 2 SUCTION ISOL DOWNSTREAM OUTSIDE (SI 407A) For LPSI Pump B: SDCS LOOP 1 SUCTION ISOL UPSTREAM INSIDE (SI 401B) SDCS LOOP 1 SUCTION ISOL DOWNSTREAM INSIDE (SI 405B) SDCS LOOP 1 SUCTION ISOL DOWNSTREAM OUTSIDE (SI 407B).
Waterford 3 2015 NRC RO Exam JOB PERFORMANCE MEASURE S4  Balance of Plant Operator Immediate Operator Actions on Control Room Evacuation Applicant:
Examiner:
 
JPM S4  Revision 1 Page 2 of 7 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Perform balance of plant operator's immediate operator action on Control Room evacuation with fire conditions.
Task Standard: Applicant performed immediate operator actions for BOP position for a fire in the Control Room in accordance with OP-901-502, Evacuation of Control Room and Subsequent Plant Shutdown. Applicant manually closed Atmospheric Dump Valve #2 due to setpoint failure.
 
==References:==
OP-901-502, Evacuation of Control Room and Subsequent Plant Shutdown  Alternate Path:
Yes Time Critical: No Validation Time:
4 mins. K/A 039 A4.01 Main Steam Supply Valves  Importance Rating 2.9 / 2.8 RO / SRO  Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM S4  Revision 0 Page 3 of 7 2015 NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
None
 
== Description:==
 
The applicant will be cued that there is a fire in CP-33. The CRS will direct him to carry out his immediate operator actions as BOP operator. ADV #2 setpoint will fail to 666 PSIG, spuriously opening ADV #2. The applicant will be required to place that controller to manual and set it to 0% output to close ADV #2. The task will end when the applicant goes to the key locker.
DIRECTION TO APPLICANT:
I will explain the initial conditions, and state the 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 actions when directed by you. Indicate to me when you understand your assigned task.
(Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM S4  Revision 0 Page 4 of 7 2015 NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The plant is at 100% power  A fire has started in CP-33  The CRS has entered OP-901-502, Evacuation of Control Room and Subsequent Plant Shutdown  The ATC is performing his immediate operator actions.
INITIATING CUE:
The CRS directs you to perform the BOP immediate operator actions.
 
JPM S4  Revision 0 Page 5 of 7 2015 NRC Exam Evaluator Note Cue the Simulator Operator to place the Simulator in RUN and initiate Trigger 1.
TASK ELEMENT 1 STANDARD 2.1 Verify Turbine trip:  Governor valves Closed  Throttle valves Closed Verification complete. Comment:    SAT  /  UNSAT TASK ELEMENT 2 STANDARD 2.2 Verify Generator trip:  Exciter Field Breaker Tripped  Generator Breaker A Tripped  Generator Breaker B Tripped Verification complete. Comment:    SAT  /  UNSAT TASK ELEMENT 3 STANDARD 2.3 RESET Moisture Separator Reheater controls. Reset was depressed. Comment:  Critical SAT  /  UNSAT
 
JPM S4  Revision 0 Page 6 of 7 2015 NRC Exam Evaluator Note The Alternate Path becomes applicable when the applicant addresses the Atmospheric Dump Valves. ADV #2 will have spuriously opened.
2.4 IF evacuating the Control Room due to fire, THEN perform the following:
TASK ELEMENT 4 STANDARD 2.4.1 IF EITHER of the following valves has spuriously Opened, THEN place the applicable controller(s) in MANUAL AND lower the output to zero: MS-116A SG 1 Atmospheric Dump MS-116B SG 2 Atmospheric Dump ADV #2 controller is placed in manual and output lowered to 0%. Comment: ADV #2 setpoint fails, driving ADV #2 open with normal pressure in S/G
#2. Critical SAT  /  UNSAT TASK ELEMENT 5 STANDARD 2.4.2 Close the following valves: MS-124A Main Steam Isol Valve #1 MS-124B Main Steam Isol Valve #2 MS-124 A & MS-124 B are closed. Comment:  Critical SAT  /  UNSAT TASK ELEMENT 6 STANDARD 2.5 Obtain assigned Operations Security Key Ring AND proceed to RAB +35 Relay Room. Keys obtained. Comment: Examiner Note: The key to open the SM key locker is located in the controlled key panel next to the RO desk.
SAT  /  UNSAT END OF TASK JPM S4  Revision 0 Page 7 of 7 2015 NRC Exam SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-166 Verify the following Malfunctions:
o MS23B to 666 psi on Trigger 1 with a 5 second delay Verify the following Overrides:
o DI-02A04S01-0 on Trigger 1 (Reactor Trip push button 'A')
o DI-02A04S02-0 on Trigger 1 (Reactor Trip push button 'D')
Coordinate with examiner to initiate Trigger 1 on his cue. This will trip the reactor and insert the ADV #2 malfunction.
 
Off Normal ProcedureOP-901-502Evacuation of Control Room and Subsequent Plant ShutdownRevision 030D. IMMEDIATE OPERATOR ACTIONS (CONT'D) 7 PLACEKEEPERSTART DONEN/A2. BOP Operator perform the following:2.1 Verify Turbine trip:Governor valves ClosedThrottle valves Closed2.2 Verify Generator trip:Exciter Field Breaker TrippedGenerator Breaker A TrippedGenerator Breaker B Tripped2.3 RESET Moisture Separator Reheater controls.2.4 IF evacuating the Control Room due to fire, THENperform the following:2.4.1 IF EITHER of the following valves hasspuriously Opened, THEN place theapplicable controller(s) in MANUAL ANDlower the output to zero: MS-116A SG 1 Atmospheric Dump MS-116B SG 2 Atmospheric Dump2.4.2 Close the following valves: MS-124A Main Steam Isol Valve #1 MS-124B Main Steam Isol Valve #22.5 Obtain assigned Operations Security Key RingAND proceed to RAB +35 Relay Room.
Waterford 3 2015 NRC RO/SRO Exam JOB PERFORMANCE MEASURE S5  Realign Containment Spray for Auto Initiation following CSAS Applicant:
Examiner:
 
JPM S5 Revision 0 Page 2 of 9 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Realign Containment Spray for Auto Initiation Following CSAS in accordance with OP-902-009 Attachment 5E, CSAS Reset Procedure Task Standard: Reset initiation and actuation relays, stopped CS Pumps, and realigned discharge valves
 
==References:==
OP-902-009 Attachment 5E, CSAS Reset Procedure Rev 310 Alternate Path:
No Time Critical:
No Validation Time:
13 min. K/A 026A4.01 CSS controls  Importance Rating 4.5/4.3 RO / SRO  Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM S5 Revision 0 Page 3 of 9 2015 NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-902-004, Excess Steam Demand Recovery OP-902-009, Standard Appendices (Handout 1)
This JPM is performed concurrently with JPM S7.
 
== Description:==
 
This task will be performed at CP-8, CP-10, and CP-33 during an excess steam demand accident that resulted in a CSAS. Containment pressure has since reduced below 16.4 PSIA and conditions have been met to reset Containment Spray. The operator will realign containment spray for automatic initiation IAW OP-902-009 Appendix 5 Attachment 5-E. There are no faults associated with this JPM.
DIRECTIONS TO APPLICANT:
I will explain the initial conditions, and state the 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 actions when directed by you. Indicate to me when you understand your assigned task.
(Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM S5 Revision 0 Page 4 of 9 2015 NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
An Excess Steam Demand Event is in progress  The crew is responding in accordance with OP-902-004, Excess Steam Demand Recovery  Containment pressure has reduced to <16.4 PSIA and is stable INITIATING CUE:
The CRS has directed you reset Containment Spray Actuation Signal in accordance with OP-902-009 Appendix 5E.
 
JPM S5 Revision 0 Page 5 of 9 2015 NRC Exam EXAMINER NOTE Cue the Simulator Operator to place the Simulator in RUN.
TASK ELEMENT 1 STANDARD 1. Place Control switches for ALL CCW to RCP isolation valves to "CLOSE:"  CC 641, CCW RCP INLET OUTSIDE ISOL CC 710, CCW RCP OUTLET INSIDE ISOL CC 713, CCW RCP OUTLET OUTSIDE ISOL Control switches for CC-641, CC-710, CC-713 in CLOSE Comment:  SAT  /  UNSAT TASK ELEMENT 2 STANDARD 2 Reset CSAS Initiation relays on ALL four channels as follows: a. Place the Reset Permissive switch to "UNLK" position. (CP-10) b. Press CSAS Reset pushbutton. c. Verify the initiation relay indicator is illuminated on the ENGINNERED SAFETY FEATURES SYSTEM mimic. d. Place the Reset permissive switch to "LK" position. Trains A, B, C, D reset permissive switch unlocked, CSAS reset pushbuttons depressed for each train, trains A, B, C, D, reset permissive switch to "LK" Comment: Key # 218 Critical SAT  /  UNSAT TASK ELEMENT 3 STANDARD 3 Reset CSAS actuation logic on BOTH trains as follows: a. Press the CSAS Reset pushbuttons. (CP-33) Train A and B CSAS reset pushbuttons depressed Comment:    Critical SAT  /  UNSAT
 
JPM S5 Revision 0 Page 6 of 9 2015 NRC Exam TASK ELEMENT 4 STANDARD 3 Reset CSAS actuation logic on BOTH trains as follows: b. Verify the actuation relay indicator is illuminated on the ENGINEERED SAFETY FEATURES SYSTEM mimic. (CP-10) Verified relay indicators lit Comment:    SAT  /  UNSAT TASK ELEMENT 5 STANDARD 4. IF BOTH CS Pumps are operating, THEN perform the following: a. Stop ONE CS pump  CS Pump A  CS Pump B Either A or B CS pump switch placed to stop Comment: Examiner Note: If asked which CS Pump the CRS would like to secure first, inform the applicant to secure CS Pump A. Critical SAT  /  UNSAT TASK ELEMENT 6 STANDARD 4. b. Verify associated CS Pump Control Switch in mid-position The CS pump control switch that was secured is in the mid-position Comment:  Critical SAT  /  UNSAT TASK ELEMENT 7 STANDARD 4. c. Monitor CNTMT parameters (pressure and temperature) for rising trends  Containment pressure and temperature monitored Comment:  SAT  /  UNSAT
 
JPM S5 Revision 0 Page 7 of 9 2015 NRC Exam TASK ELEMENT 8 STANDARD 4. d. IF adverse CNTMT parameters (pressure and temperature) rising, THEN perform the following: 1) Evaluate need to continue to operate CS 2.) Exit this attachment Evaluate that there is not a need to restart CS or exit this attachment Comment:  SAT  /  UNSAT TASK ELEMENT 9 STANDARD 4. e. IF containment parameters (pressure and temperature) are stable or trending down, THEN GO TO step 5:  Proceed to step 5 Comment: Examiner Note: If applicant states there is a slow rise in parameters, acknowledge the report and inform the applicant to continue.
SAT  /  UNSAT TASK ELEMENT 10 STANDARD 5 IF ONE CS pump is operating, THEN perform the following:
: a. Stop CS pump  CS Pump A  CS Pump B CS pump that was not stopped previously is stopped Comment:  Critical SAT  /  UNSAT TASK ELEMENT 11 STANDARD 5 b. Verify associated CS Pump Control switch in mid-position.
The second CS pump control switch is in the mid-position Comment:  Critical SAT  /  UNSAT
 
JPM S5 Revision 0 Page 8 of 9 2015 NRC Exam TASK ELEMENT 12 STANDARD 5 c. Monitor CNTMT parameters (pressure and temperature) for rising trends. Containment pressure and temperature trends are monitored. Comment:  SAT  /  UNSAT TASK ELEMENT 13 STANDARD 5 d. IF adverse CNTMT parameters (pressure and temperature) rising, THEN evaluate need to restart CS.
Determine no need to restart CS. Comment: Examiner Cue: Containment temperature and pressure will be very slowly rising due to normal ambient heatup. If applicant asks CRS for guidance, inform the applicant to continue on with the procedure.
SAT  /  UNSAT TASK ELEMENT 14 STANDARD 6 Verify Containment Spray valve(s) closed for ANY stopped CS pump(s): S 125A, CNTMT SPRAY HEADER A ISOL S 125B, CNTMT SPRAY HEADER B ISOL CS-125A and CS-125B closed Comment:  EXAMINER NOTE: These valves will be closed by placing the control switch to open and then to close.
Critical SAT  /  UNSAT END OF TASK
 
JPM S5 Revision 0 Page 9 of 9 2015 NRC Exam SIMULATOR OPERATOR INSTRUCTIONS
: 1. Reset to IC-168 2. Verify containment pressure < 16.4 PSIA 3. For 2015 NRC Exam, JPM S7 is performed concurrently. 4. For 2015 NRC Exam, ensure the applicant travels to CP-10 and CP-8 in a direction that limits encounters with the applicant performing S7.
Setup with specific IC unavailable or for non NRC exams:
: 1. Reset the simulator to an IC at any power level in Mode 1 2. Insert a main steam line break inside Containment 3. When Containment Spray Actuates, delete the malfunction and insert the main steam line break on the same Steam Generator outside Containment (This is to empty the Steam Generator without raising Containment pressure too high) 4. Stop all RCPs 5. Once Steam Generator Blowdown is complete, delete the malfunction 6. Secure both EDGs; lower ACC-126 A&B setpoints to 75F 7. Allow Containment pressure to reduce below 16.4 PSIA 8. Allow conditions to stabilize. 9. Place simulator in freeze and save IC
 
WATERFORD 3 SES OP-902-009 Revision 310 Page 58 of 177 STANDARD APPENDICES Attachment 5-E Page 1 of 3 ESFAS Reset Attachment 5-E: CSAS Reset Procedure INSTRUCTIONS
: 1. Place Control switches for ALL CCW to RCP Isolation valves to "CLOSE:"  CC 641, RCP INLET OUTSIDE ISOL  CC 710, RCP OUTLET INSIDE ISOL  CC 713, RCP OUTLET OUTSIDE ISOL
: 2. Reset CSAS Initiation relays on ALL four channels as follows:
: a. Place the Reset Permissive switch to "UNLK" position. (CP-10)
: b. Press CSAS Reset pushbutton.
: c. Verify the initiation relay indicator is illuminated on the ENGINNERED SAFETY FEATURES SYSTEM mimic.
: d. Place the Reset permissive switch to "LK" position.
: 3. Reset CSAS actuation logic on BOTH trains as follows:
: a. Press the CSAS Reset pushbuttons. (CP-33)
: b. Verify the actuation relay indicator is illuminated on the ENGINEERED SAFETY FEATURES SYSTEM mimic. (CP-10)
 
WATERFORD 3 SES OP-902-009 Revision 310 Page 59 of 177 STANDARD APPENDICES Attachment 5-E Page 2 of 3 INSTRUCTIONS
: 4. IF BOTH CS pumps are operating, THEN perform the following:
: a. Stop ONE CS pump:  CS Pump A  CS Pump B
: b. Verify associated CS Pump Control switch in mid-position. c. Monitor CNTMT parameters (pressure and temperature) for rising trends.
: d. IF adverse CNTMT parameters (pressure and temperature) rising, THEN perform the following: 1) Evaluate need to continue to operate CS. 2) Exit this attachment.
: e. IF CNTMT parameters (pressure and temperature) are stable or trending down, THEN GO TO step 5.
WATERFORD 3 SES OP-902-009 Revision 310 Page 60 of 177 STANDARD APPENDICES Attachment 5-E Page 3 of 3 INSTRUCTIONS
: 5. IF ONE CS pump is operating, THEN perform the following :
: a. Stop CS pump:  CS Pump A  CS Pump B
: b. Verify associated CS Pump Control switch in mid-position. c. Monitor CNTMT parameters (pressure and temperature) for rising trends.
: d. IF adverse CNTMT parameters (pressure and temperature) rising, THEN evaluate need to restart CS.
: 6. Verify CNTMT Spray Header valve(s) closed for ANY stopped CS pump(s):  CS 125A, CNTMT SPRAY HEADER A ISOL  CS 125B, CNTMT SPRAY HEADER B ISOL End of Appendix 5 WATERFORD 3 SESOP-902-009Revision 310STANDARD APPENDICESPage 58 of 177Attachment 5-E Page 1 of 3ESFAS ResetAttachment 5-E: CSAS Reset ProcedureINSTRUCTIONS 1.Place Control switches forALLCCWto RCP Isolationvalves to"CLOSE:" CC 641, RCP INLET OUTSIDE ISOL CC 710, RCP OUTLET INSIDE ISOL CC 713, RCP OUTLET OUTSIDE ISOL2. Reset CSAS Initiation relays onALLfour channels as follows:a. Place the Reset Permissive switch to "UNLK" position. (CP-10)b. Press CSAS Reset pushbutton.c. Verify the initiation relay indicator is illuminated on the ENGINNEREDSAFETY FEATURES SYSTEM mimic.d. Place the Reset permissive switch to "LK" position.3. Reset CSAS actuation logic onBOTHtrains as follows:a. Press the CSAS Reset pushbuttons. (CP-33)b. Verify the actuation relay indicator is illuminated on the ENGINEEREDSAFETY FEATURES SYSTEM mimic. (CP-10)
WATERFORD 3 SESOP-902-009Revision 310STANDARD APPENDICESPage 59 of 177Attachment 5-E Page 2 of 3INSTRUCTIONS 4.IFBOTH CS pumps are operating,THEN perform the following:a. Stop ONE CS pump: CS Pump A CS Pump Bb. Verify associated CS Pump Control switch in mid-position.c. Monitor CNTMT parameters (pressure and temperature) for rising trends.
d.IF adverse CNTMT parameters (pressure and temperature) rising,THEN perform the following:1) Evaluate need to continue to operate CS.2) Exit this attachment.
e.IF CNTMT parameters (pressure and temperature) are stable or trending down,THEN GO TO step 5.
WATERFORD 3 SESOP-902-009Revision 310STANDARD APPENDICESPage 60 of 177Attachment 5-E Page 3 of 3INSTRUCTIONS 5.IFONE CS pump is operating,THEN perform the following :a. Stop CS pump: CS Pump A CS Pump Bb. Verify associated CS Pump Control switch in mid-position.c. Monitor CNTMT parameters (pressure and temperature) for rising trends.
d.IFadverse CNTMT parameters (pressure and temperature) rising,THEN evaluate need to restart CS.6. Verify CNTMT Spray Header valve(s) closed forANY stopped CS pump(s): CS 125A, CNTMT SPRAY HEADER A ISOL CS 125B, CNTMT SPRAY HEADER B ISOLEnd of Appendix 5 Technical Guide for Standard Appendices TG-OP-902-009 Revision 309 18Appendix 5ESFAS Reset (cont'd)EFAS ResetThese attachments verify that main feedwater is available to feed the steam generators.The operator then may reset the actuation logic for the EFAS by ensuring the manualactuation switches are in norm and relays are reset at CP-33. The remainder of theattachment will lineup for automatic system operation.EFAS reset - the reset is designed to occur above the EFAS primary setpoint of 85%WR (62.77% NR). The primary setpoint is controlled by WR instrumentation, and thebistable is controlled by NR instrumentation. Accounting for WR uncertainty (ECI92-012) and NR uncertainty (ECI92-019) results in a reset of 68.4% NR. The reset value isdocumented in EC 8460.CSAS ResetPrior to reset of the CSAS, the control switches for CCW to the RCPs are placed in theclose position. This prevents the CCW valves from opening and thermal shocking theRCP seals. The containment spray system is reset. Each containment spray pump isthen secured sequentially while monitoring containment conditions. The controlswitches are restored to mid-position after each pump is stopped so that containmentspray will automatically actuate if containment pressure rises above the actuation setpoint. The containment spray valves are identified for closure after both of thecontainment spray pumps are stopped and the pump control switch is restored for autoactuation, the valves should be closed when instrument air pressure is available.
Waterford 3 2015 NRC RO/SRO Exam JOB PERFORMANCE MEASURE S6  Restore Power to Bus 3B Applicant:
Examiner:
 
JPM S6 Revision 0 Page 2 of 10 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Restore Power to Safety Bus 3B IAW OP-902-000, Standard Post Trip Actions.
Task Standard: Applicant transfers Train A to Unit Auxiliary Transformer (UAT) A. Upon transfer of Train B to UAT B, the Reactor and turbine trip, the applicant performs Standard Post Trip Actions to restore power to Safety Bus 3B by adjusting EDG voltage.
 
==References:==
OP-006-001, Plant Distribution (7KV, 4KV, and SSD) System Rev 316 OP-902-000, Standard Post Trip Actions Rev 15 Alternate Path:
Yes Time Critical:
No Validation Time:
7 min. K/A A4.02 Adjustment of exciter voltage (using  Importance Rating 3.3/3.4 voltage control switch RO / SRO  Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM S6 Revision 0 Page 3 of 10 2015 NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-006-001, Plant Distribution (7KV, 4KV, and SSD) System (Handout 1)  OP-902-000, Standard Post Trip Actions
 
== Description:==
 
This task takes place at CP-1. The applicant will assume the shift as the BOP operator during a plant startup at the step to transfer auxiliaries to the Unit Auxiliary Transformers. The applicant will align the A train busses and when the B train is aligned, the B UAT will fail. The failure will result in a Reactor Trip due to a loss of flow to the RCS. The "B" generator output breaker will fail to open resulting in a loss of offsite power to the "B" electrical busses. The applicant will perform the maintenance of vital auxiliaries section of OP-902-000 from memory. The applicant will trip the main generator using the trip pushbuttons, trip the generator output breaker, and recognize that the EDG started but did not supply its respective bus. The applicant will perform immediate action to raise EDG voltage to 3920 to 4350 AC volts allowing the EDG to provide power to bus 3B.
DIRECTIONS TO APPLICANT:
I will explain the initial conditions, and state the 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 actions when directed by you. Indicate to me when you understand your assigned task.
(Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM S6 Revision 0 Page 4 of 10 2015 NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The plant is performing a startup  S/G levels are being maintained by an additional operator  ATC watch is controlling RCS parameters  You are the BOP operator  Both Startup Transformers are in service  Both Unit Auxiliary Transformers are in service in accordance with OP-006-008, Transformer Operation.
INITIATING CUE:
The CRS directs you to transfer auxiliaries from the Startup Transformers to the Unit Auxiliary Transformers in accordance with OP-006-001, section 6.3.
 
JPM S6 Revision 0 Page 5 of 10 2015 NRC Exam EXAMINER NOTE Cue the Simulator Operator to place the Simulator in RUN. Task Elements 1-8 are performed using OP-006-001, Plant Distribution (7KV, 4KV and SSD) System.
TASK ELEMENT 1 STANDARD 6.3.1 Transfer from Startup Transformer (SUT) A to Unit Auxiliary Transformer (UAT) A as follows: 6.3.1.1 Verify Unit Auxiliary Transformer A in service in accordance with OP-006-008, Transformer Operation. Verified with initial conditions Comment:  EXAMINER CUE:  If asked, provide cue that the both UAT are in service in accordance with OP-006-008, Transformer Operation SAT  /  UNSAT TASK ELEMENT 2 STANDARD 6.3.1.2 Verify all fault relays Reset on CP-15 for Unit Auxiliary Transformer A. Fault Relays verified reset Comment:  SAT  /  UNSAT TASK ELEMENT 3 STANDARD 6.3.1.3 Place Bus A Transfer switch to UAT. Bus A transfer switch in UAT Comment:  Critical SAT  /  UNSAT TASK ELEMENT 4 STANDARD 6.3.1.3.1 Verify the following Startup Transformer A breakers Open:  7KV-EBKR-1A-4 Startup Transformer A 7KV Isolation  4KV-EBKR-2A-4 Startup Transformer A 4KV Isolation 7KV-EBKR-1A-4 and 4KV-EBKR-2A-4 checked open Comment:    SAT  /  UNSAT
 
JPM S6 Revision 0 Page 6 of 10 2015 NRC Exam TASK ELEMENT 5 STANDARD 6.3.1.3.2 Verify the following Unit Auxiliary Transformer A breakers Closed:  7KV-EBKR-1A-1 Unit Auxiliary Transformer A 7KV Isolation  4KV-EBKR-2A-1 Unit Auxiliary Transformer A 4KV Isolation Verifies the breakers are closed Comment:  SAT  /  UNSAT TASK ELEMENT 6 STANDARD 6.3.2 Transfer from Startup Transformer (SUT) B to Unit Auxiliary Transformer (UAT) B as follows: 6.3.2.1 Verify Unit Auxiliary Transformer B in service in accordance with OP-006-008, Transformer Operation. Verified with initial conditions Comment:  SAT  /  UNSAT TASK ELEMENT 7 STANDARD 6.3.2.2 Verify all fault relays Reset on CP-15 for Unit Auxiliary Transformer B. Fault Relays verified reset Comment:  SAT  /  UNSAT EXAMINER NOTE The fault is inserted at the following step and these steps should be performed from memory.
TASK ELEMENT 8 STANDARD 6.3.2.3 Place Bus B Transfer switch to UAT. Bus B transfer switch in UAT Comment:  Critical SAT  /  UNSAT
 
JPM S6 Revision 0 Page 7 of 10 2015 NRC Exam TASK ELEMENT 9 STANDARD Recognize Turbine and Reactor Trip, proceed to SPTAs Steps for OP-902-000, Standard Post Trip Actions, are commenced. Comment:  EXAMINER NOTE: Alternate Path Begins Here EXAMINER CUE:  Provide cue to applicant to perform Standard Post Trip Actions as the Balance of Plant Operator SAT  /  UNSAT TASK ELEMENT 10 STANDARD 2. Determine that Maintenance of Vital Auxiliaries acceptance criteria are met: a. Check the Main Turbine is tripped: Governor valves closed Throttle valves closed Governor valves and throttle valves checked closed Comment:    SAT  /  UNSAT TASK ELEMENT 11 STANDARD b. Check the Main Generator is tripped: ERATOR BREAKER A tripped ERATOR BREAKER B tripped ITER FIELD BREAKER tripped Determined Generator Breaker B is closed and proceeded to contingency Comment:  SAT  /  UNSAT
 
JPM S6 Revision 0 Page 8 of 10 2015 NRC Exam TASK ELEMENT 12 STANDARD b.1 Perform ANY of the following: 1) Manually trip the Main Generator using BOTH GENERATOR EMERG TRIP pushbuttons. 2) Manually trip the Main Generator by performing ALL of the following:
: a. Transfer BOTH electrical buses from UAT to SUT. b. Open the following breakers: ERATOR BREAKER A ERATOR BREAKER B ITER FIELD BREAKER Pushed Both Generator emergency Trip pushbuttons or opened Generator Breaker B Comment:  EXAMINER NOTE: Applicant will be successful either by pushing both Generator Emergency pushbuttons or manually tripping the Generator output breaker. Preferred order would be using the Generator Pushbuttons as they are numbered steps. The motoring of the Generator isolated offsite power due to the breaker failure to open scheme so the Generator is no longer motoring after offsite power was lost to the B busses.
SAT  /  UNSAT TASK ELEMENT 13 STANDARD c. Check station loads are energized from offsite electrical power as follows: Train A 1, 6.9 KV non safety bus 2, 4.16 KV non safety bus A3, 4.16 KV safety bus A-DC electrical bus or C vital AC Instrument Channel Train B 1, 6.9 KV non safety bus 2, 4.16 KV non safety bus B3, 4.16 KV safety bus B-DC electrical bus or D vital AC Instrument Channel Recognized bus B3 deenergized and proceeded to contingency Comment:  SAT  /  UNSAT
 
JPM S6 Revision 0 Page 9 of 10 2015 NRC Exam TASK ELEMENT 14 STANDARD c.1 IF ANY 4.16 KV safety bus is NOT powered from offsite, THEN: 1) Verify associated EDG has started AND EDG output breaker closed.
: 2) IF EDG output breaker is NOT closed THEN: erify stable EDG Voltage 3920 - 4350 AC Volts. Verify 3-2 Breaker open. Check Sequencer LOCKOUT NOT illuminated.
: 3) IF EDG output breaker is NOT closed AND Step c.1.2) is met THEN locally close EDG output breaker. 4) Verify CCW cooling available to EDG. Determined EDG output Breaker not closed, EDG Voltage checked and determined to be out of the band low, adjusted voltages to within the band, verified 3-2 tie breaker open, checked sequencer lockout not illuminated, and checked CCW pump running for B EDG. Comment:  EXAMINER NOTE: Only the adjustment of EDG voltage is critical for task completion. The EDG B output breaker will auto closed when voltage is within the band. Examiner NOTE: The JPM is complete once the EDG B output breaker has closed. Critical SAT  /  UNSAT END OF TASK JPM S6 Revision 0 Page 10 of 10 2015 NRC Exam SIMULATOR OPERATOR INSTRUCTIONS
: 1. Reset to IC-169
: 2. RESET ANY FAULT RELAYS ON CP-15 BETWEEN EACH RESET FOR THIS JPM  3. RESET SIMULATOR LIGHTING BETWEEN EACH RESET FOR THIS JPM  4. Verify the following (Should be loaded in IC): a. EG04B, MAIN GENERATOR B OUTPUT BREAKER FAILS TO OPEN (Active) b. EG04B is set to delete in 1 second on Event Trigger 2 c. EG13B, EDG B AUTO VOLTAGE REG FAILED LO, tied to Event Trigger 1 (Inactive) d. ED02F, LOSS OF UAT-B TRANSFORMER tied to Event Trigger 1 (Inactive)
: 5. Ensure Event Trigger 1 is inserted as follows (Should be loaded in IC) a. Event - UAT/SUT B SWITCH in UAT b. Code is ZDIEDSTECS2235(1) == 1
: 6. Ensure Event Trigger 2 is inserted as follows: (Should be loaded in IC) a. Event - Generator Trip - Both Required b. Code is ZDIEGGENECS2201(1) == 1 & ZDIEGGENECS2205(1) ==
1    Setup with specific IC unavailable or for non NRC exams:
: 1. Reset the simulator to an IC with the turbine ready to sync to the Grid 2. Sync the turbine to the grid in accordance with OP-010-004 3. Adjust Generator load to obtain approximately 60 MWe 4. Stabilize plant conditions 5. Enter malfunctions and Triggers listed above
: 6. Place simulator in freeze and save IC
 
Operating Procedure OP-006-001 Plant Distribution (7KV, 4KV and SSD) System Revision 316 5 3.0 PRECAUTIONS AND LIMITATIONS 3.1 PRECAUTIONS 3.1.1 If any electrical maintenance is being performed at any time when equipment is to be energized or power supplies are to be aligned, then particular consideration must be given to the possibility of backfeed to persons working. 3.1.2 No more than one incoming supply feeder per bus may be energized unless making live bus transfers from synchronized sources. 3.1.3 Priorto attempting any bus transfer, supply power should be verified available from the source that will be transferred to. Interlocks mustnot be relied upon. 3.1.4 Priorto attempting to cross-connect the following switchgear, the switchgear being cross-connected must be verified deenergized from its primary source:  SSD-ESWGR-21A, Switchgear 21A, to SSD-ESWGR-21B, Switchgear 21B  SSD-ESWGR-22A, Switchgear 22A, to SSD-ESWGR-22B, Switchgear 22B  SSD-ESWGR-4A, Switchgear 4A, to SSD-ESWGR-4B, Switchgear 4B 3.1.5 Priorto attempting to restore the primary source of power to the following switchgear, the switchgear being restored to its primary source must be verified deenergized from its respective cross-connected source:  SSD-ESWGR-21A Switchgear 21A  SSD-ESWGR-21B Switchgear 21B  SSD-ESWGR-22A Switchgear 22A  SSD-ESWGR-22B Switchgear 22B  4KV-ESWGR-4A Switchgear 4A  4KV-ESWGR-4B  Switchgear 4B 3.1.6 Transfer of power source to the following busses and motor control centers (MCCs) will be a dead bus transfer. Components fed from these busses will be deenergized during transfer:  4KV-ESWGR-3AB Switchgear 3AB  SSD-ESWGR-31AB Switchgear 31AB  SSD-EMCC-222AB Motor Control Center 222AB 3.1.7 The Main Turbine Generator must be shut down before attempting a backfeed of the Main Transformers to supply plant auxiliaries.
Operating Procedure OP-006-001 Plant Distribution (7KV, 4KV and SSD) System Revision 316 6 3.1.8 Security Diesel Generator engine radiator fill cap may only be removed if radiator coolant temperature is below its boiling point. Extreme care must be taken when coolant is hot to ensure the radiator is not under pressure by loosening fill cap to the vent position before fully removing it. 3.1.9 Security Diesel Generator engine oil pressure should rise to > 20 PSIG within 10 seconds of starting. If Security Diesel Generator engine oil pressure is < 20 PSIG after 10 seconds, then Security Diesel Generator should be secured immediately by placing the Automatic/Manual select toggle switch to Automatic. 3.1.10 If the Security Diesel Generator engine is stopped at any time while operating under load, andthe load contactor is verified open, then an attempt should be made to re-start it by placing Automatic/Manual select toggle switch to OFF & RESET, then back to MANUAL. This is to allow cooldown with no load to prevent overheating of turbocharger parts. 3.1.11 Isophase Bus duct fans must be danger tagged in accordance with OP-102, Protective and Caution Tagging, priorto removing Main Generator disconnect links to prevent introducing dust and debris into Isophase Bus. As a minimum, the following breakers must be tagged:  GEN-EBKR-211A-2H Isophase Bus Duct Exhaust Fan  GEN-EBKR-212A-3M Isophase Bus Duct Supply Fan A  GEN-EBKR-212B-3M Isophase Bus Duct Supply Fan B 3.1.12 Proper Personnel Protection Equipment and safety requirements are required in accordance with EN-IS-123, Electrical Safety, when closing any of the following breakers with the breaker cubicle door open:  SSD-EBKR-21A-4B Switchgear 21A Feeder  SSD-EBKR-21B-4B Switchgear 21B Feeder  SSD-EBKR-21B-4C Switchgear 21B Tie To Switchgear 21A 3.2 LIMITATIONS
 
====3.2.1 Appropriate====
guidelines have been incorporated into this procedure to ensure compliance with EN-OP-116. The following sections have been identified as infrequently performed tests or evolutions in accordance with EN-OP-116, Infrequently Performed Tests or Evolutions:  Section 8.4, Backfeed of Main Transformers to Supply Plant Auxiliaries  Section 8.5, Restoration of Main Transformers for Normal Service 3.2.2 Gretna Transmissions Operations Center operates equipment in the Switchyard and will require notification to realign breakers S7172, S7176, S7182, and S7186, if necessary.
Operating Procedure OP-006-001 Plant Distribution (7KV, 4KV and SSD) System Revision 316 7 3.2.3 If the Security Diesel Generator engine cranks for 30 seconds without starting, then the Security Diesel Generator should be stopped by placing Automatic/Manual select toggle switch to Automatic. 3.2.4 The Security Diesel Fuel Oil Tank should not be allowed to run out of fuel. If Security Diesel Generator engine stops due to lack of fuel supply, then it may necessitate refilling and bleeding of engine fuel lines. 3.2.5 If during startup or operation of the Security Diesel Generator there is a significantly noticeable diesel exhaust plume that is visible for >6 minutes in any consecutive 60 minute period, then UNT-006-010, Event Notification and Reporting, must be complied with. 3.2.6 When closing any of the following breakers with the breaker fully racked in, the door on the front of the breaker cubicle must be open and the Close Latch on the breaker must be depressed (similar to discharging the closing springs when these breakers are fully racked out). The black Close button on the front of the breaker only works in the test position:  SSD-EBKR-21A-4B Switchgear 21A Feeder  SSD-EBKR-21B-4B Switchgear 21B Feeder  SSD-EBKR-21B-4C Switchgear 21B Tie To Switchgear 21A Operating Procedure OP-006-001 Plant Distribution (7KV, 4KV and SSD) System Revision 316 24 6.3 TRANSFER F ROM STARTUP TO U NIT AUXILIARY TRANSFORMER
[C] 6.3.1 Transfer from Startup Transformer (SUT) A to Unit Auxiliary Transformer (UAT) A as follows:
6.3.1.1 Verify Unit Auxiliary Transformer A in service in accordance with  OP-006-008, Transformer Operation.
6.3.1.2 Verify all fault relays Reset on CP-15 for Unit Auxiliary Transformer A.
6.3.1.3 Place Bus A Transfer switch to UAT.
6.3.1.3.1 Verify the following Startup Transformer A breakers Open:  7KV-EBKR-1A-4 Startup Transformer A 7KV Isolation  4KV-EBKR-2A-4 Startup Transformer A 4KV Isolation 6.3.1.3.2 Verify the following Unit Auxiliary Transformer A breakers Closed:  7KV-EBKR-1A-1 Unit Auxiliary Transformer A 7KV Isolation  4KV-EBKR-2A-1 Unit Auxiliary Transformer A 4KV Isolation 6.3.2 Transfer from Startup Transformer (SUT) B to Unit Auxiliary Transformer (UAT) B as follows: 6.3.2.1 Verify Unit Auxiliary Transformer B in service in accordance with OP-006-008, Transformer Operation.
6.3.2.2 Verify all fault relays Reset on CP-15 for Unit Auxiliary Transformer B.
6.3.2.3 Place Bus B Transfer switch to UAT.
6.3.2.3.1 Verify the following Startup Transformer B breakers Open:  7KV-EBKR-1B-4 Startup Transformer B 7KV Isolation  4KV-EBKR-2B-4 Startup Transformer B 4KV Isolation 6.3.2.3.2 Verify the following Unit Auxiliary Transformer B breakers Closed:  7KV-EBKR-1B-1 Unit Auxiliary Transformer B 7KV Isolation  4KV-EBKR-2B-1 Unit Auxiliary Transformer B 4KV Isolation 
 
Operating ProcedureOP-006-001Plant Distribution (7KV, 4KV and SSD) SystemRevision 316 246.3 TRANSFER F ROM STARTUP TO UNIT AUXILIARY TRANSFORMER
[C]6.3.1 Transfer from Startup Transformer (SUT) A to Unit Auxiliary Transformer (UAT) Aas follows:
6.3.1.1Verify Unit Auxiliary Transformer A in service in accordance withOP-006-008, Transformer Operation.
6.3.1.2Verify all fault relays Reset on CP-15 for Unit Auxiliary Transformer A.
6.3.1.3Place Bus A Transfer switch to UAT.
6.3.1.3.1Verify the following Startup Transformer A breakers Open: 7KV-EBKR-1A-4Startup Transformer A 7KV Isolation 4KV-EBKR-2A-4Startup Transformer A 4KV Isolation 6.3.1.3.2Verify the following Unit Auxiliary Transformer A breakers Closed: 7KV-EBKR-1A-1Unit Auxiliary Transformer A 7KV Isolation 4KV-EBKR-2A-1Unit Auxiliary Transformer A 4KV Isolation6.3.2 Transfer from Startup Transformer (SUT) B to Unit Auxiliary Transformer (UAT) Bas follows:6.3.2.1 Verify Unit Auxiliary Transformer B in service in accordance with OP-006-008,Transformer Operation.
6.3.2.2Verify all fault relays Reset on CP-15 for Unit Auxiliary Transformer B.
6.3.2.3Place Bus B Transfer switch to UAT.
6.3.2.3.1Verify the following Startup Transformer B breakers Open: 7KV-EBKR-1B-4Startup Transformer B 7KV Isolation 4KV-EBKR-2B-4Startup Transformer B 4KV Isolation 6.3.2.3.2Verify the following Unit Auxiliary Transformer B breakers Closed: 7KV-EBKR-1B-1Unit Auxiliary Transformer B 7KV Isolation 4KV-EBKR-2B-1Unit Auxiliary Transformer B 4KV Isolation STANDARD POST TRIP ACTIONSOP-902-000Revision15 Page 6 of 15WATERFORD 3 SESVerify Maintenance of Vital Auxiliaries___2.Determine that Maintenance of VitalAuxiliaries acceptance criteria aremet:___a.Check the Main Turbine istripped:Governor valves closedThrottle valves closed___b.Check the Main Generator istripped:GENERATOR BREAKER AtrippedGENERATOR BREAKER BtrippedEXCITER FIELD BREAKERtripped(continue)a.1PerformANY of the following:1)Manually trip the Main Turbineusing TURBINE TRIP andTHINK pushbuttons.2)CloseBOTH MSIVs.b.1PerformANY of the following:1)Manually trip the MainGenerator usingBOTHGENERATOR EMERG TRIPpushbuttons.2)Manually trip the MainGenerator by performing ALLof the following:a.TransferBOTH electricalbuses from UAT to SUT.b.Open the following breakers:GENERATORBREAKER AGENERATORBREAKER BEXCITERFIELDBREAKERINSTRUCTIONSCONTINGENCY ACTIONS STANDARD POST TRIP ACTIONSOP-902-000Revision15 Page 7 of 15WATERFORD 3 SES 2.(continued)___c.Check station loads areenergized from offsite electricalpower as follows:Train AA1, 6.9 KV non safety busA2, 4.16 KV non safety busA3, 4.16 KV safety busA-DC electrical busA or C vital AC InstrumentChannelTrain BB1, 6.9 KV non safety busB2, 4.16 KV non safety busB3, 4.16 KV safety busB-DC electrical busB or D vital AC InstrumentChannel c.1IFANY 4.16 KV safety bus is NOT powered from offsite, THEN:1)Verify associated EDG has started AND EDG output breaker closed.
2)IF EDG output breaker is NOT closedTHEN:Verify stable EDG Voltage3920 - 4350 AC Volts.Verify 3-2 Breaker open.Check SequencerLOCKOUT NOT illuminated.
3)IF EDG output breaker is NOT closed AND Step c.1.2) is metTHEN locally closeEDG output breaker.4)Verify CCW cooling available to EDG.INSTRUCTIONSCONTINGENCY ACTIONS Waterford 3 2014 AUDIT Exam JOB PERFORMANCE MEASURE S7  Functional Check of Startup Channel Applicant:
Examiner:
 
JPM S7 Revision 0 Page 2 of 9 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Perform Range check functional test of Startup Channel 1 Task Standard: Range Check Functional test complete for Startup Channel 1
 
==References:==
OP-903-101, Startup Channel Functional Test Channel 1 and 2, Rev 8  Alternate Path:
No Time Critical:
No Validation Time:
18 min. K/A 015 A3.03, Verification of proper  Importance Rating 3.9 / 3.9 functioning/operability RO / SRO  Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM S7 Revision 0 Page 3 of 9 2015 NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-903-101, Startup Channel Functional Test Channel 1 and 2 Handout 1 This JPM is performed concurrently with S5.
 
== Description:==
 
The JPM begins with the plant in Mode 3 and stable. The applicant will be directed to perform Surveillance procedure OP-903-101 for range checks on Startup Channel 1. This JPM takes place at CP-2 and CP-12. There are no malfunctions associated with this JPM.
DIRECTIONS TO APPLICANT:
I will explain the initial conditions, and state the 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 actions when directed by you. Indicate to me when you understand your assigned task.
(Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM S7 Revision 0 Page 4 of 9 2015 NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The plant is in Mode 3 INITIATING CUE:
The CRS directs you, to perform section 7.2 for Range Checks only for Startup Channel 1 in accordance with OP-903-101, Startup Channel Functional Test Startup Channel 1 and 2.
 
JPM S7 Revision 0 Page 5 of 9 2015 NRC Exam EXAMINER NOTE When Applicant is ready, cue the simulator operator to place the simulator in RUN.
TASK ELEMENT 1 STANDARD 7.2 RANGE CHECKS 7.2.1 Momentarily depress local Trouble bistable lamp, verify Trouble bistable lamp is extinguished and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. Button depressed and documented on Att. 10.1 Comment:    SAT  /  UNSAT TASK ELEMENT 2 STANDARD 7.2.2 Place AUDIO COUNT CHANNEL SELECT switch (CP-2) to the channel not being tested. Select switch in Channel 2 Comment:  Critical SAT  /  UNSAT TASK ELEMENT 3 STANDARD 7.2.3 Place OPERATE/TEST LOW/TEST HIGH switch in Test Low and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. Switch in Test Low and documented on Att. 10.1 Comment:  Critical SAT  /  UNSAT TASK ELEMENT 4 STANDARD 7.2.4 Verify local Trouble bistable lamp is illuminated and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. bistable verified and data recorded Comment:    SAT  /  UNSAT
 
JPM S7 Revision 0 Page 6 of 9 2015 NRC Exam TASK ELEMENT 5 STANDARD 7.2.5 Verify Control/Startup Channel 1(2) Trouble annunciator Alarms (M-3 (M-4), Cabinet H) and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. Annunciator verified and data recorded Comment:    SAT  /  UNSAT TASK ELEMENT 6 STANDARD 7.2.6 Record the following Startup Channel 1(2) indications and document on Attachment 10.1, Startup Channel Functional Test Data Sheet:  Drawer local counts  Remote recorder ENI-IJR-0005 (0006)  Remote meter ENI-IJI-0005 (0006) data recorded Comment:  Critical SAT  /  UNSAT TASK ELEMENT 7 STANDARD 7.2.7 Place OPERATE/TEST LOW/TEST HIGH switch to Test-High and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. Switch in Test High and data recorded Comment:  Critical SAT  /  UNSAT TASK ELEMENT 8 STANDARD 7.2.8 Verify Channel 1(2) Neutron Flux High annunciator Alarms (K-3 (K-4), Cabinet H) and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. Annunciator verified and data recorded Comment:    SAT  /  UNSAT
 
JPM S7 Revision 0 Page 7 of 9 2015 NRC Exam TASK ELEMENT 9 STANDARD 7.2.9 Verify RCS Boron Channel 1(2) Dilution Hi annunciator Alarms (L-3 (L-4), Cabinet G) and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. Annunciator verified and data recorded Comment:    SAT  /  UNSAT TASK ELEMENT 10 STANDARD 7.2.10 Record following Startup Channel 1(2) indications and document on Attachment 10.1, Startup Channel Functional Test Data Sheet:  Drawer local counts  Remote recorder ENI-IJR-0005 (0006)  Remote meter ENI-IJI-0005 (0006) data recorded Comment:  Critical SAT  /  UNSAT TASK ELEMENT 11 STANDARD 7.2.11 Place OPERATE/TEST LOW/TEST HIGH switch in Operate and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. Switch in Operate and data recorded Comment:  Critical SAT  /  UNSAT TASK ELEMENT 12 STANDARD 7.2.12 Momentarily depress local Trouble bistable lamp, verify Trouble bistable lamp is extinguished and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. Button depressed, bistable verified and data recorded Comment:  Critical SAT  /  UNSAT
 
JPM S7 Revision 0 Page 8 of 9 2015 NRC Exam TASK ELEMENT 13 STANDARD 7.2.13 Verify Control/Startup Channel 1 (2) Trouble annunciator (M-3 (M-4), Cabinet H) is clear and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. Annunciator verified and data recorded Comment:    SAT  /  UNSAT TASK ELEMENT 14 STANDARD 7.2.14 Verify Channel 1 (2) Neutron Flux High annunicator (K-3 (K-4), Cabinet H) is clear and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. Annunciator verified and data recorded Comment:    SAT  /  UNSAT TASK ELEMENT 15 STANDARD 7.2.15 Verify RCS Boron Channel 1 (2) Dilution Hi annunciator (L-3 (L-4), Cabinet G) is clear and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. Annunciator verified and data recorded Comment:    SAT  /  UNSAT END OF TASK
 
JPM S7 Revision 0 Page 9 of 9 2015 NRC Exam SIMULATOR OPERATOR INSTRUCTIONS
: 1. Reset to IC-168
: 2. Place Simulator in Run on Lead Examiner's cue
: 3. For 2015 NRC Exam, JPM S5 is performed concurrently
: 4. For 2015 NRC Exam, ensure the applicant travels to CP-12 in a direction that limits encounters with the applicant performing S5.
There are no malfunctions associated with this JPM Setup with specific IC unavailable or for non NRC/AUDIT exams:
: 1. Reset the simulator to an IC in Mode 3 2. Allow simulator to run until all conditions stabilize 3. Acknowledge annunciators 4. Place simulator in freeze and save IC
 
OP-903-101  Revision 008 Attachment 10.1 (1 of 3) 1 10.1 STARTUP C HANNEL FUNCTIONAL TEST DATA SHEET Startup Channel _____1 and ____2  (Check Applicable Space)
Permission: Joe Supervisor________/_____Today/Now_____________
WO#:___123456_______________
SM/CRS Date/Time  STEP DESCRIPTION INITIALS  STARTUP CHANNEL HIGH VOLTAGE T EST  7.1.1 Startup HV Low lamp is extinguished.
_____N/A__    7.1.2 Startup HV On lamp is illuminated.
_____N/A__    7.1.3 Startup HV Off lamp is extinguished.
_____N/A__    7.1.4 STARTUP HV X 3/CONTROL HV X 1 switch in Startup HV X 3 .
_____N/A__    7.1.5 Startup High Voltage meter reading: _______ VDC  (600 to 800 VDC).
_____N/A__    RANGE CHECKS  7.2.1 Local Trouble bistable lamp is extinguished. __________
 
====7.2.3 Place====
OPERATE/TEST LOW/TEST HIGH switch to Test-Low. __________
 
====7.2.4 Local====
Trouble bistable lamp is illuminated. __________
7.2.5 Control/Startup Channel 1(2) Trouble alarms (M-3 (M-4), Cabinet H). __________
 
====7.2.6 LOCATION====
REQUIRED ACTUAL  Drawer local counts 5 x 10 1 to 2 x 10 2 CPS __________ CPS __________
Remote recorder ENI-IJR-0005 (0006) 5 x 10 1 to 2 x 10 2 CPS __________ CPS __________
Remote meter ENI-IJI-0005 (0006) 5 x 10 1 to 2 x 10 2 CPS __________ CPS __________
OP-903-101  Revision 008 Attachment 10.1 (2 of 3) 2 10.1 STARTUP CHANNEL FUNCTIONAL T EST DATA SHEET (C ONT'D) Startup Channel _____1 and ____2  (Check Applicable Space)
STEP DESCRIPTION INITIALS  RANGE CHECKS (C ONT'D)  7.2.7 Place OPERATE/TEST LOW/TEST HIGH switch to Test-High. __________
 
====7.2.8 Channel====
1(2) Neutron Flux High alarms (K-3 (K-4), Cabinet H).
__________
7.2.9 RCS Boron Chnl 1(2) Dilution Hi alarms (L-3 (L-4), Cabinet G). __________
7.2.10 LOCATION REQUIRED ACTUAL  Drawer local counts 5 x 10 4 to 2 x 10 5 CPS __________ CPS __________
Remote recorder ENI-IJR-0005 (0006) 5 x 10 4 to not pegged hi
__________ CPS __________
Remote meter ENI-IJI-0005 (0006) 5 x 10 4 to not pegged hi
__________ CPS __________
7.2.11 Place OPERATE/TEST LOW/TEST HIGH switch in Operate. __________
7.2.12 Local Trouble bistable lamp is extinguished. __________
7.2.13 Control/Startup Channel 1 (2) Trouble annunciators (M-3(M-4), Cabinet H) are clear. __________
7.2.14 Channel 1 (2) Neutron Flux High annunciators (K-3(K-4) Cabinet H) are clear. __________
7.2.15 RCS Boron Channel 1 (2) Dilution Hi annunciator (L-3(L-4) Cabinet G) is clear. __________
 
OP-903-101  Revision 008 [LAST PAGE] Attachment 10.1 (3 of 3) 3 10.1 STARTUP CHANNEL FUNCTIONAL T EST DATA SHEET (C ONT'D) Startup Channel _____1 and ____2  (Check Applicable Space)
STEP DESCRIPTION INITIALS  AUDIBLE COUNT RATE
 
====7.3.1 Audible====
count rate is present on Channel 1:  Control Room __________
Containment __________
 
====7.3.2 Audible====
count rate is present on Channel 2:  Control Room __________
Containment __________
RESTORATION SWITCH POSITION PERFORMED IV 7.4.1.1 OPERATE/TEST LOW/TEST HIGH Operate __________ __________
7.4.1.2 ZERO/OPERATE/125%
Operate __________ __________
7.4.1.3 TRIP TEST Off __________ __________
T EST ACCEPTANCE: INITIAL  Startup Channel Functional Test performed satisfactory in accordance with Section 6.0, Acceptance Criteria. ________  Remarks:  ___________________________________________________________________________________________ ____________________________________________________________________________________________________ ____________________________________________________________________________________________________
Performed By:  ________________/________________
Operator Date/Time  IV By:  __________________/________________ Reviewed By:  _______________/_____________
Operator Date/Time  SM/CRS Date/Time Surveillance Procedure OP-903-101 Startup Channel Functional Test Startup Channel ___1 and ___2 Revision 008 5 3.0 PRECAUTIONS AND LIMITATIONS 3.1 PRECAUTIONS
 
====3.1.1 Verify====
only one Startup Drawer is under test at any given time. 3.2 LIMITATIONS 3.2.1 Do not energize Source Range High Voltage with Reactor Power >10
-6%. High Neutron Flux will destroy Startup BF 3 detectors over time (long term concern).
Surveillance Procedure OP-903-101 Startup Channel Functional Test Startup Channel ___1 and ___2 Revision 008 10 7.2 RANGE CHECKS 7.2.1 Momentarily depress local Trouble bistable lamp, verify Trouble bistable lamp is extinguished and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. 7.2.2 Place AUDIO COUNT CHANNEL SELECT switch (CP-2) to the channel not being tested. 7.2.3 Place OPERATE/TEST LOW/TEST HIGH switch in Test Low and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. 7.2.4 Verify local Trouble bistable lamp is illuminated and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. 7.2.5 Verify Control/Startup Channel 1(2) Trouble annunciator Alarms (M-3 (M-4), Cabinet H) and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. 7.2.6 Record the following Startup Channel 1(2) indications and document on Attachment 10.1, Startup Channel Functional Test Data Sheet:  Drawer local counts  Remote recorder ENI-IJR-0005 (0006)  Remote meter ENI-IJI-0005 (0006) 7.2.7 Place OPERATE/TEST LOW/TEST HIGH switch to Test-High and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. 7.2.8 Verify Channel 1(2) Neutron Flux High annunciator Alarms (K-3 (K-4), Cabinet H) and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. 7.2.9 Verify RCS Boron Channel 1(2) Dilution Hi annunciator Alarms (L-3 (L-4), Cabinet G) and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.
Surveillance Procedure OP-903-101 Startup Channel Functional Test Startup Channel ___1 and ___2 Revision 008 11 7.2.10 Record following Startup Channel 1(2) indications and document on Attachment 10.1, Startup Channel Functional Test Data Sheet:  Drawer local counts  Remote recorder ENI-IJR-0005 (0006)  Remote meter ENI-IJI-0005 (0006) 7.2.11 Place OPERATE/TEST LOW/TEST HIGH switch in Operate and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. 7.2.12 Momentarily depress local Trouble bistable lamp, verify Trouble bistable lamp is extinguished and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. 7.2.13 Verify Control/Startup Channel 1 (2) Trouble annunciator (M-3 (M-4), Cabinet H) is clear and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. 7.2.14 Verify Channel 1 (2) Neutron Flux High annunicator (K-3 (K-4), Cabinet H) is clear and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. 7.2.15 Verify RCS Boron Channel 1 (2) Dilution Hi annunciator (L-3 (L-4), Cabinet G) is clear and document on Attachment 10.1, Startup Channel Functional Test Data Sheet. 
 
Surveillance ProcedureOP-903-101Startup Channel Functional Test Startup Channel ___1 and ___2Revision 008 107.2 RANGE CHECKS7.2.1 Momentarily depress local Trouble bistable lamp, verify Trouble bistable lamp isextinguished and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.7.2.2 Place AUDIO COUNT CHANNEL SELECT switch (CP-2) to the channel not being tested.7.2.3 Place OPERATE/TEST LOW/TEST HIGH switch in Test Low and document onAttachment 10.1, Startup Channel Functional Test Data Sheet.7.2.4 Verify local Trouble bistable lamp is illuminated and document on Attachment10.1, Startup Channel Functional Test Data Sheet.7.2.5 Verify Control/Startup Channel 1(2) Trouble annunciator Alarms (M-3 (M-4),Cabinet H) and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.7.2.6 Record the following Startup Channel 1(2) indications and document onAttachment 10.1, Startup Channel Functional Test Data Sheet: Drawer local counts Remote recorder ENI-IJR-0005 (0006) Remote meter ENI-IJI-0005 (0006)7.2.7 Place OPERATE/TEST LOW/TEST HIGH switch to Test-High and document onAttachment 10.1, Startup Channel Functional Test Data Sheet.7.2.8 Verify Channel 1(2) Neutron Flux High annunciator Alarms (K-3 (K-4), Cabinet H) and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.7.2.9 Verify RCS Boron Channel 1(2) Dilution Hi annunciator Alarms (L-3 (L-4), Cabinet G) and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.
Surveillance ProcedureOP-903-101Startup Channel Functional Test Startup Channel ___1 and ___2Revision 008 117.2.10 Record following Startup Channel 1(2) indications and document on Attachment10.1, Startup Channel Functional Test Data Sheet: Drawer local counts Remote recorder ENI-IJR-0005 (0006) Remote meter ENI-IJI-0005 (0006)7.2.11 Place OPERATE/TEST LOW/TEST HIGH switch in Operate and document onAttachment 10.1, Startup Channel Functional Test Data Sheet.7.2.12 Momentarily depress local Trouble bistable lamp, verify Trouble bistable lamp isextinguished and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.7.2.13 Verify Control/Startup Channel 1 (2) Trouble annunciator (M-3 (M-4), Cabinet H) is clear and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.7.2.14 Verify Channel 1 (2) Neutron Flux High annunicator (K-3 (K-4), Cabinet H) is clear and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.7.2.15 Verify RCS Boron Channel 1 (2) Dilution Hi annunciator (L-3 (L-4), Cabinet G) is clear and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.
O P-9 0 3-1 0 1 R e v i s i o n 0 0 8 A t t a c h m e n t 1 0.1 (1 o f 3)1 7 1 0.1 S T A R T U P C H A N N E L F U N C T I O N A L T E S T D A T A S H E E T S t a r t u p C h a n n e l_____1 a n d_____2 (C h e c k A p p l i c a b l e S p a c e)P e r m i s s i o n:_______________________/__________________W O#:________________________S M/C R S D a t e/T i m e S T E P D E S C R I P T I O N I N I T I A L S S T A R T U P C H A N N E L H I G H V O L T A G E T E S T 7.1.1 S t a r t u p H V L o w l a m p i s e x t i n g u i s h e d.__________7.1.2 S t a r t u p H V O n l a m p i s i l l u m i n a t e d.__________7.1.3 S t a r t u p H V O f f l a m p i s e x t i n g u i s h e d.__________7.1.4 S T A R T U P H V X 3/C O N T R O L H V X 1 s w i t c h i n S t a r t u p H V X 3.__________7.1.5 S t a r t u p H i g h V o l t a g e m e t e r r e a d i n g:_______V D C (6 0 0 t o 8 0 0 V D C).__________R A N G E C H E C K S 7.2.1 L o c a l T r o u b l e b i s t a b l e l a m p i s e x t i n g u i s h e d.__________7.2.3 P l a c e O P E R A T E/T E S T L O W/T E S T H I G H s w i t c h t o T e s t-L o w.__________7.2.4 L o c a l T r o u b l e b i s t a b l e l a m p i s i l l u m i n a t e d.__________7.2.5 C o n t r o l/S t a r t u p C h a n n e l 1 (2)T r o u b l e a l a r m s (M-3 (M-4), C a b i n e t H).__________7.2.6 L O C A T I O N R E Q U I R E D A C T U A L D r a w e r l o c a l c o u n t s 5 x 1 0 1 t o 2 x 1 0 2 C P S__________C P S__________R e m o t e r e c o r d e r E N I-I J R-0 0 0 5 (0 0 0 6)5 x 1 0 1 t o 2 x 1 0 2 C P S__________C P S__________R e m o t e m e t e r E N I-I J I-0 0 0 5 (0 0 0 6)5 x 1 0 1 t o 2 x 1 0 2 C P S__________C P S__________
O P-9 0 3-1 0 1 R e v i s i o n 0 0 8 A t t a c h m e n t 1 0.1 (2 o f 3)1 8 1 0.1 S T A R T U P C H A N N E L F U N C T I O N A L T E S T D A T A S H E E T (C O N T'D)S t a r t u p C h a n n e l_____1 a n d_____2 (C h e c k A p p l i c a b l e S p a c e)S T E P D E S C R I P T I O N I N I T I A L S R A N G E C H E C K S (C O N T'D)7.2.7 P l a c e O P E R A T E/T E S T L O W/T E S T H I G H s w i t c h t o T e s t-H i g h.__________7.2.8 C h a n n e l 1 (2)N e u t r o n F l u x H i g h a l a r m s (K-3 (K-4), C a b i n e t H).__________7.2.9 R C S B o r o n C h n l 1 (2)D i l u t i o n H i a l a r m s (L-3 (L-4), C a b i n e t G).__________7.2.1 0 L O C A T I O N R E Q U I R E D A C T U A L D r a w e r l o c a l c o u n t s 5 x 1 0 4 t o 2 x 1 0 5 C P S__________C P S__________R e m o t e r e c o r d e r E N I-I J R-0 0 0 5 (0 0 0 6)5 x 1 0 4 t o n o t p e g g e d h i__________C P S__________R e m o t e m e t e r E N I-I J I-0 0 0 5 (0 0 0 6)5 x 1 0 4 t o n o t p e g g e d h i__________C P S__________7.2.1 1 P l a c e O P E R A T E/T E S T L O W/T E S T H I G H s w i t c h i n O p e r a t e.__________7.2.1 2 L o c a l T r o u b l e b i s t a b l e l a m p i s e x t i n g u i s h e d.__________7.2.1 3 C o n t r o l/S t a r t u p C h a n n e l 1 (2)T r o u b l e a n n u n c i a t o r s (M-3 (M-4), C a b i n e t H)a r e c l e a r.__________7.2.1 4 C h a n n e l 1 (2)N e u t r o n F l u x H i g h a n n u n c i a t o r s (K-3 (K-4)C a b i n e t H)a r e c l e a r.__________7.2.1 5 R C S B o r o n C h a n n e l 1 (2)D i l u t i o n H i a n n u n c i a t o r (L-3 (L-4)C a b i n e t G)i s c l e a r.__________
O P-9 0 3-1 0 1 R e v i s i o n 0 0 8[L A S T P A G E]A t t a c h m e n t 1 0.1 (3 o f 3)1 9 1 0.1 S T A R T U P C H A N N E L F U N C T I O N A L T E S T D A T A S H E E T (C O N T'D)S t a r t u p C h a n n e l_____1 a n d_____2 (C h e c k A p p l i c a b l e S p a c e)S T E P D E S C R I P T I O N I N I T I A L S A U D I B L E C O U N T R A T E 7.3.1 A u d i b l e c o u n t r a t e i s p r e s e n t o n C h a n n e l 1: C o n t r o l R o o m__________C o n t a i n m e n t__________7.3.2 A u d i b l e c o u n t r a t e i s p r e s e n t o n C h a n n e l 2: C o n t r o l R o o m__________C o n t a i n m e n t__________R E S T O R A T I O N S W I T C H P O S I T I O N P E R F O R M E D I V 7.4.1.1 O P E R A T E/T E S T L O W/T E S T H I G H O p e r a t e____________________7.4.1.2 Z E R O/O P E R A T E/1 2 5%O p e r a t e____________________7.4.1.3 T R I P T E S T O f f____________________T E S T A C C E P T A N C E: I N I T I A L S t a r t u p C h a n n e l F u n c t i o n a l T e s t p e r f o r m e d s a t i s f a c t o r y i n a c c o r d a n c e w i t h S e c t i o n 6.0 , A c c e p t a n c e C r i t e r i a.________R e m a r k s:___________________________________________________________________________________________________________________________________________________________________________________________________________________________________________________________________________________________________P e r f o r m e d B y:________________/________________O p e r a t o r D a t e/T i m e I V B y:__________________/________________R e v i e w e d B y:_______________/_____________O p e r a t o r D a t e/T i m e S M/C R S D a t e/T i m e Waterford 3 2015 NRC Exam JOB PERFORMANCE MEASURE S8  Placing Fuel Handling Building Emergency Filtration Unit A in Service Applicant:
Examiner:
 
JPM S8 Revision 0 Page 2 of 12 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Place FHB Emergency Filtration Unit A in service in accordance with OP-002-009, Fuel Handling Building HVAC.
Task Standard: Applicant aligned Fuel Handling Building Emergency Filtration Unit A to Service.
 
==References:==
OP-002-009, Fuel Handling Building HVAC, revision 13 Alternate Path:
No Time Critical:
No Validation Time:
20 min. K/A A4.01 Radiation levels  Importance Rating 3.3 / 3.7 RO / SRO  Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM S8 Revision 0 Page 3 of 12 2015 NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:  OP-002-009, Fuel Handling Building HVAC, revision 13
 
== Description:==
This task takes place at CP-18. The applicant will secure FHB Normal HVAC  and then place FHB Emergency Filtration Unit A is in service.
This JPM is to be performed concurrently with S2.
DIRECTIONS TO APPLICANT:
I will explain the initial conditions, and state the 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 actions when directed by you. Indicate to me when you understand your assigned task.
(Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
 
JPM S8 Revision 0 Page 4 of 12 2015 NRC Exam APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The plant is in Mode 3 INITIATING CUE:
The CRS directs you to Place FHB Emergency Filtration Unit A in service in accordance with section 6.3 of OP-002-009, Fuel Handling Building HVAC
 
JPM S8 Revision 0 Page 5 of 12 2015 NRC Exam EXAMINER NOTE Cue the Simulator Operator to place the Simulator in RUN. This JPM is performed concurrently with S2.
TASK ELEMENT 1 STANDARD 6.3 Placing FHB Emergency Filtration Unit in Service: Procedure Note: FHB Normal HVAC is maintained in service to provide air cooling to equipment located in non-rad areas. Note reviewed Comment:  SAT  /  UNSAT TASK ELEMENT 2 STANDARD Procedure Caution: (1) SECURE FHB NORMAL HVAC IF EITHER OF THE FOLLOWING OCCURS:  FHB EXHAUST RAD MONITOR FOR THE RUNNING FHB NORMAL EXHAUST FAN SHOWS AN UNEXPLAINED INCREASE IN RADIATION LEVELS,  OR  RADIATION PROTECTION REPORTS AN INCREASE IN RADIATION LEVELS IN NON-RAD AREAS OF FHB (2) IF PAINTING IS IN PROGRESS, OR FIRE OR CHEMICAL RELEASE OCCURS INSIDE THE FHB, THEN FHB EMERGENCY FILTRATION UNITS SHOULD NOT BE RUN FOR NON-EMERGENCY PURPOSES (3) GUIDANCE CONTAINED IN PRECAUTION 3.1.3 OF THIS PROCEDURE LISTS COMPONENTS SUCH AS DOORS AND FLOOR PLUGS THAT AFFECT OPERABILITY OF FHB EMERGENCY FILTRATION UNITS. Caution reviewed Comment:  SAT  /  UNSAT
 
JPM S8 Revision 0 Page 6 of 12 2015 NRC Exam TASK ELEMENT 3 STANDARD 6.3.1 Notify Radiation Protection of Placing FHB Emergency Filtration Unit in Service. RP notified Comment:  SAT  /  UNSAT TASK ELEMENT 4 STANDARD 6.3.2 Remove FHB Normal HVAC from Service in accordance with Section 7.1, Removing FHB Normal HVAC from Service. Applicant transitions to section 7.1 to remove FHB Normal HVAC from service Comment: Instructor Note. The applicant will transition to section 7.1 of OP-002-009 to secure FHB Normal Ventilation SAT  /  UNSAT TASK ELEMENT 5 STANDARD 7.1 Removing FHB Normal HVAC from service Procedure Note: Fire detection instruments FPDEDETFHB-26R and FPDEDETFHB-26T may initiate alarms when FHB HVAC is secured for extended periods of time due to increase in humidity. Fire detection should be impaired in accordance with FP-001-015 and disarmed at the FDMCP if this occurs Note reviewed Comment:  SAT  /  UNSAT TASK ELEMENT 6 STANDARD 7.1.1 Notify Radiation Protection of Removing FHB Normal HVAC from Service. RP notified Comment:  SAT  /  UNSAT
 
JPM S8 Revision 0 Page 7 of 12 2015 NRC Exam TASK ELEMENT 7 STANDARD 7.1.2 If FHB Normal Exhaust Fan will be secured for an extended period of time (> 1 hr), then Notify Maintenance Support to secure the Temporary Chiller. Step is reviewed Comment: Instructor Note: If asked of 1 hour duration, inform the applicant that FHB Normal Exhaust will not be secured > 1 hr.
SAT  /  UNSAT TASK ELEMENT 8 STANDARD 7.1.3 Denote which FHB Normal Exhaust Fan is being stopped (circle one): A B 7.1.3.1 Place control switch for the running FHB Normal Exhaust Fan, HVF-0003A(B),  to STOP Stopped FHB Normal Exhaust Fan A Comment: Instructor Note: Placing the control switch for the FHB Normal Exhaust Fan, HVF-0003A, to STOP is the critical portion of this step.
Critical SAT  /  UNSAT TASK ELEMENT 9 STANDARD 7.1.4 Verify FHB Exhaust Fan A(B) Inlet Damper CLOSED:  HVF-111A (PID D53642) or  HVF-111B (PID D53643)
FHB Exhaust Fan A Inlet damper (HVF-111A) is verified closed. Comment:
SAT  /  UNSAT TASK ELEMENT 10 STANDARD 7.1.5 Place control switch for FHB Normal Supply Fan, HVF-0002, to STOP. Stopped the FHB Normal Supply fan Comment:  Critical SAT  /  UNSAT
 
JPM S8 Revision 0 Page 8 of 12 2015 NRC Exam TASK ELEMENT 11 STANDARD 7.1.6 Verify FHB Normal Supply Fan Inlet and Outlet Dampers CLOSED:  HVF-101 (PID D53641)  HVF-102 (PID D53668)
FHB Normal Supply Inlet and Outlet Dampers are verified closed Comment: Examiner Note: The applicant will transition back to OP-002-009 step 6.3.3  SAT  /  UNSAT TASK ELEMENT 12 STANDARD 6.3.3 Place both FHB Isol Damper control switches to CLOSE and verify the following dampers Close:  HVF-105 Spent Fuel Handling HVAC Upstream Supply Damper  HVF-106 Spent Fuel Handling HVAC Downstream Supply Damper  HVF-107 Spent Fuel Handling HVAC Upstream Return Damper  HVF-108  Spent Fuel Handling HVAC Downstream Return Damper Both FHB Isol Damper control switches taken to close and dampers verified closed. Comment: Examiner Note: Placing both FHB Isol Damper control switches to CLOSE is the critical portion of this step.
Critical SAT  /  UNSAT TASK ELEMENT 13 STANDARD 6.3.4  Place both FHB Vent Mode Select control switches to Bypass, and perform the following: 6.3.4.1 Verify the following dampers Closed:  HVF-103 FP Cool & Purif HVAC Supply Damper  HVF-104 FP Cool & Purif HVAC Supply Damper 6.3.4.2 Verify the following Open:  HVF-109 FP Cool & Purif HVAC Return Damper    HVF-110        FP Cool & Purif HVAC Return Damper  Both FHB Vent Mode Select control switches in bypass and dampers verified Comment: Examiner Note: Placing both FHB Vent Mode Select control switches to Bypass is the critical portion of this step. Critical SAT  /  UNSAT
 
JPM S8 Revision 0 Page 9 of 12 2015 NRC Exam TASK ELEMENT 14 STANDARD 6.3.5 Denote which FHB Emergency Fltr Unit(s) is being started (circle one):  A B  6.3.5.1 Place control switch for desired FHB Emergency Fltr Unit(s), HVF-0005A(B),  to START. Placed FHB EFU A to start. Comment: Instructor Note: Placing the control switch for FHB Emergency Fltr Unit A, HVF-0005A,  to START is the critical portion of this step.
Critical SAT  /  UNSAT TASK ELEMENT 15 STANDARD Procedure Caution: IF REQUIRED FHB EMERGENCY FILTRATION UNIT DIFFERENTIAL PRESSURE CANNOT BE ACHIEVED, EVEN THROUGH THE USE OF MANUAL ADJUSTMENTS TO THE INLET DAMPER HVFMVAAA202A(B), THEN A WORK REQUEST SHOULD BE GENERATED IN ACCORDANCE WITH WM-100, WORK ORDER GENERATION, SCREENING AND CLASSIFICATION. Caution reviewed Comment:  SAT  /  UNSAT TASK ELEMENT 16 STANDARD 6.3.6 Verify FHB Emergency Fltr Unit DP 8.7 to 9.2 INWC. Verified DP within the band Comment:    SAT  /  UNSAT
 
JPM S8 Revision 0 Page 10 of 12 2015 NRC Exam TASK ELEMENT 17 STANDARD 6.3.7 Denote which FHB H&V Exhaust Fan is being started (circle one):
A B  6.3.7.1  Place control switch for FHB H&V Exhaust Fan A(B), HVF-0006A(B), to START. One FHB H&V Exhaust Fan is started Comment: Instructor Note: Placing the control switch for FHB H&V Exhaust Fan A(B), HVF-0006A(B), to START is the critical portion of this step. Critical SAT  /  UNSAT TASK ELEMENT 18 STANDARD 6.3.8 Verify FHB H&V Room Exhaust Fan A(B) Intake Damper Open:  HVF-301A PID D53664 OPEN PID D53665 NT CLSD or  HVF-301B PID D53666 OPEN PID D53667 NT CLSD  Verified intake dampers open for the exhaust fan that was started. Comment:    SAT  /  UNSAT TASK ELEMENT 19 STANDARD 6.3.9 Verify Sample Pump running for FHB Emergency Exhaust WRGM, PRM-IRI-3032, at either CP-6 or CP-52. Sample pump started Comment: Examiner Note: Direct the applicant to CP-52 such that the other JPM is not interfered with.
Critical SAT  /  UNSAT
 
JPM S8 Revision 0 Page 11 of 12 2015 NRC Exam TASK ELEMENT 20 STANDARD 6.3.10 Monitor applicable Range and Effluent Level for FHB Emergency Exhaust WRGM, PRM-IRI-3032, at either CP-6 or CP-52.. Step reviewed Comment: Instructor Note: If the applicant desires to pull a trend at the RM-11 station, inform the applicant that the ATC will monitor trends such as not to interfere with JPM S2.
SAT  /  UNSAT TASK ELEMENT 21 STANDARD 6.3.11 If radiation levels permit, then Place FHB Normal HVAC in Service in accordance with Section 6.1, Placing FHB Normal HVAC in Service. Step reviewed Comment: Examiner Note: Inform the applicant that another operator will place FHB Normal HVAC in service. This JPM is complete.
SAT  /  UNSAT END OF TASK JPM S8 Revision 0 Page 12 of 12 2015 NRC Exam SIMULATOR OPERATOR INSTRUCTIONS
: 1. Reset to IC-165 2. For 2015 NRC Exam, JPM S2 is performed concurrently.
 
System Operating Procedure OP-002-009 Fuel Handling Building HVAC Revision 013 4 3.0 PRECAUTIONS AND LIMITATIONS 3.1 PRECAUTIONS
 
====3.1.1 Operability====
requirements for FHB Radioactive Gaseous Effluent Monitoring instrumentation are given by Technical Specification 3.3.3.1 and Technical Requirement 3.3.3.11. 3.1.2 If painting is in progress, or fire or chemical release occurs inside the FHB, then FHB Emergency Filtration Units should not be run for non-emergency purposes. 3.1.3 With the exception of normal personnel transit of the FHB, both FHB Emergency Filtration Units are Inoperable when any of the doors or floor plugs listed below are Open, Propped Open or otherwise impaired (refer to OP-100-014):  DOOR #D037  +21 Q-Deck to FHB  DOOR #D067  +21 FHB to +1 FHB  DOOR #D068  +1 FHB Railroad Cargo Train Bay  DOOR #D069  +21 FHB to +46 FHB  DOOR #D069A  +30 FHB Access Area To Unloading Bay Door  DOOR #D187  +46 FHB Spent Fuel Pool Door  DOOR #D188  +1 FHB to +21 FHB  Floor Plug from FHB +46 to the FHB +21  Floor Plug from FHB +21 to the FHB +1 3.2 LIMITATIONS
 
====3.2.1 Notify====
Radiation Protection when changing FHB HVAC alignments. 3.2.2 If required FHB Emergency Filtration Unit differential pressure cannot be achieved, even through the use of manual adjustments to the inlet damper HVFMVAAA202A(B), then a Work Request should be generated in accordance with WM-100, Work Order Generation, Screening and Classification. 3.2.3 Fire detection instruments FPDEDETFHB-26R and FPDEDETFHB-26T may initiate alarms when FHB HVAC is secured for extended periods of time, due to increase in humidity. Fire detection should be impaired in accordance with FP-001-015 and disarmed at the Fire Detection Main Control Panel if this occurs.
System Operating Procedure OP-002-009 Fuel Handling Building HVAC Revision 013 9 6.3 PLACING FHB EMERGENCY FILTRATION UNIT IN SERVICE  NOTE FHB Normal HVAC is maintained in service to provide air cooling to equipment located in non-rad areas.
CAUTION (1) SECURE FHB NORMAL HVAC IF EITHER OF THE FOLLOWING OCCURS:  FHB EXHAUST RAD MONITOR FOR THE RUNNING FHB NORMAL EXHAUST FAN SHOWS AN UNEXPLAINED INCREASE IN RADIATION LEVELS,  OR  RADIATION PROTECTION REPORTS AN INCREASE IN RADIATION LEVELS IN NON-RAD AREAS OF FHB (2) IF PAINTING IS IN PROGRESS, OR FIRE OR CHEMICAL RELEASE OCCURS INSIDE THE FHB, THEN FHB EMERGENCY FILTRATION UNITS SHOULD NOT BE RUN FOR NON-EMERGENCY PURPOSES (3) GUIDANCE CONTAINED IN PRECAUTION 3.1.3 OF THIS PROCEDURE LISTS COMPONENTS SUCH AS DOORS AND FLOOR PLUGS THAT AFFECT OPERABILITY OF FHB EMERGENCY FILTRATION UNITS. 6.3.1 Notify Radiation Protection of Placing FHB Emergency Filtration Unit in Service. 6.3.2 Remove FHB Normal HVAC from Service in accordance with Section 7.1, Removing FHB Normal HVAC from Service. 6.3.3 Place both FHB Isol Damper control switches to CLOSE and verify the following dampers Close:  HVF-105 Spent Fuel Handling HVAC Upstream Supply Damper  HVF-106 Spent Fuel Handling HVAC Downstream Supply Damper  HVF-107 Spent Fuel Handling HVAC Upstream Return Damper  HVF-108 Spent Fuel Handling HVAC Downstream Return Damper System Operating Procedure OP-002-009 Fuel Handling Building HVAC Revision 013 10 6.3.4 Place both FHB Vent Mode Select control switches to Bypass, and perform the following:
6.3.4.1 Verify the following dampers Closed:  HVF-103 FP Cool & Purif HVAC Supply Damper  HVF-104 FP Cool & Purif HVAC Supply Damper 6.3.4.2 Verify the following Open:  HVF-109 FP Cool & Purif HVAC Return Damper  HVF-110 FP Cool & Purif HVAC Return Damper 6.3.5 Denote which FHB Emergency Fltr Unit(s) is being started (circle one):
A B  6.3.5.1 Place control switch for desired FHB Emergency Fltr Unit(s),  HVF-0005A(B),  to START.
CAUTION IF REQUIRED FHB EMERGENCY FILTRATION UNIT DIFFERENTIAL PRESSURE CANNOT BE ACHIEVED, EVEN THROUGH THE USE OF MANUAL ADJUSTMENTS TO THE INLET DAMPER HVFMVAAA202A(B), THEN A WORK REQUEST SHOULD BE GENERATED IN ACCORDANCE WITH WM-100, WORK ORDER GENERATION, SCREENING AND CLASSIFICATION. 6.3.6 Verify FHB Emergency Fltr Unit DP 8.7 to 9.2 INWC. 6.3.7 Denote which FHB H&V Exhaust Fan is being started (circle one):
A B  6.3.7.1 Place control switch for FHB H&V Exhaust Fan A(B), HVF-0006A(B), to START. 6.3.8 Verify FHB H&V Room Exhaust Fan A(B) Intake Damper Open:  HVF-301A PID D53664 ...................................................................OPEN PID D53665...............................................................NT CLSD or  HVF-301B PID D53666....................................................................OPEN PID D53667...............................................................NT CLSD System Operating Procedure OP-002-009 Fuel Handling Building HVAC Revision 013 11 6.3.9 Verify Sample Pump running for FHB Emergency Exhaust WRGM, PRM-IRI-3032, at either CP-6 or CP-52. 6.3.10 Monitor applicable Range and Effluent Level for FHB Emergency Exhaust WRGM, PRM-IRI-3032, at either CP-6 or CP-52. 6.3.11 If radiation levels permit, then Place FHB Normal HVAC in Service in accordance with Section 6.1, Placing FHB Normal HVAC in Service. 6.3.12 If temporary FHB air conditioning is installed, then the following dampers, may be reopened to facilitate cooling of the +46 elevation of the Fuel Handling Building:  HVF-105 Spent Fuel Handling HVAC Upstream Supply Damper  HVF-106 Spent Fuel Handling HVAC Downstream Supply Damper  HVF-107 Spent Fuel Handling HVAC Upstream Return Damper  HVF-108 Spent Fuel Handling HVAC Downstream Return Damper 
 
Waterford 3 2015 NRC RO/SRO Exam JOB PERFORMANCE MEASURE P1  Start an Air Side Seal Oil Pump following a Loss of a Single Train of Offsite Power Applicant:
Examiner:
 
JPM P1  Revision 0 Page 2 of 7 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Start an Air Side Seal Oil Pump following a Loss of Offsite Power to the Train A Electrical busses and then secure the Air Side Seal Oil Backup Pump (DC) in accordance with OP-902-009 Attachment 33-C: Generator Auxiliary Operations-Loss of Single Train Off-Site Power.
Task Standard: Applicant energizes and starts the Air Side Seal Oil Pump from MCC-215B and then secures the Air Side Seal Oil Backup Pump (DC). 
 
==References:==
OP-902-009 Attachment-33, Generator Auxiliary Operations-Loss of Single Train Off-Site Power Alternate Path:
No Time Critical: No Validation Time: 10 mins. K/A G2.4.6 Knowledge of EOP mitigation  Importance Rating 3.7 / 4.7 strategies RO/SRO        Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM P1  Revision 0 Page 3 of 7 2015 NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-902-009 Attachment 33-C: Generator Auxiliary Operations-Loss of Single Train Off-Site Power
 
== Description:==
This task is performed on the TGB +40 Elevation (east side)
READ TO APPLICANT DIRECTION TO APPLICANT:
I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated , do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.
(Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
NOTE for JPM Validation Only When performing JPM validation, actions are necessary to ensure exam security is maintained. Prior to commencing in plant JPM validation, contact Health Physics and direct them to disable all cameras in the CAA in a manner that prevents anyone from viewing any of the CAA cameras.
After all in plant JPMs are complete, contact Health Physics to restore the disabled cameras.
JPM P1  Revision 0 Page 4 of 7 2015 NRC Exam APPLICANT CUE SHEET Do Not Manipulate Any Plant Components (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
A loss of offsite power to Train A Electrical busses has occurred.
INITIATING CUE:
The CRS has directed you to start the Air Side Seal Oil Pump on the MCC-215B electrical bus in accordance with OP-902-009, Attachment 33-C: Generator Auxiliary Operations-Loss of Single Train Off-Site Power
 
JPM P1  Revision 0 Page 5 of 7 2015 NRC Exam Evaluator Note 1. This JPM will take place on the TGB +40 East side.
TASK ELEMENT 1 STANDARD 1. Check Air Side Seal Oil Pump operating. Verified Air Side Seal Oil Pump is not operating. Comment: The applicant may verify Air Side Seal Oil Pump not running locally at the pump or using light indications at the Hydrogen Control Panel. Comment: There is one Air Side Seal Oil Pump but two control switches at the Hydrogen Control Panel. The proper C/S to verify depends on what MCC 215 bus is powering the ASSO pump. Examiner Cue: Inform the applicant that the Air Side Seal Oil Pump is not running if local verification is used. If applicant uses light indication at the Hydrogen Control Panel, cue the applicant that the "B" Air Side Seal Oil Pump C/S green light is on and the red light is off. If asked, the status of "A" Air Side Seal Oil Pump C/S is that the green and red light are not illuminated.
SAT  /  UNSAT TASK ELEMENT 2 STANDARD 2. IF Air Side Seal Oil pump is de-energized, THEN perform the following to transfer power source:
: a. Check status of Air Side Seal Oil Pump Transfer Switch Source Available and Load Connected lights. Verified status of Air Side Seal Oil Pump Transfer Switch Source Available and Load Connected lights. Comment: Examiner Cue: Cue the applicant that the Emergency Source Available light is illuminated and the Normal Source Available light is not illuminated. Examiner Cue: Cue the applicant that the Load Connected to Normal and Load Connected to Emergency lights are extinguished.
SAT  /  UNSAT
 
JPM P1  Revision 0 Page 6 of 7 2015 NRC Exam TASK ELEMENT 3 STANDARD b. If Emergency Source (MCC-215B) Available light is illuminated, then perform the following: 1) Toggle the Transfer Control Switch to TRANSFER TO EMERGENCY and THEN release the switch to neutral position. Transferred the Control Switch to TRANSFER TO EMERGENCY position. Comment:    Critical SAT  /  UNSAT TASK ELEMENT 4 STANDARD 2) Check both of the following:  Load Connected to Emergency light illuminated. Load Connected to Normal light extinguished. Proper light configuration is verified. Comment: Examiner Cue: Notify the applicant that the Load Connected to Emergency light is illuminated and that the Load Connected to Normal light is extinguished.
SAT  /  UNSAT TASK ELEMENT 5 STANDARD d. Verify Air Side Seal Oil pump operating. Verified Air Side Seal Oil pump is operating. Comment: The applicant may verify Air Side Seal Oil Pump running locally at the pump or using light indications at the Hydrogen Control Panel. Examiner Cue: Inform the applicant that the Air Side Seal Oil Pump is running if local verification is used. If applicant uses light indication at the Hydrogen Control Panel, cue the applicant that the "B" Air Side Seal Oil Pump C/S green light is off and the red light is on. SAT  /  UNSAT TASK ELEMENT 6 STANDARD e. Stop the Air Side Seal Oil Backup Pump (DC) at Hydrogen Control panel. Air Side Seal Oil Backup Pump is stopped. Comment: Examiner Cue: Notify the applicant that the Air Side Seal Oil Backup Pump is stopped after the switch is taken to stop.
Critical SAT  /  UNSAT
 
JPM P1  Revision 0 Page 7 of 7 2015 NRC Exam TASK ELEMENT 7 STANDARD 3. Check Seal Oil DP 10 to 14 psid. Seal Oil DP is verified. Comment: Examiner Cue: Notify the applicant that Seal Oil DP is 13 psid.
SAT  /  UNSAT END OF TASK
 
WATERFORD 3 SES OP-902-009 Revision 310 Page 174 of 177 STANDARD APPENDICES Attachment 33-C Page 1 of 4 Generator Auxiliary Operations Attachment 33-C: Generator Auxiliary Operations - Loss of Single Train Off-Site Power INSTRUCTIONS
: 1. Check Air Side Seal Oil pump operating.
: 2. IF Air Side Seal Oil pump is de-energized,  THEN perform the following to transfer power source:
: a. Check status of Air Side Seal Oil Pump Transfer Switch Source Available and Load Connected lights. 
: b. IF Emergency Source (MCC 215B) Available light is illuminated, THEN perform the following: 1) Toggle the Transfer Control switch to TRANSFER TO EMERGENCY and THEN release the switch to neutral position. 2) Check BOTH of the following:  Load Connected to Emergency light illuminated. Load Connected to Normal light extinguished.
: c. IF Normal Source (MCC 215A) Available light is illuminated, THEN perform the following: 1) Toggle the Transfer Control switch to TRANSFER TO NORMAL and THEN release the switch to neutral position. 2) Check BOTH of the following:  Load Connected to Normal light illuminated. Load Connected to Emergency light extinguished. d. Verify Air Side Seal Oil pump operating.
: e. Stop the Air Side Seal Oil Backup Pump (DC) at Hydrogen Control panel.
: 3. Check Seal Oil DP 10 to 14 psid.
WATERFORD 3 SESOP-902-009Revision 310STANDARD APPENDICES Page 174 of 177Attachment 33-C Page 1 of 4Generator Auxiliary OperationsAttachment 33-C: Generator Auxiliary Operations - Loss of Single Train Off-Site PowerINSTRUCTIONS1. Check Air Side Seal Oil pump operating.
2.IFAir Side Seal Oil pump is de-energized,THENperform the following to transfer power source:a. Check status of Air Side Seal Oil Pump Transfer Switch Source Available and Load Connected lights.
b.IF Emergency Source (MCC 215B) Available light is illuminated,THEN perform the following:1) Toggle the Transfer Control switch to TRANSFER TO EMERGENCYand THENrelease the switch to neutral position.2) CheckBOTH of the following: Load Connected to Emergency light illuminated. Load Connected to Normal light extinguished.
c.IF Normal Source (MCC 215A) Available light is illuminated,THEN perform the following:1) Toggle the Transfer Control switch to TRANSFER TO NORMALand THENrelease the switch to neutral position.2) CheckBOTH of the following: Load Connected to Normal light illuminated. Load Connected to Emergency light extinguished.d. Verify Air Side Seal Oil pump operating.e. Stop the Air Side Seal Oil Backup Pump (DC) at Hydrogen Control panel.3. Check Seal Oil DP 10 to 14 psid.
WATERFORD 3 SESOP-902-009Revision 310STANDARD APPENDICES Page 175 of 177Attachment 33-C Page 2 of 4INSTRUCTIONS4. Verify Generator Bearing Drain Vapor Extractor A(B) is operating. (+69 TGB Roof) -----------------------------------------------------------NOTE--------------------------------------------------------------AB Safety buses are preferably powered from Off-Site Power since the EDG fuel oilcalculation does not support fully loaded AB Non-Safety related buses on an EDG. ---------------------------------------------------------------------------------------------------------------------------------5. Transfer AB Safety buses to Off-Site power at SM/CRS discretion.REFER TO applicable attachment: Attachment 12-E: Energize AB Safety Buses from the A Side Attachment 12-F: Energize AB Safety Buses from the B Side 6.IFAB Safety buses energized from Off-Site Power,THENverify the following:a. Close SSD-EBKR-31AB-3A, MCC 313AB Supply breaker to restore power toMCC 313AB.b. Verify AC Bearing Oil pump andHP Seal Oil pump operating at CP-1.c. Stop Emergency Bearing Oil pump at CP-1.d. Stop Air Side Seal Oil Backup pump at Hydrogen Control panel.e. Check Air Side Seal Oil DP at least 7 psid.f. GO TO Step 10.
WATERFORD 3 SESOP-902-009Revision 310STANDARD APPENDICES Page 176 of 177Attachment 33-C Page 3 of 4INSTRUCTIONS
* 7.IF AB Safety buses are energized on the EDG,AND the TSC is operational,THEN request the TSC to evaluate EDG fuel load for full restoration of  MCC 313AB on the EDG. 8.IF the TSC isNOT operational, OR TSC approval for full restoration of MCC 313AB within 30 minutes of LOOP is NOT obtained,THEN operate AC Bearing Oil pump for one hour as follows:
: a. OpenALLbreakers on MCC 313AB EXCEPTLOG-EBKR-313AB-2M, Main Turbine AC Bearing Oil Pump breaker.b. Verify LOG-EBKR-313AB-2M, Main Turbine AC Bearing Oil Pump breaker closed.c. Close SSD-EBKR-31AB-3A, MCC 313AB Supply breaker to restore power toMCC 313AB.d. At CP-1, start AC Bearing Oil pump.Time: _____________e. At CP-1, stop DC Emergency pump.
f.WHENONEhour has elapsed since start of AC Bearing Oil pump,THEN perform the following:1) Open LOG-EBKR-313AB-2M, Main Turbine AC Bearing Oil Pump breaker.2) GO TO Step 10.
9.IF TSC approves full restoration of MCC 313AB on the EDG,THEN perform the following:a. Close SSD-EBKR-31AB-3A, MCC 313AB Supply breaker to restore power toMCC-313AB.b. Verify AC Bearing Oil pump and HP Seal Oil pump operating at CP-1.c. Stop Emergency Bearing Oil pump at CP-1.d. Stop Air Side Seal Oil Backup pump at Hydrogen Control panel.e. Verify Air Side Seal Oil DP at least 7 PSID.
WATERFORD 3 SESOP-902-009Revision 310STANDARD APPENDICES Page 177 of 177Attachment 33-C Page 4 of 4[LAST PAGE]INSTRUCTIONS 10.WHENMain Turbine speed is 0 RPM,THENopen LOG EBKRTGB 2, Turb Lube Oil Emergency Bearing Oil Pump (DC) breaker.11. Secure Main Feed Pump DC Oil pumps as follows:a. VerifyAT LEAST ONEMain Feed Pump Main Oil pump operating on EACHMain Feed pump: Main Feed Pump A Main Oil Pump Main Feed Pump B Main Oil Pumpb. Stop DC Emergency Oil Pump for associated operating Main Oil pump: Main Feed Pump A Emergency Oil Pump Main Feed Pump B Emergency Oil Pump----------------------------------------------------------- NOTE -----------------------------------------------------------Continue at Control Room discretion. As time and resources allow perform the followingsteps to shutdown and recover Turbine Auxiliary systems. --------------------------------------------------------------------------------------------------------------------------------
12.IF Turbine Lube Oil or Turbine Cooling Water NOT in service,THEN request TSC to evaluate operation of Generator Auxiliaries.REFER TO OP-003-023, "Seal Oil."End of Attachment 33-CEnd of Appendix 33 Technical Guide for Standard Appendices TG-OP-902-009 Revision 309 73Appendix 33Generator Auxiliary Operations (cont'd)Attachment 33-C: Generator Auxiliary Operations - Loss of a single train Off-Site PowerThis attachment is created to assist the operator in generator auxiliary operations in theloss of a single train of off-site power resulting in the loss of both the associated 1 and 2buses. This procedure section is written for one power train, including all associatedbuses, to be energized from off-site power. In addition the procedure direction alsoencompasses the opposite train EDG which may or may not be providing power to theopposite train 3 bus. This procedure section secures the major DC motor loadsoperating on the TGB Battery to preserve the TGB battery in the event that the TGBBattery charger, on the power train energized by off-site power, is not functioning. Thesteps are presented in a preferred or anticipated order but many of the steps are notcascading and can be performed in tandem or out of sequence by operator discretion.Step 1 verifies the Air Side Seal Oil pump is operating. This is the normal air side sealoil pump that is powered from MCC 215A or MCC 215B. If the pump is aligned to thepower train that is energized from off-site power the pump should be operating. Also ifthe pump is operating then the air side seal oil backup pump has not started. The AirSide Seal Oil pump would be the first choice for replacing the air side seal oil backuppump if it has started and so this step has been placed first in the attachment. This stepstarts the NAO performing an important task while the control room can prepare toenergize the AB buses if necessary. This procedure section starts from the assumptionthat the air side seal oil pump control switches are aligned normally (both CS-1 and CS-2 are aligned to START). The alignment of these switches to start is what energizes(illuminates) the associated power available light on the MBT.Step 2 provides direction to energize the air side seal oil pump if it is not operating dueto a loss of power. The pump is transferred the opposite train (energized train) MCC215. When the transfer is complete the air side seal oil pump should be operating. Ifthe Air side seal oil backup pump (DC) is operating then stop the backup pump at thehydrogen control panel and verify seal oil DP is maintained in normal band. The AirSide Seal Oil Pump Transfer Switch in between MCC 215A and MCC 215B indicatesnormal and emergency source available and indicates load connected to normal oremergency. The air side seal oil pump would be the first choice replacement for the airside seal oil backup pump.Step 3 checks that air side seal oil DP is operating in the normal band.
Technical Guide for Standard Appendices TG-OP-902-009 Revision 309 74Appendix 33Generator Auxiliary Operations (cont'd)Attachment 33-C: Generator Auxiliary Operations - Loss of a single train Off-Site Power (cont'd)Step 4 verifies that a Generator Bearing Vapor Extractor is operating. Operation of theseal oil vapor extractor prevents hydrogen from migrating to the main lube oil system andcollecting in the generator bearing housings and the main lube oil reservoir. Alsoprevents oil leakage from the turbine shafts. Loss of vapor extractors may result inunsafe accumulation of hydrogen in main generator bearing cavities and main lube oilreservoir and oil leakage from the main generator shaft seals.The note identifies that it is preferable to have the AB safety buses energized from off-site power since the EDG fuel loading calculation does not support the full loading of theAB safety buses. There is no loading limitation for non-safety loads if the buses areconnected to off-site power. This note provides information to the operator and is notdirection to swap energized AB safety buses from an EDG to off-site power.Transferring the AB safety buses to off-site power is at the discretion of the control room staff.Step 5 is to verify the AB safety buses are energized. While it is preferable that the ABbuses are energized from off-site power transferring the AB safety buses from anoperating EDG to off-site power may not be prudent if the AB buses are carrying safetyrelated critical loads associated with the operating EDG such as CCW or Essential ChillWater. Transferring the AB buses is performed at the operating crew's discretion. If theAB buses are de-energized because the EDG is not operating then they should beenergized from off-site power expeditiously.Step 6 identifies if the AB Safety Buses are energized from off-site power then energizeMCC 313AB by closing the supply breaker. Full loading of MCC 313AB is allowed whenon off-site power and all turbine auxiliaries should be functioning. The step providesdirection similar to Appendix 12G for starting the AC bearing oil pump and generatorseal oil backup pump from CP-1, stopping the DC emergency oil pump securing the airside seal oil backup pump and verifying air side seal oil DP. Steps one and two shouldhave restored the air side seal oil pump and securing the air side seal oil backup pumpshould not be necessary. Should the air side seal oil pump not be available and the HPseal oil pump is providing air side seal oil then the DP is likely to be lower than normaland only 8 PSID is specified. A DP of at least 7 PSID is a reasonable value for thefollowing reasons. By maintaining DP greater than 5 PSID ensures that the air side sealoil backup pump does not auto start. If the HP seal oil pump is maintaining air side sealoil, the normal setting of SO-308 is established to maintain 7.5 to 8.5 PSID. If the normalair side seal oil pump (10 to 14 PSID) is maintaining Seal Oil DP then greater than 7PSID is acceptable also. This step then directs the operator to go to step 10.
Technical Guide for Standard Appendices TG-OP-902-009 Revision 309 75Appendix 33Generator Auxiliary Operations (cont'd)Attachment 33-C: Generator Auxiliary Operations - Loss of a single train Off-Site Power (cont'd)Step 7 identifies if the AB buses are energized on the EDG then contact the TSC toevaluate the EDG fuel loading for placing the MCC 3131AB fully on the AB Safety Bus.The EDG fuel loading calculation does not support fully loading the MCC-313AB bus onan EDG. If the TSC is available they can assist the operations staff in evaluating thefuel oil loading.The EDG Fuel Oil Calculation is a conservative calculation that supports the technicalspecification 7 day fuel oil requirement. Evaluating EDG Fuel Oil Loading shouldconsider the following: Are both EDGs operating?  The limiting case for fuel oilconsumption is with both EDGs operating to mitigate the consequences of an event.The calculation considers both EDGs operating with the AB Safety Buses connected toeach EDG. What is the amount of fuel available in each tank?  Can the tanks be crossconnected if one EDG has failed?  What are the weather conditions?  Can additional fueloil be easily delivered?  Are all of the fans on the UHS in operation?  The calculationassumes worst case summertime conditions. The calculation also assumes that manualloads such as the Spent Fuel Pool pump will be loaded on both EDGs. Also to beconsidered is the amount of MWs loaded on any operating EDG. The calculationconsiders the limiting conditions of a LOCA with LOOP, a MSLB in containment with aLOOP, and shutdown with a LOOP. Therefore also to be considered is events inprogress.Step 8 should be performed to operate the AC bearing oil pump if the EDG is carryingthe AB safety buses and timely approval from the TSC is not obtained. The step meetsthe requirements of the EDG fuel oil loading calculation. This step allows energizing theAC bearing oil pump for one hour on MCC 313AB. One hour of operation of the ACbearing oil pump is supported by the EDG fuel oil loading calculation. All other loads onMCC 313 AB are de-energized by opening breakers. This allows for the emergencybearing oil pump to be stopped early and conserving TGB battery power. When the ACBearing Oil Pump is stopped seal oil will still be maintained by the air side seal oil pump.The step kicks over step 9 TSC approval to step 10 once the step has been started. Theassumption is to proceed with the design basis path once started and if approval comesto energize 313AB that can be utilized for restoration once the auxiliaries for the maingenerator have been shut down.
Technical Guide for Standard Appendices TG-OP-902-009 Revision 309 76Appendix 33Generator Auxiliary Operations (cont'd)Attachment 33-C: Generator Auxiliary Operations - Loss of a single train Off-Site Power (cont'd)Step 9 provides direction on how to fully energize MCC 313AB on the AB safety bus andsubsequent actions if the TSC approves the full restoration of the MCC 313AB bus onthe EDG. This step is performed similarly to restoring MCC-313AB with off-site poweravailable and is similar to Attachment 12-G. This step is skipped once the crew hasstarted Step 8; the reason for this is to avoid extra communications and complications once a path has been chosen.Step 10 provides direction is provided to secure the DC emergency lube oil pump byopening the breaker if the main turbine is at 0 rpm. Opening the breaker of the pumpprevents the pump from auto restarting when the AC bearing oil pump is secured. Thisstep should be performed when the main turbine reaches 0 RPM. It is acceptable to pullthis step forward if the main turbine reaches 0 rpm and the AC bearing oil pump is stilloperating. By completing this action additional loading of TGB Battery is prevented.Step 11 provides direction to verify a Main Oil pump is operating on each main feedpump and then to secure the associated Emergency Oil pump for each main feed pump.The main feed pump A(B) main oil pumps are powered from MCC 211A(B) and MCC212B(A) respectively. The step verifies that an AC Bearing Oil pump is operating andthen secures the DC pump. Since there is an AC bearing oil pump powered from eachtrain of off-site power it is not expected that the DC powered pump will be operating.However if the DC pump is operating then this step should be pulled forward andcompleted when resources are available.A note is provided at this point in the procedure to continue at control room discretion astime and resources allow. This note is a breaking point incorporated into all of theGenerator Auxiliary attachments as a stopping point for the NAO. At this point the taskof protecting the main generator and preserving the TGB batteries is completed.Following this point secondary plant cleanup actions are provided as a convenience tothe operator to ensure that the operator has control of these systems when power isrestored to the site.Step 12 requests that the TSC evaluate seal oil operation if turbine lube oil or turbinecooling water is not available. In the event of a single loss of off-site power train it ispossible that one or the other of these systems is not operating and the seal oilprocedure provides limitations for these conditions. The normal operating procedure haslimitations for operating seal oil if these systems are not in service.
Technical Guide for Standard Appendices TG-OP-902-009 Revision 309 77Appendix 33Generator Auxiliary Operations (cont'd)Contingency ActionsSeveral contingency actions have been built into the instruction steps. Direction isprovided on how to energize the AB Safety buses if they are not energized. Direction isprovided on how to energize the AC powered air side seal oil pump if it is not energized.Direction is provided on how to deal with MCC 313AB depending on whether the ABsafety buses are energized from off-site power or an EDG.DeviationsThe CEN-152 EPG does not provide direction for venting the main generator or securingTGB loads. These actions are undertaken to reduce the risk of a hydrogen explosionand to preserve functions that are maintained by the turbine building battery. Preservingthe TGB Battery preserves remote operation of the 2 bus feeder breakers and the 1 and2 bus load breakers which allows for off-site power to be more efficiently and safelyrestored. Off-site power is restored to the 4.16 KV safety buses through the non-safety 2buses. Also TGB Battery DC power supports the automatic operation of the instrumentair compressors. Instrument air compressors are energized through the 4.16 KV safetybuses. Incorporation of these actions into the EOPs is a result of INPO IER 2-12-27.
Waterford 3 2015 RO NRC Exam JOB PERFORMANCE MEASURE P2  Trip Emergency Diesel Generator B Locally Applicant:
Examiner:
 
JPM P2  Revision 0 Page 2 of 8 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Trip Emergency Diesel Generator B locally.
Task Standard: Applicant trips EDG B after initial efforts to trip the diesel fail.
 
==References:==
OP-009-002, Emergency Diesel Generator, Attachment 8.7 Performing an Emergency Shutdown of the Emergency Diesel Generator. Revision 325 Alternate Path:
Yes Time Critical: No Validation Time:
5 mins. K/A 064 K4.02 Trips for EDG while operating  Importance Rating 3.9 / 4.2 (normal or emergency)
RO / SRO  Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM P2  Revision 0 Page 3 of 8 2015 NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-009-002, Emergency Diesel Generator
 
== Description:==
The applicant will be directed to trip EDG B locally. This JPM will require entry into the RCA, +21 level. The first method the applicant uses to trip the diesel will not function and the applicant will be required to trip the diesel using another method. The reason for tripping EDG B will be due to a fuel oil leak, so depressing the System Reset pushbutton on the local control panel is required.
READ TO APPLICANT DIRECTION TO APPLICANT:
I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated , do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.
(Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
NOTE for JPM Validation Only When performing JPM validation, actions are necessary to ensure exam security is maintained. Prior to commencing in plant JPM validation, contact Health Physics and direct them to disable all cameras in the CAA in a manner that prevents anyone from viewing any of the CAA cameras.
After all in plant JPMs are complete, contact Health Physics to restore the disabled cameras.
JPM P2  Revision 0 Page 4 of 8 2015 NRC Exam APPLICANT CUE SHEET Do Not Manipulate Any Plant Components (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
Emergency Diesel Generator B is running in Emergency Mode  A fuel oil leak has developed on the EDG B.
INITIATING CUE:
The CRS directs you to locally trip EDG B in accordance with OP-009-002, Emergency Diesel Generator, section 8.7 Performing an Emergency Shutdown of the EDG.
 
JPM P2  Revision 0 Page 5 of 8 2015 NRC Exam TASK ELEMENT 1 STANDARD NOTE If control air is lost during any EDG run, then the Fuel Rack Override lever must be used to shutdown the EDG. Note reviewed. Comment:  SAT  /  UNSAT TASK ELEMENT 2 STANDARD CAUTION SUBSECTION 8.7 IS FOR EMERGENCY CONDITIONS, WHEN NORMAL SHUTDOWN IS INOPERATIVE OR IT IS NECESSARY TO RAPIDLY STOP THE EMERGENCY DIESEL GENERATOR. Caution reviewed. Comment:  SAT  /  UNSAT Evaluator Note Step 8.7.1 is not applicable since Emergency Diesel Generator B is running in Emergency Mode.
TASK ELEMENT 3 STANDARD NOTE Two Operators are required to secure the EDG in Emergency Mode using method 2 of step 8.7.2. Note reviewed. Comment:  SAT  /  UNSAT
 
JPM P2  Revision 0 Page 6 of 8 2015 NRC Exam TASK ELEMENT 4 STANDARD CAUTION THE EDG WILL RESTART IF THE FUEL RACK OVERRIDE LEVER IS RELEASED AND THE UNDERVOLTAGE OR SIAS SIGNAL IS PRESENT PRIOR TO COMPLETING STEP 8.7.2.2.2. Caution reviewed. Comment:  SAT  /  UNSAT Evaluator Note There are 2 acceptable methods to trip an EDG running in emergency mode. The applicant could choose either method to perform first. Which ever method used first will fail, requiring the applicant to exercise the other method.
8.7.2 With the Emergency Diesel Generator B in Emergency Mode, Stop the Emergency Diesel Generator B by performing one of the following methods:
TASK ELEMENT 5 STANDARD 8.7.2.1 Method 1: Pull the manual Fuel Oil Overspeed Trip on the Overspeed Governor. Overspeed pulled. Comment: This plunger is located on the upper level of the EDG. If this is attempted first, cue that the EDG B is still running.
Critical SAT  /  UNSAT TASK ELEMENT 6 STANDARD 8.7.2.2 Method 2: 8.7.2.2.1 Pull down and hold the Fuel Rack Override Lever on the North side of the Emergency Diesel Generator A(B) engine. Handle is held down. Comment: If this is attempted first, cue the applicant that the lever did not move and that the EDG B is still running.
Critical SAT  /  UNSAT Evaluator Note If the applicant uses the fuel lever second, cue him that another operator has arrived to assist. After the applicant is holding the fuel rack lever, cue that another operator is now holding the lever.
 
JPM P2  Revision 0 Page 7 of 8 2015 NRC Exam TASK ELEMENT 7 STANDARD 8.7.2.2.2 To prevent the Emergency Diesel Generator A(B) from Starting, Unlock and Close the following valves:  EGA-152A(B) A(B) Air Receiver A2(B2) Outlet Isolation  EGA-153A(B) A(B) Air Receiver A1(B1) Outlet Isolation Valves are closed. Comment:  Critical SAT  /  UNSAT TASK ELEMENT 8 STANDARD 8.7.2.2.3 Release Fuel Rack Override Lever. Lever released. Comment:  SAT  /  UNSAT TASK ELEMENT 9 STANDARD 8.7.2.2.4 Place the EDG A(B) Fuel Rack Override Lever in the Vertical and Latched position. 8.7.2.2.4.1 Document on Attachment 11.18, Performing an Emergency Shutdown of the Emergency Diesel Generator Valve Restoration or other, appropriate document. Lever in the Vertical and latched position Comment: Examiner Cue: Inform the applicant that the control room is preparing the attachment and he may continue on.
SAT  /  UNSAT TASK ELEMENT 10 STANDARD NOTE Depressing the System Reset pushbutton after the EDG has stopped will secure the Standby Fuel Oil Booster Pump, which may help mitigate the fuel oil leak. Note reviewed. Comment:    SAT  /  UNSAT
 
JPM P2  Revision 0 Page 8 of 8 2015 NRC Exam TASK ELEMENT 11 STANDARD 8.7.3 If a fuel oil leak is in progress, when the Emergency Diesel Generator A(B) has stopped then depress the System Reset pushbutton. Pushbutton depressed. Comment: Cue the applicant that EDG B has stopped rotating after the second trip is used. Critical SAT  /  UNSAT TASK ELEMENT 12 STANDARD 8.7.4 Verify steps applicable or directed by the SM/CRS in Subsection 6.5, Unloading, Stopping and Returning EDG A(B) to Standby, are completed. Control Room informed. Comment:    SAT  /  UNSAT END OF TASK System Operating Procedure OP-009-002 Emergency Diesel Generator Revision 325 48 8.7 PERFORMING AN EMERGENCY SHUTDOWN OF THE EMERGENCY DIESEL GENERATOR  NOTE If control air is lost during any EDG run, then the Fuel Rack Override lever must be used to shutdown the EDG.
CAUTION SUBSECTION 8.7 IS FOR EMERGENCY CONDITIONS, WHEN NORMAL SHUTDOWN IS INOPERATIVE OR IT IS NECESSARY TO RAPIDLY STOP THE EMERGENCY DIESEL GENERATOR. 8.7.1 With Emergency Diesel Generator A(B) in Test Mode:
8.7.1.1 For no Cooldown cycle, then perform one of the following:  Depress Emergency Stop Pushbutton on CP-1. Depress the Emergency Stop pushbutton on Emergency Diesel Generator A(B) Control Panel. Pull manual Fuel Oil Overspeed Trip on Overspeed Governor. Pull down and hold Fuel Rack Override Lever on North side of Emergency Diesel Generator A(B) engine until the engine comes to a complete Stop. (Once released, ensure the the EDG A(B) Fuel Rack Override Lever is Vertical & Latched and document on  Attachment 11.18, Performing an Emergency Shutdown of the Emergency Diesel Generator Valve Restoration, or other, appropriate document) 8.7.1.2 For a 5 minute Cooldown cycle, then perform one of the following:  Position Diesel Cranking Control Switch at CP-1 to STOP. Position Control Switch on Emergency Diesel Generator A(B) Control Panel to STOP.
System Operating Procedure OP-009-002 Emergency Diesel Generator Revision 325 49  NOTE Two Operators are required to secure the EDG in Emergency Mode using method 2 of step
 
====8.7.2. CAUTION====
THE EDG WILL RESTART IF THE FUEL RACK OVERRIDE LEVER IS RELEASED AND THE UNDERVOLTAGE OR SIAS SIGNAL IS PRESENT PRIOR TO COMPLETING STEP 8.7.2.2.2. 8.7.2 With the Emergency Diesel Generator A(B) in Emergency Mode, Stop the Emergency Diesel Generator A(B) by performing one of the following methods:
8.7.2.1 Method 1: Pull the manual Fuel Oil Overspeed Trip on the Overspeed Governor.
Or 8.7.2.2 Method 2:
8.7.2.2.1 Pull down and hold the EDG A(B) Fuel Rack Override Lever on the North side of the Emergency Diesel Generator A(B) engine.
8.7.2.2.2 To prevent the Emergency Diesel Generator A(B) from Starting, Unlock and Close the following valves:  EGA-152A(B) A(B) Air Receiver A2(B2) Outlet Isolation  EGA-153A(B) A(B) Air Receiver A1(B1) Outlet Isolation 8.7.2.2.3 Release Fuel Rack Override Lever.
8.7.2.2.4 Place the EDG A(B) Fuel  Rack Override Lever in the  Vertical and Latched position. 8.7.2.2.4.1 Document on Attachment 11.18, Performing an Emergency Shutdown of the Emergency Diesel Generator Valve Restoration, or other, appropriate document.
System Operating Procedure OP-009-002 Emergency Diesel Generator Revision 325 50  NOTE Depressing the System Reset pushbutton after the EDG has stopped will secure the Standby Fuel Oil Booster Pump, which may help mitigate the fuel oil leak. 8.7.3 If a fuel oil leak is in progress, when the Emergency Diesel Generator A(B) has stopped then depress the System Reset pushbutton. 8.7.4 Verify steps applicable or directed by the SM/CRS in Subsection 6.5, Unloading, Stopping and Returning EDG A(B) to Standby, are completed. 8.7.5 When conditions allow, then Open and lock the valves closed in Step 8.7.2.2.2  EGA-152A(B) A(B) Air Receiver A2(B2) Outlet Isolation  EGA-153A(B) A(B) Air Receiver A1(B1) Outlet Isolation 8.7.5.1 Document on Attachment 11.18, Performing an Emergency Shutdown of the Emergency Diesel Generator Valve Restoration, or other, appropriate document. 
 
System Operating ProcedureOP-009-002Emergency Diesel GeneratorRevision 325 488.7 PERFORMING AN EMERGENCY SHUTDOWN OF THE EMERGENCY DIESEL GENERATORNOTEIf control air is lost during any EDG run, then the Fuel Rack Override lever must be used toshutdown the EDG.CAUTIONSUBSECTION 8.7 IS FOR EMERGENCY CONDITIONS, WHEN NORMAL SHUTDOWN ISINOPERATIVE OR IT IS NECESSARY TO RAPIDLY STOP THE EMERGENCY DIESELGENERATOR.8.7.1 With Emergency Diesel Generator A(B) in Test Mode:
8.7.1.1For no Cooldown cycle, then perform one of the following: Depress Emergency Stop Pushbutton on CP-1. Depress the Emergency Stop pushbutton on Emergency DieselGenerator A(B) Control Panel. Pull manual Fuel Oil Overspeed Trip on Overspeed Governor. Pull down and hold Fuel Rack Override Lever on North side ofEmergency Diesel Generator A(B) engine until the engine comes to acomplete Stop. (Once released, ensure the the EDG A(B) Fuel RackOverride Lever is Vertical & Latched and document onAttachment 11.18, Performing an Emergency Shutdown of theEmergency Diesel Generator Valve Restoration, or other, appropriatedocument)8.7.1.2For a 5 minute Cooldown cycle, then perform one of the following: Position Diesel Cranking Control Switch at CP-1 to STOP. Position Control Switch on Emergency Diesel Generator A(B) ControlPanel to STOP.
System Operating ProcedureOP-009-002Emergency Diesel GeneratorRevision 325 49NOTETwo Operators are required to secure the EDG in Emergency Mode using method 2 of step 8.7.2.CAUTIONTHE EDG WILL RESTART IF THE FUEL RACK OVERRIDE LEVER IS RELEASED ANDTHE UNDERVOLTAGE OR SIAS SIGNAL IS PRESENT PRIOR TO COMPLETING STEP8.7.2.2.2.8.7.2 With the Emergency Diesel Generator A(B) in Emergency Mode, Stop theEmergency Diesel Generator A(B) by performing one of the following methods:
8.7.2.1Method 1: Pull the manual Fuel Oil Overspeed Trip on the OverspeedGovernor.Or 8.7.2.2Method 2: 8.7.2.2.1Pull down and hold the EDG A(B) Fuel Rack Override Lever on the Northside of the Emergency Diesel Generator A(B) engine.
8.7.2.2.2To prevent the Emergency Diesel Generator A(B) from Starting, Unlockand Close the following valves: EGA-152A(B) A(B) Air Receiver A2(B2) Outlet Isolation EGA-153A(B) A(B) Air Receiver A1(B1) Outlet Isolation 8.7.2.2.3Release Fuel Rack Override Lever.
8.7.2.2.4Place the EDG A(B) Fuel  Rack Override Lever in theVertical and Latched position.8.7.2.2.4.1Document on Attachment 11.18, Performing an EmergencyShutdown of the Emergency Diesel Generator Valve Restoration, orother, appropriate document.
System Operating ProcedureOP-009-002Emergency Diesel GeneratorRevision 325 50NOTEDepressing the System Reset pushbutton after the EDG has stopped will secure the StandbyFuel Oil Booster Pump, which may help mitigate the fuel oil leak.8.7.3 If a fuel oil leak is in progress, when the Emergency Diesel Generator A(B) hasstopped then depress the System Reset pushbutton.8.7.4 Verify steps applicable or directed by the SM/CRS in Subsection 6.5, Unloading,Stopping and Returning EDG A(B) to Standby, are completed.8.7.5 When conditions allow, then Open and lock the valves closed in Step 8.7.2.2.2 EGA-152A(B) A(B) Air Receiver A2(B2) Outlet Isolation EGA-153A(B) A(B) Air Receiver A1(B1) Outlet Isolation 8.7.5.1Document on Attachment 11.18, Performing an Emergency Shutdown of theEmergency Diesel Generator Valve Restoration, or other, appropriatedocument.
Waterford 3 2015 NRC Exam JOB PERFORMANCE MEASURE P3  Restore Power to the DCT Sump Pumps Following a Loss of Off Site Power Applicant:
Examiner:
 
JPM P3  Revision 0 Page 2 of 7 2015 NRC Exam JOB PERFORMANCE MEASURE DATA PAGE Task: Restore power to the DCT Sump Pumps following a Loss of Off Site Power. Task Standard: Dry Cooling Tower Sump 1 and 2 Sump Pumps are energized.
 
==References:==
OP-902-009, Standard Appendices, Appendix 20, Operation of DCT Sump Pumps Alternate Path: No Time Critical: No Validation Time:
10 Mins. K/A G2.4.34 Knowledge of RO tasks performed  Importance Rating 4.2 / 4.1 outside the main control room during an RO / SRO  emergency and the resultant operational effects. Applicant:
Time Start:
Time Finish:
Performance Time:  minutes Critical Time:
N/A minutes  Performance Rating: SAT UNSAT  Comments:
Examiner:
Date:  Signature
 
JPM P3  Revision 0 Page 3 of 7 2015 NRC Exam EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:
OP-902-009, Standard Appendices, Appendix 20, Operation of DCT Sump Pumps
 
== Description:==
Applicant will strip non-safety loads from MCC 314 A and 314 B. The safety to non-safety bus tie breaker will then be closed. The task is complete after the breakers are closed to all 4 DCT Sump pumps. All elements of this JPM are performed at the 314 A/B Switchgear area on the +1 level of the Fuel Handling Building.
READ TO APPLICANT DIRECTION TO APPLICANT:
I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated , do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.
(Read the Initial Condition and Cues from the colored Applicant Cue Sheet, and then give the cue sheet to the applicant.)
NOTE for JPM Validation Only When performing JPM validation, actions are necessary to ensure exam security is maintained. Prior to commencing in plant JPM validation, contact Health Physics and direct them to disable all cameras in the CAA in a manner that prevents anyone from viewing any of the CAA cameras.
After all in plant JPMs are complete, contact Health Physics to restore the disabled cameras.
JPM P3  Revision 0 Page 4 of 7 2015 NRC Exam  APPLICANT CUE SHEET Do Not Manipulate Any Plant Components (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)
INITIAL CONDITIONS:
The Plant has experienced a Loss of Offsite Power and recovery actions of OP-902-003 are being performed. Emergency Diesel Generators A and B are supplying power to Train A and Train B Safety Buses with both Sequencers timed out.
INITIATING CUE:
The CRS has directed you to restore power to the DCT Sump Pumps 1A, 2A, 1B, and 2B in accordance with OP-902-009, Appendix 20.
 
JPM P3  Revision 0 Page 5 of 7 2015 NRC Exam TASK ELEMENT 1 STANDARD Procedure Note:  This attachment should be performed following any power interruption to either the 3A or 3B Safety Bus (as directed from EOPs)  If a Probable Maximum Precipitation (PMP) event is in progress and any Dry Cooling Tower (DCT) Motor Driven Sump pump is unavailable, then both of the following shall be performed for the affected DCT sump pump to prevent flooding of associated 315A(B) Motor Control Center and Transformer within time frames as listed:  One DCT Motor Driven Sump pump is aligned for operation within 30 minutes of the PMP event. The DCT Portable Sump pump (diesel driven) is aligned for operation within three hours of the PMP event. Note reviewed Comment: EVALUATOR CUE:  If the applicant should asks, inform the applicant that a PMP event is not in progress.
SAT  /  UNSAT TASK ELEMENT 2 STANDARD 1. At MCC-314A, place BOTH of the following switches to "BYPASS":
DCT #1 Sump Pump A Radiation Monitor Bypass switch  DCT #2 Sump Pump A Radiation Monitor Bypass switch Both Radiation Monitor Bypass Switches in BYPASS on MCC-314A Comment: EVALUATOR CUE:  The names listed in the procedure do not exactly match the label posted on each breaker. If the candidate calls to inform the CRS, acknowledge the communication and inform the candidate to proceed. CRITICAL SAT  /  UNSAT TASK ELEMENT 3 STANDARD 2. At MCC-314B, place BOTH of the following switches to "BYPASS":
DCT #1 Sump Pump B Radiation Monitor Bypass switch  DCT #2 Sump Pump B Radiation Monitor Bypass switch Both Radiation Monitor Bypass Switches in BYPASS on MCC-314B Comment: EVALUATOR CUE:  The names listed in the procedure do not exactly match the label posted on each breaker. If the candidate calls to inform the CRS, acknowledge the communication and inform the candidate to proceed. CRITICAL SAT  /  UNSAT
 
JPM P3  Revision 0 Page 6 of 7 2015 NRC Exam TASK ELEMENT 4 STANDARD 3. IF MCC-314A is energized, AND breaker SSD-EBKR-314A-2M, MCC-314A Safety to Non-Safety Tie is open, THEN perform the following:
: a. Verify EDG A SEQUENCER is timed out. Sequencer timed out is given in Initial Conditions Comment: EVALUATOR CUE: If asked, inform the applicant that the breaker SSD-EBKR-314A-2M, MCC-314A Safety to Non-Safety Tie is open.
SAT  /  UNSAT TASK ELEMENT 5 STANDARD    b. Open ALL MCC-314A Non-Safety Load breakers. All breakers on the non-safety side of MCC-314A are open. Comment: EVALUATOR CUE:  The non-safety side of MCC 314A will be the right side of the tie breaker, where all of the breaker cubicle numbers are > 2. CRITICAL SAT  /  UNSAT TASK ELEMENT 6 STANDARD    c. Close SSD-EBKR-314A-2M, MCC 314A Safety to Non-safety Tie. SSD-EBKR314A-2M is closed. Comment: EVALUATOR CUE:  The candidate must lift the CLOSE lever on the face of the tie breaker or depress the CLOSE pushbutton above the CLOSE lever for at least 3 seconds (allows closing springs to charge) to close this breaker. If the candidate performs either of these actions report the breaker is closed. EVALUATOR CUE:  If a candidate attempts to Close a Safety to Non-Safety Tie using the electrical pushbuttons at the mid level of the cubicle, report that the breaker is still open. These switches (by the red and green lights) are not tied into the circuit.
CRITICAL SAT  /  UNSAT TASK ELEMENT 7 STANDARD    d. Close BOTH of the following Supply breakers:  SP-EBKR-314A-4F, West Dry Cooling Tower Sump Pump A  SP-EBKR-314A-5F, East Dry Cooling Tower Sump Pump A Both breakers are closed. Comment:  CRITICAL SAT  /  UNSAT
 
JPM P3  Revision 0 Page 7 of 7 2015 NRC Exam TASK ELEMENT 8 STANDARD IF MCC-314B is energized AND breaker SSD-EBKR-314B-2M, MCC-314B Safety to Non-Safety Tie is open, THEN perform the following:
: a. Verify EDG B SEQUENCER is timed out. Sequencer timed out is given in Initial Conditions Comment: EVALUATOR CUE: If asked, inform the applicant that the breaker SSD-EBKR-314B-2M, MCC-314B Safety to Non-Safety Tie is open SAT  /  UNSAT TASK ELEMENT 9 STANDARD    b. Open ALL MCC-314B Non-Safety Load breakers. All breakers on the non-safety side of MCC-314B are open. Comment: Evaluator: The non-safety side of MCC 314B will be the right side of the tie breaker, where all of the breaker cubicle numbers are > 2. CRITICAL SAT  /  UNSAT TASK ELEMENT 10 STANDARD    c. Close SSD-EBKR-314B-2M, MCC 314B Safety to Nonsafety Tie. SSD-EBKR314B-2M is closed. Comment: EVALUATOR CUE:  The candidate must lift the CLOSE lever on the face of the tie breaker or depress the CLOSE pushbutton above the CLOSE lever for at least 3 seconds (allows closing springs to charge) to close this breaker. If the candidate performs either of these actions report the breaker is closed. EVALUATOR CUE:  If a candidate attempts to Close a Safety to Non-Safety Tie using the electrical pushbuttons at the mid level of the cubicle, report that the breaker is still open. These switches (by the red and green lights) are not tied into the circuit.
CRITICAL SAT  /  UNSAT TASK ELEMENT 11 STANDARD    d. Close BOTH of the following Supply breakers:  SP-EBKR-314B-4F, West Dry Cooling Tower Sump Pump B  SP-EBKR-314B-5F, East Dry Cooling Tower Sump Pump B Both breakers are closed. Comment: EVALUATOR CUE:  If the candidate asks about a PMP event, inform him that there is no PMP event.
CRITICAL SAT  /  UNSAT END OF TASK
 
WATERFORD 3 SES OP-902-009 Revision 310 Page 121 of 177 STANDARD APPENDICES Appendix 20 Page 1 of 2 20.0 Operation of DCT Sump Pumps INSTRUCTIONS
  ------------------------------------------------------------ NOTE -----------------------------------------------------------  This attachment should be performed following any power interruption to either the 3A or 3B Safety bus (as directed from EOPs). If a Probable Maximum Precipitation (PMP) event is in progress and any Dry Cooling Tower (DCT) Motor Driven Sump pump is unavailable, then both of the following shall be performed for the affected DCT sump to prevent flooding of associated 315A(B) Motor Control Center and Transformer within time frames as listed:  One DCT Motor Driven Sump pump is aligned for operation within 30 minutes of the PMP event. The DCT Portable Sump pump (diesel driven) is aligned for operation within three hours of the PMP event. ---------------------------------------------------------------------------------------------------------------------------------
: 1. At MCC-314A, place BOTH of the following switches to "BYPASS:"  DCT #1 Sump Pump A Radiation Monitor Bypass switch  DCT #2 Sump Pump A Radiation Monitor Bypass switch  2. At MCC-314B, place BOTH of the following switches to "BYPASS:"  DCT #1 Sump Pump B Radiation Monitor Bypass switch  DCT #2 Sump Pump B Radiation Monitor Bypass switch
 
WATERFORD 3 SES OP-902-009 Revision 310 Page 122 of 177 STANDARD APPENDICES Appendix 20 Page 2 of 2 INSTRUCTIONS
: 3. IF MCC-314A is energized,  AND breaker SSD-EBKR-314A-2M, MCC-314A Safety to Non-Safety Tie is open,  THEN perform the following:
: a. Verify EDG A SEQUENCER has timed out.
: b. Open ALL MCC-314A Non-Safety Load breakers. c. Close SSD-EBKR-314A-2M, MCC-314A Safety to Non-Safety Tie.
: d. Close BOTH of the following Supply breakers:  SP-EBKR-314A-4F, West Dry Cooling Tower Sump Pump A  SP-EBKR-314A-5F, East Dry Cooling Tower Sump Pump A
: 4. IF MCC-314B is energized, AND breaker SSD-EBKR-314B-2M, MCC-314B Safety to Non-Safety Tie is open,  THEN perform the following:
: a. Verify EDG B SEQUENCER has timed out.
: b. Open ALL MCC-314B Non-Safety Load breakers. c. Close SSD-EBKR-314B-2M, MCC-314B Safety to Non-Safety Tie.
: d. Close BOTH of the following Supply breakers:  SP-EBKR-314B-4F, West Dry Cooling Tower Sump Pump B  SP-EBKR-314B-5F, East Dry Cooling Tower Sump Pump B
: 5. IF a PMP event is in progress, THEN align DCT Portable Sump Pump A(B) using OP-003-024, "Sump Pump Operation." End of Appendix 20
 
WATERFORD 3 SESOP-902-009Revision 310STANDARD APPENDICES Page 121 of 177Appendix 20Page 1 of 220.0 Operation of DCT Sump PumpsINSTRUCTIONS ------------------------------------------------------------ NOTE ----------------------------------------------------------- This attachment should be performed following any power interruption to either the 3A or3B Safety bus (as directed from EOPs). If a Probable Maximum Precipitation (PMP) event is in progress and any Dry CoolingTower (DCT) Motor Driven Sump pump is unavailable, then both of the following shall beperformed for the affected DCT sump to prevent flooding of associated 315A(B) MotorControl Center and Transformer within time frames as listed:One DCT Motor Driven Sump pump is aligned for operation within 30 minutes ofthe PMP event.The DCT Portable Sump pump (diesel driven) is aligned for operation withinthree hours of the PMP event.---------------------------------------------------------------------------------------------------------------------------------1. At MCC-314A, placeBOTH of the following switches to "BYPASS:" DCT #1 Sump Pump A Radiation Monitor Bypass switch DCT #2 Sump Pump A Radiation Monitor Bypass switch 2. At MCC-314B, placeBOTH of the following switches to "BYPASS:" DCT #1 Sump Pump B Radiation Monitor Bypass switch DCT #2 Sump Pump B Radiation Monitor Bypass switch WATERFORD 3 SESOP-902-009Revision 310STANDARD APPENDICES Page 122 of 177Appendix 20Page 2 of 2INSTRUCTIONS 3.IF MCC-314A is energized,ANDbreaker SSD-EBKR-314A-2M, MCC-314A Safety to Non-Safety Tie is open,THENperform the following:a. Verify EDG A SEQUENCER has timed out.
: b. OpenALLMCC-314A Non-Safety Load breakers.c. Close SSD-EBKR-314A-2M, MCC-314A Safety to Non-Safety Tie.
: d. CloseBOTH of the following Supply breakers: SP-EBKR-314A-4F, West Dry Cooling Tower Sump Pump A SP-EBKR-314A-5F, East Dry Cooling Tower Sump Pump A 4.IFMCC-314B is energized,ANDbreaker SSD-EBKR-314B-2M, MCC-314B Safety to Non-Safety Tie is open,THENperform the following:a. Verify EDG B SEQUENCER has timed out.
: b. OpenALLMCC-314B Non-Safety Load breakers.c. Close SSD-EBKR-314B-2M, MCC-314B Safety to Non-Safety Tie.
: d. CloseBOTH of the following Supply breakers: SP-EBKR-314B-4F, West Dry Cooling Tower Sump Pump B SP-EBKR-314B-5F, East Dry Cooling Tower Sump Pump B 5.IFa PMP event is in progress,THENalign DCT Portable Sump Pump A(B) using OP-003-024, "Sump Pump Operation."End of Appendix 20 Technical Guide for Standard Appendices TG-OP-902-009 Revision 309 50Appendix 20Restore Operation of DCT Sump PumpsObjectiveThe intent of this step is to protect the safety related MCCs 315A and 315B andassociated transformers, located in the Cooling Tower area, from potential flooding.
InstructionsThe operator is directed to restore operation of the Dry Cooling Tower (DCT) sumppumps if power is interrupted to either 3A or 3B safety buses. The specific directions forthis are included in a Standard Appendix.Contingency Actions NoneJustification for DeviationsThe EPG does not include a step to restore operation of the DCT Sump Pumps after apower interruption to the 3A or 3B safety buses. A power interruption to either of thesebuses would result in the associated MCC 314A(B) safety to nonsafety tie breakeropening. The DCT Sump Pumps are powered from the nonsafety sides of these busesand manual actions are required to restore power.Waterford 3 has committed that if a Probable Maximum Precipitation (PMP) event (30.7inches of rain in 6 hours) was to occur, and any DCT Motor Driven Sump Pump wasunavailable, to restore a minimum of one DCT Motor Driven Sump Pump within 30minutes of the PMP event and to align the DCT Portable Sump Pump (diesel driven)within 3 hours of the PMP event. This protects the safety related MCCs 315A and 315Band associated transformers, located in the Cooling Tower area, from potential flooding.ECM99-010, Dry Cooling Tower Ponding Analysis, does not credit the DCT Sumpvolume. Therefore, the "Dry Clng Tower Sump 1 (2) Level Hi" annunciators would be anearly initial indication of a PMP event. Additional indications to the Control Roominclude the notification from the National Weather Service of the potential for floodingconditions to occur and precipitation as monitored by the PMC Environmental Monitoring Group.References1. FSAR 2.4.2.3.d2. Letter W3282-06523. Commitment P 43924. ECM99-0105. EC 4301 Appendix DScenario OutlineForm ES-D 1 -2015 NRC Exam Scenario 1 D-1 Rev 1Facility:WaterfordScenario No.:
1Op Test No.:
1Examiners:Operators:Initial Conditions: Reactor power is 100%, MOCTurnover: Protected Train is B, AB Bus is aligned to Train B, Low Press Safety Injection (LPSI) pump A is tagged out. Perform a down power to ~90% for Heater Drain Pump planned maintenance.EventNo.Malf.No.EventType*EventDescription 1N/AR - ATCN - BOP N - SROInitiate a normal plant down power.
2 CH08E1I - BOPI - SROTS - SROPlant Protection System Channel D ContainmentPressure (CIAS), CB-IPI-6701SMD, fails highrequiring Technical Specification entry and bypass ofchannel trip bistables. (TS 3.3.1 & 3.3.2) 3FW26AI - BOPI - SROTS - SROSteam Generator #1 Feedwater flow instrument FW-IFR-1111 fails low. OP-901-201, Steam GeneratorLevel Control Malfunction. (TRM 3.3.5) 4 RC15A1I - ATCI - SROTS - SROPressurizer Level Control Channel Level Transmitter,RC-ILT-0110X, fails high requiring implementation ofOP-901-110, Pressurizer Level Control Malfunction.(TS 3.3.3.5 & 3.3.3.6) 5 L_L10 L_M10ED01A,B,C,DTU06 RD11A32 RD11A47M - AllA seismic event causes a loss of offsite power andmain turbine trip (auto reactor trip). Two CEAs fail toinsert. (Critical Task 1, Emergency Borate using CVCS). The crew will enter OP-902-000, StandardPost Trip Actions and diagnose into OP-902-003, Lossof Offsite Power/Forced Circulation.
6 RC23AM - AllLarge RCS Cold Leg break will cause the crew to re-diagnose and enter OP-902-002, Loss of CoolantAccident Recovery Procedure.
7RP05A3RP05B3 RP05C3 RP05D3I - ATCI - SROContainment Spray (CS) fails to AUTO Actuaterequiring manual actuation. (Critical Task 2,Manually Initiate Containment Spray
)8SI01EC - BOP C - SROLPSI pump B trips requiring implementation of OP-902-008, Functional Recovery Procedure. The crewwill align CS pump B to replace LPSI pump B inaccordance with OP-902-009, Standard Appendices,Att. 27.*(N)ormal,    (R)eactivity,    (I)nstrument,    (C)omponent,    (M)ajor Scenario Event DescriptionNRC Scenario 1- 2 -2015 NRC Exam Scenario 1 D-1 Rev 1The crew assumes the shift at 100% power with instructions to perform a plant down power to ~90% inpreparation for planned Heater Drain Pump maintenance. The SRO should direct the plant down power inaccordance with OP-010-005, Plant Shutdown and the provided reactivity plan.At lead examiner's discretion, CB-IPI-6701SMD, Containment Pressure (CIAS) fails high. The SROshould review Technical Specifications 3.3.1 and 3.3.2. Per Table 3.3-1 under Containment Pressure -High (Functional Unit 6) the SRO should enter Technical Specification 3.3.1 action 2. Per Table 3.3-3under Functional Units 1b (Safety Injection, Containment Pressure-High), 3b (Containment Isolation,Containment Pressure-High), and 4c (Main Steam Line Isolation, Containment Pressure High) the SROshould enter Tech 3.3.2 action 13. The SRO should direct the BOP to bypass the Containment PressureHigh (RPS) and Containment Pressure High (ESF) trip bistables (13&16) in PPS Channel D within 1 hour.The BOP should bypass the trip bistables in accordance with OP-009-007, Plant Protection System.After the trip bistables have been placed in bypass, Steam Generator #1 Feedwater flow instrument FW-IFR-1111 fails low. The Feedwater Control System will respond by increasing Feedwater flow to SteamGenerator #1. The SRO should enter OP-901-201, Steam Generator Level Control Malfunction. TheBOP will be required to take manual control and match Feedwater and Main Steam flow. The UltrasonicFlow Meter will fail as a result of the instrument failure and require entry into TRM 3.3.5. Feedwatercontrols for Steam Generator #1 may remain in manual as a result of this failure requiring manualpositioning of the valves on a Reactor Trip.After the crew has restored Steam Generator 1 to between 50% and 70% Narrow Range, PressurizerLevel Control Channel Level Transmitter, RC-ILT-0110X, fails high. The SRO should enter OP-901-110,Pressurizer Level Control Malfunction and implement Section E1. The crew should take manual controlof the Pressurizer Level Controller and/or operate Charging Pumps to restore Pressurizer level, swapcontrol to the Channel Y level channel, and return the Pressurizer Level Controller back to AUTO. TheSRO should review Technical Specifications 3.3.3.5 and 3.3.3.6 and OP-903-013, Monthly ChannelChecks. The SRO should determine that TS 3.3.3.6 requirements are met, but enter TS 3.3.3.5 Action a.After Pressurizer Level Control is in AUTO, a seismic event causes a loss of offsite power, a main turbinetrip and a reactor trip. Two CEAs fail to insert on the reactor trip. The ATC should commence EmergencyBoration in accordance with OP-901-103, Emergency Boration (CRITICAL TASK 1). The SRO shouldimplement OP-902-000, Standard Post Trip Actions (SPTA) and verify that the ATC has commencedemergency boration. The crew will diagnose into OP-902-003, Loss of Offsite Power/Forced Circulation.Once the crew diagnoses OP-902-003, Loss of Offsite Power/Forced Circulation, an RCS leak occurs onRCS Cold Leg 1A that progresses to a Large Break Loss of Coolant Accident. When ContainmentPressure exceeds the Containment Spray (CSAS) setpoint, Containment Spray fails to actuate. The ATCshould manually initiate Containment Spray(CRITICAL TASK 2). The crew should re-diagnose to OP-902-002, Loss of Coolant Accident Recovery Procedure.After the crew verifies proper operation of Component Cooling Water or at lead examiners discretion, LowPressure Safety Injection (LPSI) pump B will trip on overcurrent. The crew should recognize that OP-902-002 safety functions are not met and the SRO should go to OP-902-008, Functional Recovery. When theSRO performs prioritization, Inventory Control (IC-2) should be the highest priority. The SRO shouldrequest TSC/Shift Manager permission and direct the BOP to align Containment Spray pump B to replaceLPSI pump B and re-establish LPSI flow.The scenario can be terminated after the crew has re-established low pressure safety injection flow or atthe lead examiner's discretion.
NRC Scenario 1- 3 -2015 NRC Exam Scenario 1 D-1 Rev 1CRITICAL TASKS1. ESTABLISH REACTIVITY CONTROLThis task is satisfied by establishing emergency boration prior to exiting OP-902-000, StandardPost Trip Actions. This task becomes applicable after the reactor trips. OP-902-000, StandardPost Trip Actions, directs this as a contingency action to satisfy the Reactivity Control safetyfunction. OP-901-103, Emergency Boration, contains the immediate operator actions required tobe taken.2. ESTABLISH CONTAINMENT TEMPERATURE AND PRESSURE CONTROLThis task is satisfied by manually initiating Containment Spray Actuation Signal prior to exitingstep 15 (Verify Containment Spray Actuation) of OP-902-002, Loss of Coolant AccidentRecovery Procedure, or Containment pressure exceeding 44 PSIG (59 PSIA). This taskbecomes applicable after Containment Pressure rises above 17.7 PSIA. OP-902-000, StandardPost Trip Actions, directs this activity to satisfy the Containment Pressure and TemperatureControl safety function.Scenario Quantitative Attributes1. Malfunctions after EOP entry (1-2)22. Abnormal events (2-4)23. Major transients (1-2)24. EOPs entered/requiring substantive actions (1-2)25. EOP contingencies requiring substantive actions (0-2)16. EOP based Critical tasks (2-3)2 NRC Scenario 1- 4 -2015 NRC Exam Scenario 1 D-1 Rev 1SCENARIO SETUPA. Reset Simulator to IC-161B. Verify Scenario Malfunctions and Remotes are loaded, as listed in the Scenario Timeline.C. Place LPSI pump A control switch in 'OFF' with a Danger tag.D. Ensure Protected Train B sign is placed in SM office window.E. Verify EOOS is 10.0 Green with LPSI Pump A removed.F. Complete the simulator setup checklist.G. Start Insight, open file Crew Performance.tis.
NRC Scenario 1- 5 -2015 NRC Exam Scenario 1 D-1 Rev 1SIMULATOR BOOTH INSTRUCTIONSEvent 1 Plant Down Power1. If the Senior Line Manager/Duty Plant Manager is called, acknowledge the report and inform theControl Room that you will remain in the protected area for the down power.2. If Woodlands (Load Dispatcher) is called, acknowledge the report.Event 2 Containment Pressure PPS Channel D (CIAS) CB-IPI-6701SMD Fails High1. On Lead Examiner's cue, initiate EventTrigger 2.2. If Work Week Manager or PMI are called, inform the caller that a work package will be assembledand a team will be sent to the Control Room.Event 3 Steam Generator #1 Feedwater Flow Instrument FW-IFR-1111 Fails Low1. On Lead Examiner's cue, initiate EventTrigger 3.2. If Work Week Manager or PMI are called, inform the caller that a work package will be assembledand a team will be sent to the Control Room.Event 4 Pressurizer Level Control Channel Level Transmitter, RC-ILT-0110X, Fails High1. On Lead Examiner's cue, initiate EventTrigger 4.2. If Work Week Manager or PMI are called, inform the caller that a work package will be assembledand a team will be sent to the Control Room.3. If sent to LCP-43, wait 3 minutes and report indicator RC-ILI-0110-X1 appears to be failed high. Ifasked to report Ch. 'Y', report value as read on Extreme View.Event 5 Seismic Event / Loss of Offsite power / Turbine Trip / 2 Stuck CEAs1. On Lead Examiner's cue, initiate EventTrigger 5.2. If the Duty Plant Manager is called, inform the caller that you will make the necessary calls.3. If requested to check Emergency Diesel Generators (EDG), wait 3 minutes and report EDGs areoperating properly. Initiate event triggers 20&21 to acknowledge local annunciator panels.4. If called as an NAO to locally close MSR temperature control valves, wait 5 minutes, initiate eventtrigger 22 and report all MSR temperature valves are closed.5. If called as an NAO to align power to the DCT sump pumps, wait 5 minutes, run schedule file"Re-energize A(B) Powered DCT Sump Pumps.sch" as appropriate and make report to theControl Room after the schedule file completes all actions.6. If called as an NAO to align Potable Water to Instrument Air compressors, wait 5 minutes, runschedule file "IA Comp A(B) Align to PW.sch" as appropriate and make report to the ControlRoom after the schedule file completes all actions.Event 6/7 Large RCS Cold Leg break / Containment Spray Fails to AUTO Actuate1. On Lead Examiner's cue, initiate EventTrigger 6.2. If the Duty Plant Manager is called, inform the caller that you will make the necessary calls.3. If Chemistry is called to perform samples acknowledge the request.
NRC Scenario 1- 6 -2015 NRC Exam Scenario 1 D-1 Rev 1Event 8 Low Pressure Safety Injection Pump B Trips / Align CS to replace LPSI1. On Lead Examiner's cue, initiate EventTrigger 7.2. If the Duty Plant Manager is called, inform the caller that you will make the necessary calls.3. If Chemistry is called to perform samples acknowledge the request.4. If called as an NAO to investigate the trip at the breaker, report overcurrent flags on all 3 phases.5. If called as an NAO to investigate the trip at the pump, report that there is no oil visible on themotor bearing sightglass and oil is dripping from the motor housing.6. If called as an NAO to rack out LPSI pump B breaker or open the knife switch, wait 2 minutes andreport that you will be opening the knife switch for LPSI pump B, then initiate event trigger 8(SIR33). Make report to the Control Room that you have done so.7. If called as an NAO to place CS-125B override keyswitch in "Override", wait 2 minutes and theninitiate event trigger 9 (CSR13B) to place CS-125B in override. Make report to the Control Roomthat you have done so.8. If called as an NAO to locally close SI-129B, wait 3 minutes and then initiate event trigger 23(SIR50 & SIR51) to close SI-129B. Pull up Extreme View - LP Safety Injection to check positionand make report to the Control Room that you have done so.
9.At the end of the scenario, before resetting, complete data collection by saving the file as2015 Scenario 1-(start-end time).tid. Export to .csv file. Save the file into the folder for theappropriate crew.
NRC Scenario 1- 7 -2015 NRC Exam Scenario 1 D-1 Rev 1SCENARIO TIMELINEEVENT KEYDESCRIPTIONTRIGGERDELAYHH:MM:SSRAMPHH:MM:SSFINALEVENT DESCRIPTIONN/ASIR32LPSI PUMP A BREAKER RACKED OUT (Not listed in Summary)N/AN/AN/ARKOUTLOW PRESS SAFETY INJECTION PUMP A TAGGED OUT 1N/AN/AN/AN/AN/AN/APLANT DOWN POWER 2 CH08E1CNTMT PRESS TRANSMITTER 6701 SMD FAILS HI 200:00:0000:00:00ACTIVECONTAINMENT PRESSURE PPS CHANNEL D (CIAS) CB-IPI-6701SMD FAILS HIGH 3FW26A SG1 FEED FLOW INST FAILS LOW TO 17%
300:00:0000:00:1017%STEAM GENERATOR #1 FEEDWATER FLOW INSTRUMENT FW-IFR-1111 FAILS LOW 4RC15A1PZR LEVEL CONTROL CHANNEL, RC-ILT-0110X, FAILS HIGH 400:00:0000:00:00ACTIVEPRESSURIZER LEVEL CONTROL CHANNEL LEVEL TRANSMITTER, RC-ILT-0110X, FAILS HIGH 5L_L10SEISMIC RECORDERS IN OPERATION (Delete after 30 Seconds) 500:00:0000:00:00 FAIL_ONSEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5L_M10SEISMIC EVENT 500:00:0000:00:00FAIL_ONSEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5ED01A LOSS OF OFFSITE POWER (LINE A) 500:00:0300:00:00 ACTIVESEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5 ED01BLOSS OF OFFSITE POWER (LINE A) 500:00:0300:00:00ACTIVESEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5ED01C LOSS OF OFFSITE POWER (LINE B) 500:00:0700:00:00 ACTIVESEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5 ED01DLOSS OF OFFSITE POWER (LINE B) 500:00:0700:00:00ACTIVESEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS NRC Scenario 1- 8 -2015 NRC Exam Scenario 1 D-1 Rev 1EVENT KEYDESCRIPTIONTRIGGERDELAYHH:MM:SSRAMPHH:MM:SSFINALEVENT DESCRIPTION 5TU06TURBINE TRIP 500:00:0700:00:00 ACTIVESEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5RD11A32CEA 32 MECHANICALLY STUCKN/A00:00:0000:00:00ACTIVESEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5RD11A47 CEA 47 MECHANICALLY STUCKN/A00:00:0000:00:00 ACTIVESEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 6RC23ARCS COLD LEG 1A RUPTURE 600:00:0000:03:0014%LARGE RCS COLD LEG BREAK / CONTAINMENT SPRAY FAILS TO AUTO ACTUATE 7RP05A3 FAILS TO TRIP CH A HI-HI CONT. PRESS (CSAS)N/A00:00:0000:00:00 ACTIVELARGE RCS COLD LEG BREAK / CONTAINMENT SPRAY FAILS TO AUTO ACTUATE 7 RP05B3FAILS TO TRIP CH B HI-HI CONT. PRESS (CSAS)N/A00:00:0000:00:00ACTIVELARGE RCS COLD LEG BREAK / CONTAINMENT SPRAY FAILS TO AUTO ACTUATE 7RP05C3 FAILS TO TRIP CH C HI-HI CONT. PRESS (CSAS)N/A00:00:0000:00:00 ACTIVELARGE RCS COLD LEG BREAK / CONTAINMENT SPRAY FAILS TO AUTO ACTUATE 7 RP05D3FAILS TO TRIP CH D HI-HI CONT. PRESS (CSAS)N/A00:00:0000:00:00ACTIVELARGE RCS COLD LEG BREAK / CONTAINMENT SPRAY FAILS TO AUTO ACTUATE 8SI01ELOSS OF LOW PRESS SAFETY INJECTION PUMP B 700:00:0000:00:00 ACTIVELOW PRESS SAFETY INJECTION PUMP B TRIPS / ALIGN CS PUMP B TO REPLACE LPSI PUMP B 8SIR33LPSI PUMP B BREAKER RACKED OUT 8N/AN/ARKOUTLOW PRESS SAFETY INJECTION PUMP B TRIPS / ALIGN CS PUMP B TO REPLACE LPSI PUMP B 8CSR13B CS-125B OVERRIDE KEYSWITCH 9N/AN/AOVRDLOW PRESS SAFETY INJECTION PUMP B TRIPS / ALIGN CS PUMP B TO REPLACE LPSI PUMP B NRC Scenario 1- 9 -2015 NRC Exam Scenario 1 D-1 Rev 1EVENT KEYDESCRIPTIONTRIGGERDELAYHH:MM:SSRAMPHH:MM:SSFINALEVENT DESCRIPTIONN/AEGR26EDG A LOCAL ANNUN ACK 20N/AN/AACKNEDG A LOCAL ANNUNCIATOR PANELN/AEGR27 EDG B LOCAL ANNUN ACK 21N/AN/AACKNEDG B LOCAL ANNUNCIATOR PANELN/AMSR43CLOSE MSR TEMPERATURE CNTRL VALVES 22N/AN/A CLSDCLOSE MSR TEMPERATURE CNTRL VALVESN/ASIR50SI-129B - SDC B FCV CONTROL 23N/AN/ALOCALSI-129B - SDC B FCV CONTROLN/ASIR51SI-129B - SDC B FCV POSITION 2300:00:0500:00:00 0%SI-129B - SDC B FCV POSITION NRC Scenario 1- 10 -2015 NRC Exam Scenario 1 D-1 Rev 1REFERENCESEventProcedures 1OP-010-005, Plant Shutdown, Rev. 326OP-002-005, Chemical and Volume Control, Rev. 47OP-005-007, Main Turbine and Generator, Rev. 303OP-004-004, Control Element Drive, Rev. 19 2OP-009-007, Plant Protection System, Rev. 16OP-903-013, Monthly Channel Checks, Rev. 18Technical Specification 3.3.1Technical Specification 3.3.2 3OP-901-201, Steam Generator Level Control Malfunction, Rev. 6EN-OP-115, Conduct of Operations, Rev. 15Tech Requirement Manual 3.3.5 4OP-901-110, Pressurizer Level Control Malfunction, Rev. 8OP-903-013, Monthly Channel Checks, Rev. 18Technical Specification 3.3.3.5Technical Specification 3.3.3.6 5OP-902-000, Standard Post Trip Actions, Rev. 15OP-901-103, Emergency Boration, Rev. 3OP-902-009, Standard Appendices, Rev. 310, Appendix 1 (Diagnostic Flow Chart),Appendix 2 (Figures) 6OP-902-002, Loss of Coolant Accident Recovery Procedure, Rev. 19OP-902-009, Standard Appendices, Rev. 310, Appendix 1 (Diagnostic Flow Chart),Appendix 2 (Figures) 7EN-OP-115, Conduct of Operations, Rev. 15 8OP-902-008, Functional Recovery Procedure, Rev. 23OP-902-009, Standard Appendices, Rev. 310, Appendix 27 (Aligning CS to replace LPSI),and Appendix 21 (Overrides for Containment Isolation)
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #1 Page 1 of 34Event
 
== Description:==
Normal Plant Down PowerTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0Examiner NoteEvent 1 is a normal plant evolution. The crew will be pre-briefed and ready to start the downpower once they take the shift.OP-010-005, Section 9.1, Plant Shutdown to Hot Standby SRO9.1.6 Begin RCS boration in accordance with OP-002-005, Chemical andVolume Control to reduce Reactor power.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #1 Page 2 of 34Event
 
== Description:==
Normal Plant Down PowerTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0(note)The SRO directs the ATC to coordinate with the BOP and perform aplant down power to ~90%. The SRO will direct the ATC to initiate RCSboration in accordance with OP-002-005. SRO direction should includean RCS temperature band and instructions on how to maintain ASIusing CEAs.CAUTIONCONTROL RODS SHOULD NEVER BE WITHDRAWN OR MANUALLY INSERTED EXCEPT IN ADELIBERATE CAREFULLY CONTROLLED MANNER WHILE CLOSELY MONITORING THEREACTOR'S RESPONSE.
SRO9.1.7 Maintain ASI using CEA Reg. Group 5, 6 or Group P ControlElement Assemblies in accordance with Attachment 9.10, AxialShape Control Guidelines. (Refer to T.S. 3.1.3.6).
SRO9.1.8 When Average Reactor Coolant Temperature (Tavg) begins to drop,then reduce Generator load to match Tavg and ReferenceTemperature (Tref) in accordance with OP-005-007, Main Turbineand Generator.NOTE(1) If USBSCAL is not in service, the COLSS Steam Calorimetric will be automatically disabled whenMSBSCAL (PMC PID C24246) drops below 95% Power, and will revert back to FWBSCAL (PMC PID C24235).(2) If USBSCAL is not in service, there may be a step change in COLSS indicated Plant Power of1.0%, when COLSS Steam Calorimetric is disabled.
SRO9.1.9 When reactor power consistently indicates less than 98% power, asindicated 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 1.9.1.9.1  If C24648 does not automatically change to 1, then informReactor Engineering and set the value of 1 for COLSS powersmoothing constant K24250, [ADDRSSBL SMOOTHING FORBSCAL (ALPHA)] in accordance with OP-004-005, CoreOperating Limits Supervisory System.OP-002-005, Section 6.7, Direct Boration to RCSCAUTIONTHE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #1 Page 3 of 34Event
 
== Description:==
Normal Plant Down PowerTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0CAUTION (1) THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSSCHECKEDAND COMPLETED PRIOR TO LEAVING CP-4.(2) AT LEAST ONE REACTOR COOLANT PUMP IN EACH LOOP SHOULD BE OPERATING PRIORTO PERFORMING DIRECT BORATION OPERATIONS TO ENSURE PROPER CHEMICAL MIXING.
ATC6.7.1 Inform SM/CRS that this Section is being performed.NOTEWhen 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 BoronPPM 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)ATC6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be addedon Attachment 11.6, Calculation of Boric Acid Volume for DirectBoration or VCT Borate Makeup Mode.
ATC6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Aciddesired.(note)Procedure does not give specific steps to set the counter. 155 gal ofacid on the counter is set by pressing: UP arrow button ENTER button the side arrow button to move the cursor the raise button toenter 155 ( per reactivity plan) ENTER RESET ATC6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desiredBoric Acid Makeup Pump A(B).
ATC6.7.5 Place Direct Boration Valve, BAM-143, control switch to AUTO.
ATC6.7.6 Place Makeup Mode selector switch to BORATE.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Normal Plant Down PowerTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 ATC6.7.7 Verify selected Boric Acid Makeup Pump A(B) Starts.
ATC6.7.8 Verify Direct Boration Valve, BAM-143, Opens.NOTEThe Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is mostaccurate in the range of 10 - 25 GPM.(note)ATC will likely use manual boric acid flow control. "CVCS Boric AcidMakeup Flow Hi/Lo" on CP-4 is an expected annunciator.
ATC6.7.9 If manual control of Boric Acid flow is desired, then perform thefollowing: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 >3GPM flow rate.
ATC6.7.10 If automatic control of Boric Acid flow is desired, then perform thefollowing:6.7.10.1 Place Boric Acid Flow controller, BAM-IFIC-0210Y, in Auto.6.7.10.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, setpointpotentiometer to >3 GPM flow rate.
ATC6.7.11 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate orOpen.ATC6.7.12 Observe Boric Acid flow rate for proper indication.
ATC6.7.13 When Boric Acid Makeup Batch Counter has counted down todesired value, then verify Boric Acid Makeup Control Valve, BAM-141, Closed.NOTEStep 6.7.14 may be repeated as necessary to achieve desired total boron addition for plant conditions.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #1 Page 5 of 34Event
 
== Description:==
Normal Plant Down PowerTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 ATC6.7.14 If additional boric acid addition is required and with SM/CRSpermission, then perform the following:6.7.14.1 Reset Boric Acid Makeup Batch Counter.6.7.14.2 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediateor Open.6.7.14.3 Observe Boric Acid flow rate for proper indication.6.7.14.4 When Boric Acid Makeup Batch Counter has counted down todesired value, then verify Boric Acid Makeup Control Valve, BAM-141, Closed.(note)The ATC, with the SRO's direction, may secure boric acid addition atany time by lowering the output on the acid flow controller to zero orby closing BAM-143. Steps 6.7.15-6.7.20 secure the full acid additionlineup.ATC6.7.15 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual.
ATC6.7.16 Verify both Boric Acid Flow controller, BAM-IFIC-0210Y, output andsetpoint potentiometer set to zero.
ATC6.7.17 Place Makeup Mode selector switch to MANUAL.
ATC6.7.18 Verify Selected Boric Acid Makeup Pump A(B) Stops.
ATC6.7.19 Verify Direct Boration Valve, BAM-143, Closed.
ATC6.7.20 Place Direct Boration Valve, BAM-143, control switch to CLOSE.OP-005-007, Section 6.2, Main Turbine & Generator OperationCAUTIONTHE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY. REACTORPOWER, RCS TEMPERATURE, AND MAIN GENERATOR MW LOAD SHOULD BE CLOSELYMONITORED DURING PERFORMANCE OF THIS SECTION. [INPO 06-006]
BOP6.2.1 To change Load/Rate perform the following:6.2.1.1  Depress LOAD/RATE MW/MIN pushbutton.6.2.1.2  Depress appropriate numerical pushbuttons for desired loadrate.6.2.1.3  Depress ENTER pushbutton.NOTEPrior to changing Reference Demand, Main Turbine load must not be changing.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #1 Page 6 of 34Event
 
== Description:==
Normal Plant Down PowerTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 BOP6.2.2 To change Main Turbine load, perform the following:6.2.2.1  Depress REF pushbutton.6.2.2.2  Depress appropriate numerical pushbuttons for desired MWload.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.OP-004-004, Section 6.7, Operation of CEAs in Manual Group (MG) ModeCAUTION(1) CRITICALITY SHALL BE ANTICIPATED ANY TIME CEAS ARE WITHDRAWN AND THEREACTOR IS NOT CRITICAL.(2) OBSERVE APPLICABLE GROUP INSERTION LIMITS IN ACCORDANCE WITH TECHNICALSPECIFICATION 3.1.3.6 (REG GROUP), AND TECHNICAL SPECIFICATION 3.1.3.5 (SHUTDOWN BANKS).(3) IMPROPER OPERATION OF CEAS IN MANUAL GROUP MODE MAY CAUSE A REACTOR TRIPBASED ON AN OUT-OF-SEQUENCE CONDITION.(4) CEA INITIALIZATION PROGRAM MUST BE RUNNING IN THE PLANT MONITORINGCOMPUTER TO HAVE GROUP STOPS AND SEQUENTIAL PERMISSIVES AVAILABLE.CAUTIONTHE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY. [INPO 06-006]
ATC6.7.1 Verify Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer.
ATC6.7.2 Position Group Select switch to desired group.
ATC6.7.3 Place Mode Select switch to MG and verify the following: White lights Illuminated on Group Selection Matrix for selected group MG light Illuminates ATC6.7.4 Operate CEA Manual Shim switch to WITHDRAW or INSERT groupto desired height while monitoring the following: CEA Position Indicator selected CEA group is moving in desireddirection If Reactor is critical, then monitor the following: Reactor Power Reactor Coolant System (RCS) temperature Axial Shape Index (ASI)
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #1 Page 7 of 34Event
 
== Description:==
Normal Plant Down PowerTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0NOTEThe Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when theMode Select switch is not in OFF.
ATC6.7.5 When desired set of moves have been completed, then place ModeSelect switch to OFF.Examiner NoteThis event is complete when both the ATC and BOP have performed actions to commence aplant down power and the reactivity manipulation is performed ORAs directed by the Lead EvaluatorExaminer NoteCue the Simulator Operator when ready for Event 2 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #2 Page 8 of 34Event
 
== Description:==
Containment Pressure PPS Channel D (CIAS), CB-IPI-6701SMD, fails highTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0ATC/BOP Recognizes and reports indications of failed channel.Alarms: RPS CHANNEL TRIP CNTMT PRESSURE HI (Cabinet K, A-17) CNTMT PRESSURE HI PRETRIP B/D (Cabinet K, C-17) RPS CHANNEL D TROUBLE (Cabinet K, H-18) ESFAS CHANNEL TRIP CNTMT PRESSURE HI (Cabinet K, L-17) CNTMT PRESSURE HI ESFAS PRETRIP B/D (Cabinet K, N-17)Indications: PPS Channel D Containment Pressure (CIAS), CB-IPI-6701SMD failedhigh on CP-7 All other Containment Pressure instruments reading normal on CP-7 Pretrip and Trip Bistable Lights illuminated for Containment Pressure HICNT PRESS (RPS and ESF) on Channel D CP-7 ROM.OP-009-007, Plant Protection System ,Section 6.2, Trip Channel Bypass Operation(note)All BOP manipulations for OP-009-007 are located at CP-10 (backpanel) except as noted.
SRO6.2.1 Refer to Attachment 11.11, PPS Bistable Bypass Chart to assist indetermination of Trip Channels requiring placement in bypass.(note)SRO determines the following bistables are affected and need to bebypassed: 13-HI CNT PRESS(RPS) 16-HI CNT PRESS(SIAS/CIAS/MSIS)
SRODirects BOP to bypass the HI CNT PRESS(RPS) and HI CNT PRESS(SIAS/CIAS/MSIS) bistables in PPS Channel D within 1 hour in accordancewith OP-009-007, Plant Protection System.
BOP6.2.2 To place a bistable in or remove a bistable from bypass, go toAttachment 11.10, Trip Channel Bypass Operation.
BOP11.10.1 To Bypass a Trip Channel, perform the following:11.10.1.1 Circle the bistable numbers selected for bypass underStep 11.10.1.4.(note)BOP circles bistable numbers 13 and 16 in Step 11.10.1.4 table Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #2 Page 9 of 34Event
 
== Description:==
Containment Pressure PPS Channel D (CIAS), CB-IPI-6701SMD, fails highTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 BOP11.10.1.2 Check desired Trip Channel is not Bypassed on another PPSChannel.BOP11.10.1.3 Open key-locked portion of BCP in desired PPS Channel.
BOP11.10.1.4 Depress Bypass push buttons for the desired Trip Channels BOP11.10.1.5 Check all selected bistable Bypass push buttons remain in aDepressed state.
BOP11.10.1.6 Check all selected bistable Bypass lights Illuminate on BCP forthe desired Trip Channels.CREW11.10.1.7 Check all selected bistable Bypass lights Illuminate on ROM forthe desired Trip Channels.(note)Crew verifies correct bistables lit on CP-7 PPS Channel D RemoteOperator Module.
SROReviews the following Technical Specifications and determines applicableactions: 3.3.1 action 2 3.3.2 actions 13 3.3.3.5 - no actions required 3.3.3.6 - no actions requiredExaminer NoteThis event is complete when bistables are bypassed and Technical Specifications have beenaddressed ORAs directed by the Lead EvaluatorExaminer NoteCue the Simulator Operator when ready for Event 3 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #3 Page 10 of 34Event
 
== Description:==
Steam Generator #1 Feedwater flow instrument FW-IFR-1111 fails lowTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 BOPRecognize and report indications of Feedwater flow instrument failure.Alarms: Steam Generator 1 Steam/FW Flow Signal Dev (Cabinet F, T-17) Steam Generator 2 Steam/FW Flow Signal Dev (Cabinet F, U-17) SG 1 Level Hi/Lo (Cabinet F, U-14) COLSS MASTER (Cabinet L, A-6)Indications: Feedwater Flow indicator FW-IFR-1111 fails low Steam Generator 1 Level Rising (SG-ILR1-1105 and 1111) Deviation between steam flow AND feedwater flow on SG 1(note)The Ultrasonic Flow Meter quality goes to BAD on this malfunction.The ATC should not disrupt the CRS and the BOP when trying tostabilize S/G #1 level. The ATC should inform the CRS after the plant isstable and the flow chart is complete. TRM 3.3.5 entry is required on afailure of the UFM.Examiner NoteWhen a control system is not operating properly in automatic, it is acceptable for the SRO todirect taking manual control prior to entering the appropriate procedure.
SRODirects BOP to take manual control of Feedwater Control System 1 (FWCS)and match Feedwater flow and Steam flow on Steam Generator 1 andrestore level to 50-70% NR.
BOPWill take manual control of FWCS 1 and Match Feedwater Flow and SteamFlow.SROEnters and directs the implementation of OP-901-201, Steam GeneratorLevel MalfunctionOP-901-201, Steam Generator Level Malfunction, E0, General SRO1. Go to Attachment 1, General Actions.OP-901-201, Steam Generator Level Malfunction, Attachment 1, General Actions SRODid a Reactor Trip occur?NO - continue with flowchart Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #3 Page 11 of 34Event
 
== Description:==
Steam Generator #1 Feedwater flow instrument FW-IFR-1111 fails lowTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0SRO/BOPObserve the affected Steam Generator FWCS controllersANDnoteANYcontrollers that are behaving erratically.Steam Generator 1FW IFIC 1111 , S/G 1 FWCS Master ControllerFW IHIC 1111 , S/G 1 Main FRV ControllerFW IHIC 1105 , S/G 1 S / U FRV ControllerFW IHIC 1107 , SGFP A Speed ControllerSteam Generator 2FW IFIC 1121 , S/G 2 FWCS Master ControllerFW IHIC 1121 , S/G 2 Main FRV ControllerFW IHIC 1106 , S/G 2 S / U FRV ControllerFW IHIC 1108 , SGFP B Speed Controller(note)BOP should determine that no controllers are malfunctioning.N/APlace appropriate controllers for the affected FWCS in manualANDestablish control of S/G level.(note)Controllers already in MANUAL (prior order)SRO/BOP Is the output of the affected FWCS Master Controller behaving erratically?(note)NO - continue with flowchartSRO/BOPVerifySGFP Discharge pressure for BOTH SGFP ' s is matchedAND isgreater than S / G pressures.(note)BOP verifies - continue with flowchart SROStop turbine load changes except to match Tave and Tref.(note)SRO should direct ATC/BOP to stop downpower and stabilize theplant. ATC will secure adding boric acid to the RCS and the BOP willstop turbine load reduction. After stopping the downpower, Turbineload adjustment is allowed to match Tave and Tref.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #3 Page 12 of 34Event
 
== Description:==
Steam Generator #1 Feedwater flow instrument FW-IFR-1111 fails lowTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0SRO/BOPReview the following guidelinesANDrestore S /G level to 50-70% NR:
1.IFone SGFP Speed controller is in auto, THENuse its output to help setthe SGFP Speed controller that is in manual.2. Momentary taps on the raiseANDlower buttons of the Main FeedwaterReg Valve Controller have a noticeable impact on associated SteamGenerator level.3. Use the Startup Feedwater Reg Valve Controller to control SteamGenerator level at low power levels.4. Use indications on the unaffected FWCS controllers to help set affectedFWCS controllers.(note)SRO & BOP review guidanceSRO/BOPCheck the following Control Channel indicators to determine if a ControlChannel has failed: (See Note 3) FW IFR 1111, Steam Generator 1 Feedwater Flow (green pen ) FW IFR 1011, Steam Generator 1 Steam Flow (red pen ) FW IFR 1121, Steam Generator 2 Feedwater Flow (green pen ) FW IFR 1021, Steam Generator 2 Steam Flow (red pen ) SG ILR1111, Steam Generator 1 Downcomer Level (green pen ) SG ILR1105, Steam Generator 1 Downcomer Level (red pen ) SG ILR1121, Steam Generator 2 Downcomer Level (green pen ) SG ILR1106, Steam Generator 2 Downcomer Level (red pen )(note)BOP should determine FW IFR 1111, Steam Generator 1 FeedwaterFlow (green pen) is failed low.
SROControl Channel level deviation of > 7%?(note)NO - continue with flowchart SROMain Feedwater Pump Speed Controller malfunction?(note)NO - continue with flowchart SROIs feedwater flow for the affected SG abnormally high?(note)NO-continue with flowchartSRO/BOPDetermineANDcorrectthe cause of themalfunction
.(note)BOP should report which controllers are still in MANUAL. SRO andBOP should discuss contingency actions for FWCS 1 being inMANUAL. SRO will conduct a brief at this point.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #3 Page 13 of 34Event
 
== Description:==
Steam Generator #1 Feedwater flow instrument FW-IFR-1111 fails lowTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0Examiner NoteThis event is complete after the SRO has completed the flowchart and Steam Generator 1 levelis being controlled ORAs directed by the Lead Evaluator.Examiner NoteCue the Simulator Operator when ready for Event 4 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #4 Page 14 of 34Event
 
== Description:==
Pressurizer Level Control Channel Level Transmitter, RC-ILT-0110X, fails highTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 ATCRecognize and report indications of failed instrument.Alarms: PRESSURIZER LEVEL HI/LO (Cabinet H, B-1) PRESSURIZER LEVEL HI-HI (Cabinet H, A-1) LETDOWN FLOW HI/LO (Cabinet G, C-1) LETDOWN HX OUTLET PRESS HI (Cabinet G, A-2)Indications Mismatch between Charging (CVC-IFI-0212) AND Letdown (CVC-IFI-0202) flow indications. Letdown rises to maximum, with 1 chargingpump running Deviation between indicated level AND programmed level as indicatedon Pressurizer level recorder (RC-ILR-0110). RC-ILI-0110X reading ~ 100% Actual Pressurizer level RC-ILI-0110Y slowly lowering. Pressurizer Backup Heaters energize(note)SRO may direct the ATC to take manual control of Pressurizer LevelController, RC-ILIC-0110 and match Letdown flow and Charging flowprior to entering procedure.
SROEnter and direct the implementation of OP-901-110, Pressurizer LevelControl Malfunction.OP-901-110, Section E0, General Actions SRO 1.Stop Turbine load changes.(note)If not already performed in the previous event, the SRO should directATC/BOP to stop downpower. ATC will secure adding boric acid to theRCS and the BOP will stop turbine load reduction. After stopping thedownpower, Turbine load adjustment is allowed to match Tave andTref.N/A 2.IF malfunction is due to failure of Letdown Flow Control valve, THENgo to OP-901-112, CHARGING/LETDOWN MALFUNCTION.
SRO 3.IF malfunction is due to failure of Pressurizer Level Control Channel(incorrect readings on either RC-ILI-0110X OR RC-ILI-0110Y), thengo to Subsection E 1, Pressurizer Level Control Channel Malfunction.OP-901-110, Section E1, Pressurizer Level Control Channel Malfunction Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #4 Page 15 of 34Event
 
== Description:==
Pressurizer Level Control Channel Level Transmitter, RC-ILT-0110X, fails highTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0NOTESelecting the non-faulted channel may cause automatic actions to occur if actual level is not atprogram level.
ATC1. Place Pressurizer Level Controller (RC-ILIC-0110) in MAN and adjustOUTPUT to slowly adjust letdown flow to restore Pressurizer level.
ATC2. Transfer Pressurizer Level Control CHANNEL SELECT switch to non-faulted channel.
ATC3. Transfer Pressurizer CHANNEL SELECT LO LEVEL HEATERCUTOFF switch to non-faulted channel.
ATC4. Verify desired backup Charging pumps in AUTO.
ATC5. Verify all PROPORTIONAL and BACKUP HEATER BANKS reset.
ATC6. Place Pressurizer Level Controller (RC-ILIC-0110) in AUTO and verifyPressurizer Level is being restored to setpoint.
ATC7. Verify Pressurizer level controlling at program setpoint in accordancewith Attachment 1, Pressurizer Level Versus Tave Curve.
SRO8. Refer to the following Technical Specifications for Operabilitydetermination. 3.2.8, Power Distribution Systems, Pressurizer Pressure 3.3.3.5, Instrumentation, Remote Shutdown Instrumentation 3.3.3.6, Instrumentation, Accident Monitoring Instrumentation 3.4.3.1, Reactor Coolant System, Pressurizer(note)The SRO should review Technical Specifications 3.3.3.5 and 3.3.3.6and OP-903-013, Monthly Channel Checks. The SRO should determinethat TS 3.3.3.6 requirements are met, but enter TS 3.3.3.5 Action a.Examiner NoteThis event is complete after Pressurizer Level Control System is selected to non-faultedchannel and returned to automatic operation and Technical Specifications have beenaddressed ORAs directed by the Lead Evaluator Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #4 Page 16 of 34Event
 
== Description:==
Pressurizer Level Control Channel Level Transmitter, RC-ILT-0110X, fails highTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0Examiner NoteCue the Simulator Operator when ready for Event 5EventTrigger 5 will initiate seismic event alarms, loss of offsite power, and a turbine trip. All will occurin less than 10 seconds and will result in an automatic reactor trip.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #5 Page 17 of 34Event
 
== Description:==
Seismic Event / Loss of Offsite Power / Turbine Trip / 2 Stuck CEAsTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0ATC/BOP Recognize and report indications of Seismic Event / Loss of Offsite Power /Turbine Trip / Reactor Trip / 2 stuck CEAsAlarms: SEISMIC RECORDERS IN OPERATION (Cabinet L, L-10) SEISMIC EVENT (Cabinet L, M-10) SWITCHING STATION TROUBLE(Cabinet D, T-7) 230 KV LINE A VOLTAGE LOST (Cabinet D, U-7) 230 KV LINE B VOLTAGE LOST (Cabinet D, U-8)Indications: Turbine Tripped (All Turbine Valves closed on CP-1 mimic) Reactor Tripped (All except two rod bottom lights illuminated) CEA 32 and 47 Rod Bottom Lights NOT illuminated and their UpperElectrical Limit (red) lights remain illuminated Lights in the Control Room dim and re-energize when EDGs tie to theirrespective safety buses SRODirects ATC and BOP to carry out Standard Post trip Actions.OP-902-000, Standard Post Trip Actions (STPAs)CRITICAL TASK 1ESTABLISH REACTIVITY CONTROLThis task is satisfied by establishing emergency boration prior to exiting OP-902-000, StandardPost Trip Actions.This task becomes applicable after the reactor trips.
ATC1. DetermineReactivity Control acceptance criteria are met:a. Check reactor power is dropping.b. Check startup rate is negative.c. Check less thanTWOCEAs are NOTfully inserted.Examiner NoteATC is required to emergency borate due to criteria 1.c NOT met.Emergency Boration steps:
ATC1. If Charging is available, then perform the following:
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #5 Page 18 of 34Event
 
== Description:==
Seismic Event / Loss of Offsite Power / Turbine Trip / 2 Stuck CEAsTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 ATC1.1 Place Makeup Mode selector switch to MANUAL. (CRITICAL)ATC1.2 Align borated water source by performing one of the following (a or b):a. Initiate Emergency Boration using Boric Acid Pump as follows: Open Emergency Boration Valve, BAM-133.
(CRITICAL) Start one Boric Acid Pump. (CRITICAL) Close recirc valve for Boric Acid Pump started: BAM-126A Boric Acid Makeup Pump RecircValve A (CRITICAL)or BAM-126B Boric Acid Makeup Pump RecircValve B (CRITICAL)ORb. Initiate Emergency Boration using Gravity Feed as follows: Open the following Boric Acid Makeup Gravity Feedvalves: BAM-113A Boric Acid Makeup Gravity FeedValve A (CRITICAL) BAM-113B Boric Acid Makeup Gravity FeedValve B (CRITICAL)ATC1.3 Close VCT Disch Valve, CVC-183. (CRITICAL)ATC1.4 Verify at least one Charging Pump operating and Charging Header flowgreater than or equal to 40 GPM. (CRITICAL)OP-902-000, Standard Post Trip Actions (continued)
BOP2. DetermineMaintenance of Vital Auxiliariesacceptance criteria aremet:a. Check the Main Turbine is tripped: Governor valves closed Throttle valves closed BOPb. Check the Main Generator is tripped: GENERATOR BREAKER A tripped GENERATOR BREAKER B tripped EXCITER FIELD BREAKER tripped Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #5 Page 19 of 34Event
 
== Description:==
Seismic Event / Loss of Offsite Power / Turbine Trip / 2 Stuck CEAsTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 BOPc. Check station loads are energized from offsite electrical power asfollows: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 ChannelTrain 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 BOP c.1 IFANY 4.16 KV safety bus is NOT powered from offsite, THEN:1) Verify associated EDG has startedAND EDG output breakerclosed.2)IF EDG output breaker isNOT closedTHEN: Verify stable EDG Voltage 3920 - 4350 AC Volts. Verify 3-2 Breaker open. Check Sequencer LOCKOUTNOT illuminated.
3)IF EDG output breaker isNOT closedAND Step c.1.2) is metTHEN locally close EDG output breaker.4) Verify CCW cooling available to EDG.(note)BOP should verify Component Cooling Water pumps running on CP-8 ATC3. DetermineRCS Inventory Control acceptance criteria are met:a. Check thatBOTH the following conditions exist: Pressurizer level is 7% to 60% Pressurizer level is trending to 33% to 60%b. Check RCS subcooling is greater than or equal to 28&#xba;F.(note)The ATC should use CET subcooling on QSPDS or CP-7 to determineRCS subcooling due to the loss of RCPs.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #5 Page 20 of 34Event
 
== Description:==
Seismic Event / Loss of Offsite Power / Turbine Trip / 2 Stuck CEAsTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 ATC4. DetermineRCS Pressure Control acceptance criteria are met bychecking thatBOTH of the following conditions exist: Pressurizer pressure is 1750 psia to 2300 psia Pressurizer pressure is trending to 2125 psia to 2275 psia ATC5. DetermineCore Heat Removal acceptance criteria are met:a. Check at least one RCP is operating.b. Check operating loop T is less than 13&#xba;F.c. Check RCS subcooling is greater than or equal to 28&#xba;F.(note)Core Heat Removal safety function will not be met. All Reactor CoolantPumps (RCPs) will be stopped due to loss of power; Operators shouldmonitor for natural circulation conditions 5-15 minutes after the loss of RCPs.BOP6. DetermineRCS Heat Removal acceptance criteria are met:a. Check that at least one steam generator hasBOTH of the following: Steam generator level is 10% to 76% NR Main Feedwater is available to restore level within 55%-70%
NR. [60-80% NR]
.BOPa2. Verify Emergency Feedwater is available to restore level in at leastone steam generator within 55%-70% NR[60-80% NR]
.(note)Main Feedwater will not be available. BOP should perform contingencyaction a2.
ATCb. Check RCS TC is 530 &#xba;F to 550 &#xba;F BOPc. Check steam generator pressure is 885 psia to 1040 psia.
BOPd. Check Feedwater Control in Reactor Trip Override: MAIN FW REG valves are closed STARTUP FW REG valves are 13% to 21% open Operating main Feedwater pumps are 3800 rpm to 4000 rpm(note)If FWCS 1 controllers were in manual prior to the reactor trip, the BOPshould manually place affected components (i.e. Main & Startup FWREG valves) in there required positions. The Feedwater pumps may betripped due to the loss of power.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #5 Page 21 of 34Event
 
== Description:==
Seismic Event / Loss of Offsite Power / Turbine Trip / 2 Stuck CEAsTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 BOPe. Reset moisture separator reheaters, and check the temperaturecontrol valves closed.(note)MSR temperature control valve indication will be lost. The BOP shouldrequest an NAO to verify the valves are closed locally.
ATC7. DetermineContainment Isolation acceptance criteria are met:a. Check containment pressure is less than 16.4 psia.b. Check NO containment area radiation monitor alarms ORunexplained rise in activity.c. Check NO steam plant activity monitor alarms OR unexplained risein activity.ATC/BOP8 DetermineContainment Temperature and Pressure Controlacceptance criteria are met:a. Check containment temperature is less than or equal to 120&#xba;F.b. Check containment pressure is less than 16.4 psia.N/A 9.IF ALLsafety function acceptance criteria are met,AND NOcontingency actions were performed,THENGO TO OP-902-001,"Reactor Trip Recovery" procedure.
SRO 10. IF ANYsafety function acceptance criteria are NOTmet,OR ANYcontingency action was taken,THENGO TO Appendix 1, "DiagnosticFlowchart.OP-902-009, Standard Appendices, Appendix 1 Diagnostic Flow ChartExaminer NoteAppendix 1 is a flow chart used to diagnose to the correct recovery procedure for the event inprogress. The steps below will be followed by a YES or NO to indicate proper flow path.
ATCRx Pwr dropping, SUR negative, and < two CEAs NOT fully inserted orEmergency Boration in progress (YES)ATCPressurizer pressure dropping rapidly and Pressurizer level changing (NO)BOPAt least one 7KV non-safety bus and one 4KV safety bus powered fromoffsite (same train) (NO)BOPAt least one 4KV safety bus and one 125VDC bus energized (same train)
(YES)
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Seismic Event / Loss of Offsite Power / Turbine Trip / 2 Stuck CEAsTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 SROGo To OP-902-003, Loss of Offsite/Forced Circulation RecoveryOP-902-003, Loss of Offsite Power/Forced Circulation Recovery SRO1. Confirm diagnosis of a LOOP/LOFC by checking Safety Function StatusCheck Acceptance criteria are satisfied.CREW2. Announce a Loss of Offsite Power or a Loss of Forced Circulation is inprogress using the plant page.Examiner NoteThis event is complete after the crew diagnoses OP-902-003, Loss of Offsite Power/ForcedCirculation OrAs directed by the Lead Evaluator.Examiner NoteCue the Simulator Operator when ready for Events 6 & 7EventTrigger 6 will initiate the RCS leak on cold leg 1A.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #6 & 7 Page 23 of 34Event
 
== Description:==
Large RCS Cold Leg Break / Containment Spray Fails to Auto actuateTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0Examiner NoteStep 15 directs the operators to verify Containment Spray Actuation initiated if containmentpressure is 17.7 psia or greater. This step is critical task 2 and has been pulled up sincecontainment pressure will be rising rapidly.ATC/BOP Recognize and report indications of Loss of Coolant Accident.Alarms: Pressurizer Pressure Hi/Lo (Cabinet H, E-1) Pressurizer Level Hi/Lo (Cabinet H, B-1) Containment Pressure Hi/Lo (Cabinet M, H-4, Cabinet N, H-14) Containment Water Leakage Hi (Cabinet N, L-20) Containment Water Leakage Hi-Hi (Cabinet N, K-20) Rad Monitoring Sys Activity Hi-Hi (Cabinet L, A-9)Indications: RCS pressure dropping (CP-7, CP-2) Pressurizer level lowering (CP-2, CP-8, QSPDS 1) Backup Charging Pump starts (CP-4) Letdown flow goes to minimum (CP-4) Rising radiation levels in containment (RM-11, CP-6)(note)If not already automatically initiated, the SRO may direct a preemptivemanual initiation of Safety Injection Actuation Signal (SIAS) andContainment Isolation Actuation Signal (CIAS). Containment SprayActuation Signal (CSAS) is not normally preemptively initiated.The SRO will then direct the ATC and the BOP back to the diagnosticflow chart.CRITICAL TASK 2ESTABLISH CONTAINMENT TEMPERATURE AND PRESSURE CONTROLThis task is satisfied by manually initiating Containment Spray Actuation Signal prior to exitingstep 15 (Verify Containment Spray Actuation) of OP-902-002, Loss of Coolant AccidentRecovery Procedure, or Containment pressure exceeding 44 PSIG (59 PSIA).This task becomes applicable after Containment Pressure rises above 17.7 PSIA.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #6 & 7 Page 24 of 34Event
 
== Description:==
Large RCS Cold Leg Break / Containment Spray Fails to Auto actuateTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 ATCVerify Containment Spray Actuation
*15.IF containment pressure is greater than or equal to 17.7 psia, THEN:a. Verify CSAS is initiated. (CRITICAL)b. VerifyALL operating Containment Spray pumps are delivering flowgreater than 1750 gpm.(note)The ATC will manually initiate CSAS at CP-7 by pressing both CSASpush buttons.OP-902-009, Standard Appendices, Appendix 1 Diagnostic Flow Chart ATCRx Pwr dropping, SUR negative, and < two CEAs NOT fully inserted orEmergency Boration in progress (YES)ATCPressurizer pressure dropping rapidly and Pressurizer level changing (YES)BOPSteam Generator Pressure Abnormally Low (NO)N/APrimary Break ATCContainment Pressure and Temperature Abnormally High (YES)ATCActivity in the Steam Plant (NO)N/ALOCA Inside Containment BOPAt least one 4KV safety bus energized (YES)SROGo To OP-902-002, Loss of Coolant Accident RecoveryOP-902-002, Loss of Coolant Accident Recovery SRO*1. Confirm diagnosis of a LOCA:a. Check Safety Function Status Check Acceptance criteria are satisfied.
b.IFSteam Generator sample path is available, THENdirect Chemistryto sampleBOTHSteam Generators for activity.(note)If asked to perform step 1.a as the STA, simply acknowledge therequest.CREW2. Announce a Loss of Coolant Accident is in progress using the plant page.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #6 & 7 Page 25 of 34Event
 
== Description:==
Large RCS Cold Leg Break / Containment Spray Fails to Auto actuateTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 SRO*3. Advise the Shift Manager to REFER TO EP-001-001, "Recognition &Classification of Emergency Condition" and implement the EmergencyPlan.(note)If asked to perform step 3 as the SM, simply acknowledge the request.
SRO*4. REFER TO Section 6.0, "Placekeeper" and record the time of the reactortrip.CREW*5.IFpower has been interrupted to either 3A or 3B safety buses,THENperform Appendix 20, "Operation of DCT Sump Pumps".(note)Crew should send an NAO to restore DCT Sump Pumps on both safetybuses.ATC*6.IF PZR pressure is less than 1684 psia,THEN check SIAS has initiated.
ATC6.1 Verify SIAS is initiated.ATC/BOP*7.IF SIAS has initiated,THEN:a. Verify Safety Injection pumps have started.b. Check Safety Injection flow is within the following: Attachment 2-E, "HPSI Flow Curve" Attachment 2-F, "LPSI Flow Curve"c. VerifyALL available Charging pumps are operating.Examiner NoteAppendix 2-E and Appendix 2-F are contained on the next 2 pages. Injection flow will bemeeting all requirements.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #6 & 7 Page 26 of 34Event
 
== Description:==
Large RCS Cold Leg Break / Containment Spray Fails to Auto actuateTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #6 & 7 Page 27 of 34Event
 
== Description:==
Large RCS Cold Leg Break / Containment Spray Fails to Auto actuateTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 ATC*8.IF PZR 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 ofAttachment 2A-D, "RCS Pressure and Temperature Limits,"THEN stopALL RCPs.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #6 & 7 Page 28 of 34Event
 
== Description:==
Large RCS Cold Leg Break / Containment Spray Fails to Auto actuateTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0N/A 9.IF RCPs are operating, THEN:a. Verify CCW available to RCPs.b. IF a CSAS is initiated, THEN stop ALL RCPs.
c.IF RCS TC is less than 382&#xba;F[384&#xba;F],THEN verify no more than twoRCPs are operating.
BOP*10. Check a CCW pump is operating for each energized 4.16 KV Safetybus.Examiner NoteThis event is complete after the crew completes Critical Task 2 and steps 1-10 in OP-902-002.
OrAs directed by the Lead Evaluator.Examiner NoteCue the Simulator Operator when ready for Event 8EventTrigger 7 will initiateEvent 8 (loss of LPSI pump B)
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #8 Page 29 of 34Event
 
== Description:==
Low Pressure Safety Injection Pump B Trips / Functional Recovery ProcedureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0Examiner NoteEventTrigger 7 will initiateEvent 8 (loss of LPSI pump B)This will cause a loss of low pressure safety injection and require the crew to enter the FunctionalRecovery Procedure (OP-902-008) to align a Containment Spray pump to re-establish low pressuresafety injection.
BOPRecognizes and reports indications of LPSI pump B tripAlarms LPSI PUMP B TRIP/TROUBLE (Cabinet N, E-13)Indications LPSI pump B control switch Amber Light (CP-8) Ammeter above control switch - zero amps (CP-8) LPSI pump B flow - zero (CP-8)CREWRecognizes that safety functions for OP-902-002, Loss of Coolant Accident,are not being met. SRO directs going directly to OP-902-008, FunctionalRecovery.OP-902-008, Functional RecoveryCREW1. Announce that the Functional Recovery Procedure is in progress usingthe plant page.
SRO2. Advise the Shift Manager to REFER TO EP-001-001, "Recognition &Classification of Emergency Condition" and implement the EmergencyPlan.SRO3. REFER TO the "Placekeeper" and record the time of the reactor trip.N/A 4.IF pressurizer pressure is less than 1621 psia,AND SIAS is actuated,THENa. Verify no more than two RCPs are operating.
b.IF pressurizer pressure is less than the minimum RCP NPSH ofAppendix 2A-D, "RCS Pressure and Temperature Limits",THEN stopALL RCPs.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Low Pressure Safety Injection Pump B Trips / Functional Recovery ProcedureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0N/A 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 382&#xba;F [384&#xba;F],THEN verify no more than twoRCPs are operating.NOTEThe Shift Chemist should be notified if a SIAS or CIAS has occurred. The secondary samplingcontainment isolation valves should not be opened following an SIAS or CIAS until directed by the ShiftChemist.SRO6. Direct Chemistry to sampleBOTHsteam generators for activity and boron.NOTE If a Temporary Diesel Generator is the source of AC power, the Verify Equipment Ventilationstep must still be performed. Door Stops and Ceiling Access Panel tool located in Shift Manager Office. Portable emergency lighting is available in Appendix R lockers located at LCP-43, RemoteShutdown Panel and +35 RAB Relay Room and Shift Manager Office.Verify Equipment VentilationN/A 7.IFAC power is lost toBOTH3A and 3B Safety buses,THENperformthe following within 30 minutes from the onset of SBO:N/Aa. Perform the following behind Control panels: REFER TO Attachment 7-D, "Process Analog Control CabinetDoors" and open cabinet doors. Open Door 259, Secondary Access (southwest corner)N/Ab. Open the following Lighting Panel breakers: LTN-EPNL-322: (behind CP-8) o LTN-EBKR-322-1 o LTN-EBKR-322-2 o LTN-EBKR-322-3 LTN-EPNL-323: (near main Control Room entrance) o LTN-EBKR-323-2 o LTN-EBKR-323-3 o LTN-EBKR-323-4 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #8 Page 31 of 34Event
 
== Description:==
Low Pressure Safety Injection Pump B Trips / Functional Recovery ProcedureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0N/Ac. Open doors in front of Control panels: Door 84, Equipment Access (north wall double doors) Door 293, Sound Partition (between west wall and CP-53) Door 292, Sound Partition (between CP-53 and CP-8) Door 291,Sound Partition (between CP-18 and CP-15) Door 77, Main Entrance (northeast corner)N/Ad. Open six Ceiling Access panels, (Control Room proper area).NOTE If a Temporary Diesel Generator is available and ready to load within 30 minutes of SBOonset, then load stripping via the associated Attachment 7-A or 7-B should not be necessary. Performing Attachment 7-A and 7-B will remove DC control power from the EDGs includingloss of EDG Annunciator Panels and CP-1 indicating lights. An EDG will not start with controlpower removed.N/A 8.IF AC power is lost toBOTH 3A and 3B Safety buses,THEN directNAOs to performALL of the following within 30 minutes from the onsetof SBO: Attachment 7-A, "Switchgear Room A Removable Loads" Attachment 7-B, "Switchgear Room B Removable Loads" Attachment 7-C, "Switchgear Room AB Removable Loads"CREW 9.IFpower has been interrupted toeither 3A or 3B safety buses,THENperform Appendix 20, "Operation of DCT Sump Pumps".(note)If not already done, the crew should send an NAO to restore DCT SumpPumps on both safety buses.
BOP10. Place Hydrogen Analyzers in service as follows:Train Aa. Place Train A H2 ANALYZER CNTMT ISOL VALVE keyswitch toOPEN. (Key 216)b. Place H2 ANALYZER A POWER to ON.c. Check H2 ANALYZER A Pumps indicate ON.Train Ba. Place Train B H2 ANALYZER CNTMT ISOL VALVE keyswitch toOPEN. (Key 217)b. Place H2 ANALYZER B POWER to ON.c. Check H2 ANALYZER B Pumps indicate ON.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Low Pressure Safety Injection Pump B Trips / Functional Recovery ProcedureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 SRO11. Identify success paths to be used to satisfy each safety function usingBOTH of the following: Resource Assessment Trees Safety Function Tracking Sheet(note)SRO should determine priorities and paths as follows on the SafetyFunction Tracking Sheet:  (Priorities may vary depending on timeparameters checked; however, Priority 1 should be IC-2) Reactivity Control, RC-1 =
4 Maintenance of Vital Auxiliaries (DC), MVA-DC-1 =
7 Maintenance of Vital Auxiliaries (AC), MVA-AC-2 =
5 RCS Inventory Control, IC-2 =
1 RCS Pressure Control, PC-2 =
2 RCS and Core Heat Removal, HR-2 =
3 Containment Isolation, CI-1 =
8 Containment Temperature and Pressure Control, CTPC-2 =
6RCS Inventory Control, IC-2SRO/ATC 1. Verify SIAS is initiated.
BOP2. Optimize Safety injection:a. Verify Safety Injection pumps have started.b. Check Safety Injection flow is within ALL of the following: Attachment 2-E, "HPSI Flow Curve" Attachment 2-F, "LPSI Flow Curve"c. Verify ALL available Charging pumps are operating.(note)The crew will determine that step 2.b is not met. The contingencyactions for this step do not provide the guidance needed to align a CSpump to replace a LPSI pump. The SRO will need to pull up step 15(below) and follow contingency step 15.1 to find the requiredprocedural guidance.
SRO15. Check IC-2, Safety Injection is satisfied byALL of the following:
a.IF RAS has NOT initiated,THEN at leastONE Charging pump isoperating.
b.IF RAS has NOT initiated,AND LPSI pump stop criteria areNOT met,THEN LPSI flow within Attachment 2-F, "LPSI Flow Curve." c.IF HPSI throttle criteria areNOT met, THEN HPSI flow withinAttachment 2-E, "HPSI Flow Curve."d. RVLMS LEVEL PLENUM indicates greater than or equal to 20%.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Low Pressure Safety Injection Pump B Trips / Functional Recovery ProcedureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0 SRO15.1 IF the RCS Inventory Control safety function is still NOT met, THEN GO TO RCS Inventory Control Continuing Actions.RCS Inventory Control Continuing Actions SRO3. Restore the RCS Inventory safety function to a success path byperformingANY of the following:a. Restore the vital auxiliaries necessary to operate components orsystems in the success path.b. Manually operate alternate components to implement a success path.
c.IF BOTH LPSI pumps are NOT available,AND the TSC concurs,THEN REFER TO Appendix 27, "Aligning CS to Replace LPSI" andalign a CS Pump.Attachment 27-B: CS Pump B to Replace LPSI Pump B SRO1. Obtain TSC concurrence prior to performing this evolution.(note)The SRO should communicate step 1 to the Lead Examiner as if to theShift Manager. If asked, simply reply, "TSC concurs". The SRO shouldselect train B since LPSI pump A is tagged out.
BOP2. Verify LPSI Pump B Control switch in "OFF." BOP3. Open the Breaker knifeswitch for LPSI Pump B.(note)The Crew will direct an NAO to open the breaker knifeswitch.
BOP4. Verify Containment Spray Pump B Control switch in "OFF." BOP5. Place SI 129B, LPSI FLOW CONTROL VALVE to "AUTO." (Key 146)
BOP6. Place SI-IFIC-0306, LPSI FLOW CONTROLLER HEADERS 1A/1B in"MAN." BOP7. Adjust SI-IFIC-0306, LPSI FLOW CONTROLLERS HEADER 1A/1B to0% output.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
1Event #8 Page 34 of 34Event
 
== Description:==
Low Pressure Safety Injection Pump B Trips / Functional Recovery ProcedureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 1 D-2 Rev 0(note)The Crew may direct an NAO to locally close SI-129B since loss ofInstrument Air will cause SI-129B to fail open. The position of SI-129B(open or closed) will not affect injection flow to the core. It is preferredto have SI-129B closed so that the discharge from the ContainmentSpray pump will be directed through the Shutdown Cooling (SDC) HeatExchanger instead of bypassing around it. In a normal lineup, LPSIflow does not go through the SDC Heat Exchanger.
BOP8. REFER TO Appendix 21 "Overrides for Containment Isolation" and closeCS 125B, CNTMT SPRAY HEADER B ISOL.
BOP9. Open SI 125B/SI 412B, SHDN HX B ISOL valves. (Key 145)
BOP10. Start Containment Spray Pump B.
BOP11. Open SI 415B, LPSI SHUTDOWN TEMP CONTROL valve. (Key 147)
BOP12. Verify LPSI Header B flow exists.Attachment 21-A CS-125B Override2. Override CS 125B, CNTMT Spray HDR B Isolation as follows:
BOPa. Place CNTMT Spray Pump B Control switch to "OFF." NAOb. Obtain key 76 from SM office.
NAOc. Place keyswitch, Containment Spray 125B Override, to"OVERRIDE."(located on the side of Auxiliary Panel 2, +35Relay Rm)BOPd. Place CS 125B, CNTMT SPRAY HEADER B ISOL valve to"OPEN" and THEN to "CLOSE."Examiner NoteThis event is complete after the crew re-establishes Low Pressure Safety Injection flow OrAs directed by the Lead Evaluator.
Appendix DScenario OutlineForm ES-D 1 -2015 NRC Exam Scenario 2 D-1 Rev 1Facility:Waterford 3Scenario No.:
2Op Test No.:
1Examiners:Operators:Initial Conditions: Reactor power is 100%, MOC.Turnover: Protected Train is B, AB Busses are aligned to Train B. No major equipment OOS. Maintain 100%.EventNo.Malf.No.EventType*EventDescription 1NI01HI - BOPI - SROTS - SROChannel D Excore Nuclear Instrument SafetyChannel, ENI-IJI-0001D, middle detector fails low. (TS3.3.1 & 3.3.3.6) 2 CV01BC - ATC C - SROTS - SROCharging Pump B trips on overcurrent requiringimplementation of OP-901-112, Charging or Letdownmalfunction. (TS 3.1.2.4; TRM 3.1.2.4) 3SG01AR - ATCN - BOP N - SROTS - SROSteam Generator #1 tube leakage occurs requiringimplementation of OP-901-202, Steam Generator tubeleakage or High Activity and a rapid downpower inaccordance with OP-901-212, Rapid PlantDownpower. (TS 3.4.5.2) 4TP01ATP08BC - BOP C - SRORunning Turbine Cooling Water Pump A trips and thestandby pump does not auto start resulting in manualaction to start in accordance with OP-901-512, Loss ofTurbine Cooling Water 5SG01AM - AllSteam Generator tube leakage worsens leading toReactor Trip and Safety Injection (Critical Task 1,isolate SG not before THOT reduced below 520 F)(Critical Task 3, commence RCS depressurizationto 930 PSIA prior to lifting ADV (auto) or MSSV) (#3Dominant Accident Sequence
)6 RP09DI - ATCI - BOPRelay K202 failure, RC-606, Control Bleed offContainment Isolation and FP-601B, Fire Water BContainment Isolation fail to auto close.
7 CC12E2I-ATC I-SROComponent Cooling Water Surge Tank level SwitchCC-ILS-7013A fails low, isolating Component CoolingWater to the Reactor Coolant Pumps, requiring thecrew to secure all running Reactor Coolant Pumps.
(Critical Task 2, trip running RCPs prior toexceeding 3 minutes without CCW flow
)*(N)ormal,    (R)eactivity,    (I)nstrument,    (C)omponent,    (M)ajor Scenario Event DescriptionNRC Scenario 2- 2 -2015 NRC Exam Scenario 2 D-1 Rev 1The crew assumes the shift at 100% power with instructions to maintain 100% power.After taking the shift, ENI Channel D Log Power Instrument (ENI-IJI-0001-D), (middle channel), fails low.The SRO should review and enter Technical Specification 3.3.1 action 2 and bypass Hi Linear Power, HiLPD, Lo DNBR (1, 3 & 4) within 1 hour in accordance with OP-009-007, Plant Protection System.Bypassing High Log Power and Reactor Coolant Flow-Low (2 & 14) on PPS D is not required in Mode 1,but may be performed. The SRO should also evaluate and enter Technical Specification 3.3.3.6 action29 which is to restore the channel within 30 days.After Technical Specifications are addressed, Charging Pump B trips on overcurrent. The SRO shouldimplement OP-901-112, Charging or Letdown Malfunction, Section E 1, Charging Malfunction. The SROshould direct the ATC to start a standby charging pump after verifying a suction path available or isolateLetdown using CVC-101, Letdown Stop Valve. If Letdown is isolated, Charging and Letdown will be re-initiated using Attachment 2 of OP-901-112. The SRO should review and enter Technical Specification3.1.2.4 and Technical Requirement Manual 3.1.2.4. Technical Specification 3.1.2.4 may be exited afteraligning Charging Pump AB to replace Charging Pump B. However, Technical Requirement Manual3.1.2.4 should not be exited while Charging Pump B remains inoperable.After the crew addresses the Charging pump malfunction, Steam Generator 1 develops a tube leak at ~ 3gpm. The SRO should implement OP-901-202, Steam Generator Tube Leakage or High Activity. TheSRO should determine that based on leak indications, Technical Specification 3.4.5.2 is not met forPrimary-to-Secondary Leakage or Identified Leakage and enter TS 3.4.5.2 Action a to be in Mode 3 within6 hours. The SRO should also determine that the current leakage requires implementation of OP-901-212, Rapid Plant Power Reduction.After the reactivity manipulation has been satisfied, the running Turbine Cooling Water Pump A will tripand the standby pump will fail to start automatically. The CRS should direct the BOP to start the standbypump in accordance with OP-901-512, Loss of Turbine Cooling Water and monitor affected loads.After the crew has restored Turbine Cooling Water, the Steam Generator tube leakage will worsen to aSteam Generator tube rupture with leakage greater than Charging Pump capacity. The SRO shoulddirect a manual Reactor Trip and Safety Injection/Containment Isolation actuation. The crew shouldproceed through OP-902-000, Standard Post Trip Actions and diagnose to OP-902-007, SteamGenerator Tube Rupture Recovery. After the Containment Isolation Signal is initiated, Relay K202 failsand RC-606, Control Bleed off Containment Isolation and FP-601B, Fire Water B Containment Isolationfail to auto close requiring manual action by the ATC and BOP.The crew will perform steps of OP-902-007, Steam Generator Tube Rupture Recovery to perform a rapidcooldown of the RCS to THOT less than 520F and isolate the #1 Steam Generator(CRITICAL TASK 1)
.While the crew is performing the rapid plant cooldown, Component Cooling Water Surge Tank levelswitch, CC-ILS-7013A fails low isolating Component Cooling Water to the Reactor Coolant Pumps. TheATC will have to take action and stop all running RCPs within 3 minutes of isolation of flow(CRITICALTASK 2). The SRO may implement OP-901-510, CCW System Malfunction. Once the crew has stoppedRCPs and isolated #1 Steam Generator, the crew should then take action to commence depressurizingthe RCS in accordance with OP-902-007(CRITICAL TASK 3). In Waterford 3 Probalistic Risk Analysis,the #3 Dominant Accident Sequence that would lead to core damage is a "SGTR with a failure todepressurize This is mitigated by performing Critical Task 3.The scenario can be terminated once the crew commences the RCS depressurization in accordance withOP-902-007, Steam Generator Tube Rupture Recovery or at the lead examiner's discretion.
NRC Scenario 2- 3 -2015 NRC Exam Scenario 2 D-1 Rev 1CRITICAL TASKS1. ISOLATE MOST AFFECTED STEAM GENERATORThis task is satisfied by closing Main Steam isolation valve, Main Feedwater isolation valve, EmergencyFeedwater flow control and isolation valves, steam supply to EFW pump AB, steam line drains, andBlowdown isolation valves for #1 Steam Generator after THOT reduced below 520F and prior to exitingthe step to Isolate the Most Affected Steam Generator (step 17) of OP-902-007. This task becomesapplicable when the crew enters OP-902-007, Steam Generator Tube Rupture Recovery.2. TRIP ANY RCP EXCEEDING OPERATING LIMITSThis task is satisfied by stopping all running Reactor Coolant Pumps prior to exceeding 3 minutes withoutComponent Cooling Water flow to the RCPs. This task becomes applicable after all RCP CCW flow lostannunciators actuate. The alarms indicate the possibility for additional Reactor Coolant System pressureboundary degradation through the Reactor Coolant Pumps. The time requirement of 3 minutes is basedon the Reactor Coolant Pump operating limit of 3 minutes without CCW cooling.3. PREVENT LIFTING AFFECTED SG SAFETY VALVESThis task is satisfied by commencing an RCS depressurization to less than 930 PSIA using auxiliaryspray valves and charging pumps prior to lifting atmospheric dump valve in automatic or main steamsafety valves on affected Steam Generator. This task becomes applicable after the RCS has beencooled down to RCS THOT less than 520F and Steam generator #1 is isolated (Critical Task 1).Scenario Quantitative Attributes1. Malfunctions after EOP entry (1-2)22. Abnormal events (2-4)33. Major transients (1-2)14. EOPs entered/requiring substantive actions (1-2)15. EOP contingencies requiring substantive actions (0-2)06. EOP based Critical tasks (2-3)3 NRC Scenario 2- 4 -2015 NRC Exam Scenario 2 D-1 Rev 1SCENARIO SETUPA. Reset Simulator to IC-162.B. Verify Scenario Malfunctions, Remotes, and overrides are loaded, as listed in the Scenario Timeline.C. Ensure Protected Train B sign is placed in SM office window.D. Verify EOOS is 10.0 Green with nothing out of serviceE. Complete the simulator setup checklist.F. Start Insight, open file Crew Performance.tis.
NRC Scenario 2- 5 -2015 NRC Exam Scenario 2 D-1 Rev 1SIMULATOR BOOTH INSTRUCTIONSEvent 1 Channel D Excore NI Safety Channel, ENI-IJI-0001D, middle detector fails low1. On Lead Examiner's cue, initiate EventTrigger 1.2. If Work Week Manager or PMI are called, inform the caller that a work package will be assembledand a team will be sent to the Control Room.3. If sent to LCP-43, wait 3 minutes and report channel ENI-IJI-0001-D1 appears to be faileddownscale. All other power channels read approximately 100%.Event 2 Charging Pump B Trip1. On Lead Examiner's cue, initiate EventTrigger 2.2. If Work Week Manager or PMI are called, inform the caller that a work package will be assembledand a team will be sent to the Charging Pump room and breaker.3. If called as NAO to investigate the breaker, wait 3 minutes and report overcurrent flags aredropped for all 3 phases for Charging Pump B4. If called as NAO to investigate the pump, wait 3 minutes and report that there are someindications of charring at the motor vent area, and an acrid odor is present but there is no fire.5. If directed to perform prestart checks for the A or AB Charging pump, wait 2 minutes and reportthe following for directed pump:a. Suction and discharge valves are openb. Proper oil level existsc. Motor vents unobstructedd. All personnel clear of the pump6. If directed to check a started Charging pump for proper operation following start, wait 1 minuteand report the following:a. Suction and discharge valves are openb. Proper oil pressure and seal water flow existc. No abnormal vibrations or noises presentEvent 3 Steam Generator Tube Leakage #1 Steam Generator / Rapid Plant Downpower1. On Lead Examiner's cue, initiate EventTrigger 3.1. If Chemistry is called to sample the Steam Generators for activity, acknowledge and wait 30minutes and report leakage into Steam Generator 1 is ~ 10 GPM.2. If called as DPM or Duty OPS Manager, acknowledge the communication and tell contact personthat you will make the additional communications per OI-035-000, Attachment 1.3. If requested as Programs & Components Engineering to monitor for loose parts in the Stay CavityArea of Steam Generator, acknowledge the request and inform the caller that will monitor andevaluate data as necessary.4. If Chemistry is called to sample the RCS for Dose Equivalent Iodine due to the down power,acknowledge and report that samples will be taken 2-6 hours from notification time and if askedtell the caller your name is Dustan Milam.5. If notified as Load Dispatcher (Woodlands) acknowledge the communications and inform thecaller that the grid will remain stable with available backup generation.6. If requested to remove polisher vessels from service, inform the caller that you will monitorPolisher D/P and remove vessels as necessary.
NRC Scenario 2- 6 -2015 NRC Exam Scenario 2 D-1 Rev 1Event 4 Turbine Cooling Water Pump A Trip1. On Lead Examiner's cue, initiate EventTrigger 4.2. If Work Week Manager, Computer Technician, or PMI are called, inform the caller that a workpackage will be assembled and a team will be sent to the Control Room.3. If called as NAO to investigate the breaker for the tripped TCCW Pump, wait 3 minutes and reportthat the breaker is tripped, with overcurrent indications at the breaker.4. If called as NAO to investigate the TCCW pump locally, wait 3 minutes and report no obviousreason why the pump has tripped.Event 5 Steam Generator Tube Rupture1. On Lead Examiner's cue, initiate EventTrigger 5.2. If called as NAO to verify proper operation of unloaded Emergency Diesel Generators, then wait 2minutes and manually initiate EventTrigger 15. Wait an additional minute and manually initiateEventTrigger 25 to acknowledge local EDG panels. Report that both A and B EDGs are runningproperly unloaded.Event 6 Relay K202 Failure (RC-606 and FP-601B no auto closure)1. No actions for this eventEvent 7 Component Cooling water Surge Tank level switch, CC-ILS-7013A fails low1. After the crew has commenced the RCS cooldown and on Lead Examiner's cue, initiate EventTrigger 7.2. At the end of the scenario, before resetting, end data collection and save the file as 2015Scenario 2-(start-end time).tid. Export to .csv file. Save the file into the folder for theappropriate crew.
.
NRC Scenario 2- 7 -2015 NRC Exam Scenario 2 D-1 Rev 1SCENARIO TIMELINEEVENT KEYDESCRIPTIONTRIGGERDELAYHH:MM:SSRAMPHH:MM:SSFINALEVENT DESCRIPTION 6 RP09DRELAY K202 FAILED, CIAS TRAIN B (CVC/RC/FP)N/A00:00:0000:00:00ACTIVERC-606 AND FP-601B NO AUTO CLOSURE 4TP08BTCCW PUMP B AUTO START DISABLEN/A00:00:0000:00:00ACTIVETURBINE COOLING WATER PUMP NO AUTO START 1NI01HMIDDLE DETECTOR (D2) SAFETY CHANNEL D FAIL (0-100%)
100:00:0000:00:00 0LOG CHANNEL MIDDLE DETECTOR FAILURE 2 CV01BCHARGING PUMP B TRIPPED 200:00:0000:00:00ACTIVECHARGING PUMP B TRIP 3SG01ASG1 TUBE LEAK (100% = 3200 GPM) 300:00:0000:00:000.3STEAM GENERATOR TUBE LEAK OF ~10 GPM 4TP01ATCCW PUMP A TRIP 400:00:0000:00:00ACTIVETCCW PUMP A TRIP 5SG01ASG1 TUBE LEAK (100% = 3200 GPM) 500:00:0000:00:00 8STEAM GENERATOR TUBE LEAK OF ~250 GPM 7 CC12E2CCW SURGE TNK LVL 7013AS FAILS LO 700:00:0000:00:00ACTIVECCW SURGE TNK LVL 7013AS FAILS LO 5EGR26EDG A LOCAL ANNUN ACK 1500:00:0000:00:00ACKNLOCAL EDG ANNUNCIATOR ACKNOWLEDGE 5EGR27EDG B LOCAL ANNUN ACK 2500:00:0000:00:00ACKNLOCAL EDG ANNUNCIATOR ACKNOWLEDGE NRC Scenario 2- 8 -2015 NRC Exam Scenario 2 D-1 Rev 1REFERENCESEventProcedures 1OP-009-007, Plant Protection System, Rev. 16OP-903-013, Monthly Channel Checks, Rev. 18Technical Specification 3.3.1Technical Specification 3.3.3.6 2OP-901-112, Charging or Letdown Malfunction, Rev. 6OP-002-005, Chemical Volume Control, Rev. 47Technical Specification 3.1.2.4Technical Requirements Manual 3.1.2.4 3OP-901-202, Steam Generator Tube Leakage or High Activity, Rev. 15OP-002-005, Chemical Volume Control, Rev. 47OP-004-004, Control Element Drive, Rev. 19OP-901-212, Rapid Plant Power Reduction, Rev. 7Technical Specification 3.4.5.2 4OP-901-512, Loss of Turbine Cooling Water, Rev. 3 5OP-902-000, Standard Post Trip Actions, Rev. 15OP-902-007, Steam Generator Tube Rupture Recovery, Rev. 16OP-902-009, Standard Appendices, Rev. 310, Appendix 2, FiguresOP-902-009, Standard Appendices, Rev. 310, Appendix 1, Diagnostic Flow Chart 6OP-902-007, Steam Generator Tube Rupture Recovery, Rev. 16 7OP-902-007, Steam Generator Tube Rupture Recovery, Rev. 16 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
2Event #1 Page 1 of 35Event
 
== Description:==
Channel D Excore Nuclear Instrument middle detector fails lowTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0Examiner NoteCue the Simulator Operator when ready for Event 1 ATCRecognizes and reports indications of failed channel.Alarms: RPS CHANNEL TRIP LOCAL PWR DENSITY HI (Cabinet K, A-11) LOCAL PWR DENSITY HI PRETRIP B/D (Cabinet K, C-11) DNBR LO PRETRIP B/D (Cabinet K, C-12) EXCORE/CPC CHNL D POWER DEVIATION (Cabinet K, K-14) RPS CHANNEL D TROUBLE (Cabinet K, H-18)Indications: ENI-IJR-0001, Log Power indication fails downscale ENI-IJI-001D, Log Power Safety Channel D indication fails downscale Pre-Trip indication Channel D HI LOCAL POWER bistable Trip indication Channel D HI LOCAL POWER bistable Pre-Trip indication Channel D LOW DNBR bistableExaminer NoteAll BOP manipulations for OP-009-007 are located at CP-10 except as noted. The CRS maybypass bistable 2 - HI LOG POWER, but is not required.OP-009-007, Plant Protection System ,Section 6.2, Trip Channel Bypass Operation SRO6.2.1 Refer to Attachment 11.11, PPS Bistable Bypass Chart to assist indetermination of Trip Channels requiring placement in bypass.(note)SRO determines the following bistables are affected and need to bebypassed: 1-HI LN POWER 3-HILOCAL POWER 4-LO DNBR(note)SRO directs BOP to bypass the HI LN POWER, HILOCAL POWER,and LODNBR bistables in PPS Channel D within 1 hour in accordance withOP-009-007, Plant Protection System.
BOP6.2.2 To place a bistable in or remove a bistable from bypass, go toAttachment 11.10, Trip Channel Bypass Operation.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Channel D Excore Nuclear Instrument middle detector fails lowTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0OP-009-007, Plant Protection System ,Attachment 11.10, Trip Channel Bypass OperationCAUTION(1) ATTEMPTING TO PLACE MORE THAN ONE TRIP CHANNEL IN BYPASS REMOVES BOTHTRIP CHANNELS FROM BYPASS.(2)      PRIOR TO PLACING ANY TRIP CHANNEL IN BYPASS, VERIFY BYPASS PUSH BUTTONSON DE-ENERGIZED PPS BAY NOT DEPRESSED.
BOP11.10.1 To Bypass a Trip Channel, perform the following:11.10.1.1 Circle the bistable numbers selected for bypass underStep 11.10.1.4.(note)BOP circles bistable numbers 1, 3 and 4 in Step 11.10.1.4 table BOP11.10.1.2 Check desired Trip Channel is not Bypassed on another PPSChannel.BOP11.10.1.3 Open key-locked portion of BCP in desired PPS Channel.
BOP11.10.1.4 Depress Bypass push buttons for the desired Trip Channels BOP11.10.1.5 Check all selected bistable Bypass push buttons remain in aDepressed state.
BOP11.10.1.6 Check all selected bistable Bypass lights Illuminate on BCP forthe desired Trip Channels.CREW11.10.1.7 Check all selected bistable Bypass lights Illuminate on ROM forthe desired Trip Channels.(note)Crew verifies correct bistables lit on CP-7 PPS Channel D RemoteOperator Module.
SROReviews the following Technical Specifications and determines applicableactions: 3.3.1 action 2 3.3.3.5 - no actions required 3.3.3.6 - action 29 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
2Event #1 Page 3 of 35Event
 
== Description:==
Channel D Excore Nuclear Instrument middle detector fails lowTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0Examiner NoteThis event is complete when bistables are bypassed and Technical Specifications have beenaddressed orAt Lead Examiner's DiscretionExaminer NoteCue the Simulator Operator when ready for Event 2 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
2Event #2 Page 4 of 35Event
 
== Description:==
Charging Pump B TripsTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 BOPRecognize and report indications of Charging Pump B trip.Alarms: CHARGING PUMPS HEADER FLOW LO (Cabinet G, H-5) CHARGING PUMP B TRIP/TROUBLE (Cabinet G, B-6)Indications: Charging Pump B indicates OFF Charging flow lowering PZR level lowering Letdown flow loweringExaminer NoteThe SRO may direct the BOP to verify a suction source and start a Charging Pump upon theinitial report, prior to entering the off normal.
SROEnter and direct the implementation of OP-901-112, Charging or LetdownMalfunction.OP-901-112, Charging or Letdown Malfunction, E 0 - GeneralN/A1. Stop turbine load changes.N/A2. IF malfunction is due to failure of the Pressurizer Level Control System,THEN go to OP-901-110, PRESSURIZER LEVEL CONTROLMALFUNCTION.
SRO3. IF a Charging Malfunction is indicated, THEN go to Subsection E1,Charging Malfunction.OP-901-112, Charging or Letdown Malfunction, E 1 - Charging MalfunctionNOTEIf all Charging Pumps are secured, then LETDOWN STOP VALVE (CVC 101) will close on highREGEN HX TUBE OUTLET temperature if RCS is 470 F.CAUTIONTHE REACTOR COOLANT SYSTEM WILL BE BORATED IF A CHARGING PUMP IS STARTEDWITH THE RWSP AS THE MAKEUP WATER SOURCE.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Charging Pump B TripsTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 ATC1. 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 ChargingPump(s).1.3 IF the Charging Pump can NOT be restarted, THEN verify closedLETDOWN STOP VALVE (CVC 101).1.4 IF the reason for the Charging pump trip is corrected ANDPressurizer level is in normal operating band, THEN placeCharging and Letdown in service in accordance with Attachment 2.N/A2. IF normal Charging flow can NOT be established AND Pressurizer levelfalls below minimum Pressurizer level for operation in accordance withAttachment 1, Pressurizer Level Versus Tave Curve, THEN perform thefollowing:
BOP3. IF the PMC is available, THEN display PMC Group CVCS and monitorCharging System parameters to determine cause of Chargingmalfunction.
SRO4. Inspect Charging System for possible cause of malfunction.N/A5. IF a Charging Line rupture has occurred, THEN perform the following:CAUTIONIF HPSI PUMPS ARE OPERATING, THEN CHARGING PUMPS SHOULD NOT BE ALIGNED TOHPSI HEADER.NOTEAligning Charging to HPSI Train A renders HPSI train A INOPERABLE and Charging PumpsINOPERABLE. Enter TS 3.5.2 and 3.1.2.4. Refer to TS 3.5.3.N/A6. IF flow can NOT be established through the normal Charging Pumpdischarge path, THEN align Charging Pumps to discharge throughHPSI Header A as follows:N/A7. WHEN repairs have been completed to the Charging Header, THENrestore Charging Pumps discharge alignment to normal as follows:
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Charging Pump B TripsTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 SROReviews and enters the following Technical Specifications and TechnicalRequirements Manual actions: 3.1.2.4 (Technical Specification) 3.1.2.4 (Technical Requirements Manual)Examiner NoteThe SRO may align the AB Charging pump to replace the B Charging pump to allow exit ofTechnical Specification 3.1.2.4. The crew will remain in TRM 3.1.2.4 even if they align the ABpump.OP-002-005, Section 6.2, Charging Pump OperationsNOTEIf there is an Inoperable Charging Pump, then at SM/CRS discretion the Standby Charging Pumpsselector switch may be aligned so that the Operable Backup Charging Pump will be the first oneselected for auto starting capability.
ATC6.2.8 Verify Standby Charging Pumps selector switch in the appropriatePosition for the Charging Pump started (Pump in Lead) per Table6.2.8.(note)Position "AB-A" is preferred if Charging Pump A is started due toinoperable pump B.TABLE 6.2.8 PUMP IN L EAD POSITION BAB - A AB - AB ABA - B ATC6.2.9 Place control switch(es) for Standby Charging Pump A(B)(AB) toAUTO.ATC6.2.10 Place Pump AB Assignment switch to the appropriate Position forthe Charging Pump A(B)(AB) to be Assigned to Trip on SIAS, perTable 6.2.10.(note)Position 'B' will be selected due to inoperable pump B.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Charging Pump B TripsTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0TABLE 6.2.10 ASSIGNED TO TRIP ONSIAS POSITION A A ABNORM B BExaminer NoteThis event is complete after the ATC aligns the AB Charging pump to replace the B Chargingpump and the SRO has evaluated Technical Specifications/Technical Requirements Manual orAt Lead Examiner's DiscretionExaminer NoteCue the Simulator Operator when ready for Event 3 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube Leakage #1 SGTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0ATC / BOP Recognize and report indications of SGTLAlarms PMC alarm for Primary to Secondary Leakage BLOWDOWN ACTIVITY HI/MONITOR TROUBLE (Cabinet E, B-19) VACUUM PUMPS EXHAUST ACTIVITY HI/MONITOR TROUBLE(Cabinet E, C-3)Indications Primary to Secondary Leakage indicated on RM-11 Letdown flow lowering SROEnter and direct the implementation of OP-901-202, Steam Generator TubeLeakage or High Activity.OP-901-202, Steam Generator Tube Leakage or High ActivityN/A1. IF Pressurizer level CANNOT be maintained with available ChargingPumps, THEN perform the following:1.1 Manually trip Reactor.1.2 Manually initiate Safety Injection Actuation (SIAS) ANDContainment Isolation Actuation (CIAS).1.3 GO TO OP-902-000, STANDARD POST TRIP ACTIONS.(note)Step 1 (above) will not be performed at this time, but will beimplemented during Event 5.NOTE(1) The calculated Primary to Secondary Leak Rate values must be considered valid, unless thereading can be quickly diagnosed as incorrect due to an obvious malfunction of the PMC or AEDischarge Rad Monitor.(2) The AE Discharge Rad Monitor is considered the primary Rad Monitor which has the sensitivityto measure small Primary to Secondary Leakage. The AE Discharge Rad Monitor readinginputs into the Primary to Secondary Leak Calculation on PMC Group PLSR. The MS Line N16Rad Monitors may be used as verification of AE Discharge Rad Monitor or as primary indicationif the AE Discharge Rad Monitor is OOS.(3) If Primary to Secondary leakage will result in a backup Charging Pump cycling to maintainPressurizer level, starting and continuously running an additional Charging Pump will allow for amore accurate leakrate determination.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube Leakage #1 SGTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 BOP2. Determine RCS leak rate using ANY of the following: Calculated Steam Generator leakage displayed on PMC GroupPSLR (PMC PID C48304) Calculated Steam Generator leakage displayed on PMC PIDC48251 (RE5501 CH1 LEAK RATE) and C48252 (RE5501 CH2LEAK RATE) Approximate RCS leak rate by subtracting total of Letdown flowAND RCP CBO flow from Charging Flow Calculated Charging / Letdown Mismatch displayed on PMC GroupLeakrate (PMC PID S13001) RCS Leak Rate calculation in accordance withOP-903-024, REACTOR COOLANT SYSTEM WATERINVENTORY BALANCE Calculated steam generator leakage based upon chemistry sample,per CE-003-705, DETERMINATION OF PRIMARY-TO-SECONDARY LEAK RATE ATC2.1If necessary, then start an additional Charging Pump.
SRO3. IF primary to secondary leakage in any Steam Generator is 75 gpd(~0.05 gpm), then:
SRO3.1  Commence a rapid plant shutdown in accordance with OP-901-212,RAPID PLANT POWER REDUCTION, AND concurrently with thisProcedure, reduce Plant Power to50% within 1hour.
SRO3.2 WHEN Plant Power is50%, THEN in accordance with OP-901-212,RAPID PLANT POWER REDUCTION, AND concurrently with thisProcedure, be in Mode 3 within 2 hours AND Mode 5 in the following 30 hours.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
2Event #3 Page 10 of 35Event
 
== Description:==
Steam Generator Tube Leakage #1 SGTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0OP-901-212, Rapid Plant Power Reduction, E 0, General ActionsExaminer NoteA Rapid downpower does not have to be started at 30MW/min, but should attempt to eventuallyreach that value. The crew will likely not start the load reduction at that high of a rate.NOTE(1) A rapid power reduction is defined as approximately 30 MW/minute load reduction on the mainturbine.(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 casesSM/CRS may NA the step.(4) Steps within this procedure may be performed concurrently or out of sequence with SM/CRSconcurrence.(5) During power reduction PMC PID C24650, COLSS DESCENDING PWR TRACK (DUMOUT19),will automatically select and display the correct power indication.OP-010-003, Plant Startup, provides greater detail on which power indications are displayed byPID C24650 based on power level and whether or not the UFM is in service.(6) Volume Control Tank (VCT) level may lower during the down power. Charging pump suctionswaps to the RWSP at 8% VCT level. Makeup to the VCT in accordance with OP-002-005,Chemical and Volume Control, may be necessary if boration from the RWSP is not desired.
ATC1. Begin RCS Boration by one of the following methods:1.1 Direct Boration or1.2 Borate from the RWSP using one or two Charging Pump asfollows:1.2.1 Open RWSP to Charging Pumps Suction Isolation, CVC-507.1.2.2 Close Volume Control Tank Outlet Isolation, CVC-183.1.2.3 If necessary, then start another Charging pump Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube Leakage #1 SGTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0OP-002-005, Section 6.7, Direct Boration to RCSCAUTION(1) THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSS-CHECKEDAND COMPLETED PRIOR TO LEAVING CP-4.(2) AT LEAST ONE REACTOR COOLANT PUMP IN EACH LOOP SHOULD BE OPERATINGPRIOR TO PERFORMING DIRECT BORATION OPERATIONS TO ENSURE PROPERCHEMICAL MIXING.
ATC6.7.1 Inform SM/CRS that this Section is being performed.NOTEWhen 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 BoronPPM change. 1.2.1.1Power Defect Vs Power Level 1.4.3.1Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD) 1.4.4.1Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD) 1.4.5.1Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD) 1.4.6.1Inverse Boron Worth Vs. Tmod at EOC (340 EFPD)ATC6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be addedon Attachment 11.6, Calculation of Boric Acid Volume for DirectBoration or VCT Borate Makeup Mode.
ATC6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Aciddesired.ATC6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desiredBoric Acid Makeup Pump A(B).
ATC6.7.5 Place Direct Boration Valve, BAM-143, control switch to AUTO.
ATC6.7.6 Place Makeup Mode selector switch to BORATE.
ATC6.7.7 Verify selected Boric Acid Makeup Pump A(B) Starts.
ATC6.7.8 Verify Direct Boration Valve, BAM-143, Opens.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube Leakage #1 SGTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0NOTEThe Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is mostaccurate in the range of 10 - 25 GPM.(note)ATC will likely use manual boric acid flow control. "CVCS Boric AcidMakeup Flow Hi/Lo" on CP-4 is an expected annunciator.
ATC6.7.9 If manual control of Boric Acid flow is desired, then perform thefollowing:6.7.9.1 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, inManual.6.7.9.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, outputto >3 GPM flow rate.
ATC6.7.10 If automatic control of Boric Acid flow is desired, then perform thefollowing:6.7.10.1 Place Boric Acid Flow controller, BAM-IFIC-0210Y, inAuto.6.7.10.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y,setpoint potentiometer to >3 GPM flow rate.
ATC6.7.11 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate orOpen.ATC6.7.12 Observe Boric Acid flow rate for proper indication.
ATC6.7.13 When Boric Acid Makeup Batch Counter has counted down todesired value, then verify Boric Acid Makeup Control Valve, BAM-141, Closed.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube Leakage #1 SGTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0NOTEStep 6.7.14 may be repeated as necessary to achieve desired total boron addition for plant conditions.
ATC6.7.14 If additional boric acid addition is required and with SM/CRSpermission, then perform the following:6.7.14.1 Reset Boric Acid Makeup Batch Counter.6.7.14.2 Verify Boric Acid Makeup Control Valve, BAM-141,Intermediate or Open.6.7.14.3 Observe Boric Acid flow rate for proper indication.6.7.14.4 When Boric Acid Makeup Batch Counter has counteddown to desired value, then verify Boric Acid MakeupControl Valve, BAM-141, Closed.
ATC6.7.15 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual.
ATC6.7.16 Verify both Boric Acid Flow controller, BAM-IFIC-0210Y, output andsetpoint potentiometer set to zero.
ATC6.7.17 Place Makeup Mode selector switch to MANUAL.
ATC6.7.18 Verify Selected Boric Acid Makeup Pump A (B) Stops.
ATC6.7.19 Verify Direct Boration Valve, BAM-143, Closed.
ATC6.7.20 Place Direct Boration Valve, BAM-143, control switch to CLOSE.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube Leakage #1 SGTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0OP-901-212, Rapid Plant Power Reduction, E 0, General Actions (cont.)NOTETo prevent Pressurizer heater cutout, avoid operating with Pressurizer pressure near the heater cutoutpressure of 2270 PSIA while on Boron Equalization.
ATC2. Perform Boron Equalization as follows:2.1 Place available Pressurizer Pressure Backup Heater ControlSwitches to ON.2.2 Reduce Pressurizer Spray Valve Controller(RC-IHIC-0100) setpoint potentiometer to establish spray flowand maintain RCS pressure 2250 PSIA (2175 - 2265).CAUTIONREFER TO TECHNICAL SPECIFICATION 3.1.3.6 FOR TRANSIENT INSERTION LIMITS.
ATC3. Operate CEAs in accordance with OP-004-004, Control Element Drive,to maintain ASI using CEA Reg. Group 5, 6 or Group P Control ElementAssemblies in accordance with OP-010-005, Plant Shutdown,Attachment 9.10, Axial Shape Control Guidelines.OP-004-004, Section 6.7, Operation of CEAs in Manual Group (MG) ModeCAUTION(1) CRITICALITY SHALL BE ANTICIPATED ANY TIME CEAS ARE WITHDRAWN AND THEREACTOR IS NOT CRITICAL.(2) OBSERVE APPLICABLE GROUP INSERTION LIMITS IN ACCORDANCE WITH TECHNICALSPECIFICATION 3.1.3.6 (REG GROUP), AND TECHNICAL SPECIFICATION 3.1.3.5 (SHUTDOWN BANKS).(3) IMPROPER OPERATION OF CEAS IN MANUAL GROUP MODE MAY CAUSE A REACTOR TRIPBASED ON AN OUT-OF-SEQUENCE CONDITION.(4) CEA INITIALIZATION PROGRAM MUST BE RUNNING IN THE PLANT MONITORINGCOMPUTER TO HAVE GROUP STOPS AND SEQUENTIAL PERMISSIVES AVAILABLE.CAUTIONTHE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY. [INPO 06-006]
ATC6.7.1 Verify Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer.
ATC6.7.2 Position Group Select switch to desired group.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube Leakage #1 SGTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 ATC6.7.3 Place Mode Select switch to MG and verify the following: White lights Illuminated on Group Selection Matrix for selected group MG light Illuminates ATC6.7.4 Operate CEA Manual Shim switch to WITHDRAW or INSERT groupto desired height while monitoring the following: CEA Position Indicator selected CEA group is moving in desireddirection If Reactor is critical, then monitor the following: Reactor Power Reactor Coolant System (RCS) temperature Axial Shape Index (ASI)NOTEThe Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when theMode Select switch is not in OFF.
ATC6.7.5 When desired set of moves have been completed, then place ModeSelect switch to OFF.OP-901-212, Rapid Plant Power Reduction, E 0, General Actions (cont.)
SRO4. Notify the Woodlands System Load Dispatcher that a rapid powerreduction is in progress.
BOP5. Announce to Station Personnel over the Plant Paging System that arapid plant power reduction is in progress.
ATC6. Maintain RCS Cold Leg Temperature 536F to 549 F.BOP7. Commence Turbine load reduction by performing the following:7.1 Depress LOAD RATE MW/MIN pushbutton.7.2 Set selected rate in Display Demand Window.7.3 Depress ENTER pushbutton.7.4 Depress REFERENCE pushbutton.7.5 Set desired load in Reference Demand Window.7.6 Depress ENTER pushbutton.7.7 Depress GO pushbutton.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube Leakage #1 SGTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0NOTEIf USBSCAL is not in service, the COLSS Steam Calorimetric will be automatically disabled whenMSBSCAL, PMC PID C24246, drops below 95% Power, and will revert back to FWBSCAL, PMCPID C24235. This may result in a step change in COLSS indicated Plant Power (BSCAL) of up to1.0% when this occurs.SRO/ATC 8. When Reactor Power consistently indicates less than 98% power, asindicated 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.N/A9. If C24648 does not automatically change to 1, then inform ReactorEngineering and set the value of 1 for COLSS power smoothingconstant K24250, [ADDRSSBL SMOOTHING FOR BSCAL (ALPHA)] inaccordance with OP-004-005, Core Operating Limits SupervisorySystem.SRO/BOP 10. Following a Reactor Power change of >15% within a one hour period,direct Chemistry Department to sample Reactor Coolant System (RCS)for an isotopic iodine analysis two to six hours later.
BOP11. When Condensate flow is <18,000 gpm, verify Gland Steam CondenserBypass, CD-154, Closed (PMC PID D02404).
BOP12. Monitor Condensate Polisher differential pressure and removePolishers from service to maintain system pressure in accordance withOP-003-031, Condensate Polisher/Backwash Treatment.N/A13. When Reactor Power is approximately 70% or Heater Drain Pump flowis unstable, then remove Heater Drain Pumps from service by takingpump control switches to Stop.
SROReviews the following Technical Specifications and determines applicableactions: 3.4.5.2 action aExaminer NoteThis event is complete after the Reactivity Manipulation is satisfied and the SRO has evaluatedTechnical Specifications ORAt Lead Examiner's Discretion Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube Leakage #1 SGTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0Examiner NoteCue the Simulator Operator when ready for Event 4 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Turbine Cooling Water Pump A TripsTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0ATC / BOP Recognize and report indications of Turbine Cooling water Pump A TripAlarms TURBINE CLNG WATER DISCH HDR PRESS LO (Cabinet E, E-9) TURBINE CLNG WTR PUMP A TRIP/TROUBLE (Cabinet E, F-9) HYDROGEN TEMPERATURE HI (Cabinet D, H-8) FWPT A OIL COOLER OIL DISCH TEMP HI (Cabinet F, Q-15) FWPT B OIL COOLER OIL DISCH TEMP HI (Cabinet F, Q-19)Indications TCCW Pump A indication STOP and Yellow Lights TCCW Pump B indication STOP lightExaminer NoteIf the crew neglects to start the B TCCW pump, the turbine will trip due to high vibrationresulting in a Reactor Power Cutback.Examiner NoteThe BOP may start the B TCCW Pump upon indications of it failing to auto start, prior toentering the off normal.
SROEnter and direct the implementation of OP-901-512, Loss of Turbine CoolingWater.OP-901-512, Loss of Turbine Cooling Water, E 0, General Actions SRO1. IF loss of Turbine Cooling Water is due to loss of Turbine Cooling WaterPumps, THEN go to Subsection E1, Loss of Turbine Cooling WaterPumps.OP-901-512, Loss of Turbine Cooling Water, E 1, Loss of Turbine Cooling Water Pumps BOP1. IF EITHER Turbine Cooling Water Pump is available, THEN attempt tostart Turbine Cooling Water Pump to restore system flow.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Turbine Cooling Water Pump A TripsTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 BOP2. IF ANY of the following equipment is in operation, THEN monitor theassociated Turbine Cooling Water temperatures AND secure ANYunnecessary loads: Condenser Vacuum Pumps Steam Generator Feed Pump Turbines Heater Drain Pumps Turbine EH System Condensate Pumps Main Turbine Lube Oil Coolers Generator Exciter Coolers Generator Hydrogen Coolers Instrument Air Compressors Station Air Compressors Stator Coil Water System Hydrogen Seal Oil Coolers Isophase Bus Coolers Hydrogen DryersCAUTIONAT 100% POWER A TOTAL LOSS OF TURBINE COOLING WATER WILL RESULT IN SIGNIFICANTMAIN TURBINE DAMAGE IN 2-3 MINUTES WITH THE GENERATOR AS THE MOST LIMITINGCOMPONENT.N/A3. IF BOTH Turbine Cooling Water pumps are unavailable AND flow canNOT be restored, THEN perform the following:N/A4. Align Potable Water to Instrument Air and Station Air Compressors asfollows:Examiner NoteThis event is complete after the BOP has started the A TCCW Pump ORAt Lead Examiner's DiscretionExaminer NoteCue the Simulator Operator when ready for Event 5 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 ATCRecognize and report indications of Steam Generator Tube RuptureAlarms: PRESSURIZER LEVEL HI/LO (Cabinet H, B-1)Indications: PZR level lowering PZR pressure lowering All Pressurizer Heaters Energized Volume Control tank loweringOP-901-202, Steam Generator Tube Leakage or High Activity ATC1. IF Pressurizer level CANNOT be maintained with available ChargingPumps, THEN perform the following:1.1 Manually trip Reactor.1.2 Manually initiate Safety Injection Actuation (SIAS) ANDContainment Isolation Actuation (CIAS).1.3 GO TO OP-902-000, STANDARD POST TRIP ACTIONS.OP-902-000, Standard Post Trip Actions ATC1. DetermineReactivity Control acceptance criteria are met:a. Check reactor power is dropping.b. Check startup rate is negative.c. Check less thanTWOCEAs are NOTfully inserted.
BOP2. DetermineMaintenance of Vital Auxiliariesacceptance criteria aremet:a. Check the Main Turbine is tripped: Governor valves closed Throttle valves closed BOPb. Check the Main Generator is tripped: GENERATOR BREAKER A tripped GENERATOR BREAKER B tripped EXCITER FIELD BREAKER tripped Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
2Event #5 Page 21 of 35Event
 
== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 BOPc. Check station loads are energized from offsite electrical power asfollows: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 ChannelTrain 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 ChannelExaminer NoteThe Pressurizer will empty during this event and will not be able to be maintained usingCharging and Letdown flow.
ATC3. DetermineRCS Inventory Control acceptance criteria are met:a. Check thatBOTH the following conditions exist: Pressurizer level is 7% to 60% Pressurizer level is trending to 33% to 60%b. Check RCS subcooling is greater than or equal to 28&#xba;F.
ATCa.1Restore and maintain pressurizer level 33% to 60% by performingANYof the following:1) Operate Pressurizer Level Control System.2) Manually operate charging pumps and letdown control valves.
ATC4. DetermineRCS Pressure Control acceptance criteria are met bychecking thatBOTH of the following conditions exist: Pressurizer pressure is 1750 psia to 2300 psia Pressurizer pressure is trending to 2125 psia to 2275 psia ATC4.1  Restore and maintain pressurizer pressure 2125 psia to 2275 psia byperformingANYof the following:a. Operate Pressurizer Pressure Control System.b. Manually operate heaters and spray.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0Examiner NotePressurizer pressure will eventually lower below the 2 thresholds (1684; 1621 PSIA) after thePressurizer empties.
ATC4.2 IFpressurizer pressure is less than 1684 psia,THENverify thefollowing have initiated.IAS ATC4.3 IFpressurizer pressure is less than 1621 psia,THENverify no morethan two RCPs are operating.
ATC4.4 IFpressurizer pressure is less than the minimum RCP NPSH ofAppendix 2-A, "RCS Pressure and Temperature Limits",THENstopALL RCPs.Examiner NoteAppendix 2-A is contained on the next page. Conditions should allow for 2 RCPs to remainrunning.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 ATC5. DetermineCore Heat Removal acceptance criteria are met:a. Check at least one RCP is operating.b. Check operating loop T is less than 13&#xba;F.c. Check RCS subcooling is greater than or equal to 28&#xba;F.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 BOP6. DetermineRCS Heat Removal acceptance criteria are met:a. Check that at least one steam generator hasBOTH of the following: Steam generator level is 10% to 76% NR Main Feedwater is available to restore level within 55%-70%NR.[60% to 80% NR]
ATCb. Check RCS TC is 530 &#xba;F to 550 &#xba;F BOPc. Check steam generator pressure is 885 psia to 1040 psia.
BOPd. 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 BOPe. Reset moisture separator reheaters, and check the temperaturecontrol valves closed.
ATC7. DetermineContainment Isolation acceptance criteria are met:a. Check containment pressure is less than 16.4 psia.b. Check NO containment area radiation monitor alarms ORunexplained rise in activity.c. Check NO steam plant activity monitor alarms OR unexplained risein activity.Examiner NoteEvent 6 is contained on the next page and thereafter Event 5 is recommenced. It is possiblethat the applicants perform the actions of Event 6 either before or after this step in OP-902-000,Standard Post Trip Actions.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Relay K202 failure, RC-606 and FP-601B fail to auto closeTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 BOPRecognize indications of RC-606 and FP-601B Failure to closeAlarms N/AIndications RC-606 position indicates OPEN (Red) (CP-4) FP-601B position indicates OPEN (Red) (CP-8)Examiner NoteThese valves may have been noticed and closed earlier in the scenario.
ATCCloses RC-606, Controlled Bleedoff Inside Containment Isolation BOPCloses FP-601B, Firewater to Containment IsolationExaminer NoteThe next section returns to actions contained in Event 5.Examiner NoteThis event is complete after the RC-606 and FP-601B are closed Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0OP-902-000, Standard Post Trip Actions (cont.)
BOP8 DetermineContainment Temperature and Pressure Controlacceptance criteria are met:a. Check containment temperature is less than or equal to 120&#xba;F.b. Check containment pressure is less than 16.4 psia.N/A 9.IF ALLsafety function acceptance criteria are met,AND NOcontingency actions were performed,THENGO TO OP-902-001,"Reactor Trip Recovery" procedure.
SRO 10. IF ANYsafety function acceptance criteria are NOTmet,OR ANYcontingency action was taken,THENGO TO Appendix 1, "DiagnosticFlowchart.OP-902-009, Standard Appendices, Appendix 1 Diagnostic Flow ChartExaminer NoteAppendix 1 is a flow chart used to diagnose to the correct recovery procedure for the event inprogress. The steps below will be followed by a YES or NO to indicate proper flow path.
ATCRx Pwr dropping, SUR negative, and < two CEAs NOT fully inserted orEmergency Boration in progress (YES)ATCPressurizer pressure dropping rapidly and Pressurizer level changing (YES)BOPSteam Generator Pressure Abnormally Low (NO)N/APrimary Break ATCContainment Pressure and Temperature Abnormally High (NO)ATCActivity in the Steam Plant (YES)N/ASteam Generator Tube Rupture BOPAt least one 4KV safety bus energized (YES)SROGo To OP-902-007, Steam Generator Tube Rupture Recovery Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0OP-902-007, Steam Generator Tube Rupture RecoveryNOTEThe Shift Chemist should be notified if a SIAS or CIAS has occurred. The secondary samplingcontainment isolation valves should not be opened following an SIAS or CIAS until directed by the ShiftChemist.BOP*1. Confirm diagnosis of a SGTR:a. Check Safety Function Status Check acceptance criteria aresatisfied.
b.IFsteam generator sample path is available,THEN directChemistry to sampleBOTHsteam generators for activity.(note)If asked to perform step 1.a as the STA, simply acknowledge therequest.BOP2. Announce a Steam Generator Tube Rupture is in progress using theplant page.
SRO*3. Advise the Shift Manager to REFER TO EP-001-001, "Recognition &Classification of Emergency Condition", and implement the EmergencyPlan.(note)If asked to perform step 3 as the SM, simply acknowledge the request.
SRO*4. REFER TO Section 6.0, "Placekeeper", and record the time of thereactor trip.N/A*5.IFpower has been interrupted to either 3A or 3B safetybuses,THENperform Appendix 20, "Operation of DCT Sump Pumps".
ATC*6.IFpressurizer pressure is less than 1684 psia,THENverify SIAS hasinitiated.
BOP*7.IFSIAS 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. VerifyALLavailable charging pumps are operating.Examiner NoteAppendix 2-E and Appendix 2-F are contained below. Injection flow will be meeting allrequirements.
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== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 ATC*8.IFpressurizer pressure is less than 1621 psia,ANDSIAS is actuated,THEN:a. Verify no more than two RCPs are operating.
b.IFpressurizer pressure is less than the minimum RCP NPSH ofAppendix 2A-D, "RCS Pressure and Temperature Limits",THENstopALL RCPs.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0(note)Appendix 2A is contained earlier in this guide.
ATC*9.IFRCPs are operating,THEN:a. Verify CCW available to RCPs.
b.IFa CSAS is initiated,THENstopALL RCPs.c.IFRCS TC is less than 382&#xba;F,THENverify no more than twoRCPs are operating.
BOP*10. Check a CCW pump is operating for each energized 4.16 KV safetybus.BOP11. Commence a rapid RCS cooldown to less than 520&deg;F T H using thesteam bypass valves.(note)BOP will:Place 1 Steam Dump permissive switch to Manual [MS-319A(B)(C) MS-320A(B)(C)]Place controller for valve permissive switch placed in manualabove to Manual [MS-IHIC-0319-A(B)(C) MS-IHIC-0320-A(B)(C)]Raise output on controller to ~50%Examiner NoteCue the simulator operator to initiate Event 7 once the cooldown has started. Event 7 iscontained on the next page and thereafter Event 5 is recommenced.
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== Description:==
CCW Surge Tank level switch CC-ILS-7013A fails lowTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 BOPRecognize and report indications of CCW Surge Tank level switch failureAlarms CCW A SURGE TANK LVL LOST(Cabinet SA, B-5)start 3 min RCP 1A(B) 2A(B) CCW FLOW LOST (Cabinet SA, A-1(2)(3)(4)start 3 min RCP 1A(B) 2A(B) CCW FLOW LOST (Cabinet SB, A-6(7)(8)(9) RCP 1A(B) 2A(B) CCW PRESSURE LO (Cabinet H, G-3(5)(7)(9) RCP 1A(B) 2A(B) CCW FLOW LO (Cabinet H, H-3(5)(7)(10) CCW MAKEUP PUMP A RUNNING/POWER LOST (Cabinet M, G-2) SHUTDOWN HX A CCW FLOW LO (Cabinet M, H-2)Indications CC-200A/CC-727 position indicates closed (GREEN) CC-963A position indicates closed (GREEN) CCW Surge Tank levels indicate constant level CCW A header pressure and flow risingExaminer NoteThe step below is a continuous action step in OP-902-007 to verify CCW flow to the RCPs.
ATC*9.IFRCPs are operatin g,THEN:a. Verify CCW available to RCPs.
b.IFa CSAS is initiated,THENstopALL RCPs.c.IFRCS TC is less than 382&#xba;F,THENverify no more than twoRCPs are operating.CRITICAL TASKTRIP ANY RCP EXCEEDING OPERATING LIMITSThis task is satisfied by stopping all running Reactor Coolant Pumps prior to exceeding 3minutes without Component Cooling Water flow to the RCPs.This task becomes applicable after all RCP CCW flow lost annunciators actuate ATCa.1 IFCCW is lost to RCPsAND is NOTrestored within 3 minutes, THENstop the affected pumps. (CRITICAL)Examiner NoteThe next section returns to actions contained in Event 5.
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2Event #7 Page 32 of 35Event
 
== Description:==
CCW Surge Tank level switch CC-ILS-7013A fails lowTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0Examiner NoteThis event is complete after the ATC has stopped all running RCPs ORCritical task Performance Criteria has been exceeded Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0Examiner NoteAfter Event 7 has been completed and all RCPs have been turned off, the RCS will shift toNatural Circulation mode. During the transition with steady steam flow the T will increase.This will give the appearance of RCS temperature stable or rising as indicated THOT will stabilizeor slightly rise as TCOLD lowers during the buildup to establish the thermal driving headnecessary to establish Natural Circulation.Examiner NoteAppendix 2A is contained earlier in this guide.CRITICAL TASKPREVENT LIFTING AFFECTED SG SAFETY VALVESThis task is satisfied by commencing an RCS depressurization to less than 930 PSIA usingauxiliary spray valves and charging pumps prior to lifting atmospheric dump valve in automaticor main steam safety valves on affected Steam Generator.This task becomes applicable after the RCS has been cooled down to RCS THOT less than 520 Fand Steam Generator #1 is isolated.
ATC*12. Depressurize the RCS:a. Maintain pressurizer pressure withinALLof the following criteria:Within Appendix 2A-D, "RCS Pressure and Temperature Limits"Less than 930 psiaWithin 50 psi of the most affected steam generator pressureIFRCPs are operating, greater than the minimum RCP NPSH ofAppendix 2A-D, "RCS Pressure and Temperature Limits" ATCb. Operate main orauxiliary pressurizer spray. (CRITICAL)BOP c.IFHPSI throttle criteria are met,THENperformANYof the following:Control charging and letdown flowottle HPSI flow BOP*13.IFMSIS is NOT present,THENlower the automatic initiation setpointsas the cooldown and depressurization proceed for MSIS (low SGPressure).N/A 14.IFSIAS is NOT present,THENlower the automatic initiation setpointsas the cooldown and depressurization proceed for SIAS (low PZRPressure).N/A 15.IFoffsite power has been lost,THEN:
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 BOP16. Determine the most affected steam generator by consideringALLof thefollowing:Steam generator activitiesMain steam line radiation levelsSteam generator Blowdown radiation monitor readingsSteam generator level rise when NOTfeedingOne steam generator level rising faster than the other with feed andsteaming rates being essentially the same for bothFeed flow mismatch between steam generatorsSteam flow vs. feed flow mismatch in a steam generator prior to thereactor tripCRITICAL TASKISOLATE MOST AFFECTED STEAM GENERATORThis task is satisfied by closing Main Steam isolation valve, Main Feedwater isolation valve,Emergency Feedwater flow control and isolation valves, steam supply to EFW pump AB, steamline drains, and Blowdown isolation valves for #1 Steam Generator after THOT reduced below 520F and prior to exiting the step to Isolate the Most Affected Steam Generator (step 17) of OP-902-007.This task becomes applicable when the crew enters OP-902-007, Steam Generator TubeRupture Recovery BOP 17.Whenthe RCS TH is less than 520&deg;F,THENisolate the most affectedsteam generator:Steam Generator 1a. Place the ADV setpoint to 980 psig and verify the controller in AUTO.
BOPb. Verify the MSIV is closed. (CRITICAL)BOPc. Verify the MFIV is closed. (CRITICAL)N/A d.IFEFAS-1 isNOTinitiated,THENclose EFW Isolation Valves:FW 228A SG 1 PRIMARYFW 229A SG 1 BACKUP BOPe. Place EFW Flow Control Valves in MAN and close:FW 224A SG 1 PRIMARY (CRITICAL)EFW 223A SG 1 BACKUP (CRITICAL)BOPf. Close MS 401A, PUMP AB TURB STM SUPPLY SG 1. (CRITICAL)
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
2Event #5 Page 35 of 35Event
 
== Description:==
Steam Generator Tube RuptureTimePositionApplicant's Actions or Behavior2015 NRC Exam Scenario 2 D-2 Rev 0 BOPg. Close Main Steam Line 1 Drains:120A NORMAL119A BYPASS BOPh. Close Steam Generator Blowdown isolation valves:03A STM GEN 1 (OUT)02A STM GEN 1 (IN)
BOPi. Check the Main Steam Safety valves are closed.(note)The crew will send an NAO to verify Main Steam Safety valves are notlifting on SG1.Examiner NoteThis event is complete after the crew has isolated the #1 Steam Generator and commenceddepressurization of the RCS ORAt Lead Examiner's Discretion Appendix DScenario OutlineForm ES-D 1 -2015 NRC Exam Scenario 3 D-1 Rev 1Facility:WaterfordScenario No.:
3Op Test No.:
1Examiners:Operators:Initial Conditions: Mode 2, Reactor Power ~1%. Two Charging Pumps in operation.Turnover: Protected Train is B. AB Bus is aligned to Train B. Dilute to 5-10% power.EventNo.Malf.No.EventType*EventDescription 1N/AR - ATC N - SRODilute to 5-10% power, perform 100 gallon PMUaddition.2 RC22B2I - BOPI - SROTS - SRONarrow Range Safety Pressure Instrument, RC-IPT-0101B, fails low requiring TS 3.3.1 entry andbypassing of affected trip bistables.
3 CV35A CVR101C - ATCC - BOP C - SRODuring dilution, PMU counter fails to secure flow OP-901-104, Inadvertent Positive Reactivity Addition.
4 CC01AC - BOP C - SROTS - SROComponent Cooling Water Pump A trips requiringentry into OP-901-510, Component Cooling WaterSystem Malfunction (TS 3.7.3 & Cascading).
5RX14AI - ATCI - SROPressurizer Pressure RC-IPR-0100 X fails high, MainSpray Valves open requiring entry into OP-901-120,Pressurizer Pressure Malfunction.
6MS13AM - AllMain Steam Line Break outside Containment, SG 1,OP-902-004, Excess Steam Demand Recovery.
(Critical Task 1, stabilize RCS temperature withinP/T limits prior to lifting a PZR safety or SG safety)(Critical Task 2, stabilize RCS pressure within P/Tlimits and within 1500-1600 psid of the faulted SGprior to RCS pressure exceeding 2500 PSIA
)7 RP08GC - BOP C - SROMain Feedwater Isolation Valve Steam Generator 1,FW-184A fails to AUTO close on MSIS.
*(N)ormal,    (R)eactivity,    (I)nstrument,    (C)omponent,    (M)ajor Scenario Event DescriptionNRC Scenario 3- 2 -2015 NRC Exam Scenario 3 D-1 Rev 1The crew assumes the shift with the reactor at 1% power following a forced outage. The turnover willinclude instructions to perform RCS dilution to 5 - 10% power.The reactivity plan will include instructions to dilute in multiple PMU batches. The initial batch will be 100gallons of PMU. Each subsequent batch will be 50 gallons of PMU. This will allow for an observablepower rise without concern for a reactor trip on the PMU failure.After the first 100 gallons of PMU are added, Pressurizer pressure instrument, RC-IPI-0101B fails low.The ATC operator will receive the annunciators for this failure. The CRS should evaluate Tech Specsand enter Tech Spec 3.3.1 and determine that the Plant Protection System bistables for high LPD, lowDNBR and high Pressurizer pressure (3, 4, & 5) must be bypassed within 1 hour on Channel B. TechSpec 3.3.3.5 and 3.3.3.6 should be referenced but not entered.During the second dilution, the Primary Water counter will fail to secure dilution. The ATC should attemptto secure Primary Water Flow by operating PMU-144 and CVC-510. Neither of these actions will secureflow. The CRS should enter OP-901-104, Inadvertent Positive Reactivity Addition, and secure PrimaryMakeup Pump A.After these actions are completed, Component Cooling Water Pump A trips on overcurrent. The SROshould enter OP-901-510, Component Cooling Water System Malfunction, and direct the start ofComponent Cooling Water Pump AB to replace Component Cooling Water Pump A. The SRO shouldenter Technical Specification 3.7.3, TRM 3.7.3, and cascading Technical Specifications per OP-100-014,Technical Specification and Technical Requirements Compliance.After the Tech Specs are evaluated, Pressurizer pressure instrument RC-IPR-0100 X fails high. Thiscauses both Main Spray valves to open. The SRO should direct the ATC to take manual control andclose the spray valves and enter OP-901-120, Pressurizer Pressure Malfunction. The ATC will align thenon-faulted Pressurizer pressure channel.After the Pressurizer Pressure Control Channel Y is selected, a non-isolable Main Steam line breakoutside Containment occurs on Main Steam Line 1, resulting in a reactor trip, Safety Injection ActuationSignal (SIAS), Containment Isolation Actuation Signal (CIAS) and Main Steam Isolation Signal (MSIS).FW-184A, Feedwater Isolation Valve A fails to close automatically on the MSIS requiring the BOP tomanually close the valve. The SRO should diagnose to OP-902-004, Excess Steam Demand RecoveryProcedure. The crew should take action to stabilize Reactor Coolant System temperature(CRITICALTASK 1) and pressure(CRITICAL TASK 2) when Reactor Coolant System pressureAND Core ExitThermocouple temperatures start to rise.The scenario can be terminated after the crew has isolated Steam Generator 1 or at the lead examiner'sdiscretion.
NRC Scenario 3- 3 -2015 NRC Exam Scenario 3 D-1 Rev 1CRITICAL TASKS1. ESTABLISH REACTOR COOLANT SYSTEM TEMPERATURE CONTROLThis task is satisfied by taking action to stabilize Reactor Coolant System temperature within thelimits of the Reactor Coolant System Pressure/Temperature Limits curve using AtmosphericDump Valve 2 and establishing EFW flow to Steam Generator 2 prior to lifting a Pressurizersafety (2500 psia) or Steam Generator safety (1070 psig). This task becomes applicable onceCET temperature and PZR pressure begin to rise following the Main Steam Line Break. EitherOP-902-000, Standard Post Trip Actions or OP-902-004, Excess Steam Demand Recoverydirect actions to satisfy this task.2. ESTABLISH REACTOR COOLANT SYSTEM PRESSURE CONTROLThis task is satisfied by taking actions to stabilize RCS pressure within the limits of the ReactorCoolant System P/T curve and actions are taken to maintain Reactor Coolant System pressurewithin 1500-1600 psid of the faulted steam generator. Action to address this task shouldcommence prior to RCS pressure exceeding 2500 PSIA. This task becomes applicable onceCET temperature and PZR pressure begin to rise following the Main Steam Line Break. EitherOP-902-000, Standard Post Trip Actions or OP-902-004, Excess Steam Demand Recoverydirect actions to satisfy this task.Scenario Quantitative Attributes1. Malfunctions after EOP entry (1-2)12. Abnormal events (2-4)33. Major transients (1-2)14. EOPs entered/requiring substantive actions (1-2)15. EOP contingencies requiring substantive actions (0-2)06. EOP based Critical tasks (2-3)2 NRC Scenario 3- 4 -2015 NRC Exam Scenario 3 D-1 Rev 1SCENARIO SETUPA. Reset Simulator to IC-163.1. Use keys 165 - 168 for S/G high level bypass setup.B. Verify Scenario Malfunctions and Remotes are loaded, as listed in the Scenario Timeline.C. Ensure Event Trigger 10 is inserted as follows (Should be loaded in IC):1. Event - PMU Pump A to STOP2. Code is ZDIFWPMUECS1357(1) == 1D. Ensure Protected Train B sign is placed in SM office window.E. Verify EOOS is 10.0 GreenF. Place a copy of OP-010-003, Plant Startup, on CRS's desk with step 9.4.54 (raise power to 5%)circled and several of the previous steps circle-slashed to show progress. Fill in initials (and circle-slash) steps 9.4.59 (mode 1 Tech Spec logs) and 9.4.60 (Chemistry contacted) as complete. Signstep 9.4.61 (SM permission to enter mode 1).G. Complete the simulator setup checklist.H. Remove PMC point D39502 from scan (DFP).I. Start Insight, open file Crew Performance.tis.
NRC Scenario 3- 5 -2015 NRC Exam Scenario 3 D-1 Rev 1SIMULATOR BOOTH INSTRUCTIONSEvent 1 Dilute to 5-10% power, Perform 100 gallon PMU addition1. If called as Chemistry to verify SG chemistry is within specification, inform the caller that SGchemistry is satisfactory. If asked for your name, say Joe Chemist.2. If called as an NAO to open or throttle open MS-148, acknowledge the communication. Wait 5minutes, report that you will be slowly opening/throttling MS-148, MS Supply to Gland SealIsolation. Initiate EventTrigger 1. After MS-148 completes ramping, report that MS-148 isopen/throttled open. If you are directed to further throttle open MS-148, simply acknowledge therequest, wait ~30 seconds and report the new throttled position. Repeat as necessary until it isreported that MS-148 is fully open.3. If called as an NAO to transfer Auxiliary Steam from Aux Boiler Steam to Main Steam,acknowledge the communication. Wait 15 minutes, and then report that Auxiliary Steam has beentransferred to Main Steam (no remote necessary).4. If called as an NAO to secure the Portable Auxiliary Boiler, acknowledge the communication. Wait5 minutes, initiate EventTrigger 17 and report that the Portable Aux Boiler is secured.Event 2 Narrow Range Safety Pressure Instrument, RC-IPT-0101B, fails Low1. After the first 100 gallon addition is completed or on Lead Examiner's cue, initiate EventTrigger 2.2. If Work Week Manager or PMI are called, inform the caller that a work package will be assembledand a team will be sent to the Control Room.Event 3 PMU flow malfunction1. On Lead Examiner's cue,insert EventTrigger 3after the ATC has established PMU flow(second addition).2. If called to operate valves listed in OP-901-104, acknowledge communication and report that youwill work on valve list.Event 4 Component Cooling Water Pump A Trips1. On Lead Examiner's cue, initiate EventTrigger 4.2. If called as the watchstander and sent to CCW Pump A, wait 3 minutes, report that the pumplooks normal locally.3. If called as the watchstander and sent to CCW Pump A breaker, wait 3 minutes, report that thebreaker indicates open and that there are various breaker parts on the floor of the cubicle.4. If Work Week Manager or PME are called, inform the caller that a work package will beassembled and a team will be sent to the Control Room.Event 5 Pressurizer pressure instrument RC-IPR-0100 X fails High1. On Lead Examiner's cue, initiate EventTrigger 5.2. If Work Week Manager or I&C are called, inform the caller that a work package will be assembledand a team will be sent to the Control Room.
NRC Scenario 3- 6 -2015 NRC Exam Scenario 3 D-1 Rev 1Event 6 Main Steam Line Break outside Containment, SG 11. On Lead Examiner's cue, initiate EventTrigger 6.2. If the Duty Plant Manager is called, inform the caller that you will make the necessary calls.3. If Chemistry is called to perform samples acknowledge the request.4. If requested to check Emergency Diesel Generators (EDG), wait 3 minutes and report EDGs areoperating properly. Initiate event triggers 15 & 16 to acknowledge local annunciator panels.5. If called as an NAO to check for steam outside, wait 2 minutes, report that a large amount ofsteam is issuing from the west MSIV area.Event 7 Main Feedwater Isol Valve SG1, FW-184A, fails to AUTO close on MSIS1. No communications should occur for this evolution.
2.At the end of the scenario, before resetting, complete data collection by saving the file as2015 Scenario 3-(start-end time).tid. Export to .csv file. Save the file into the folder for theappropriate crew. Restore PMC point D39502 (RTP).3. After the simulator is reset, verify PMC point D39502 is in service by displaying and thenescaping from the display.
NRC Scenario 3- 7 -2015 NRC Exam Scenario 3 D-1 Rev 1SCENARIO TIMELINEEVENT KEYDESCRIPTIONTRIGGERDELAYHH:MM:SSRAMPHH:MM:SSFINALEVENT DESCRIPTION 1MSR09MS-148 MS to GS ISOL VALVE 100:00:0000:01:0012%DILUTE TO RAISE POWER 2RC22B2 PZR CPC SAFETY, RC-IPT-0101B, FAILS LOW 200:00:0000:00:00 ACTIVENR SAFETY PRESSURE INSTRUMENT, RC-IPT-0101B, FAILS LOW 3 CV35AMAKUP CTRLR FAILS TO ISSUE VLV CLSR WHEN BATCH COMP 300:00:0000:00:00ACTIVEDURING DILUTION, PMU COUNTER FAILS TO SECURE FLOW 3CVR101 PMU-140 DILUTION TO CVCS PUMP SUCTION (0-100%)
300:00:0000:00:00 2%DURING DILUTION, PMU COUNTER FAILS TO SECURE FLOW 3 CVR101PMU-140 DILUTION TO CVCS PUMP SUCTION (0-100%)
1000:00:0000:00:00 0%DURING DILUTION, PMU COUNTER FAILS TO SECURE FLOW 4CC01A CCW PUMP A TRIP 400:00:0000:00:00 ACTIVECOMPONENT COOLING WATER PUMP A TRIP 5 RX14APZR PRESSURE CNTL CHL 100 X FAIL (0-100%) (1500-2500 PSIA) 500:00:0000:00:00100%PRESSURIZER PRESSURE RC-IPR-0100 X FAILS HIGH 6MS13A MS A BREAK OUTSIDE CNTMT BEFORE MSIV (0-100%)
600:00:0000:00:00 6%NON-ISOLABLE MAIN STEAM LINE A BREAK OUTSIDE CONTAINMENT 7 RP08GRELAY K305 FAILED, MSIS TRAIN A (MS/FW)N/A00:00:0000:00:00ACTIVEFW-184A (SG1 FW ISOL VLV) FAILS TO AUTO CLOSE ON MSISN/AEGR26 EDG A LOCAL ANNUN ACK 15N/AN/AACKNEDG A LOCAL ANNUNCIATOR PANELN/AEGR27EDG B LOCAL ANNUN ACK 16N/AN/AACKNEDG B LOCAL ANNUNCIATOR PANEL NRC Scenario 3- 8 -2015 NRC Exam Scenario 3 D-1 Rev 1EVENT KEYDESCRIPTIONTRIGGERDELAYHH:MM:SSRAMPHH:MM:SSFINALEVENT DESCRIPTIONN/AMSR32 TEMPORARY AUX BOILER 17N/AN/AOFFLINETEMPORARY AUX BOILER (16 MIN TILL RATED PRESS)
NRC Scenario 3- 9 -2015 NRC Exam Scenario 3 D-1 Rev 1REFERENCESEventProcedures 1OP-010-003, Plant Startup, Rev. 335OP-002-005, Chemical and Volume Control, Rev. 47 2OP-009-007, Plant Protection System, Rev. 16OP-903-013, Monthly Channel Checks, Rev. 18Technical Specification 3.3.1 3OP-901-104, Inadvertent Positive Reactivity Addition, Rev. 302 4OP-901-510, Component Cooling Water Malfunction, Rev. 303OP-100-014, TS & TRM Compliance, Rev. 328Technical Specification 3.7.3 & CascadingTech Requirement Manual 3.7.3 5OP-901-120, Pressurizer Pressure Control Malfunction, Rev. 302Technical Specification 3.2.8 6OP-902-000, Standard Post Trip Actions, Rev. 15OP-902-004, Excess Steam Demand Recovery Procedure, Rev. 15OP-902-009, Standard Appendices, Rev. 310, Appendix 1 (Diagnostic Flow Chart),Appendix 2 (Figures) 7OP-902-004, Excess Steam Demand Recovery Procedure, Rev. 15OI-038-000, EOP Operations Expectations/Guidance, Rev. 10EN-OP-115, Conduct of Operations, Rev. 15 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Dilute to 5-10% powerTimePositionApplicant's Actions or BehaviorExaminer NoteEvent 1 is a normal plant evolution. The crew will be pre-briefed and ready to start raisingpower once they take the shift. Per the reactivity plan the crew will add 100 gallons of PrimaryMakeup Water (PMU) on the first batch followed by 50 gallon batches.OP-010-003, Section 9.4, Plant Startup to 10% Power SRO9.4.54  Begin raising Reactor power by CEA withdrawal or boron dilution to5% full power.(note)The SRO directs the ATC to coordinate with the BOP and raise powerto 5-10%. The SRO will direct the ATC to initiate RCS dilution inaccordance with OP-002-005 and the approved reactivity plan.OP-002-005, Section 6.9, VCT Makeup using the Dilute Makeup Mode (C)NOTEVCT makeup and RWSP makeup utilize the same supply header. VCT makeup cannot be performedwhile performing the following procedure sections:  Section 6.12RWSP Blended Makeup Section 6.13          RWSP Boration.CAUTIONTHE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITYCAUTIONTHIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSS-CHECKED ANDCOMPLETED PRIOR TO LEAVING CP-4.
ATC6.9.1 Inform SM/CRS that this Section is being performed.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Dilute to 5-10% powerTimePositionApplicant's Actions or BehaviorNOTEWhen 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 BoronPPM change. 1.2.1.1Power Defect Vs Power Level 1.4.3.1Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD) 1.4.4.1Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD) 1.4.5.1Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD) 1.4.6.1Inverse Boron Worth Vs. Tmod at EOC (340 EFPD)N/A6.9.2 At SM/CRS discretion, calculate volume of Primary Makeup waterto be added on Attachment 11.7, Calculation of Primary MakeupWater Volume for Direct Dilution or VCT Dilute Makeup Mode.(note)Not applicable, reactivity plan gives required volume.
ATC6.9.3 Set Primary Makeup Water Batch Counter to volume of PrimaryMakeup water desired.(note)Procedure does not give specific steps to set the counter. 100 gal ofwater on the counter is set by pressing: UP arrow button ENTER button the side arrow button to move the cursor the raise button toenter 10 (counter reading is multiplied by 10) ENTER RESET ATC6.9.4 Place Makeup Mode selector switch to DILUTE.
ATC6.9.5 Open VCT Makeup Valve, CVC-510.NOTEThe Dilution Flow Totalizer will not register below 5 GPM. The Dilution Flow Totalizer is most accurateat >10 GPM.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Dilute to 5-10% powerTimePositionApplicant's Actions or BehaviorCAUTIONDILUTION SHALL IMMEDIATELY BE STOPPED IF PRE-POWER DEPENDENT INSERTION LIMIT(H-9, CABINET H) ALARM IS INITIATED OR ANY UNEXPECTED REACTIVITY CHANGE OCCURS.(note)ATC will likely use manual Primary Makeup Water flow control. "CVCSRx Makeup Wtr Flow Hi/Lo" on CP-4 is an expected annunciator.
ATC6.9.6If manual control of Primary Makeup Water flow is desired, thenperform the following:6.9.6.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Manual.6.9.6.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, output to >5 GPM flow rate.
ATC6.9.7If automatic control of Primary Makeup Water flow is desired,then perform the following:6.9.7.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Auto.6.9.7.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, setpoint potentiometer to >5 GPM flow rate.
ATC6.9.8Verify Primary Makeup Water Control Valve, PMU-144,Intermediate or Open ATC6.9.9Observe Primary Makeup water flow rate for proper indication ATC6.9.10 Operate VCT Inlet/Bypass to Holdup Tanks, CVC-169 Control Switchto BMS/Auto positions as necessary to maintain VCT pressure and levelwithin normal operating bands.
ATC6.9.11 When Primary Makeup Water Batch Counter has counted down todesired value, then verify Primary Makeup Water Control Valve, PMU-144,Closed.NOTEStep 6.9.12 may be repeated as necessary to achieve desired total Primary Makeup Water addition forplant conditions.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Dilute to 5-10% powerTimePositionApplicant's Actions or Behavior ATC6.9.12 If additional Primary Makeup Water addition is required and withSM/CRS permission, then perform the following:6.9.12.1 Reset Primary Makeup Water Batch Counter.6.9.12.2 Verify Primary Makeup Water Control Valve, PMU-144,Intermediate or Open.6.9.12.3 Observe Primary Makeup Water flow rate for proper indication.6.9.12.4 When Primary Makeup Water Batch Counter has counted downto desired value, then verify Primary Makeup Water ControlValve, PMU-144, Closed.(note)The reactivity plan describes that additional PMU additions will berequired. The SRO may or may not use this option. It is acceptable ifthe crew chooses to leave this aligned.
ATC6.9.13 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, inManual.ATC6.9.14 Verify both Primary Makeup Water Flow controller, PMU-IFIC-0210X,output and setpoint potentiometer set to zero.
ATC6.9.15 Close VCT Makeup Valve, CVC-510.
ATC6.9.16 Place Makeup Mode selector switch to MANUAL.
ATC6.9.17 Verify VCT Inlet/Bypass To Holdup Tanks, CVC-169, aligned to theVCT and control switch in AUTO.Examiner NoteThis event is complete after the crew has added 100 gallons of Primary Makeup OrAs directed by the Lead EvaluatorExaminer NoteCue the Simulator Operator when ready for Event 2 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Narrow Range Safety Pressure Instrument, RC-IPT-0101B fails lowTimePositionApplicant's Actions or Behavior ATCRecognize and report indications of failed channel.Alarms: RPS CHANNEL TRIP LOCAL PWR DENSITY HI (Cabinet K, A-11) RPS CHANNEL TRIP DNBR LO (Cabinet K, A-12) RPS CHANNEL B TROUBLE (Cabinet K, F-18) CORE PROTECT CHNL B CALCULATOR TROUBLE (Cabinet K, N-12)Indications: Pressurizer pressure instrument RC-IPI-0101B on CP-7 indicates low DNBR and LPD trip and pre-trip lamps lit on CP-7 Channel B CPC Channel B on CP-7 'Sensor Fail' lamp litExaminer NoteCrew may continue with OP-010-003, Plant Startup. The step to establish Main Steam to GlandSeals is included in this section for your reference.OP-009-007, Plant Protection System ,Section 6.2, Trip Channel Bypass Operation(note)All BOP manipulations for OP-009-007 are located at CP-10 (backpanel) except as noted.
SRO6.2.1 Refer to Attachment 11.11, PPS Bistable Bypass Chart to assist indetermination of Trip Channels requiring placement in bypass.(note)SRO determines the following bistables are affected and need to bebypassed: 3-HILOCAL POWER 4-LO DNBR 5-HI PZR PRESS SRODirects BOP to bypass the HI LOCAL POWER, LO DNBR, and HI PZRPRESS bistables in PPS Channel B within 1 hour in accordance with OP-009-007, Plant Protection System.
BOP6.2.2 To place a bistable in or remove a bistable from bypass, go toAttachment 11.10, Trip Channel Bypass Operation.
BOP11.10.1 To Bypass a Trip Channel, perform the following:11.10.1.1 Circle the bistable numbers selected for bypass underStep 11.10.1.4.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Narrow Range Safety Pressure Instrument, RC-IPT-0101B fails lowTimePositionApplicant's Actions or Behavior(note)BOP circles bistable numbers 3, 4 and 5 in Step 11.10.1.4 table BOP11.10.1.2 Check desired Trip Channel is not Bypassed on another PPSChannel.BOP11.10.1.3 Open key-locked portion of BCP in desired PPS Channel.
BOP11.10.1.4 Depress Bypass push buttons for the desired Trip Channels BOP11.10.1.5 Check all selected bistable Bypass push buttons remain in aDepressed state.
BOP11.10.1.6 Check all selected bistable Bypass lights Illuminate on BCP forthe desired Trip Channels.CREW11.10.1.7 Check all selected bistable Bypass lights Illuminate on ROM forthe desired Trip Channels.(note)Crew verifies correct bistables lit on CP-7 PPS Channel B RemoteOperator Module.
SROReviews the following Technical Specifications and determines applicableactions: 3.3.1 action 2 3.3.3.5 - no actions required 3.3.3.6 - no actions required(note)OP-903-013, Monthly Channel Checks, does not list this instrument forTech Spec 3.3.3.5 and 3.3.3.6 applicability.Examiner NoteThe step to establish Main Steam to Gland Seals is included below for your reference. It is notnecessary to complete this step prior to advancing with the scenario.OP-010-003, Section 9.4, Plant Startup to 10% Power (cont.)
BOP9.4.55 Prior to exceeding 5% power, verify Linear Power Channels areon scale.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
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== Description:==
Narrow Range Safety Pressure Instrument, RC-IPT-0101B fails lowTimePositionApplicant's Actions or BehaviorNOTEGS PCV Bypass Valve, GS-104, will normally be Closed, when Main Steam is supplying the GlandSeal System.CAUTIONATC OPERATOR SHOULD BE NOTIFIED PRIOR TO TRANSFERRING GLAND SEAL STEAM (GS)SUPPLY TO MAIN STEAM, AS THE CHANGE IN STEAM FLOW MAY CAUSE A CHANGE IN RCSTEMPERATURE AND REACTIVITY.
BOP9.4.56Establish Main Steam to Gland Seals as follows:
BOP9.4.56.1Adjust GS PCV Bypass Valve, GS-104, to maintain 100 to 140PSIG on the Gland Steam Header Pressure Recorder (GS-IPR-1801).NAO9.4.56.2Slowly Open Main Steam Supply Valve to Gland Seal Isolation,MS-148.BOP9.4.56.3Close Auxiliary Boiler Steam to Gland Steam, ABS-314.BOP/NAO9.4.56.4Verify HP and LP Turbine Seals are maintaining approximately1.5 to 3 PSIG.BOP/NAO9.4.56.5Verify Main Feedwater Pump Seals are maintainingapproximately 3 to 5 PSIG.
NAO9.4.57Transfer Auxiliary Steam supply from Auxiliary Boiler Steam toMain Steam in accordance with OP-005-002, Auxiliary Steam.
NAO9.4.58Secure Auxiliary Boiler in accordance with OP-005-001,Auxiliary Boiler.Examiner NoteThis event is complete after the SRO has addressed Technical Specifications andPPS Channel B trip bistables are bypassed ORAs directed by the Lead EvaluatorExaminer NoteCue the Simulator Operator when ready for Event 3.Event 3 must be triggered while PMU is actively flowing to the VCT during the second PMUaddition.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #3 Page 8 of 30Event
 
== Description:==
PMU Failure / Inadvertent DilutionTimePositionApplicant's Actions or BehaviorExaminer NoteOn this 50 gallon water addition, the PMU Batch Counter will fail to secure PMU flow.Event 3 must be triggered while PMU is actively flowing to the VCT during the second PMUaddition.(note)ATC aligns for second PMU add (50 gallons) in accordance with OP-002-005, Chemical and Volume Control.OP-002-005, Section 6.9, VCT Makeup using the Dilute Makeup Mode (C)NOTEVCT makeup and RWSP makeup utilize the same supply header. VCT makeup cannot be performedwhile performing the following procedure sections:  Section 6.12RWSP Blended Makeup Section 6.13          RWSP Boration.CAUTIONTHE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITYCAUTIONTHIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSS-CHECKED ANDCOMPLETED PRIOR TO LEAVING CP-4.
ATC6.9.1 Inform SM/CRS that this Section is being performed.NOTEWhen 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 BoronPPM change. 1.2.1.1Power Defect Vs Power Level 1.4.3.1Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD) 1.4.4.1Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD) 1.4.5.1Inverse 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)
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #3 Page 9 of 30Event
 
== Description:==
PMU Failure / Inadvertent DilutionTimePositionApplicant's Actions or BehaviorN/A6.9.2 At SM/CRS discretion, calculate volume of Primary Makeup water tobe added on Attachment 11.7, Calculation of Primary Makeup WaterVolume for Direct Dilution or VCT Dilute Makeup Mode.(note)Not applicable, reactivity plan gives required volume.
ATC6.9.3 Set Primary Makeup Water Batch Counter to volume of PrimaryMakeup water desired.(note)Procedure does not give specific steps to set the counter. 50 gal ofwater on the counter is set by pressing: UP arrow button ENTER button the side arrow button to move the cursor the raise button toenter 5 (counter reading is multiplied by 10) ENTER RESET ATC6.9.4 Place Makeup Mode selector switch to DILUTE.
ATC6.9.5 Open VCT Makeup Valve, CVC-510.NOTEThe Dilution Flow Totalizer will not register below 5 GPM. The Dilution Flow Totalizer is most accurateat >10 GPM.CAUTIONDILUTION SHALL IMMEDIATELY BE STOPPED IF PRE-POWER DEPENDENT INSERTION LIMIT(H-9, CABINET H) ALARM IS INITIATED OR ANY UNEXPECTED REACTIVITY CHANGE OCCURS.
ATC6.9.6.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, inManual.ATC6.9.6.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X,output to >5 GPM flow rate.
ATC6.9.8 Verify Primary Makeup Water Control Valve, PMU-144, Intermediateor Open.ATC6.9.9 Observe Primary Makeup water flow rate for proper indication.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #3 Page 10 of 30Event
 
== Description:==
PMU Failure / Inadvertent DilutionTimePositionApplicant's Actions or Behavior ATC6.9.10 Operate VCT Inlet/Bypass to Holdup Tanks, CVC-169 Control Switchto BMS/Auto positions as necessary to maintain VCT pressure and levelwithin normal operating bands.6.9.11 When Primary Makeup Water Batch Counter has counted down todesired value, then verify Primary Makeup Water Control Valve, PMU-144,Closed.Examiner NotePMU Batch Counter will fail to secure PMU flow.
ATCRecognize and report indications of PMU failure.Indications: PMU flow does not change as the PMU Batch Counter reaches 0gallons PMU Batch Counter counts through 0 and continues counting withnegative numbers. Dilution Flow Totalizer continues counting up ATC Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, outputto 0% output. Close CVC-510, VCT Makeup valve.(note)These actions will reduce flow, but flow will continue at ~ 7 gpm.
CRSEnter and direct the implementation of OP-901-104, Inadvertent PositiveReactivity Addition, section E 1, Actions During Startup, Power Operation,and ShutdownOP-901-104 Section E1, Actions During Startup, Power Operations, and Shutdown ATC1. Verify REACTOR MAKE UP PRI WTR CONTR VA (PMU 144) Closed.
BOP2. Stop both Primary Makeup Water Pumps A and B.(note)PMU flow will go to 0 gpm after PMU Pump A is secured.SRO/ATC 3. Verify only one Charging Pump operating.
ATC4. Bypass or secure Purification Ion Exchangers as follows:
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #3 Page 11 of 30Event
 
== Description:==
PMU Failure / Inadvertent DilutionTimePositionApplicant's Actions or Behavior ATC4.1 Place LETDOWN TO ION EXCHANGER BYPASS valve (CVC 140)to BYPASS.N/A4.2 If Shutdown Cooling Purification is in service, then at SM/CRSdiscretion, secure SDC Purification in accordance with OP-009-005,Shutdown Cooling System.
SRO5. If dilution still in progress, then Close PMU Hdr to Dilution Tee and ChemAdd Tank Isol, PMU 135 (RAB-4 5A&J).6. Borate as necessary to maintain stable plant conditions.Examiner NoteCrew may wait to see the effect of the extra PMU prior to performing boration. The steps forDirect Boration and CEA insertion are included in this section. It is not necessary to hold atthis point for either actionOP-002-005, Section 6.7, Direct Boration to RCSCAUTIONTHE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY.CAUTION (1) THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSSCHECKEDAND COMPLETED PRIOR TO LEAVING CP-4.(2) AT LEAST ONE REACTOR COOLANT PUMP IN EACH LOOP SHOULD BE OPERATING PRIORTO PERFORMING DIRECT BORATION OPERATIONS TO ENSURE PROPER CHEMICAL MIXING.
ATC6.7.1 Inform SM/CRS that this Section is being performed.NOTEWhen 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 BoronPPM 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)
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #3 Page 12 of 30Event
 
== Description:==
PMU Failure / Inadvertent DilutionTimePositionApplicant's Actions or Behavior ATC6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be addedon Attachment 11.6, Calculation of Boric Acid Volume for DirectBoration or VCT Borate Makeup Mode.
ATC6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Aciddesired.(note)Procedure does not give specific steps to set the counter. Desiredamount of acid on the counter is set by pressing: UP arrow button ENTER button the side arrow button to move the cursor the raise button to desired amount ENTER RESET ATC6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desiredBoric Acid Makeup Pump A(B).
ATC6.7.5 Place Direct Boration Valve, BAM-143, control switch to AUTO.
ATC6.7.6 Place Makeup Mode selector switch to BORATE.
ATC6.7.7 Verify selected Boric Acid Makeup Pump A(B) Starts.
ATC6.7.8 Verify Direct Boration Valve, BAM-143, Opens.NOTEThe Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is mostaccurate in the range of 10 - 25 GPM.(note)ATC will likely use manual boric acid flow control. "CVCS Boric AcidMakeup Flow Hi/Lo" on CP-4 is an expected annunciator.
ATC6.7.9 If manual control of Boric Acid flow is desired, then perform thefollowing: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 >3GPM flow rate.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #3 Page 13 of 30Event
 
== Description:==
PMU Failure / Inadvertent DilutionTimePositionApplicant's Actions or Behavior ATC6.7.10 If automatic control of Boric Acid flow is desired, then perform thefollowing:6.7.10.1 Place Boric Acid Flow controller, BAM-IFIC-0210Y, in Auto.6.7.10.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, setpointpotentiometer to >3 GPM flow rate.
ATC6.7.11 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate orOpen.ATC6.7.12 Observe Boric Acid flow rate for proper indication.
ATC6.7.13 When Boric Acid Makeup Batch Counter has counted down todesired value, then verify Boric Acid Makeup Control Valve, BAM-141, Closed.NOTEStep 6.7.14 may be repeated as necessary to achieve desired total boron addition for plant conditions.
ATC6.7.14 If additional boric acid addition is required and with SM/CRSpermission, then perform the following:6.7.14.1 Reset Boric Acid Makeup Batch Counter.6.7.14.2 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediateor Open.6.7.14.3 Observe Boric Acid flow rate for proper indication.6.7.14.4 When Boric Acid Makeup Batch Counter has counted down todesired value, then verify Boric Acid Makeup Control Valve, BAM-141, Closed.
ATC6.7.15 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual.
ATC6.7.16 Verify both Boric Acid Flow controller, BAM-IFIC-0210Y, output andsetpoint potentiometer set to zero.
ATC6.7.17 Place Makeup Mode selector switch to MANUAL.
ATC6.7.18 Verify Selected Boric Acid Makeup Pump A(B) Stops.
ATC6.7.19 Verify Direct Boration Valve, BAM-143, Closed.
ATC6.7.20 Place Direct Boration Valve, BAM-143, control switch to CLOSE.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #3 Page 14 of 30Event
 
== Description:==
PMU Failure / Inadvertent DilutionTimePositionApplicant's Actions or BehaviorOP-004-004, Section 6.7, Operation of CEAs in Manual Group (MG) ModeCAUTION(1) CRITICALITY SHALL BE ANTICIPATED ANY TIME CEAS ARE WITHDRAWN AND THEREACTOR IS NOT CRITICAL.(2) OBSERVE APPLICABLE GROUP INSERTION LIMITS IN ACCORDANCE WITH TECHNICALSPECIFICATION 3.1.3.6 (REG GROUP), AND TECHNICAL SPECIFICATION 3.1.3.5 (SHUTDOWN BANKS).(3) IMPROPER OPERATION OF CEAS IN MANUAL GROUP MODE MAY CAUSE A REACTOR TRIPBASED ON AN OUT-OF-SEQUENCE CONDITION.(4) CEA INITIALIZATION PROGRAM MUST BE RUNNING IN THE PLANT MONITORINGCOMPUTER TO HAVE GROUP STOPS AND SEQUENTIAL PERMISSIVES AVAILABLE.CAUTIONTHE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY. [INPO 06-006]
ATC6.7.1 Verify Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer.
ATC6.7.2 Position Group Select switch to desired group.
ATC6.7.3 Place Mode Select switch to MG and verify the following: White lights Illuminated on Group Selection Matrix for selected group MG light Illuminates ATC6.7.4 Operate CEA Manual Shim switch to WITHDRAW or INSERT groupto desired height while monitoring the following: CEA Position Indicator selected CEA group is moving in desireddirection If Reactor is critical, then monitor the following: Reactor Power Reactor Coolant System (RCS) temperature Axial Shape Index (ASI)NOTEThe Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when theMode Select switch is not in OFF.
ATC6.7.5 When desired set of moves have been completed, then place ModeSelect switch to OFF.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #3 Page 15 of 30Event
 
== Description:==
PMU Failure / Inadvertent DilutionTimePositionApplicant's Actions or BehaviorExaminer NoteThis event is complete after the crew has entered OP-901-104 and secured PMU Pump A OrAs directed by the Lead EvaluatorExaminer NoteCue the Simulator Operator when ready for Event 4.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #4 Page 16 of 30Event
 
== Description:==
Component Cooling Water Pump A tripsTimePositionApplicant's Actions or Behavior BOPRecognize and report indications of tripped CCW Pump.Alarms: CCW PUMP A TRIP/TROUBLE (Cabinet M, B-2 ) RCP 1A CCW FLOW LO (Cabinet H, H-3) RCP 1B CCW FLOW LO (Cabinet H, H-5) RCP 2A CCW FLOW LO (Cabinet H, H-7) RCP 2B CCW FLOW LO (Cabinet H, H-10)Indications Amber trip/trouble light on CCW Pump A control switch CCW System pressure abnormally low and dropping CCW System and component flows abnormally low(note)Based on how long the crew takes to align CCW Pump AB, red RCPLow Flow alarms may come in on CP-2. This should be called out bythe ATC.SROEnter and direct the implementation of OP-901-510, Component CoolingWater System Malfunction.OP-901-510 Section E0, GeneralN/A 1.IF ANY of the following occur, THEN GO TO Subsection E 1, System Leakage: CCW Surge Tank level dropping CCW Dry Cooling Towers isolated due to low CCW Surge Tanklevel CMU-226, WATER STORAGE MAKEUP CCW SURGE TANK,cycling frequently CCW header isolates due to low CCW Surge Tank level Local observation of CCW leak reported to Control Room SRO 2.IF ANY of the following occur, THEN GO TO Subsection E 2, Loss ofCCW Pump(s): CCW system OR component flows low Amber trip/trouble light on CCW PUMP A(B)(AB) Control Switch Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #4 Page 17 of 30Event
 
== Description:==
Component Cooling Water Pump A tripsTimePositionApplicant's Actions or BehaviorOP-901-510 Section E2, Loss of CCW Pump(s)N/A1. IF CCW is lost to in-service Shutdown Cooling train, THEN implementOP-901-131, SHUTDOWN COOLING MALFUNCTION, AND performconcurrently with this procedure.N/A2. IF Component Cooling Water Pump AB has tripped, THEN Startstandby CCW Pump.2.1 PLACECCWASSIGNMENT SWITCH TONORM POSITION.BOP3. IF Component Cooling Water Pump A has tripped, THEN align CCWPump AB for Operation as follows:
BOP3.1 Position CCW ASSIGNMENT switch to position A.
BOP3.2 Verify Open the following valves: CC-126A/CC-114A CCW SUCT & DISCH HEADER TIEVALVES AB TO A CC-127A/CC-115A CCW SUCT & DISCH HEADER TIEVALVES AB TO A BOP3.3 Start CC-0001AB, Component Cooling Water Pump AB.
SRO3.4 Evaluate AB Electrical Bus alignment for Technical SpecificationOperability requirements.(note)With the AB Safety Bus aligned to Train B, credit cannot be takenfor CCW Pump ABThe SRO should enter Tech Spec 3.7.3, TRM 3.7.3 and CascadingTech Specs per OP-100-014.This includes a 1 hour requirement to verify off site electricalpower. The CRS should vocalize this requirement and assign theOP-903-066 surveillance to either the BOP or ATC operator. TheBOP is preferred.Cascading Tech Specs also includes a 2 hour requirement to verifycomponents that rely on Train B safety power operable per3.8.1.1.d.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #4 Page 18 of 30Event
 
== Description:==
Component Cooling Water Pump A tripsTimePositionApplicant's Actions or BehaviorExaminer NoteThis event is complete after CCW pump A is started and the SRO has addressed TechnicalSpecifications ORAs directed by the Lead EvaluatorExaminer NoteCue the Simulator Operator when ready for Event 5.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #5 Page 19 of 30Event
 
== Description:==
Pressurizer Pressure Control Channel RC-IPR-0100X fails HiTimePositionApplicant's Actions or Behavior ATCRecognize and report indications of failed pressure instrument.Alarms PRESSURIZER PRESSURE HI/LO (Cabinet H, E-1) PRESSURIZER PRESS SIGNAL DEVIATION (Cabinet H, F-1)Indications Recorder RC-IPR-0100 red pen fails Hi. Controller RC-IPIC-0100 process fails Hi. Controller RC-IPIC-0100 output goes to 100%. All Pressurizer Proportional and Backup Heaters secure. Both Pressurizer Main Spray Valves go full open. Pressurizer Pressure drops rapidly due to the full Main Spray.
ATCPlace Pressurizer Spray Controller RC-IHIC-0100 to MAN and close theMain Spray Valves.(note)This action may be taken before the crew enters OP-901-120.Operations procedures include allowances for taking manual control ofcomponents when their automatic function is not controlling. The CRSshould direct this action prior to entering off normal procedure OP-901-120.CRSEnter and direct the implementation of OP-901-120, Pressurizer PressureMalfunction, and use sub-section E1, Pressurizer Pressure Control ChannelInstrument Failure.OP-901-120 Section E0, GeneralCautionSteam Generator pressures dropping concurrently with dropping Pressurizer level may be indicative ofan excess steam demand.N/A1. IF Pressurizer Pressure and Level are dropping concurrently, OR RCSleakage is otherwise indicated, THEN GO TO OP-901-111, Reactor CoolantSystem Leak.
ATC2. If Pressurizer Pressure is dropping and any of the following haveoccurred, then place Pressurizer Spray Controller (RC-IHIC-0100) to MANand adjust output to 0%: Pressurizer Pressure Channel X/Y recorder (RC-IPR-0100)indicates in-service Pressurizer Pressure Control Channelinstrument has failed high Pressurizer Pressure controller (RC-IPIC-0100) output has failedhigh Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #5 Page 20 of 30Event
 
== Description:==
Pressurizer Pressure Control Channel RC-IPR-0100X fails HiTimePositionApplicant's Actions or Behavior Any Pressurizer Spray Valve (RC-301A or RC-301B) has failed open Pressurizer Spray Controller (RC-IHIC-0100) output has failedhigh.N/A2.1 If any Pressurizer spray valve remains failed open, then PlacePressurizer Spray Valves selector switch to select operable Spray Valve.
CRS3. IF PRESSURIZER PRESSURE CHANNEL X/Y recorder (RC-IPR-0100)indicates a Pressurizer Pressure Control Channel instrument has failed,THEN GO TO Subsection E1, Pressurizer Pressure Control ChannelInstrument Failure.OP-901-510 Subsection E1, Pressurizer Pressure Control Channel Instrument Failure.
ATC1. Verify control channel instrument failure by checking PRESSURIZERPRESSURE CHANNEL X/Y recorder (RC-IPR-0100).
ATC2. Transfer Pressurizer pressure control to operable channel usingPressurizer Pressure Channel Selector control switch.(note)Position Y should be selected.
ATC3. IF Pressurizer Pressure control channel is failed high, THEN perform thefollowing:a. Transfer Pressurizer Lo Level Heater Cutout selector switch to theOperable Pressurizer Pressure control channel.b. Reset Proportional Heater Banks #1 & #2.c. Place Pressurizer Spray Controller (RC-IHIC-0100) to AUTO.
ATC4. Verify proper operation of Pressurizer Pressure controller (RC-IPIC-0100)AND Pressurizer Pressure controlling OR being restored to 2250 PSIA.
CRSRefer to the following Technical Specifications and Technical Requirements: TS 3.2.8 TS 3.4.3.1 TRM 3.4.3.1 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #5 Page 21 of 30Event
 
== Description:==
Pressurizer Pressure Control Channel RC-IPR-0100X fails HiTimePositionApplicant's Actions or Behavior(note)Pressure should drop below 2125 PSIA. Pressure will recover to>2125 PSIA after Channel Y is selected and Pressurizer Heaters areenergized.TS 3.2.8 entry required if RCS pressure drops below 2125 PSIA, butthe Tech Spec is only applicable in Mode 1. Power may still be <5%at this point.Examiner NoteThis event is complete when Pressurizer Pressure Control has been transferred to Channel Y.
OrAs directed by the Lead Evaluator.Examiner NoteCue the Simulator Operator when ready for Event 5.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #6&7 Page 22 of 30Event
 
== Description:==
Main Steam line break outside Containment (SG 1); FW-184A fails to AUTOclose on MSISTimePositionApplicant's Actions or Behavior ATCRecognize and report indications of failed pressure instrument.Alarms EXCORE /CPC CHNL D POWER DEVIATION (Cabinet K, K-14) EXCORE /CPC CHNL B POWER DEVIATION (Cabinet K, K-12) EXCORE /CPC CHNL C POWER DEVIATION (Cabinet K, K-13) EXCORE /CPC CHNL A POWER DEVIATION (Cabinet K, K-11) LOCAL POWER DENSITY HI PRETRIP B/D (Cabinet K, C-11)Indications Lowering Steam Generator Pressure CP-1, CP-8 Lowering Steam Generator Level CP-1, CP-8 Lowering RCS temperatures Tavg, Th, Tc CP-2, CP-7 Reactor Power Rising CP-2, CP-7 SRODirects a manual reactor trip.(note)The SRO may also direct a manual actuation of SIAS and CIAS. If notthe SRO should direct Emergency Boration per OP-901-103,Emergency Boration due to the uncontrolled cooldown. The followingsteps are applicable after the reactor is tripped and the crew isperforming Standard Post Trip Actions.Emergency Boration steps:
ATC1. If Charging is available, then perform the following:
ATC1.1 Place Makeup Mode selector switch to MANUAL.
ATC1.2 Align borated water source by performing one of the following (a or b):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: BAM-126A Boric Acid Makeup Pump RecircValve A or BAM-126B Boric Acid Makeup Pump RecircValve B OR Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #6&7 Page 23 of 30Event
 
== Description:==
Main Steam line break outside Containment (SG 1); FW-184A fails to AUTOclose on MSISTimePositionApplicant's Actions or Behaviorb. Initiate Emergency Boration using Gravity Feed as follows: Open the following Boric Acid Makeup Gravity Feedvalves: BAM-113A Boric Acid Makeup Gravity FeedValve A BAM-113B Boric Acid Makeup Gravity FeedValve B ATC1.3 Close VCT Disch Valve, CVC-183.
ATC1.4 Verify at least one Charging Pump operating and Charging Header flowgreater than or equal to 40 GPM.OP-902-000, Standard Post Trip Actions (STPAs)
ATC1. DetermineReactivity Control acceptance criteria are met:a. Check reactor power is dropping.b. Check startup rate is negative.c. Check less thanTWOCEAs are NOTfully inserted.
BOP2. DetermineMaintenance of Vital Auxiliariesacceptance criteria aremet:a. Check the Main Turbine is tripped: Governor valves closed Throttle valves closed BOPb. Check the Main Generator is tripped: GENERATOR BREAKER A tripped GENERATOR BREAKER B tripped EXCITER FIELD BREAKER tripped Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #6&7 Page 24 of 30Event
 
== Description:==
Main Steam line break outside Containment (SG 1); FW-184A fails to AUTOclose on MSISTimePositionApplicant's Actions or Behavior BOPc. Check station loads are energized from offsite electrical power asfollows: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 ChannelTrain 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 ATC3. DetermineRCS Inventory Control acceptance criteria are met:a. Check thatBOTH the following conditions exist: Pressurizer level is 7% to 60% Pressurizer level is trending to 33% to 60%b. Check RCS subcooling is greater than or equal to 28&#xba;F.(note)This safety function may or may not be met, depending on the speedthe crew is working Standard Post Trip Actions. Either way, there areno contingencies necessary for this step.
ATC4. DetermineRCS Pressure Control acceptance criteria are met bychecking thatBOTH of the following conditions exist: Pressurizer pressure is 1750 psia to 2300 psia Pressurizer pressure is trending to 2125 psia to 2275 psiaExaminer NotePressurizer pressure will eventually lower below the 2 thresholds (1684; 1621 PSIA) after thePressurizer empties.SRO/ATC4.2 IF pressurizer pressure is less than 1684 psia,THEN verify thefollowing have initiated.IAS ATCIf directed by SRO, initiate Safety Injection Actuation (SIAS), Main SteamIsolation (MSIS) and Containment Isolation Actuation (CIAS) at CP-7.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #6&7 Page 25 of 30Event
 
== Description:==
Main Steam line break outside Containment (SG 1); FW-184A fails to AUTOclose on MSISTimePositionApplicant's Actions or Behavior ATC4.3 IFpressurizer pressure is less than 1621 psia,THENverify no morethan two RCPs are operating ATC4.4 IFpressurizer pressure is less than the minimum RCP NPSH ofAppendix 2-A, "RCS Pressure and Temperature Limits",THENstopALL RCPs.Examiner NoteAppendix 2-A is contained on the next page. Conditions should allow for 2 RCPs to remainrunning.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #6&7 Page 26 of 30Event
 
== Description:==
Main Steam line break outside Containment (SG 1); FW-184A fails to AUTOclose on MSISTimePositionApplicant's Actions or Behavior ATC5. DetermineCore Heat Removal acceptance criteria are met:a. Check at least one RCP is operating.b. Check operating loop T is less than 13&#xba;F.c. Check RCS subcooling is greater than or equal to 28&#xba;F.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #6&7 Page 27 of 30Event
 
== Description:==
Main Steam line break outside Containment (SG 1); FW-184A fails to AUTOclose on MSISTimePositionApplicant's Actions or Behavior BOP6. DetermineRCS Heat Removal acceptance criteria are met:a. Check that at least one steam generator hasBOTH of the following: Steam generator level is 10% to 76% NR Main Feedwater is available to restore level within 55%-70%
NR. [60-80% NR]
.BOPa2. Verify Emergency Feedwater is available to restore level in at leastone steam generator within 55%-70% NR[60-80% NR]
.(note)Main Feedwater will not be available. BOP should perform contingencyaction a2.
ATCb. Check RCS TC is 530 &#xba;F to 550 &#xba;F SRO b2.IFRCS TC is less than 530 &#xba;F,THENperform the following: IFRCS TC is being controlled by an ESD, THENREFER TOAppendix 13, "Stabilize RCS Temperature" and stabilize RCStemperature using the least affected steam generator.(note)Appendix 13 directs steps to address PTS after Representative CETtemperature and Pressurizer pressure have both started to rise. Thesteps are also contained in the excess steam demand recoveryprocedure.
BOPc. Check steam generator pressure is 885 psia to 1040 psia.
BOP c1.IFsteam generator pressure is less than 885 psia,THENperformALLof the following:1) Verify steam bypass valves are closed.2) Verify ADVs are closed.
c2.IFsteam generator pressure is less than or equal to 666 psia,THENverify MSIS is initiated.(note)When MSIS has initiated the BOP should verify that both MSIVs andboth MFIVs, FW-184 A(B) close. FW-184A does not close automaticallyrequiring BOP action to close FW-184A.
BOPd. 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 Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #6&7 Page 28 of 30Event
 
== Description:==
Main Steam line break outside Containment (SG 1); FW-184A fails to AUTOclose on MSISTimePositionApplicant's Actions or Behavior(note)With a MSIS, MAIN FW REG valves and STARTUP FW REG valves willbe closed. Both MFW Pumps will be coasting down.
BOPe. Reset moisture separator reheaters, and check the temperaturecontrol valves closed.
ATC7. DetermineContainment Isolation acceptance criteria are met:a. Check containment pressure is less than 16.4 psia.b. Check NO containment area radiation monitor alarms ORunexplained rise in activity.c. Check NO steam plant activity monitor alarms OR unexplained risein activity.ATC/BOP8 DetermineContainment Temperature and Pressure Controlacceptance criteria are met:a. Check containment temperature is less than or equal to 120&#xba;F.b. Check containment pressure is less than 16.4 psia.N/A 9.IF ALLsafety function acceptance criteria are met,AND NOcontingency actions were performed,THENGO TO OP-902-001,"Reactor Trip Recovery" procedure.
SRO 10. IF ANYsafety function acceptance criteria are NOTmet,OR ANYcontingency action was taken,THENGO TO Appendix 1, "DiagnosticFlowchart.OP-902-009, Standard Appendices, Appendix 1 Diagnostic Flow ChartExaminer NoteAppendix 1 is a flow chart used to diagnose to the correct recovery procedure for the event inprogress. The steps below will be followed by a YES or NO to indicate proper flow path.
ATCRx Pwr dropping, SUR negative, and < two CEAs NOT fully inserted orEmergency Boration in progress (YES)ATCPressurizer pressure dropping rapidly and Pressurizer level changing (YES)BOPSteam Generator Pressure Abnormally Low (YES)ATCActivity in the Steam Plant (NO)
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #6&7 Page 29 of 30Event
 
== Description:==
Main Steam line break outside Containment (SG 1); FW-184A fails to AUTOclose on MSISTimePositionApplicant's Actions or BehaviorN/ASecondary  Break ATCContainment Pressure and Temperature Abnormally High (NO)N/ASecondary  Break Outside Containment ATCActivity in Containment (NO)BOPAt least one 4KV safety bus energized (YES)SROGo To OP-902-004, Excess Steam Demand Recovery SROAfter Excess Steam Demand is identified, direct ATC and BOP to monitorfor the trigger points for the need to stabilize Reactor Coolant Systemtemperature.Critical parameters are Pressurizer pressure rising and Reactor CoolantSystem Representative CET temperature rising.Steps for stabilizing Reactor Coolant System temperature following anexcess steam demand are contained in 2 procedures. Appendix 13 is used if the critical parameters are both rising before theSRO has entered OP-902-004, Excess Steam Demand Recovery. Step 16 of OP-902-004 is used if both parameters start rising after thecrew has entered OP-902-004.CRITICAL TASKESTABLISH REACTOR COOLANT SYSTEM TEMPERATURE CONTROLThis task is satisfied by taking action to stabilize Reactor Coolant System temperature withinthe limits of the Reactor Coolant System Pressure/Temperature Limits curve usingAtmospheric Dump Valve 2 and establishing EFW flow to Steam Generator 2 prior to lifting aPressurizer safety (2500 psia) or Steam Generator safety (1070 psig). This task becomesapplicable once CET temperature and PZR pressure begin to rise following the Main Steam Line Break.BOPWhen directed by the SRO to take action to stabilize Reactor CoolantSystem temperature: Place the Atmospheric Dump Valve for Steam Generator 2 to manualand fully open Atmospheric Dump Valve 2.
Appendix DRequired Operator ActionsForm ES-D-2Op Test No.: NRC Scenario #
3Event #6&7 Page 30 of 30Event
 
== Description:==
Main Steam line break outside Containment (SG 1); FW-184A fails to AUTOclose on MSISTimePositionApplicant's Actions or Behavior Manually initiate Emergency Feedwater Actuation Signal for SteamGenerator 2. Place Emergency Feedwater Flow Control Valve to manual andcommence feeding Steam Generator 2.CRITICAL TASKESTABLISH REACTOR COOLANT SYSTEM PRESSURE CONTROLThis task is satisfied by taking actions to stabilize RCS pressure within the limits of the ReactorCoolant System P/T curve and actions are taken to maintain Reactor Coolant System pressurewithin 1500-1600 psid of the faulted steam generator. Action to address this task shouldcommence prior to RCS pressure exceeding 2500 PSIA. This task becomes applicable onceCET temperature and PZR pressure begin to rise following the Main Steam Line Break.
ATCWhen directed by the SRO to take action to stabilize Reactor CoolantSystem pressure: IFReactor Coolant System pressure is  1500 psia,THENstabilizeReactor Coolant System pressure at a value not to exceed 1600 psidbetween the Reactor Coolant System and the lowest SG pressure. IFReactor Coolant System pressure is < 1500 psia,THENstabilizeReactor Coolant System pressure at > HPSI shutoff head (1500-1600psia).Examiner NoteThis scenario is complete after Reactor Coolant System temperature and pressure have beenstabilized ORAs directed by the Lead Evaluator.
ES-301 Administrative Topics Outline Form ES-30 1-1  2015 NRC Revision 0 Facility: Waterford 3 Date of Examination:
9/14/2015  Examination Level:
RO  SRO  Operating Test Number:
1  Administrative Topic (see Note) Type Code* Describe activity to be performed A1 Conduct of Operations K/A Importance:
3.9 N , R 2.1.25, Ability to interpret reference materials, such as graphs, curves, tables, etc.
Determine Spent Fuel Pool (SFP) level by alternate monitoring and calculate time to boil in the SFP per OP
-901-513, SFP Cooling Malfunction.
A2 Conduct of Operations K/A Importance:
3.6 D , R 2.1.18, Ability to make accurate, clear, and concise logs, records, status boards, and reports.
Perform OP
-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data
. A3 Equipment Control K/A Importance:
3.7 P ,D,R 2.2.12, Knowledge of surveillance procedures
. Determine Acceptability of Containment Temperature in accordance with OP
-903-001, Technical Specification Surveillance Logs, Attachmen t s 11.1 and 11.20. (From 201 2 NRC Exam) A4 Radiation Control K/A Importance:
3.2 D , R 2.3.4 , Knowledge of radiation exposure limits under normal and emergency conditions
. Calculate stay time to perform a tagout verification. Room dose rate and operator's yearly dose provided Emergency Plan Not Selected NOTE: All items (five total) are required for SROs. RO applicants require only four items unless they are retaking only the administrative topics (which would require all five items)
.
* Type Codes &
Criteria: (C)ontrol room, (S)imulator, or Class(R)oom (D)irect from (N)ew or (M)odified from
 
ES-301 Administrative Topics Outline Form ES-301-1  2015 NRC Revision 0 Facility: Waterford 3 Date of Examination:
9/14/2015  Examination Level:
RO  SRO  Operating Test Number:
1  Administrative Topic (see Note) Type Code* Describe activity to be performed A5 Conduct of Operations K/A Importance:
4.6 D,R 2.1.20, Ability to interpret and execute procedure steps
. Perform SM/CRS review of OP
-901-501, PMC or Core Operating Limit Supervisory System Malfunction, Attachments 1, 2 and 3 following a PMC failure.
A6 Conduct of Operations K/A Importance
: 3.8 D,R 2.1.1 8, Ability to make accurate, clear, and concise logs, records, status boards, and reports.
Review and approve OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data.
A7 Equipment Control K/A Importance:
4.1 P , D , R 2.2.12, Knowledge of Surveillance Procedures Review a completed Containment Pressure calculation in accordance with OP
-903-001, Technical Specification Surveillance Logs, Attachment 11.5, Containment Pressure Calculation.
(From 2012 NRC Exam)
A8 Radiation Control K/A Importance:
3.7 M ,R 2.3.4, Knowledge of radiation exposure limits under normal or emergency conditions.
Authorize Emergency Exposure as the Emergency Director in accordance with EP
-002-030, Emergency Radiation Exposure Guidelines and Controls.
A9 Emergency Plan K/A Importance:
4.6 N ,R 2.4.41, Knowledge of the emergency action level thresholds and classifications.
Determine appropriate Emergency Plan EAL.
NOTE: All items (five total) are required for SROs. RO applicants require only four items unless they are retaking only the administrative topics (which would require all five items)
.
* Type Codes & Criteria:
(C)ontrol room, (S)imulator, or Class(R)oom (D)irect from (N)ew or (M)odified from
 
ES-301 Control Room/In
-Plant Systems Outline Form ES-301-2  1 2015 NRC Revision 1 Facility: Waterford 3 Date of Examination:
9/14/2015  Exam Level RO  SRO-I  SRO-U  Operating Test No.:
1      Control Room Systems
* 8 for RO; 7 for SRO-I; 2 or 3 for SRO
-U  System / JPM Title Type Code* Safety Function S1 001 Control Rod Drive; ATC Operator Immediate Operator Actions on 2 Dropped CEAs from OP
-901-102, CEA or CEDMCS Malfunction Fault: The first and second reactor trip options do not function, requires performance of the final reactor trip contingency from EOP OP-902-000, Standard Post Trip Actions.
A2.13 ATWS    RO
- 4.4, SRO - 4.6 A, D, S 1 S2 00 4 Chemical and Volume Control System, Align Charging Pu mps to discharge through HPSI Header A in accordance with OP-902-009 Appendix 30, Charging to the RCS via the HPSI Header A4.0 8 , Charging  RO - 3.8, SRO - 3.4 N ,S 2 S3 005 Shutdown Cooling System; Place Shutdown Cooling Train A in Service Fault: After LPSI Pump A is running, SI
-405A will fail closed, requiring the operator to take immediate operator actions IAW OP
-90 1-13 1 , Shutdown Cooling Malfunction, to secure LPSI Pump A. (Repeat from 2012 NRC Exam)
A4.01 Controls and indication for RHR pumps RO - 3.6, SRO - 3.4 A,D,L, P, S 4 P S 4 039 Main and Reheat Steam System; BOP operator immediate operator actions on evacuation of the Control Room in accordance with OP-901-502, Control Room Evacuation Fault: Atmospheric Dump Valve B will spuriously open, requiring the applicant to take contingency actions to control Steam Generator pressure. A4.01 Main steam supply. Valves RO - 2.9, SRO - 2.8  A, D ,S 4 S S5 026 Containment Spray System Reset CSAS in accordance with OP
-902-009, Standard Appendices, Section 5
- E  (Repeat from 2014 NRC Exam
) A4.01 CSS Controls      RO - 4.5, SRO - 4.3 D,EN,P,L, S 5 S 6 064 Emergency Diesel Generators Restore Power to Safety Bus 3B in accordance with OP
-902-000, Standard Post Trip Actions.
Fault: EDG B voltage is low out of the band preventing auto closure of the EDG B output breaker.  (WF3 OE) A4.0 2 Adjustment of exciter voltage (using voltage control switch)
RO - 3.3, SRO - 3.4 A,M, S 6 ES-301 Control Room/In
-Plant Systems Outline Form ES-301-2  2 2015 NRC Revision 1 S 7 015 Nuclear Instrumentation System Perform Range Check functional test of startup Channels in accordance with OP
-903-101, Startup Channel Functional Test 015 A3.03, Verification of proper functioning/operability RO - 3.9, SRO - 3.9 L, D ,S 7 S8 034 Fuel Handling Equipment Place the FHB Emergency Filtration Unit in service in accordance with OP-002-009, Fuel Handling Building HVAC A4.01 Radiation levels  RO - 3.3, SRO - 3.7 N, S 8  In-Plant Systems
* (3 for RO); (3 for SRO-I); (3 or 2 for SRO
-U) P1 04 5 Main Turbine Generator System Start an Air Side Seal Oil Pump following a loss of single train of offsite power per OP
-902-009 Attachment 33
-C. G2.4.6 Knowledge of EOP mitigation strategies RO - 3.7, SRO - 4.7 N , E , L 4 S P2 064 Emergency Diesel Generator (ED/G) System; Trip Emergency Diesel Generator B locally.
Fault: The first method the applicant performs to trip the EDG B will fail, requiring contingency actions to secure EDG B.
K4.02 Trips for ED/G while operating (normal or emergency)
RO - 3.9, SRO - 4.2 A,D, R 6 P3 008 Component Cooling Water System; Restore Power to the DCT Sump Pumps Following a Loss of Off Site Power in accordance with OP
-902-009, Standard Appendices G2.4.34 Knowledge of RO tasks performed outside the main control room during an emergency and the resultant operational effects.
RO - 4.2, SRO - 4.1 D,R,E ,L 8
* All RO and SRO
-I control room (and in
-plant) systems must be different and serve different safety functions; all five SRO-U systems must serve different safety functions; in
-plant systems and functions may overlap those tested in the control room.
* Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 5 (C)ontrol room 0 (D)irect from bank  9 /  8 /  4 7 (E)mergency or abnormal in
-plant  1 /  1 /  1 2 (EN)gineered safety feature
  /  1 (L)ow-Power / Shutdown 1 /  1 /  1 5 (N)ew or (M)odified from bank including 1(A) 2 /  2 /  1 4 (P)revious 2 exams 3 /  3 /  2 (randomly selected) 2 (R)CA  1 /  1 /  1 2 (S)imulator 8
ES-301 Control Room/In
-Plant Systems Outline Form ES-301-2  3 2015 NRC Revision 1 Facility: Waterford 3 Date of Examination:
9/14/2015  Exam Level RO  SRO-I  SRO-U  Operating Test No.:
1      Control Room Systems
:
* 8 for RO; 7 for SRO
-I; 2 or 3 for SRO
-U System / JPM Title Type Code* Safety Function S1 001 Control Rod Drive; ATC Operator Immediate Operator Actions on 2 Dropped CEAs from OP
-901-102, CEA or CEDMCS Malfunction Fault: The first and second reactor trip options do not function, requires performance of the final reactor trip contingency from EOP OP
-902-000, Standard Post Trip Actions.
A2.13 ATWS    RO
- 4.4, SRO - 4.6 A,D,S 1 S2    S3    S4    S5 026 Containment Spray System Reset CSAS in accordance with OP
-902-009, Standard Appendices, Section 5
- E  (Repeat from 2014 NRC Exam) A4.01 CSS Controls RO - 4.5, SRO - 4.3 D,EN,P,L, S 5 S6 064 Emergency Diesel Generators Restore Power to Safety Bus 3B in accordance with OP
-902-000, Standard Post Trip Actions.
Fault: EDG B voltage is low out of the band preventing auto closure of the EDG B output breaker.  (WF3 OE) A4.02 Adjustment of exciter voltage (using voltage control switch)
RO - 3.3, SRO - 3.4 A,M,S 6 S7. S8.
ES-301 Control Room/In
-Plant Systems Outline Form ES-301-2  4 2015 NRC Revision 1 In-Plant Systems
* (3 for RO);(3 for SRO-I); (3 or 2 for SRO
-U) P1 045 Main Turbine Generator System Start an Air Side Seal Oil Pump following a loss of single train of offsite power per OP
-902-009 Attachment 33
-C. G2.4.6 Knowledge of EOP mitigation strategies RO - 3.7, SRO - 4.7 N, E , L 4S P2    P3 008 Component Cooling Water System; Restore Power to the DCT Sump Pumps Following a Loss of Off Site Power in accordance with OP
-902-009, Standard Appendices G2.4.34 Knowledge of RO tasks performed outside the main control room during an emergency and the resultant operational effects.
RO - 4.2, SRO - 4.1 D,R,E,L 8
* All RO and SRO
-I control room (and in
-plant) systems must be different and serve different safety functions; all five SRO-U systems must serve different safety functions; in
-plant systems and functions may overlap those tested in the control room.
* Type Codes Criteria for RO / SRO
-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 2 (C)ontrol room 0 (D)irect from bank 9 /  8 /  4 3 (E)mergency or abnormal in
-plant  1 /  1 /  1 2 (EN)gineered safety feature
  /  1 (L)ow-Power / Shutdown 1 /  1 /  1 3 (N)ew or (M)odified from bank including 1(A) 2 /  2 /  1 2 (P)revious 2 exams 3 /  3 /  2 (randomly selected) 1 (R)CA  1 /  1 /  1 1 (S)imulator 3}}

Latest revision as of 09:30, 10 January 2025

2015-09 Draft Operating Test and Revised Outlines
ML15225A564
Person / Time
Site: Waterford Entergy icon.png
Issue date: 09/14/2015
From: Vincent Gaddy
Operations Branch IV
To:
Entergy Operations
References
Download: ML15225A564 (449)
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