ML20233A922
ML20233A922 | |
Person / Time | |
---|---|
Site: | Arkansas Nuclear ![]() |
Issue date: | 06/05/2020 |
From: | Greg Werner Operations Branch IV |
To: | Entergy Operations |
References | |
ES-301-1 | |
Download: ML20233A922 (402) | |
Text
ES-301 Administrative Topics Outline Form ES-301-1 Facility: ANO Unit 1 Date of Examination: 3/30/2020 Examination Level: RO SRO Operating Test Number: 1 Administrative Topic (see Note) Type Describe activity to be performed Code*
A1 Calculate Minimum Required Boron to Maintain Conduct of Operations R,D Shutdown Margin K/A - 2.1.43, Importance Rating 4.1 A1JPM-RO-RBAL3 A2 Perform Time to Boil / Core Uncovery Conduct of Operations R,M Estimation K/A - 2.1.25, Importance Rating 3.9 A1JPM-RO-TTB A3 Perform Service Water Surveillance Equipment Control R,N A1JPM-RO-SURV3 K/A - 2.2.12, Importance Rating 3.7 A4 Ability to comply with Radiation Work Permit Radiation Control R,D,P requirements K/A - 2.3.7, Importance Rating 3.5 A1JPM-RO-ADMIN-RWP3 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 and Criteria: (C)ontrol room, (S)imulator, or Class(R)oom (D)irect from bank ( 3 for ROs; 4 for SROs and RO retakes)
(N)ew or (M)odified from bank ( 1)
(P)revious 2 exams ( 1, randomly selected)
ES-301 Administrative Topics Outline Form ES-301-1 Facility: ANO Unit 1 Date of Examination: 3/30/2020 Examination Level: RO SRO Operating Test Number: 1 Administrative Topic (see Note) Type Describe activity to be performed Code*
A5 Review Calculated Minimum Required Boron to Conduct of Operations R,D Maintain Shutdown Margin K/A - 2.1.43, Importance Rating 4.3 A1JPM-SRO-RBAL3 A6 Review Time to Boil / Core Uncovery Estimation Conduct of Operations R,M A1JPM-SRO-TTB K/A - 2.1.25, Importance Rating 4.2 A7 Determine Operability of SW and Apply T.S.
Equipment Control R,N A1JPM-SRO-ADMINSW K/A - 2.2.37, Importance Rating 4.6 A8 Ability to comply with Radiation Work Permit Radiation Control R,D requirements K/A - 2.3.7, Importance Rating 3.6 A1JPM- SRO-ADMIN-RWP3 A9 Classify an Emergency Event Emergency Plan R,N A1JPM-SRO-EAL18 K/A - 2.4.41, Importance Rating 4.6 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 and Criteria: (C)ontrol room, (S)imulator, or Class(R)oom (D)irect from bank ( 3 for ROs; 4 for SROs and RO retakes)
(N)ew or (M)odified from bank ( 1)
(P)revious 2 exams ( 1, randomly selected)
ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: ANO Unit 1 Date of Examination: 3/30/2020 Exam Level: RO SRO-I SRO-U Operating Test Number: 1 Control Room Systems: 8 for RO, 7 for SRO-I, and 2 or 3 for SRO-U System/JPM Title Type Code* Safety Function S1. Perform RCS Boration BATCH Feed Method D/S 1 004 A4.07 (RO 3.9 / SRO 3.7)
RO S2. Perform actions required for Reactor Building Sump Blockage A/EN/L/N/S 2 006 A2.02 (RO 3.9 / SRO 4.3)
RO / SRO-I / SRO-U S3. Respond to Pressurizer ERV Failure A/L/N/S 3 010 A2.03 (RO 4.1 / SRO 4.2)
RO / SRO-I S4. Initiate Common Feedwater N/L/S 4S E04 EA1.1 (RO 4.4 / SRO 4.2)
RO / SRO-I S5. Place Hydrogen Recombiner M55B in Operation D/L/P/EN/S 5 028 A4.01 (RO 4.0/SRO 4.0)
RO / SRO-I / SRO-U S6. Synchronize and Load #1 EDG with a failure of the load switch A/D/P/S 6 064 A2.05 (RO 3.1 / SRO 3.2)
RO / SRO-I S7. Bypass MSLI L/N/S 7 E02 EA1.1 (RO 4.0 / SRO 3.6)
RO / SRO-I S8. Reactor Building Purge Gaseous Release L/N/S 9 071 A1.06 (RO 2.5 / SRO 2.8)
RO / SRO-I
ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 In-Plant Systems:* 3 for RO, 3 for SRO-I, and 3 or 2 for SRO-U A/D/L P1. Perform ICS Startup 4S 041 A4.01 (RO 2.9 / SRO 3.1)
RO / SRO-I / SRO-U A/D/E P2. Manual Actuation of Halon System #3 8 086 A4.06 (RO 3.2 / SRO 3.2)
RO / SRO-I / SRO-U L/N/R P3. Perform Decay Heat System Auxiliary Spray Alignment prior to 3 Sump Recirculation 006 A4.05 (RO 3.9 / SRO 3.8)
RO / SRO-I / SRO-U
- 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, and in-plant systems and functions may overlap those tested in the control room.
- Type Codes Criteria for R /SRO-I/SRO-U (A)lternate path 5/5 /3 (C)ontrol room (D)irect from bank 5/4/3 (E)mergency or abnormal in-plant 1/1/1 (EN)gineered safety feature 2 / 2 / 2 (control room system)
(L)ow-Power/Shutdown 8/8/3 (N)ew or (M)odified from bank including 1(A) 6/6/3 (P)revious 2 exams 2 / 2 / 1 (randomly selected)
(R)CA 1/1/1 (S)imulator
ADMINISTRATIVE JOB PERFORMANCE MEASURE A1JPM-RO-RBAL3 Page 1 of 6 UNIT: 1 REV # 1 DATE: ______________________________
TUOI NUMBER: A1JPM-RO-RBAL3 SYSTEM/DUTY AREA: ADMINISTRATIVE TOPIC - CONDUCT OF OPERATIONS TASK: ESTIMATE BORON CONCENTRATION REQUIRED TO MAINTAIN SHUTDOWN MARGIN DURING COOLDOWN USING RHOBAL PROGRAM JTA#: ANO1-RO-OPROC-NORM-70 KA VALUE RO: 4.1 SRO: 4.3 KA
REFERENCE:
2.1.43 APPROVED FOR ADMINISTRATION TO: RO: x SRO:
TASK LOCATION: INSIDE CR: OUTSIDE CR:_________ BOTH:____X____
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE:_______________ SIMULATOR: CLASS ROOM:__PERFORM___
POSITION EVALUATED: RO:___X ___ SRO:___________
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE:____ CLASS ROOM:__X___
TESTING METHOD: SIMULATE:_________ PERFORM:___X______
APPROXIMATE COMPLETION TIME IN MINUTES: 10 MINUTES REFERENCE(S): 1103.015, Rev. 061 and Rhobal computer program EXAMINEE'S NAME:________________________________ LOGON ID ____________________
EVALUATOR'S NAME:__________________________________________________________________
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY:________________ UNSATISFACTORY:_________________
PERFORMANCE CHECKLIST COMMENTS:
____________ Start Time ____________ Stop Time ____________ Total Time SIGNED _Robert Possage_______________________________ DATE: _______________________
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
ADMINISTRATIVE JOB PERFORMANCE MEASURE A1JPM-RO-RBAL3 Page 2 of 6 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS: The plant is preparing for shutdown prior to a refueling outage. EFPD = 475. RCS Tave = 555°F. APSR at 0%. Desired final RCS Tave = 185°F Cooldown is scheduled to commence later today.
TASK STANDARD: The examinee has calculated the minimum required Boron concentration to maintain shutdown margin during cooldown using RHOBAL and determined the value to be between 615 to 645 ppm.
TASK PERFORMANCE AIDS: Personal computer with RHOBAL program available.
ADMINISTRATIVE JOB PERFORMANCE MEASURE A1JPM-RO-RBAL3 Page 3 of 6 INITIATING CUE:
The Control Room Supervisor directs you to calculate the Minimum Required Boron concentration to maintain shutdown margin during cooldown using 1103.015, Reactivity Balance Calculation and the RHOBAL program.
(C) PERFORMANCE CHECKLIST STANDARD SAT UNSAT N/A NOTE: Examinee may start in the Poison menu or in the Shutdown Margin menu.
Either way, the examinee must establish a power history.
(C) 1. Activate Shutdown Margin Clicked (or Alt S via keyboard) on pull down menu. on Shutdown Margin in menu ____ ____ ___
bar. _
(C) 2. Run program to determine Performed the following Boron concentration required actions: ____ ____ ___
to maintain shutdown margin.
- Clicked on Worksheet 5, _
"Boron Concentration Required to Maintain SDM during Cooldown or Heatup.
- Entered 475 for Cycle Burnup in EFPD.
- Entered 0 for all CRA positions.
- Entered 555 for RCS Average Temperature in degrees F.
- Entered 185 for Final Desired RCS Average Temperature in degrees F.
NOTE: Step 3 may be performed prior to step 1 via the Poison menu.
ADMINISTRATIVE JOB PERFORMANCE MEASURE A1JPM-RO-RBAL3 Page 4 of 6 (C) PERFORMANCE CHECKLIST STANDARD SAT UNSAT N/A
- 3. Activate Xenon and Clicked (or Alt P via keyboard)
Samarium menu. on Xenon and Samarium in ____ ____ ___
menu bar. _
(C) 4. Enter power history. Performed the following actions: ____ ____ ___
- Entered 100% Power _
Level
- Entered 475 for Burnup
- Clicked on At power equilibrium concentrations.
- Clicked on INITIALIZE POISONS button.
(C) 5. Determine required Boron Noted the required Boron conc concentration. from Table or Figure B6 to be ____ ____ ___
631. _
Accept 615 to 645.
END
ADMINISTRATIVE JOB PERFORMANCE MEASURE A1JPM-RO-RBAL3 Page 5 of 6 KEY JPM INITIAL TASK CONDITIONS:
- The plant is preparing for startup after a refueling outage.
- EFPD = 475
- RCS Tave = 555°F
- Final RCS Tave = 185°F
- APSR are at 0 %
- Cooldown is scheduled to commence later today.
INITIATING CUE:
The SM/CRS directs you to calculate Minimum Required Boron concentration to maintain shutdown margin during heatup using 1103.015, Reactivity Balance Calculation and the RHOBAL program.
____631 (615 - 645)___ ppmB
ADMINISTRATIVE JOB PERFORMANCE MEASURE A1JPM-RO-RBAL3 Page 6 of 6 EXAMINEES COPY JPM INITIAL TASK CONDITIONS:
- The plant is preparing for startup after a refueling outage.
- EFPD = 475
- RCS Tave = 555°F
- Final RCS Tave = 185°F
- APSR are at 0 %
- Cooldown is scheduled to commence later today.
INITIATING CUE:
The SM/CRS directs you to calculate Minimum Required Boron concentration to maintain shutdown margin during heatup using 1103.015, Reactivity Balance Calculation and the RHOBAL program.
__________________________ ppmB
A1JPM-RO-TTB PAGE 1 OF 10 UNIT: 1 REV #: 2 DATE:
SYSTEM/DUTY AREA: Conduct of Operations TASK: Perform Time to Boil and Time to Core Uncovery Calculations JTA#: ANO1-RO-DHR-NORM-204 KA VALUE RO: 3.9 SRO: 4.2 KA
REFERENCE:
2.1.25 APPROVED FOR ADMINISTRATION TO: RO: X SRO:
TASK LOCATION: INSIDE CR: OUTSIDE CR: X BOTH:
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: Classroom: Perform POSITION EVALUATED: RO: X SRO:
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: Classroom: X TESTING METHOD: SIMULATE: PERFORM: X APPROXIMATE COMPLETION TIME IN MINUTES: 20 Minutes REFERENCE(S): 1015.002 EXAMINEE'S NAME: Logon EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Stop Total Time Time Time SIGNED: Robert Possage DATE:
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
A1JPM-RO-TTB PAGE 2 OF 10 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS:
Plant shutdown for refueling.
RCS level is being drained to 376 in preparation for Reactor head removal.
Time after shutdown = 65 hours7.523148e-4 days <br />0.0181 hours <br />1.074735e-4 weeks <br />2.47325e-5 months <br />.
Both OTSG primary manways are removed.
Nozzle dams are NOT installed.
RCS Temperature is 120°F.
Plant computer is inoperable due to power supply maintenance.
TASK STANDARD:
Calculated the following:
- 1) In step 2.2, used Figure 1 and determined Decay Heat Correction Factor to be 1.28 - 1.32 (1.3 +/- 0.2)
- 2) In step 3.2, used Figure 2A and determined Time to Boil is 28.8 - 31.0 minutes (29.9 +/- 1.1)
- 3) In step 4.2, used Figure 4A and determined time to core uncovery is 268.6 - 290.4 minutes (279.5 +/- 10.9)
- 3) In step 5.2, determined estimated heatup rate to be 2.84 - 3.32 °F/minute (3.08 +/- 0.24)
- 4) In step 6.0, determined makeup rate to be 65 to 70 gpm. (Graph readability - 68 actual value)
TASK PERFORMANCE AIDS:
1015.002, Decay Heat Removal and LTOP System Control 1015.002B, Calculation of Time to Boil/Core Uncovery Estimate SIMULATOR SETUP:
NA EXAMINER'S NOTES:
A1JPM-RO-TTB PAGE 3 OF 10 INITIATING CUE:
CRS directs you to perform time to boil and time to core uncovery calculations using 1015.002B, Calculation of Time to Boil/Core Uncovery Estimate, through step 6.0.
(C) PERFORMANCE CHECKLIST STANDARD SAT UNSAT N/A NOTE The figures referred to in this form are the figures of, Graphs Used To Determine RCS Time to Boil/Core Uncovery Estimates, Attachment C of this procedure.
1.0 Record the following data: Examinee recorded the data on the paper copy of 1015.002B, (See key) using the initial conditions given ____ ____ ____
on the Examinee Copy. (See key) 2.0 2.1 Decay Heat Correction Examinee recorded 1.0 in the Factor space provided since refueling ____ ____ ____
has not commenced per the Record fraction of spent fuel initial conditions. (See key) assemblies in core______
(obtain from Reactor Engineering) (1.0 if prior to refueling) 2.2 C Using Figure 1 of Attachment Examinee referred to Figure 1 C, Graphs Used To (Page 54 of 135) and determined ____ ____ ____
Determine RCS Time to based on 65 hours7.523148e-4 days <br />0.0181 hours <br />1.074735e-4 weeks <br />2.47325e-5 months <br /> after Boil/Core Uncovery shutdown (given in initial Estimates, DETERMINE conditions) the Correction Factor Decay Heat Correction should be 1.3.
Factor Band of 1.28 - 1.32 (See key)
NOTE NOTE Examinee read and place kept Step 5.8 in the definitions Note. Examinee determined the section defines the RCS as RCS is opens since the initial ____ ____ ____
OPEN if a Steam Generator conditions stated both OTSG Primary Manway is removed primary manways are removed.
and unobstructed by filter or ventilating devices.
(See key) 3.1 Using the appropriate figure from Attachment C, OBTAIN Examinee referred to Figure 2A uncorrected Time to Boil. (Page 55 of 135) and determined ____ ____ ____
based on 65 hours7.523148e-4 days <br />0.0181 hours <br />1.074735e-4 weeks <br />2.47325e-5 months <br /> after LOG uncorrected Time to shutdown (given in initial Boil: _____________ conditions) the Uncorrected Time to Boil should be 23 minutes.
(See Key)
A1JPM-RO-TTB PAGE 4 OF 10 (C) PERFORMANCE CHECKLIST STANDARD SAT UNSAT N/A 3.2 Multiply by Decay Heat Examinee multiplied 23 value C Correction Factor from step (step 3.1.3) by 1.3 (step 2.2) and ____ ____ ____
2.2: determined time to boil should be 29.9 minutes.
(See key)
(See key) 28.8 - 31.0 minutes (29.9 +/-
1.1) 4.1 Examinee referred to Figure 4A Using the appropriate (Page 59 of 135) and determined figure from Attachment C, based on 65 hours7.523148e-4 days <br />0.0181 hours <br />1.074735e-4 weeks <br />2.47325e-5 months <br /> after ____ ____ ____
OBTAIN uncorrected Time shutdown (given in initial To Core Uncovery: conditions) the Uncorrected Time to Core Uncovery RCS Open, RV Head On should be 215 minutes.
LOG uncorrected Time To (See key)
Core Uncovery: __________
210 - 220 minutes (215 +/- 5)
(See key) 4.2 Multiply by Decay Heat Examinee multiplied 215 minutes C
Correction Factor from step (step 4.1.5) by 1.3 (step 2.2) and ____ ____ ____
2.2: determined time to core (See key) uncovery should be 279.5 minutes (See key) 268.6 - 290.4 minutes (279.5 +/-
10.9) 5.1 Using Figure 6 of Attachment Examinee referred to Figure 6 C, DETERMINE uncorrected and determined the Uncorrected heatup rate ______°F/min. RCS Heatup Rate should be 4.0 o ____ ____ ____
F/min.
5.2 Divide by Decay Correction Examinee divided 4 oF/min (step Factor from step 2.2: 5.1) by 1.3 (step 2.2) and C determined heatup rate to be (See key) ____ ____ ____
3.08 °F/minute.
(See key) 2.84 - 3.32 °F/minute (3.08 +/-
0.24) 6.0 Using Figure 7A or 7B of Examinee referred to Figure 7A Attachment C, RECORD (based on initial conditions giving required makeup rate: time after shutdown in hours) and C _________ gpm ____ ____ ____
determined makeup rate to be 68 gpm.
(See key) 65 to 75 gpm
A1JPM-RO-TTB PAGE 5 OF 10 (C) PERFORMANCE CHECKLIST STANDARD SAT UNSAT N/A END
A1JPM-RO-TTB PAGE 6 OF 10 KEY CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 1 OF 4 1.0 RECORD the following data:
- Time after reactor shutdown ___ 65_____ hours or days (CIRCLE one)
- RCS level ___376___
- RCS Pressure ____0____
o
- RCS temperature __120 f___ (referred to as T1 on Att C figures) 2.0 Decay Heat Correction Factor 2.1 RECORD fraction of spent fuel assemblies in core __ 1.0_____
(fraction of spent fuel assemblies in core is obtained from Reactor Engineering or value of 1.0 is used if prior to refueling) 2.2 Using Figure 1 of Attachment C, Graphs Used To Determine RCS Time to Boil/Core Uncovery Estimates, DETERMINE Decay Heat Correction Factor :
Correction Factor Decay Heat Fraction of Spent Fuel =
Correction Factor Assemblies in Core
(___1.3____) = __1.3_____
( 1.0 )
A1JPM-RO-TTB PAGE 7 OF 10 KEY CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 2 OF 4 NOTE
- Reactor Coolant System open is contained in the Definitions section of this procedure.
- If the status of the RCS (open or intact) is unknown the RCS will be considered open for Time to Boil determination.
3.0 Determining Time to Boil:
3.1 Using the appropriate figure from Attachment C, OBTAIN uncorrected Time to Boil.
3.1.1 IF RCS is open, THEN USE ONE of the following:
- Figure 2A for RCS temp 40°F to 140°F
- Figure 3A for RCS temp 40°F to 140°F
- Figure 3B for RCS temp 140°F to 300°F 3.1.3 LOG uncorrected Time to Boil: ___23______
3.2 MULTIPLY uncorrected Time to Boil by Decay Heat Correction Factor:
Uncorrected Time Decay Heat Time to boil in X =
to Boil in minutes Correction Factor minutes X =
(__23__) (__1.3__) __29.9___
A1JPM-RO-TTB PAGE 8 OF 10 KEY CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 3 OF 4 4.0 Determining Time To Core Uncovery:
4.1 Using the appropriate figure from Attachment C, OBTAIN uncorrected Time To Core Uncovery:
4.1.1 IF Incore Instrument guide tubes are breached AND RV Head is installed, THEN ASSUME a conservative initial RCS level of 369.5' and USE ONE of the following:
- Figure 4A for RCS temp 40°F to 140°F
- Figure 4B for RCS temp 140°F to 200°F 4.1.2 IF RCS is open with nozzle dams removed, THEN USE ONE of the following:
- Figure 4A for RCS temp 40°F to 140°F
- Figure 4B for RCS temp 140°F to 200°F 4.1.3 IF EITHER SG has nozzle dam installed, THEN USE ONE of the following:
- Figure 4C for RCS temp 40°F to 140°F
- Figure 5A for RCS temp 40°F to 140°F
- Figure 5B for RCS temp 140°F to 240°F
- Figure 5C for RCS temp 240°F to 340°F 4.1.5 LOG uncorrected Time To Core Uncovery: ____215______
4.2 MULTIPLY uncorrected Time To Core Uncovery by Decay Heat Correction Factor:
Uncorrected time to Decay Heat Time to Core Core Uncovery in X Correction Factor = Uncovery in minutes minutes
(_215_) X (_1.3__) = _279.5_
A1JPM-RO-TTB PAGE 9 OF 10 KEY CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 4 OF 4 5.0 Determining Time To Core Uncovery:
5.1 Using Figure 6 of Attachment C, DETERMINE uncorrected heatup rate
__4.0____°F/min.
5.2 DIVIDE by Decay Heat Correction Factor:
Uncorrected Heatup Rate Estimated Heatup
=
Decay Heat Correction Factor Rate in °F/min
(____4_______) = ___3.08____
( 1.3 )
6.0 Using Figure 7A or 7B of Attachment C, RECORD required makeup rate: __68____ gpm 7.0 IF Time to Boil is significantly less than previous Time to Boil estimate AND in Mode 5 or 6, THEN REEVALUATE ANY containment closure estimates for ALL outstanding items on the Containment Closure Breach List.
8.0 UPDATE the Status Board with the new data.
Performed by _______________________________ Date __________ Time __________
Calculations Reviewed/
Confirmed by CRS or SM: _______________________ Date __________ Time ________
A1JPM-RO-TTB PAGE 10 OF 10 EXAMINEEES COPY JPM INITIAL TASK CONDITIONS:
Given the following Plant conditions:
- Plant shutdown for refueling.
- RCS level is being drained to 376 in preparation for Reactor head removal.
- Time after shutdown = 65 hours7.523148e-4 days <br />0.0181 hours <br />1.074735e-4 weeks <br />2.47325e-5 months <br />.
- Both OTSG primary manways are removed.
- Nozzle dams are NOT installed.
- RCS Temperature is 120°F.
- Plant computer is inoperable due to power supply maintenance.
INITIATING CUE:
CRS directs you to perform time to boil and time to core uncovery calculations using Form 1015.002B, Calculation of Time to Boil/Core Uncovery Estimate, through step 6.0.
Document the results on the attached 1015.002B form.
1015.002 page 130 of 135 CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 1 OF 4 1.0 RECORD the following data:
Time after reactor shutdown __________ hours or days (CIRCLE one)
RCS level __________
RCS Pressure __________
RCS temperature __________ (referred to as T1 on Att C figures) 2.0 Decay Heat Correction Factor 2.1 RECORD fraction of spent fuel assemblies in core __________
(fraction of spent fuel assemblies in core is obtained from Reactor Engineering or value of 1.0 is used if prior to refueling) 2.2 Using Figure 1 of Attachment C, Graphs Used To Determine RCS Time to Boil/Core Uncovery Estimates, DETERMINE Decay Heat Correction Factor :
Correction Factor Decay Heat Fraction of Spent Fuel =
Correction Factor Assemblies in Core
(__________) = ___________
( )
FORM TITLE: FORM NO. REV.
CALCULATION OF TIME TO BOIL/CORE UNCOVERY ESTIMATE 1015.002B 066
1015.002 page 131 of 135 CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 2 OF 4 NOTE Reactor Coolant System open is contained in the Definitions section of this procedure.
If the status of the RCS (open or intact) is unknown the RCS will be considered open for Time to Boil determination.
3.0 Determining Time to Boil:
3.1 Using the appropriate figure from Attachment C, OBTAIN uncorrected Time to Boil.
3.1.1 IF RCS is open, THEN USE ONE of the following:
Figure 2A for RCS temp 40°F to 140°F Figure 2B for RCS temp 140°F to 200°F 3.1.2 IF RCS is intact, THEN USE ONE of the following::
Figure 3A for RCS temp 40°F to 140°F Figure 3B for RCS temp 140°F to 300°F 3.1.3 LOG uncorrected Time to Boil: _____________
3.2 MULTIPLY uncorrected Time to Boil by Decay Heat Correction Factor:
Uncorrected Time Decay Heat Time to boil in X =
to Boil in minutes Correction Factor minutes X =
(______) (______) ________
FORM TITLE: FORM NO. REV.
CALCULATION OF TIME TO BOIL/CORE UNCOVERY ESTIMATE 1015.002B 066
1015.002 page 132 of 135 CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 3 OF 4 4.0 Determining Time To Core Uncovery:
4.1 Using the appropriate figure from Attachment C, OBTAIN uncorrected Time To Core Uncovery:
4.1.1 IF Incore Instrument guide tubes are breached AND RV Head is installed, THEN ASSUME a conservative initial RCS level of 369.5' and USE ONE of the following:
Figure 4A for RCS temp 40°F to 140°F Figure 4B for RCS temp 140°F to 200°F 4.1.2 IF RCS is open with nozzle dams removed, THEN USE ONE of the following:
Figure 4A for RCS temp 40°F to 140°F Figure 4B for RCS temp 140°F to 200°F 4.1.3 IF EITHER SG has nozzle dam installed, THEN USE ONE of the following:
Figure 4C for RCS temp 40°F to 140°F Figure 4D for RCS temp 140°F to 200°F 4.1.4 IF RCS is intact, THEN USE ONE of the following:
Figure 5A for RCS temp 40°F to 140°F Figure 5B for RCS temp 140°F to 240°F Figure 5C for RCS temp 240°F to 340°F 4.1.5 LOG uncorrected Time To Core Uncovery: _____________
4.2 MULTIPLY uncorrected Time To Core Uncovery by Decay Heat Correction Factor:
Uncorrected time to Decay Heat Time to Core Core Uncovery in X Correction Factor = Uncovery in minutes minutes
(______) X (______) = ________
FORM TITLE: FORM NO. REV.
CALCULATION OF TIME TO BOIL/CORE UNCOVERY ESTIMATE 1015.002B 066
1015.002 page 133 of 135 CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 4 OF 4 5.0 Determining Time To Core Uncovery:
5.1 Using Figure 6 of Attachment C, DETERMINE uncorrected heatup rate ______°F/min.
5.2 DIVIDE by Decay Heat Correction Factor:
Uncorrected Heatup Rate Estimated Heatup
=
Decay Heat Correction Factor Rate in F/min
(____________) = ___________
( )
6.0 Using Figure 7A or 7B of Attachment C, RECORD required makeup rate: _________ gpm 7.0 IF Time to Boil is significantly less than previous Time to Boil estimate AND in Mode 5 or 6, THEN REEVALUATE ANY containment closure estimates for ALL outstanding items on the Containment Closure Breach List.
8.0 UPDATE the Status Board with the new data.
Performed by _______________________________ Date __________ Time __________
Calculations Reviewed/
Confirmed by CRS or SM: _______________________ Date __________ Time __________
FORM TITLE: FORM NO. REV.
CALCULATION OF TIME TO BOIL/CORE UNCOVERY ESTIMATE 1015.002B 066
PAGE: 53 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 1 OF 16 GRAPHS USED TO DETERMINE RCS TIME TO BOIL/CORE UNCOVERY ESTIMATES This attachment is used with Form 1015.002B, Calculation of RCS Time To Boil/Core Uncovery Estimate when required.
Assumptions used in developing the curves are as follows:
Infinite time at 100% power.
All decay heat is transferred to the coolant or core components.
No heat loss from the system.
Surge line volume neglected.
No makeup from outside sources.
Correction shall be made for the fraction of spent fuel assemblies after refueling.
Reactor vessel head is on.
Boiling occurs at or near atmospheric pressure when the RCS is open.
Boiling occurs at 448°F when the RCS is intact.
Index of figures:
Figure 1 Decay Heat Correction Factors Figure 2A Uncorrected Time to Boil; RCS open, 40°F to 140°F Figure 2B Uncorrected Time to Boil; RCS open, 140°F to 200°F Figure 3A Uncorrected Time to Boil; RCS intact, 40°F to 140°F Figure 3B Uncorrected Time to Boil; RCS intact, 140°F to 300°F Figure 4A Uncorrected Time to Core Uncovery; RCS open, 40°F to 140°F Figure 4B Uncorrected Time to Core Uncovery; RCS open, 140°F to 200°F Figure 4C Uncorrected Time to Core Uncovery; RCS open, nozzle dams installed 40°F to 140°F Figure 4D Uncorrected Time to Core Uncovery; RCS open, nozzle dams installed 140°F to 200°F Figure 5A Uncorrected Time to Core Uncovery; RCS intact, 40°F to 140°F Figure 5B Uncorrected Time to Core Uncovery; RCS intact, 140°F to 240°F Figure 5C Uncorrected Time to Core Uncovery; RCS intact, 240°F to 340°F Figure 6 Uncorrected RCS Heatup Rate Figure 7A Required Makeup Rate; Hours after Shutdown Figure 7B Required Makeup Rate; Days after Shutdown
PAGE: 54 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 2 OF 16 Figure 1 Decay Heat Correction Factors 3.4 3.2 3.0 Time in Days 2.8 2.6 2.4 2.2 Correction Factor 2.0 1.8 1.6 Time in Hours 1.4 1.2 1.0 0.8 0.6 0.4 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 Time After Shutdown
PAGE: 55 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 3 OF 16 Figure 2A Uncorrected Time to Boil RCS Open 55 o
T1=40 F 50 o
T1=60 F 45 o
40 T1=80 F 35 o T1=100 F Time to Boil (min.)
30 o
T1=120 F 25 o
T1=140 F 20 15 10 5
365 367 369 371 373 375 377 379 381 383 420 385 RCS Level (ft.)
PAGE: 56 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 4 OF 16 Figure 2B Uncorrected Time to Boil RCS Open 24 22 o T1=140 F 20 18 o
16 T1=160 F Time to Boil (min.)
14 12 o
10 T1=180 F 8
6 o
4 T1=200 F 2
0 365 367 369 371 373 375 377 379 381 383 420 RCS Level (ft.)
PAGE: 57 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 5 OF 16 Figure 3A Uncorrected Time to Boil RCS Intact 150 o
140 T1=40 F o
T1=60 F 130 o
T1=80 F 120 o
T1=100 F o
110 T1=120 F Time to Boil (min.)
o T1=140 F 100 90 80 70 60 50 40 365 367 369 371 373 375 377 379 381 383 420 RCS Level (ft.)
PAGE: 58 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 6 OF 16 Figure 3B Uncorrected Time to Boil RCS Intact 110 o
T1=140 F 100 o
T1=160 F 90 o T1=180 F o
80 T1=200 F o
T1=220 F 70 Time to Boil (min.)
o T1=240 F o
60 T1=260 F o
T1=280 F 50 o
T1=300 F 40 30 20 10 365 367 369 371 373 375 377 379 381 383 420 RCS Level (ft.)
PAGE: 59 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 7 OF 16 FIGURE 4A UNCORRECTED TIME TO CORE UNCOVERY RCS OPEN, RV HEAD ON 650 T1=40 F T1=60 F 600 T1=80 F 550 TIME TO CORE UNCO VERY (10 m inute increm ents) 500 T1=100 F T1=120 F 450 T1=140 F 400 350 300 250 200 150 100 50 0
365 370 375 380 385 390 395 400 405 410 415 420 RCS LEVEL (1 foot increments)
PAGE: 60 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 8 OF 16 FIGURE 4B UNCORRECTED TIME TO CORE UNCOVERY RCS OPEN, RV HEAD ON 600 T1=140 F 550 T1=160 F 500 T1=200 F TIME TO CORE UNCOVERY (10 minute increments) 450 400 T1=180 F 350 300 250 200 150 100 50 0
365 370 375 380 385 390 395 400 405 410 415 420 RCS LEVEL (1 foot increments)
PAGE: 61 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 9 OF 16 Figure 4C Uncorrected Time to Core Uncovery RCS Open, Nozzle Dams Installed 500 o
T1=40 F o
T1=60 F 400 T1=80oF o
T1=100 F Time to Core Uncovery (min.)
300 T1=120oF o
T1=140 F 200 100 0
365 375 385 395 405 RCS Level (ft.)
PAGE: 62 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 10 OF 16 Figure 4D Uncorrected Time to Core Uncovery RCS Open, Nozzle Dams Installed 400 o
T1=140 F o
T1=160 F 300 T1=200oF Time to Core Uncovery (min.)
o T1=180 F 200 100 0
365 375 385 395 405 RCS Level (ft.)
PAGE: 63 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 11 OF 16 FIGURE 5A UNCORRECTED TIME TO CORE UNCOVERY RCS INTACT, RV HEAD ON 800 750 700 650 TIME TO CORE UNCOVERY (10 minute increments) 600 T1=40 F 550 T1=60 F 500 450 T1=80 F T1=100 F 400 350 T1=120 F 300 T1= 140 F 250 200 150 100 50 0
360 365 370 375 380 385 390 395 400 405 410 415 420 RCS LEVEL (1 foot increments)
PAGE: 64 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 12 OF 16 FIGURE 5B UNCORRECTED TIME TO CORE UNCOVERY RCS INTACT, RV HEAD ON 700 650 600 550 TIME TO CORE UNCOVERY (10 minute increments) 500 T1=140 F 450 T1=160 F 400 T1=180 F 350 T1=200 F 300 T1=220 F 250 T1=240 F 200 150 100 50 0
360 365 370 375 380 385 390 395 400 405 410 415 420 RCS LEVEL (1 foot increments)
PAGE: 65 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 13 OF 16 FIGURE 5C UNCORRECTED TIME TO CORE UNCOVERY RCS INTACT, RV HEAD ON 600 T1=240 F 550 500 T IM E T O C O R E U N C O V E R Y (10 m inu te increm e nts) 450 400 T1=260 F T1=280 F 350 T1=300 F 300 T1=320 F 250 T1=340 F 200 150 100 50 0
360 365 370 375 380 385 390 395 400 405 410 415 420 RCS LEVEL (1 foot increments)
PAGE: 66 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 14 OF 16 Figure 6 Uncorrected RCS Heatup Rate 10.0 9.0 o
T1=400 F 8.0 o T1=300 F o
T1=200 F 7.0 o
T1=100 F RCS Heatup Rate ( F/min.)
6.0 o
5.0 4.0 3.0 2.0 1.0 0.0 365 367 369 371 373 375 377 379 381 383 420 RCS Level (ft.)
PAGE: 67 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 15 OF 16 Figure 7A Required Makeup Rate 260 240 220 200 Required Makeup (gpm) 180 160 RCS Pressure = 0 psig 140 RCS Pressure = 100 psig RCS Pressure = 200 psig 120 RCS Pressure = 300 psig RCS Pressure = 400 psig 100 RCS Pressure = 500 psig 80 60 0 10 20 30 40 50 60 70 80 90 100 Hours After Shutdown
PAGE: 68 of 135 1015.002 DECAY HEAT REMOVAL AND LTOP SYSTEM CONTROL CHANGE: 066 ATTACHMENT C PAGE 16 OF 16 Figure 7B Required Makeup Rate 120 110 100 90 Required Makeup (gpm) 80 70 RCS Pressure = 0 psig RCS Pressure = 100 psig 60 RCS Pressure = 200 psig RCS Pressure = 300 psig 50 RCS Pressure = 400 psig RCS Pressure = 500 psig 40 30 20 0 10 20 30 40 50 60 70 80 90 100 Days After Shutdown
A1JPM-RO-SURV3 PAGE 1 OF 4 UNIT: 1 REV #: 0 DATE:
SYSTEM/DUTY AREA: Equipment Control TASK: Perform Service Water Pump Test (P-4A/B/C)
JTA#: ANO1-RO-SWACW-SURV-43 KA VALUE RO: 3.7 SRO: 4.1 KA
REFERENCE:
2.2.12 APPROVED FOR ADMINISTRATION TO: RO: X SRO:
TASK LOCATION: INSIDE CR: OUTSIDE CR: BOTH: X SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: CLASSROOM: Perform POSITION EVALUATED: RO: X SRO:
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: CLASSROOM: X TESTING METHOD: SIMULATE: PERFORM:
APPROXIMATE COMPLETION TIME IN MINUTES: 15 Minutes REFERENCE(S): 1104.029 EXAMINEE'S NAME: LOGON:
EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Stop Total Time Time Time SIGNED: Robert Possage DATE:
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
A1JPM-RO-SURV3 PAGE 2 OF 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the applicant has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS:
Plant is shutdown with refueling in progress.
1104.029 Supplement 1 in progress completed up to Step 2.13 P-4A has been running for 3 minutes.
TASK STANDARD:
Calculated / Perform the following:
- 1) P-4A actual differential pressure of 87.5 psid (86.5 to 88.5 psid)
- 2) P-4A baseline differential pressure of 97.5 psid (96 to 98 psid)
- 3) Circled NO in Table 3 TASK PERFORMANCE AIDS:
1104.029 Supplement 1 SIMULATOR SETUP:
NA EXAMINER'S NOTES:
A1JPM-RO-SURV3 PAGE 3 OF 4 INITIATING CUE:
CRS directs you to perform Steps 2.14 - 2.20 and any actions required by Section 3.0.
PERFORMANCE CHECKLIST STANDARDS SAT UNSAT N/A NOTE: Provide examinee with a copy of the in progress surveillance.
- 1. Applicant reviewed 1104.029, Review 1104.029, Supplement 1. ____ ____ ____
Supplement 1.
- 2. Applicant calculates Actual Pump Calculate Actual Pump Diff Diff Pressure using Table 2 Data (C) Pressure using data from and equation provided in ____ ____ ____
Table 2 and record value in 1104.0029 supplement 1.
Table 3.
80 psig + 7.5 psig = 87.5 psig
- 3. Applicant Plots calculated diff Plot test value on P-4A Pump pressure value on P-4A Pump Curve. Curve. ____ ____ ____
4.
Find the value of Baseline Applicant Finds baseline Pump Diff Press and record Differential pressure using SW in Table 3. Loop 1 flow from Table 2 and ____ ____ ____
P-4A Pump Curve.
5.
Calculate P-4A Deviation Applicant Calculates Deviation (C) from Baseline and Record in from Baseline using provided Table 3. equation in 1104.029 supplement 1.
97.5 psid - 87.5 psid = 10 psid 6.
(C) Evaluate P-4A Actual Pump Applicant circles NO on Table 3 Differential Pressure, for Data Within Limiting Range.
compare to LIMITING RANGE FOR OPERABILITY
- 7. Applicant may discuss declaring Complete Section 3.0 pump inoperable, notifying SM, writing Condition Report, initiating corrective action, and referring to ____ ____ ____
Tech Specs.
NOTE:
The SM or CRS will consult Tech Specs; it is the ROs responsibility to report the inoperability of P-4A only. Service Water operability will be determined by the SM/CRS.
Inform the Applicant that steps 2.21 - 2.49 will be completed by another operator.
A1JPM-RO-SURV3 PAGE 4 OF 4 PERFORMANCE CHECKLIST STANDARDS SAT UNSAT N/A NOTE: Provide examinee with a copy of the in progress surveillance.
END EXAMINEEES COPY JPM INITIAL TASK CONDITIONS:
Given the following Plant conditions:
- Plant is shutdown with refueling in progress.
- Service Water Pump P-4A Test in accordance with 1104.029 Supplement 1 is in progress, completed through step 2.13.
- P-4A has been running for 3 minutes.
INITIATING CUE:
CRS directs you to perform Steps 2.14 - 2.20 and any actions required by Section 3.0.
2.21 through 2.49 will be completed by another operator.
PAGE: 311 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 9 OF 27 KEY
- 2. WHEN flow has been stable for at least two minutes, THEN:
COMMENCE P-4A Motor Bearing vibration data collection per Vibrometer Data sheet.
RECORD the following Measured Values in Table 2:
Loop I Press: SPDS/Alt Test Inst Loop I Press: P1-3608 SW Loop I Flow: SPDS/ALT Test Inst A SW Bay Level: SPDS Suction Pressure: SPDS Local Discharge Press: Local P1-3611/Alt Test Inst 2.14 CALCULATE Actual Pump Duff Pressure (APA) using the following values as recorded in Table 2:
Local Disch Press + Suction Pressure LPA 80 + 7.5 87.5 2.15 RECORD Actual Pump Duff Pressure (t.PA) in Table 3.
2.16 Using Actual Pump Duff Press (APA) and SW Loop I Flow, PLOT test value on P-4A Pump Curve.
2.17 Using the Baseline on the P-4A Pump Curve and using SW Loop I Flow, FIND the value of Baseline Pump Duff Press (APB).
2.18 RECORD Baseline Pump Duff Press (tXPB) in Table 3.
PAGE: 312of551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 10 OF 27 KEY NOTE P-4A Deviation From Baseline could be a negative number. For trending purposes, the negative sign is included.
2.19 CALCULATE P-4A Deviation From Baseline using data from Table 3:
. P-4A Deviation psi)
(APa (APA psi)
From Baseline
=
97.5 87.5 10 2.20 RECORD P-4A Deviation From Baseline in Table 3 including negative sign, if applicable.
NOTE Bearing temperature is considered stable when three consecutive readings at ten-minute intervals vary no more than 3%.
¶ IE this test is to prove operability after significant maintenance, THEN:
2.21.1 CONTINUE test until motor bearing temperatures are stable.
2.21.2 RECORD stable motor bearing temperatures in Table 4.
IE this test is NQI being performed to prove operability after significant maintenance, THEN MARK motor bearing temperatures in Table 4 N/A.
2.23 WHEN P-4A Motor Bearing vibration data is collected, THEN RECORD data in Table 5.
I 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM PAGE: 323 of 551 CHANGE: 120 L
SUPPLEMENT I PAGE 21 OF 27 KEY TABLE 2 Test Quantity Instrument Measured Acceptable Limiting Range Is Data Within Values Normal Range For Operability Limiting Range SW Loop I Press Alt Test_Inst 7$. 6 psig N/A N/A N/A P 1-3608 L psig SW Loop I Flow Anst tJ2 N/A N/A N/A SPD A SW Bay Level Callevel 33, LI feet N/A > 332 feet Suction Press Cled N/A N/A N/A tion_Pres Local Discharge Press Local P1-361 ltrestmf N/A N/A N/A psig Table 2 data gathered by: initial date KEY TABLE 3 Test quantity Measured Acceptable I Limiting Range Is Data Within Values Normal Range For Operability Limiting Range?
Actual Pump Duff Press Acceptable Normal and Limiting Range (APA) 87.5 values are per P-4A Pump Curve YES NO Baseline Pump Duff Press (APe) 97.5 psi N/A N/A N/A P-4A Deviation From psi N/A Baseline 10 N/A N/A Table 3 data gathered by: initial date TABLE 4 Test Quantity Measured Acceptable Limiting Range Is Data Within Instrument Values Normal Range For Operability Limiting Range Mtr Upper Brg TE-3651 Temp (P1284 or TR-3651) il/A °F <180°F N/A N/A MtrLowerBrg TE-3652 Temp (P1285 or TR-3651) °F <180°F N/A N/A Table 4 data gathered by: initial dZ
PAGE: 325 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 23 OF 27 KEY TABLE 9 Test Measured Acceptable Limiting Valve DES# Normal Range If within Direction Stroke Time Value for Initial Date (nearest 1/10 sec) Limiting (sec) Operability Value SG-5 Close sec 147.1 - 199.0 225.0 SG-1 Open sec 154.0-208.2 235.4 (__j SG-3 Open sec 157.9-213.7 241.5 (..J CV-3644 Open sec 48.0 64.8
- 73.3 (__)
CV-3646 Open sec 39.2 53.0
- 59.9 (__J 3.6 IF NO is circled in Table 2, 3 or 5, THEN:
- DECLARE P-4A inoperable.
- NOTIFY the Shift Manager.
- INITIATE a Condition Report.
- INITIATE corrective action.
- REFERENCE Tech Spec for applicable conditions.
3.7 i.E ANY measured value in Table 2, 3, 4 or 5 does NOT fall within the Acceptable Normal Range, THEN INITIATE corrective action.
PAGE: 327 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I KEY PAGE 25 OF 27 P-4A Pump Curve 115 Baseline iting 110
- Aceptable Normal Range Limiting Range 105 Comprehensive Limit 100 95 90 NN 0
a 85 rtingj I Range I NNN E
a-80 75 70 EEEEEEIEE 65 4ç 60 55 z::z:::::z::z:::::::N 50 4000 4500 5000 5500 6000 6500 7000 7500 Pump Flow (gpm)
PAGE: 303 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 1 OF 27 SERVICE WATER PUMP P-4A TEST
{4.2.2}
This test demonstrates operability of Service Water Pump (P-4A) and its discharge check valve by running the pump at rated flow and exercising the check valve. This test also demonstrates operability of SW system flow path motor-operated valves by exercising the valves a complete cycle and measuring stroke times to required safety function positions. This test satisfies ANO 1ST program requirements 10 CFR 50.55a(f). Reference Values for 1ST Components are contained in Appendix B. 18-month testing requirements are contained in Supp. 8.
This supplement tests both red and green train components. Test method has been evaluated and determined to be acceptable.
The steps in this section may be performeGfrrder with the substeps performed in the order specified.
1.0 INITIAL CONDITIONS CHECK the purpose of this test:
fr43 Regularly scheduled quarterly test B) Operability test following significant maintenance (DESCRIBE maintenance performed in section 4.0).
C) Other (DESCRIBE in section 4.0).
IF test is to prove operability following significant maintenance, THEN NOTIFY System Engineer to determine necessity to perform Attachment C Service Water Pump Reference Values Determination.
- 1. ffi during this test a valve stroke time is .4QI within Acceptable Normal Range AND stroke time is within Limiting Value for Operability, THEN prior to changing system alignment, REFER TO Appendix A, Operability, Failure of Valve Stroke to Meet Acceptable Normal Range and PERFORM ONE of the following:
RETEST valve.
DECLARE valve inoperable.
Ør ENSURE system aligned per 3305.001, Ops System Alignment Tests, System Alignment Confirmation section.
CHECK motor oil level per Service Water Pump Motor P-4AIB/C Lube Oil Check, Exhibit J of 1107.001, Electrical System Operations.
OBTAIN vibrometer from Predictive Maintenance Lab.
W RECORD vibrometer M&TE# and Cal Due Date in Acceptance Criteria, section 3.0, at Table 5.
PAGE: 304 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 2 OF 27 ENSURE two currently calibrated stopwatches available.
RECORD stopwatch DES# and cal due date in section 3.0.
WHEN timing valve strokes, THEN:
IDENTIFY the stopwatch providing stroke time.
RECORD initial and date.
If test data taken under proper test conditionside the Limiting Range for Operability, the component being tested is declared inoperable for conservatism, even if instrument mis-calibration is suspected.
I.E SPDS is specified in instrument column for recording test data and SPDS instrumentation is NOT available, THEN PERFORM EITHER of the following:
- POSTPONE this surveillance.
- INSTALL appropriate alternate instruments.
IF alternate test instruments are used for an instrument other than local discharge pressure indicator, THEN:
1.10.1 ENSURE test instrument(s) meet the following requirements:
- Calibration is current.
- Test instrument accuracy is +/-2% of full scale or better.
- Range of Analog test instrument is less than 3 times normal process value.
- Range of Digital test instrument is scaled so that normal process value remains less than 70% of full scale.
1.10.2 OBTAIN Independent Verification instrument(s) meet the requirements stated above for:
- Cal Due Date
- Accuracy
- Range I.V. by:
PAGE: 305 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 3 OF 27 4A10.3 ENSURE instrument column in section 3.0 is annotated to show the instrument number used and the cal due date.
1.10.4 ENSURE alternate instrument use is documented with appropriate explanation of reason(s) in Supervisor Review and Analysis section.
1.10.5 INSTALL alternate test instrument(s) at SPDS transmitter local instrument connection.
1.10.6 OBTAIN independent verification instrument(s) is(are) installed at SPDS transmitter local instrument connection.
l.V. by 1.10.7 WHEN alternate test instrument(s) are aligned, THEN MAINTAIN instruments attended.
IF SW Pump P-4A Disch Press (P1-3611) is unavailable, THEN:
1.11.1 OBTAIN alternate analog test instrument meeting the following requirements:
- Calibration is current.
Test instrument accuracy
+/-0.5% of full scale or better for pump dP (suction, discharge).
- Range of ANALOG test instrument is less than 3 times normal process value.
1.11.2 OBTAIN independent verification instrument(s) meet the requirements stated above for:
- Cal due date
- Accuracy
- Range l.V. by
PAGE: 306 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 4 OF 27 4b41 1.3 RECORD alternate test instrument M&TE number and cal due date in step 3.0.
1.11.4 ANNOTATE in Supervisor Review and Analysis section, alternate test instrument used for pump discharge pressure for gauge unavailable, etc.
1.11.5 INSTALL alternate test instrument as follows:
A. ENSURE test connection valve between SW Pump P-4A Discharge PS-361 I Isol (SW-361 1 E) and PS-361 I closed.
B. INSTALL alternate test instrument at test connection between SW Pump P-4A Discharge PS-3611 Isol (SW-361 I E) and PS-3611.
C. POSITION alternate test instrument at same elevation as SW Pump P-4A Disch Press (P1-3611).
1.11.6 OBTAIN independent verification of alternate test instrument installation.
l.V. by 1.11.7 WHEN alternate test instrument(s) are aligned, THEN MAINTAIN instruments attended.
NOTIFY the following that dual train (red and green) testing will be performed during the performance of this supplement:
If manned, CCC.
If manned, CRSA.
Shift Manager or Operations Management.
PAGE: 307 of 551 I 104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 5 OF 27 2.0 TEST METHOD ENSURE A and B SW bays crosstied via A/B SW Bay Crosstie (SG-3) and aligned to the lake via Lake Supply to A SW Bay (SG-1).
IE C SW bay is in service AND aligned to the lake via Lake Supply to C SW Bay (SG-2)
AND B/C SW Bay Crosstie (SG-4) available, THEN ENSURE SG-4 is open.
ENSURE the following valves are open to cross-connect SW loops at ICW coolers:
- Loop I Supply to ICW Coolers (CV-3820)
- Loop II Supply to ICW Coolers (CV-3811)
- SW Loops I & II Crossconnect (SW-5)
- SW Loops I & II Crossconnect (SW-6)
IF SW Pump (P-4A) is NOT in service, THEN:
2.4.1 ENSURE SW Pump P-4B to P-4C Crossties open:
- P-4B to P-4C Crosstie (CV-3640)
- P-4B to P-4C Crosstie (CV-3642) 2.4.2 if desired by CRS/SM to minimize SW Pressure rise due to starting third SW Pump, THEN PERFORM ONE or more of the following:
A. if adjusting SW pressure with SW-4026A, THEN:
- 1. RECORD as-found percent open indication:
- 2. THROTTLE SW-4026A to obtain SW Loop pressures 65 to 85 psig.
- 3. RECORD as-left SW-4026A percent open indication:
B if adjusting SW pressure with SW-4026B, THEN while counting turns, THROTTLE SW-4026B to obtain SW Loop pressures 65 to 85 psig.
- RECORD number of turns operated:
C. jf CRS desires to place additional SW loads into service, THEN RECORD additional SW loads:
PAGE: 308 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 6 OF 27 MAKE a plant announcement that a Service Water pump will be started.
2.4.4 START SW Pump (P-4A).
2.4.5 CHECK P-4A packing leakoff.
2.4.6 IF ALL 3 service water pumps are operating, THEN:
A. STOP SW Pump (P-4B).
B. CHECK for reverse rotation of SW Pump (P-4B).
C. IF reverse rotation indicated, THEN:
- 1. MAKE an entry in Category E/Locked Component Log for P-4B Disch Isol (SW-2B).
- 2. UNLOCK and CLOSE P-4B Disch Isol (SW-2B).
- 3. DECLARE SW Pump (P-4B) and P-4B Disch Ck (SW-1B) inoperable.
- 4. REFER TO Technical Specifications.
D. NOTIFY Chemistry to stop Chemical Injection to B SW Bay.
2.4.7 IF SW pressure adjustment was performed in step 2.4.2 AND CRS desires to make SW pressure adjustment, THEN PERFORM ONE of the following to restore SW pressure:
A. IF adjusting SW pressure with SW-4026A, THEN:
- 1. THROTTLE SW-4026A to obtain SW Loop pressures 65 to 85 psig.
- 2. RECORD as-left SW-4026A percent open indication:
B. if adjusting SW pressure with SW-4026B, THEN while counting turns, THROTTLE SW-4026B to obtain SW Loop pressures 65 to 85 psig.
. RECORD number of tums operated:
C. IF CRS desires to remove additional SW loads from service, THEN RECORD SW loads removed:
PAGE: 309 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 7 OF 27 48 if SW Pump (P-4A) will remain in service at the completion of this test, THEN NOTIFY Chemistry to realign Chemical Injection.
Stroke test of Loop II Supply to ICW Coolers (CV-381 1):
While measuring stroke time, CLOSE CV-381 1.
RECORD CV-381 1 closing stroke time in Table 1.
OPEN Loop II Supply to ICW Coolers (CV-381 1).
NOTE Normally, P-4A to P-4B Crossties (CV-3644 and CV-3646) are open and steps 2.7 and 2.8 will be marked N/A.
¶ IF P-4A to P-4B Crosstie (CV-3644) is closed, THEN PERFORM the following to stroke test CV-3644 open:
2.7.1 While measuring stroke time, OPEN CV-3644.
2.7.2 RECORD CV-3644 opening stroke time in Table 9.
IF P-4A to P-4B Crosstie (CV-3646) is closed, THEN PERFORM the following to stroke test CV-3646 open:
2.8.1 While measuring stroke time, OPEN CV-3646.
2.8.2 RECORD CV-3646 opening stroke time in Table 9.
Closed stroke test of P-4A to P-4B Crosstie (CV-3646)
While measuring stroke time, CLOSE CV-3646.
RECORD CV-3646 closing stroke time in Table 1:
Closed stroke test of P-4A to P-4B Crosstie (CV-3644):
While measuring stroke time, CLOSE CV-3644.
RECORD CV-3644 closing stroke time in Table 1:
PAGE: 310 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 8 OF 27 Actual SW/ACW flow of less than 1500 gpmwiuse SPDS flow indication to indicate 0 gpm.
From SPDS Diagnostic Display or SPDS point F3902, CHECK SW Loop I flow is 4000 gpm or greater.
IF SW Loop I flow is less than 4000 gpm, THEN:
A. IF RB Cooling will be placed into service to raise SW Loop I flow, THEN CHECK Service Water biocide injection system in service (allowed exception: system unavailable with lake temperature less than 60°F or greater than 80°F).
B. PLACE idle load(s) into service to raise SW Loop I flow to 4000 gpm or greater.
I 1. LIST load(s) placed into service below:
C. IF additional load(s) are added, THEN:
- 1. MONITOR component temperatures closely.
- 2. ADJUST cooling water flows as necessary. 4 IF alternate test instrument is installed for SW Pump P-4A Disch Press (P1-3611),
THEN:
2.12.1 OPEN test connection valve isolating disch press alternate test instrument at PS-361 1.
2.12.2 MAINTAIN alternate test instrument attended unless isolated.
PAGE: 311 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 9 OF 27
- 2. WHEN flow has been stable for at least two minutes, THEN:
COMMENCE P-4A Motor Bearing vibration data collection per Vibrometer Data sheet.
RECORD the following Measured Values in Table 2:
Loop I Press: SPDS/Alt Test Inst Loop I Press: P1-3608 SW Loop I Flow: SPDS/ALT Test Inst A SW Bay Level: SPDS Suction Pressure: SPDS Local Discharge Press: Local P1-3611/Alt Test Inst 2.14 CALCULATE Actual Pump Duff Pressure (APA) using the following values as recorded in Table 2:
Local Disch Press + Suction Pressure LPA
+
2.15 RECORD Actual Pump Duff Pressure (t.PA) in Table 3.
2.16 Using Actual Pump Duff Press (APA) and SW Loop I Flow, PLOT test value on P-4A Pump Curve.
2.17 Using the Baseline on the P-4A Pump Curve and using SW Loop I Flow, FIND the value of Baseline Pump Duff Press (APB).
2.18 RECORD Baseline Pump Duff Press (tXPB) in Table 3.
PAGE: 312of551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 10 OF 27 NOTE P-4A Deviation From Baseline could be a negative number. For trending purposes, the negative sign is included.
2.19 CALCULATE P-4A Deviation From Baseline using data from Table 3:
. P-4A Deviation psi)
(APa (APA psi)
From Baseline
=
2.20 RECORD P-4A Deviation From Baseline in Table 3 including negative sign, if applicable.
NOTE Bearing temperature is considered stable when three consecutive readings at ten-minute intervals vary no more than 3%.
¶ IE this test is to prove operability after significant maintenance, THEN:
2.21.1 CONTINUE test until motor bearing temperatures are stable.
2.21.2 RECORD stable motor bearing temperatures in Table 4.
IE this test is NQI being performed to prove operability after significant maintenance, THEN MARK motor bearing temperatures in Table 4 N/A.
2.23 WHEN P-4A Motor Bearing vibration data is collected, THEN RECORD data in Table 5.
PAGE: 313of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 11 OF 27 2.24 CHECK SW Loop I flow 5600 gpm or greater.
2.24.1 IF SW Loop I flow is less than 5600 gpm, THEN:
A. IF RB Cooling will be placed into service to raise SW Loop I flow, THEN CHECK Service Water biocide injection system in service (allowed exception: system unavailable with lake temperature is less than 60°F or greater than 80°F).
B. PLACE idle load(s) into service to raise SW Loop I flow to 5600 gpm or greater.
- 1. LIST load(s) placed into service below:
C. IF additional load(s) are added, THEN:
- 1. MONITOR component temperatures closely. p
- 2. ADJUST cooling water flows as necessary.
2.25 RECORD the following:
- Open stroking of P-4A Disch Ck (SW-lA) in Table 6.
- Flow rate: gpm
- Flow instrument:
2.26 IF additional load(s) were added in order to raise SW flow for this test, THEN RESTORE load(s) listed in steps 2.11.1.B and 2.24.1.B to original status.
PAGE: 314 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 12 OF 27 2.27 Closed stroke test of A/B SW Bay Crosstie (SG-3):
NOTE Any delay during the performance of the following series of steps could result in lowering B SW Bay level.
CAUTION With SW Bay Level starting at 332 feet or less and SW Flow 8000 gpm or greater, SW pump NPSH limits could be exceeded during suction transfer from Lake to Pond. This could result in pump damage.
2.27.1 ENSURE A and B SW Bay Levels are above 332 feet.
2.27.2 While measuring stroke time, CLOSE SG-3.
2.27.3 jf SW Pump P-4B is in service AND B/C SW Bay Crosstie (SG-4) is closed, THEN OPEN Pond Supply to B SW Bay (SG-6).
2.27.4 RECORD SG-3 closing stroke time in Table 7.
NOTE Any delay during the performance of the following series of steps will result in lowering A SW Bay level.
2.28 Closed stroke test of Lake Supply to A SW Bay (SG-1):
2.28.1 While measuring stroke time, CLOSE SG-1.
2.28.2 RECORD SG-1 closing stroke time in Table 7.
SUPPLEMENT I PAGE 13 OF 27 NOTE Aligning a SW Pump suction to Emergency Cooling Pond will cause the ECP level to drop.
2.29 Open stroke test of Pond Supply to A SW Bay (SG-5):
2.29.1 While measuring stroke time, OPEN SG-5.
2.29.2 IF SG-5 fails to operate, THEN:
A. PERFORM ONE of the following:
- OPEN Lake Supply to A SW Bay (SG-1).
- OPEN A/B SW Bay Crosstie (SG-3).
B. E Pond Supply to B SW Bay (SG-6) is closed, THEN ENSURE B/C SW Bay Crosstie (SG-4) open.
2.29.3 RECORD SG-5 open stroke time in Table 7.
CAUTION Sediment can enter pump suction when going on Emergency Cooling Pond.
I 2.30 MONITOR SW Pump (P-4A) discharge pressure and strainer AP while in this configuration.
2.31 WHEN 15 minutes of operation on Emergency Cooling Pond has elapsed, THEN RECORD the following:
SW Loop I flow gpm
PAGE: 316 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 14 OF 27 NOTE Any delay during the performance of the following series of steps will result in lowering A SW Bay level.
2.32 Closed stroke test of Pond Supply to A SW Bay (SG-5):
2.32.1 While measuring stroke time, CLOSE SG-5.
2.23.2 RECORD SG-5 close stroke time in Table 9.
2.33 Open stroke test of Lake Supply to A SW Bay (SG-1):
2.33.1 While measuring stroke time, OPEN SG-1.
2.33.2 IF SG-1 fails to operate, THEN:
A. PERFORM ONE of the following:
- OPEN Pond Supply to A SW Bay (SG-5).
- OPEN A/B SW Bay Crosstie (SG-3).
B. IF Pond Supply to B SW Bay (SG-6) is closed, THEN ENSURE B/C SW Bay Crosstie (SG-4) open.
2.33.3 RECORD SG-1 open stroke time in Table 9.
NOTE Any delay during the performance of the following series of steps will result in lowering B SW Bay level.
2.34 Open stroke test of A/B SW Bay Crosstie (SG-3):
2.34.1 E SW Pump (P-4B) is in service supplied from the ECP, THEN CLOSE Pond Supply to B SW Bay (SG-6).
2.34.2 While measuring stroke time, OPEN SG-3.
2.34.3 RECORD SG-3 open stroke time in Table 9.
2.35 ffl P-4A to P-4B Crosstie (CV-3644) was N.QI open stroke tested in step 2.7, THEN:
2.35.1 While measuring stroke time, OPEN CV-3644.
2.35.2 RECORD CV-3644 opening stroke time in Table 9.
PAGE: 317 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 15 OF 27 2.36 E P-4A to P-4B Crosstie (CV-3646) was 4.QI open stroke tested in step 2.8, THEN:
2.36.1 While measuring stroke time, OPEN CV-3646.
2.36.2 RECORD CV-3646 opening stroke time in Table 9.
2.37 ENSURE P-4A to P-4B Crosstie valves open:
- P-4A to P-4B Crosstie (CV-3644)
- P-4A to P-4B Crosstie (CV-3646)
NOTE Powering SW Pumps P-4B and P-4C from opposite buses satisfies Tech Spec requirements for train separation.
CAUTION If three SW pumps are operating due to high SW system heat loads, a delay in the subsequent steps to restart SW Pump P-4A can cause overheating of SW system loads.
2.38 IF in Mode 14 AND SW Pumps P-4B and P-4C are operable, THEN:
2.38.1 CHECK P4B Bus Select MOD Control selected to A3.
2.38.2 IF P4B Bus Select MOD Control selected to A4, THEN:
A. ENSURE SW Pump P-4C in service.
B. ENSURE SW Pump P-4B is secured.
C. ENSURE BOTH SW Pump P-4B supply breakers are open:
- On C18, A-303 indicates open
- On C16, A-403 indicates open D. TRANSFER P4B Bus Select MOD Control to A3.
E. PERFORM 1107.002, ES Electrical System Operation, Transfer MCC B55156 to B5 section.
PAGE: 318of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 16 OF 27 2.38.3 IF desired by CRS/SM to minimize SW Pressure rise due to starting third SW Pump, THEN PERFORM ONE or more of the following:
A. jf adjusting SW pressure with SW-4026A, THEN:
- 1. RECORD as-found percent open indication:
- 2. THROTTLE SW-4026A to obtain SW Loop pressures 65 to 85 psig.
- 3. RECORD as-left SW-4026A percent open indication:
B ffl adjusting SW pressure with SW-4026B, THEN while counting turns, THROTTLE SW-4026B to obtain SW Loop pressures 65 to 85 psig.
. RECORD number of turns operated:
C. IE CRS desires to place additional SW loads into service, THEN RECORD additional SW loads:
2.38.4 ENSURE SW Pumps P-4B and P-4C in service.
2.38.5 ENSURE SW Crosstie valves open:
- P-4A to P-4B Crosstie (CV-3644)
- P-4A to P-4B Crosstie (CV-3646)
- P-4B to P-4C Crosstie (CV-3640)
- P-4B to P-4C Crosstie (CV-3642)
PAGE: 319 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 17 OF 27 NOTE Stopping of P-4A pump shaft confirms seating of P-4A Disch Check (SW-IA).
2.38.6 STOP SW Pump (P-4A).
2.38.7 CHECK SW Pump (P-4A) shaft stops.
2.38.8 IF reverse rotation indicated, THEN:
A. MAKE an entry in Category E/Locked Component Log for P-4A Disch Isol (SW-2A).
B. UNLOCK and CLOSE P-4A Disch Isol (SW-2A).
C. DECLARE SW Pump (P-4A) and P-4A Disch Ck (SW-lA) inoperable.
D. REFER TO Technical Specifications.
2.38.9 RECORD closing of P-4A Disch Ck (SW-lA) in Table 6.
2.38.10 IF desired by CRS/SM, THEN RESTART SW Pump (P-4A).
NOTE In Mode 5, 6 or defueled, only one SW pump is required to be operating.
2.39 IF plant is in Mode 5, 6 or defueled AND plant conditions allow stopping P-4A, THEN PERFORM the following to stop P-4A:
2.39.1 IF in Mode 6, THEN REFER TO Refueling Operations (TS 3.9) to determine SW pump requirements.
2.39.2 IF a single SW Pump will be in operation in the subsequent steps, THEN CHECK SW flow is less than 8000 gpm.
2.39.3 ENSURE SW Pump P-4B or P-4C in service.
PAGE: 320 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 18 OF 27 2.39.4 ENSURE SW Crosstie valves open:
- P-4A to P-.4B Crosstie (CV-3644)
- P-4A to P-4B Crosstie (CV-3646)
- P-4B to P-4C Crosstie (CV-3640)
- P-4B to P-4C Crosstie (CV-3642)
NOTE Stopping of P-4A pump shaft confirms seating of P-4A Disch Check (SW-lA).
2.39.5 STOP SW Pump (P-4A).
2.39.6 CHECK SW Pump (P-4A) shaft stops.
2.39.7 E reverse rotation indicated, THEN:
A. MAKE an entry in Category E/Locked Component Log for P-4A Disch lsol (SW-2A).
B. UNLOCK and CLOSE P-4A Disch Isol (SW-2A).
C. DECLARE SW Pump (P-4A) and P-4A Disch Ck (SW-lA) inoperable.
D. REFER TO Technical Specifications.
2.39.8 RECORD closing of P-4A Disch Check (SW-IA) in Table 6.
2.39.9 if desired by CRS/SM, THEN RESTART SW Pump (P-4A).
2.40 if plant is in Mode 5, 6 or defueled AND plant conditions prevent stopping P-4A, THEN:
- MARK SW-lA closure N/A in Table 6.
- INITIATE a Condition Report to document that SW-IA requires 1ST stroke.
2.41 RETURN system to desired pump configuration per Pump Rotation section of this procedure.
2.42 ENSURE that sluice gates and cross-ties are aligned as required by Table 9.1.4 of this procedure.
PAGE: 321 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 19 OF 27 2.43 IE SW pressure adjustment was performed in step 2.38.3 AND CRS desires to make SW pressure adjustment, THEN PERFORM ONE or more ot the following to restore SW pressure:
2.43.1 jf adjusting SW pressure with SW-4026A, THEN:
A. THROTTLE SW-4026A to obtain SW Loop pressures 65 to 85 psig.
B. RECORD as-left SW-4026A percent open indication:
2.43.2 E adjusting SW pressure with SW-4026B, THEN while counting turns, THROTTLE SW-4026B to obtain SW Loop pressures 65 to 85 psig.
. RECORD number of turns operated:
2.43.3 IF CRS desires to remove additional SW loads from service, THEN RECORD SW loads removed:
2.44 ffi alternate test instrument installed for P-4A Disch Press (P1-361 1),
THEN:
2.44.1 ENSURE test connection valve between SW Pump P-4A Discharge PS-36 11 Isol (SW-361 I E) and PS-36 11 closed.
2.44.2 REMOVE test instrument.
2.44.3 ENSURE SW-361 IE is open.
2.45 IF alternate test instruments are installed, THEN REMOVE alternate test instruments.
Independent Verification by 2.46 SRO REVIEW ALL calculations and CONFIRM correct.
Reviewed and confirmed by:
2.47 RECORD and REVIEW required trend data.
Recorded and reviewed by:
2.48 IF trend graphs are available, THEN ATTACH copies of graphs.
2.49 UPDATE plant risk software to reflect final SW system alignments (including SW Pump P-4B power alignment).
PAGE: 322 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 20 OF 27 3.0 ACCEPTANCE CRITERIA 3.1 RECORD Stopwatch information:
DES #: 041S Cal Due Date DES#: 05/ Cal Due Date 3.2 COMPARE Measured Values/Stroke Times with Acceptable Normal Range and Limiting Value for Operability.
3.3 IDENTIFY if Measured Value/Stroke Time is within Limiting Value for Operability.
3.4 if alternate test instrument is used for discharge pressure, THEN RECORD alternate test instrument info below:
M&TE # iLl/A Cal Due Date 3.5 COMPARE measured values observed during P-4A testing with Acceptable Normal Range and Limiting Value for Operability.
I 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM PAGE: 323 of 551 CHANGE: 120 L
SUPPLEMENT I PAGE 21 OF 27 TABLE 2 Test Quantity Instrument Measured Acceptable Limiting Range Is Data Within Values Normal Range For Operability Limiting Range SW Loop I Press Alt Test_Inst 7$. 6 psig N/A N/A N/A P 1-3608 L psig SW Loop I Flow Anst tJ2 N/A N/A N/A SPD A SW Bay Level Callevel 33, LI feet N/A > 332 feet Suction Press Cled N/A N/A N/A tion_Pres Local Discharge Press Local P1-361 ltrestmf N/A N/A N/A psig Table 2 data gathered by: initial date TABLE 3 Test quantity Measured Acceptable I Limiting Range Is Data Within Values Normal Range For Operability Limiting Range?
Actual Pump Duff Press Acceptable Normal and Limiting Range (APA) values are per P-4A Pump Curve YES NO Baseline Pump Duff Press (APe)
N/A N/A N/A psi P-4A Deviation From Baseline psi N/A N/A N/A Table 3 data gathered by: initial date TABLE 4 Test Quantity Measured Acceptable Limiting Range Is Data Within Instrument Values Normal Range For Operability Limiting Range Mtr Upper Brg TE-3651 Temp (P1284 or TR-3651) il/A °F <180°F N/A N/A MtrLowerBrg TE-3652 Temp (P1285 or TR-3651) °F <180°F N/A N/A Table 4 data gathered by: initial dZ
PAGE: 324 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 22 OF 27 Vibrometer M&TE # Cal Due Date TABLE 5 Test Quantity Measured Acceptable Limiting Range Is Data Within Location Values Normal Range For Operability Limiting Range?
Motor Radial Point 1 on Upper Brg Vib Motor Map <0.287 in/sec <0.69 in/sec YES NO in/sec Motor Radial Point 2 on Upper Brg Vib Motor Map <0.325 in/sec <0.7 in/sec YES NO in/sec Motor Axial Point 3 on Upper Brg Vib Motor Map <0.242 in/sec <0.582 in/sec YES NO in/sec Table 5 data gathered by: initial date TABLE 6 Test Limiting Value (V) If Within Limiting Valve Initial Date Direction For Operability Range Full stroke confirmed by SW-lA Open SWLooplflow (J S600gpm SW-lA Closureconfirmedby Closed P-4A pump_shaft_stopping TABLE 7 Measured Acceptable Limiting Test (v) If within Valve DES# Stroke Time Normal Range Value for Initial Date Direction Limiting Value (nearest 1/10 sec) (sec) Operability SG-3 Close sec 151.8 205.4
- 232.2 (J SG-1 Close sec 151.2 204.5
- 231.2 (J SG-5 Open sec 147.7 - 199.9 225.9 (____
TABLE 8 Test Quantity I Instrument I Measured Values I Acceptable I Limiting Range Normal Range For Operability Is Data Within Limiting Range A SW Bay SPDS/ I I I I
feet N/A N/A N/A Level on ECP Alt Test Inst I Table 8 data gathered by: initial date
PAGE: 325 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 23 OF 27 TABLE 9 Test Measured Acceptable Limiting Valve DES# Normal Range If within Direction Stroke Time Value for Initial Date (nearest 1/10 sec) Limiting (sec) Operability Value SG-5 Close sec 147.1 - 199.0 225.0 SG-1 Open sec 154.0-208.2 235.4 (__j SG-3 Open sec 157.9-213.7 241.5 (..J CV-3644 Open sec 48.0 64.8
- 73.3 (__)
CV-3646 Open sec 39.2 53.0
- 59.9 (__J 3.6 IF NO is circled in Table 2, 3 or 5, THEN:
- DECLARE P-4A inoperable.
- NOTIFY the Shift Manager.
- INITIATE a Condition Report.
- INITIATE corrective action.
- REFERENCE Tech Spec for applicable conditions.
3.7 i.E ANY measured value in Table 2, 3, 4 or 5 does NOT fall within the Acceptable Normal Range, THEN INITIATE corrective action.
PAGE: 326 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 24 OF 27 3.8 E measured value is outside Limiting Value/Range in Table 1, 6, 7, or 9, THEN:
- DECLARE that valve inoperable.
- NOTIFY Shift Manager.
- INITIATE a Condition Report.
- INITIATE corrective action.
- REFERENCE Tech Spec for applicable conditions.
3.9 IF ANY measured stroke time does QI fall within the Acceptable Normal Range, THEN:
3.9.1 Immediately RETEST valve or DECLARE valve inoperable.
3.9.2 REFER TO Appendix A, Operability of this procedure for additional guidance.
Performed by: Print Name Signature Initial Date
PAGE: 327 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 25 OF 27 P-4A Pump Curve 115 Baseline iting 110
- Aceptable Normal Range Limiting Range 105 Comprehensive Limit 100 95 90 NN 0
a 85 rtingj I Range I NNN E
a-80 75 70 EEEEEEIEE 65 4ç 60 55 z::z:::::z::z:::::::N 50 4000 4500 5000 5500 6000 6500 7000 7500 Pump Flow (gpm)
PAGE: 328 of 551 1 104029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 26 OF 27 Motor Map (3)
Motor Upper Bearing Axial (2)
Motor Upper Bearing Radial (1)
Motor Upper Bearing Radial In
\\\ /
//
POINT VELOCITY Data Collected By NO (in/sec)
Date I
2 Vibrometer M&TE #
Calibration Due Date 3
PAGE: 329 of 5 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 27 OF 27 4.0 SUPERVISOR REVIEW AND ANALYSIS (circle one) 4.1 Do all measured values recorded in the Acceptance Criteria fall within the specified Limiting Range/Value For Operability? YES NO 4.2 Do all measured values recorded in the Acceptance Criteria section fall within the Acceptable Normal Range?
(CIRCLE N/A if the only values outside the Acceptable Normal range are also outside the Limiting RangeNalue for Operability) YES NO N/A 4.3 IF NO is answered to 4.1, THEN PERFORM the following corrective actions:
- ENSURE LCO Tracking Record is completed.
- ENSURE Condition Report initiated.
4.4 IF NO is answered to 4.2, THEN PERFORM the following corrective actions:
- ENSURE Condition Report has been initiated.
- COMPLETE 1000.009A, Surveillance Test Program Revision Request to raise the test frequency.
For pumps: The test frequency shall be doubled.
For valves: The test frequency is monthly.
4.5 IF answer to either 4.1 or 4.2 is NO, THEN DESCRIBE the action taken below:
4.6 Has this equipment been proven operable per the Acceptance Criteria? YES NO 4.7 Have all the administrative requirements of this test been satisfied (i.e., all initial blocks initialed or marked N/A, all data entered, cal due dates listed, applicable signature spaces signed, etc.)? YES NO Supervisor Date
Page 1 of 5 A1JPM-RO-ADMIN-RWP3 UNIT: 1 REV # 2 DATE: ______________________________
JPM ID: A1JPM-RO-ADMIN-RWP3 SYSTEM/DUTY AREA: ADMINISTRATIVE TOPIC - Radiation Control TASK: Ability to comply with radiation work permit requirements JTA#: ANO1-RO-DHR-NORM-2 KA VALUE RO: 3.5 SRO: 3.6 KA
REFERENCE:
2.3.7 APPROVED FOR ADMINISTRATION TO: RO: X SRO:
TASK LOCATION: INSIDE CR: OUTSIDE CR:_________ CLASSROOM: X SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE:_____________ SIMULATOR: Classroom: ________X_______
POSITION EVALUATED: RO:____X______ SRO:___________
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE:______ Classroom:__X___
TESTING METHOD: SIMULATE:_________ PERFORM:___X________
APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): RWP 2020-1002, P-34A survey map, EXAMINEE'S NAME:_______________________________ Logon ID: ___________________
EVALUATOR'S NAME:__________________________________________________________________
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY:________________ UNSATISFACTORY:_________________
PERFORMANCE CHECKLIST COMMENTS:
____________ Start Time ____________ Stop Time ____________ Total Time SIGNED __Robert Possage ______________________________ DATE: _______________________
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
Page 2 of 5 A1JPM-RO-ADMIN-RWP3 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed per NUREG 1021 Appendix E.
INITIAL PLANT CONDITIONS
- Decay Heat Removal Pump P-34A has indications of a leak on the pump inboard seal.
- The SM/CRS has directed you to quantify the leakage from the P-34A seal.
- This is NOT an emergency
- Your total dose for the year is currently 1950 mrem.
- You are a qualified CAT 3 Advanced Rad Worker.
- RWP, 20201002 Task 1 governs the planned activity TASK STANDARD:
Using the above information, applicant determined:
- Remaining available dose is 50 mR
- MAXIMUM stay time at the P-34A pump inboard seal area is 10.0 minutes. (8-10 minutes are acceptable)
- Required protective clothing requirements are single set of anti-Cs.
TASK PERFORMANCE AIDS: RWP 2020-1002, P-34A survey map .
SIMULATOR SETUP: NA
Page 3 of 5 A1JPM-RO-ADMIN-RWP3 INITIATING CUE:
Use the attached RWP, 2020-1002 Task 1.
Using the above information, determine the MAXIMUM stay time at the P-34A pump inboard seal area for the WCO entry.
(C) PERFORMANCE STEP PERFORMANCE STANDARD SAT UNSAT N/A
- 1. Reviews P-34A Pump survey Examinee determined dose rate of map to determine dose rates in 115 mR/hr at the inboard pump seal.
the vicinity of the inboard pump seal. _____ _____ _____
(C) 2. Determines remaining Examinee determined remaining allowable dose. allowable dose is 50 mR 2000 mR - 1950 mR = 50 mR (C) 3. Determines stay time based on Examinee determined stay time the given dose in the pump based on RWP limits of 20 mrem inboard seal area not to would allow him to stay at the pump exceed the RWP limits. inboard seal area for 10.0 minutes (8 - 10 minutes).
20 mR X 60 min = 10.0 minutes 120 mR/hr 1 hr (C) 4. Reviews P-34A Pump survey Examinee identified the map for contamination smear contamination levels are > 1000 data to determine the dpm/100 cm 2 but less than 100,000 _____ _____ _____
protective clothing (PC) dpm/100 cm 2; therefore, a single set requirements for this task. of Anti-Cs is required to enter into the P-34A pump room.
END
Page 4 of 5 A1JPM-RO-ADMIN-RWP3 ANSWER KEY JPM INITIAL TASK CONDITIONS:
- Decay Heat Removal Pump P-34A has indications of a leak on the pump inboard seal.
- The SM/CRS has directed you to quantify the leakage from the P-34A seal.
- Your total dose for the year is currently 1950 mrem.
- You are a qualified CAT 3 Advanced Rad Worker.
INITIATING CUE:
Refer to the attached RWP, 20201002 Task 1 and the P-34A pump room survey map.
Using the above information, determine:
- Your remaining available dose for the year based on ANO administrative limits.
2000 mrem - 1950 mrem = 50 mrem remaining
- Your MAXIMUM stay time at the P-34A pump inboard seal area.
20 mR X 60 min = 10.0 minutes (8-10 minutes) (C) 120 mR/hr 1 hr
- Your Protective Clothing requirements:
Single set of Anti-Cs (C)
Page 5 of 5 A1JPM-RO-ADMIN-RWP3 EXAMINEES COPY JPM INITIAL TASK CONDITIONS:
- Decay heat Removal Pump P-34A has indications of a leak on the pump inboard seal.
- The SS/CRS has directed you to quantify the leakage from the P-34A seal.
- This is NOT an emergency
- Your total dose for the year is currently 1950 mrem.
- You are a qualified CAT 3 Advanced Rad Worker.
INITIATING CUE:
Refer to the attached RWP, 20201002 Task 1 and the P-34A pump room survey map.
Using the above information, determine:
- Your remaining available dose for the year based on ANO administrative limits.
- Your MAXIMUM stay time at the P-34A pump inboard seal area.
- Your Protective Clothing requirements:
Survey: ANO-1606-0004 ANO Thursday, June 30, 2016 Template: 1a1-05_jpg Page 1 of 1 Details Smear Data (DPM/100cm2) 1 20000 DPM Unit: 1 2 25000 DPM Building: RAB 3 30000 DPM Elevation: 317 4 35000 DPM Room: 13 RxPwr: 100 LAS Data (ccpm/LAS)
Template: 1a1-05_jpg 1 6000 ccpm/LAS Frequency: 10CFR50.75G Decomm 2 <100 ccpm/LAS Survey Date: 08/22/2016 3/25/202015:58 3 <100 ccpm/LAS Status: In-Progress 4 <100 ccpm/LAS Rwp: 20161001 20201002 B/G to Alpha Ratio Hydro Inj Rate: NA Surveyed By: Harrell, John Alpha Data (DPM/100cm2) Badge: 20970 Reviewed By:
DPM Notes:
Instruments Used Instrument: LM-177 CHP-CR-148 100 Cal Due Date: 5/31/2020 7/31/2016 SrcChk Date: 6/29/2016 4/30/2020 DC & Bkg: NA NA MDA: NA 120 Instrument: 9-3 CHP-DR-331 120 Cal Due Date: 12/31/2016 5/31/2020 SrcChk Date: 4/30/2020 6/29/2016 DC & Bkg: NA NA MDA: NA 105
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP
Title:
OPERATIONS ACTIVITIES UNIT-1 (Bulk Work) RWP No.:
20201002 Rev. 00 Comments:
- 20201002*
RWP Type: GENERAL RWP Status: Begin Date: Close On Date:
ACTIVE 1/1/2020 12/31/2020 Prepared By: KOWALEWSKI, JACOB J Job Supervisor: Unit 1 Operations Shift Supervisor Estimated Dose: Estimated Hours: Actual Dose: Actual Hours:
900 mrem 14,500.00 39 mrem 494.46 Locations Buildings Elevations Rooms LOW LEVEL RADWASTE BUILDING 354 NON-LOCKED HIGH RADIATION AREA OLD RADWASTE BUILDING 354 NON-LOCKED HIGH RADIATION AREA OUTSIDE CONTROLLED ACCESS ALL OUTSIDE CONTROLLED ACCESS UNIT 1 AUXILIARY BUILDING ALL NON-LOCKED HIGH RADIATION AREA Radiological Conditions Description Value Unit Smear data is in dpm/100 cm2 unless otherwise noted. <1K - 40K DPM/100CM2 General area gamma dose rates are in mrem/hour unless otherwise noted. 0.2 - 200 MILLIREM/HOUR Tasks Task Description Status 1 OPERATIONS ACTIVITIES UNIT-1 Active 2 OPERATIONS TRAINEE ACTIVITIES UNIT-1 Active Requirements Requirement Groups Requirement Descriptions N/A Additional Instructions Instruction 1:
Instruction 2:
Instruction 3:
Approvals Approver Title Name Date ALARA REVIEW KOWALEWSKI, JACOB J 12/04/2019 RWP PREPARER LAQUE, NICHOLAS J 12/03/2019 RP SUPERVISOR FOLEY, CHRISTOPHER J 12/05/2019 Attachments N/A 1/13/2020 3:03:32PM Page 1 of 7
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP No.: 20201002 Task Number: 1 Rev.: 00 Task
Description:
OPERATIONS ACTIVITIES UNIT-1 Task Status: Active Estimate Dose: 850.00 Estimate Hours: 13,500.00 Hot Particle: Hi-Contamination:
Hi-Rad: Yes Yes Locked Hi-Rad: No Yes Alarm Settings Dose Alarm (mrem) 20.00 Dose Rate (mrem/hr) 200.00 Requirements Requirement Groups Requirement Descriptions Contamination Control All materials are required to be surveyed in a small articles monitor or hand frisked by RP (with RP Supervisor approval) PRIOR TO unconditional release from a Radiologically Controlled Area.
IF the RCA is a satellite RCA with no whole body contamination monitor available, THEN the radworker should: a) perform a hand and foot frisk. b) IF the frisk indicates contamination is present, THEN contact RP. c) IF the frisk DOES NOT indicate the presence of contamination, THEN proceed to the nearest whole body contamination monitor and gamma sensitive monitor.
If the RCA is a satellite RCA, and a "Contamination Area" is entered, the radworker will perform a whole body frisk. The radworker must then clear ARGOS (or PCM-1B) AND GEM-5 (or PM-7).
Notify RP prior to exposing a contaminated surface or opening a contaminated system.
Obey the monitoring instructions posted at the RCA exit point Upon exit of an RCA, whole body monitoring is required utilizing a whole body contamination monitor (ARGOS or equivalent). A whole body gamma monitor must also be cleared (GEM 5 or equivalent).
Upon exiting areas posted as "Contamination Area", perform a hand and foot frisk at the designated frisker location.
Use RP approved mats or pads when kneeling, sitting or laying in contaminated areas.
Use face shield for activities that have increased risk of facial contamination. These activities include working with contaminated components overhead, or having a body position that presents the potential for facial contamination.
With RP approval, reaching across a contamination boundary is permitted using surgeon's gloves OR cotton liners with rubber gloves. When reaching into the area of higher contamination, gloves must be removed when hands are returned to the lower level side of the boundary.
Dosimetry Requirements FOR WORK IN HIGH RADIATION AREAS - If your work conditions are in OR will cause hearing impairment (such as work in a high noise area, use of a communications headset, etc.) THEN the use of an SRD amplifying device (PAM) is required.
If an SRD dose alarm occurs: 1) Secure Work. 2) Immediately leave the RCA. 3)
Notify RP.
If an SRD dose rate alarm occurs: 1) Secure Work. 2) Back out of the immediate area until the alarm clears. 3) Notify others in your work crew. 4) Immediately notify RP for further instructions.
Periodically check your SRD. This check should be performed more frequently in areas where your ability to hear is diminished.
Whole body DLR and SRD required for entry.
1/13/2020 3:03:32PM Page 2 of 7
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP No.: 20201002 Task Number: 1 Rev.: 00 Requirements Requirement Groups Requirement Descriptions Engineering Controls Consider having a HEPA Ventilation unit or HEPA vacuum in service prior to the start of a potential airborne radioactivity causing evolution.
When venting or draining, monitor the rate of system drain to ensure the rate of drain does NOT exceed the capacity of the floor drain.
Refer to TEDE Screening Document for guidance concerning contamination levels and confinement factors necessary to maintain airborne radioactivity levels <30% DAC.
Surface wetting, misting, or encapsulation should be considered to reduce the risk of airborne radioactivity.
Exposure Reduction Minimize crew size to reduce overall exposure for the job.
Move components to a low dose area for work when practical.
Use Low Dose Waiting Areas whenever possible to minimize exposure.
Remove unnecessary personnel from affected areas when moving material with dose rates of concern.
Protective Requirements Entry into Contamination Areas require single Anti-Cs.
Entry into High Contamination Areas require double Anti-Cs .
The outer layer of protective clothing is to be water repellent when working with water or wet components.
With RP approval prior to each entry, partial Protective Clothing (booties, rubber shoe covers, cotton liners, and rubber gloves) may be worn in lieu of a full set of PCs to access a Contamination Area (CA) where the known contamination is less than or equal to 10,000 dpm / 100 cm2. Any activities that require kneeling, sitting, climbing, or leaning against surfaces will require the use of full PCs.
RP Coverage Entry into High Radiation Areas requires a radiological brief from RP, AND an electronic alarming dosimeter (SRD) to meet Tech Spec monitoring requirements.
Notify RP when performing operations activities which could change plant radiological conditions. For example venting/draining radioactive systems, performing degas or decay heat/shutdown cooling operations, or other non routine system functions.
Radiation Worker Self-Briefing - WHEN the following conditions are met, THEN the worker may enter the RCA without directly interfacing with RP (the following radiological conditions must be true): 1) dose rate in work area and travel path <25 mrem/hr and area is not posted HRA 2) work area contamination levels are <10K dpm/100 cm2 AND area is not posted HCA 3) work is not in Alpha Level 2 or 3 area 4 area is not posted Airborne Radioactivity Area 5) access above 7' above floor is not required 6) work is not abrasive (cutting, welding, grinding etc) 7) work does not involve movement of radioactive material from RA, HRA, or LHRA 8) no opening of contaminated containers 9) no breach of contaminated systems 10) The work does not involve system operation, such as opening a valve that may allow radioactive material transfer through a pipe. ***If any of the Self-Brief criteria cannot be met, THEN, contact RP prior to starting work.***
Radiological Conditions Dose rates may increase as the water level is lowered.
Radiological conditions should be reviewed to ensure awareness of conditions in your work area. This information can be obtained from either a Status Board or RP personnel.
RP should monitor for dose gradients and relocate dosimetry as necessary using guidance from EN-RP-204. Contact ALARA if relocation is warranted.
Respiratory Protection Based on historical and current data, the airborne radioactivity is less than 30 percent of a DAC. Respiratory protection is not required unless otherwise directed by RP Supervision.
1/13/2020 3:03:32PM Page 3 of 7
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP No.: 20201002 Task Number: 1 Rev.: 00 Requirements Requirement Groups Requirement Descriptions Special Radiological Requirements The prerequisite for a secondary resin transfer include 1) Secure the fill head such that changes in pressure will not cause a spill. 2) Conduct a walkdown (pre-transfer) to ensure that hose connections and leak integrity is satisfactory. 3) Construct a berm sufficient to contain the material being transferred.
Stop Work Criteria Critical Step - If UNEXPECTED alpha contamination > or equal to 500 dpm/100cm2 is detected, Then stop work and follow the guidance in EN RP 122.
Critical Step - Indications either from local samples or remote indication (CAM) of airborne radioactivity in quantities in excess of 30 percent of a DAC.
Critical Step - Loss of control of radioactive material such that loose surface contamination exceeds area postings.
Critical Step - RWP package contains TEDE Screening. Inability to remain within the bounds for contamination levels and confinement factors (specified in the TEDE Screening) will require that work be stopped.
Critical Step - Radiation dose rates in the immediate area are greater than the SRD dose rate alarm set point.
Additional Instructions Instruction 1:
Instruction 2:
Instruction 3:
Instruction 4:
Instruction 5:
Attachments N/A 1/13/2020 3:03:32PM Page 4 of 7
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP No.: 20201002 Task Number: 2 Rev.: 00 Task
Description:
OPERATIONS TRAINEE ACTIVITIES UNIT-1 Task Status: Active Estimate Dose: 50.00 Estimate Hours: 1,000.00 Hot Particle: Hi-Contamination:
Hi-Rad: Yes Yes Locked Hi-Rad: No Yes Alarm Settings Dose Alarm (mrem) 15.00 Dose Rate (mrem/hr) 150.00 Requirements Requirement Groups Requirement Descriptions Contamination Control All materials are required to be surveyed in a small articles monitor or hand frisked by RP (with RP Supervisor approval) PRIOR TO unconditional release from a Radiologically Controlled Area.
IF the RCA is a satellite RCA with no whole body contamination monitor available, THEN the radworker should: a) perform a hand and foot frisk. b) IF the frisk indicates contamination is present, THEN contact RP. c) IF the frisk DOES NOT indicate the presence of contamination, THEN proceed to the nearest whole body contamination monitor and gamma sensitive monitor.
If the RCA is a satellite RCA, and a "Contamination Area" is entered, the radworker will perform a whole body frisk. The radworker must then clear ARGOS (or PCM-1B) AND GEM-5 (or PM-7).
Notify RP prior to exposing a contaminated surface or opening a contaminated system.
Obey the monitoring instructions posted at the RCA exit point Upon exit of an RCA, whole body monitoring is required utilizing a whole body contamination monitor (ARGOS or equivalent). A whole body gamma monitor must also be cleared (GEM 5 or equivalent).
Upon exiting areas posted as "Contamination Area", perform a hand and foot frisk at the designated frisker location.
Use RP approved mats or pads when kneeling, sitting or laying in contaminated areas.
Use face shield for activities that have increased risk of facial contamination. These activities include working with contaminated components overhead, or having a body position that presents the potential for facial contamination.
With RP approval, reaching across a contamination boundary is permitted using surgeon's gloves OR cotton liners with rubber gloves. When reaching into the area of higher contamination, gloves must be removed when hands are returned to the lower level side of the boundary.
Dosimetry Requirements FOR WORK IN HIGH RADIATION AREAS - If your work conditions are in OR will cause hearing impairment (such as work in a high noise area, use of a communications headset, etc.) THEN the use of an SRD amplifying device (PAM) is required.
If an SRD dose alarm occurs: 1) Secure Work. 2) Immediately leave the RCA. 3)
Notify RP.
If an SRD dose rate alarm occurs: 1) Secure Work. 2) Back out of the immediate area until the alarm clears. 3) Notify others in your work crew. 4) Immediately notify RP for further instructions.
Periodically check your SRD. This check should be performed more frequently in areas where your ability to hear is diminished.
Whole body DLR and SRD required for entry.
1/13/2020 3:03:32PM Page 5 of 7
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP No.: 20201002 Task Number: 2 Rev.: 00 Requirements Requirement Groups Requirement Descriptions Engineering Controls Consider having a HEPA Ventilation unit or HEPA vacuum in service prior to the start of a potential airborne radioactivity causing evolution.
When venting or draining, monitor the rate of system drain to ensure the rate of drain does NOT exceed the capacity of the floor drain.
Refer to TEDE Screening Document for guidance concerning contamination levels and confinement factors necessary to maintain airborne radioactivity levels <30% DAC.
Surface wetting, misting, or encapsulation should be considered to reduce the risk of airborne radioactivity.
Exposure Reduction Minimize crew size to reduce overall exposure for the job.
Move components to a low dose area for work when practical.
Use Low Dose Waiting Areas whenever possible to minimize exposure.
Remove unnecessary personnel from affected areas when moving material with dose rates of concern.
Protective Requirements Entry into Contamination Areas require single Anti-Cs.
Entry into High Contamination Areas require double Anti-Cs .
The outer layer of protective clothing is to be water repellent when working with water or wet components.
With RP approval prior to each entry, partial Protective Clothing (booties, rubber shoe covers, cotton liners, and rubber gloves) may be worn in lieu of a full set of PCs to access a Contamination Area (CA) where the known contamination is less than or equal to 10,000 dpm / 100 cm2. Any activities that require kneeling, sitting, climbing, or leaning against surfaces will require the use of full PCs.
RP Coverage Entry into High Radiation Areas requires a radiological brief from RP, AND an electronic alarming dosimeter (SRD) to meet Tech Spec monitoring requirements.
Notify RP when performing operations activities which could change plant radiological conditions. For example venting/draining radioactive systems, performing degas or decay heat/shutdown cooling operations, or other non routine system functions.
Radiation Worker Self-Briefing - WHEN the following conditions are met, THEN the worker may enter the RCA without directly interfacing with RP (the following radiological conditions must be true): 1) dose rate in work area and travel path <25 mrem/hr and area is not posted HRA 2) work area contamination levels are <10K dpm/100 cm2 AND area is not posted HCA 3) work is not in Alpha Level 2 or 3 area 4 area is not posted Airborne Radioactivity Area 5) access above 7' above floor is not required 6) work is not abrasive (cutting, welding, grinding etc) 7) work does not involve movement of radioactive material from RA, HRA, or LHRA 8) no opening of contaminated containers 9) no breach of contaminated systems 10) The work does not involve system operation, such as opening a valve that may allow radioactive material transfer through a pipe. ***If any of the Self-Brief criteria cannot be met, THEN, contact RP prior to starting work.***
Radiological Conditions Dose rates may increase as the water level is lowered.
Radiological conditions should be reviewed to ensure awareness of conditions in your work area. This information can be obtained from either a Status Board or RP personnel.
RP should monitor for dose gradients and relocate dosimetry as necessary using guidance from EN-RP-204. Contact ALARA if relocation is warranted.
Respiratory Protection Based on historical and current data, the airborne radioactivity is less than 30 percent of a DAC. Respiratory protection is not required unless otherwise directed by RP Supervision.
1/13/2020 3:03:32PM Page 6 of 7
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP No.: 20201002 Task Number: 2 Rev.: 00 Requirements Requirement Groups Requirement Descriptions Special Radiological Requirements The prerequisite for a secondary resin transfer include 1) Secure the fill head such that changes in pressure will not cause a spill. 2) Conduct a walkdown (pre-transfer) to ensure that hose connections and leak integrity is satisfactory. 3) Construct a berm sufficient to contain the material being transferred.
Stop Work Criteria Critical Step - If UNEXPECTED alpha contamination > or equal to 500 dpm/100cm2 is detected, Then stop work and follow the guidance in EN RP 122.
Critical Step - Indications either from local samples or remote indication (CAM) of airborne radioactivity in quantities in excess of 30 percent of a DAC.
Critical Step - Loss of control of radioactive material such that loose surface contamination exceeds area postings.
Critical Step - RWP package contains TEDE Screening. Inability to remain within the bounds for contamination levels and confinement factors (specified in the TEDE Screening) will require that work be stopped.
Critical Step - Radiation dose rates in the immediate area are greater than the SRD dose rate alarm set point.
Additional Instructions Instruction 1:
Instruction 2:
Instruction 3:
Instruction 4:
Instruction 5:
Attachments N/A 1/13/2020 3:03:32PM Page 7 of 7
ADMINISTRATIVE JOB PERFORMANCE MEASURE A1JPM-SRO-RBAL3 Page 1 of 6 UNIT: 1 REV # 1 DATE: ______________________________
TUOI NUMBER: ANO-1-JPM-RO-RBAL3 SYSTEM/DUTY AREA: ADMINISTRATIVE TOPIC - CONDUCT OF OPERATIONS TASK: ESTIMATE BORON CONCENTRATION REQUIRED TO MAINTAIN SHUTDOWN MARGIN DURING COOLDOWN USING RHOBAL PROGRAM JTA#: ANO1-RO-OPROC-NORM-70 KA VALUE RO: 4.1 SRO: 4.3 KA
REFERENCE:
2.1.43 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR: OUTSIDE CR:_________ BOTH:____X____
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE:_______________ SIMULATOR: CLASS ROOM:__PERFORM___
POSITION EVALUATED: RO:___ ___ SRO:____X____
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE:____ CLASS ROOM:__X___
TESTING METHOD: SIMULATE:_________ PERFORM:___X______
APPROXIMATE COMPLETION TIME IN MINUTES: 10 MINUTES REFERENCE(S): 1103.015, Rev. 061 EXAMINEE'S NAME:________________________________ LOGON ID ____________________
EVALUATOR'S NAME:__________________________________________________________________
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY:________________ UNSATISFACTORY:_________________
PERFORMANCE CHECKLIST COMMENTS:
____________ Start Time ____________ Stop Time ____________ Total Time SIGNED _Robert Possage_______________________________ DATE: _______________________
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
ADMINISTRATIVE JOB PERFORMANCE MEASURE A1JPM-SRO-RBAL3 Page 2 of 6 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS: The plant is preparing for shutdown prior to a refueling outage. EFPD = 475. RCS Tave = 555°F. APSR at 0%. Desired final RCS Tave = 185°F Cooldown is scheduled to commence later today.
TASK STANDARD: The examinee has calculated the minimum required Boron concentration to maintain shutdown margin during cooldown using RHOBAL and determined the value to be between 615 to 645 ppm and therefore disagreed with the ROs calculation.
TASK PERFORMANCE AIDS: Personal computer with RHOBAL program available.
ADMINISTRATIVE JOB PERFORMANCE MEASURE A1JPM-SRO-RBAL3 Page 3 of 6 INITIATING CUE:
As Control Room Supervisor verify the Minimum Required Boron concentration as determined by your RO in order to maintain shutdown margin during cooldown using 1103.015, Reactivity Balance Calculation and the RHOBAL program.
(C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNS AT NOTE: Examinee may start in the Poison menu or in the Shutdown Margin menu.
Either way, the examinee must establish a power history.
(C) 1. Activate Shutdown Margin Clicked (or Alt S via keyboard) on pull down menu. on Shutdown Margin in menu ____ ____ ____
bar.
(C) 2. Run program to determine Performed the following Boron concentration required actions:
to maintain shutdown margin.
during Cooldown or Heatup.
- Entered 475 for Cycle Burnup in EFPD.
- Entered 0 for all CRA positions.
- Entered 555 for RCS Average Temperature in degrees F.
- Entered 185 for Final Desired RCS Average Temperature in degrees F.
NOTE: Step 3 may be performed prior to step 1 via the Poison menu.
ADMINISTRATIVE JOB PERFORMANCE MEASURE A1JPM-SRO-RBAL3 Page 4 of 6 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNS AT
- 3. Activate Xenon and Clicked (or Alt P via keyboard)
Samarium menu. on Xenon and Samarium in ____ ____ ____
menu bar.
- 4. Enter power history. Performed the following actions: ____ ____ ____
- Entered 100% Power Level
- Entered 475 for Burnup
- Clicked on At power equilibrium concentrations.
- Clicked on INITIALIZE POISONS button.
(C) 5. Determine required Boron Noted the required Boron conc concentration. from Table or Figure B6 to be ____ ____ ____
631.
Accept 615 to 645.
(C) 6. Determine that the RO was Disagreed with the calculated incorrect in his calculations. value of 561 ppmB. ____ ____ ____
END
ADMINISTRATIVE JOB PERFORMANCE MEASURE A1JPM-SRO-RBAL3 Page 5 of 6 KEY JPM INITIAL TASK CONDITIONS:
- The plant is preparing for startup after a refueling outage.
- EFPD = 475
- RCS Tave = 555°F
- Final RCS Tave = 185°F
- APSR are at 0%
- Cooldown is scheduled to commence later today.
- The RO has calculated a Minimum Required boron concentration of 561 ppm to maintain shutdown margin during cooldown.
INITIATING CUE:
As Control Room Supervisor verify the Minimum Required Boron concentration as determined by your RO in order to maintain shutdown margin during cooldown using 1103.015, Reactivity Balance Calculation and the RHOBAL program.
What is the Minimum Required Boron concentration to maintain shutdown margin during cooldown?
____631 (615 - 645)___ ppmB Do you AGREE or DISAGREE with your ROs calculated value? (Circle one)
ADMINISTRATIVE JOB PERFORMANCE MEASURE A1JPM-SRO-RBAL3 Page 6 of 6 EXAMINEES COPY JPM INITIAL TASK CONDITIONS:
- The plant is preparing for startup after a refueling outage.
- EFPD = 475
- RCS Tave = 555°F
- Final RCS Tave = 185°F
- APSR are at 0%
- Cooldown is scheduled to commence later today.
- The RO has calculated a Minimum Required boron concentration of 561 ppm to maintain shutdown margin during cooldown.
INITIATING CUE:
As Control Room Supervisor verify the Minimum Required Boron concentration as determined by your RO in order to maintain shutdown margin during cooldown using 1103.015, Reactivity Balance Calculation and the RHOBAL program.
What is the Minimum Required Boron concentration to maintain shutdown margin during cooldown?
_______________ ppmB Do you AGREE or DISAGREE with your ROs calculated value? (Circle one)
A1JPM-SRO-TTB PAGE 1 OF 14 UNIT: 1 REV #: 2 DATE:
SYSTEM/DUTY AREA: Conduct of Operations TASK: Review Time to Boil and Time to Core Uncovery Calculations JTA#: ANO1-SRO-DHR-NORM-204 KA VALUE RO: 3.9 SRO: 4.2 KA
REFERENCE:
2.1.25 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR: OUTSIDE CR: X BOTH:
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: Classroom: Perform POSITION EVALUATED: RO: SRO: X ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: Classroom: X TESTING METHOD: SIMULATE: PERFORM: X APPROXIMATE COMPLETION TIME IN MINUTES: 20 Minutes REFERENCE(S): 1015.002 EXAMINEE'S NAME: Logon EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Stop Total Time Time Time SIGNED: Robert Possage DATE:
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
A1JPM-SRO-TTB PAGE 2 OF 14 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS:
Plant shutdown for refueling.
RCS level is being drained to 376 in preparation for Reactor head removal.
Time after shutdown = 65 hours7.523148e-4 days <br />0.0181 hours <br />1.074735e-4 weeks <br />2.47325e-5 months <br />.
Both OTSG primary manways are removed.
Nozzle dams are NOT installed.
RCS Temperature is 120°F.
Plant computer is inoperable due to power supply maintenance.
TASK STANDARD:
SRO identified the following errors:
- 1) In step 3.1, used Figure 2A and determined Uncorrected Time to Boil is 23 minutes
- 2) In step 3.2, used Figure 2A and determined Time to Boil is 28.8 - 31.0 minutes (29.9 +/- 1.1)
- 3) In step 4.2, used Figure 4A and determined time to core uncovery is 268.6 - 290.4 minutes (279.5 +/- 10.9)
- 3) In step 5.2, determined estimated heatup rate to be 2.84 - 3.32 °F/minute (3.08 +/- 0.24)
- 4) In step 6.0, determined makeup rate to be 65 to 75 gpm.
- 5) SRO did not confirm calculations TASK PERFORMANCE AIDS:
1015.002 and 1015.002B.
SIMULATOR SETUP:
NA EXAMINER'S NOTES:
A1JPM-SRO-TTB PAGE 3 OF 14 INITIATING CUE:
CRS directs you to perform time to boil and time to core uncovery calculations using 1015.002B, Calculation of Time to Boil/Core Uncovery Estimate, through step 6.0.
PERFORMANCE STEP PERFORMANCE STANDARD SAT UNSAT N/A NOTE The figures referred to in this form are the figures of, Graphs Used To Determine RCS Time to Boil/Core Uncovery Estimates, Attachment C of this procedure.
1.0 Reviewed the following data: Examinee reviewed the data using the initial conditions given (See key) on the Examinee Copy. (See ___ ___ ___
key) 2.0 2.1 Decay Heat Correction Examinee reviewed 1.0 in the Factor space provided since refueling ___ ___ ___
has not commenced per the initial Reviewed fraction of spent conditions. (See key) fuel assemblies in core______
(obtain from Reactor Engineering) (1.0 if prior to refueling) 2.2 Using Figure 1 of Attachment Examinee referred to Figure 1 C, Graphs Used To (Page 54 of 135) and determined ___ ___ ___
Determine RCS Time to based on 65 hours7.523148e-4 days <br />0.0181 hours <br />1.074735e-4 weeks <br />2.47325e-5 months <br /> after shutdown Boil/Core Uncovery (given in initial conditions) the Estimates, DETERMINE Correction Factor should be 1.3.
Decay Heat Correction Band of 1.28 - 1.32 Factor (See key)
NOTE NOTE Examinee determined the RCS is Step 5.8 in the definitions opens since the initial conditions section defines the RCS as stated both OTSG primary ___ ___ ___
OPEN if a Steam Generator manways are removed.
Primary Manway is removed and unobstructed by filter or ventilating devices.
(See key) 3.1 Using the appropriate figure from Attachment C, OBTAIN Examinee referred to Figure 2A C uncorrected Time to Boil. (Page 55 of 135) and recognized ___ ___ ___
that the uncorrected time to boil LOG uncorrected Time to should have been 23 rather than Boil: _____________ 18.
o (140 Fline gives the 18 value)
(See Key)
A1JPM-SRO-TTB PAGE 4 OF 14 PERFORMANCE STEP PERFORMANCE STANDARD SAT UNSAT N/A 3.2 Examinee multiplied 23 value (step 3.1.3) by 1.3 (step 2.2) and C Multiply by Decay Heat determined time to boil should be ___ ___ ___
Correction Factor from step 29.9 minutes rather than 23.4 2.2:
minutes (See key)
(See key) 28.8 - 31.0 minutes (29.9 +/- 1.1) 4.1 Examinee referred to Figure 4A Using the appropriate (Page 59 of 135) and determined C figure from Attachment C, based on 65 hours7.523148e-4 days <br />0.0181 hours <br />1.074735e-4 weeks <br />2.47325e-5 months <br /> after shutdown ___ ___ ___
OBTAIN uncorrected Time (given in initial conditions) the To Core Uncovery: Uncorrected Time to Core Uncovery RCS Open, RV Head On should be 215 minutes rather LOG uncorrected Time To than the 200 minutes.
Core Uncovery: __________
(Figure 4C gives the 200 value)
(See key)
(See key) 4.2 Multiply by Decay Heat Examinee multiplied 215 minutes C
Correction Factor from step (step 4.1.5) by 1.3 (step 2.2) and ___ ___ ___
2.2: determined time to core uncovery (See key) should be 279.5 minutes rather than 260 minutes.
(See key) 268.6 - 290.4 minutes (279.5 +/-
10.9) 5.1 Using Figure 6 of Attachment Examinee referred to Figure 6 C, DETERMINE uncorrected and determined the Uncorrected ___ ___ ___
heatup rate ______°F/min. RCS Heatup Rate should be 4.0 o
F/min.
5.2 Divide by Decay Correction Examinee divided 4 oF/min (step Factor from step 2.2: 5.1) by 1.3 (step 2.2) and (See key) determined heatup rate to be 3.08 ___ ___ ___
°F/minute.
(See key) 2.84 - 3.32 °F/minute (3.08 +/-
0.24) 6.0 Using Figure 7A or 7B of Examinee referred to Figure 7A Attachment C, RECORD (based on initial conditions giving required makeup rate: time after shutdown in hours) and
_________ gpm ___ ___ ___
determined makeup rate to be 68 gpm.
(See key) 65 to 75 gpm END
A1JPM-SRO-TTB PAGE 5 OF 14 A1JPM-SRO-TTB PAGE 6 OF 14 Applicant Copy CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 1 OF 4 1.0 RECORD the following data:
- Time after reactor shutdown ___ 65_____ hours or days (CIRCLE one)
- RCS level ___376___
- RCS Pressure ____0____
o
- RCS temperature __120 F___ (referred to as T1 on Att C figures) 2.0 Decay Heat Correction Factor 2.1 RECORD fraction of spent fuel assemblies in core __ 1.0_____
(fraction of spent fuel assemblies in core is obtained from Reactor Engineering or value of 1.0 is used if prior to refueling) 2.2 Using Figure 1 of Attachment C, Graphs Used To Determine RCS Time to Boil/Core Uncovery Estimates, DETERMINE Decay Heat Correction Factor :
Correction Factor Decay Heat Fraction of Spent Fuel =
Correction Factor Assemblies in Core
(___1.3____)
= __1.3_____
( 1.0 )
A1JPM-SRO-TTB PAGE 7 OF 14 CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 2 OF 4 NOTE
- Reactor Coolant System open is contained in the Definitions section of this procedure.
- If the status of the RCS (open or intact) is unknown the RCS will be considered open for Time to Boil determination.
3.0 Determining Time to Boil:
3.1 Using the appropriate figure from Attachment C, OBTAIN uncorrected Time to Boil.
3.1.1 IF RCS is open, THEN USE ONE of the following:
- Figure 2A for RCS temp 40°F to 140°F
- Figure 3A for RCS temp 40°F to 140°F
- Figure 3B for RCS temp 140°F to 300°F 3.1.3 LOG uncorrected Time to Boil: ___18______
3.2 MULTIPLY uncorrected Time to Boil by Decay Heat Correction Factor:
Uncorrected Time Decay Heat Time to boil in X =
to Boil in minutes Correction Factor minutes X =
(__18__) (__1.3__) __23.4___
A1JPM-SRO-TTB PAGE 8 OF 14 CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 3 OF 4 4.0 Determining Time To Core Uncovery:
4.1 Using the appropriate figure from Attachment C, OBTAIN uncorrected Time To Core Uncovery:
4.1.1 IF Incore Instrument guide tubes are breached AND RV Head is installed, THEN ASSUME a conservative initial RCS level of 369.5' and USE ONE of the following:
- Figure 4A for RCS temp 40°F to 140°F
- Figure 4B for RCS temp 140°F to 200°F 4.1.2 IF RCS is open with nozzle dams removed, THEN USE ONE of the following:
- Figure 4A for RCS temp 40°F to 140°F
- Figure 4B for RCS temp 140°F to 200°F 4.1.3 IF EITHER SG has nozzle dam installed, THEN USE ONE of the following:
- Figure 4C for RCS temp 40°F to 140°F
- Figure 5A for RCS temp 40°F to 140°F
- Figure 5B for RCS temp 140°F to 240°F
- Figure 5C for RCS temp 240°F to 340°F 4.1.5 LOG uncorrected Time To Core Uncovery: ____200______
4.2 MULTIPLY uncorrected Time To Core Uncovery by Decay Heat Correction Factor:
Uncorrected time to Decay Heat Time to Core Core Uncovery in X Correction Factor = Uncovery in minutes minutes
(_200_) X (_1.3__) = _260_
A1JPM-SRO-TTB PAGE 9 OF 14 CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 4 OF 4 5.0 Determining Time To Core Uncovery:
5.1 Using Figure 6 of Attachment C, DETERMINE uncorrected heatup rate
__4.0____°F/min.
5.2 DIVIDE by Decay Heat Correction Factor:
Uncorrected Heatup Rate Estimated Heatup
=
Decay Heat Correction Factor Rate in °F/min
(____4_______) =
( 1.3 ) ___3.08____
6.0 Using Figure 7A or 7B of Attachment C, RECORD required makeup rate: __68____ gpm 7.0 IF Time to Boil is significantly less than previous Time to Boil estimate AND in Mode 5 or 6, THEN REEVALUATE ANY containment closure estimates for ALL outstanding items on the Containment Closure Breach List.
8.0 UPDATE the Status Board with the new data.
Performed by _______________________________ Date __________ Time __________
Calculations Reviewed/
Confirmed by CRS or SM: _______________________ Date __________ Time ________
A1JPM-SRO-TTB PAGE 10 OF 14 KEY CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 5 OF 4 1.0 RECORD the following data:
- Time after reactor shutdown ___ 65_____ hours or days (CIRCLE one)
- RCS level ___376___
- RCS Pressure ____0____
o
- RCS temperature __120 F___ (referred to as T1 on Att C figures) 2.0 Decay Heat Correction Factor 2.1 RECORD fraction of spent fuel assemblies in core __ 1.0_____
(fraction of spent fuel assemblies in core is obtained from Reactor Engineering or value of 1.0 is used if prior to refueling) 2.2 Using Figure 1 of Attachment C, Graphs Used To Determine RCS Time to Boil/Core Uncovery Estimates, DETERMINE Decay Heat Correction Factor :
Correction Factor Decay Heat Fraction of Spent Fuel =
Correction Factor Assemblies in Core
(___1.3____)
= __1.3_____
( 1.0 )
A1JPM-SRO-TTB PAGE 11 OF 14 KEY CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 6 OF 4 NOTE
- Reactor Coolant System open is contained in the Definitions section of this procedure.
- If the status of the RCS (open or intact) is unknown the RCS will be considered open for Time to Boil determination.
3.0 Determining Time to Boil:
3.1 Using the appropriate figure from Attachment C, OBTAIN uncorrected Time to Boil.
3.1.1 IF RCS is open, THEN USE ONE of the following:
- Figure 2A for RCS temp 40°F to 140°F
- Figure 3A for RCS temp 40°F to 140°F
- Figure 3B for RCS temp 140°F to 300°F 3.1.3 LOG uncorrected Time to Boil: ___23______
3.2 MULTIPLY uncorrected Time to Boil by Decay Heat Correction Factor:
Uncorrected Time Decay Heat Time to boil in X =
to Boil in minutes Correction Factor minutes X =
(__23__) (__1.3__) __29.9___
A1JPM-SRO-TTB PAGE 12 OF 14 KEY CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 7 OF 4 4.0 Determining Time To Core Uncovery:
4.1 Using the appropriate figure from Attachment C, OBTAIN uncorrected Time To Core Uncovery:
4.1.1 IF Incore Instrument guide tubes are breached AND RV Head is installed, THEN ASSUME a conservative initial RCS level of 369.5' and USE ONE of the following:
- Figure 4A for RCS temp 40°F to 140°F
- Figure 4B for RCS temp 140°F to 200°F 4.1.2 IF RCS is open with nozzle dams removed, THEN USE ONE of the following:
- Figure 4A for RCS temp 40°F to 140°F
- Figure 4B for RCS temp 140°F to 200°F 4.1.3 IF EITHER SG has nozzle dam installed, THEN USE ONE of the following:
- Figure 4C for RCS temp 40°F to 140°F
- Figure 5A for RCS temp 40°F to 140°F
- Figure 5B for RCS temp 140°F to 240°F
- Figure 5C for RCS temp 240°F to 340°F 4.1.5 LOG uncorrected Time To Core Uncovery: ____215______
4.2 MULTIPLY uncorrected Time To Core Uncovery by Decay Heat Correction Factor:
Uncorrected time to Decay Heat Time to Core Core Uncovery in X Correction Factor = Uncovery in minutes minutes
(_215_) X (_1.3__) = _279.5_
A1JPM-SRO-TTB PAGE 13 OF 14 KEY CALCULATION OF RCS TIME TO BOIL/CORE UNCOVERY ESTIMATE PAGE 8 OF 4 5.0 Determining Time To Core Uncovery:
5.1 Using Figure 6 of Attachment C, DETERMINE uncorrected heatup rate
__4.0____°F/min.
5.2 DIVIDE by Decay Heat Correction Factor:
Uncorrected Heatup Rate Estimated Heatup
=
Decay Heat Correction Factor Rate in °F/min
(____4_______) =
( 1.3 ) ___3.08____
6.0 Using Figure 7A or 7B of Attachment C, RECORD required makeup rate: __68____ gpm 7.0 IF Time to Boil is significantly less than previous Time to Boil estimate AND in Mode 5 or 6, THEN REEVALUATE ANY containment closure estimates for ALL outstanding items on the Containment Closure Breach List.
8.0 UPDATE the Status Board with the new data.
Performed by _______________________________ Date __________ Time __________
Calculations Reviewed/
Confirmed by CRS or SM: _______________________ Date __________ Time ________
A1JPM-SRO-TTB PAGE 14 OF 14 EXAMINEEES COPY JPM INITIAL TASK CONDITIONS:
Given the following Plant conditions:
- Plant shutdown for refueling.
- RCS level is being drained to 376 in preparation for Reactor head removal.
- Time after shutdown = 65 hours7.523148e-4 days <br />0.0181 hours <br />1.074735e-4 weeks <br />2.47325e-5 months <br />.
- Both OTSG primary manways are removed.
- Nozzle dams are NOT installed.
- RCS Temperature is 120°F.
- Plant computer is inoperable due to power supply maintenance.
INITIATING CUE:
SM directs you to review the attached time to boil and time to core uncovery calculations using Form 1015.002B, Calculation of Time to Boil/Core Uncovery Estimate, through step 6.0.
Document the results on the attached 1015.002B form.
Based on your review, do you confirm the calculations are correct?
Yes _______ No _______
ADMINISTRATIVE JOB PERFORMANC MEASURE A1JPM-SRO-ADMINSW Page 1 of 4 UNIT: 1 REV # 0 DATE: ___________________
SYSTEM/DUTY AREA: Service Water (SW)
TASK: Determine Operability of Service Water Pump JTA: ANO-SRO-ADMIN-NORM-103 KA VALUE RO: 3.6 SRO: 4.6 KA
REFERENCE:
2.2.37 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR: OUTSIDE CR:___X______ BOTH:________
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE _____________ SIMULATOR: Classroom: __Perform________
POSITION EVALUATED: RO:_______ SRO:____X_______
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE:__________ Classroom: __X____
TESTING METHOD: SIMULATE:_________ PERFORM: X APPROXIMATE COMPLETION TIME IN MINUTES: 30 MINUTES REFERENCE(S): Technical Specification (T.S. 3.7.7 & B3.7.7), OP-1104.029 EXAMINEE'S NAME:________________________________ Logon: _______________________
EVALUATOR'S NAME:__________________________________________________________________
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY:________________ UNSATISFACTORY:_________________
PERFORMANCE CHECKLIST COMMENTS:
Start Time ____________ Stop Time ____________ Total Time______________
SIGNED _Robert Possage_______________________________ DATE: _______________________
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
ADMINISTRATIVE JOB PERFORMANC MEASURE A1JPM-SRO-ADMINSW Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS:
You are conducting 1104.029 Supplement 1 Section 4 Supervisor Review and Analysis.
Determine if P-4A is OPERABLE / INOPERABLE and apply Technical Specifications to include CONDITION, REQUIRED ACTION and COMPLETION TIMES TASK STANDARD:
- 1) SRO identified the following errors
- Table 3 data was inappropriately plotted on P-4A Pump Curve
- Actual differential pressure of 87.5 falls outside the LIMITING RANGE FOR OPERABILITY
- 2) Identify that P-4A Service Water pump is inoperable TASK PERFORMANCE AIDS: T.S. 3.7.7 and T.S. Bases for 3.7.7, OP-1306.017
ADMINISTRATIVE JOB PERFORMANC MEASURE A1JPM-SRO-ADMINSW Page 3 of 4 INITIATING CUE: The CRS/SM directs you to determine whether P-4A Service Water Pump is OPERABLE / INOPERABLE and apply Technical Specifications to include CONDITION, REQUIRED ACTION and COMPLETION TIMES.
Critical Tasks: 1, 2, and 4 C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT
- 1) Applicant Reviews 1104.029 Applicant references necessary Supplement 1 Data Sheets. documents to determine the following:
C Table 3 Data was incorrectly transposed to the P-4A pump Curve.
- 2) Applicant re-plots data on the P-4A Applicant determines that the Actual pump curve. Diff Press of 87.5 psi falls outside the C LIMITING RANGE FOR OPERABILITY.
- 3) Determine P-4A OPERABILITY. Applicant determines that P-4A is INOPERABLE due to Actual Diff C Press being outside the LIMITING RANGE FOR OPERABILITY.
END
ADMINISTRATIVE JOB PERFORMANC MEASURE A1JPM-SRO-ADMINSW Page 4 of 4 Applicants Copy INITIAL CONDITIONS:
- Plant at 95% power.
- You are reviewing OP-1104.029 Supplement 1 INITIATING CUE:
The SM directs you to conduct a supervisory review of OP-1104.029 Supplement 1 per Section 4 and determine if P-4A is OPERABLE /
List any errors identified:
P-4A OPERABLE: YES ___ NO ___
I 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM PAGE: 323 of 551 CHANGE: 120 L
SUPPLEMENT I PAGE 21 OF 27 TABLE 2 Test Quantity Instrument Measured Acceptable Limiting Range Is Data Within Values Normal Range For Operability Limiting Range SW Loop I Press Alt Test_Inst 7$. 6 psig N/A N/A N/A P 1-3608 L psig SW Loop I Flow Anst tJ2 N/A N/A N/A SPD A SW Bay Level Callevel 33, LI feet N/A > 332 feet Suction Press Cled N/A N/A N/A tion_Pres Local Discharge Press Local P1-361 ltrestmf N/A N/A N/A psig Table 2 data gathered by: initial date KEY TABLE 3 Test quantity Measured Acceptable I Limiting Range Is Data Within Values Normal Range For Operability Limiting Range?
Actual Pump Duff Press Acceptable Normal and Limiting Range (APA) 87.5 values are per P-4A Pump Curve YES NO Baseline Pump Duff Press N/A N/A N/A (APe) 97.5 psi P-4A Deviation From psi N/A N/A N/A Baseline 10 Table 3 data gathered by: initial date TABLE 4 Test Quantity Measured Acceptable Limiting Range Is Data Within Instrument Values Normal Range For Operability Limiting Range Mtr Upper Brg TE-3651 Temp (P1284 or TR-3651) il/A °F <180°F N/A N/A MtrLowerBrg TE-3652 Temp (P1285 or TR-3651) °F <180°F N/A N/A Table 4 data gathered by: initial dZ
PAGE: 327 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 25 OF 27 P-4A Pump Curve KEY 115 Baseline iting 110
- Aceptable Normal Range Limiting Range 105 Comprehensive Limit 100 95 90 NN 0
a 85 rtingj I Range I NNN E
a-80 75 70 EEEEEEIEE 65 4ç 60 55 z::z:::::z::z:::::::N 50 4000 4500 5000 5500 6000 6500 7000 7500 Pump Flow (gpm)
PAGE: 329 of 5 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I KEY PAGE 27 OF 27 4.0 SUPERVISOR REVIEW AND ANALYSIS (circle one) 4.1 Do all measured values recorded in the Acceptance Criteria fall within the specified Limiting Range/Value For Operability? YES NO 4.2 Do all measured values recorded in the Acceptance Criteria section fall within the Acceptable Normal Range?
(CIRCLE N/A if the only values outside the Acceptable Normal range are also outside the Limiting RangeNalue for Operability) YES NO N/A 4.3 IF NO is answered to 4.1, THEN PERFORM the following corrective actions:
- ENSURE LCO Tracking Record is completed.
- ENSURE Condition Report initiated.
4.4 IF NO is answered to 4.2, THEN PERFORM the following corrective actions:
- ENSURE Condition Report has been initiated.
- COMPLETE 1000.009A, Surveillance Test Program Revision Request to raise the test frequency.
For pumps: The test frequency shall be doubled.
For valves: The test frequency is monthly.
4.5 IF answer to either 4.1 or 4.2 is NO, THEN DESCRIBE the action taken below:
Declare P-4A Service Water Pump Inoperable 4.6 Has this equipment been proven operable per the Acceptance Criteria? YES NO 4.7 Have all the administrative requirements of this test been satisfied (i.e., all initial blocks initialed or marked N/A, all data entered, cal due dates listed, applicable signature spaces signed, etc.)? YES NO Supervisor Date
PAGE: 303 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 1 OF 27 SERVICE WATER PUMP P-4A TEST
{4.2.2}
This test demonstrates operability of Service Water Pump (P-4A) and its discharge check valve by running the pump at rated flow and exercising the check valve. This test also demon strates operability of SW system flow path motor-operated valves by exercising the valves a complete cycle and measuring stroke times to required safety function positions. This test satisfies ANO 1ST progra m requirements 10 CFR 50.55a(f). Reference Values for 1ST Components are contained in Appendix B. 18-month testing requirements are contained in Supp. 8.
This supplement tests both red and green train components. Test method has been evaluated and determined to be acceptable.
The steps in this section may be per[orme.a+order with the substeps performed in the order specified.
1.0 INITIAL CONDITIONS CHECK the purpose of this test:
Regularly scheduled quarterly test B) Operability test following significant maintenance (DESCRIBE maintenance performed in section 4.0).
C) Other (DESCRIBE in section 4.0).
jf test is to prove operability following significant maintenance, THEN NOTIFY System Engineer to determine necessity to perform Attachment C Service Water Pump Reference Values Determination.
IE during this test a valve stroke time is NOT within Acceptable Normal Range AND stroke time is within Limiting Value for Operability, THEN prior to changing system alignment, REFER TO Appendix A, Operability, Failure of Valve Stroke to Meet Acceptable Normal Range and PERFORM ONE of the following:
RETEST valve.
DECLARE valve inoperable.
Ø ENSURE system aligned per 3305.001, Ops System Alignment Tests, System Alignment Confirmation section.
CHECK motor oil level per Service Water Pump Motor P-4AJB/C Lube Oil Check, Exhibit J of 1107.001, Electrical System Operations.
OBTAIN vibrometer from Predictive Maintenance Lab.
RECORD vibrometer M&TE# and Cal Due Date in Acceptance Criteria, section 3.0, at Table 5.
PAGE: 304 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 2 OF 27 ENSURE two currently calibrated stopwatches available.
RECORD stopwatch DES# and cal due date in section 3.0.
WHEN timing valve strokes, THEN: p IDENTIFY the stopwatch providing stroke time.
RECORD initial and date.
If test data taken under proper test conditionside the Limiting Range for Operability, the component being tested is declared inoperable for conservatism, even if instrument mis-calibration is suspected.
f SPDS is specified in instrument column for recording test data and SPDS instrumentation is NOT available, THEN PERFORM EITHER of the following:
- POSTPONE this surveillance.
- INSTALL appropriate alternate instruments.
IF alternate test instruments are used for an instrument other than local discharge pressure indicator, THEN:
1.10.1 ENSURE test instrument(s) meet the following requirements:
- Calibration is current.
- Test instrument accuracy is +/-2% of full scale or better.
- Range of Analog test instrument is less than 3 times normal process value.
- Range of Digital test instrument is scaled so that normal process value remains less than 70% of full scale.
1.10.2 OBTAIN Independent Verification instrument(s) meet the requirements stated above for:
- Cal Due Date
- Accuracy
- Range IV. by:
PAGE: 305 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 3 OF 27 0.3 ENSURE instrument column in section 3.0 is annotated to show the instrument number used and the cal due date.
1.10.4 ENSURE alternate instrument use is documented with appropriate explanation of reason(s) in Supervisor Review and Analysis section.
1.10.5 INSTALL alternate test instrument(s) at SPDS transmitter local instrument connection.
1.10.6 OBTAIN independent verification instrument(s) is(are) installed at SPDS transmitter local instrument connection.
I.V. by 1.10.7 WHEN alternate test instrument(s) are aligned, THEN MAINTAIN instruments attended.
IF SW Pump P-4A Disch Press (P1-3611) is unavailable, THEN:
1.11.1 OBTAIN alternate analog test instrument meeting the following requirements:
- Calibration is current.
Test instrument accuracy
+/-0.5% of full scale or better for pump dP (suction, discharge).
- Range of ANALOG test instrument is less than 3 times normal process value.
1.11.2 OBTAIN independent verification instrument(s) meet the requirements stated above for:
- Caldue date
- Accuracy
- Range IV. by
PAGE: 306 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 4 OF 27 1.3 RECORD alternate test instrument M&TE number and cal due date in step 3.0.
1.11.4 ANNOTATE in Supervisor Review and Analysis section, alternate test instrument used for pump discharge pressure for gauge unavailable, etc.
1.11 .5 INSTALL alternate test instrument as follows:
A. ENSURE test connection valve between SW Pump P-4A Discharge PS-3611 Isol (SW-3611E) and PS-3611 closed.
B. INSTALL alternate test instrument at test connection between SW Pump P-4A Discharge PS-361 1 Isol (SW-361 1 E) and PS-361 1.
C. POSITION alternate test instrument at same elevation as SW Pump P-4A Disch Press (P1-3611).
1.11.6 OBTAIN independent verification of alternate test instrument installation.
I.V. by 1.11.7 WHEN alternate test instrument(s) are aligned, THEN MAINTAIN instruments attended.
NOTIFY the following that dual train (red and green) testing will be performed during the performance of this supplement:
I4Alf manned, CCC.
If manned, CRSA.
Shift Manager or Operations Management.
SUPPLEMENT I PAGE 5 OF 27 TEST METHOD ENSURE A and B SW bays crosstied via A/B SW Bay Crosstie (SG-3) and aligned to the lake via Lake Supply to A SW Bay (SG-1).
ffl C SW bay is in service AND aligned to the lake via Lake Supply to C SW Bay (SG-2)
AND B/C SW Bay Crosstie (SG-4) available, THEN ENSURE SG-4 is open.
ENSURE the following valves are open to cross-connect SW loops at ICW coolers:
- Loop I Supply to ICW Coolers (CV-3820)
- Loop II Supply to ICW Coolers (CV-3811)
- SW Loops I & II Crossconnect (SW-5)
2.4.1 ENSURE SW Pump P-4B to P-4C Crossties open:
- P-4B to P-4C Crosstie (CV-3640)
- P-4B to P-4C Crosstie (CV-3642) 2.4.2 IE desired by CRS/SM to minimize SW Pressure rise due to starting third SW Pump, THEN PERFORM ONE or more of the following:
A. IF adjusting SW pressure with SW-4026A, THEN:
- 1. RECORD as-found percent open indication:
- 2. THROTTLE SW-4026A to obtain SW Loop pressures 65 to 85 psig.
- 3. RECORD as-left SW-4026A percent open indication:
B jf adjusting SW pressure with SW-4026B, THEN while counting turns, THROTTLE SW-4026B to obtain SW Loop pressures 65 to 85 psig.
- RECORD number of turns operated:
C. if CRS desires to place additional SW loads into service, THEN RECORD additional SW loads:
PAGE: 308 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 6 OF 27
,It/A2.4.3 MAKE a plant announcement that a Service Water pump will be started 2.4.4 START SW Pump (P-4A).
2.4.5 CHECK P-4A packing leakoff.
2.4.6 IF ALL 3 service water pumps are operating, THEN:
A. STOP SW Pump (P-4B).
B. CHECK for reverse rotation of SW Pump (P-4B).
C. IF reverse rotation indicated, THEN:
- 1. MAKE an entry in Category E/Locked Component Log for P-4B Disch Isol (SW-2B).
- 2. UNLOCK and CLOSE P-4B Disch Isol (SW-2B).
- 3. DECLARE SW Pump (P-4B) and P-4B Disch Ck (SW-1B) inoperable.
- 4. REFER TO Technical Specifications.
D. NOTIFY Chemistry to stop Chemical Injection to B SW Bay.
2.4.7 IF SW pressure adjustment was performed in step 2.4.2 AND CRS desires to make SW pressure adjustment, THEN PERFORM ONE of the following to restore SW pressure:
A. IE adjusting SW pressure with SW-4026A, THEN:
- 1. THROTTLE SW-4026A to obtain SW Loop pressures 65 to 85 psig.
- 2. RECORD as-left SW-4026A percent open indication:
B. IF adjusting SW pressure with SW-4026B, THEN while counting turns, THROTTLE SW-4026B to obtain SW Loop pressures 65 to 85 psig.
. RECORD number of turns operated:
C. IF CRS desires to remove additional SW loads from service, THEN RECORD SW loads removed:
SUPPLEMENT I PAGE 7 OF 27 IF SW Pump (P-4A) will remain in service at the completion of this test, THEN NOTIFY Chemistry to realign Chemical Injection.
Stroke test of Loop II Supply to ICW Coolers (CV-381 1):
While measuring stroke time, CLOSE CV-381 1.
RECORD CV-381 1 closing stroke time in Table 1.
9- OPEN Loop II Supply to ICW Coolers (CV-381 1).
NOTE Normally, P-4A to P-4B Crossties (CV-3644 and CV-3646) are open and steps 2.7 and 2.8 will be marked N/A.
/
IF P-4A to P-48 Crosstie (CV-3644) is closed, THEN PERFORM the following to stroke test CV-3644 open:
2.7.1 While measuring stroke time, OPEN CV-3644.
2.7.2 RECORD CV-3644 opening stroke time in Table 9.
IF P-4A to P-4B Crosstie (CV-3646) is closed, THEN PERFORM the following to stroke test CV-3646 open:
2.8.1 While measuring stroke time, OPEN CV-3646.
2.8.2 RECORD CV-3646 opening stroke time in Table 9.
Closed stroke test of P-4A to P-4B Crosstie (CV-3646):
While measuring stroke time, CLOSE CV-3646.
RECORD CV-3646 closing stroke time in Table 1:
Closed stroke test of P-4A to P-4B Crosstie (CV-3644):
While measuring stroke time, CLOSE CV-3644.
RECORD CV-3644 closing stroke time in Table 1:
SUPPLEMENT I PAGE 8 OF 27 Actual SW/ACW flow of less than 1500 gpmuse SPDS flow indication to indicate 0 gpm.
From SPDS Diagnostic Display or SPDS point F3902, CHECK SW Loop I flow is 4000 gpm or greater.
IF SW Loop I flow is less than 4000 gpm, THEN:
A. f RB Cooling will be placed into service to raise SW Loop I flow, THEN CHECK Service Water biocide injection system in service (allowed exception: system unavailable with lake temperature less than 60°F or greater than 80°F).
B. PLACE idle load(s) into service to raise SW Loop I flow to 4000 gpm or greater.
- 1. LIST load(s) placed into service below:
C. IF additional load(s) are added, THEN:
- 1. MONITOR component temperatures closely.
4
- 2. ADJUST cooling water flows as necessary. 4 jf alternate test instrument is installed for SW Pump P-4A Disch Press (P1-3611),
THEN:
2.12.1 OPEN test connection valve isolating disch press alternate test instrument at PS-361 1.
2.12.2 MAINTAIN alternate test instrument attended unless 4
isolated.
PAGE: 311 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 9 OF 27 WHEN flow has been stable for at least two minutes, THEN:
0 COMMENCE P-4A Motor Bearing vibration data collection per Vibrometer Data sheet.
0 RECORD the following Measured Values in Table 2:
Loop I Press: SPDS/Alt Test Inst Loop I Press: P1-3608 SW Loop I Flow: SPDS/ALT Test Inst A SW Bay Level: SPDS Suction Pressure: SPDS Local Discharge Press: Local P1-361 1/Alt Test Inst j ,
CALCULATE Actual Pump Duff Pressure (APA) using the following values as recorded in Table 2:
Local Disch Press + Suction Pressure = APA
+
7, RECORD Actual Pump Duff Pressure (APA) in Table 3.
Using Actual Pump Duff Press (APA) and SW Loop I Flow, PLOT test value on P-4A Pump Curve.
0 Using the Baseline on the P-4A Pump Curve and using SW Loop I Flow, FIND the value of Baseline Pump Duff Press (APB). RECORD Baseline Pump Duff Press (APB) in Table 3.
PAGE: 312of551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 10 OF 27
().
P-4A Deviation From Baseline could be a number. For trending purposes, the negative sign is included.
CALCULATE P-4A Deviation From Baseline using data from Table 3:
(APB
- psi) . P-4A Deviation
- (APA
- psi)
From Baseline pbç -17gw
/9 RECORD P-4A Deviation From Baseline in Table 3 including negative sign, if applicable.
L NOTE Bearing temperature is considered stable when three consecutive readings at ten-minute intervals vary no more than 3%.
I.E this test is to prove operability after significant maintenance, THEN:
2.21.1 CONTINUE test until motor bearing temperatures are stable.
2.21.2 RECORD stable motor bearing temperatures in Table 4.
jf this test is NQI being performed to prove operability after significant maintenance, THEN MARK motor bearing temperatures in Table 4 N/A.
WHEN P-4A Motor Bearing vibration data is collected, THEN RECORD data in Table 5.
I PAGE: 313of551 L 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE II OF 27 9- CHECK SW Loop I flow 5600 gpm or greater.
jf SW Loop I flow is less than 5600 gpm, THEN:
A. IF RB Cooling will be placed into service to raise SW Loop I flow, THEN CHECK Service Water biocide injection system in service (allowed exception: system unavailable with lake temperature is less than 60°F or greater than 80°F).
B. PLACE idle load(s) into service to raise SW Loop I flow to 5600 gpm or greater.
- 1. LIST load(s) placed into service below:
C. IF additional load(s) are added, THEN:
- 1. MONITOR component temperatures closely. 1
- 2. ADJUST cooling water flows as necessary. 4 RECORD the following:
Open stroking of P-4A Disch Ck (SW-lA) in Table 6.
Flow rate: 52t.__.. gpm Flow instrument:
IF additional load(s) were added in order to raise SW flow for this test, THEN RESTORE load(s) listed in steps 2.ll.l.B and 2.24.l.B to original status.
PAGE: 314 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 12 OF 27 0 Closed stroke test of A/B SW Bay Crosstie (SG-3):
Any delay during the performance of the series of steps could result in lowering B SW Bay level.
With SW Bay Level starting at 332 feet or e s and SW Flow 8000 gpm or greater, SW pump NPSH limits could be exceeded during suction transfer from Lake to Pond. This could result in pump damage.
ENSURE A and B SW Bay Levels are above 332 feet.
While measuring stroke time, CLOSE SG-3.
IF SW Pump P-.4B is in service AND B/C SW Bay Crosstie (SG-4) is closed, THEN OPEN Pond Supply to B SW Bay (SG-6).
RECORD SG-3 closing stroke time in Table 7.
Any delay during the performance of the folwtg series of steps will result in lowering A SW Bay level.
V Closed stroke test of Lake Supply to A SW Bay (SG-1):
While measuring stroke time, CLOSE SC-i.
RECORD SC-I closing stroke time in Table 7.
SUPPLEMENT I PAGE 13 OF 27 Aligning a SW Pump suction to Emergenoling Pond will cause the ECP level to drop.
test of Pond Supply toA SW Bay (SG-5):
While measuring stroke time, OPEN SG-5.
IF SG-5 fails to operate, THEN:
A. PERFORM ONE of the following:
- OPEN Lake Supply to A SW Bay (SG-1).
- OPEN A/B SW Bay Crosstie (SG-3).
B. jf Pond Supply to B SW Bay (SG-6) is closed, THEN ENSURE B/C SW Bay Crosstie (SG-4) open.
RECORD SG-5 open stroke time in Table 7.
I Sediment can enter pump suction going on Emergency Cooling Pond.
I MONITOR SW Pump (P-4A) discharge pressure and strainer AP while in this configuration.
WHEN 15 minutes of operation on Emergency Cooling Pond has elapsed, THEN RECORD the following:
A SW Bay Level on ECP in Table 8.
oop I flow from either SPDS Diagnostic Display or SPDS point F3902.
SW Loop I flow S4 Q gpm
PAGE: 316 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 14 OF 27 Any delay during the peormance of the feries of steps will result in lowering A SW Bay level.
Closed stroke test of Pond Supply to A SW Bay (SG-5):
While measuring stroke time, CLOSE SG-5.
RECORD SG-5 close stroke time in Table 9.
test of Lake Supply to A SW Bay (SG-1):
While measuring stroke time, OPEN SG-1.
Jf SG-1 fails to operate, THEN:
A. PERFORM ONE of the following:
- OPEN Pond Supply to A SW Bay (SG-5).
- OPEN A/B SW Bay Crosstie (SG-3).
B. IF Pond Supply to B SW Bay (SG-6) is closed, THEN ENSURE B/C SW Bay Crosstie (SG-4) open.
RECORD SG-1 open stroke time in Table 9.
Any delay during the peormance of the foIries of steps will result in lowering B SW Bay level.
0 Open stroke test of NB SW Bay Crosstie (SG-3):
.E SW Pump (P-4B) is in service supplied from the ECP, THEN CLOSE Pond Supply to B SW Bay (SG-6).
While measuring stroke time, OPEN SG-3.
RECORD SG-3 open stroke time in Table 9.
if P-4B Crosstie (CV-3644) was NOT open stroke tested in step 2.7, While measuring stroke time, OPEN CV-3644.
RECORD CV-3644 opening stroke time in Table 9.
PAGE: 317of 551 1104M29 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 15 OF 27 P-4A to P-4B Crosstie (CV-3646) was NOT open stroke tested in step 2.8, THEN:
While measuring stroke time, OPEN CV3646.
2 RECORD CV-3646 opening stroke time in Table 9.
ENSURE P-4A to P-4B Crosstie valves open:
P-4A to P-4B Crosstie (CV-3644)
P-4A to P-4B Crosstie (CV-3646)
Powering SW Pumps P-4B and P-4C from ite buses satisfies Tech Spec requirements for train separation.
If three SW pumps are operating due to histem heat loads, a delay in the subsequent steps to restart SW Pump P-4A can cause overheating of SW system loads.
IF in Mode 14 AND SW Pumps P-4B and P-4C are operable, THEN:
CHECK P4B Bus Select MOD Control selected to A3.
if P4B Bus Select MOD Control selected to A4, THEN:
I A. ENSURE SW Pump P-4C in service.
B. ENSURE SW Pump P-4B is secured.
C. ENSURE BOTH SW Pump P-4B supply breakers are open:
- On C18, A-303 indicates open
- On C16, A-403 indicates open D. TRANSFER P4B Bus Select MOD Control to A3.
E. PERFORM 1107.002, ES Electrical System Operation, Transfer MCC B55/56 to B5 section.
PAGE: 318of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 16 OF 27
!E desired by CRS/SM to minimize SW Pressure rise due to starting third S SW Pump, THEN PERFORM ONE or more of the following:
IE adjusting SW pressure with SW-4026A, wf THEN:
RECORD as-found percent open indication:
THROTTLE SW-.4026A to obtain SW Loop pressures 65 to 85 psig.
RECORD as-left SW-4026A percent open indication:
I.E adjusting SW pressure with SW-4026B, 9
THEN while counting turns, THROTTLE SW-4026B to obtain SW Loop pressures 65 to 85 psig.
. RECORD number of turns operated:
ffl CRS desires to place additional SW loads into service, THEN RECORD additional SW loads:
ENSURE SW Pumps P-4B and P-4C in service.
ENSURE SW Crosstie valves open:
P-4A to P-4B Crosstie (CV-3644)
ØP4A to P-4B Crosstie (CV-3646)
P-4B to P-4C Crosstie (CV-3640)
P-4B to P-4C Crosstie (CV-3642)
SUPPLEMENT I PAGE 17 OF 27 Stopping of P-4A pump shaft confir*eating of P-4A Disch Check (SW-lA).
STOP SW Pump (P-4A).
CHECK SW Pump (P-4A) shaft stops.
IF reverse rotation indicated, THEN:
A. MAKE an entry in Category E/Locked Component Log for P-4A Disch lsol (SW-2A).
B. UNLOCK and CLOSE P-4A Disch Isol (SW-2A).
C. DECLARE SW Pump (P-4A) and P-4A Disch Ck (SW-lA) inoperable.
D. REFER TO Technical Specifications.
RECORD closing of P-4A Disch Ck (SW-lA) in Table 6.
IF desired by CRS/SM, THEN RESTART SW P p (P-4A).
In Mode 5, 6 or defueled, only oump is required to be operating.
Jf plant is in Mode 5, 6 or defueled AND plant conditions allow stopping P-4A, THEN PERFORM the following to stop P-4A:
2.39.1 IF in Mode 6, THEN REFER TO Refueling Operations (TS 3.9) to determine SW pump requirements.
2.39.2 IF a single SW Pump will be in operation in the subsequent steps, THEN CHECK SW flow is less than 8000 gpm.
2.39.3 ENSURE SW Pump P-4B or P-4C in service.
SUPPLEMENT I PAGE 18 OF 27 i4 ENSURE SW Crosstie valves open:
- P-4A to P-4B Crosstie (CV-3644)
- P-4A to P-4B Crosstie (CV-3646)
- P-4B to P-4C Crosstie (CV-3640)
- P-4B to P-4C Crosstie (CV-3642)
Stopping of P-4A pump shaft confirØng of P-4A Disch Check (SW-IA).
STOP SW Pump (P-4A).
2.3 .6 CHECK SW Pump (P-4A) shaft stops.
2.3 .7 IF reverse rotation indicated, THEN:
A. MAKE an entry in Category E/Locked Component Log for P-4A Disch Isol (SW-2A).
B. UNLOCK and CLOSE P-.4A Disch Isol (SW-2A).
C. DECLARE SW Pump (P-4A) and P-4A Disch Ck (SW-lA) inoperable.
D. REFER TO Technical Specifications.
2 39.8 RECORD closing of P-4A Disch Check (SW-lA) in Table 6.
2 9.9 If desired by CRS/SM, THEN RESTART SW Pump (P-4A).
IF plant is in Mode 5, 6 or defueled AND plant conditions prevent stopping P-4A, THEN:
- MARK SW-lA closure N/A in Table 6.
- INITIATE a Condition Report to docu ment that SW-lA requires 1ST stroke.
RETURN system to desired pump configuration per Pump Rotation section of this procedure.
ENSURE that sluice gates and cross-ties are aligned as required by Table 9.1 .4 of this procedure.
PAGE: 321 of 551 I 104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 19 OF 27 IF SW pressure adjustment was performed in step 2.38.3 AN..P CRS desires to make SW pressure adjustment, THEN PERFORM ONE or more ot the following to restore SW pressure:
IE adjusting SW pressure with SW-4026A, THEN:
THROTTLE SW-4026A to obtain SW Loop pressures 65 to 85 psig.
RECORD as-left SW-4026A percent open indication:
IE adjusting SW pressure with SW-4026B, THEN while counting turns, THROTTLE SW-4026B to obtain SW Loop pressures 65 to 85 psig.
. RECORD number of turns operated:
IF CRS desires to remove additional SW loads from service, THEN RECORD SW loads removed:
IF alternate test instrument installed for P-4A Disch Press (P1-361 1),
THEN:
2.44.1 ENSURE test connection valve between SW Pump P-4A Discharge PS-3611 Isol (SW-3611E) and PS-3611 closed.
2.44.2 REMOVE test instrument.
2.44.3 ENSURE SW-3611E is open.
IF alternate test instruments are installed, THEN REMOVE alternate test instruments.
Independent Verification by 2.46 SRO REVIEW ALL calculations and CONFIRM correct.
Reviewed and confirmed by:
2.47 RECORD and REVIEW required trend data.
Recorded and reviewed by:
2.48 jE trend graphs are available, THEN ATTACH copies of graphs.
2.49 UPDATE plant risk software to reflect final SW system alignments (including SW Pump P-4B power alignment).
PAGE: 322 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 20 OF 27 ACCEPTANCE CRITERIA l,
3 RECORD Stopwatch information:
DES #: 0 Cal Due Date DES#: 05/ Cal Due Date 3 COMPARE Measured Values/Stroke Times with Acceptable Normal Range and Limiting Value for Operability.
J31 IDENTIFY if Measured Value/Stroke Time is within Limiting Value for Operability.
IF alternate test instrument is used for discharge pressure, THEN RECORD alternate test instrument info below:
M&TE# Ft/A CalDueDatet..
COMPARE measured values observed during P-4A testing with Acceptable Normal Range and Limiting Value for Operability.
TABLE 1 T Measured Acceptable Limiting Valve Dreeon DES# Stroke Time Normal Range Value for Initial Date If I I (nearest 1/10 sec) (sec) Operability Lirnitin Close sec CV-3811 05! 45.0-60.8 68.7 CV-3646 Close ptfg sec 369 49.9
- 56.4 (____
CV-3644 Close 7 f7 sec 42.0 56.8
- 64.2
(_)
PAGE: 323 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 21 OF 27 TABLE 2 Test Quantity Instrument Measured Acceptable Limiting Range Is Data Within Values Normal Range For Operability Limiting Range SW Loop I Press Alt_Test_Inst ?L6psig N/A N/A N/A P 1-3608
- 11. C psig SW Loop I Flow N/A N/A N/A Anst A SW Bay Level SPD Callevel 33j Llfeet N/A > 332 feet Suction Press Cled N/A N/A N/A Sj.ition Press psig Local Discharge Press Local P1-361 it Test Int N/A N/A N/A psig Table 2 data gathered by: initial date 1gft,a, I
TABLE 3 Test quantity Measured Acceptable I Limiting Range Is Data Within Values Normal Range For Operability Limiting Range?
Actual Pump Duff Press Acceptable Normal and Limiting Range (zPA) values are per P-4A Pump Curve NO Baseline Pump Duff Press (zP8) N/A N/A N/A P-4A Deviation From pSi N/A N/A Baseline /Q N/A Table 3 data gathered by: initial date 16I7 TABLE 4 Test Quantity Instrument Measured Acceptable Limiting Range Is Data Within Values Normal Range For Operability Limiting Range MtrUpperBrg TE-3651 Temp (P1284 orTR-3651) °F <180°F N/A N/A Mtr Lower Brg TE-3652 Temp (P1285 or TR-3651) il/A °F <180°F NIA N/A Table 4 data gathered by: initial J!4...
1104.029 PAGE: 324 of 551 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 22 OF 27 Vibrometer M&TE # VA Oi2 Cal Due Date 5/f//co TABLE 5 Test Quantity Location Measured Acceptable Limiting Range Is Data Within Values Normal Range For Operability Limiting Range?
Motor Radial Point 1 on
<0.287 in/sec <0.69 in/sec Upper Brg Vib Motor Map 0 t17in/sec NO Motor Radial Point 2 on Upper Brg Vib Motor Map <0.325 in/sec <0.7 in/sec NO t$inIsec Motor Axial Point 3 on Upper BrgVib Motor Map Oin/sec <0.242 in/sec <0.582 in/sec NO Table 5 data gathered by: initial Em)? date14y TABLE 6 Valve Test Limiting Value (V) If Within Limiting Direction For Operability Initial Date --
Range Full stroke confirmed by SW-I A Open SW Loop I flow 5600ciom Closure confirmed by 4 :4, (-
SW-lA Closed P-4A pump shaft stopping I
PAGE: 325 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 23 OF 27 TABLE 9 Test Measured Acceptable Limiting Valve DES# Stroke Time Normal Range Value for Initial Date If within Direction Limiting (nearest 1/10 sec) (sec) Operability Value SG-5 Close 14/7. 3 sec 147.1 - 199.0 225.0 SG-1 Open /75sec 154.0-208.2 235.4 SG-3 Open /,tsec 157.9-213.7 241.5 (t CV-3644 Open *% 4,J sec 48.0-64.8 73.3 L1f CV-3646 Open Øj 34 /_ sec 39.2 53.0
- 59.9 0
/
p94 IF NO is circled in Table 2, 3 or 5, THEN:
- DECLARE P-4A inoperable.
- NOTIFY the Shift Manager.
- INITIATE a Condition Report.
- INITIATE corrective action.
- REFERENCE Tech Spec for applicable conditions.
IF ANY measured value in Table 2, 3, 4 or 5 does jQI fall within the Acceptable Normal Range, THEN INITIATE corrective action.
SUPPLEMENT I PAGE 24 OF 27 IE measured value is outside Limiting Value/Range in Table 1, 6, 7, or 9, THEN:
- DECLARE that valve inoperable.
- NOTIFY Shift Manager.
- INITIATE a Condition Report.
- INITIATE corrective action.
- REFERENCE Tech Spec for applicable conditions.
4A IF ANY measured stroke time does NOT fall within the Acceptable Normal Range, THEN:
3.9.1 Immediately RETEST valve or DECLARE valve inoperable.
3.9.2 REFER TO Appendix A, Operability of this procedure for additional guidance.
Performed by: Print Name Initial Date
PAGE: 327 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 25 OF 27 P-4A Pump Curve 115 I Baseline Comprehensive I i Limiting 110 - - -
- Axeptable Normal Range Limiting Range 105 Comprehensive Limit 100 95 EEEZEEEZEZEE 90 Limitingj Range I S a85 EEE 0
0.
E 80 0
75 70 65 60 55 50j 4000 4500 5000 5500 6000 6500 7000 7500 Pump Flow (gpm)
PAGE: 328 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHANGE: 120 SUPPLEMENT I PAGE 26 OF 27 Motor Map (3)
Motor Upper Bearing Axial (2)
Motor Upper Bearing Radial (1)
Motor Upper Bearing Radial
/
//
POINT VELOCITY Data Collected By iiV7 7?. NO (in/sec)
Date 1 Vibrometer M&TE # ZVA 012.. 2 4 Calibration Due Date V
o.i/ %.
PAGE: 329 of 551 1104.029 SERVICE WATER AND AUXILIARY COOLING SYSTEM CHAMGE: 120 SUPPLEMENT I PAGE 27 OF 27 4.0 SUPERVISOR REVIEW AND ANALYSIS 4.1 (circle one)
Do all measured values recorded in the Acceptance Criteria fall within the specified Limiting RangeNalue For Operability?
YES NO 4.2 Do all measured values recorded in the Acceptance Criteria section fall within the Acceptable Normal Range?
(CIRCLE N/A if the only values outside the Acceptable Norma l
range are also outside the Limiting RangeNalue for Operability)
YES NO N/A 4.3 NO is answered to 4.1, THEN PERFORM the following corrective actions:
- ENSURE LCO Tracking Record is completed.
- ENSURE Condition Report initiated.
4.4 IF NO is answered to 4.2, THEN PERFORM the following corrective actions:
- ENSURE Condition Report has been initiated.
- COMPLETE 1000.009A, Surveillance Test Program Revision Request to raise the test frequency.
For pumps: The test frequency shall be doubled.
For valves: The test frequency is monthly.
4.5 IF answer to either 4.1 or 4.2 is NO, THEN DESCRIBE the action taken below:
4.6 Has this equipment been proven operable per the Acceptance Criteria?
YES NO 4.7 Have all the administrative requirements of this test been satisfied (i.e., all initial blocks initialed or marked N/A, all data entered, cal due dates listed, applicable signature spaces signed, etc.)?
YES NO Superv isor Date
Page 1 of 5 A1JPM-SRO-ADMIN-RWP3 UNIT: 1 REV # 2 DATE: ______________________________
JPM ID: A1JPM-RO-ADMIN-RWP3 SYSTEM/DUTY AREA: ADMINISTRATIVE TOPIC - Radiation Control TASK: Ability to comply with radiation work permit requirements JTA#: ANO1-RO-DHR-NORM-2 KA VALUE RO: 3.5 SRO: 3.6 KA
REFERENCE:
2.3.7 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR: OUTSIDE CR:_________ CLASSROOM: X SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE:_____________ SIMULATOR: Classroom: ________X_______
POSITION EVALUATED: RO:____ ______ SRO:____X_______
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE:______ Classroom:__X___
TESTING METHOD: SIMULATE:_________ PERFORM:___X________
APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): RWP 2020-1002, P-34A survey map, EXAMINEE'S NAME:_______________________________ Logon ID: ___________________
EVALUATOR'S NAME:__________________________________________________________________
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY:________________ UNSATISFACTORY:_________________
PERFORMANCE CHECKLIST COMMENTS:
____________ Start Time ____________ Stop Time ____________ Total Time SIGNED __Robert Possage ______________________________ DATE: _______________________
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
Page 2 of 5 A1JPM-SRO-ADMIN-RWP3 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed per NUREG 1021 Appendix E.
INITIAL PLANT CONDITIONS
- Decay Heat Removal Pump P-34A has indications of a leak on the pump inboard seal.
- The WCO is going to quantify the leakage from the P-34A seal.
- This is NOT an emergency
- His total dose for the year is currently 1950 mrem.
- He is a qualified CAT 3 Advanced Rad Worker.
- RWP, 20201002 Task 1 governs the planned activity TASK STANDARD:
Using the above information, determine the MAXIMUM stay time at the P-34A pump inboard seal area for the WCO entry.
- Disagree with the WCOs calculated time
- MAXIMUM stay time at the P-34A pump inboard seal area is 10.0 minutes. (8-10 minutes are acceptable)
TASK PERFORMANCE AIDS: RWP 2020-1002, P-34A survey map .
SIMULATOR SETUP: NA
Page 3 of 5 A1JPM-SRO-ADMIN-RWP3 INITIATING CUE:
Use the attached RWP, 2020-1002 Task 1.
Using the above information, determine the MAXIMUM stay time at the P-34A pump inboard seal area for the WCO entry.
(C) PERFORMANCE STEP PERFORMANCE STANDARD SAT UNSAT N/A
- 1. Reviews P-34A Pump survey Examinee determined dose rate of map to determine dose rates in 120 mR/hr at the inboard pump seal.
the vicinity of the inboard pump seal. _____ _____ _____
(C) 2. Determines stay time based on Examinee determined stay time the given dose in the pump based on RWP limits of 20 mrem inboard seal area not to would allow him to stay at the pump exceed the RWP limits. inboard seal area for 10.0 minutes (8-10 minutes).
20 mR X 60 min = 10.0 minutes 120 mR/hr 1 hr (C) 3. Determines that the WCO Examinee DISAGREED with the misapplied the Annual WCO assessment of MAXIMUM stay Administrative Limit rather time. _____ _____ _____
than the RWP limit END
Page 4 of 5 A1JPM-SRO-ADMIN-RWP3 ANSWER KEY JPM INITIAL TASK CONDITIONS:
- Decay Heat Removal Pump P-34A has indications of a leak on the pump inboard seal.
- The WCO is going to quantify the leakage from the P-34A seal.
- This is NOT an emergency
- His total dose for the year is currently 1950 mrem.
- He is a qualified CAT 3 Advanced Rad Worker.
- RWP, 20201002 Task 1 governs the planned activity INITIATING CUE:
Your WCO determined that he has an allowable stay time of 25 minutes.
What is your calculated MAXIMUM allowable stay time?
_____10.0 minutes________ (C)
- Calculated MAXIMUM stay time at the P-34A pump inboard seal area.
20 mR X 60 min = 10.0 minutes (8-10 minutes) (C) 120 mR/hr 1 hr Do you AGREE or DISAGREE with the WCO? (circle one) (C)
NOTE:
If you use the Admin Limit of 50 mR the MAXIMUM allowable stay time would be 25 minutes.
Page 5 of 5 A1JPM-SRO-ADMIN-RWP3 EXAMINEES COPY JPM INITIAL TASK CONDITIONS:
- Decay Heat Removal Pump P-34A has indications of a leak on the pump inboard seal.
- The WCO is going to quantify the leakage from the P-34A seal.
- This is NOT an emergecy
- His total dose for the year is currently 1950 mrem.
- He is a qualified CAT 3 Advanced Rad Worker.
- RWP, 20201002 Task 1 governs the planned activity INITIATING CUE:
Your WCO determined that he has a MAXIMUM allowable stay time of 25 minutes.
What is your calculated MAXIMUM stay time?
Do you AGREE or DISAGREE with the WCO? (circle one)
Survey: ANO-1606-0004 ANO Thursday, June 30, 2016 Template: 1a1-05_jpg Page 1 of 1 Details Smear Data (DPM/100cm2) 1 20000 DPM Unit: 1 2 25000 DPM Building: RAB 3 30000 DPM Elevation: 317 4 35000 DPM Room: 13 RxPwr: 100 LAS Data (ccpm/LAS)
Template: 1a1-05_jpg 1 6000 ccpm/LAS Frequency: 10CFR50.75G Decomm 2 <100 ccpm/LAS Survey Date: 08/22/2016 3/25/202015:58 3 <100 ccpm/LAS Status: In-Progress 4 <100 ccpm/LAS Rwp: 20161001 20201002 B/G to Alpha Ratio Hydro Inj Rate: NA Surveyed By: Harrell, John Alpha Data (DPM/100cm2) Badge: 20970 Reviewed By:
DPM Notes:
Instruments Used Instrument: LM-177 CHP-CR-148 100 Cal Due Date: 5/31/2020 7/31/2016 SrcChk Date: 6/29/2016 4/30/2020 DC & Bkg: NA NA MDA: NA 120 Instrument: 9-3 CHP-DR-331 120 Cal Due Date: 12/31/2016 5/31/2020 SrcChk Date: 4/30/2020 6/29/2016 DC & Bkg: NA NA MDA: NA 105
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP
Title:
OPERATIONS ACTIVITIES UNIT-1 (Bulk Work) RWP No.:
20201002 Rev. 00 Comments:
- 20201002*
RWP Type: GENERAL RWP Status: Begin Date: Close On Date:
ACTIVE 1/1/2020 12/31/2020 Prepared By: KOWALEWSKI, JACOB J Job Supervisor: Unit 1 Operations Shift Supervisor Estimated Dose: Estimated Hours: Actual Dose: Actual Hours:
900 mrem 14,500.00 39 mrem 494.46 Locations Buildings Elevations Rooms LOW LEVEL RADWASTE BUILDING 354 NON-LOCKED HIGH RADIATION AREA OLD RADWASTE BUILDING 354 NON-LOCKED HIGH RADIATION AREA OUTSIDE CONTROLLED ACCESS ALL OUTSIDE CONTROLLED ACCESS UNIT 1 AUXILIARY BUILDING ALL NON-LOCKED HIGH RADIATION AREA Radiological Conditions Description Value Unit Smear data is in dpm/100 cm2 unless otherwise noted. <1K - 40K DPM/100CM2 General area gamma dose rates are in mrem/hour unless otherwise noted. 0.2 - 200 MILLIREM/HOUR Tasks Task Description Status 1 OPERATIONS ACTIVITIES UNIT-1 Active 2 OPERATIONS TRAINEE ACTIVITIES UNIT-1 Active Requirements Requirement Groups Requirement Descriptions N/A Additional Instructions Instruction 1:
Instruction 2:
Instruction 3:
Approvals Approver Title Name Date ALARA REVIEW KOWALEWSKI, JACOB J 12/04/2019 RWP PREPARER LAQUE, NICHOLAS J 12/03/2019 RP SUPERVISOR FOLEY, CHRISTOPHER J 12/05/2019 Attachments N/A 1/13/2020 3:03:32PM Page 1 of 7
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP No.: 20201002 Task Number: 1 Rev.: 00 Task
Description:
OPERATIONS ACTIVITIES UNIT-1 Task Status: Active Estimate Dose: 850.00 Estimate Hours: 13,500.00 Hot Particle: Hi-Contamination:
Hi-Rad: Yes Yes Locked Hi-Rad: No Yes Alarm Settings Dose Alarm (mrem) 20.00 Dose Rate (mrem/hr) 200.00 Requirements Requirement Groups Requirement Descriptions Contamination Control All materials are required to be surveyed in a small articles monitor or hand frisked by RP (with RP Supervisor approval) PRIOR TO unconditional release from a Radiologically Controlled Area.
IF the RCA is a satellite RCA with no whole body contamination monitor available, THEN the radworker should: a) perform a hand and foot frisk. b) IF the frisk indicates contamination is present, THEN contact RP. c) IF the frisk DOES NOT indicate the presence of contamination, THEN proceed to the nearest whole body contamination monitor and gamma sensitive monitor.
If the RCA is a satellite RCA, and a "Contamination Area" is entered, the radworker will perform a whole body frisk. The radworker must then clear ARGOS (or PCM-1B) AND GEM-5 (or PM-7).
Notify RP prior to exposing a contaminated surface or opening a contaminated system.
Obey the monitoring instructions posted at the RCA exit point Upon exit of an RCA, whole body monitoring is required utilizing a whole body contamination monitor (ARGOS or equivalent). A whole body gamma monitor must also be cleared (GEM 5 or equivalent).
Upon exiting areas posted as "Contamination Area", perform a hand and foot frisk at the designated frisker location.
Use RP approved mats or pads when kneeling, sitting or laying in contaminated areas.
Use face shield for activities that have increased risk of facial contamination. These activities include working with contaminated components overhead, or having a body position that presents the potential for facial contamination.
With RP approval, reaching across a contamination boundary is permitted using surgeon's gloves OR cotton liners with rubber gloves. When reaching into the area of higher contamination, gloves must be removed when hands are returned to the lower level side of the boundary.
Dosimetry Requirements FOR WORK IN HIGH RADIATION AREAS - If your work conditions are in OR will cause hearing impairment (such as work in a high noise area, use of a communications headset, etc.) THEN the use of an SRD amplifying device (PAM) is required.
If an SRD dose alarm occurs: 1) Secure Work. 2) Immediately leave the RCA. 3)
Notify RP.
If an SRD dose rate alarm occurs: 1) Secure Work. 2) Back out of the immediate area until the alarm clears. 3) Notify others in your work crew. 4) Immediately notify RP for further instructions.
Periodically check your SRD. This check should be performed more frequently in areas where your ability to hear is diminished.
Whole body DLR and SRD required for entry.
1/13/2020 3:03:32PM Page 2 of 7
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP No.: 20201002 Task Number: 1 Rev.: 00 Requirements Requirement Groups Requirement Descriptions Engineering Controls Consider having a HEPA Ventilation unit or HEPA vacuum in service prior to the start of a potential airborne radioactivity causing evolution.
When venting or draining, monitor the rate of system drain to ensure the rate of drain does NOT exceed the capacity of the floor drain.
Refer to TEDE Screening Document for guidance concerning contamination levels and confinement factors necessary to maintain airborne radioactivity levels <30% DAC.
Surface wetting, misting, or encapsulation should be considered to reduce the risk of airborne radioactivity.
Exposure Reduction Minimize crew size to reduce overall exposure for the job.
Move components to a low dose area for work when practical.
Use Low Dose Waiting Areas whenever possible to minimize exposure.
Remove unnecessary personnel from affected areas when moving material with dose rates of concern.
Protective Requirements Entry into Contamination Areas require single Anti-Cs.
Entry into High Contamination Areas require double Anti-Cs .
The outer layer of protective clothing is to be water repellent when working with water or wet components.
With RP approval prior to each entry, partial Protective Clothing (booties, rubber shoe covers, cotton liners, and rubber gloves) may be worn in lieu of a full set of PCs to access a Contamination Area (CA) where the known contamination is less than or equal to 10,000 dpm / 100 cm2. Any activities that require kneeling, sitting, climbing, or leaning against surfaces will require the use of full PCs.
RP Coverage Entry into High Radiation Areas requires a radiological brief from RP, AND an electronic alarming dosimeter (SRD) to meet Tech Spec monitoring requirements.
Notify RP when performing operations activities which could change plant radiological conditions. For example venting/draining radioactive systems, performing degas or decay heat/shutdown cooling operations, or other non routine system functions.
Radiation Worker Self-Briefing - WHEN the following conditions are met, THEN the worker may enter the RCA without directly interfacing with RP (the following radiological conditions must be true): 1) dose rate in work area and travel path <25 mrem/hr and area is not posted HRA 2) work area contamination levels are <10K dpm/100 cm2 AND area is not posted HCA 3) work is not in Alpha Level 2 or 3 area 4 area is not posted Airborne Radioactivity Area 5) access above 7' above floor is not required 6) work is not abrasive (cutting, welding, grinding etc) 7) work does not involve movement of radioactive material from RA, HRA, or LHRA 8) no opening of contaminated containers 9) no breach of contaminated systems 10) The work does not involve system operation, such as opening a valve that may allow radioactive material transfer through a pipe. ***If any of the Self-Brief criteria cannot be met, THEN, contact RP prior to starting work.***
Radiological Conditions Dose rates may increase as the water level is lowered.
Radiological conditions should be reviewed to ensure awareness of conditions in your work area. This information can be obtained from either a Status Board or RP personnel.
RP should monitor for dose gradients and relocate dosimetry as necessary using guidance from EN-RP-204. Contact ALARA if relocation is warranted.
Respiratory Protection Based on historical and current data, the airborne radioactivity is less than 30 percent of a DAC. Respiratory protection is not required unless otherwise directed by RP Supervision.
1/13/2020 3:03:32PM Page 3 of 7
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP No.: 20201002 Task Number: 1 Rev.: 00 Requirements Requirement Groups Requirement Descriptions Special Radiological Requirements The prerequisite for a secondary resin transfer include 1) Secure the fill head such that changes in pressure will not cause a spill. 2) Conduct a walkdown (pre-transfer) to ensure that hose connections and leak integrity is satisfactory. 3) Construct a berm sufficient to contain the material being transferred.
Stop Work Criteria Critical Step - If UNEXPECTED alpha contamination > or equal to 500 dpm/100cm2 is detected, Then stop work and follow the guidance in EN RP 122.
Critical Step - Indications either from local samples or remote indication (CAM) of airborne radioactivity in quantities in excess of 30 percent of a DAC.
Critical Step - Loss of control of radioactive material such that loose surface contamination exceeds area postings.
Critical Step - RWP package contains TEDE Screening. Inability to remain within the bounds for contamination levels and confinement factors (specified in the TEDE Screening) will require that work be stopped.
Critical Step - Radiation dose rates in the immediate area are greater than the SRD dose rate alarm set point.
Additional Instructions Instruction 1:
Instruction 2:
Instruction 3:
Instruction 4:
Instruction 5:
Attachments N/A 1/13/2020 3:03:32PM Page 4 of 7
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP No.: 20201002 Task Number: 2 Rev.: 00 Task
Description:
OPERATIONS TRAINEE ACTIVITIES UNIT-1 Task Status: Active Estimate Dose: 50.00 Estimate Hours: 1,000.00 Hot Particle: Hi-Contamination:
Hi-Rad: Yes Yes Locked Hi-Rad: No Yes Alarm Settings Dose Alarm (mrem) 15.00 Dose Rate (mrem/hr) 150.00 Requirements Requirement Groups Requirement Descriptions Contamination Control All materials are required to be surveyed in a small articles monitor or hand frisked by RP (with RP Supervisor approval) PRIOR TO unconditional release from a Radiologically Controlled Area.
IF the RCA is a satellite RCA with no whole body contamination monitor available, THEN the radworker should: a) perform a hand and foot frisk. b) IF the frisk indicates contamination is present, THEN contact RP. c) IF the frisk DOES NOT indicate the presence of contamination, THEN proceed to the nearest whole body contamination monitor and gamma sensitive monitor.
If the RCA is a satellite RCA, and a "Contamination Area" is entered, the radworker will perform a whole body frisk. The radworker must then clear ARGOS (or PCM-1B) AND GEM-5 (or PM-7).
Notify RP prior to exposing a contaminated surface or opening a contaminated system.
Obey the monitoring instructions posted at the RCA exit point Upon exit of an RCA, whole body monitoring is required utilizing a whole body contamination monitor (ARGOS or equivalent). A whole body gamma monitor must also be cleared (GEM 5 or equivalent).
Upon exiting areas posted as "Contamination Area", perform a hand and foot frisk at the designated frisker location.
Use RP approved mats or pads when kneeling, sitting or laying in contaminated areas.
Use face shield for activities that have increased risk of facial contamination. These activities include working with contaminated components overhead, or having a body position that presents the potential for facial contamination.
With RP approval, reaching across a contamination boundary is permitted using surgeon's gloves OR cotton liners with rubber gloves. When reaching into the area of higher contamination, gloves must be removed when hands are returned to the lower level side of the boundary.
Dosimetry Requirements FOR WORK IN HIGH RADIATION AREAS - If your work conditions are in OR will cause hearing impairment (such as work in a high noise area, use of a communications headset, etc.) THEN the use of an SRD amplifying device (PAM) is required.
If an SRD dose alarm occurs: 1) Secure Work. 2) Immediately leave the RCA. 3)
Notify RP.
If an SRD dose rate alarm occurs: 1) Secure Work. 2) Back out of the immediate area until the alarm clears. 3) Notify others in your work crew. 4) Immediately notify RP for further instructions.
Periodically check your SRD. This check should be performed more frequently in areas where your ability to hear is diminished.
Whole body DLR and SRD required for entry.
1/13/2020 3:03:32PM Page 5 of 7
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP No.: 20201002 Task Number: 2 Rev.: 00 Requirements Requirement Groups Requirement Descriptions Engineering Controls Consider having a HEPA Ventilation unit or HEPA vacuum in service prior to the start of a potential airborne radioactivity causing evolution.
When venting or draining, monitor the rate of system drain to ensure the rate of drain does NOT exceed the capacity of the floor drain.
Refer to TEDE Screening Document for guidance concerning contamination levels and confinement factors necessary to maintain airborne radioactivity levels <30% DAC.
Surface wetting, misting, or encapsulation should be considered to reduce the risk of airborne radioactivity.
Exposure Reduction Minimize crew size to reduce overall exposure for the job.
Move components to a low dose area for work when practical.
Use Low Dose Waiting Areas whenever possible to minimize exposure.
Remove unnecessary personnel from affected areas when moving material with dose rates of concern.
Protective Requirements Entry into Contamination Areas require single Anti-Cs.
Entry into High Contamination Areas require double Anti-Cs .
The outer layer of protective clothing is to be water repellent when working with water or wet components.
With RP approval prior to each entry, partial Protective Clothing (booties, rubber shoe covers, cotton liners, and rubber gloves) may be worn in lieu of a full set of PCs to access a Contamination Area (CA) where the known contamination is less than or equal to 10,000 dpm / 100 cm2. Any activities that require kneeling, sitting, climbing, or leaning against surfaces will require the use of full PCs.
RP Coverage Entry into High Radiation Areas requires a radiological brief from RP, AND an electronic alarming dosimeter (SRD) to meet Tech Spec monitoring requirements.
Notify RP when performing operations activities which could change plant radiological conditions. For example venting/draining radioactive systems, performing degas or decay heat/shutdown cooling operations, or other non routine system functions.
Radiation Worker Self-Briefing - WHEN the following conditions are met, THEN the worker may enter the RCA without directly interfacing with RP (the following radiological conditions must be true): 1) dose rate in work area and travel path <25 mrem/hr and area is not posted HRA 2) work area contamination levels are <10K dpm/100 cm2 AND area is not posted HCA 3) work is not in Alpha Level 2 or 3 area 4 area is not posted Airborne Radioactivity Area 5) access above 7' above floor is not required 6) work is not abrasive (cutting, welding, grinding etc) 7) work does not involve movement of radioactive material from RA, HRA, or LHRA 8) no opening of contaminated containers 9) no breach of contaminated systems 10) The work does not involve system operation, such as opening a valve that may allow radioactive material transfer through a pipe. ***If any of the Self-Brief criteria cannot be met, THEN, contact RP prior to starting work.***
Radiological Conditions Dose rates may increase as the water level is lowered.
Radiological conditions should be reviewed to ensure awareness of conditions in your work area. This information can be obtained from either a Status Board or RP personnel.
RP should monitor for dose gradients and relocate dosimetry as necessary using guidance from EN-RP-204. Contact ALARA if relocation is warranted.
Respiratory Protection Based on historical and current data, the airborne radioactivity is less than 30 percent of a DAC. Respiratory protection is not required unless otherwise directed by RP Supervision.
1/13/2020 3:03:32PM Page 6 of 7
Entergy Arkansas Nuclear One RADIOLOGICAL WORK PERMIT
- For Informational Use Only *****
Consult Posted Copy for Official Radiological Work Permit Information RWP No.: 20201002 Task Number: 2 Rev.: 00 Requirements Requirement Groups Requirement Descriptions Special Radiological Requirements The prerequisite for a secondary resin transfer include 1) Secure the fill head such that changes in pressure will not cause a spill. 2) Conduct a walkdown (pre-transfer) to ensure that hose connections and leak integrity is satisfactory. 3) Construct a berm sufficient to contain the material being transferred.
Stop Work Criteria Critical Step - If UNEXPECTED alpha contamination > or equal to 500 dpm/100cm2 is detected, Then stop work and follow the guidance in EN RP 122.
Critical Step - Indications either from local samples or remote indication (CAM) of airborne radioactivity in quantities in excess of 30 percent of a DAC.
Critical Step - Loss of control of radioactive material such that loose surface contamination exceeds area postings.
Critical Step - RWP package contains TEDE Screening. Inability to remain within the bounds for contamination levels and confinement factors (specified in the TEDE Screening) will require that work be stopped.
Critical Step - Radiation dose rates in the immediate area are greater than the SRD dose rate alarm set point.
Additional Instructions Instruction 1:
Instruction 2:
Instruction 3:
Instruction 4:
Instruction 5:
Attachments N/A 1/13/2020 3:03:32PM Page 7 of 7
ADMINISTRATIVE JOB PERFORMANC MEASURE A1JPM-SRO-EAL18 Page 1 of 5 UNIT: 1 REV # 0 DATE: ___________________
SYSTEM/DUTY AREA: Administrative Topic - Emergency Procedures / Plan TASK: Classify an Emergency Event JTA: ANO-SRO-EPLAN-EMERG-278 KA VALUE RO: 2.9 SRO: 4.6 KA
REFERENCE:
2.4.41 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR: OUTSIDE CR:___ ______ BOTH:___X_____
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE _____________ SIMULATOR: Classroom: __PERFORM______
POSITION EVALUATED: RO:_______ SRO:____X_______
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE:__________ Classroom: ___ X___
TESTING METHOD: SIMULATE:_________ PERFORM: X APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): 1903.010 EAL Classification and 1903.011 Emergency Response Notification EXAMINEE'S NAME:___________________ _____________ Logon: _______________________
EVALUATOR'S NAME:__________________________________________________________________
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY:________________ UNSATISFACTORY:_________________
PERFORMANCE CHECKLIST COMMENTS:
Start Time ____________ Stop Time ____________ Total Time______________
SIGNED _Robert Possage_______________________________ DATE: _______________________
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
ADMINISTRATIVE JOB PERFORMANC MEASURE A1JPM-SRO-EAL18 Page 2 of 5 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the applicant has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS:
- There are no Security Events in progress.
- Reactor Power at 15%
- B Steam Generator Tube leak confirmed at 20 gpm
- S/U #1 supplying A1, A2, H1, & H2.
- ATC depressed Rx Trip Pushbutton and power remained at 15%
- ATC depressed CRD Power Supply Breaker Trip Pushbuttons on C03 and all rods inserted and reactor power dropping TASK STANDARD:
Applicant correctly classifies this event (within 15 minutes of the completion of reading the initiating cue to the applicant) as a SU6.2, A manual trip did not shut down the reactor as indicated by reactor power >5%
after any manual trip action was initiated AND A subsequent automatic trip or manual trip action taken at the reactor control console (C03) (manual reactor trip pushbuttons or DROPS) is successful in shutting down the reactor as indicated by reactor power <5% and completes paperwork through step 6 of the applicable Emergency Direction and Control Checklist in 1903.011 (1903.011P).
TASK PERFORMANCE AIDS: OP-1903.010 Attachments 1 (Index of EALs), 2 (ANO EAL Basis Document) and 3 (EAL Matrix Chart), 1903.011 Attachment 1 (NUE), and 1903.011J (NUE ED&C Checklist)
THIS IS A TIME CRITICAL JPM.
Instructor Note: Read the Initiating Cue and record start time. The clock start time begins after the Initiating Cues have been read and acknowledged using three part communication.
ADMINISTRATIVE JOB PERFORMANC MEASURE A1JPM-SRO-EAL18 Page 3 of 5 INITIATING CUE: For the given plant conditions, determine the applicable EAL classification and complete paperwork through step 6 of the applicable Emergency Direction and Control checklist in 1903.011.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT
- 1. If EAL classification is known, then Proceeded to Tab S, System proceed to appropriate tab or on EAL Malfunction section of 1903.010 or on Matrix Chart. EAL Matrix Chart. ____ ____ ____
Record Start Time: __________
- 2. If EAL classification is not known, Turned to Attachment 1 of 1903.010, then compare the abnormal conditions Index of EALs or reviewed EAL Matrix with those listed in Attachment 1 "Index Chart. ____ ____ ____
of Emergency Action Levels" or on EAL Matrix Chart.
- 3. Turn to the appropriate tab which Proceeded to Tab S, System corresponds to the condition picked Malfunction section of 1903.010 or on from the Index of EALs or on EAL EAL Matrix Chart. ____ ____ ____
Matrix Chart.
- 4. Assess the information available from Turned to the specific EAL in Tab S, valid indications or reports. Turn to System Malfunction section of appropriate EAL and compare EAL 1903.010 or on EAL Matrix Chart. ____ ____ ____
criteria with event conditions. Also review any related EALs.
SU6.2, A manual trip did not
- 5. Declare the Emergency shut down the reactor as C Classification. indicated by reactor power >5%
after any manual trip action was initiated AND A subsequent Record Stop Time: __________ automatic trip or manual trip action taken at the reactor control console (C03) (manual ____ ____ ____
reactor trip pushbuttons or DROPS) is successful in shutting down the reactor as indicated by reactor power <5%
CONTINUED
ADMINISTRATIVE JOB PERFORMANC MEASURE A1JPM-SRO-EAL18 Page 4 of 5 JPM ID: A1JPM-SRO-MSSV C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSA T
EXAMINER CUE: If asked, the ERO has not been activated.
- 6. Begin completion of form 1903.011J, Began completion of form 1903.011J, C NUE Emergency Direction and Control NUE Emergency Direction and Checklist. Control Checklist.
Applicant should N/A step 1 and fill in the data on steps 2 and 3.
Applicant should simulate (or state) ____ ____ ____
POSITIVE CUE: direction of a Control Room Communicator has activated Communicator to activate Everbridge Everbridge. per Attachment 9, ERO Notification System Section 1.0.
POSITIVE CUE: Applicant should simulate (or state)
Communicator has started initial direction of a Control Room notifications. Communicator to perform notifications using Form 1903.011-Y, Emergency Class Initial Notification Message.
- 7. Inform the Control Room Staff of the Announced NUE to the crew (or Emergency Class declaration. words to that effect).
POSITIVE CUE: ____ ____ ____
Crew understands NUE.
NEGATIVE CUE:
Crew understands __________
EXAMINER CUE: This concludes the JPM.
END
ADMINISTRATIVE JOB PERFORMANC MEASURE A1JPM-SRO-EAL18 Page 5 of 5 Applicants Copy THIS IS A TIME CRITICAL JPM.
INITIAL CONDITIONS:
- There are no Security Events in progress.
- Reactor Power at 15%
- B Steam Generator Tube leak confirmed at 20 gpm
- S/U #1 supplying A1, A2, H1, & H2.
- ATC depressed Rx Trip Pushbutton and power remained at 15%
- ATC depressed CRD Power Supply Breaker Trip Pushbuttons on C03 and all rods inserted and reactor power dropping INITIATING CUE:
For the given plant conditions, determine the applicable EAL classification and complete paperwork through step 6 of the applicable Emergency Direction and Control Checklist in 1903.011.
TIME BEGINS NOW.
Record Start Time: _______________________
Page 1 of 7 JOB PERFORMANCE MEASURE Unit: 1 Rev # 10 Date:
JPM NUMBER: A1JPM-RO-CHEM1 System/Duty Area: Primary Chemical Addition Task: Perform RCS Boration, Batch Feed Method JA# ANO1-RO-CA-NORM-6 KA Value RO 3.9 SRO 3.7 KA Reference 004 A4.07 Approved For Administration To: RO X SRO Task Location: Inside CR: X Outside CR: Both:
Suggested Testing Environment And Method (Perform Or Simulate):
Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: X SRO:
Actual Testing Environment: Simulator: X Plant Site: Lab Testing Method: Simulate: Perform: X Approximate Completion Time In Minutes: 10 Minutes Reference(S): 1103.004, Rev. 034, Section 8 and Exhibit A Examinee's Name: Logon ID:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time Signed Robert Possage Date:
Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 7 TUOI NUMBER: ANO-1-JPM-RO-CHEM1 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS:
Makeup Tank level is to be raised by 20 inches. Calculations have determined that 50 gallons of boric acid and 550 gallons of water are required to be added to maintain present boron concentration (Rx is critical). 1103.004 is completed through step 8.1.5.
TASK STANDARD:
50 gallons of boric acid added as indicated by the batch controller.
TASK PERFORMANCE AIDS: Copy of 1103.004 section 8.0 and Exhibit A Simulator Setup:
Set batch size to something other than 50 gallons.
Set valve position to something greater than 20%.
Page 3 of 7 TUOI NUMBER: ANO-1-JPM-RO-CHEM1 INITIATING CUE: The SM/CRS directs you to perform a manual batch feed addition of 50 gallons of boric acid to the makeup tank in accordance with 1103.004, starting at step 8.2.
CRITICAL ELEMENTS (C): 8.2, 8.5, 8.8, and 8.9 UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT C 8.2 SET UP Batch Controller for the required batch size Upper display indicated 50 gallons.
and OBTAIN Licensed Operator confirmation per Lower display indicated zero gallons.
Exhibit A, Setting Up the Batch Controller (Reference Use).
EXAMINER NOTE: The following is from Exhibit A, Setting Up the Batch Controller.
1.1 DEPRESS upper DISPLAY key and DEPRESS Depressed upper DISPLAY key, then BATCH key. BATCH key. Upper display showed previous batch size. ____ ____ ____
POSITIVE CUE:
Upper display shows previous batch size.
1.2 DEPRESS lower DISPLAY key and DEPRESS Depressed lower DISPLAY key, then TOTAL key. TOTAL key. Lower display showed previous batch total. ____ ____ ____
POSITIVE CUE:
Lower display shows previous batch total.
1.3 DEPRESS TOTAL RESET key and OBSERVE Depressed TOTAL RESET key.
lower display indicates "0". Observed that the lower display ____ ____ ____
indicated 0.
POSITIVE CUE:
Lower display indicates zero.
EXAMINER NOTE: Step 2.1 is not applicable.
2.2 DEPRESS BATCH SET key. Depressed BATCH SET key to set batch size.
POSITIVE CUE: ____ ____ ____
Lower display indicates 50.
2.3 DEPRESS appropriate keys for desired batch size Depressed 5, 0 keys if not already from Attachment B, RCS Liquid Addition Data displayed.
Sheet. ____ ____ ____
POSITIVE CUE:
Lower display indicates 50.
2.4 CHECK lower display indicates desired batch size. Lower display indicated 50 gallons.
POSITIVE CUE: ____ ____ ____
Lower display indicates 50.
2.5 DEPRESS ENTER key. Depressed ENTER key.
POSITIVE CUE: ____ ____ ____
Upper display indicates 50.
2.6 CHECK upper display indicates proper batch size. Upper display indicated 50 gallons.
POSITIVE CUE: ____ ____ ____
Upper display indicates 50.
Page 4 of 7 UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT 2.7 OBTAIN Licensed Operator confirmation of Obtained Licensed Operator required batch size confirmation of required batch size.
POSITIVE CUE:
Licensed Operator confirmed batch size.
2.8 DEPRESS lower DISPLAY key. Depressed lower DISPLAY key.
POSITIVE CUE: ____ ____ ____
Lower DISPLAY key depressed.
2.9 CHECK lower display is still "0". Lower display indicated zero gallons.
POSITIVE CUE: ____ ____ ____
Total indicates zero.
3.0Adjusting Batch Controller Flow Control Valve N/A (CV-1249) ____ ____ ____
POSITIVE CUE:
N/A 3.1 DEPRESS VALVE SET key. Depressed VALVE SET key, displayed previous valve setting. ____ ____ ____
POSITIVE CUE:
Lower display indicates 100%.
3.2 PERFORM ONE of the following: Depressed 2, 0 keys if not already
- IF this is for a boric acid addition, THEN displayed. ____ ____ ____
DEPRESS [20].
POSITIVE CUE:
Lower display indicates 20 3.3 DEPRESS ENTER. Depressed ENTER POSITIVE CUE:
Enter key depressed.
3.4 CONFIRM VALVE SET indicates the demanded VALVE SET indicated 20%
valve position in lower display. ____ ____ ____
POSITIVE CUE:
Valve set indicates 20%
3.5 OBTAIN Licensed Operator confirmation of Obtained Licensed Operator VALVE SET. confirmation of required batch size. ____ ____ ____
POSITIVE CUE:
Licensed Operator confirmation obtained for valve setting 3.6 DEPRESS lower display key. Lower display key depressed.
POSITIVE CUE:
Lower display key depressed.
3.7 DEPRESS TOTAL key to return lower display to TOTAL key depressed and lower TOTAL. display indicated 0 ____ ____ ____
POSITIVE CUE:
Total key depressed and lower display indicates 0
Page 5 of 7 TUOI NUMBER: ANO-1-JPM-RO-CHEM1 UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT EXAMINER NOTE: Back to 1103.004 8.3 ENSURE Letdown 3-Way Valve (CV-1248) is in Verified CV-1248 is in the the LETDOWN position. LETDOWN position. ____ ____ ____
POSITIVE CUE:
CV-1248 in LETDOWN position.
8.4 ENSURE Condensate to Batch Controller Verified CV-1251 is closed (CV-1251) closed. ____ ____ ____
POSITIVE CUE:
Green light on Red light off for CV-1251 8.5 OPEN Batch Controller Outlet (CV-1250). Opened CV-1250 C ____ ____ ____
POSITIVE CUE:
Red light on Green light off for CV-1250 8.6 IF Makeup Filter (F-3A, F-3B) flow will exceed Placed idle letdown filter (F3) filter 80 gpm/filter during this evolution, THEN in service ____ ____ ____
PLACE an additional Makeup Filter into service:
- OPEN Makeup Filter Inlet to F-3A (CV-1246).
- OPEN Makeup Filter Inlet to F-3B (CV-1247).
POSITIVE CUE:
Both letdown filters (F3A and F3B) are in service.
EXAMINER NOTE: Step 8.7 was completed during the performance of Exhibit A, which set CV-1249 to 20% open.
Step 8.8 will be performed from C04, the option to start the pump locally is not applicable.
8.8 Placing desired Boric Acid Pump(s) (P-39A or Started P-39A and/or P-39B Boric P-39B or both) into service: Acid Pump(s) ____ ____ ____
C
- START Boric Acid Pump (P-39A) at EITHER of the following:
- Panel C04
- START Boric Acid Pump (P-39B) at EITHER of the following:
- Panel C04 POSITIVE CUE:
P-39A/B running (Red light on Green light off) 8.8.1 MONITOR for rise in discharge pressure. Checked for rise in discharge pressure. ____ ____ ____
POSITIVE CUE:
Discharge pressure indication rose to 70 psig 8.9 DEPRESS RUN key to start Batch Controller. Depressed RUN key.
C ____ ____ ____
POSITIVE CUE:
RUN key depressed, bottom display counting up towards 50.
Page 6 of 7 UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT EXAMINER NOTE: Step 8.10 is not applicable.
8.9.1 CHECK Boric Acid Pump (P-39A/B) discharge Checked P-39 discharge pressure pressure drops slightly on Boric Acid Pumps indication dropped slightly. ____ ____ ____
Discharge Press (PI-1608B).
POSITIVE CUE:
P-39 discharge pressure drops slightly.
8.9.2 IF discharge pressure does NOT drop slightly, N/A THEN: ____ ____ ____
A. STOP running Boric Acid pumps.
B. TAKE corrective action.
POSITIVE CUE:
P-39 discharge pressure drops slightly 8.11 IF Batch Controller automatically terminates at Checked red STOP light lit on C batch total OR batch must be interrupted, THEN: BATCH Controller. ____ ____ ____
POSITIVE CUE:
Red STOP light lit on BATCH Controller 50 gallons added to the Makeup Tank NEGATIVE CUE:
Red STOP light lit on BATCH Controller XX gallons added to the Makeup Tank 8.11.1 SECURE the running boric acid pump(s) within Stopped boric acid pump(s) within 30 30 seconds as follows: seconds after Batch Controller stops. ____ ____ ____
- STOP Boric Acid Pump (P-39A) at EITHER of the following:
- Panel C04
- STOP Boric Acid Pump (P-39B) at EITHER of the following:
- Panel C04 POSITIVE CUE:
Green lights ON for both boric acid pump(s).
END
Page 7 of 7 TUOI NUMBER: ANO-1-JPM-RO-CHEM1 INITIAL CONDITIONS:
Makeup Tank level is to be raised by 20 inches.
Calculations have determined that a 50 gallons of boric acid and 550 gallons of water are required to be added to maintain present boron concentration (Rx is critical).
1103.004 is completed through step 8.1.5.
INITIATING CUE:
The SM/CRS directs you to perform a manual batch feed addition of 50 gallons of boric acid to the makeup tank in accordance with 1103.004, starting at step 8.2.
PAGE: 19 of 116 1103.004 SOLUBLE POISON CONCENTRATION CONTROL CHANGE: 034 8.1.2 IF needed, THEN COMPLETE Attachment A.10, BAAT Inventory Planning Sheet.
8.1.3 REFER TO Attachment A.8, Estimation of Time to Complete a Concentration Change After MUT Addition.
8.1.4 IF plant cooldown or plant heatup is NOT being performing, AND if desired, THEN GO TO Attachment H, Batch Controller Operation.
CAUTION Proper batching of DI water to the Makeup Tank (T-4) during high Condensate Transfer System usage can require two Condensate Transfer Pumps (P-9A, P-9B) in service to provide adequate pressure. (CR-ANO-1-2012-1045) 8.1.5 IF intending to add DI water after the boric acid addition, THEN CHECK Condensate Transfer system in service.
NOTE Boric acid and water volume are aligned as separate batches with Boric acid and then water.
8.2 SET UP Batch Controller for the required batch size and OBTAIN Licensed Operator confirmation per Exhibit A, Setting Up the Batch Controller (Reference Use).
8.3 ENSURE Letdown 3-Way Valve (CV-1248) is in the LETDOWN position.
CAUTION If Condensate to Batch Controller (CV-1251) is not closed, moderator dilution can occur.
8.4 ENSURE Condensate to Batch Controller (CV-1251) closed.
8.5 OPEN Batch Controller Outlet (CV-1250).
8.6 IF Makeup Filter (F-3A, F-3B) flow will exceed 80 gpm/filter during this evolution, THEN PLACE an additional Makeup Filter into service:
- OPEN Makeup Filter Inlet to F-3A (CV-1246).
- OPEN Makeup Filter Inlet to F-3B (CV-1247).
PAGE: 20 of 116 1103.004 SOLUBLE POISON CONCENTRATION CONTROL CHANGE: 034 NOTE
- Batch Controller Flow Control Valve (CV-1249) should normally be opened no more than 20% for feeding boric acid. Further opening reduces the accuracy of the batch totalizer.
- If adding boric acid for plant cooldown in Mode 3 or Mode 4, Batch Controller Flow Control Valve (CV-1249) may be opened greater than 20% to maximize boric acid addition rate.
Change in BAAT level should be used to check the quantity of boric acid added.
8.7 PERFORM ONE of the following (8.7.1 or 8.7.2) to set Batch Controller Flow Control Valve (CV-1249):
8.7.1 IF boric acid addition is for plant cooldown in Mode 3-4, THEN:
A. DEPRESS VALVE SET key.
B. DEPRESS value for desired valve opening.
C. DEPRESS ENTER.
D. CONFIRM VALVE SET indicates the demanded valve position in lower display.
E. DEPRESS lower display key.
F. DEPRESS TOTAL key to return lower display to TOTAL.
G. MONITOR BAAT level to check quantity of boric acid added.
8.7.2 ADJUST Batch Controller Flow Control Valve (CV-1249) as needed per Exhibit A, Setting Up the Batch Controller (Reference Use).
PAGE: 21 of 116 1103.004 SOLUBLE POISON CONCENTRATION CONTROL CHANGE: 034 CAUTION Running a boric acid pump dead-headed for more than 30 seconds is prohibited.
8.8 Placing desired Boric Acid Pump(s) (P-39A or P-39B or both) into service:
- START Boric Acid Pump (P-39A) at EITHER of the following:
- Panel C04
- Boric Acid Panel C101
- START Boric Acid Pump (P-39B) at EITHER of the following:
- Panel C04
- Boric Acid Panel C101 8.8.1 MONITOR for rise in discharge pressure.
8.9 DEPRESS RUN key to start Batch Controller.
8.9.1 CHECK Boric Acid Pump (P-39A/B) discharge pressure drops slightly on Boric Acid Pumps Discharge Press (PI-1608B).
8.9.2 IF discharge pressure does NOT drop slightly, THEN:
A. STOP running Boric Acid pumps.
B. TAKE corrective action.
8.10 COORDINATE with Chemistry to sample RCS boron at each 30 ppmB interval.
8.10.1 IF boration is for other than normal activities such as significant boration to maintain rod position following power change, THEN DIRECT Chemistry to evaluate the potential effect of the shift in boron on lithium control band.
PAGE: 22 of 116 1103.004 SOLUBLE POISON CONCENTRATION CONTROL CHANGE: 034 CAUTION When Batch Controller is stopped, Boric Acid Pumps (P-39A and P-39B) will dead-head.
8.11 IF Batch Controller automatically terminates at batch total OR batch must be interrupted, THEN:
8.11.1 SECURE the running boric acid pump(s) within 30 seconds as follows:
- STOP Boric Acid Pump (P-39A) at EITHER of the following:
- Panel C04
- Boric Acid Panel C101
- STOP Boric Acid Pump (P-39B) at EITHER of the following:
- Panel C04
- Boric Acid Panel C101 8.11.2 IF batch must be interrupted, THEN DEPRESS STOP key on batch controller.
8.11.3 ENSURE Batch Controller Outlet (CV-1250) closed.
8.11.4 DEPRESS Batch Controller VALVE SET and CHECK lower display at 0% indicating CV-1249 is closed.
8.11.5 DEPRESS upper or lower display key for desired display.
8.11.6 IF CRS/SM directs, THEN PERFORM ONE of the following to remove extra Makeup Filter from service:
- CLOSE Makeup Filter Inlet to F-3A (CV-1246).
- CLOSE Makeup Filter Inlet to F-3B (CV-1247).
PAGE: 23 of 116 1103.004 SOLUBLE POISON CONCENTRATION CONTROL CHANGE: 034 8.12 IF batch was interrupted, THEN:
8.12.1 IF necessary to refill BAAT, THEN PERFORM boric acid mix operation per appropriate section of 1104.003, Chemical Addition.
8.12.2 IF batching operations are NOT complete, THEN RECORD this procedure and section as an evolution in progress in appropriate document (Shift Relief sheet, station log, etc).
8.12.3 RETURN TO step 8.3 and REPEAT this section.
8.13 IF condensate batch is required to follow boric acid batch, THEN:
8.13.1 SET UP Batch Controller for the required batch size and OBTAIN Licensed Operator confirmation per Exhibit A, Setting Up the Batch Controller (Reference Use).
8.13.2 IF Makeup Filter (F-3A, F-3B) flow will exceed 80 gpm/filter, THEN PLACE an additional Makeup Filter into service:
- OPEN Makeup Filter Inlet to F-3A (CV-1246).
- OPEN Makeup Filter Inlet to F-3B (CV-1247).
8.13.3 OPEN Condensate to Batch Controller (CV-1251).
8.13.4 OPEN Batch Controller Outlet (CV-1250).
8.13.5 DEPRESS RUN key to start Batch Controller.
8.13.6 ADJUST Batch Controller Flow Control Valve (CV-1249) to regulate flow as desired per Exhibit A, Setting Up the Batch Controller (Reference Use).
PAGE: 24 of 116 1103.004 SOLUBLE POISON CONCENTRATION CONTROL CHANGE: 034 8.13.7 WHEN desired volume is transferred OR automatically terminated by batch controller, THEN ENSURE the following valves closed:
- Batch Controller Outlet (CV-1250)
- Batch Controller Flow Control Valve (CV-1249) 8.13.8 CLOSE Condensate to Batch Controller (CV-1251).
8.13.9 IF CRS/SM directs, THEN PERFORM ONE of the following to remove extra Makeup Filter from service:
- CLOSE Makeup Filter Inlet to F-3A (CV-1246).
- CLOSE Makeup Filter Inlet to F-3B (CV-1247).
8.14 IF total feed volume was divided into multiple batches, THEN:
8.14.1 UPDATE Attachment B, RCS Liquid Addition Data Sheet with final data.
8.14.2 RETURN TO step 8.2 and REPEAT this section to complete desired total feed volume per the calculations.
8.15 UPDATE Attachment B, RCS Liquid Addition Data Sheet.
8.16 MONITOR for expected reactivity effects of boration.
8.17 ENSURE any procedure in progress entry related to this evolution is removed.
PAGE: 114 of 116 1103.004 SOLUBLE POISON CONCENTRATION CONTROL CHANGE: 034 1103.004 EXHIBIT A Revised 4/27/2017 PAGE 1 OF 2 SETTING UP THE BATCH CONTROLLER (Reference Use)
NOTE
- The following is the normal method for operating the Batch Controller.
- Other parameters and displays described in the Description section of this procedure may be used as desired.
1.0 Assigning Upper and Lower Displays and Resetting Total to Zero:
1.1 DEPRESS upper DISPLAY key and DEPRESS BATCH key.
1.2 DEPRESS lower DISPLAY key and DEPRESS TOTAL key.
1.3 DEPRESS TOTAL RESET key and OBSERVE lower display indicates "0".
2.0 Setting the Desired Batch Size:
2.1 IF "FAIL WDOG" is displayed, THEN GO TO Operation with "FAIL WDOG" on Batch Controller section of this procedure.
NOTE
- Depressing the BATCH SET key causes the lower display to indicate the previously set batch size.
- The BATCH SET function defaults to the lower display. The lower display will return to totalizer readout when BATCH SET function is complete.
2.2 DEPRESS BATCH SET key.
2.3 DEPRESS appropriate keys for desired batch size from Attachment B, RCS Liquid Addition Data Sheet.
2.4 CHECK lower display indicates desired batch size.
2.5 DEPRESS ENTER key.
2.6 CHECK upper display indicates proper batch size.
PAGE: 115 of 116 1103.004 SOLUBLE POISON CONCENTRATION CONTROL CHANGE: 034 1103.004 EXHIBIT A Revised 4/27/2017 PAGE 2 OF 2 2.7 OBTAIN Licensed Operator confirmation of required batch size.
NOTE The RUN key is disabled if the controller is left in the BATCH SET mode.
2.8 DEPRESS lower DISPLAY key.
2.9 CHECK lower display is still "0".
3.0 Adjusting Batch Controller Flow Control Valve (CV-1249) 3.1 DEPRESS VALVE SET key.
NOTE For feeding boric acid, Batch Controller Flow Control Valve (CV-1249) is opened no more than 20%. Further opening will not raise boric acid flow and reduces the accuracy of the batch totalizer.
3.2 PERFORM ONE of the following:
- IF this is for a boric acid addition, THEN DEPRESS [20].
- IF for DI Water, THEN DEPRESS desired value.
3.3 DEPRESS ENTER.
3.4 CONFIRM VALVE SET indicates the demanded valve position in lower display.
3.5 OBTAIN Licensed Operator confirmation of VALVE SET.
3.6 DEPRESS lower display key.
3.7 DEPRESS TOTAL key to return lower display to TOTAL.
SIMULATOR JOB PERFORMACE MEASURE Page 1 of 6 A1JPM-RO-EOP36 UNIT: 1 REV # 0 DATE: ___________________
SYSTEM/DUTY AREA: Emergency Core Cooling System (ECCS)
TASK: Perform Actions Required for Reactor Building Sump Blockage JTA#: ANO1-RO-EOP-EMERG-179205 KA VALUE RO: 3.9 SRO: 4.3 KA
REFERENCE:
006 A2.02 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR:_________ BOTH:________
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE _____________ SIMULATOR: Perform LAB:__________
POSITION EVALUATED: RO:_______ SRO:___________
ACTUAL TESTING ENVIRONMENT: SIMULATOR: X PLANT SITE:__________ LAB:________
TESTING METHOD: SIMULATE:_________ PERFORM: X APPROXIMATE COMPLETION TIME IN MINUTES: 10 MINUTES REFERENCE(S): RT-15 Shift to RB Sump Suction Step 3 EXAMINEE'S NAME:________________________________ Logon: _______________________
EVALUATOR'S NAME:__________________________________________________________________
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY:________________ UNSATISFACTORY:_________________
PERFORMANCE CHECKLIST COMMENTS:
Start Time ____________ Stop Time ____________ Total Time______________
SIGNED _Robert Possage_______________________________ DATE: _______________________
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
SIMULATOR JOB PERFORMACE MEASURE Page 2 of 6 A1JPM-RO-EOP36 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS: ESAS has actuated due to a LOCA, RB Sump Suction has been aligned.
You have been directed by the CRS to monitor for indications of RB Sump blockage per RT-15 TASK STANDARD: LPI Flow throttled to >2800 gpm / pump and Both Reactor Building Spray Pumps secured.
TASK PERFORMANCE AIDS: Copy of RT-15 Steps 3 and 4. .
This is an alternate path JPM (Step 3).
SUGGESTED SIMULATOR SETUP:
IC2, then insert large RCS leak so that full ESAS actuation occurs. Trip all RCPs and go to reflux boiling setpoint for EFW. Close CV-1000, CV-1008 and CV-1009, simulator is in FREEZE.
SIMULATOR JOB PERFORMACE MEASURE Page 3 of 6 A1JPM-RO-EOP36 INITIATING CUE: The SM/CRS directs you to perform Step 3 of RT-15.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT EXAMINER NOTE: Allow the applicant to review RT-15 actions while the simulator is in FREEZE, once they are ready to start place the simulator in RUN.
- 3. MONITOR for indications of RB sump blockage as Identified fluctuations in LPI flow for indicated by ONE or MORE P-34A/B on C16/18 of the following:
C
- Discharge press, suct press or flow on dedicated SPDS/PDS displays
- Flow on C16/C18
- LPI discharge press, suct press, or motor amps on dedicated PDS/PMS displays
- Discharge press, suct press, flow or motor amps on the SPDS points listed below:
NEGATIVE CUE:
Both LPI pumps indicating fluctuating flow.
SIMULATOR JOB PERFORMACE MEASURE Page 4 of 6 A1JPM-RO-EOP36 C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT
A. Re-verify suction flow path Verified CV-1405, CV-1406, CV-properly aligned as follows: 1414, CV-1415, CV-1436, and CV-1437 open
- 1) ENSURE the following valves open:
- CV-1405 CV-1406
- CV-1414 CV-1415
- P34A and P34B Pump ____ ____ ____
Suctions From BWST:
- CV-1436 CV-1437 POSITIVE CUE:
Red lights ON Green light OFF for CV-1405, CV-1406, CV-1414, CV-1415, CV-1436, and CV-1437.
B. THROTTLE Low Pressure On C16/18, Verified Low Pressure Injection (Decay Heat) Blocks Injection (Decay Heat) Blocks CV-to minimum flow listed below: 1400 and CV-1401 throttled to >
- CV-1400 2800 gpm/pump C
> 2800 > 3050 below 2800 gpm during gpm/pump gpm/pump adjustment does not constitute failure of this CRITICAL STEP, as POSITIVE CUE: long as the applicant responds to
> 2800 gpm/pump the annunciator alarm and raises flow back above 2800 gpm.)
SIMULATOR JOB PERFORMACE MEASURE Page 5 of 6 A1JPM-RO-EOP36 C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT EXAMINER NOTE: Based on correct assessment the applicant will stop BOTH Reactor Building Spray Pumps in the following steps.
C. IF BOTH trains of RB Spray are operating, THEN:
- 1) IF there is NO evidence of Containment breach, THEN: On C18, Verified Reactor Building Spray pump P-35A stopped and a) STOP BOTH RB Spray RB Spray Block Valve CV-2401 pumps: closed C
- P35A AND C
- P35B b) CLOSE BOTH RB Spray On C16, Verified Reactor Building Block valves: Spray pump P-35B stopped and ____ ____ ____
RB Spray Block Valve CV-2400
- CV-2401 closed
- CV-2400 c) GO TO step 4.E.
POSITIVE CUE:
Containment pressure is stable Green light ON, Red light OFF for P-35A, P-35B, CV-2401, and CV-2400 END
SIMULATOR JOB PERFORMACE MEASURE Page 6 of 6 A1JPM-RO-EOP36 Applicants Copy INITIAL CONDITIONS:
The SM/CRS directs you to monitor for RB Sump Blockage per RT-15 Step 3.
CHANGE 1202.012 REPETITIVE TASKS 022 PAGE 75 of 123 SHIFT TO RB SUMP SUCTION PAGE 7 OF 12
- Discharge press, suct press or flow on dedicated SPDS/PDS displays
- Flow on C16/C18
- LPI discharge press, suct press, or motor amps on dedicated PDS/PMS displays
- Discharge press, suct press, flow or motor amps on the SPDS points listed below:
SPDS Points to Monitor for RB Sump Blockage LPI RB Spray HPI P34A P34B P35A P35B P36A P36B P36C Disch Press P1404 P1405 P2426 P2425 P1241 P1242 P1243 Suct Press P1407 P1408 P2429 P2428 P1246 P1247 P1248 F1228 F1209 F1230 F1210 Flow F1401 F1402 F2401 F2400 F1231 F1211 F1232 F1212 Motor Amps I1A305 I1A405 1202.012 RT-15 Rev 10-20-19
CHANGE 1202.012 REPETITIVE TASKS 022 PAGE 76 of 123 SHIFT TO RB SUMP SUCTION PAGE 8 OF 12
A. Re-verify suction flow path properly aligned as follows:
- 1) ENSURE the following valves open:
- CV-1405 - CV-1406
- CV-1414 - CV-1415
- P34A and P34B Pump Suctions From BWST:
- CV-1436 - CV-1437
- 2) ENSURE BWST T3 Outlets closed:
- CV-1407
- CV-1408 B. THROTTLE Low Pressure Injection (Decay Heat) Blocks to minimum flow listed below:
- CV-1400
³ 2800 gpm/pump ³ 3050 gpm (4. CONTINUED ON NEXT PAGE) 1202.012 RT-15 Rev 10-20-19
CHANGE 1202.012 REPETITIVE TASKS 022 PAGE 77 of 123 SHIFT TO RB SUMP SUCTION PAGE 9 OF 12
- 4. (Continued)
C. IF BOTH trains of RB Spray are operating, THEN:
- 1) IF there is NO evidence of Containment breach, THEN:
a) STOP BOTH RB Spray pumps:
- P35A
- P35B b) CLOSE BOTH RB Spray Block valves:
- CV-2401
- CV-2400 c) GO TO step 4.E.
- 2) IF evidence of Containment breach exists, THEN:
a) STOP one RB Spray pump (P35A or P35B).
b) CLOSE associated RB Spray Block valve.
P35A P35B CV-2401 CV-2400 c) GO TO step 4.E.
(4. CONTINUED ON NEXT PAGE) 1202.012 RT-15 Rev 10-20-19
CHANGE 1202.012 REPETITIVE TASKS 022 PAGE 78 of 123 SHIFT TO RB SUMP SUCTION PAGE 10 OF 12
- 4. (Continued)
D. IF one train of RB Spray is operating AND there is NO evidence of Containment breach, THEN:
- 1) STOP RB Spray pump (P35A or P35B).
- 2) CLOSE associated RB Spray Block valve.
P35A P35B CV-2401 CV-2400 E. CONTACT TSC for further direction.
- 5. DIRECT RP to monitor BWST and NaOH tank outlet piping for indication of back-leakage from LPI or RB Spray system.
- 6. IF back-leakage from LPI suction to BWST is indicated, THEN DISPATCH an operator to unlock and close BWST Outlet (BW-1) and CONTINUE this RT.
- 7. IF back-leakage through test & recirc header is indicated and radiation levels permit, THEN DISPATCH an operator to confirm the following valves closed and CONTINUE this RT:
- DH Test & Recirc Bypass around DH-10 (DH-9)
- DH Test & Recirc Header To/From BWST (DH-10)
- P-34A Disch to Test & Recirc HDR (DH-8A) (Locked Valve)
- P-34B Disch to Test & Recirc HDR (DH-8B) (Locked Valve)
- 8. IF ANY back-leakage into NaOH Tank (T-10) is indicated by rising level or RP survey, THEN DISPATCH an operator to unlock and close NaOH T-10 Outlet VLV (CA-49) and CONTINUE this RT.
- 9. IF ANY back-leakage to BWST or NaOH tank is indicated, THEN CONTACT TSC to evaluate installation of BWST/NaOH tank vent filter and CONTINUE this RT.
1202.012 RT-15 Rev 10-20-19
CHANGE 1202.012 REPETITIVE TASKS 022 PAGE 79 of 123 SHIFT TO RB SUMP SUCTION PAGE 11 OF 12
- 10. IF Makeup Tank level exceeds 86 inches, THEN MAINTAIN Makeup Tank level less than or equal to 86 inches as follows:
A. ENSURE Makeup Tank Outlet (CV-1275) open.
B. CLOSE Decay Heat Supply to Makeup Pump Suction associated with OP HPI pump:
P36A/B P36B/C CV-1276 CV-1277 C. WHEN Makeup Tank level is 55 to 86 inches, THEN OPEN Decay Heat Supply to Makeup Pump Suction (CV-1276 or CV-1277).
- 11. IF NaOH Tank T-10 level is greater than 16 feet AND there is NO evidence of back-leakage into NaOH Tank (T-10),
THEN:
A. OPEN RB Spray NaOH Addition T10 Outlets:
- CV-1616
- CV-1617 B. WHEN T-10 level is 6 to 16 feet, THEN CLOSE RB Spray NaOH Addition T10 Outlets:
- CV-1616
- CV-1617 1202.012 RT-15 Rev 10-20-19
CHANGE 1202.012 REPETITIVE TASKS 022 PAGE 80 of 123 SHIFT TO RB SUMP SUCTION PAGE 12 OF 12
- 12. IF NaOH Tank T-10 level is greater than 16 feet AND evidence of back-leakage into NaOH Tank (T-10) exists, THEN NOTIFY TSC that appropriate amount of NaOH might not have been added.
- 14. IF refill of BWST is possible, THEN INITIATE BWST refill using 1104.003, Chemical Addition, Attachment L1 Boric Acid and Condensate Addition To BWST (T-3) (NORMAL METHOD).
END 1202.012 RT-15 Rev 10-20-19
A1JPM-RO-PZR06 Page 1 of 5 JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date:
JPM ID: A1JPM-RO-PZR06 System/Duty Area: Pressurizer Pressure Control System Task: Respond to Pressurizer ERV Failure JTA# ANO1-RO-PZR-SURV-11 KA Value RO 4.1 SRO 4.2 KA
Reference:
010 A2.03 Approved For Administration To: RO X SRO X Task Location: Inside CR X Outside CR Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site Simulator X Lab Testing Method: Perform X Simulate Approximate Completion Time in Minutes: 10 Minutes Reference(s): 1103.005 PZR Operation (Supplement 1, Rev 50)
Examinee's Name: Login ID:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Robert Possage Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
A1JPM-RO-PZR06 Page 2 of 5 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS:
- The plant is in cold shutdown.
- RCS pressure 30 - 70 psig.
- Personnel Hatch Interlock is enabled.
- Personnel are clear of the ERV vicinity
- You are responsible for panel C04 and related annunciators.
TASK STANDARD:
Recognized ERV failure and closed CV-1000 to isolate ERV.
TASK PERFORMANCE AIDS:
1103.005 Section Supplement 1 This JPM is an Alternate Success Path JPM.
SIMULATOR SETUP:
RCS pressure 30 - 70 psig.
When PSV-1000 is opened, insert malfunction to fail the ERV PSV-1000 to full open.
A1JPM-RO-PZR06 Page 3 of 5 INITIATING CUE:
The CRS/SM directs you to perform Supplement 1 of 1103.005 Pressurizer Operation beginning at Step 6.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT
- 6. ENSURE RCS pressure remains Verified RCS pressure as 30 - 70 psig during testing of ERV. indicated (SPDS P1041) 30 - 70 psig.
POSITIVE CUE:
CV-1008 is in manual and throttled open.
7.a At Auxiliary Equipment Panel (Red) Placed Relief Valve Monitor (C486-1), PLACE Relief Valve Monitor VYI-1000A full scale range VYI-1000A full scale range selector to 1 g selector to 1 g position.
position.
POSITIVE CUE:
Relief Valve Monitor VYI-1000A full scale range selected to 1 g position.
EXAMINER NOTE: Once the ERV (PSV-1000) is opened, it will be failed open which will start the ALTERNATE PATH for the JPM.
BOOTH: Insert malfunction to fail PSV-1000 full open.
7.b MEASURE stroke time and OPEN ERV Timed and Opened PSV-1000.
(C) (PSV-1000).
POSITIVE CUE: ____ ____ ___
RCS pressure is dropping and PSV-1000 is full open.
A1JPM-RO-PZR06 Page 4 of 5 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT 7.c RECORD PSV-1000 open stroke time in Recorded PSV-1000 open Table 2. time in Table 2 POSITIVE CUE:
Stroke time recorded in Table 2 7.d CHECK ERV open using ALL of the Verified ERV (Acoustic following: Monitor) indicated flow, RCS
- ERV (Acoustic Monitor) on C04 pressure dropped, and
- Dropping RCS pressure Quench Tank pressure rose.
- Rising Quench Tank pressure ____ ____ ___
POSITIVE CUE:
ERV (Acoustic Monitor) indicates flow, RCS pressure dropping and Quench Tank pressure rising.
7.e MEASURE stroke time and CLOSE ERV Recognized ERV failed to (C) (PSV-1000). close and transition to step 7.h.
AP NEGATIVE CUE: ____ ____ ___
ERV (Acoustic Monitor) indicates flow, RCS pressure dropping and Quench Tank pressure rising.
7.h IF ERV fails to close, THEN CLOSE Closed ERV Isolation CV-1000 (C) ERV Isolation (CV-1000).
POSITIVE CUE:
Applicant transitions to Step 8.2.13.
7.i PLACE ERV Acoustic Monitor Full Placed Relief Valve Monitor Scale Range selector to 10 g position. VYI-1000A full scale range selector to 10 g position.
POSITIVE CUE:
Relief Valve Monitor VYI-1000A full scale range selected to 1 g position.
END
A1JPM-RO-PZR06 Page 5 of 5 INITIAL CONDITIONS:
- The plant is in cold shutdown.
- RCS pressure 30 - 70 psig.
- Personnel Hatch Interlock is enabled.
- Personnel are clear of the ERV vicinity
- You are responsible for panel C04 and related annunciators.
INITIATING CUE:
The CRS/SM directs you to perform Supplement 1 of 1103.005 Pressurizer Operation beginning at Step 6.
1103.005 Rev. 050 Page 58 of 74 PRESSURIZER OPERATIONS Supplement 1 Page 1 of 7 EXERCISING PRESSURIZER ELECTROMAGNETIC RELIEF VALVE (PSV-1000) {3.2.3}
This test demonstrates operability of the Electromatic Relief Valve (ERV). This test satisfies requirements of 10 CFR 50.55a(f), ANO IST program for stroke time measurement, exercising, and fail-safe operation. This test also satisfies part of Surveillance TR 3.4.2.1 for RCS vent path operability.
This test is related to SR 3.4.11.5 "Channel calibration of ERV opening circuitry". Reference Values for IST Components are contained in Appendix B.
1.0 INITIAL CONDITIONS
- 1. IDENTIFY the purpose of this test ():
__A) Regularly scheduled cold shutdown test.
__B) Regularly scheduled 18 month test.
__C) Operability test following significant maintenance.
__D) Other (DESCRIBE in section 4.0).
- 2. ENSURE at least ONE Stop watch available for measuring valve stroke time and RECORD Stopwatch(s) M&TE# and Cal Due Date in Table 2.
- 3. CHECK RCS temperature 100°F or greater. {3.2.1}
- 4. CHECK RCS pressure 30 psig - 70 psig.
- 5. CHECK ERV Isolation (CV-1000) open.
CRITICAL STEP
- 6. IF elevated airborne activity is expected as a result of ERV operations, THEN PERFORM ONE of the following: {3.2.6}
- CHECK personnel Hatch interlock is enabled.
- STATION a Personnel Hatch watch to ensure only one door opened at a time.
1103.005 Rev. 050 Page 59 of 74 PRESSURIZER OPERATIONS Supplement 1 Page 2 of 7 EXERCISING PRESSURIZER ELECTROMAGNETIC RELIEF VALVE (PSV-1000) {3.2.3}
- 7. WHEN timing valve strokes for Table 1 data, THEN:
- IDENTIFY the stopwatch providing stroke time.
- Operator INITIAL and DATE.
- 8. IF a valve stroke time is NOT within Acceptable Normal Range AND stroke time is within Limiting Value for Operability, THEN:
- a. Prior to changing system alignment, REFER TO Appendix A, OPERABILITY.
- b. PERFORM ONE of the following:
- RETEST valve.
- DECLARE valve inoperable.
1103.005 Rev. 050 Page 60 of 74 PRESSURIZER OPERATIONS Supplement 1 Page 3 of 7 EXERCISING PRESSURIZER ELECTROMAGNETIC RELIEF VALVE (PSV-1000) {3.2.3}
2.0 TEST METHOD
- 1. RECORD initial data for the following parameters:
- Quench Tank Pressure (PIS-1051) _______ psig
- Relief Valve Monitor VYI-1000A ___________ %
WARNING Opening the ERV causes a localized steam release at the pilot valve vent. This is a radiation and safety hazard.
CRITICAL STEP
- 2. ENSURE personnel are clear of the vicinity of the ERV.
- 3. MAINTAIN RCS pressure between 30 psig and 70 psig for minimum of 10 minutes.
- 4. Using same instruments in step 2.1, RECORD final data for the following parameters:
- Quench Tank Pressure (PIS-1051) _______ psig
- Relief Valve Monitor VYI-1000A ___________ %
- 5. COMPARE data recorded in step 2.4 to data recorded in step 2.1 and RECORD results in Table 1.
1103.005 Rev. 050 Page 61 of 74 PRESSURIZER OPERATIONS Supplement 1 Page 4 of 7 EXERCISING PRESSURIZER ELECTROMAGNETIC RELIEF VALVE (PSV-1000) {3.2.3}
- 7. TESTING ERV:
- a. At Auxiliary Equipment Panel (Red) (C486-1), PLACE Relief Valve Monitor VYI-1000A full scale range selector to 1 g position.
- b. MEASURE stroke time and OPEN ERV (PSV-1000).
- c. RECORD PSV-1000 open stroke time in Table 2.
- d. CHECK ERV open using ALL of the following:
- ERV (Acoustic Monitor) on C04
- Dropping RCS pressure
- Rising Quench Tank pressure
- e. MEASURE stroke time and CLOSE ERV (PSV-1000).
- f. RECORD PSV-1000 close stroke time in Table 2.
- g. OBSERVE ERV closed using ALL of the following:
- ERV (Acoustic Monitor) on C04
- RCS pressure stable
- Quench Tank pressure stable
- i. PLACE ERV Acoustic Monitor Full Scale Range selector to 10 g position.
1103.005 Rev. 050 Page 62 of 74 PRESSURIZER OPERATIONS Supplement 1 Page 5 of 7 EXERCISING PRESSURIZER ELECTROMAGNETIC RELIEF VALVE (PSV-1000) {3.2.3}
3.0 ACCEPTANCE CRITERIA
- 1. COMPARE measured values/stroke times with Acceptable Normal Range and Limiting Value for Operability.
- 2. IDENTIFY (ü) valves that stroke within Limiting Value for Operability.
Table 1
() () If Limiting Test Confirmation Within Acceptance Criteria Value For Initial Date Quantity of Seat Limiting Operability Tightness Value
( ) Yes PSV-1000 Seat No rise observed in parameters Seat recorded in Steps 2.1 and 2.4. Tightness (____)
Tightness ( ) No Confirmed Table 2
() If Measured Acceptable Limiting Test Within Valve DES # Value/Stroke Time Normal Value for Initial Date Direction Limiting (nearest 1/10 sec) Range Operability Value PSV-1000 Open sec £ 2.0 sec £ 2.0 sec (____)
PSV-1000 Close (1) sec 4.0-11.8 sec £ 15.8 sec (____)
NOTE (1): Valve stroke in test direction demonstrates proper fail safe operation.
Stopwatch information:
DES#: ____________Cal Due Date __________
DES#: ____________Cal Due Date __________
1103.005 Rev. 050 Page 63 of 74 PRESSURIZER OPERATIONS Supplement 1 Page 6 of 7 EXERCISING PRESSURIZER ELECTROMAGNETIC RELIEF VALVE (PSV-1000) {3.2.3}
- 3. IF PSV-1000 seat leakage is indicated, THEN:
- INITIATE a Condition Report.
- 4. IF valve stroke time is NOT within Limiting Value in Table 2, THEN:
- DECLARE ERV inoperable.
- ENSURE Condition Report initiated.
- NOTIFY Shift Manager.
- REFER TO TRM 3.4.2 for required actions.
- 5. IF ANY measured stroke time does NOT fall within the Acceptable Normal Range, THEN:
- REFER TO Appendix A, OPERABILITY.
- ENSURE CR initiated.
- DESCRIBE the action taken in 4.0 such as valve was retested, valve declared inoperable, CR #, etc.
Print Name Signature Initial Date Performed by:
1103.005 Rev. 050 Page 64 of 74 PRESSURIZER OPERATIONS Supplement 1 Page 7 of 7 EXERCISING PRESSURIZER ELECTROMAGNETIC RELIEF VALVE (PSV-1000) {3.2.3}
4.0 SUPERVISOR REVIEW AND ANALYSIS (CIRCLE one)
- 1. Do ALL measured values/stroke times recorded in Acceptance Criteria section fall within the specified Limiting Range/Value For Operability? .................................................................................................... Yes No
- 2. Do all measured values recorded in the Acceptance Criteria section fall within the Acceptable Normal Range? (CIRCLE N/A if the only values outside the Acceptable Normal Range are also outside the Limiting Value for Operability) ....................................................................................................Yes No N/A
- 3. IF NO is answered to 4.1, THEN PERFORM the following corrective actions:
- ENSURE LCO Tracking Record is completed.
- ENSURE Condition Report initiated.
- 4. IF NO is answered to 4.2 and retest is successful, OR Engineering Evaluation of valve was performed, THEN:
- DOCUMENT results in step 4.5.
- ENSURE Condition Report initiated.
- 5. IF answer to EITHER step 4.1or 4.2 is NO, THEN DESCRIBE action taken below.
- 6. Has this equipment been proven operable per the ACCEPTANCE CRITERIA? ... Yes No
- 7. Have all of the administrative requirements of this test been satisfied (i.e., all initial blocks initialed or marked N/A, all data entered, cal due dates listed, applicable signature spaces signed,etc.)?.......................................... Yes No Supervisor ______________________________________ Date______________
A1JPM-RO-CFW01 Page 1 of 6 JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date:
JPM ID: A1JPM-RO-CFW01 System/Duty Area: Emergency and Abnormal Operations Task: Perform CFW Feed to Unit 1 SGs from Unit 1Control Room JTA# ANO1-RO-CFW-EMERG-1 KA Value RO 4.4 SRO 4.2 KA Reference E04 EA1.1 Approved For Administration To: RO X SRO X Task Location: Inside CR: X Outside CR: Both:
Suggested Testing Environment And Method (Perform or Simulate ):
Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Simulator : X Plant Site: Lab:
Testing Method: Simulate: Perform: X Approximate Completion Time In Minutes: 10 Minutes Reference(s): 1106.007 Attachment E - CFW Feed to Unit 1 SGs from Unit 1 Control Room Examinee's Name: Logon ID:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed : Robert Possage Date:
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
A1JPM-RO-CFW01 Page 2 of 6 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner should verify that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS:
Unit 1 is in MODE 3, post Reactor Trip.
A fire has caused a loss of Main Feedwater, Auxiliary Feedwater and EFW.
TASK STANDARD:
CFW flow (340 gpm to 400 gpm) has been established to A SG using P-805A Common Feedwater Pump.
TASK PERFORMANCE AIDS:
1106.007 Attachment E - CFW Feed to Unit 1 SGs from Unit 1 Control Room SUGGESTED SIMULATOR SETUP:
MODE 3 Both MFW Pumps tripped Both EFW Pumps inoperable (Malfunctions FW076 and FW622)
Condensate Pumps in P-T-L AFP inoperable (FW080)
Fire alarm in for EFW pump room (Malfunction FS_C4_4_U_R)
CFW Breakers A1512 and A1532 are open
A1JPM-RO-CFW01 Page 3 of 6 INITIATING CUE: The SM/CRS directs you to establish CFW flow (340 gpm to 400 gpm) to the A SG with CFW Pump P-805A being powered from the London line using 1106.007 Attachment E.
UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT
- 1. ENSURE CFW power available by performing the following:
1.1. SELECT 4160V Electrical Screen. SELECTED 4160V Electrical Screen.
C POSITIVE CUE:
4160V Electrical Screen selected.
1.2.1. CHECK ONE of the following supply breakers CHECKED ONE of the following closed: supply breakers closed:
- A1512, London Line Feed to A15
- A1512, London Line Feed
- A1532, A1 Feed to A15 to A15
- A1532, A1 Feed to A15 Identified both breakers open.
1.2.2 IF A15 de-energized AND desired to power A15 IF A15 de-energized AND desired Bus from the London Line, THEN: to power A15 Bus from the London Line, THEN:
- ENSURE A1532 open.
- CLOSE A1512.
- ENSURED A1532 open.
- CLOSED A1512.
INSTRUCTOR NOTE: Step 1.2.3 is N/A Step1.3 IF P-805B will be used is N/A.
- 2. Starting CFW:
2.1 SELECT Injection Screen Display on HMI QC- SELECTED Injection Screen 7100. Display on HMI QC-7100.
C ____ ____ ____
POSITIVE CUE:
Injection Screen Display selected.
2.2.1 SELECT P-805A by pressing P-805A symbol. SELECTED P-805A by pressing C P-805A symbol.
POSITIVE CUE:
P-805A selected.
CONTINUED
A1JPM-RO-CFW01 Page 4 of 6 UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT INSTRUCTOR NOTE: Step 2.2.2 IF P-805A powered from A1 is N/A.
2.2.3 SELECT START button in pop-up box. SELECTED START button in pop-up box.
C POSITIVE CUE:
Start button selected.
INSTRUCTOR NOTE: Step 2.3 IF starting CFW Pump B is N/A.
2.4 CHECK selected pump icon changes from green to CHECKED selected pump icon red. changes from green to red.
POSITIVE CUE:
P-805A icon is RED.
2.5 CHECK selected pump discharge pressure greater CHECKED selected pump than or equal to 1350 psig. discharge pressure greater than or equal to 1350 psig. ____ ____ ____
POSITIVE CUE:
P-805A discharge press at 1375 psig.
3.1 REFER TO Tech Spec 3.6.3, Reactor Building REFERED TO Tech Spec 3.6.3, Isolation Valves. Reactor Building Isolation Valves.
POSITIVE CUE:
3.2 UNLOCK and CLOSE Disconnect Switch for UNLOCK and CLOSE Disconnect CV-2660A (S-2660A2). Switch for CV-2660A (S-2660A2).
C ____ ____ ____
POSITIVE CUE:
Disconnect Switch S-2660A2 closed.
CONTINUED
A1JPM-RO-CFW01 Page 5 of 6 UN C PERFORMANCE CHECKLIST STANDARD N/A SAT SAT 3.3 ENSURE CV-2660A operation selected to manual. ENSURED CV-2660A operation C selected to manual.
POSITIVE CUE:
CV-2660A selected to manual.
3.4 THROTTLE OPEN CV-2660A to between 340 gpm THROTTLED OPEN CV-2660A to and 400 gpm on CFW Flow to E-24A (F2960). between 340 gpm and 400 gpm on CFW Flow to E-24A (F2960).
C POSITIVE CUE:
F2960 at 370 gpm.
NEGATIVE CUE:
F2960 at 0 gpm.
3.5 MONITOR SG A for level rise. MONITORED SG A for level rise.
POSITIVE CUE:
SG A level rising.
INSTRUCTOR CUE: Once CFW flow is established at 340-400 gpm inform Examinee that JPM is complete (steps 3.6 through 6.0 will not be performed).
END
A1JPM-RO-CFW01 Page 6 of 6 JPM ID: A1JPM-RO-CFW01 INITIAL CONDITIONS:
Unit 1 is in MODE 3, post Reactor Trip.
A fire has caused a loss of Main Feedwater, Auxiliary Feedwater and EFW.
INITIATING CUE:
The SM/CRS directs you to establish CFW flow (340 gpm to 400 gpm) to the A SG with CFW Pump P-805A being powered from the London line using 1106.007 Attachment E.
PAGE: 64 of 161 1106.007 COMMON FEEDWATER SYSTEM CHANGE: 007 ATTACHMENT E PAGE 1 OF 5 CFW FEED TO UNIT 1 SGs FROM UNIT 1 CONTROL ROOM 1.0 ENSURE CFW power available by performing the following:
1.1 SELECT 4160V Electrical Screen.
1.2 IF P-805A to be used, THEN:
1.2.1 CHECK ONE of the following supply breakers closed:
- A1512, London Line Feed to A15
- A1532, A1 Feed to A15 1.2.2 IF A15 de-energized AND desired to power A15 Bus from the London Line, THEN:
A. ENSURE A1532 open.
B. CLOSE A1512.
1.2.3 IF A15 de-energized AND desired to power A15 Bus from A1, THEN:
A. ENSURE A1512 open.
B. CLOSE A1532.
1.3 IF P-805B to be used, THEN:
1.3.1 CHECK ONE of the following supply breakers closed:
- A1912, London Line Feed to A19
- A1932, A1 Feed to A19 1.3.2 IF A19 de-energized AND desired to power A19 from the London Line, THEN:
A. ENSURE A1932 open.
B. CLOSE A1912.
(Step 1.0 continued on next page)
PAGE: 65 of 161 1106.007 COMMON FEEDWATER SYSTEM CHANGE: 007 ATTACHMENT E PAGE 2 OF 5 1.0 (continued) 1.3.3 IF A19 de-energized AND desired to power A19 from A1, THEN:
A. ENSURE A1912 open.
B. CLOSE A1932.
2.0 Starting CFW:
2.1 SELECT Injection Screen Display on HMI QC-7100.
NOTE If CFW powered from A1 and EFW Pump P-7B receives an automatic start signal or its supply breaker (A-311) is closed, the CFW Pump will not run due to load shed.
2.2 IF starting CFW Pump A (P-805A),
THEN:
NOTE P-805A pump icon will be a gray hue if load shed is enabled.
2.2.1 SELECT P-805A by pressing P-805A symbol.
2.2.2 IF P-805A powered from A1 AND load shed enabled, THEN:
A. REQUEST permission from CRS to bypass load shed.
B. IF permission obtained to bypass load shed, THEN PRESS Load Shed Bypass.
2.2.3 SELECT START button in pop-up box.
(Step 2.0 continued on next page)
PAGE: 66 of 161 1106.007 COMMON FEEDWATER SYSTEM CHANGE: 007 ATTACHMENT E PAGE 3 OF 5 2.0 (continued) 2.3 IF starting CFW Pump B (P-805B),
THEN:
NOTE P-805B pump icon will be a gray hue if load shed is enabled.
2.3.1 SELECT P-805B by pressing P-805B symbol.
2.3.2 IF P-805B powered from A1 AND load shed is enabled, THEN:
A. REQUEST permission from CRS to bypass load shed.
B. IF permission obtained to bypass load shed, THEN PRESS Load Shed Bypass.
2.3.3 SELECT START button in pop-up box.
2.4 CHECK selected pump icon changes from green to red.
2.5 CHECK selected pump discharge pressure greater than or equal to 1350 psig.
3.0 IF feedwater will be aligned to SG A, THEN:
3.1 REFER TO Tech Spec 3.6.3, Reactor Building Isolation Valves.
3.2 UNLOCK and CLOSE Disconnect Switch for CV-2660A (S-2660A2).
3.3 ENSURE CV-2660A operation selected to manual.
NOTE Time for CV-2660A from full closed to full open is 26 seconds.
3.4 As directed by applicable RT (RT-5; RT-16; RT-17, etc.), THROTTLE OPEN CV-2660A to maintain SG A level on CFW Flow to E-24A (F2960).
3.5 MONITOR SG A for level rise.
3.6 IF desired by CRS/SM to place CV-2660A into automatic control, THEN PLACE AUTO/MANUAL MODE button on HMI QC-7100 in AUTO.
PAGE: 67 of 161 1106.007 COMMON FEEDWATER SYSTEM CHANGE: 007 ATTACHMENT E PAGE 4 OF 5 4.0 IF feedwater will be aligned to SG B, THEN:
4.1 REFER TO Tech Spec 3.6.3, Reactor Building Isolation Valves.
4.2 UNLOCK and CLOSE Disconnect Switch for CV-2660B (S-2660B2).
4.3 ENSURE CV-2660B operation selected to manual.
NOTE Time for CV-2660B from full closed to full open is 26 seconds.
4.4 As directed by applicable RT (RT-5; RT-16; RT-17, etc.), THROTTLE OPEN CV-2660B to maintain SG B level on CFW Flow to E-24B (F2950).
4.5 MONITOR SG B for level rise.
4.6 IF desired by CRS/SM to place CV-2660B into automatic control, THEN PLACE AUTO/MANUAL MODE button on HMI QC-7100 in AUTO.
5.0 IF flow to the SGs lowers to less than 200 gpm, THEN CONSIDER opening Recirc Test Line Inlet Isol (FW-2846) to ensure proper CFW pump recirc flow to minimize pump wear.
PAGE: 68 of 161 1106.007 COMMON FEEDWATER SYSTEM CHANGE: 007 ATTACHMENT E PAGE 5 OF 5 6.0 WHEN feeding with CFW complete, THEN:
6.1 SELECT Injection Screen Display on QC-7100.
6.2 IF CFW System was aligned to feed SG A, THEN:
6.2.1 ENSURE Unit 1 SG A Injection (CV-2660A) in MANUAL.
6.2.2 ENSURE CV-2660A closed.
6.2.3 OPEN and LOCK Disconnect Switch for CV-2660A (S-2660A2).
6.3 IF CFW System was aligned to feed SG B, THEN:
6.3.1 ENSURE Unit 1 SG B Injection (CV-2660B) in MANUAL.
6.3.2 ENSURE CV-2660B closed.
6.3.3 OPEN and LOCK Disconnect Switch for CV-2660B (S-2660B2).
6.4 IF securing CFW Pump A (P-805A),
THEN:
6.4.1 SELECT P-805A by pressing P-805A symbol.
6.4.2 SELECT STOP button in pop-up box.
6.5 IF securing CFW Pump B (P-805B),
THEN:
6.5.1 SELECT P-805B by pressing P-805B symbol.
6.5.2 SELECT STOP button in pop-up box.
SIMULATOR JOB PERFORMACE MEASURE Page 1 of 6 A1JPM-RO-HYD03 UNIT: 1 REV # 5 DATE: ___________________
SYSTEM/DUTY AREA: Hydrogen Recombiner and Purge Control System TASK: Place Hydrogen Recombiner M55B in Operation JTA#: ANO1-RO-RBH2-NORM-1 KA VALUE RO: 4.0 SRO: 4.0 KA
REFERENCE:
028 A4.01 APPROVED FOR ADMINISTRATION TO: RO: X SRO:
TASK LOCATION: INSIDE CR: X OUTSIDE CR:_________ BOTH:________
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE _____________ SIMULATOR: Perform LAB:__________
POSITION EVALUATED: RO:_______ SRO:___________
ACTUAL TESTING ENVIRONMENT: SIMULATOR: X PLANT SITE:__________ LAB:________
TESTING METHOD: SIMULATE:_________ PERFORM: X ALTERNATE PATH:________
APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): 1104.031 EXAMINEE'S NAME:________________________________ Logon: _______________________
EVALUATOR'S NAME:__________________________________________________________________
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY:________________ UNSATISFACTORY:_________________
PERFORMANCE CHECKLIST COMMENTS:
Start Time ____________ Stop Time ____________ Total Time ______________
SIGNED _Robert Possage_______________________________ DATE: _______________________
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
SIMULATOR JOB PERFORMACE MEASURE Page 2 of 6 A1JPM-RO-HYD03 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS: A LOCA has occurred. Containment hydrogen concentration is 2.5%. Both Hydrogen Recombiners are shutdown. Containment pressure is 26.0 psia. Pre-LOCA containment temperature was 120 oF.
TASK STANDARD: Hydrogen Recombiner M55B in operation at power setting of 67.5 KW to 68.0 KW on JI-1001.
TASK PERFORMANCE AIDS: Copy of 1104.031 Section 8.0 and Attachment B2 Simulator setup:
Place Hydrogen Samplers in service per 1104.031 Exhibit A.
SIMULATOR JOB PERFORMACE MEASURE Page 3 of 6 A1JPM-RO-HYD03 INITIATING CUE: The CRS/SM directs you to place hydrogen recombiner (M55B) in operation.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT CAUTION To stop buildup of explosive hydrogen, Hydrogen Recombiner, M-55A or M-55B is required to be operating prior to hydrogen concentration reaching 3.0% as indicated on the highest reading hydrogen analyzer.
8.1.1 ENSURE Hydrogen Recombiner M-55B Verified power adjust Power Adjust Potentiometer (HS-7473) is potentiometer set to zero on ____ ____ ____
set at zero. C26 (if not already at zero used knurled knob on power POSITIVE CUE: adjust potentiometer on C26 Power adjust potentiometer for M55B is set at and turned to the left and set zero on C26. at zero using HS-7473).
8.1.2 PLACE Hydrogen Recombiner M55B Turned on hydrogen handswitch (HS-7471) to ON. recombiner M55B using HS-7471 on C26. ____ ____ ____
C POSITIVE CUE:
M55B red light ON.
NEGATIVE CUE:
M55B green light ON.
CAUTION Selecting OFF on Thermocouple Selector handswitch (HS-7475) causes excessive current in Hydrogen Recombiner (M55B) Temperature (TI-2301) leading to frequent failure.
8.1.3 On Thermocouple Selector handswitch Thermocouple #1, 2 or 3 (HS-7475), ENSURE thermocouple #1, 2, selected to input to TI-2301 ____ ____ ____
or 3 is selected to input to Hydrogen using handswitch HS-7475 on Recombiner (M55B) Temperature C26.
(TI-2301).
POSITIVE CUE:
Thermocouple #1, 2 or 3 selected as desired to input to TI-2301.
8.1.4 Slowly TURN (slow enough to observe KW Slowly adjusted potentiometer rise without overshooting) Power Adjust clockwise until power on C Potentiometer (HS-7473) clockwise to raise JI-1001 on C26 indicates ____ ____ ____
power to 5 KW on M55B Power (JI-1001). ~5 KW.
POSITIVE CUE:
Power on JI-1001 indicates 5KW.
SIMULATOR JOB PERFORMACE MEASURE Page 4 of 6 A1JPM-RO-HYD03 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT 8.1.5 Slowly TURN (slow enough to observe KW Increased power to ~10 KW C rise without overshooting) Power Adjust using power adjust ____ ____ ____
Potentiometer (HS-7473) clockwise to raise potentiometer on C26.
power to 10 KW on M55B Power (JI-1001). Recorded time 10 KW was A. RECORD initial time at 10 KW: achieved.
B. MAINTAIN 10 KW output for heatup/standby service.
POSITIVE CUE:
Power is at 10 KW on JI-1001.
EXAMINER CUE:
- Inform examinee that taking data every 30 minutes on Attachment E will be simulated.
- Inform examinee that ten minutes have elapsed after achieving 10 KW.
8.2 Placing Hydrogen Recombiner (M-55B) into Acknowledge that 10 minutes Service: have elapsed 8.2.1 ENSURE Hydrogen Recombiner ____ ____ ____
(M-55B) has been at 10 KW for at least 10 minutes.
POSITIVE CUE:
Power at 10 KW on JI-1001 AND 10 minutes have elapsed.
8.2.2 Slowly TURN (slow enough to Increased power on M55B to observe KW rise without ~20 KW using power adjust overshooting) Power Adjust potentiometer on C26. ____ ____ ____
C Potentiometer (HS-7473) clockwise to raise power to 20 KW on M55B Power (JI-1001).
A. RECORD initial time at 20 KW:
POSITIVE CUE:
Power at 20 KW on JI-1001.
8.2.3 DETERMINE power required for Determined Recombiner Containment pressure per power to be from 67.5 to 68.0 Attachment B2, Recombiner Power KW using Attachment B of ____ ____ ____
C (M-55B) Versus Containment 1104.031.
Pressure.
A. KW setting __________
SIMULATOR JOB PERFORMACE MEASURE Page 5 of 6 A1JPM-RO-HYD03 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT EXAMINER CUE:
- Inform examinee that five minutes have elapsed after they have determined final power level.
CAUTION Recombiner power greater than 75 KW and temperature greater than 1450°F could cause heater failure.
B. WHEN M-55B has been at 20 KW for 5 Power increased to 67.5 to minutes, THEN slowly TURN Power Adjust 68.0 KW range using power ____ ____ ____
C Potentiometer (HS-7473) clockwise to raise adjust potentiometer on C26.
power to the value determined above as indicated on M55B Power (JI-1001) while maintaining the following limits:
- M55B Temperature (TI-2301) less than 1450°F
- M55B Power (JI-1001) less than 75 KW POSITIVE CUE:
Hydrogen concentration dropping on QI-7459 and M55B maintaining power at determined value.
NEGATIVE CUE:
Hydrogen concentration rising or steady on QI-7459.
END
SIMULATOR JOB PERFORMACE MEASURE Page 6 of 6 A1JPM-RO-HYD03 Applicants Copy INITIAL CONDITIONS:
- A LOCA has occurred.
- Containment hydrogen concentration is 2.5%.
- Both hydrogen recombiners are shutdown.
- Containment pressure is 26.0 psia.
- Pre-LOCA containment temperature was 120°F.
INITIATING CUE:
The CRS/SM directs you to place hydrogen recombiner (M55B) in operation.
PAGE: 10 of 82 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 034 8.0 PLACING HYDROGEN RECOMBINER (M-55B) INTO SERVICE CAUTION To stop buildup of explosive hydrogen, Hydrogen Recombiner, M-55A or M-55B is operated prior to hydrogen concentration reaching 3.0% as indicated on the highest reading hydrogen analyzer.
8.1 Placing Hydrogen Recombiner (M-55B) into Heatup/Standby Service:
8.1.1 ENSURE Hydrogen Recombiner M-55B Power Adjust Potentiometer (HS-7473) is set at zero.
8.1.2 PLACE Hydrogen Recombiner M55B handswitch (HS-7471) to ON.
CAUTION Selecting OFF on Thermocouple Selector handswitch (HS-7475) causes excessive current in Hydrogen Recombiner (M55B) Temperature (TI-2301) leading to frequent failure.
8.1.3 On Thermocouple Selector handswitch (HS-7475),
ENSURE thermocouple #1, 2, or 3 is selected to input to Hydrogen Recombiner (M55B) Temperature (TI-2301).
8.1.4 Slowly TURN (slow enough to observe KW rise without overshooting)
Power Adjust Potentiometer (HS-7473) clockwise to raise power to 5 KW on M55B Power (JI-1001).
8.1.5 Slowly TURN (slow enough to observe KW rise without overshooting)
Power Adjust Potentiometer (HS-7473) clockwise to raise power to 10 KW on M55B Power (JI-1001).
A. RECORD initial time at 10 KW: __________.
B. MAINTAIN 10 KW output for heatup/standby service.
8.1.6 During heatup, MONITOR and RECORD ALL THREE thermocouple temperatures at least every 30 minutes on Attachment E, Hydrogen Recombiner M-55B Data Sheet.
8.1.7 IF M-55B fails during heatup or operation AND M-55B is needed for hydrogen removal, THEN PERFORM Placing Hydrogen Recombiner (M-55A) into Service section of this procedure.
PAGE: 11 of 82 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 034 8.2 Placing Hydrogen Recombiner (M-55B) into Service:
8.2.1 ENSURE Hydrogen Recombiner (M-55B) has been at 10 KW for at least 10 minutes.
8.2.2 Slowly TURN (slow enough to observe KW rise without overshooting)
Power Adjust Potentiometer (HS-7473) clockwise to raise power to 20 KW on M55B Power (JI-1001).
A. RECORD initial time at 20 KW: __________.
8.2.3 DETERMINE power required for Containment pressure per Attachment B2, Recombiner Power (M-55B) Versus Containment Pressure.
A. KW setting __________
CAUTION Recombiner power greater than 75 KW and temperature greater than 1450°F could cause heater failure.
B. WHEN M-55B has been at 20 KW for 5 minutes, THEN slowly TURN Power Adjust Potentiometer (HS-7473) clockwise to raise power to the value determined above as indicated on M55B Power (JI-1001) while maintaining the following limits:
- M55B Temperature (TI-2301) less than 1450°F
- M55B Power (JI-1001) less than 75 KW 8.2.4 CHECK for proper Hydrogen Recombiner operation by observing the following:
- Acceptance Criteria for proper system function:
Hydrogen concentration stable or dropping on BOTH of the following:
- C-178 H2 Sampler H2 Concentration % H2 (QI-7457)
- C-179 H2 Sampler H2 Concentration % H2 (QI-7459)
- Hydrogen Recombiner maintaining power at value determined in step 8.2.3.A.
PAGE: 12 of 82 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 034 NOTE
- Even though thermocouples are non-Q and are not reliable indicators in a post-LOCA environment, temperature can aid in trending.
- Recombiner temperature can be plotted on Attachment C, Typical Recombiner Heatup Rate for checking thermocouple operation and estimating time when recombination temperature is expected to be reached.
8.2.5 ESTABLISH validity of temperature indication by comparing DT between thermocouples as follows:
- IF ALL THREE thermocouples fall within a 60°F band, THEN USE the average of the three temperatures.
- IF TWO thermocouples are NOT within 60°F of each other, THEN CONSIDER thermocouples invalid.
- IF the THREE thermocouples fall outside a 60°F band AND TWO temperatures are within 60°F, THEN USE the average of the closest two.
8.2.6 MONITOR for indication that recombiner operating temperature of 1225°F has been reached.
NOTE Valid thermocouples show a ramp rise in temperature with hydrogen concentration 2% or more, indicating recombination temperature has been reached and recombination is taking place.
8.2.7 IF hydrogen concentration is 2% or more, THEN MONITOR for a ramp rise in temperature.
8.2.8 WHEN M55B has operated at full power for four hours, THEN RECORD data once per hour in Attachment E, Hydrogen Recombiner M-55B Data Sheet.
8.2.9 IF proper power setting causes average valid temperature to exceed 1450°F OR in-service Hydrogen Recombiner has insufficient capacity, THEN:
A. PERFORM Placing Hydrogen Recombiner (M-55A) into Service section of this procedure.
B. WHEN M-55A is heated to 1225°F, THEN PERFORM Securing Hydrogen Recombiner (M-55B) section of this procedure.
PAGE: 26 of 82 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 034 ATTACHMENT B1 PAGE 1 OF 1 RECOMBINER POWER (M-55A)
VERSUS CONTAINMENT PRESSURE 70 65 60OF 90OF 120OF Power (1 KW increments) 60 55 50 45 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 Post-LOCA Containment Pressure (0.2 psia increments)
Notes: The pre-LOCA average Reactor Building Temperature from SPDS (TAVRB1) from history file is used if available. Otherwise, the logs are used.
Graph is based on reference power of 42.77 KW.
PAGE: 27 of 82 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 034 ATTACHMENT B2 PAGE 1 OF 1 RECOMBINER POWER (M-55B)
VERSUS CONTAINMENT PRESSURE 75 60OF 90OF 120OF 70 65 Power (1 KW increments) 60 55 50 45 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 Post-LOCA Containment Pressure (0.2 psia increments)
Notes: The pre-LOCA average Reactor Building Temperature from SPDS (TAVRB1) from history file is used if available. Otherwise, the logs are used.
Graph is based on reference power of 40.8 KW.
PAGE: 28 of 82 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 034 ATTACHMENT C TYPICAL RECOMBINER HEATUP RATE 1300 51 KW Input 1200 1100 1000 Recombiner Temperature (20 oF Increments) 900 800 700 600 500 400 300 200 100 0
0 0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 5.5 Time (Hours)
SIMULATOR JOB PERFORMANCE MEASURE Page 1 of 5 A1JPM-RO-EDG04 UNIT: 1 REV # 5 DATE: ___________________
SYSTEM/DUTY AREA: Emergency Diesel Generator (EDG) System TASK: Parallel DG1 to the Grid JTA#: ANO1-RO-EDG-NORM-10 KA VALUE RO: 3.1 SRO: 3.2 KA
REFERENCE:
064 A2.05 APPROVED FOR ADMINISTRATION TO: RO: X SRO:
TASK LOCATION: INSIDE CR: X OUTSIDE CR:_________ BOTH:________
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE _____________ SIMULATOR: Perform LAB:__________
POSITION EVALUATED: RO:_______ SRO:___________
ACTUAL TESTING ENVIRONMENT: SIMULATOR: X PLANT SITE:____ ______ LAB:________
TESTING METHOD: SIMULATE:_________ PERFORM: X APPROXIMATE COMPLETION TIME IN MINUTES: 10 MINUTES REFERENCE(S): 1104.036 Emergency Diesel Generator Operations EXAMINEE'S NAME:________________________________ Logon: _______________________
EVALUATOR'S NAME:__________________________________________________________________
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY:________________ UNSATISFACTORY:_________________
PERFORMANCE CHECKLIST COMMENTS:
Start Time ____________ Stop Time ____________ Total Time ______________
SIGNED _Robert Possage_______________________________ DATE: _______________________
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
SIMULATOR JOB PERFORMANCE MEASURE Page 2 of 5 A1JPM-RO-EDG04 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS: DG1 is running with its output breaker open and its Service Water Inlet valve (CV-3806) open.
TASK STANDARD: DG1 frequency adjusted, Output Breaker Closed and DG1 manually tripped due to its load continuing to rise uncontrollably, prior to tripping automatically.
TASK PERFORMANCE AIDS: Copy of 1104.036 Section 7.0 and Synch Switch Handle This is an alternate success path JPM SIMULATOR SETUP:
- Start VEF-24A and VEF-24B DG Room Exhaust Fans on C19.
- Verify DG1 Volts Select switch NOT in OFF on C10.
- Start DG1 on C10.
- Verify CV-3806 open (SW to DG1).
When the DG1 output breaker is closed and load is 1,000 kW, then insert switch override C10 DI_DG1_GV_LW Lower, DG1, Governor Control to FALSE and insert switch override C10 DI_DG1_GV_RA Raise, DG1, Governor Control to TRUE which will fail the governor handswitch in the raise position, this will cause the DG1 load to rise without control.
- IOR DI_DG1_GV_LW False
- IOR DI_DG1_GV_RA True Simulator Setup: IC-210 Have SPDS VITAL Screen up on the large TV near C10.
SIMULATOR JOB PERFORMANCE MEASURE Page 3 of 5 A1JPM-RO-EDG04 INITIATING CUE: The CRS/SM directs you to parallel DG1 to the grid and load DG1 to ~2750 KW starting at 1104.036 Step 7.9.5. All procedural steps from 7.1 through 7.9.4 have been performed and/or acknowledged for DG1.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT 7.9.5 PLACE Synchronize switch On C10, placed Synchronize for DG1 Output Breaker A-308 to switch for breaker A-308 to ON ON. position.
C ____ ____ ____
POSITIVE CUE:
Incoming and running voltmeters indicating; synchroscope rotating.
NEGATIVE CUE:
Synchroscope off.
NOTE SPDS points, A3 Bus A3 Voltage (E1A3) for Running and DG1 Bus Voltage (E1DG1) for Incoming, are useful as comparison points.
7.9.6 ADJUST DG1 voltage On C10, adjusted DG1 voltage regulator (INCOMING) to either regulator control switch to match match or be no greater than 20 volts INCOMING voltage to within a of A3 (Running) voltage. range of RUNNING voltage -0/+20 volts.
POSITIVE CUE:
INCOMING and RUNNING voltages are matched.
NOTE: Voltages may be verified matched on C10 or SPDS or on plant computer.
EXAMINER CUE: The procedure calls for a peer check of voltage comparison. Provide feedback that a peer check has been received.
7.9.7 ADJUST DG1 governor On C10, adjusted DG1 governor control until frequency is 60 Hz with control switch to achieve synchroscope rotating slowly in frequency at ~60 Hz with FAST direction (clockwise). synchroscope rotating slowly in C FAST direction (clockwise). ____ ____ ____
POSITIVE CUE:
Frequency ~60 Hz, synchroscope rotatingslowly in FAST direction.
NEGATIVE CUE:
Synchroscope rotating in the SLOW direction.
CONTINUED
SIMULATOR JOB PERFORMANCE MEASURE Page 4 of 5 A1JPM-RO-EDG04 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT NOTE: IA Operator When the Applicant raises load through 1,000 kW, verify that the following are occurring:
Insert switch override C10 DI_DG1_GV_LW Lower, DG1, Governor Control to FALSE and Insert switch override C10 DI_DG1_GV_RA Raise, DG1, Governor Control to TRUE which will fail the governor handswitch in the raise position, this will cause the DG1 load to rise without control.
- IOR DI_DG1_GV_LW False
- IOR DI_DG1_GV_RA True NOTE
- If synchroscope is rotating too fast, sync-check relay will prevent breaker from closing.
- Gradual and uniform load changes minimize engine wear and internal stresses. A 100% load change to 2750 KW, typically takes 90 sec. Longer loading times are acceptable when delays are caused by reactive load adjustments or equipment monitoring.
CAUTION A delay in loading diesel after closing output breaker can result in generator motoring which causes lockout relay to actuate, tripping DG output breaker and shutdown of the engine.
7.9.8 As synchroscope On C10, closed DG1 Output Breaker approaches 12 oclock position A-308.
C (5 min. til) CLOSE DG1 Output ____ ____ ____
Breaker (A-308).
POSITIVE CUE:
A-308 red light ON, green light OFF.
EXAMINER NOTE: ***Alternate Path begins here*** Fault will occur as the load is raised through 1,000 kW 7.9.8 On C10, begin raising load with the A. Using DG1 governor control, governor control switch.
RAISE load to 2625 to 2750 C KW. ____ ____ ____
POSITIVE CUE:
DG1 load rising normally up to 1,000 kW.
NEGATIVE CUE:
DG1 load rising without signal / demand present.
- 5. Operator identifies uncontrollable On C10, tripped DG1 (stop rising load and trips DG1. pushbutton or to lockout) before the diesel automatically trips.
C POSITIVE CUE: ____ ____ ____
DG1 green light ON, red light OFF.
NEGATIVE CUE:
DG1 load at 2800 KW and rising.
END
SIMULATOR JOB PERFORMANCE MEASURE Page 5 of 5 A1JPM-RO-EDG04 Applicants Copy INITIAL CONDITIONS:
DG1 is running with its output breaker open and its service water inlet valve (CV-3806) open.
INITIATING CUE:
The CRS/SM directs you to parallel DG1 to the grid and load DG1 to ~2750 KW starting at 1104.036 Step 7.9.5.
All procedural steps from 7.1 through 7.9.4 have been performed and/or acknowledged for DG1.
PAGE: 22 of 423 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 084 CAUTION With DG paralleled to the grid, grid disturbance can cause damage to DG.
7.9 IF desired to parallel DG1 to the grid, THEN:
7.9.1 IF DG1 is paralleled to the grid AND both main generator output breakers open, OR offsite power is lost, THEN:
A. ENSURE ONE of the following conditions:
- 1. DG1 supplying Bus A3:
- A1 to A3 Feeder Breaker (A-309) open.
- DG1 Output Breaker (A-308) closed.
- 2. Offsite power supplying Bus A3:
- A1 to A3 Feeder Breaker (A-309) closed.
- DG1 Output Breaker (A-308) open.
B. Using Concurrent Verification, SET DG1 Governor Speed Droop setting to hard stop (zero), referring to Exhibit D, DG1 Governor Droop Setting, as necessary.
David Ross CV by: ______________________________
C. ADJUST DG1 voltage regulator to 4160 volts.
D. ADJUST DG1 governor control to 60 Hz.
E. For K-4A Crankcase Press HI PS-5283 Isolation (FO-283):
1 ENSURE FO-283 is closed and locked.
- 2. ENSURE Category E/Locked Component Log is updated.
7.9.2 IF in Modes 1-4, THEN ENTER TS 3.8.1 Condition B.
Now Today Time ________ Date _________
7.9.3 NOTIFY Unit 2 CRS/SM that DG1 will be rendered inoperable.
PAGE: 23 of 423 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 084 CRITICAL STEP 7.9.4 Using Concurrent Verification, SET DG1 Governor Speed Droop setting to 45, referring to Exhibit D, DG1 Governor Droop Setting as necessary.
David Ross CV by: ______________________________
7.9.5 PLACE Synchronize switch for DG1 Output Breaker (A-308) to ON.
NOTE SPDS points, A3 Bus Voltage (E1A3) for Running and DG1 Bus Voltage (E1DG1) for Incoming, are useful as comparison points.
7.9.6 ADJUST DG1 voltage regulator (Incoming) to either match or be no greater than 20 volts of A3 (Running) voltage.
- OBTAIN a peer check of voltage comparison.
7.9.7 ADJUST DG1 governor control until frequency is 60 Hz with synchroscope rotating slowly in FAST direction (clockwise).
NOTE
- If synchroscope is rotating too fast, sync-check relay will prevent breaker from closing.
- Gradual and uniform load changes minimize engine wear and internal stresses. A 100%
load change to 2750 KW, typically takes 90 sec. Longer loading times are acceptable when delays are caused by reactive load adjustments or equipment monitoring.
CAUTION A delay in loading diesel after closing output breaker can result in generator motoring which causes lockout relay to actuate, tripping DG output breaker and shutdown of the engine.
7.9.8 As synchroscope approaches 12 o'clock position (5 min 'til),
CLOSE DG1 Output Breaker (A-308).
CRITICAL STEP A. Using DG1 governor control, RAISE load to 2625 to 2750 KW.
B. Using DG1 voltage regulator, MINIMIZE KVARs.
7.9.9 PLACE synchronize switch for DG1 Output Breaker (A-308) to OFF.
7.10 TAKE DG1 Logsheet (OPS-A15a) every 30 minutes for the first hour.
7.11 TAKE DG1 Logsheet (OPS-A15a) hourly after the first hour.
7.12 IF directed by CRS/SM, THEN using EN-OP-102, Protective and Caution Tagging, REMOVE Test &
Maintenance tags installed for testing.
A1JPM-RO-EFIC05 Page 1 of 6 JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date: 12/20/19 JPM ID: A1JPM-RO-EFIC05 System/Duty Area: Emergency Feedwater Initiation and Control System (EFIC)
Task: Bypass MSLI during plant shutdown JTA# ANO1-RO-EFIC-NORM-4 KA Value RO 4.0 SRO 3.6 KA
Reference:
E02 EA1.1 Approved For Administration To: RO X SRO X Task Location: Inside CR X Outside CR Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site Simulator Lab Testing Method: Perform Simulate Approximate Completion Time in Minutes: 10 Minutes Reference(s): 1105.005 Emergency Feedwater Initiation and Control Rev. 48 (Step 8.2)
Examinee's Name: ID:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Robert Possage Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
A1JPM-RO-EFIC05 Page 2 of 6 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS:
- Plant shutdown in progress.
- Steam Generator pressure 625 - 725 psig.
TASK STANDARD:
Bypassed MSLI prior to actuation.
TASK PERFORMANCE AIDS:
1105.005 Step 8.2 SIMULATOR SETUP:
Plant shutdown in progress, Steam Generator pressure between 625 - 725 psig.
A1JPM-RO-EFIC05 Page 3 of 6 INITIATING CUE:
The CRS/SM directs you to bypass MSLI per 1105.005 Step 8.2.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT 8.2 WHEN SG pressure is between 625 psig N/A and 725 psig, THEN BYPASS SG Low Pressure initiate as follows:
POSITIVE CUE:
N/A EXAMINER NOTE: Not all cabinets are fully modeled. Use the A Cabinet as an example for the other three channels. The only CRITICAL STEP is actually placing the SG toggle switch in the BYPASS position.
8.2.1 At EFIC-C cabinet (C37-3): Timed and Opened PSV-1000.
A. On Alarm panel, CHECK Pressure Bypass Permissive Bistable Tripped lamps for EITHER SG A or SG B are flashing bright to dim.
(C) B. On Initiate module, PLACE SG toggle switch in BYPASS position and RELEASE.
C. On Alarm panel, CHECK SG Low Pressure Bypass lamp flashing bright to dim.
POSITIVE CUE:
RCS pressure is dropping and PSV-1000 is full open.
A1JPM-RO-EFIC05 Page 4 of 6 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT 8.2.2 At EFIC-A cabinet (C37-1): Recorded PSV-1000 open time in Table 2 A. On Alarm panel, CHECK Pressure Bypass Permissive Bistable Tripped lamps for EITHER SG A or SG B are flashing bright to dim.
(C) B. On Initiate module, PLACE SG toggle switch in BYPASS position and ____ ____ ___
RELEASE.
C. On Alarm panel, CHECK SG Low Pressure Bypass lamp flashing bright to dim.
POSITIVE CUE:
Stroke time recorded in Table 2 8.2.3 At EFIC-D cabinet (C37-4): Verified ERV (Acoustic Monitor) indicated flow, RCS A. On Alarm panel, CHECK Pressure Bypass pressure dropped, and Permissive Bistable Tripped lamps for Quench Tank pressure rose.
EITHER SG A or SG B are flashing bright to dim.
(C) B. On Initiate module, PLACE SG toggle switch in BYPASS position and RELEASE.
C. On Alarm panel, CHECK SG Low Pressure Bypass lamp flashing bright to dim.
POSITIVE CUE:
ERV (Acoustic Monitor) indicates flow, RCS pressure dropping and Quench Tank pressure rising.
A1JPM-RO-EFIC05 Page 5 of 6 8.2.4 At EFIC-B cabinet (C37-2): Recognized ERV failed to close and transition to step A. On Alarm panel, CHECK Pressure Bypass 7.h.
Permissive Bistable Tripped lamps for EITHER SG A or SG B are flashing bright to dim.
B. On Initiate module, PLACE SG toggle (C) switch in BYPASS position and RELEASE.
C. On Alarm panel, CHECK SG Low Pressure Bypass lamp flashing bright to dim.
NEGATIVE CUE:
ERV (Acoustic Monitor) indicates flow, RCS pressure dropping and Quench Tank pressure rising.
8.2.5 CHECK EFIC SYSTEM TROUBLE Closed ERV Isolation CV-1000 (K12-C7) clear.
POSITIVE CUE:
Applicant transitions to Step 8.2.13.
8.2.6 CHECK EFIC LO SG PRESS Placed Relief Valve Monitor BYPASSED (K12-E8) in alarm. VYI-1000A full scale range selector to 10 g position.
POSITIVE CUE:
Relief Valve Monitor VYI-1000A full scale range selected to 1 g position.
END
A1JPM-RO-EFIC05 Page 6 of 6 INITIAL CONDITIONS:
- Plant shutdown in progress.
- Steam Generator pressure 625 - 725 psig.
INITIATING CUE:
The CRS/SM directs you to bypass MSLI per 1105.005 Step 8.2.
PAGE: 26 of 138 1105.005 EMERGENCY FEEDWATER INITIATION AND CONTROL CHANGE: 048 8.1.6 On EFIC-B Cabinet (C37-2), CHECK the following:
- On Alarm panel:
- ALL Test Results lamps off
- ALL other Alarm panel lamps on dim
- On Compensation modules, ALL lamps off
- On Bistable modules, ALL Trip lamps on dim.
- On Initiate module, ALL lamps on dim
- On Trip modules, ALL lamps on dim
- On Test Results module, ALL lamps off
- On Control modules, Auto lamps flashing (bright to dim)
NOTE
- EFW and MSLI initiate on SG Low Pressure can only be bypassed with one or both OTSGs at less than 725 psig.
- When third EFIC channel is bypassed, EFIC LO SG PRESS BYPASSED (K12-E8) will alarm and EFIC SYSTEM TROUBLE (K12-C7) will clear.
CAUTION With EFIC initiation on SG low pressure bypassed, maximum allowed SG pressure is 725 psig to provide margin to automatic reset at 745 psig.
8.2 WHEN SG pressure is between 625 psig and 725 psig, THEN BYPASS SG Low Pressure initiate as follows:
8.2.1 At EFIC-C cabinet (C37-3):
A. On Alarm panel, CHECK Pressure Bypass Permissive Bistable Tripped lamps for EITHER SG A or SG B are flashing bright to dim.
B. On Initiate module, PLACE SG toggle switch in BYPASS position and RELEASE.
C. On Alarm panel, CHECK SG Low Pressure Bypass lamp flashing bright to dim.
PAGE: 27 of 138 1105.005 EMERGENCY FEEDWATER INITIATION AND CONTROL CHANGE: 048 8.2.2 At EFIC-A cabinet (C37-1):
A. On Alarm panel, CHECK Pressure Bypass Permissive Bistable Tripped lamps for EITHER SG A or SG B are flashing bright to dim.
B. On Initiate module, PLACE SG toggle switch in BYPASS position and RELEASE.
C. On Alarm panel, CHECK SG Low Pressure Bypass lamp flashing bright to dim.
8.2.3 At EFIC-D cabinet (C37-4):
A. On Alarm panel, CHECK Pressure Bypass Permissive Bistable Tripped lamps for EITHER SG A or SG B are flashing bright to dim.
B. On Initiate module, PLACE SG toggle switch in BYPASS position and RELEASE.
C. On Alarm panel, CHECK SG Low Pressure Bypass lamp flashing bright to dim.
8.2.4 At EFIC-B cabinet (C37-2):
A. On Alarm panel, CHECK Pressure Bypass Permissive Bistable Tripped lamps for EITHER SG A or SG B are flashing bright to dim.
B. On Initiate module, PLACE SG toggle switch in BYPASS position and RELEASE.
C. On Alarm panel, CHECK SG Low Pressure Bypass lamp flashing bright to dim.
8.2.5 CHECK EFIC SYSTEM TROUBLE (K12-C7) clear.
8.2.6 CHECK EFIC LO SG PRESS BYPASSED (K12-E8) in alarm.
A1JPM-RO-GR01 Page 1 of 7 JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date: 12/20/19 JPM ID: A1JPM-RO-GR01 System/Duty Area: Waste Gas Disposal System Task: Reactor Building Purge Gaseous Release JTA# ANO1-RO-RBPURG-NORM-1 KA Value RO 3.1 SRO 3.9 KA
Reference:
071 A4.26 Approved For Administration To: RO X SRO X Task Location: Inside CR X Outside CR Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site Simulator Lab Testing Method: Perform Simulate Approximate Completion Time in Minutes: 10 Minutes Reference(s): 1104.033 Reactor Building Ventilation Attachment B (Step 5)
Examinee's Name: ID:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Robert Possage Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
A1JPM-RO-GR01 Page 2 of 7 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS:
- Plant shutdown in progress.
- SPING 1 OPERABLE
- Plant Heating alignment is not desired for winter operations.
- Containment Closure Determination paperwork has been completed per Step 5.5.1
- IA-823 is unlocked, opened, and entered in the Cat E log.
TASK STANDARD:
CV-7401, CV-7402, CV-7403, CV-7404 open, VSF-2 and VEF-15 running.
TASK PERFORMANCE AIDS:
1104.033 Attachment B SIMULATOR SETUP:
Plant shutdown in progress.
A1JPM-RO-GR01 Page 3 of 7 INITIATING CUE:
The CRS/SM directs you to commence release per 1104.033 Attachment B, Reactor Building Purge Gaseous Release Permit.
C PERFORMANCE CHECKLIST STANDARD SAT UNSAT N/A 5.1 IF SPING 1 was assumed Applicant acknowledged that if functional/available prior to purge, SPING 1 becomes unavailable THEN ACKNOWLEDGE that SPING 1 or non-functional, then the becoming non-functional or unavailable release will be terminated.
anytime (for any reason) during the performance of this permit requires ____ ____ ___
termination of the purge and a new purge permit initiated. (Ref. ODCM L2.2.1)
POSITIVE CUE:
N/A 5.2 IF CRS/SM directs Plant Heating aligned N/A per initial conditions.
for Winter operation, THEN PERFORM applicable steps of Aligning Plant Heating To Reactor Building When Shutdown section. ____ ____ ___
POSITIVE CUE:
N/A 5.3 Ensure RB Cooling Fan (VSF-1E) off. Verified Green light on Red light off for VSF-1E.
POSITIVE CUE: ____ ____ ___
Green light on Red light off for VSF-1E 5.4 ENSURE RB Cooling Fan VSF-1E Isol Verified Green light on Red Damper (CV-7400) closed. light off for CV-7400.
POSITIVE CUE:
Green light on Red light off for CV-7400
A1JPM-RO-GR01 Page 4 of 7 C PERFORMANCE CHECKLIST STANDARD SAT UNSAT N/A 5.5 Operating CV-7403, CV-7404 IA Isol Verified completed per (IA-823) initial conditions.
5.5.1 COMPLETE 1015.002, Decay Heat Removal and LTOP System Control, Attachment G, Containment Closure Determination Sheet.
5.5.2 MAKE entry in Category E/Locked Component Log for opening IA-823.
5.5.3 UNLOCK and OPEN IA-823.
POSITIVE CUE:
All completed per initial conditions Examiner Note: Step 5.6 is not applicable.
No action required for this 5.7 Opening RB Purge dampers: step.
POSITIVE CUE:
N/A
A1JPM-RO-GR01 Page 5 of 7 C PERFORMANCE CHECKLIST STANDARD SAT UNSAT N/A 5.7.1 At C15, DETERMINE if RB Pressure is positive, negative, or equal to atmospheric pressure: Applicant determined that
- PI-2400 PI-2402 RB Pressure is slightly
- PI-2401 PI-2403 positive and is trending 5.7.2 IF PMS is available, THEN INITIATE pressure.
trend of the following points:
A. OPEN the following valves: CRITICAL STEP (C)
- RB Purge Outlet (CV-7401)
- RB Purge Outlet (CV-7403) Applicant opened CV-7401 B. WHEN RB pressure equals atmospheric and CV-7403 and allowed ____ ____ ___
pressure OR PMS trend indicates RB Pressure to equalize.
pressure is equalized, THEN OPEN the Then opened CV-7402 and following valves: CV-7404
- RB Purge Inlet (CV-7402)
- RB Purge Outlet (CV-7401)
- RB Purge Outlet (CV-7403)
- RB Purge Inlet (CV-7402)
- RB Purge Inlet (CV-7404)
POSITIVE CUE:
RB Pressure is slightly positive (0.15 psig)
CV-7401, CV-7402, CV-7403, and CV-7404 Red light on and Green light off.
A1JPM-RO-GR01 Page 6 of 7 C PERFORMANCE CHECKLIST STANDARD SAT UNSAT N/A 5.8 PLACE RB Purge Exhaust Fan Applicant placed HS-7422 (C) VEF-15 handswitch (HS-7422) in in AUTO AUTO.
POSITIVE CUE:
Handswitch pointing towards AUTO.
No action required for this 5.9 Starting RB Purge Supply Fan (VSF-2) step.
POSITIVE CUE:
N/A CRITICAL STEP (C) 5.9.1 PLACE RB Purge Supply Fan VSF-2 Applicant started VSF-2 and handswitch HS-7421 in START. verified that VEF-15 5.9.2 IF RB Purge Exhaust Fan (VEF-15) automatically started.
did NOT auto start, THEN PLACE HS-7422 to MAN.
5.9.3 DETERMINE if VEF-15 flow rate is Applicant verified that 1.44E4 to 2.16E4 cfm using ONE of VEF-15 flow rate is the following: acceptable.
- Containment Purge SPING 1 (RX-9820) Channel 10.
- Rise in Totalized Stack Gas Flow (RI-8001) from RR-4830.
5.9.4 IF VEF 15 flow is NOT within 1.44E4 to 2.16E4 cfm,THEN: N/A ____ ____ ___
A. PLACE HS-7421 for VSF-2 to STOP.
B. PLACE HS-7422 to OFF.
C. CLOSE the following valves:
- RB Purge Outlet (CV-7403)
- RB Purge Inlet (CV-7404)
D. TAKE action to have fan flow adjusted to within limits.
POSITIVE CUE:
Red light on and Green light off for VSF-2 and VEF-15.
VEF-15 flow rate 1.77E4 cfm END
A1JPM-RO-GR01 Page 7 of 7 INITIAL CONDITIONS:
- Plant shutdown in progress.
- SPING 1 OPERABLE
- Plant Heating alignment is not desired for winter operations.
- Containment Closure Determination paperwork has been completed per Step 5.5.1
- IA-823 is unlocked, opened, and entered in the Cat E log.
INITIATING CUE:
The CRS/SM directs you to commence release per 1104.033 Attachment B, Reactor Building Purge Gaseous Release Permit.
PAGE: 58 of 115 1104.033 REACTOR BUILDING VENTILATION CHANGE: 084 ATTACHMENT B PAGE 4 OF 14 4.0 VERIFICATION NEEDED PRIOR TO PURGE (OPERATIONS) 4.1 CHECK RB Purge filter unit integrity established.
4.2 CHECK Reactor Building operability per TS 3.6.1 is NOT required.
N/A 4.3 IF SPING 1 is non-functional or unavailable, THEN:
4.3.1 ENSURE requirements specified in Analysis section of this permit for SPING 1 non-functional or unavailable have been performed.
4.3.2 IF SPING 1 channel 10 is unavailable, THEN LOG Totalized Stack Gas Flow (FI-8001) from Process Radiation Monitor Effluent Recorder (RR-4830):
4.4 OBTAIN CRS/SM approval to proceed with release.
Kyle Schwarber CRS/SM ___________________________________
5.0 RELEASE (OPERATIONS) 5.1 IF SPING 1 was assumed functional/available prior to purge, THEN ACKNOWLEDGE that SPING 1 becoming non-functional or unavailable anytime (for any reason) during the performance of this permit requires termination of the purge and a new purge permit initiated. (Ref. ODCM L2.2.1) 5.2 IF CRS/SM directs Plant Heating aligned for Winter operation, THEN PERFORM applicable steps of Aligning Plant Heating To Reactor Building When Shutdown section.
5.3 ENSURE RB Cooling Fan (VSF-1E) off.
5.4 ENSURE RB Cooling Fan VSF-1E Isol Damper (CV-7400) closed.
5.5 Operating CV-7403, CV-7404 IA Isol (IA-823) 5.5.1 COMPLETE 1015.002, Decay Heat Removal and LTOP System Control, Attachment G, Containment Closure Determination Sheet.
5.5.2 MAKE entry in Category E/Locked Component Log for opening IA-823.
5.5.3 UNLOCK and OPEN IA-823.
PAGE: 59 of 115 1104.033 REACTOR BUILDING VENTILATION CHANGE: 084 ATTACHMENT B PAGE 5 OF 14 5.6 IF during this purge release it becomes necessary to stop and restart purge release for reasons OTHER than SPING 1 becoming non-functional or unavailable, THEN:
5.6.1 PLACE RB Purge Supply Fan VSF-2 handswitch (HS-7421) in STOP.
5.6.2 PLACE RB Purge Exhaust Fan VEF-15 handswitch (HS-7422) in OFF.
5.6.3 CLOSE the following dampers:
- RB Purge Outlet (CV-7401)
- RB Purge Inlet (CV-7402)
- RB Purge Outlet (CV-7403)
- RB Purge Inlet (CV-7404) 5.6.4 RECORD release stop time ______________ Date _____________
5.6.5 ENSURE Station Log entry is made.
5.6.6 NOTIFY Chemistry that purge was terminated.
5.6.7 RECORD the following on Process Radiation Monitoring Effluent Recorder (RR-4830) EACH time purge is stopped:
- Time
- Date
- Purge Permit Number 5.6.8 RESTART purge per steps 5.7 through 5.10 of this permit.
PAGE: 60 of 115 1104.033 REACTOR BUILDING VENTILATION CHANGE: 084 ATTACHMENT B PAGE 6 OF 14 5.7 Opening RB Purge dampers:
CAUTION Reverse filter flow (performing steps out of sequence) can damage RB purge exhaust filters.
CRITICAL STEP 5.7.1 At C15, DETERMINE if RB Pressure is positive, negative, or equal to atmospheric pressure:
- PI-2400
- PI-2402
- PI-2401
- PI-2403 5.7.2 IF PMS is available, THEN INITIATE trend of the following points:
- P2405 (PMS)
- P2406 (PMS)
A. OPEN the following valves:
- RB Purge Inlet (CV-7402)
- RB Purge Inlet (CV-7404)
B. WHEN RB pressure equals atmospheric pressure OR PMS trend indicates pressure is equalized, THEN OPEN the following valves:
- RB Purge Outlet (CV-7401)
- RB Purge Outlet (CV-7403)
PAGE: 61 of 115 1104.033 REACTOR BUILDING VENTILATION CHANGE: 084 ATTACHMENT B PAGE 7 OF 14 5.7.4 IF RB pressure is positive, THEN:
A. OPEN the following valves:
- RB Purge Outlet (CV-7401)
- RB Purge Outlet (CV-7403)
B. WHEN RB pressure equals atmospheric pressure OR PMS trend indicates pressure is equalized, THEN OPEN the following valves:
- RB Purge Inlet (CV-7402)
- RB Purge Outlet (CV-7401)
- RB Purge Inlet (CV-7402)
- RB Purge Outlet (CV-7403)
PAGE: 62 of 115 1104.033 REACTOR BUILDING VENTILATION CHANGE: 084 ATTACHMENT B PAGE 8 OF 14 NOTE RB Purge Exhaust Fan (VEF-15) is interlocked to start when RB Purge Supply Fan (VSF-2) starts. If VEF-15 does not start, VSF-2 will trip 10 seconds later. Placing VSF-2 in OVERRIDE will allow VSF-2 to run whether or not VEF-15 is running.
5.9 Starting RB Purge Supply Fan (VSF-2) 5.9.1 PLACE RB Purge Supply Fan VSF-2 handswitch HS-7421 in START.
5.9.2 IF RB Purge Exhaust Fan (VEF-15) did NOT auto start, THEN PLACE HS-7422 to MAN.
5.9.3 DETERMINE if VEF-15 flow rate is 1.44E4 to 2.16E4 cfm using ONE of the following:
- Containment Purge SPING 1 (RX-9820) Channel 10
- Rise in Totalized Stack Gas Flow (FI-8001) from RR-4830 NOTE Maintaining the prescribed stack flow ensures isokinetic sampling conditions for noble gas, particulate, charcoal analysis streams remain functional. During non-isokinetic conditions, sampling accuracy is invalidated for SPING 1 and alternate sampling per ODCM L 2.2.1.
5.9.4 IF VEF-15 flow is NOT within 1.44E4 to 2.16E4 cfm, THEN:
A. PLACE HS-7421 for VSF-2 to STOP.
B. PLACE HS-7422 to OFF.
C. CLOSE the following valves:
- RB Purge Outlet (CV-7403)
- RB Purge Inlet (CV-7404)
D. TAKE action to have fan flow adjusted to within limits.
PAGE: 63 of 115 1104.033 REACTOR BUILDING VENTILATION CHANGE: 084 ATTACHMENT B PAGE 9 OF 14 5.10 RECORD the following:
- On Process Radiation Monitoring Effluent Recorder (RR-4830):
- Time
- Date
- Purge Permit Number
- Release start time ______________ Date __________________
- VEF-15 flow ______________________ E4 cfm.
5.11 NOTIFY Chemistry of Release start time.
5.12 MAKE a Station Log entry.
NOTE TRM 3.6.1 is satisfied by the performance of 5120.416, In-Place Testing Of The Unit 1 Rx Building Purge Filtration System. SPING 1 Channel 10 flow rates are not accurate enough to confirm flow within 10% of design flow. SPING 1 Channel 10 flow is monitored to detect adverse trends in fan performance and to bound the release criteria by observing flow within 20% of design flow.
5.13 IF SPING 1 Channel 10 is available AND notification is received from Chemistry that flow is out of specification per Form 1604.051A, Unit 1 SPING Monitor Log, THEN:
5.13.1 CHECK actual (stable) SPING 1 Channel 10 flow rate 1.44E4 to 2.16E4 cfm.
5.13.2 IF SPING 1 Channel 10 flow is NOT within 1.44E4 to 2.16E4 cfm, THEN TERMINATE release as follows:
A. NOTIFY SM.
B. PLACE RB Purge Supply Fan VSF-2 handswitch (HS-7421) to STOP.
C. PLACE RB Purge Exhaust Fan VEF-15 handswitch (HS-7422) to OFF.
5.13.2 Continued on next page
Page 1 of 5 JOB PERFORMANCE MEASURE Unit: 1 Rev 3 Date:
JPM ID: A1JPM-RO-ICS04 System/Duty Area: Integrated Control System Task: Perform ICS Startup JTA# ANO1-RO-ICS-NORM-38 KA Value RO 2.9 SRO 3.1 KA
Reference:
041 A4.01 Approved For Administration To: RO X SRO X Task Location: Inside CR Outside CR X Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulate Simulator: Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site X Simulator Lab Testing Method: Perform Simulate X Approximate Completion Time in Minutes: 10 Minutes Reference(s): 1105.004 Section 42.0 Examinee's Name: Login ID:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Robert Possage Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 5 JPM ID: A1JPM-RO-ICS04 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
THIS IS AN ALTERNATE PATH JPM.
JPM INITIAL TASK CONDITIONS:
The plant is in Mode 3.
ICS has been shutdown.
The S-1 and S-2 switches in C46-3 are open.
Breakers RS3-4 and Y02-34 have been verified closed.
TASK STANDARD:
ICS power supply breakers S-1 and S-2 closed and power restored.
TASK PERFORMANCE AIDS:
1105.004, Section 42.0.
Page 3 of 5 JPM ID: A1JPM-RO-ICS04 INITIATING CUE: The CRS/SM directs you to startup ICS per 1105.004 Section 41.0, steps 41.4 through step 41.6.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT EXAMINER NOTE: The Examinee should proceed to the ICS/Relay room on elevation 372.
Steps 42.1 - 42.3 are completed based on initial conditions given for the JPM.
42.4 At C46-2, ENSURE power supply switches inside cabinet are ON for the following: At C46-2, verified power supply
- ICS-PS-1 switches inside cabinet are ON
- ICS-PS-2 for the following:
- ICS-PS-3
- ICS-PS-1
- ICS-PS-4
- ICS-PS-2
- ICS-PS-3 POSITIVE CUE:
- ICS-PS-4 Power supply switches in ON position.
42.5 Resetting ICS Supply breakers S1 and S2 42.5.1 In C46 3, CLOSE AC Supply breakers S1 and S2. At the top of ICS cabinet C-46-3, closed AC supply breakers S1 AP FAULTED CUE (ALTERNATE PATH): and S2.
AC Supply breakers S1 and S2 failed to close.
42.5.2 IF S1 and S2 fail to close, THEN:
A. In ICS Cabinet (C46 2), WITHDRAW Supply Monitor 2 7 2 far enough to break connection. In ICS cabinet C-46-2, unscrewed and withdrew Supply Monitor 2 POSITIVE CUE: 2 far enough to break connection. ____ ____ ____
C Supply Monitor 2-7-2 is withdrawn, connection is broken.
B. CLOSE S1 and S2.
At the top of ICS cabinet C-46-3, POSITIVE CUE: closed AC supply breakers S1 AC Supply breakers S1 and S2 are in closed position. and S2.
C C. INSERT Supply Monitor 2 7 2.
In ICS cabinet C-46-2, inserted POSITIVE CUE: Supply Monitor 2-7-2 far enough Supply Monitor 2-7-2 is inserted, connection is made. to make connection C
D. ENSURE screws are hand tightened. Supply Monitor 2-7-2 inserted and screws hand tightened.
POSITIVE CUE: ____ ____ ____
C Supply Monitor 2-7-2 in inserted position, screws are in tightened position.
CONTINUED
Page 4 of 5 JPM ID: A1JPM-RO-ICS04 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT 42.6 At ICS and Aux System Power Supply Alarm At ICS and Aux System Power Panel (K14), RESET annunciators Supply Alarm Panel (K14),
depressed acknowledge button.
POSITIVE CUE:
All annunciators on K14 are clear.
NEGATIVE CUE:
ICS power supply annunciator on K14 in alarm.
42.7 CHECK the following clear: At ICS and Aux System Power
- C-46 +24V PS NOT EXIST (K14-A4) Supply Alarm Panel (K14),
- C-46 -24V PS NOT EXIST (K14-A5) checked the following
- C-46 +24V BP NOT EXIST (K14-A6) annunciators clear:
- C-46 -24V BP NOT EXIST (K14-A7)
- C-46 +24V PS NOT EXIST (K14-A4) ____ ____ ____
- C-46 -24V PS NOT EXIST POSITIVE CUE: (K14-A5)
All annunciators on K14 are clear.
- C-46 +24V BP NOT EXIST (K14-A6)
NEGATIVE CUE:
- C-46 -24V BP NOT EXIST ICS power supply annunciator on K14 in alarm. (K14-A7)
INSTRUCTOR NOTE: Inform Examinee JPM is complete.
END
Page 5 of 5 JPM ID: A1JPM-RO-ICS04 INITIAL CONDITIONS:
- The plant is in Mode 3.
- ICS has been shutdown.
- The S-1 and S-2 switches in C46-3 are open.
- Breakers RS3-4 and Y02-34 have been verified closed.
INITIATING CUE:
The CRS/SM directs you to startup ICS per 1105.004 Section 41.0, steps 41.4 through step 41.6.
PAGE: 74 of 89 1105.004 INTEGRATED CONTROL SYSTEM CHANGE: 036 41.0 N/A ICS SHUTDOWN CAUTION Performance of this section results in the loss of control to all ICS components.
41.1 In ICS Relay Room, at C46-3, OPEN the following breakers (located inside panel at top):
- S-1
- S-2 41.2 At Y02, OPEN Sola Trans Bypass Switch S-16 XY-234 (to ICS Y Bus) (Y02-34).
41.3 At RS3, OPEN ICS Cabinet C46 (RS3-4).
42.0 ICS STARTUP 42.1 In ICS Relay Room, at C46-3, ENSURE the following breakers open (located inside panel at top):
- S-1
- S-2 42.2 At RS3, CLOSE ICS Cabinet C46 (RS3-4).
42.3 At Y02, CLOSE Sola Trans Bypass Switch S-16 XY-234 (to ICS Y Bus) (Y02-34).
42.4 At C46-2, ENSURE power supply switches inside cabinet are ON for the following:
- ICS-PS-1
- ICS-PS-2
- ICS-PS-3
- ICS-PS-4
PAGE: 75 of 89 1105.004 INTEGRATED CONTROL SYSTEM CHANGE: 036 42.5 Resetting ICS Supply breakers S1 and S2:
42.5.1 In C46-3, CLOSE AC Supply breakers S1 and S2.
42.5.2 IF S1 and S2 fail to close, THEN:
A. In ICS Cabinet (C46-2), WITHDRAW Supply Monitor 2-7-2 far enough to break connection.
B. CLOSE S1 and S2.
C. INSERT Supply Monitor 2-7-2.
D. ENSURE screws are hand tightened.
42.6 At ICS and Aux System Power Supply Alarm Panel (K14), RESET annunciators.
42.7 CHECK the following clear:
- C-46 +24V PS NOT EXIST (K14-A4)
- C-46 -24V PS NOT EXIST (K14-A5)
- C-46 +24V BP NOT EXIST (K14-A6)
- C-46 -24V BP NOT EXIST (K14-A7) 42.8 CHECK ICS H/A stations HAND lamps lit.
42.9 CHECK ICS H/A stations POS/MEAS VAR indications do not indicate mid-scale (exception: ICS stations that indicate mid-scale due to plant conditions).
42.10 At C13, CHECK ALL ICS Instrument Power Supply Status lamps on.
JOB PERFORMANCE MEASURE Page 1 of 4 Unit: 1 Rev 1 Date:
JPM ID: A1JPM-RO-FP03 System/Duty Area: Fire Protection System Task: Manual Actuation of Halon System #3 JTA# ANO1-AO-AOP-OFFNORM-310 (Vision ID: 268798)
Reference:
086 A4.06 Approved For Administration To: RO X SRO X Task Location: Inside CR Outside CR X Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulate Simulator: Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site X Simulator Lab Testing Method: Simulate X Perform Approximate Completion Time in Minutes: 10 Minutes Reference(s): 1104.032 Fire Protection Systems, Exhibit A Examinee's Name: Login ID:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 4 JPM ID: A1JPM-RO-FP003 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
THIS IS AN ALTERNATE PATH JPM.
JPM INITIAL TASK CONDITIONS:
- Fire Protection System Trouble K12-D1 is in alarm due to Control Room Ceiling Trouble Zone 129-F.
- Smoke present in Control Room Ceiling area.
TASK STANDARD:
- Pulled the pin from the Pilot valve (on the Reserve Pilot cylinder).
- Pulled down on the Pull handle (on the Reserve Pilot cylinder).
TASK PERFORMANCE AIDS:
1104.032 Fire Protection Systems, Exhibit A - Manual Actuation of Halon System #2 or #3
Page 3 of 4 JPM ID: A1JPM-RO-FP003 INITIATING CUE: The CRS/SM directs you to manually actuate Halon System #3 (Control Room Ceiling) in accordance with 1104.032 Exhibit A.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT TRANSITION NOTE: The Examinee should proceed to the turbine deck behind missile wall/control room expansion.
- 1. On the Main Pilot cylinder, PULL the pin from the On the Main Pilot cylinder, Pilot valve. PULLED the pin from the Pilot valve. ____ ____ ____
POSITIVE CUE:
Pin pulled from Main Pilot valve.
- 2. PULL down on the Pull handle (on the Main Pilot PULLED down on the Pull handle cylinder). (on the Main Pilot cylinder).
FAULTED CUE (ALTERNATE PATH): ____ ____ ____
Main Pull handle down, all System #3 Main cylinders at ~750 psig and stable (use pen/pencil/etc. to show that pressure is stable).
- 3. IF the Halon system did NOT actuate, THEN on the Reserve Pilot cylinder:
3.1 PULL the pin from the Pilot valve. On the Reserve Pilot cylinder, PULLED the pin from the Pilot C ____ ____ ____
POSITIVE CUE: valve.
Pin pulled from Reserve Pilot valve.
3.2 PULL down on the Pull handle. PULLED down on the Pull handle (on the Reserve Pilot cylinder).
POSITIVE CUE:
C ____ ____ ____
Reserve Pull handle down, flow noise present accompanied by Reserve cylinder pressures lowering (use pen/pencil/etc.to show that pressure is lowering).
INSTRUCTOR NOTE: Inform Examinee JPM complete.
END
Page 4 of 4 JPM ID: A1JPM-RO-FP003 INITIAL CONDITIONS:
- Fire Protection System Trouble K12-D1 is in alarm due to Control Room Ceiling Trouble Zone 129-F.
- Smoke present in Control Room Ceiling area.
INITIATING CUE:
The CRS/SM directs you to manually actuate Halon System #3 (Control Room Ceiling) in accordance with 1104.032 Exhibit A.
PAGE: 152 of 397 1104.032 FIRE PROTECTION SYSTEMS CHANGE: 091 1104.032 EXHIBIT A Revised 11/28/2016 MANUAL ACTUATION OF HALON SYSTEM #2 OR #3 PAGE 1 OF 1 1.0 On the Main Pilot cylinder, PULL the pin from the Pilot valve.
2.0 PULL down on the Pull handle.
3.0 IF the Halon system did NOT actuate, THEN on the Reserve Pilot cylinder:
3.1 PULL the pin from the Pilot valve.
3.2 PULL down on the Pull handle.
Page 1 of 6 JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date:
JPM ID: A1JPM-RO-DHR01 System/Duty Area: Emergency Core Cooling System Task: Perform Decay Heat System Auxiliary Spray Alignment prior to Sump Recirculation JTA# ANO1-RO-DHR-NORM-19 KA Value RO 3.9 SRO 3.8 KA
Reference:
006 A4.05 Approved For Administration To: RO X SRO X Task Location: Inside CR Outside CR X Both Suggested Testing Environment and Method (Perform or Simulate ):
Plant Site: Simulate Simulator: Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Plant Site X Simulator Lab Testing Method: Perform Simulate X Approximate Completion Time in Minutes: 30 Minutes Reference(s): 1104.004, DHR Operating Procedure (R_131) Section21.0 Examinee's Name: Logon ID:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time
- Signed Robert Possage Date
- Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
Page 2 of 6 JPM ID: A1JPM-RO-DHR01 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall ensure that the examinee has been briefed on NUREG 1021 Appendix E.
JPM INITIAL TASK CONDITIONS:
- CV-1416 Aux Spray Valve is closed
- P-34B is the operating LPI Pump TASK STANDARD:
Align DH System Aux Spray as follows
- MU-64 Closed
- DH-4B Open
- DH-5B Open
- DH-94 Open
- DH-15 Open
- DH-63 Open TASK PERFORMANCE AIDS:
Copy of Section 21.0, DH System Aux Spray Alignment Prior toRB Sump Recirc.
Page 3 of 6 JPM ID: A1JPM-RO-DHR01 INITIATING CUE: The CRS/SM directs you to perform 1104.004 Section 21.0 DH System Aux Spray Alignment Prior to RB Sump Recirc.
C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT INSTRUCTOR NOTE: Step 21.1 is completed per the initial conditions.
21.0 DH SYSTEM AUX SPRAY ALIGNMENT PRIOR TO RB SUMP RECIRC 21.2 In UNPPR, ENSURE HP Pressurizer Aux Spray Verified HP Pressurizer Aux C Isolation (MU 64) closed. Spray Isolation (MU 64) closed ____ ____ ____
POSITIVE CUE:
MU-64 is fully clockwise and looks just like you see it.
21.3 In Lower North Piping Room, OPEN RCP Seal Opened RCP Seal Injection Filter Injection Filter F 2 Bypass (MU 41). F 2 Bypass (MU 41) by turning hand wheel counterclockwise. ____ ____ ____
POSITIVE CUE:
Handwheel for MU-41 will not turn any farther in the counter-clockwise (open) direction.
TRANSITION NOTE: The Examinee should proceed to 317 Elevation.
21.4 ENSURE P 34A Disch to DH Test & Recirc Verified P 34A Disch to DH Test Header (DH 8A) closed and locked. & Recirc Header (DH 8A) closed and locked.
POSITIVE CUE: ____ ____ ____
DH-8A fully clockwise and locked just like you see it.
21.5 OPEN supply valves from an operating LPI pump: Opened P 34B Supply to MU Prefilter and PZR Aux Spray C
- P 34B Supply (DH 4B) and ____ ____ ____
P 34B Supply to MU Prefilter and P 34B Supply to MU Prefilter and PZR Aux Spray PZR Aux Spray (DH 5B)
(DH 4B)
P 34B Supply to MU Prefilter and PZR Aux Spray (DH 5B)
POSITIVE CUE Handwheel for DH-4B and DH-5B will not turn any farther in the counter-clockwise (open) direction.
CONTINUED
Page 4 of 6 JPM ID: A1JPM-RO-DHR01 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT 21.6 ENSURE supply valves closed from the other LPI Verified P 34A Supply to MU pump: Prefilter and PZR Aux Spray
- P 34A Supply (DH 4A) and P 34A Supply to MU ____ ____ ____
Prefilter and PZR Aux Spray P 34A Supply to MU Prefilter and PZR Aux Spray (DH 5A) closed (DH 4A) .
P 34A Supply to MU Prefilter and PZR Aux Spray (DH 5A)
POSITIVE CUE:
DH-4A and DH-5A fully clockwise just like you see it.
21.7 In A DH Vault, ENSURE Pressurizer Aux Opened Pressurizer Aux Spray Spray Isolation (DH 94) is open. Isolation (DH 94).
C ____ ____ ____
POSITIVE CUE Handwheel for DH-94 will not turn any farther in the counter-clockwise (open) direction.
21.8 ENSURE DH Room Drains closed: Verified DH Room Drains closed:
- RBS/DH Room Drain Isol (A) (ABS 14) RBS/DH Room Drain Isol (A)
(ABS 14)
- RBS/DH Room Drain Isol (B) (ABS 13) and RBS/DH Room Drain Isol (B)
POSITIVE CUE: (ABS 13)
Handwheels for ABS-13 and ABS-14 are just like you see it.
21.9 ENSURE DH Room watertight doors closed: Verified DH Room watertight doors closed:.
- A DH Room door
- B DH Room door POSITIVE CUE:
Both doors are closed and the handle is in line with the taped arrow.
Page 5 of 6 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT 21.10 In Upper North Piping Penetration Room:
21.10.1 UNLOCK and OPEN DH to PZR Aux Spray UNLOCKED and OPENED DH to C Valve (DH 15). PZR Aux Spray Valve (DH 15).
POSITIVE CUE: ____ ____ ____
Handwheel for DH-15 will not turn any farther in the counter-clockwise (open) direction.
21.10.2 OPEN Pressurizer Aux Spray Valve (DH 63). OPENED Pressurizer Aux Spray C Valve (DH 63).
POSITIVE CUE:
Handwheel for DH-63 will not turn any farther in the ____ ____ ____
counter-clockwise (open) direction.
INSTRUCTOR CUE: Inform Examinee that the JPM is complete.
END
Page 6 of 6 JPM ID: A1JPM-RO-DHR01 INITIAL CONDITIONS:
- Aux Spray Valve CV-1416 is energized and closed
- P-34B Decay Heat Pump is the operating LPI pump INITIATING CUE:
The CRS/SM directs you to align DH System Aux Spray prior to RB Sump Recirc per 1104.004 Section 21.0.
PAGE: 120 of 584 1104.004 DECAY HEAT REMOVAL OPERATING PROCEDURE CHANGE: 131 20.18 N/A Restoration alignment:
20.18.1 CLOSE the following valves:
- Pressurizer Makeup Block Valve (CV-1233)
- Pressurizer Makeup Block Valve (CV-1234)
- Condensate/BA/Clean Liq Waste MUP Byp Isol (CZ-45) 20.18.2 REMOVE the shift turnover sheet entry regarding alternate purification effects on Letdown Relief Valve (PSV-1236).
20.18.3 ALIGN valves using Attachment C2, Decay Heat Coolant Purification By MU Demineralizer Restoration Lineup.
21.0 DH SYSTEM AUX SPRAY ALIGNMENT PRIOR TO RB SUMP RECIRC 21.1 ENSURE Aux Spray Valve (CV-1416) closed.
21.2 In UNPPR, ENSURE HP Pressurizer Aux Spray Isolation (MU-64) closed.
21.3 In Lower North Piping Room, OPEN RCP Seal Injection Filter F-2 Bypass (MU-41).
21.4 ENSURE P-34A Disch to DH Test & Recirc Header (DH-8A) closed and locked.
21.5 OPEN supply valves from an operating LPI pump:
- P-34A Supply
- P-34A Supply to MU Prefilter and PZR Aux Spray (DH-4A)
- P-34A Supply to MU Prefilter and PZR Aux Spray (DH-5A)
- P-34B Supply
- P-34B Supply to MU Prefilter and PZR Aux Spray (DH-4B)
- P-34B Supply to MU Prefilter and PZR Aux Spray (DH-5B)
PAGE: 121 of 584 1104.004 DECAY HEAT REMOVAL OPERATING PROCEDURE CHANGE: 131 21.6 ENSURE supply valves closed from the other LPI pump:
- P-34A Supply
- P-34A Supply to MU Prefilter and PZR Aux Spray (DH-4A)
- P-34A Supply to MU Prefilter and PZR Aux Spray (DH-5A)
- P-34B Supply
- P-34B Supply to MU Prefilter and PZR Aux Spray (DH-4B)
- P-34B Supply to MU Prefilter and PZR Aux Spray (DH-5B) 21.7 In A DH Vault, ENSURE Pressurizer Aux Spray Isolation (DH-94) is open.
CAUTION If RBS/DH Room Drain Isolation (ABS-14, ABS-13) is left partly open, DH vault can flood causing inoperability of LPI/DH train.
{4.2.5} 21.8 ENSURE DH Room Drains closed:
- RBS/DH Room Drain Isol (A) (ABS-14)
- RBS/DH Room Drain Isol (B) (ABS-13)
{4.2.5} 21.9 ENSURE DH Room watertight doors closed:
- A DH Room door
- B DH Room door 21.10 In Upper North Piping Penetration Room:
21.10.1 UNLOCK and OPEN DH to PZR Aux Spray Valve (DH-15).
21.10.2 OPEN Pressurizer Aux Spray Valve (DH-63).
{4.2.5} 21.11 In Ventilation Room elev 404' on east wall at Auxiliary Bldg H&V Control Cabinet (C143), PLACE the following valves in DAMPERS CLOSED position:
- B Decay Heat Room Dampers Isol (IA-7635)
- A Decay Heat Room Dampers Isol (IA-7636) 21.12 UNLOCK and CLOSE Pressurizer Aux Spray Valve CV-1416 breaker (B5531).
Facility: ANO-1 Scenario No.: 1 R0 Op-Test No.: 2020-1 Examiners: ____________________________Operators: _____________________________
Initial Conditions:
- IC201 - End of Life - Run Schedule File Scenario 1 R0
- 80% Power. - EFIC failed
- C-28A IA Compressor is out of service for - Group 5 Rod 12 and Group 3 Rod 1 overhaul (B-3256) Hang Caution card are stuck and will not insert during
- Make sure vacuum alarm adjusted correctly Rx trip
- C-8B In Service - CV-2827 Failed Closed Turnover:
- Boron 660 ppmB -
Event Event Event Malf. No.
No. Type* Description C-(BOP)
Loss of B3 with a failure of C-5B to start (Condenser 1 ED191 C-(SRO)
Vacuum Pump)
AOP I-(ATC) 2 TR049 I-(SRO) LT-1001 Pressurizer Level Fails Low (T.S. 3.3.15)
C-(BOP) 3 CV058 D RCP Seal Cooler Leak (35 gpm) (T.S. 3.4.13)
C-(SRO)
FW075 B MFW Pump Trip with a failure of CV-2827 (Results in 4 C-(SRO)
CV2827 Reactor Trip)
RD351 5 C-(SRO) 2 Stuck Control Rods - Emergency Boration RD363 CT 6 RC045 M-(ALL) Pressurizer Steam Space Leak increases to ~800 gpm C-(ATC) 7 FW621 EFIC Fails to actuate on low SG level C-(SRO)
C-(ATC)
C-(BOP) 8 RC045 RCPs must be secured within 2 minutes of LOSM C-(SRO)
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 47
Target Quantitative Attributes (Section D.5.d) Actual Attributes Malfunctions after EOP entry (1-2) 1 Abnormal Events (2-4) 3 Major Transients (1-2) 1 EOPs entered requiring substantive actions (1-2) 1 EOP contingencies requiring substantive actions ( 1per 1 scenario set)
Critical Tasks (2) 2 SCENARIO 1 OBJECTIVES
- 1) Evaluate individual ability to recognize and respond to a Loss of MCC (B3)
- 2) Evaluate individual ability to recognize and respond to a failed pressurizer level transmitter
- 3) Evaluate individual ability to recognize when conditions require the entry into technical specifications conditions.
- 4) Evaluate individual ability to estimate RCS leakage rate.
- 5) Evaluate individual ability to recognize and respond to excess RCS leakage.
- 6) Evaluate individual ability to reduce plant power.
- 7) Evaluate individual ability to recognize and respond to a Loss of Feedwater.
- 8) Evaluate individual ability to recognize and respond to Reactor Trip.
- 9) Evaluate individual ability to recognize and respond to a failure of EFIC
- 10) Evaluate individual ability to recognize and respond to a Loss of Subcooling Margin.
Page 2 of 47
SCENARIO 1 NARRATIVE Event One: Loss of B3 with a failure of C-5B to automatically start The crew will assume plant responsibility at ~80% power. Several alarms will occur due to the loss of load center but K02-C8 NON-ES Bus Loss of Voltage indicates a loss of B-3. Priority should be placed on verifying redundant equipment running for the following alarms, K05-A3 Vacuum Pump Trip, K05-C7 EH Pump P-14A/P-14B Trip, and K12-C3 Instrument Air Compressor Trouble. Actions will be directed from 1203.046 Section 3 (BOP-C) (SRO-C)
Event Two: Pressurizer level transmitter (LT-1001) fails low Once the plant is stabilized, the controlling pressurizer level transmitter will fail low. This will cause K09-C3, Pressurizer Level Lo and K09-A3, Pressurizer Level Lo-Lo. The crew should diagnose the failure by comparing diverse indication of pressurizer level and the lack of RCS pressure drop. The SRO will utilize OP-1203.015, Pressurizer Systems Failure, Section 4 - pressurizer Level Indication Malfunction. The ATC will determine that LT-1002 is the valid signal and select it for level control. The SRO will enter Post Accident Monitoring (PAM) Instrumentation T.S 3.3.15. (ATC-C) (SRO-C) AOP, TS Event Three: D RCP Seal Cooler Leak (35 gpm) develops The crew will recognize indications of an RCP Seal Cooler leak (Skewed seal injection flow rates, RCP Seal alarms) and receive K10-B2, Process Monitor Radiation Hi alarm. The crew will calculate a leak rate of ~35 gpm based on the NUC-ICW Surge Tank level rate of change (As reported from the field). The SRO will enter OP-1203.039, Excess RCS Leakage AOP and direct the crew accordingly. The SRO will also enter RCS Operational Leakage T.S. 3.4.13 Condition A. The crew will commence a plant shutdown in accordance with OP-1203.045, Rapid Plant Shutdown to allow for securing the RCP with the seal cooler leak. (ATC-C) (BOP-C) (SRO-C) AOP, TS Event Four: B MFW Pump Trip with a failure of CV-2827 (MFW Pump Crosstie valve)
Once power is stabilized and the RCP secured, the B MFWP will trip with a subsequent failure of the crosstie valve. With no feed to the B steam generator, the ATC will trip the reactor. The SRO will enter the Reactor Trip EOP. (ATC-C) (SRO-C) AOP Event Five: 2 Stuck Control Rods During immediate actions the ATC will identify two stuck rods and commence Emergency Boration per RT-12. It is a CRITICAL TASK to commence emergency boration within 15 minutes of the trip. Since Letdown was isolated due to the RCP seal cooler leak contingency actions from RT-12 will be required.
This may be handed off to the BOP or performed by the ATC. (ATC-C) (BOP-C) (SRO-C) EOP, CT CT Justification: CT-23 Safety significance - Establish and Maintain Reactor Shutdown Requirements.
Initiating Cue - Lack of Green In Limit lights for two control rods post trip.
Measurable Performance Standard - Manual initiation of Emergency Boration per RT-12 within 15 minutes of the reactor trip.
Performance Feedback - HPI flow to the RCS via an injection nozzle. (CV-1220 or CV-1285)
Event Six / Eight: Pressurizer Steam Space Leak (~800 gpm)
After emergency boration has been initiated and at the discretion of the lead examiner, a large pressurizer steam space leak will begin. This leak will result in a Loss of Subcooling Margin, this will require a transition to the contingency EOP. The second critical task of tripping all RCPs within two minutes of a LOSM will be required during this event. The SRO will direct the crew in accordance with OP-1202.002 Loss of Subcooling Margin. (ATC-C) (BOP-C) (SRO-C) EOP, CT CT Justification: CT-1 Safety significance - Failure of a fission product barrier (RCS)
Initiating Cue - SCM monitor on ICCMDS indicates <30 oF and timer counting. Train A/B ICC Event alarms on K11.
Measureable Performance Standard - Trip ALL RCPs within 2 minutes of LOSM following the reactor trip.
Performance Feedback - Change of status lamps on control console for RCPs and indicated RCS flow near zero.
Page 3 of 47
Event Seven: EFIC Fails to actuate on low SG level As a result of the B MFW Pump trip and crosstie valve failure, the B steam generator will not have a source of feedwater. Steam generator level will drop to the EFIC low level setpoint but will fail to actuate.
The ATC will identify the low level and manually actuate EFW from the remote matrix on C09.
(ATC-C) (SRO-C) EOP The scenario can be terminated at the discretion of the lead examiner.
Page 4 of 47
Simulator Instructions for Scenario 1 Reset simulator to MOL ~100% power IC steady state Ensure malfunctions agree with scenario guide (either schedule file or IC)
Event Time Event Description No. Type C-(BOP)
Loss of B3 with a failure of C-5B to start (Condenser 1 T=0 C-(SRO)
Vacuum Pump)
AOP I-(ATC) 2 T=12 I-(SRO) LT-1001 Pressurizer Level Fails Low (T.S. 3.3.15)
C-(BOP) 3 T=20 RCP Seal Cooler Leak (35 gpm) (T.S. 3.4.13)
C-(SRO)
B MFW Pump Trip with a failure of CV-2827 (Results in 4 T=55 C-(SRO)
EOP C-(ATC) 5 T=55 C-(SRO) 2 Stuck Control Rods - Emergency Boration CT 6 T=60 M-(ALL) Pressurizer Steam Space Leak increases to ~800 gpm C-(ATC) 7 T=60 EFIC Fails to actuate on low SG level C-(SRO)
C-(ATC)
C-(BOP) 8 T=60 RCPs must be secured within 2 minutes of LOSM C-(SRO)
CT Page 5 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __1__
Event
Description:
__Loss of B-3 with a failure of C-5B to automatically start________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: The BOP should manually start C-5B Vacuum Pump and C-1B Gland Steam Condenser Exhauster.
BOOTH OPERATOR: When directed to check status of equipment, wait 2 minutes and report component running. When directed to perform breaker alignment wait 15 minutes and report completed unless redirected to perform something else. When directed report Instantaneous Overcurrent Flag on A-103 T=0 ATC Acknowledge and report NON-ES BUS LOSS OF VOLTAGE (K02-C8)
SRO Update and enter 1203.046 Loss of Load Center BOP 1. ENSURE Condenser Vacuum Pump (C-5B) running.
BOP 2. ENSURE EH Oil Pump (P-14B) running.
NLO 3. ENSURE Isophase Bus Cooling Fan (C-8B) running.
ATC 4. ENSURE Instrument Air Compressor (C-28B) running.
SRO 5. DISPATCH an operator (with a ladder) to align Main Transformer cooling supplies from B4 as follows:
- For Main Phase Xfmr (X-01B):
A. OPEN breaker 8-5.
B. CLOSE BOTH of the following breakers, using a ladder as necessary:
7 8
- ENSURE Main Phase Xfmrs (X-01C and X-01S) on B4 supply (cooling fans running).
N/A 6. IF Letdown/Bleed 3-way Valve (CV-1248) is in the BLEED position N/A BOP 7. ENSURE Gland Steam Cond Exhauster (C-1B) running.
BOP 8. ENSURE Air Side Seal Oil Backup Pump (P-25) running.
BOP 9. REFER TO the following:
- 1107.001, Electrical System Operations, Attachment D, 480 Non-ES Motor Control Center Checklist to determine components that could require actions
- 1107.007, Non-ESF Electrical Bus Outage, Attachment G, 480V Load Center B3 Outage to determine possible contingencies for de-energized components CREW 10. DETERMINE cause of loss of B3.
N/A 11. WHEN the cause of the loss of B3 has been determined and correctedN/A End of Event Page 6 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __2__
Event
Description:
____ LT-1001 Pressurizer Level Fails Low (T.S. 3.3.15)_________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: Cues to the crew will be K09-C3 PZR LEVEL LO, and K09-A3, PZR LEVEL LOLO. LRS-1001 reading 0 inches, M/U Flow rising T=15 ATC Acknowledge and report K09-C3 PZR LEVEL LO, and K09-A3, PZR LEVEL LOLO. Report that LRS-1001 is reading 0 inches and LRS-1002 is reading 220 inches and rising.
SRO Enter OP-1203.015, Pressurizer Systems Failure - Section 4, Pressurizer Level Indication Malfunction.
ATC / SRO 2. IF one level indicator differs from the rest (indicator is assumed invalid), THEN GO TO step 5.
ATC 5. WHEN validity of transmitters and indicators is determined, THEN SELECT valid Pressurizer level transmitter using HS-1002.
- 6. IF invalid instrument indication is greater than 16" from other level indications, THEN:
SRO A. DECLARE invalid instrument inoperable.
B. REFER TO Post Accident Monitoring (PAM) Instrumentation (TS TS 3.3.15).
ATC 7. ENSURE Pressurizer Heater Proportional Control (PIC-1004) in AUTO.
End of Event NOTES: .
Page 7 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __3__
Event
Description:
__D RCP Seal Cooler Leak (35 gpm) (T.S. 3.4.13) ________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: Cues to the crew will be skewed seal injection flow, RCP seal alarms, and eventually K10-B2, Process Monitor Radiation Hi.
T=20 ATC Acknowledge and report K08-C7, RCP Bleedoff Temperature Hi and skewed seal injection flowrates.
BOP Report that the alarm is due to D RCP SRO Enter OP-1203.039, Excess RCS Leakage EXAMINER NOTE: All the contingency actions in Step 1 are IF Desired, but I dont expect him to direct Steps A or B, he might direct Step C at this point.
SRO C. IF desired, THEN PERFORM ONE of the following:
- REDUCE letdown flow by closing Orifice Bypass (CV-1223)
- ISOLATE Letdown by closing either:
- Letdown Coolers Outlet (RCS)
¨ CV-1221
- Letdown Coolers Outlets (RCS):
¨ CV-1214
¨ CV-1216
- 2. PERFORM Exhibit 1, Estimate of RCS Leakrate and CONTINUE with ATC/BOP this procedure.
A. Periodically, PERFORM Exhibit 1 to maintain status of leakrate.
B. ADVISE Shift Manager to implement 1903.010, Emergency Action Level Classification.
C. PERFORM step 14 in conjunction with efforts to isolate leak.
EXAMINER NOTE: Step 14 will commence a plant shutdown per 1203.045 Rapid Plant Shutdown.
- 3. CHECK location of leak is known.
SRO PERFORM applicable step(s):
- For RCS Leakage into ICW System: Step 5 SRO - 5. ENSURE leakrate trend established using ICW Surge Tank T-37B Level.
BOOTH OPERATOR: When directed to trend and report T-37B level, wait 2 minutes and report that level is rising at 0.1 psid/min. (This equates to 33.3 gpm)
BOP 6. CHECK Letdown Cooler tubes have integrity.
Page 8 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __3__
Event
Description:
__D RCP Seal Cooler Leak (35 gpm) (T.S. 3.4.13) ________________
__(Continued)______________________________________________________________________
Time Position Applicants Actions or Behavior
- 7. CHECK BOTH of the following exist:
- RCP Seal Cooler tube integrity is sat
- EITHER of the following:
- Letdown Cooler tube integrity is sat
- Letdown Cooler is capable of isolation
- 7. PERFORM the following:
ATC A. IF seal injection is available, THEN ENSURE 2.5 gpm or more seal injection flow per RCP.
N/A B. IF seal injection is NOT available AND RCP(s) are operating,THEN: ...N/A ATC C. PLACE RCP Seal Cooling pumps in PULL-TO-LOCK:
- P-114A
- P-114B D. ENSURE Letdown isolated.
E. CLOSE Nuclear ICW RB Inlet (CV-2233).
BOP F. CLOSE BOTH Nuclear ICW RB Outlets:
- CV-2214
H. IF required for adequate RCP seal cooling, THEN:
ATC 1) ENSURE RC Pump Seals Total INJ Flow (CV-1207) in HAND.
- 2) RAISE seal injection flow.
SRO I. DIRECT Radiation Protection to implement 1601.307, Unit 1 Off-Normal Operations for primary to ICW leak.
NLO J. CLOSE ICW Surge Tank Crossconnect Isol (ICW-165).
K. IF RCP Seal temperatures rise indicating inadequate seal SRO cooling due to RCS leakage greater than seal injection flow, THEN PERFORM step 8 for inadequate seal cooling.
L. IF Nuclear Loop ICW Feed and Bleed in progress, THEN N/A as time allows, SECURE Feed and Bleed per 1104.028, ICW System Operating Procedure.
SRO M. GO TO step 14.
Page 9 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __3__
Event
Description:
__D RCP Seal Cooler Leak (35 gpm) (T.S. 3.4.13) ________________
__(Continued)______________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: Step 8 is performed for the pump with the leaking seal cooler, while Step 14 is also being performed.
BOP 8. CHECK RCP seal temp rise indicates proper cooling even with RCS leakage into seal cooler.
- 8. IF RCP seals temperatures rise indicating inadequate seal cooling due to RCS leakage greater than seal injection flow,THEN:
A. IF tripping the affected RCP(s) will result in automatic N/A reactor trip N/A B. IF tripping the affected RCP(s) will NOT cause an BOP automatic reactor trip, THEN:
- 1) TRIP affected RCP(s).
- 2) ENSURE proper ICS response.
- 3) IF only ONE RCP is in operation per loop, THEN REFER TO Tech Spec 3.4.4.
BOP C. IF RCP was stopped, THEN MONITOR affected RCP for reverse rotation using ANY of the following:
N/A D. IF RCP reverse rotation is indicated, N/A E. For any RCP tripped due to inadequate seal cooling, BOP PERFORM 1203.031, Reactor Coolant Pump and Motor Emergency, Exhibit A, RCP Seal Bleedoff Isolation for applicable RCP.
EXAMINER NOTE: Exhibit A for isolation of seal bleedoff is located at the back of the exam guide.
Exhibit A will be performed on the stopped pump to limit the heatup rate of the seal.
EXAMINER NOTE: The SRO should decide that the leakage inside containment requires a Rapid Plant Shutdown at a rate between 0.5 to 5%/minute.
If asked, the Senior Manager, Operations agrees with the recommended actions of the crew.
- 14. Determining whether operation should continue:
SRO A. CHECK total RCS leakage exceeds the amount allowed by Tech Spec 3.4.13.
TS B. CHECK total RCS leakage poses a threat to continued plant operations C. CHECK reactor is critical.
ATC D. COMMENCE plant shutdown per 1203.045, Rapid Plant Shutdown.
Continued Page 10 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __3__
Event
Description:
__D RCP Seal Cooler Leak (35 gpm) (T.S. 3.4.13) ________________
__(Continued)______________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: The following guidance is from 1203.045 Rapid Plant Shutdown ATC 1. COMMENCE power reduction at 0.5 to 10% per minute.
- 2. During power reduction:
- IF power reduction is NOT due to automatic runback, THEN ENSURE ATC has been given a specific end point for the power reduction and rate of desired power change.
- IF power reduction is due to automatic runback, N/A
- IF necessary to maintain Makeup tank level, THEN:
- OPEN BWST T3 Outlet to operating HPI Pump (CV 1407 or CV 1408).
- MINIMIZE or ISOLATE Letdown.
- IF power reduction is due to Transmission Control Center North (TCC N) request, ...N/A
- IF power reduction is NOT at TCC N request, THEN as time allows, MAKE notifications to TCC N per the following:
- ENS DC 201, ENS Transmission Grid Monitoring
- EN FAP WM 015, Unit Generation Forecasting for EMO/MISO ATC 3. MONITOR ICS and EHC subsystems for proper integrated response
- 4. While monitoring ICS and EHC:
- INITIATE manual control of ICS or EHC subsystems as deemed appropriate by the operator for potential failures of control systems.
- DIRECT ATC to refer to applicable exhibit for manual operation of ICS.
- IF desired to restore automatic control of a subsystem, THEN REFER TO 1105.004, Integrated Control System.
- IF desired to stop downpower above final ULD setpoint, THEN PERFORM Operation of SG/RX Demand Hand/Auto Station, Exhibit 1.
Continued Page 11 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __3__
Event
Description:
__D RCP Seal Cooler Leak (35 gpm) (T.S. 3.4.13) ________________
__(Continued)______________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: The following guidance is from 1203.045 Rapid Plant Shutdown
- 5. IF plant has been stabilized with the reactor critical, THEN:
- DIRECT ATC to refer to Contingency Reactivity Plans located in the Plant Data Book.
- USE 1102.004, Power Operation, Exhibit A, Operation of APSR Group to control imbalance (ref. Plant Data Book).
- ESTABLISH desired control bands with the ATC.
(Recommended: power band is +/- 2%.)
- IF power is oscillating greater than 2%, THEN CONSIDER placing ICS Hand/ Auto Station(s) in HAND to stabilize plant power.
- WHEN time permits, THEN PERFORM transient brief stressing reactivity control aspects:
- Reactor status versus Contingency Reactivity Plan
- Review and maintain COLR limits
- Expected rod movement
- Expected boration / dilution SRO 6. IF reducing power below 90%, THEN SECURE Zinc Injection per ONE of the following:
- REQUEST Chemistry secure Zinc Injection per 1052.036, Unit 1 Reactor Coolant System (RCS) Zinc Control.
- PERFORM 1104.003, Chemical Addition, Securing Zinc Injection section SRO 7. IF reducing power below Heater Drain Pump operation, THEN as time permits, PERFORM 1106.031, MSR Drain Demineralizer Operation, Removing MSR DI From Service section.
Continued Page 12 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __3__
Event
Description:
__D RCP Seal Cooler Leak (35 gpm) (T.S. 3.4.13) ________________
__(Continued)______________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: The following guidance is from 1203.045 Rapid Plant Shutdown
- CONTINUE power reduction to 60 to 65%.
- TRIP Heater Drain Pump (P8A/B) associated with the tripped BOP RCP:
P8A P8B P32C P32A P32D P32B A. DISPATCH an operator to perform 1203.012E, Annunciator K06 Corrective Action, applicable Exhibits A or B Local Actions for Heater Drain Tank T 40A/T 40B Level Control on High Level Dump.
B. On C02, ENSURE Low Level Condenser Sprays (HS 2907) open.
C. IF Polisher Bypass Valve (CS-27) is throttled open/open,THEN DIRECT Auxiliary Operators to throttle CS-27 per 1102.016, Power Reduction and Plant Shutdown.
EXAMINER NOTE: If not already performed, the crew will stop the RCP with the seal cooler leak.
End of Event NOTES: .
Page 13 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __5__
Event
Description:
____ B MFW Pump Trip with a failure of CV-2827 _________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: Steps 4-11 will not help the situation, Step 12 will verify proper EFW actuation. However, I expect the SRO to transition to the Reactor Trip EOP once the conditions are recognized for a reactor trip. The EOP will also address verification of EFW actuation. No AOP steps need to be performed once the reactor is tripped.
ATC Acknowledge and report K07-A8) B MFP Turbine Trip SRO Update and enter 1203.027 Loss of Steam Generator Feed ATC 1. IF EITHER of the following conditions apply:
- SG level is less than 15" with no indication of recovery
- Feedwater flow is lost to EITHER SG with no indication of recovery with Reactor power above 7%. THEN:
A. TRIP the reactor.
B. PERFORM 1202.001, Reactor Trip in conjunction with this procedure.
N/A 2. IF both MFWPs are running AND ONE MFWP has failed without tripping, N/A ATC 3. IF ONE MFWP is operating, THEN ENSURE that Feedwater Pumps Disch Crosstie (CV-2827) is open.
ATC Identify that CV-2827 failed to open and a Reactor Trip is required.
ATC 12. IF feedwater flow to BOTH SGs can NOT be restored, THEN PERFORM RT-5 to actuate EFW.
SRO Transition to 1202.001 Reactor Trip EOP End of Event 5 NOTES: .
Page 14 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __6__
Event
Description:
____ Two Stuck Control Rods - Emergency Boration _________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: RT-12 and RT-19 are located at the back of the exam guide.
It is a CRITICAL TASK for the ATC to initiate Emergency Boration within 15 minutes of the reactor trip. Emergency Boration (RT-12) will require Step 2 be performed due to letdown being isolated earlier.
ATC 1. Depress Reactor Trip PB.
A. Verify all rods inserted AND reactor power dropping.
ATC/BOP A. Perform the following:
- 1) IF reactor fails to trip, THEN N/A
- 2) IF more than one rod fails to fully insert CT OR reactor power is not dropping, THEN perform Emergency Boration (RT-12).
- 3) Do not continue until the reactor is shutdown BOP 2. Depress Turbine trip PB.
A. Check Turbine throttle and governor valves closed.
ATC/BOP 3. Check adequate SCM.
SRO 4. Perform the following:
- Advise Shift Manager to implement Emergency Action Level Classification (1903.010).
- Direct Control Board Operators to monitor floating steps ATC 5. Verify Orifice Bypass (CV-1223) demand adjusted to zero.
BOP 6. Open BWST T3 Outlet (CV-1407 or CV-1408) to operating HPI pump.
N/A 7. IF Emergency Boration is not in progress, THEN adjust Pressurizer Level Control setpoint to 100.
ATC 8. Control RCS press within limits of Figure 3 (RT-14).
BOP 9. Check for proper electrical response (RT-19).
ATC 10. Check normal Makeup and Seal Injection are in service.
EXAMINER NOTE: Once Emergency Boration is in progress (Step I complete) insert next event at the discretion of the lead examiner.
End of Event 6 Page 15 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __7,8,9__
Event
Description:
Pressurizer Steam Space Leak increases to ~800 gpm .
EFIC Fails to actuate on low SG level / RCPs must be secured within 2 minutes of LOSM__
Time Position Applicants Actions or Behavior EXAMINER NOTE: Cues to the crew will be significant drop in RCS pressure / rate of change in pressure. ESAS Low RCS Pressure Trip Setpoint is <1590 psig.
ATC/BOP Announce that the leakage has increased significantly.
ATC/BOP FLOATING STEP IF SCM is less than adequate AND 4160V bus A1 or A2 is SRO energized, THEN GO TO 1202.002, "LOSS OF SUBCOOLING MARGIN" procedure.
EXAMINER NOTE: SRO will transition to Loss Of Subcooling Margin. Once ESAS actuates, Step 3 below is no longer applicable.
ATC/BOP 1. Check elapsed time since loss of adequate SCM is less than 2 minutes BOP 2. TRIP ALL RCPs:
- P32A
- P32C
- P32B
ATC 4. CHECK Makeup Tank level remains above 18".
ATC 5. PERFORM proper EFW actuation and control verification (RT-5).
SRO 6. DIRECT Control Board Operators to monitor floating steps.
Continued Page 16 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __7,8,9__
Event
Description:
Pressurizer Steam Space Leak increases to ~800 gpm .
EFIC Fails to actuate on low SG level / RCPs must be secured within 2 minutes of LOSM__
__(Continued)__________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: In Step 8, the BOP will have to perform RT-10 which is in the back of this exam guide.
ATC 7. CHECK MFW is the feed source. (Contingency Action)
- A Main Feed Pump
BOP 8. PERFORM proper ESAS actuation verification (RT-10).
ATC 9. CHECK RCS press is greater than or equal to 150 psig.
- 10. Determining potential transition:
A. CHECK ALL of the following apply:
- RCS T-cold is less than 540°F and dropping
- SCM is adequate N/A B. GO TO 1202.003, Overcooling.
- 11. ISOLATE Pressurizer Spray Line as follows:
A. PLACE Pressurizer Spray Control Mode in MAN.
ATC B. ENSURE Pressurizer Spray (CV-1008) closed (modulating valve).
C. CLOSE Pressurizer Spray Isolation (CV-1009).
- 12. CHECK EITHER of the following conditions exist:
- ERV was opened by procedure to intentionally depressurize the RCS ATC 13. CHECK Nuclear Loop ICW process monitor alarm clear.
ATC 14. CHECK CET temps remain subcooled.
ATC 15. CHECK SG tube integrity (RT-18).
ATC 16. CHECK SCM remains less than adequate.
Page 17 of 47
Op-Test No.: __1__ Scenario No.: __1__ Event No.: __7,8,9__
Event
Description:
Pressurizer Steam Space Leak increases to ~800 gpm .
EFIC Fails to actuate on low SG level / RCPs must be secured within 2 minutes of LOSM__
__(Continued)__________________________________________________________________
Time Position Applicants Actions or Behavior ATC 17. CHECK RCS press remains greater than or equal to 150 psig.
ATC 18. CHECK SG levels at or approaching 370 to 410.
- 19. CHECK primary to secondary heat transfer in progress indicated by ALL of the following:
- T-cold tracking associated SG T-sat (Fig. 2)
- T-hot tracking CET temps
- T-hot/T-cold DT stable or dropping ATC 20. CHECK SCM is adequate. (Contingency Action)
SRO 20. GO TO step 29.
- 29. CHECK primary to secondary heat transfer in progress indicated by ALL of the following:
- T-cold tracking associated SG T-sat (Fig. 2)
- T-hot tracking CET temps
- T-hot/T-cold DT stable or dropping ATC 30. CHECK SG levels at or approaching one of the following Any RCP RCPs Off and RCPs Off and SCM on SCM adequate less than adequate 20 to 40 300 to 340 370 to 410 ATC 31. CHECK SCM remains less than adequate.
ATC 32. CHECK ALL of the following:
- Cause of loss of adequate SCM is corrected
- SCM is adequate
- Primary to secondary heat transfer is in progress End of scenario Page 18 of 47
1203.031 EXHIBIT A REVISED 11/17/2016 RCP SEAL BLEEDOFF ISOLATION PAGE 1 OF 2 CAUTION
- Closing the seal bleed off path on a running RCP will cause seal damage due to overheating.
- Closing the seal bleed off valves after the RCP is tripped limits the heatup rate of the seal.
1.0 IF desired to isolate RCP seal Bleedoff on ALL RCPs, THEN:
A. PLACE RCP Seal Bleed off (Alternate Path to Quench Tank) in CLOSE:
RCP Seal Bleed off RCP (Alternate Path to Quench Tank)
P-32A SV-1273 P-32B SV-1272 P-32C SV-1271 P-32D SV-1270 B. PERFORM ONE of the following:
- CLOSE RCP Seal Bleedoff (Normal) Return (CV-1274).
- CLOSE RCP Seal Bleedoff (Normal) from P32A/B/C/D:
- CV-1270
- CV-1271
- CV-1272
- CV-1273 Page 19 of 47
1203.031 EXHIBIT A REVISED 11/17/2016 RCP SEAL BLEEDOFF ISOLATION PAGE 2 OF 2 CAUTION
- Closing the seal bleed off path on a running RCP will cause seal damage due to overheating.
- Closing the seal bleed off valves after the RCP is tripped limits the heatup rate of the seal.
2.0 IF desired to isolate a single RCP seal bleedoff flowpath, THEN:
A. PLACE associated RCP Seal Bleed off (Alternate Path to Quench Tank) in CLOSE:
RCP Seal Bleed off RCP (Alternate Path to Quench Tank)
P-32A SV-1273 P-32B SV-1272 P-32C SV-1271 P-32D SV-1270 B.. CLOSE associated RCP Seal Bleed off (Normal):
RCP Seal Bleed off RCP (Normal)
P-32A CV-1273 P-32B CV-1272 P-32C CV-1271 P-32D CV-1270 Page 20 of 47
THEN CLOSE EITHER of the following to isolate Letdown:
- Letdown Coolers Outlet (RCS) (CV-1221)
- BOTH Letdown Coolers Outlets (RCS):
- CV-1214
- CV-1216
- 2. IF OP or STBY HPI pump is running, THEN:
A. ENSURE BWST T3 Outlet to OP or STBY HPI pump is open.
OP or STBY HPI PUMP P36A/P36B (RED) P36C/P36B (GREEN)
CV-1407 CV-1408 B. IF RCP Seal Injection is in service, THEN PLACE RCP Seal INJ Block (CV-1206) in OVRD.
C. WHEN associated BWST T3 Outlet is open, THEN OPEN HPI Block associated with OP or STBY HPI pump to maintain PZR level and RCS press.
OP or STBY HPI PUMP P36A/P36B (RED) P36C/P36B (GREEN)
CV-1220 CV-1285 D. IF initiating HPI for Emergency Boration only, THEN GO TO RT-12 step 2.B.
E. IF PZR level or RCS press continues to drop, THEN OPEN additional HPI Blocks as necessary associated with OP or STBY HPI pump:
OP or STBY HPI PUMP P36A/P36B (RED) P36C/P36B (GREEN)
CV-1219 CV-1227 CV-1278 CV-1228 CV-1279 CV-1284 Page 21 of 47
INITIATE HPI PAGE 2 OF 7
- 3. IF EITHER OP or STBY HPI pumps are available AND BOTH pumps are off, THEN PLACE OP or STBY HPI pump in service as follows:
A. ENSURE BWST T3 Outlet to OP or STBY HPI pump is open.
OP or STBY HPI PUMP P36A/P36B (RED) P36C/P36B (GREEN)
CV-1407 CV-1408 B. ENSURE RCP Seal INJ Block (CV-1206) closed.
C. CLOSE EITHER RCS Makeup Block:
- CV-1233
- CV-1234 D. ENSURE ONE of the following conditions exists to prevent dead heading pump:
- BOTH HPI Pump RECIRC Blocks are open:
- CV-1300
- CV-1301
OP or STBY HPI PUMP P36A/P36B (RED) P36C/P36B (GREEN)
CV-1220 CV-1285 E. IF HPI Pump (P-36B) will be used, THEN ENSURE the following selected to energized bus:
- P36B/P64B Bus Select MOD Control
(3. CONTINUED ON NEXT PAGE)
Page 22 of 47
INITIATE HPI PAGE 3 OF 7
- 3. (Continued)
G. START OP or STBY HPI pump.
H. STOP AUX Lube Oil pump.
I. WHEN associated BWST T3 Outlet is open, THEN:
OP or STBY HPI PUMP P36A/P36B (RED) P36C/P36B (GREEN)
CV-1220 CV-1285
- 2) IF PZR level or RCS press continues to drop, THEN OPEN additional HPI Blocks associated with OP or STBY HPI pump:
OP or STBY HPI PUMP P36A/P36B (RED) P36C/P36B (GREEN)
CV-1219 CV-1227 CV-1278 CV-1228 CV-1279 CV-1284
- 3) MONITOR Makeup Tank level and CONTROL per step 10 as necessary.
J. IF initiating HPI for Emergency Boration only, THEN GO TO RT-12 step 2.B.
Page 23 of 47
RT-5 PROPER EFW ACTUATION AND CONTROL VERIFICATION
- 1. ENSURE EFW actuation indicated on C09:
Train A: Train B:
- Bus 1
- Bus 1
- Bus 2
- Bus 2 NOTE Table 1 contains EFW fill rate and level bands for various plant conditions.
- 2. ENSURE at least one EFW pump (P7A or P7B) running with flow to SG(s) through applicable EFW CNTRL valve(s).
SG A SG B CV-2645 P7A CV-2647 CV-2646 P7B CV-2648
- 3. IF SCM is NOT adequate, THEN:
A. SELECT Reflux Boiling setpoint for the following:
- Train A
- Train B NOTE Table 2 contains examples of less than adequate/excessive EFW flow.
B. ENSURE EFW CNTRL valves operate to establish and maintain SG levels 370 to 410.
(3. CONTINUED ON NEXT PAGE)
Page 24 of 47
RT-5 PROPER EFW ACTUATION AND CONTROL VERIFICATION
- 3. (Continued)
NOTE A SG is considered available if it has the capability to be fed and steamed.
a) IF EFW flow is less than adequate, THEN CONTROL EFW to applicable SG in HAND to maintain greater than or equal to 340 gpm to applicable SG until level is 370 to 410.
b) IF EFW flow is excessive AND greater than 340 gpm to either SG, THEN THROTTLE EFW to applicable SG in HAND to limit SG depressurization while maintaining greater than or equal to 340 gpm to each SG until SG level is 370 to 410.
- 2) IF only one SG is available, THEN FEED available SG in HAND at greater than or equal to 570 gpm until SG level is 370 to 410.
- 3) IF EFW is being controlled in HAND AND SG press drops below 720 psig due to EFW flow induced overcooling, THEN:
a) CONTINUE feeding at required minimum rate.
b) BYPASS MSLI by momentarily placing SG Bypass toggle switch on each EFIC cabinet Initiate module in BYPASS.
- C37-3
- C37-4
- C37-1
- C37-2 (3. CONTINUED ON NEXT PAGE)
Page 25 of 47
RT-5 PROPER EFW ACTUATION AND CONTROL VERIFICATION
- 3. (Continued) c) PLACE applicable EFW CNTRL valves in VECTOR OVERRIDE:
SG A SG B CV-2645 P7A CV-2647 CV-2646 P7B CV-2648 d) PLACE applicable EFW ISOL valves in MANUAL.
SG A SG B CV-2627 P7A CV-2620 CV-2670 P7B CV-2626
- 4. IF SCM is adequate, THEN:
CAUTION Excessive EFW flow can result in loss of SCM due to RCS shrinkage.
NOTE
- Table 2 contains examples of less than adequate/excessive EFW flow.
- CETs are expected to rise until natural circ conditions are established. If EFW flow control is in HAND, additional flow may not be necessary to prevent rising CETs until natural circ is established.
A. ENSURE EFW CNTRL valves operate to establish and maintain applicable SG level band per Table 1.
- 1) IF EFW flow is less than adequate OR EFW flow is excessive, THEN CONTROL EFW to applicable SG in HAND as necessary to ensure the following:
- MAINTAIN continuous EFW flow until applicable level band is reached.
- MAINTAIN sufficient EFW flow to ensure SG level is either stable OR rising until applicable level band is reached.
Page 26 of 47
RT-5 PROPER EFW ACTUATION AND CONTROL VERIFICATION
- 5. IF all RCPs are off, THEN CHECK primary to secondary heat transfer in progress indicated by all of the following:
- T-cold tracking associated SG T-sat (Fig. 2)
- T-hot tracking CET temps
- T-hot/T-cold DT stable or dropping
Table 1 EFIC Automatic Level Control Setpoints Condition Level Band Automatic Fill Rate Any RCP running 20 to 40 No fill rate limit All RCPs off and Natural Circ selected 300 to 340 2 to 8/min All RCPs off and Reflux Boiling selected 370 to 410 2 to 8/min Table 2 Examples of Less Than Adequate EFW Flow Indications
- All RCPs off and EFIC level not trending toward applicable level band Examples of Excessive EFW Flow Indications
- SCM approaching minimum adequate due to EFW flow induced overcooling
Appendix D Scenario Outline RT-10 VERIFY PROPER ESAS ACTUATION
- 1. Verify BWST T3 Outlets open:
- CV-1407
- CV-1408 A. IF BWST T3 Outlet (CV-1407 or CV-1408) fails to open, THEN obtain Shift Manager/CRS permission to override ES.
B. Override AND stop associated HPI, LPI, and RB Spray pumps until failed valve is opened:
CV-1407 CV-1408 P34A P34B P36A/B P36C/B P35A P35B
- 2. Verify SERV WTR to DG1 and DG2 CLRs open:
- CV-3806
- CV-3807 Page 28 of 47
Appendix D Scenario Outline VERIFY PROPER ESAS ACTUATION
- 3. IF any RCP is running, THEN perform the following:
A. IF ES Channel 5 or 6 has actuated, THEN perform the following:
- 1) IF SCM is adequate, THEN trip all running RCPs due to loss of ICW:
- P32A
- P32C
- P32B
- P32D
- 2) IF SCM is NOT adequate, THEN check elapsed time since loss of adequate SCM AND perform the following:
a) IF £ 2 minutes have elapsed, THEN trip all RCPs:
- P32A
- P32C
- P32B
- P32D b) IF > 2 minutes have elapsed, THEN perform the following:
(1) Leave currently running RCPs on.
(2) IF RCS press > 150 psig, THEN notify CRS to GO TO 1202.002, LOSS OF SUBCOOLING MARGIN procedure.
(3) Restore RCP services per RT-8 while continuing.
B. IF neither ES channel 5 nor 6 has actuated, THEN dispatch an operator to perform Service Water And Auxiliary Cooling System (1104.029) Exhibit B, "Restoring SW to ICW Following ES Actuation" while continuing.
- 1) WHEN ICW Cooler SW Outlets and Bypasses are aligned per 1104.029, Exhibit B, THEN perform the following:
a) Obtain Shift Manager/CRS permission to override ES.
b) Override AND open one Service Water to ICW Coolers Supply (CV-3811 or CV-3820).
Page 29 of 47
Appendix D Scenario Outline VERIFY PROPER ESAS ACTUATION
- 4. Verify proper ESAS Channels tripped:
Condition Channels Actuated RCS press 1550 psig 1,2,3,4 RB press 18.7 psia 1,2,3,4,5,6 RB press 44.7 psia 7,8,9,10
- 5. Perform the following:
A. Verify each component properly actuated on C16 and C18, except those overridden in previous steps.
B. Verify proper ES system flow rates.
NOTE
- During ESAS actuation, low LPI flow is expected until RCS depressurizes below LPI pump shutoff head.
- During large break LOCAs, high LPI flow can be experienced. Flow is throttled to ensure ECCS flows are maintained within assumptions of calculations.
- 1) IF any of the following conditions exist:
- A HPI FLOW HI/LO (K11-A4)
- B HPI FLOW HI/LO (K11-A5)
- A LPI FLOW HI/LO (K11-B4)
- B LPI FLOW HI/LO (K11-B5)
- A RB SPRAY FLOW HI (K11-C4)
- B RB SPRAY FLOW HI (K11-C5)
THEN use Annunciator K11 Corrective Action (1203.012J) to clear unexpected alarms.
C. IF only one train of HPI is available AND RCS press is > 600 psig, THEN throttle HPI Block valve with the highest flow to within 20 gpm of the next highest flow.
Page 30 of 47
Appendix D Scenario Outline VERIFY PROPER ESAS ACTUATION
- 6. On C10, perform the following:
- Verify DGs operating within normal limits:
- 4100 to 4200 V - 4100 to 4200 V
- 59.5 to 60.5 Hz - 59.5 to 60.5 Hz
- £ 2750 KW - £ 2750 KW
- Verify the following breakers open:
- A3-A4 Crossties:
- A-310 - A-410
- B5-B6 Crossties:
- B-513 - B-613
- Unit AUX feeds to A1 and A2:
- A-112 - A-212
- Verify the following breakers closed:
- A3 Feeds to B5:
- A-301 - B-512
- A4 Feeds to B6:
- A-401 - B-612
- 7. On C09, perform the following:
A. Check AUX Cooling Water header depressurized.
B. IF proper EFW actuation and control has NOT already been verified, THEN verify proper EFW actuation and control (RT-5).
Page 31 of 47
Appendix D Scenario Outline VERIFY PROPER ESAS ACTUATION
- 8. On C19, perform the following:
A. Verify LPI (Decay Heat) Room Cooler running in each Decay Heat Room:
P34A Room P34B Room VUC1A or B VUC1C or D B. IF RB Spray has actuated, THEN verify SW to RB Spray P35A and P35B LO CLRs open:
- CV-3804
- CV-3805
- 9. IF all RCPs are off AND RCP Seal INJ Block (CV-1206) is closed, THEN place RCP Seal Bleedoff (Alternate Path to Quench Tank) controls in CLOSE:
- SV-1271
- SV-1273
- SV-1270
- SV-1272
A. Verify all four RB Cooling Fans running:
- VSF1A
- VSF1C
- VSF1B
- VSF1D B. Verify RB Cooling Coils Service Water Inlet/Outlet valves open:
- CV-3812/CV-3814
- CV-3813/CV-3815 C. Verify key-locked Chiller Bypass Dampers unlatched:
- SV-7410
- SV-7412
- SV-7411
- SV-7413 Page 32 of 47
Appendix D Scenario Outline VERIFY PROPER ESAS ACTUATION
- 12. Verify each component properly actuated on C26.
- 13. Verify the following sample valves closed on C26:
- Pressurizer Steam Space Sample Valve (CV-1814)
- Pressurizer Water Space Sample Valve (CV-1816)
- Hot Leg Sample (SV-1840)
- 14. Verify the following High Point Vents closed:
Reactor A Loop B Loop Pressurizer Vessel
- SV-1081
- SV-1091
- SV-1071
- SV-1082
- SV-1092
- SV-1072
- SV-1077
- SV-1083
- SV-1093
- SV-1073
- SV-1079
- SV-1084
- SV-1094
- SV-1074
- 15. IF AUX Lube Oil pump for running HPI pump fails to stop after 20 second time delay, THEN within one hour of ESAS actuation dispatch an operator to stop AUX Lube Oil pump locally at breaker while continuing:
P64A P64B P64C B5721 B5722/B6515 B6514
- 16. Place running Low Pressure Injection (Decay Heat) Pump (P34A/P34B) hand switches in NORMAL-AFTER-START to enable DECAY HEAT PUMP TRIP (K09-A7) alarm:
- P34A
- P34B
- 17. Monitor ENGINEERED SAFEGUARDS ACTUATION SYSTEM alarms on K11.
Page 33 of 47
Appendix D Scenario Outline VERIFY PROPER ESAS ACTUATION
- 18. IF any of the following components/systems are in service:
- Condensate Pumps
- Condenser Vacuum Pumps
- Waterbox Vacuum Pumps
- Seal Oil System
- Control Room Chillers THEN coordinate with CRS/SM to secure components and/or systems, as time permits.
- 19. Coordinate with CRS/SM to re-verify component actuation with another operator.
END Page 34 of 47
Appendix D Scenario Outline RT-12 EMERGENCY BORATION
- 1. IF Boric Acid pump (P39A or P39B) and Batch Controller are available, THEN perform the following:
A. IF any of the following conditions exist:
- Both OP and STBY HPI Pumps are off
- Letdown is isolated
- An unexpected delay occurs in implementation of Step 1 THEN GO TO step 2.
B. Set Batch Controller for maximum batch size as follows:
- 1) Depress lower DISPLAY.
- 2) Depress TOTAL.
- 3) Depress TOTAL RESET.
- 4) Depress BATCH SET.
- 5) Depress 9, six times.
- 6) Depress ENTER.
- 7) Depress lower DISPLAY.
C. Verify Condensate to Batch Controller (CV-1251) closed.
D. Open Batch Controller Outlet (CV-1250).
E. Verify both Makeup Filters in service:
- F3A
- F3B F. Record initial BAAT (T-6) level ____________ in.
G. Start available Boric Acid pump(s) (P39A or P39B or both).
(1. CONTINUED ON NEXT PAGE)
Page 35 of 47
Appendix D Scenario Outline RT-12 EMERGENCY BORATION
- 1. (Continued)
H. Start Batch Controller by depressing RUN key.
I. Adjust Batch Controller Flow CNTRL VLV (CV-1249) to 100% open as follows:
- 1) Depress VALVE SET.
- 2) Depress numbers: 1, 0, 0.
- 3) Depress ENTER.
- 4) Depress lower DISPLAY.
- 5) Depress RATE.
J. IF Batch Controller output rate < 5 gpm, THEN perform the following:
- 1) Stop running Boric Acid pump(s):
- P39A
- P39B
- 2) Close Batch Controller Outlet (CV-1250).
- 3) Stop Batch Controller by depressing STOP key.
- 4) GO TO step 2.
K. Adjust Pressurizer Level Control Setpoint to 220".
L. Verify BWST T3 Outlet to OP HPI pump (CV-1407 or CV-1408) open.
M. WHEN PZR level is ³ 100",
THEN establish maximum Letdown flow allowed by cooling capacity and component limitations.
(1. CONTINUED ON NEXT PAGE)
Page 36 of 47
Appendix D Scenario Outline RT-12 EMERGENCY BORATION
- 1. (Continued)
N. Perform the following as necessary to maintain Makeup Tank level 55 to 86":
- 1) Close Batch Controller Outlet (CV-1250).
- 2) Stop running Boric Acid pump(s):
- P39A
- P39B
- 3) Place 3-Way Valve (CV-1248) in BLEED.
- 4) WHEN Makeup Tank level is lowered to desired level, THEN perform the following:
a) Return 3-Way Valve (CV-1248) to LETDOWN.
b) Start available Boric Acid pump(s) (P39A or P39B or both).
c) Open Batch Controller Outlet (CV-1250).
O. As time permits, determine actual required boration as follows:
- 2) Calculate batch add required using Plant Computer OR Soluble Poison Concentration Control (1103.004), Attachment A.3, "Feed Volume For Batch Boration or Dilution". gal
- 3) Use 1103.004, Attachment D, "Volume of BAAT Vs. Depth of Liquid to determine desired final BAAT level.
(1. CONTINUED ON NEXT PAGE)
Page 37 of 47
Appendix D Scenario Outline RT-12 EMERGENCY BORATION
- 1. (Continued)
P. WHEN required amount of boric acid has been added per step 1.O.
OR as determined by Reactor Engineering, THEN perform the following:
- 1) Stop Boric Acid pump(s):
- P39A
- P39B
- 2) Close Batch Controller Outlet (CV-1250).
- 3) Verify Makeup Tank level 55 to 86".
- 4) Close BWST T3 Outlet to OP HPI pump (CV-1407 or CV-1408).
- 5) Adjust Letdown flow to desired rate.
Page 38 of 47
Appendix D Scenario Outline RT-12 EMERGENCY BORATION
- 2. IF HPI will be used for emergency boration, THEN perform the following:
B. Verify HPI Block valve (CV-1220 or CV-1285) associated with running HPI pump open.
C. IF Letdown is in service, THEN place 3-Way Valve (CV-1248) in BLEED.
D. WHEN PZR level is ³ 100",
THEN establish maximum Letdown flow allowed by cooling capacity and component limitations.
E. Maintain PZR level 200 to 220" as follows:
- 1) Verify both HPI Pump RECIRC Blocks open:
- CV-1300
- CV-1301
- 2) Throttle HPI Block valve (CV-1220 or CV-1285) as necessary.
F. As time permits, determine actual required boration as follows:
- 2) Calculate final BWST level for required boron addition using Plant Computer OR Soluble Poison Concentration Control (1103.004), Attachment A.6, "Continuous Feed and Bleed from BWST". ft G. WHEN required amount of boric acid has been added per step 2.F.
OR as determined by Reactor Engineering, THEN perform the following:
- 2) Adjust Letdown flow as directed by CRS.
END Page 39 of 47
Appendix D Scenario Outline RT-14 CONTROL RCS PRESS NOTE
- PTS limits apply if any of the following has occurred:
- RCS C/D rate > 100°F/hr with Tcold < 355°F
- RCS C/D rate > 50°F/hr with Tcold < 300°F
- Once invoked, PTS limits apply until an evaluation is performed to allow normal press control.
- PZR cooldown rate <100°F/hr.
- 2. IF RCS press is controlled AND will be reduced below 1650 psig, THEN BYPASS ESAS as RCS press drops below 1700 psig.
- 3. IF PZR steam space leak exists, THEN LIMIT RCS press as PZR goes solid by one or more of the following:
A. THROTTLE makeup flow.
B. IF SCM is adequate, THEN THROTTLE HPI flow by performing the following:
- 1) ENSURE both HPI Recirc Blocks open:
- CV-1300
- CV-1301
- 2) THROTTLE HPI.
C. RAISE Letdown flow.
- 1) IF Letdown is isolated AND SCM is adequate, THEN unless fuel damage or RCS to ICW leak is suspected, RESTORE Letdown per RT-13.
D. Using ERV:
- 1) ENSURE Electromatic Relief ERV Isolation (CV-1000) open.
- 2) CYCLE Electromatic Relief ERV (PSV-1000).
Page 40 of 47
Appendix D Scenario Outline RT-14 CONTROL RCS PRESS
- 4. IF RCS press is high, THEN LIMIT press using one or more of the following:
A. THROTTLE makeup flow.
B. THROTTLE HPI flow by performing the following:
- 1) CHECK adequate SCM AND any of the following conditions met:
- CET temps dropping
- 2) ENSURE both HPI Recirc Blocks open:
- CV-1300
- CV-1301
- 3) THROTTLE HPI.
C. IF RCP is running, THEN OPERATE Pressurizer Spray Control (CV-1008) in HAND.
D. PLACE Pressurizer Heaters in OFF.
E. RAISE Letdown flow.
- 1) IF Letdown is isolated AND SCM is adequate, THEN unless fuel damage or RCS to ICW leak is suspected, RESTORE Letdown per RT-13.
CAUTION Quench Tank pressure of 100 psig will blow the Quench Tank rupture disk.
F. Using ERV:
- 1) ENSURE Electromatic Relief ERV Isolation (CV-1000) open.
- 2) CYCLE Electromatic Relief ERV (PSV-1000).
G. CYCLE both valves for Pressurizer Vent to Quench Tank:
- SV-1077
- SV-1079 (4. CONTINUED ON NEXT PAGE)
Page 41 of 47
Appendix D Scenario Outline RT-14 CONTROL RCS PRESS
- 4. (Continued)
H. IF PZR AUX Spray is in service, THEN THROTTLE Pressurizer AUX Spray (CV-1416) open.
I. IF desired to secure HPI pump(s),
THEN:
P36A P36B P36C P64A P64B P64C
- 2) STOP desired HPI pump(s):
- P36A
- P36B
- P36C
- 3) CLOSE all associated HPI Block valves:
P36A/B P36B/C
- CV-1219
- CV-1227
- CV-1220
- CV-1228
- CV-1278
- CV-1284
- CV-1279
- CV-1285
- 5. IF RCS press is low, THEN RAISE press using one or more of the following:
A. RAISE makeup flow.
B. RAISE HPI flow or initiate HPI per RT-2.
C. IF RCP is running, THEN ENSURE Pressurizer Spray Control (CV-1008) closed.
D. IF PZR AUX Spray is in service, THEN THROTTLE Pressurizer AUX Spray (CV-1416) closed.
E. REDUCE Letdown flow.
F. PLACE Pressurizer Heaters in MANUAL.
(5. CONTINUED ON NEXT PAGE)
Page 42 of 47
Appendix D Scenario Outline RT-14 CONTROL RCS PRESS
- 5. (Continued)
CAUTION If HPI cooling is in progress, Electromatic Relief ERV Isolation (CV-1000) is left open until HPI cooling is no longer required.
G. ENSURE Electromatic Relief ERV (PSV-1000) or Electromatic Relief ERV Isolation (CV-1000) closed.
H. ENSURE both Pressurizer Vent to Quench Tank valves closed:
- SV-1077
- SV-1079 CAUTION With RCS solid, 1°F temp change can cause 100 psig press change.
- LOWER RCS temp to lower RCS press NOTE Adjusting Pressurizer Level Control setpoint and HPI as necessary to maintain normal makeup flow on-scale will allow CV-1235 to automatically compensate for small changes in RCS leak rate and cooldown rate.
- 7. IF normal makeup is in service AND HPI is in service, THEN ADJUST Pressurizer Level Control setpoint and HPI as necessary to maintain normal makeup flow on-scale.
END Page 43 of 47
Appendix D Scenario Outline RT-18 CHECK SG TUBE INTEGRITY
- 1. Check the following indications:
- None of the following radiation monitor indications rising OR in alarm:
- Main Condenser process monitor (RI-3632)
- Either OTSG N-16 Gross Detector:
¨ RI-2691
¨ RI-2692
- Either Steam Line High Range Radiation Monitor:
¨ RI-2681
¨ RI-2682
- No report from Nuclear Chemistry that SG tube leak exists.
- No rise in unidentified RCS leakage accompanied by:
- Higher than expected SG level
- Lower than expected FW flow rate END Page 44 of 47
Appendix D Scenario Outline RT-19 CHECK PROPER ELECTRICAL RESPONSE
- 1. CHECK 125 V DC Bus D01 energized:
- Turbine Trip Solenoid Power Available light lit
- Breaker position indications for A3 and odd-train 480V buses on C10 lit A. IF 125 V DC Bus D01 is de-energized, THEN INFORM CRS to perform Loss of D01 section of 1203.036, Loss of 125 V DC in conjunction with Reactor Trip procedure, while continuing.
- 2. CHECK Main Generator and Exciter Field breakers open.
- 5114
- 5118
- 1) IF 125 V DC Bus D01 is energized, THEN:
a) INFORM the CRS.
b) Manually TRIP Main Generator breakers:
- 5114
- 5118 c) Manually TRIP Exciter Field breaker.
- 2) IF 125 V DC Bus D01 is de-energized, THEN MAINTAIN Main Generator and Exciter Field breakers closed.
Page 45 of 47
Appendix D Scenario Outline RT-19 CHECK PROPER ELECTRICAL RESPONSE
- 3. CHECK DGs off:
- DG1
- DG2 A. IF DG is running, THEN :
- ENSURE associated SERV WTR to DG CLRs open:
DG1 DG2 CV-3806 CV-3807
- 4100 to 4200 V
- 59.5 to 60.5 Hz
- Less than 2750 KW
- 4. CHECK vital 4160 V buses energized:
- A3
- A4 A. IF either 4160 V bus A3 or A4 is de-energized, THEN INFORM CRS.
- 5. CHECK non-vital 4160 V buses energized:
- A1
- A2 A. IF either 4160 V bus A1 or A2 is de-energized, THEN INFORM CRS.
Page 46 of 47
Appendix D Scenario Outline RT-19 CHECK PROPER ELECTRICAL RESPONSE
- 6. MONITOR Electrical system alarms K01 and K02.
A. IF abnormal alarms are indicated, THEN INFORM CRS.
END Page 47 of 47
Appendix D Scenario Outline Facility: ANO-1 Scenario No.: 2 R0 Op-Test No.: 2020-1 Examiners: ____________________________Operators: _____________________________
Initial Conditions:
- IC202 - Beginning of Life - Run Schedule File Scenario 2 R0
- 60% Power. - B5106 and B5110 Open
- Mablevale Line isolated for repairs - Boron 1290 ppm
- Maintain <490 MWe (Net)
Turnover:
- Perform a 2 minute delithiation -
- Reactivity Brief completed
- EFIC 1/2 Trip, I&C performing monthly surveillance Event Event Event Malf. No.
No. Type* Description N-(BOP) 1 N/A Align for 2 minute delithiation N-(SRO)
C-(SRO) 2 K01-A5 Inverter Y11 failure TS C-(ATC)
C-(BOP) 3 ES254 Inadvertent EFW actuation C-(SRO)
B2564 C-(BOP) P-33C ICW Pump trips with an auto start failure on P-33B 4
SW071 C-(SRO) ICW Pump.
ACA I-(ATC)
I-(BOP) 5 TR580 Controlling Header Pressure fails to 800 psig I-(SRO)
AOP 6 MS131 M-(ALL) A Main Steam Line break inside containment I-(ATC)
ES263 I-(BOP) 7 ESAS Channels 5 & 6 fail to actuate automatically ES264 I-(SRO)
CT CV2670 C-(ATC) EFIC Vector Isolation failure for one EFW flow path to 8
HIC2646 CT failed generator
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 43
Appendix D Scenario Outline Target Quantitative Attributes (Section D.5.d) Actual Attributes Malfunctions after EOP entry (1-2) 2 Abnormal Events (2-4) 4 Major Transients (1-2) 1 EOPs entered requiring substantive actions (1-2) 1 EOP contingencies requiring substantive actions ( 1per 1 scenario set)
Critical Tasks (2) 2 SCENARIO 2 OBJECTIVES
- 1) Evaluate individual ability to perform RCS Delithiation.
- 2) Evaluate individual ability to recognize and respond to 120 VAC Inverter Annunciators on K-1.
- 3) Evaluate individual ability to recognize and respond to inadvertent EFIC actuation
- 4) Evaluate individual ability to recognize when conditions require the entry into Technical Specifications conditions.
- 5) Evaluate individual ability to recognize and respond to ICW System Annunciators on K-12.
- 6) Evaluate individual ability to recognize and recover letdown flow following high letdown temperature.
- 7) Evaluate individual ability to recognize and respond to ICS input failures.
- 8) Evaluate individual ability to recognize and respond to Overcooling.
- 9) Evaluate individual ability to recognize and respond to ESAS Actuation Annunciators on K-11.
- 10) Evaluate individual ability to recognize the need to perform manual intervention to control EFW.
Page 2 of 43
Appendix D Scenario Outline SCENARIO 2 NARRATIVE Event One: Normal operation align for two minute delithiation The crew will assume plant responsibility at ~60% power. The SRO will direct commencing Chemistry requested two minute delithiation in accordance with OP-1104.002 Section10.0.
(ATC-N) (SRO-N)
Event Two: Inverter Y11 failure Following the delithiation, K01-A5, RS1 Inverter Trouble annunciator will alert the crew of an inverter failure. The BOP will dispatch the NLO to investigate. Report from the field will be that the Y11 Inverter has failed and automatically selected the Alternate Power Supply. The SRO will declare Y11 Inoperable and enter T.S. 3.8.7 Condition A and direct the NLO to make preparations for placing Y13 into service.
(SRO-C) ACA, TS Event Three: Inadvertent EFW actuation Once the T.S. entry has been announced to the crew, I&C will cause an inadvertent EFIC actuation during their monthly surveillance. The crew should respond to K12-A5, EFW Actuation Signal. The ACA will direct stopping the EFW pumps and then send the RO to 1105.005, Emergency Feedwater Initiation and Control for resetting EFIC. During the restoration, EFW will be inoperable and the SRO will enter T.S. 3.7.5 Condition E.
(ATC-C) (BOP-C) (SRO-C) ACA, TS Event Four: P-33C ICW Pump trips with a failure of P-33B to automatically start Once EFIC is reset and TS entry announced, the running Nuclear ICW Pump (P-33C) will trip with a failure of the standby pump P-33B to automatically start. This will require the ATC to diagnose and manually start P-33B ICW pump. It will also result in a high temperature automatic isolation of the letdown flowpath. The BOP will utilize OP-1104.002 Section 14.0, Recovery of Letdown Following High Letdown Temperature.
(ATC-C) (BOP-C) (SRO-C) ACA Event Five: Controlling Header Pressure fails to 800 psig Once Letdown has been restored, the controlling header pressure will fail to 800 psig. This will cause ICS to pull rods and close governor valves to recover header pressure . The ATC will take SG/RX to hand and keep power less than 100% while the BOP places the Turbine in Manual and the TBVs in Hand. The ATC and BOP will work together to maintain <490 MWe while recovering header pressure. Once header pressure is recovered and a good signal selected, the Turbine, TBVs, and SG/RX can be returned to automatic control.
(ATC-I) (BOP-I) (SRO-I) AOP Event Six: A Main Steam Line break inside containment The major event will be an overcooling due to a main steam line break inside containment that will result in RB pressure rising to the ESAS actuation setpoint of Channels 1-6. After the immediate actions of Reactor Trip are completed, the SRO should identify the need to transition to the Overcooling EOP.
(ATC-C) (BOP-C) (SRO-C) EOP Page 3 of 43
Appendix D Scenario Outline Event Seven: ESAS Channels 5 & 6 fail to actuate automatically A main steam line break inside containment will result in RB pressure rising to the ESAS actuation setpoint of Channels 1-6. However, Channels 5 & 6 are failed and will not automatically actuate. The ATC will identify the failure and manually actuate Channels 5 & 6. If the ATC does not recognize the failure, then the BOP will identify the failure during the performance of RT-10 which verifies actuation of ESAS. The critical task of actuating Channels 5 & 6 must be performed prior to the completion of RT-10.
(ATC-I) (BOP-I) (SRO-I) EOP, CT CT Justification: CT-19 Safety significance - Isolate possible RCS leak paths and assure containment integrity.
Initiating Cue - RB Pressure HI (2.175 psig) alarm on K11 and Reactor Building pressure >4 psig (ESAS setpoint).
Measurable Performance Standard - Manually actuate Channels 5 & 6 prior to reporting the completion of RT-10.
Performance Feedback - Annunciators for RB Isolation Channel 5 & 6 on K11 and components reposition to ESAS position for Channels 5 & 6.
Event Eight: EFIC Vector Isolation failure for one EFW flow path to failed generator A malfunction of the Vector Isolation signal to the faulted generator will result in continuing to feed the bad steam generator. The ATC should identify this failure and manually isolate the flowpath by closing CV-2670 or CV-2646 or both in accordance with RT-6. This will stop the feed source of overcooling. Once the bad steam generator depressurizes the overcooling will be terminated and the crew will stabilize RCS temperature.
The critical task of manually controlling EFW must be performed prior to the completion of RT-6.
(ATC-C) (SRO-C) EOP(RT), CT CT Justification: CT-11 and CT-16 Safety significance - Excessive primary to secondary heat transfer due to overfeeding faulted steam generator.
Initiating Cue - RCS overcooling in progress, skewed EFW flow to faulted SG preventing depressurization and causing continued overcooling conditions.
Measurable Performance Standard - Manually control EFW flow to A Steam Generator prior to reporting the completion of RT-6.
Performance Feedback - EFW flowrate near zero, faulted steam generator pressure trending towards zero, RCS temperature stable or rising.
The scenario can be terminated at the discretion of the lead examiner.
Page 4 of 43
Appendix D Scenario Outline Simulator Instructions for Scenario 2 Reset simulator to MOL ~100% power IC steady state Ensure malfunctions agree with scenario guide (either schedule file or IC)
Event Time Event Description No. Type N-(BOP) 1 T=0 Align for 2 minute delithiation N-(SRO)
C-(SRO) 2 T=5 Inverter Y11 failure TS C-(ATC) 3 T=15 C-(SRO) Inadvertent EFW actuation AOP, TS C-(ATC)
C-(BOP) P-33C ICW Pump trips with an auto start failure on P-33B ICW 4 T=35 C-(SRO) Pump.
ACA I-(ATC)
I-(BOP) 5 T=50 Controlling Header Pressure fails to 800 psig I-(SRO)
AOP 6 T=60 M-(ALL) A Main Steam Line break inside containment I-(ATC)
I-(BOP) 7 T=60 ESAS Channels 5 & 6 fail to actuate automatically I-(SRO)
CT C-(ATC) EFIC Vector Isolation failure for one EFW flow path to failed 8 T=60 CT generator Page 5 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __1__
Event
Description:
__Align for 2 minute delithiation (OP-1104.002 Step 10.0)_______________
Time Position Applicants Actions or Behavior EXAMINER NOTE: Chemistry will request an idle DI be placed in service for delithiating the RCS. Boron concentrations are maintained on the status board.
T=0 BOP 10.1 WHEN two demineralizers are in service, THEN ENSURE letdown flow is greater than 50 gpm EXAMINER NOTE: The applicants were told that a reactivity brief had already been conducted and they were given the opportunity to discuss concerns prior to taking the watch.
BOP 10.3 IF performing RCS delithiation, THEN:
BOP 10.3.1 OBTAIN total desired delithiation time from Chemistry.
10.3.2 PREFERRED METHOD: IF the difference between RCS boron and the delithiating DI is less than 50 ppm OR delithiating DI is equal to RCS boron BOP concentration if near EOL (less than 30 EFPD from projected end of cycle),
THEN:
A. OPEN inlet to delithiating DI:
- T-36A Purif Demineralizer Inlet (CV-1244)
B. CLOSE inlet to previously in-service DI:
- T-36B Purif Demineralizer Inlet (CV-1245)
C. OBSERVE that letdown flow is equal to previous value.
D. WHEN recommended delithiation time is complete OR letdown flow changes unexpectedly, THEN:
- 1. OPEN inlet to previously in-service DI:
- T-36B Purif Demineralizer Inlet (CV-1245)
- 2. CLOSE inlet to delithiating DI:
- T-36A Purif Demineralizer Inlet (CV-1244)
E. UPDATE Status Board with RCS boron concentration.
N/A F. IF DI boron concentration is unknown, THEN N/A G. RECORD completion of delithiation in the Station Log including length of time DI was in service and letdown flow.
END OF EVENT Page 6 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __2__
Event
Description:
__Inverter Y11 Failure (Alternate Source to Load) ________________
Time Position Applicants Actions or Behavior T=5 ATC Acknowledge and report RS1 INVERTER TROUBLE annunciator (K01-A5)
BOP 1. CHECK SPDS ACDC display to determine RS1 bus voltage and supplying Inverter (Y11 or Y15).
BOP 2. DISPATCH an operator to Local Annunciator for Inverter Y11 (K1620) or Y15 (K1654).
BOP 3. REFER TO Attachment E, RS1 Inverter Trouble Alarm Response for further instructions.
SRO 4. REFER TO TS 3.8.7, TS 3.8.8, TS 3.8.9 and TS 3.8.10 for operability TS requirements.
BOOTH ROLE PLAY: When contacted as the NLO to check Inverter Trouble, wait ~2 minutes and report that the cause of the alarm is Inverter Failure and that the Alternate Source is supplying the load.
EXAMINER NOTE: The following is from Attachment E for Inverter Failure.
SRO 1. IF a condition other than normal transfer results in a 120 VAC vital bus being TS powered from inverter on alternate source, THEN ENTER TS 3.8.7 Condition A.
NLO 2. IF Alternate Source Supplying Load light is on, THEN TRANSFER Manual Selector Switch to ALT SOURCE TO LOAD position.
NLO 3. INVESTIGATE cause of alarm.
NLO 4. RESTORE Inverter (Y11 or Y15) to normal operation per 1107.003, Inverter and 120V Vital AC Distribution END OF EVENT NOTES: .
Page 7 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __3__
Event
Description:
___ Inadvertent EFW actuation______________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: K12-A5, EFW Actuation Signal will address securing EFW Pumps and then 1105.005 will reset EFIC.
EXAMINER NOTE: This first section is for K12-A5, EFW Actuation Signal EXAMINER CUE: Promptly inform the SRO that a technicians error caused the EFW actuation, all bistables have been checked and all are clear - none are tripped.
T=15 ATC Acknowledge and report EFW Actuation Signal (K12-A5)
N/A 1. IF EFW is needed for SG feed, THEN PERFORM RT-5 ATC 2. IF EFW is unnecessary OR a component malfunction is evident, THEN:
A. IF directed by CRS/SM to stop EFW Pump (P-7B), THEN PLACE ATC EFW Pump P7B handswitch in PULL-TO-LOCK.
B. IF directed by CRS/SM to stop EFW Pump (P-7A), THEN:
- CV-2613
- CV-2663
- 2) CLOSE the following:
- CV-2613
- CV-2663 N/A C. TAKE manual control of EFW using 1106.006, Emergency Feedwater Pump Operation, Manual Intervention to Control EFW SRO section.
D. REFER TO TS 3.7.5.
TS N/A 3. IF Steam Generator pressure is less than or equal to 900 psig, N/A
- 4. RESET EFIC/EFW System per 1105.005, Emergency Feedwater BOP Initiation and Control, Returning EFIC System and EFW components to Normal Automatic Condition section.
EXAMINER NOTE: This section is for resetting EFIC per 1105.005 BOP 13.1 ENSURE alternate feedwater source is in service or RCS is on Decay Heat Removal BOP 13.2 Using EFIC cabinet bistables, alarm panels and control room indications, ENSURE that parameters responsible for EFW initiation are in normal control bands.
Continued Page 8 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __3__
Event
Description:
___ Inadvertent EFW actuation______________________________________
_Continued________________________________________________________________________
Time Position Applicants Actions or Behavior SRO 13.3 IF Unit is above Mode 5 AND ANY SG is relied upon for heat removal, THEN ENTER TS 3.7.5 Condition E or Condition F.
ATC 13.4 IF EFW Train B is actuated, THEN ENSURE EFW Pump P-7B handswitch (HS-2805) in PULL-TO-LOCK.
ATC 13.5 ENSURE the following conditions are met:
- EFW Pump Turbine K-3 Steam Admission Valves (CV-2613/2615) in MAN
- EFW Pump Turbine K-3 Steam Admission Valve (CV-2613) closed
- EFW Pump Turbine K-3 Steam Admission Bypass (CV-2615) closed
- EFW Pump Turbine K-3 Steam Admission Valves (CV-2663/2665) in MAN
- EFW Pump Turbine K-3 Steam Admission Valve (CV-2663) in closed
- EFW Pump Turbine K-3 Steam Admission Bypass (CV-2665) in closed N/A 13.6 IF initiating signal came from external trip N/A N/A 13.7 IF RCPs are unavailable, N/A BOP 13.8 IF Bistable Tripped memory lamp(s) are flashing on EFIC cabinet alarm panel(s), THEN DEPRESS Reset pushbutton on associated bistable module:
- EFIC-C cabinet (C37-3)
- EFIC-A cabinet (C37-1)
- EFIC-D cabinet (C37-4)
- EFIC-B cabinet (C37-2)
BOP 13.9 OBSERVE Bistable Tripped memory lamp goes from flashing (bright to dim) to dim upon reset on each EFIC cabinet alarm panel:
- EFIC-C cabinet (C37-3)
- EFIC-A cabinet (C37-1)
- EFIC-D cabinet (C37-4)
- EFIC-B cabinet (C37-2)
Continued Page 9 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __3__
Event
Description:
___ Inadvertent EFW actuation______________________________________
_Continued________________________________________________________________________
Time Position Applicants Actions or Behavior BOP 13.10 RESET EFW trip modules by EITHER of the following:
- DEPRESS EFW Reset pushbutton for actuated bus on Remote Switch Matrix:
- Train A
- Train B
- EFIC-A cabinet (C37-1)
- EFIC-B cabinet (C37-2)
BOP 13.11 CHECK the following:
- EFW Bus actuated lamps on remote switch Train A matrix are off.
- EFW Bus actuated lamps on remote switch Train B matrix are off.
ATC 13.12 REMOVE HS 2805 from PULL TO LOCK.
ATC 13.13 For EFW Pump Turbine K 3 Steam Admission Valve (CV 2613) steam path:
13.13.1 ENSURE CV 2613 and CV 2615 are closed.
13.13.2 ENSURE CV 2613 is in AUTO.
Continued NOTES: .
Page 10 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __3__
Event
Description:
___ Inadvertent EFW actuation______________________________________
_Continued________________________________________________________________________
Time Position Applicants Actions or Behavior NLO 13.14 For EFW Pump Turbine K 3 Steam Admission Valve (CV 2663) steam path:
13.14.1 OPEN the following breakers:
- EFW Pump Turbine K3 Steam Admission Bypass Valve CV 2665 breaker (D1523)
- EFW Pump Turbine K3 Steam Admission Valve CV 2663 breaker (D1512) 13.14.2 In LSPR, MANUALLY CLOSE the following:
- EFW Pump Turbine K3 Steam Admission Bypass Valve (CV 2665)
- EFW Pump Turbine K3 Steam Admission Valve (CV 2663) 13.14.3 CLOSE the following breakers:
- D1523
- D1512 SRO 13.15 IF TS 3.7.5 Condition D/E time clocks were entered for this section, THEN EXIT TS 3.7.5 Condition D/E.
SRO 13.16 NOTIFY Chemistry of steam release and request initiation of Form 1604.015B, P 7A and 2P 7A Sample Report.
End of Event NOTES: .
Page 11 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __4__
Event
Description:
__P-33C ICW Pump trips with an auto start failure of P-33B ICW Pump ___
Time Position Applicants Actions or Behavior EXAMINER NOTE: Several annunciators will come in during this event. K12-B4, ICW Flow Lo and K10-A8, Letdown Temp Hi will need to be addressed to correct the conditions.
EXAMINER NOTE: This first section is for ICW Flow Lo annunciator (K12-B4)
T=35 ATC Acknowledge and report ICW Flow Lo annunciator (K12-B4) and Letdown Temp Hi annunciator (K10-A8)
N/A 1. IF only ONE ICW pump is available, THEN PERFORM 1203.052, Loss of Intermediate Cooling Water in conjunction with these actions.
N/A 2. IF Non-Nuclear loop flow is low, THEN:
- 3. IF Nuclear loop flow is low, THEN:
ATC A. ENSURE ICW Pump (P-33C or P-33B) is operating.
B. IF ICW valves have been operated, THEN ENSURE proper valve N/A alignment.
C. IF ES signal NOT present, THEN ENSURE the following valves open on BOP C16 and C18:
ATC D. MONITOR Nuclear loop ICW equipment (Letdown, RCP Seals, etc.) for overheating.
NLO E. Locally, CHECK ICW Surge Tank (T-37B) level is 0.5 to 2.7 psid.
BOOTH ROLE PLAY: When contacted as the NLO to check ICW Surge Tank levels, wait
~2 minutes and report that the surge tanks are indicating 1.3 and 1.5.
EXAMINER NOTE: This section is for Letdown Temp Hi annunciator (K10-A8). The first three steps require no action.
- 4. IF temperature rises to greater than or equal to 135°F, THEN ENSURE ONE of the following is closed:
- Letdown Cooler Outlet (CV-1221)
- Letdown Cooler Outlets (CV-1214 and CV-1216)
BOP 5. DISPATCH an operator to Purification DI Bypass (MU-9).
- 6. RESTORE letdown using 1104.002, Makeup & Purification System BOP Operation, Recovery of Letdown Following High Letdown Temperature Trip section.
Continued Page 12 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __4__
Event
Description:
__P-33C ICW Pump trips with an auto start failure of P-33B ICW Pump ___
_Continued________________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: This will be from 1104.002, Makeup & Purification System Operation, Recovery of Letdown Following High Letdown Temperature Trip section.
14.1 ENSURE the following valves are closed:
- Letdown Block Orifice Bypass (CV-1223)
- T-36A Purif Demineralizer Inlet (CV-1244)
- T-36B Purif Demineralizer Inlet (CV-1245) 14.2 ENSURE the following valves are open:
- LD Cooler E-29A Outlet MOV (CV-1214)
- LD Cooler E-29B Outlet MOV (CV-1216)
NLO 14.3 OPEN T-36A & B Bypass (MU-9).
N/A 14.4 IF BOTH Purification Demineralizer (T-36A and T-36B) will be OOS CREW 14.5 DETERMINE cause of high temperature.
EXAMINER NOTE: Letdown Coolers Outlet (CV-1221) can re-close until warm water trapped in letdown line is flushed past TE-1221. To restore letdown, it could be necessary to cycle CV-1221.
BOP 14.6 WHEN cause is corrected, THEN OPEN Letdown Coolers Outlet (CV-1221).
ATC 14.7 CHECK letdown temperature is less than 130°F at TIS-1221 (local) or on TE-1237 (C04, SPDS or PMS).
14.8 IF CV-1221 closes automatically on high temperature, THEN CYCLE BOP CV-1221 to lower temperature to less than 130°F on TE-1237 or TIS-1221.
Continued NOTES: .
Page 13 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __4__
Event
Description:
__P-33C ICW Pump trips with an auto start failure of P-33B ICW Pump ___
_Continued________________________________________________________________________
Time Position Applicants Actions or Behavior 14.9 IF temperature is less than 130°F on TE-1237 AND CV-1221 BOP closes automatically on high temperature, THEN ENSURE temperature is less than 130°F at TIS-1221.
BOP 14.10 ENSURE CV-1221 is open.
14.11 OPEN At least ONE of the following valves:
- T-36A Purif Demineralizer Inlet (CV-1244)
- T-36B Purif Demineralizer Inlet (CV-1245)
NLO 14.12 CLOSE MU-9.
ATC 14.13 RE-ESTABLISH desired letdown flow.
END OF EVENT NOTES: .
Page 14 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __5__
Event
Description:
__ Controlling Header Pressure fails to 800 psig ________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: The crew should initially diagnose this as an Undesired Power Change and enter 1203.001 ICS Abnormal Operations. Then further diagnosis will pinpoint the problem to the header pressure bias failure.
T=50 ATC Acknowledge and report SASS Mismatch alarm (K07B4)
ATC 1. PLACE SG/RX Master in HAND.
- 2. CHECK steam pressure control is NOT impacted as indicated by:
- Controlling SG Pressure(s) controlled between 870 and 920 psig
- 3. IF steam pressure control is impacted, THEN:
BOP A. ENSURE Turbine is in TURB MAN control.
B. PLACE BOTH TURB BYP Valves H/A stations in HAND.
- 4. ADJUST components in HAND/TURB MAN as necessary to achieve the ATC/ following:
- Reactor Power less than 100%
- SG Pressures stable N/A 5. IF ICS control parameters are NOT stabilized, EXAMINER NOTE: Since power started at 60%, it should be maintained around 60% rather than just <100% as directed in the next step.
- 6. ADJUST components in HAND/TURB MAN as necessary to achieve the following prescribed bands:
ATC/
- Controlling SG Pressure(s) 880 to 910 psig (with TURB BYP Valves closed if Main Generator is on line)
ATC/ 7. IF cause is pinpointed or corrected, THEN RETURN functional ICS H/A BOP Stations to AUTO as directed by CRS using 1105.004, Integrated Control System or 1203.045, Rapid Plant Shutdown.
EXAMINER NOTE: The crew will utilize K07-B4 ACA to select a good signal for header pressure.
BOP 1. OBSERVE SASS lights on C03, C04, and C13 to identify affected instrument.
ATC 2. DETERMINE if a transfer from the preferred source has occurred.
SRO 3. IF a controlling ICS input is impacted, THEN PERFORM 1203.001, ICS Abnormal Operation in conjunction with this ACA.
BOP 4. OBSERVE the non-selected input on the plant computer for mismatch indication.
Continued Page 15 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __5__
Event
Description:
__ Controlling Header Pressure fails to 800 psig ________________
_Continued________________________________________________________________________
Time Position Applicants Actions or Behavior N/A 5. IF SASS MISMATCH is due to controlling RCS Pressure Selector, N/A N/A 6. IF a transfer has occurred, N/A
- 7. IF transfer has NOT occurred AND desired by CRS/SM, THEN to select X or Y signal:
BOP A. CHECK signal to be selected is a usable signal.
B. IF ICS controlling input is impacted, THEN ENSURE affected stations SRO are in manual (Ref. 1203.001, ICS Abnormal Operation).
C. IF FW Temperature or FW Flow input is impacted, THEN ENSURE N/A selection for BOTH FW Temperature and FW Flow is maintained on same NNI-X or NNI-Y.
ATC D. MAKE selection.
ATC E. CHECK that new signal source is providing proper control signal.
SRO 8. For failed input signals or persistent mismatch indications, INITIATE corrective action for repair.
- 9. For persistent mismatch alarms:
NLO A. PLACE Mismatch Alarm Bypass switch in C47-2 for the failed component in ON.
SRO B. ENSURE a Condition Report initiated for repair.
C. INSTALL ALARM BYPASSED tag adjacent to the associated ATC instrument SASS selector switch.
N/A 10. WHEN failed transmitters have been repaired, N/A Continued NOTES: .
Page 16 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __5__
Event
Description:
__ Controlling Header Pressure fails to 800 psig ________________
_Continued________________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: The crew will utilize 1105.004 to return the Turbine to automatic control.
Steps 9.1 and 9.2 are N/A.
BOP 9.3 IF header pressure is NOT at setpoint, THEN slowly ADJUST turbine load to stabilize header pressure within 5 psi of setpoint.
9.4 WHEN turbine header pressure is within 5 psi of setpoint AND header pressure rate of change is less than 10 psi/minute, THEN TRANSFER BOP turbine controls as follows:
9.4.1 On C33, DEPRESS INTEG CONTROL.
9.4.2 IF UNIT MASTER IN TRACK (K07-A1) was in alarm solely due to turbine mode, THEN CHECK UNIT MASTER IN TRACK (K07-A1) clear.
BOP 9.5 CHECK turbine control is steady.
EXAMINER NOTE: The crew will utilize 1105.004 to return the SG/RX to automatic control.
The procedure calls out Critical Steps which for ANO is a step that if not done correctly can have irreversible consequences.
14.1 CHECK ONE of the following:
- SG/RX POS and MEAS VAR agree within 3%.
14.2 IF signals do not agree within specified tolerance, THEN ATC MAINTAIN SG/RX Master in HAND until problem is resolved.
14.3 IF unexpected feedwater flow change occurs, THEN without delay:
14.3.1 PLACE Feedwater Loop Demands in HAND:
- Loop A
- Loop B 14.3.2 PLACE Diamond in MANUAL.
14.3.3 STABILIZE reactor power and T-ave.
14.3.4 REFER TO 1203.001 ICS Abnormal Operations.
ATC 14.4 PLACE SG/RX Demand H/A station in AUTO.
END OF EVENT NOTES: .
Page 17 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __6, 7, & 8__
Event
Description:
__Main Steam Line Break inside containment. ESAS Channels 5 & 6 fail _
_to actuate automatically. EFIC Vector Isolation failure for one EFW Flow Path to faulted generator._
Time Position Applicants Actions or Behavior EXAMINER NOTE: Shortly after the reactor trip A Steam Generator pressure will be <900 psig which will satisfy entry conditions for Overcooling.
T=60 ATC Diagnose and report an undesired power change and recommend tripping the reactor.
ATC 1. Depress Reactor Trip PB.
A. Verify all rods inserted AND reactor power dropping.
BOP 2. Depress Turbine trip PB.
A. Check Turbine throttle and governor valves closed.
ATC 3. Check adequate SCM.
- 4. Perform the following:
- Advise Shift Manager to implement Emergency Action Level SRO Classification (1903.010).
- Direct Control Board Operators to monitor floating steps CREW Recognize A Steam Generator pressure dropping and Reactor Building pressure rising and the need to transition to OVERCOOLING ATC 1. CHECK adequate SCM.
SRO 2. DIRECT Control Board Operators to monitor floating steps.
BOP 3. OPEN BWST T3 Outlet to OP HPI pump (CV-1407 or CV-1408).
ATC 4. CHECK Pressurizer Level Control valve (CV-1235) maintains PZR level greater than or equal to 55.
ATC 5. CHECK RCS press remains greater than or equal to 1700 psig.
ATC 6. CHECK RCS T-cold remains greater than 465°F.
BOP 6. IF four RCPs are running, THEN TRIP one RCP (P32A or P32B).
ATC 7. CONTROL RCS press within limits of Figure 3 (RT-14).
Continued Page 18 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __6, 7, & 8__
Event
Description:
__Main Steam Line Break inside containment. ESAS Channels 5 & 6 fail _
_to actuate automatically. EFIC Vector Isolation failure for one EFW Flow Path to faulted generator._
_Continued________________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: RT-5, RT-6, RT-9, and RT-10 are located at the back of this exam guide.
If not already identified then the CRITICAL TASK of actuating Channel 5 & 6 will be completed during the performance of RT-10 below ATC 8. CHECK ESAS ACTUATION alarms clear on K11.
- 8. PERFORM the following:
A. Throttling HPI:
- CV-1300 AND CV-1301
- 2) IF ES HPI pump is only HPI pump in service OR HPI pump recirc N/A flow path to Makeup Tank is unavailable, THEN MAINTAIN HPI pump flow greater than or equal to 90 gpm
CV-1219 CV-1227 BOP CV-1220 CV-1228 CV-1278 CV-1284 CV-1279 CV-1285 CT B. PERFORM proper ESAS actuation verification (RT-10).
C. IF RB Spray has actuated, THEN as time permits, SECURE RB BOP Spray using 1104.005, Reactor Building Spray System Operation, Securing Reactor Building Spray System after ESAS Actuation section.
ATC 9. CHECK MSSV OPEN (K07-C5) alarm clear.
ATC 10. CHECK RB press less than 17 psia and stable.
EXAMINER NOTE: If not already identified then the CRITICAL TASK of isolating the EFW to the bad SG will occur below.
- 10. PERFORM the following for bad SG:
A. ENSURE bad SG EFW ISOL valves in MANUAL and closed (modulating ATC valves):
SG A SG B CT CV 2627 CV 2620 CV 2670 CV 2626 ATC B. ACTUATE EFW.
ATC C. ACTUATE MSLI for bad SG and PERFORM proper actuation and BOP control verification (RT-6).
ATC D. MAXIMIZE RB cooling (RT-9).
SRO E. IF EFW is in service, THEN TRIP both MFW pumps:
F. IF overcooling is terminated, THEN GO TO step 26.
Continued Page 19 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __6, 7, & 8__
Event
Description:
__Main Steam Line Break inside containment. ESAS Channels 5 & 6 fail _
_to actuate automatically. EFIC Vector Isolation failure for one EFW Flow Path to faulted generator._
_Continued________________________________________________________________________
Time Position Applicants Actions or Behavior
- 11. CHECK the following:
- MSLI alarms clear on K12:
MSLI OTSG A (K12 A7)
MSLI OTSG B (K12 A8)
- 11. PERFORM the following:
A. PERFORM proper MSLI actuation and control verification (RT 6).
ATC B. IF EFW is in service, THEN TRIP BOTH MFW pumps:
- Main Feed Pump A
- Main Feed Pump B SRO C. IF overcooling is terminated, THEN GO TO step 26.
D. IF overcooling remains in progress, THEN GO TO step 39.
- 12. PERFORM the following:
A. PERFORM proper EFW actuation and control verification (RT 5).
B. TRIP BOTH MFW pumps:
- Main Feed Pump A
- Main Feed Pump B C. IF SG press is less than 650 psig, THEN TRIP all Condensate pumps:
- P2A
- P2B
- P2C SRO D. IF overcooling is terminated, THEN GO TO step 26.
E. IF overcooling remains in progress, THEN GO TO step 17.
EXAMINER NOTE: SRO should transition to Step 26
- 26. WHEN overcooling is terminated, THEN:
A. CHECK BOTH of the following for EACH SG:
- MSIV is open
- TURB BYP Valves are available A. PERFORM the following:
- 1) OPERATE ATM Dump Control System to prevent RCS heatup:
ATC 2) PLACE TURB BYP Valves for SG(s) with closed MSIV in HAND.
- 3) CLOSE TURB BYP Valves for SG(s) with closed MSIV to prevent loss of condenser vacuum.
- 4) GO TO step 26.C.
ATC B. OPERATE TURB BYP Valves to prevent RCS heatup.
ATC C. CHECK feedwater aligned for EACH SG.
Continued Page 20 of 43
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __2__ Event No.: __6, 7, & 8__
Event
Description:
__Main Steam Line Break inside containment. ESAS Channels 5 & 6 fail _
_to actuate automatically. EFIC Vector Isolation failure for one EFW Flow Path to faulted generator._
_Continued________________________________________________________________________
Time Position Applicants Actions or Behavior CAUTION: Drying out a SG can cause the 60°F (tubes hotter) Tube-To-Shell DT limit to be exceeded due to ambient temperature losses.
NOTE: Methods of limiting Tube-To-Shell deltaT (tubes hotter) are listed in order of preference.
C. PERFORM the following, while continuing with this procedure:
N/A 1) IF steam leak is isolated locally, THEN REFILL intact SG (RT 16).
- 2) IF leak is NOT isolated locally, THEN PERFORM the following ATC to maintain SG Tube To Shell delta T less than or equal to 60oF (tubes hotter), while continuing with this procedure:
ATC a) IF RCPs are running, THEN USE 1203.040, Forced Flow Cooldown for RCS cool down.
N/A b) IF ALL RCPs are off N/A c) IF RCPs are unavailable AND leak is outside containment
- 3) IF EITHER SG is dry, THEN MAINTAIN RCS pressure low ATC within limits of Figure 3 (RT 14), while continuing with this procedure.
WARNING: Feeding SG(s) with an unisolable steam leak is hazardous to personnel and equipment in the area.
CAUTION: Feeding SG(s) with an unisolable steam leak inside containment will add unborated water to RB sump.
EXAMINER NOTE: When Overcooling is terminated and temperature is stabilized / controlled, then FREEZE NOTES: .
Page 21 of 43
Appendix D Scenario Outline RT-5 PROPER EFW ACTUATION AND CONTROL VERIFICATION
- 1. ENSURE EFW actuation indicated on C09:
Train A: Train B:
- Bus 1
- Bus 1
- Bus 2
- Bus 2 NOTE Table 1 contains EFW fill rate and level bands for various plant conditions.
- 2. ENSURE at least one EFW pump (P7A or P7B) running with flow to SG(s) through applicable EFW CNTRL valve(s).
SG A SG B CV-2645 P7A CV-2647 CV-2646 P7B CV-2648
- 3. IF SCM is NOT adequate, THEN:
A. SELECT Reflux Boiling setpoint for the following:
- Train A
- Train B NOTE Table 2 contains examples of less than adequate/excessive EFW flow.
B. ENSURE EFW CNTRL valves operate to establish and maintain SG levels 370 to 410.
(3. CONTINUED ON NEXT PAGE)
Page 22 of 43
Appendix D Scenario Outline PROPER EFW ACTUATION AND CONTROL VERIFICATION
- 3. (Continued)
NOTE A SG is considered available if it has the capability to be fed and steamed.
a) IF EFW flow is less than adequate, THEN CONTROL EFW to applicable SG in HAND to maintain greater than or equal to 340 gpm to applicable SG until level is 370 to 410.
b) IF EFW flow is excessive AND greater than 340 gpm to either SG, THEN THROTTLE EFW to applicable SG in HAND to limit SG depressurization while maintaining greater than or equal to 340 gpm to each SG until SG level is 370 to 410.
- 2) IF only one SG is available, THEN FEED available SG in HAND at greater than or equal to 570 gpm until SG level is 370 to 410.
- 3) IF EFW is being controlled in HAND AND SG press drops below 720 psig due to EFW flow induced overcooling, THEN:
a) CONTINUE feeding at required minimum rate.
b) BYPASS MSLI by momentarily placing SG Bypass toggle switch on each EFIC cabinet Initiate module in BYPASS.
- C37-3
- C37-4
- C37-1
- C37-2 (3. CONTINUED ON NEXT PAGE)
Page 23 of 43
Appendix D Scenario Outline PROPER EFW ACTUATION AND CONTROL VERIFICATION
- 3. (Continued) c) PLACE applicable EFW CNTRL valves in VECTOR OVERRIDE:
SG A SG B CV-2645 P7A CV-2647 CV-2646 P7B CV-2648 d) PLACE applicable EFW ISOL valves in MANUAL.
SG A SG B CV-2627 P7A CV-2620 CV-2670 P7B CV-2626
- 4. IF SCM is adequate, THEN:
CAUTION Excessive EFW flow can result in loss of SCM due to RCS shrinkage.
NOTE
- Table 2 contains examples of less than adequate/excessive EFW flow..
- CETs are expected to rise until natural circ conditions are established. If EFW flow control is in HAND, additional flow may not be necessary to prevent rising CETs until natural circ is established.
A. ENSURE EFW CNTRL valves operate to establish and maintain applicable SG level band per Table 1.
- 1) IF EFW flow is less than adequate OR EFW flow is excessive, THEN CONTROL EFW to applicable SG in HAND as necessary to ensure the following:
- MAINTAIN continuous EFW flow until applicable level band is reached.
- MAINTAIN sufficient EFW flow to ensure SG level is either stable OR rising until applicable level band is reached.
Page 24 of 43
Appendix D Scenario Outline PROPER EFW ACTUATION AND CONTROL VERIFICATION
- 5. IF all RCPs are off, THEN CHECK primary to secondary heat transfer in progress indicated by all of the following:
- T-cold tracking associated SG T-sat (Fig. 2)
- T-hot tracking CET temps
- T-hot/T-cold DT stable or dropping
Table 1 EFIC Automatic Level Control Setpoints Condition Level Band Automatic Fill Rate Any RCP running 20 to 40 No fill rate limit All RCPs off and Natural Circ selected 300 to 340 2 to 8/min All RCPs off and Reflux Boiling selected 370 to 410 2 to 8/min Table 2 Examples of Less Than Adequate EFW Flow Indications
- All RCPs off and EFIC level not trending toward applicable level band Examples of Excessive EFW Flow Indications
- SCM approaching minimum adequate due to EFW flow induced overcooling
Appendix D Scenario Outline RT-6 PROPER MSLI AND EFW ACTUATION AND CONTROL VERIFICATION
- 1. ENSURE MSLI actuation indicated for affected SG(s) on C09:
Train A Train B Bus 1 Bus 1 Bus 2 Bus 2
- 2. ENSURE EFW actuation indicated on C09:
Train A Train B Bus 1 Bus 1 Bus 2 Bus 2
- 3. ENSURE affected SG(s) MSIV, Main Feedwater Isolation, Main Feedwater Block, Low Load, and Startup valves closed:
SG A SG B CV-2691 MSIV CV-2692 Main CV-2680 Feedwater CV-2630 Isolation Main CV-2625 Feedwater CV-2675 Block CV-2622 Low Load CV-2672 CV-2623 Startup CV-2673
- 4. ENSURE affected SG(s) ATM Dump Control System operating to maintain SG press 1000 to 1040 psig, unless SG depressurizes:
SG A SG B ATM Dump CV-2676 CV-2619 ISOL ATM Dump CV-2668 CV-2618 CNTRL Page 26 of 43
Appendix D Scenario Outline PROPER MSLI AND EFW ACTUATION AND CONTROL VERIFICATION
- 5. IF bad SG press is less than or equal to 600 psig and other SG press is greater than 600 psig OR DP between SGs is greater than 150 psig and both SGs less than 600 psig, THEN ENSURE EFW ISOL and EFW CNTRL valves to bad SG closed:
SG A SG B CV-2627 CV-2670 ISOL CV-2620 CV-2626 CV-2645 CV-2646 CNTRL CV-2647 CV-2648 NOTE Table 1 contains EFW fill rate and level bands for various plant conditions.
OR flow to both SGs if both are less than or equal to 600 psig and DP is less than or equal to 150 psig through applicable EFW CNTRL valves:
SG A SG B CV-2645 P7A CV-2647 CV-2646 P7B CV-2648
- 7. IF SCM is NOT adequate, THEN:
A. SELECT Reflux Boiling setpoint for the following:
- Train A
- Train B NOTE Table 2 contains examples of less than adequate/excessive EFW flow.
B. ENSURE EFW CNTRL valves operate to establish and maintain good SG level(s) 370 to 410.
(7. CONTINUED ON NEXT PAGE)
Page 27 of 43
Appendix D Scenario Outline PROPER MSLI AND EFW ACTUATION AND CONTROL VERIFICATION
- 7. (Continued)
NOTE A SG is considered available if it has the capability to be fed and steamed.
a) IF EFW flow is less than adequate, THEN CONTROL EFW to applicable SG in HAND to maintain greater than or equal to 340 gpm to applicable SG until level is 370 to 410.
b) IF EFW flow is excessive AND greater than 340 gpm to either SG, THEN THROTTLE EFW to applicable SG in HAND to limit SG depressurization while maintaining greater than or equal to 340 gpm to each SG until SG level is 370 to 410.
- 2) IF only one SG is available, THEN FEED available SG in HAND at greater than or equal to 570 gpm until SG level is 370 to 410.
- 3) IF EFW is being controlled in HAND AND SG press drops below 720 psig due to EFW flow induced overcooling, THEN:
a) CONTINUE feeding at required minimum rate b) BYPASS MSLI by momentarily placing SG Bypass toggle switch on each EFIC cabinet Initiate module in BYPASS:
- C37-3
- C37-4
- C37-1
- C37-2 (7. CONTINUED ON NEXT PAGE)
Page 28 of 43
Appendix D Scenario Outline PROPER MSLI AND EFW ACTUATION AND CONTROL VERIFICATION
- 7. (Continued) c) PLACE applicable EFW CNTRL valves in VECTOR OVERRIDE:
SG A SG B CV-2645 P7A CV-2647 CV-2646 P7B CV-2648 d) PLACE applicable EFW ISOL valves in MANUAL:
SG A SG B CV-2627 P7A CV-2620 CV-2670 P7B CV-2626
- 8. IF SCM is adequate, THEN:
CAUTION Excessive EFW flow can result in loss of SCM due to RCS shrinkage.
NOTE
- Table 2 contains examples of less than adequate/excessive EFW flow.
- CETs are expected to rise until natural circ conditions are established. If EFW flow control is in HAND, additional flow may not be necessary to prevent rising CETs until natural circ conditions are established.
A. ENSURE EFW CNTRL valves operate to establish and maintain applicable SG level band per Table 1.
- 1) IF EFW flow is less than adequate OR EFW flow is excessive, THEN CONTROL EFW to applicable SG in HAND as necessary to ensure the following:
- MAINTAIN sufficient EFW flow to ensure SG level is either stable OR rising until applicable level band is reached.
Page 29 of 43
Appendix D Scenario Outline PROPER MSLI AND EFW ACTUATION AND CONTROL VERIFICATION
- 9. IF a Condensate pump is running, THEN DISPATCH an operator to close bad SG Startup FW Control Valve Bypass while continuing:
- 10. IF all RCPs are off, THEN CHECK primary to secondary heat transfer in progress indicated by all of the following:
- T-cold tracking associated SG T-sat (Fig. 2)
- T-hot tracking CET temps
- T-hot/T-cold DT stable or dropping
Page 30 of 43
Appendix D Scenario Outline PROPER MSLI AND EFW ACTUATION AND CONTROL VERIFICATION Table 1 EFIC Automatic Level Control Setpoints Condition Level Band Automatic Fill Rate Any RCP running 20 to 40 No fill rate limit All RCPs off and Natural Circ selected 300 to 340 2/min to 8/min All RCPs off and Reflux Boiling selected 370 to 410 2/min to 8/min Table 2 Examples of Less Than Adequate EFW Flow Indications
- All RCPs off and EFIC level not trending toward applicable level band Examples of Excessive EFW Flow Indications
- SCM approaching minimum adequate due to EFW flow induced overcooling
Appendix D Scenario Outline RT-9 MAXIMIZE RB COOLING
- 1. Verify all four RB Cooling Fans running:
- VSF1A
- VSF1C
- VSF1B
- VSF1D
- 2. Open RB Cooling Coils Service Water Inlet/Outlet valves:
- CV-3812/CV-3814
- CV-3813/CV-3815
- 3. Unlatch key-locked Chiller Bypass Dampers:
- SV-7410
- SV-7412
- SV-7411
- SV-7413 END Page 32 of 43
Appendix D Scenario Outline RT-10 VERIFY PROPER ESAS ACTUATION
- 1. Verify BWST T3 Outlets open:
- CV-1407
- CV-1408 A. IF BWST T3 Outlet (CV-1407 or CV-1408) fails to open, THEN obtain Shift Manager/CRS permission to override ES.
B. Override AND stop associated HPI, LPI, and RB Spray pumps until failed valve is opened:
CV-1407 CV-1408 P34A P34B P36A/B P36C/B P35A P35B
- 2. Verify SERV WTR to DG1 and DG2 CLRs open:
- CV-3806
- CV-3807 Page 33 of 43
Appendix D Scenario Outline VERIFY PROPER ESAS ACTUATION
- 3. IF any RCP is running, THEN perform the following:
A. IF ES Channel 5 or 6 has actuated, THEN perform the following:
- 1) IF SCM is adequate, THEN trip all running RCPs due to loss of ICW:
- P32A
- P32C
- P32B
- P32D
- 2) IF SCM is NOT adequate, THEN check elapsed time since loss of adequate SCM AND perform the following:
a) IF £ 2 minutes have elapsed, THEN trip all RCPs:
- P32A
- P32C
- P32B
- P32D b) IF > 2 minutes have elapsed, THEN perform the following:
(1) Leave currently running RCPs on.
(2) IF RCS press > 150 psig, THEN notify CRS to GO TO 1202.002, LOSS OF SUBCOOLING MARGIN procedure.
(3) Restore RCP services per RT-8 while continuing.
B. IF neither ES channel 5 nor 6 has actuated, THEN dispatch an operator to perform Service Water And Auxiliary Cooling System (1104.029) Exhibit B, "Restoring SW to ICW Following ES Actuation" while continuing.
- 1) WHEN ICW Cooler SW Outlets and Bypasses are aligned per 1104.029, Exhibit B, THEN perform the following:
a) Obtain Shift Manager/CRS permission to override ES.
b) Override AND open one Service Water to ICW Coolers Supply (CV-3811 or CV-3820).
Page 34 of 43
Appendix D Scenario Outline VERIFY PROPER ESAS ACTUATION
- 4. Verify proper ESAS Channels tripped:
Condition Channels Actuated RCS press 1550 psig 1,2,3,4 RB press 18.7 psia 1,2,3,4,5,6 RB press 44.7 psia 7,8,9,10
- 5. Perform the following:
A. Verify each component properly actuated on C16 and C18, except those overridden in previous steps.
B. Verify proper ES system flow rates.
NOTE
- During ESAS actuation, low LPI flow is expected until RCS depressurizes below LPI pump shutoff head.
- During large break LOCAs, high LPI flow can be experienced. Flow is throttled to ensure ECCS flows are maintained within assumptions of calculations.
- 1) IF any of the following conditions exist:
- A HPI FLOW HI/LO (K11-A4)
- B HPI FLOW HI/LO (K11-A5)
- A LPI FLOW HI/LO (K11-B4)
- B LPI FLOW HI/LO (K11-B5)
- A RB SPRAY FLOW HI (K11-C4)
- B RB SPRAY FLOW HI (K11-C5)
THEN use Annunciator K11 Corrective Action (1203.012J) to clear unexpected alarms.
C. IF only one train of HPI is available AND RCS press is > 600 psig, THEN throttle HPI Block valve with the highest flow to within 20 gpm of the next highest flow.
Page 35 of 43
Appendix D Scenario Outline VERIFY PROPER ESAS ACTUATION
- 6. On C10, perform the following:
- Verify DGs operating within normal limits DG 1 DG 2 4100 TO 4200 4100 TO 4200 59.5 TO 60.5 59.5 TO 60.5
<2750 kw <2750 kw
- Verify the following breakers open:
- A3-A4 Crossties A-310 A-410
- B5-B6 Crossties B-513 B-613
- Unit AUX feeds to A1 and A2 A-112 A-212
- Verify the following breakers closed
- A3 Feeds to B5 A-301 B-512
- A4 Feeds to B6 A-401 B-612
- 7. On C09, perform the following:
A. Check AUX Cooling Water header depressurized.
B. IF proper EFW actuation and control has NOT already been verified, THEN verify proper EFW actuation and control (RT-5).
Page 36 of 43
Appendix D Scenario Outline VERIFY PROPER ESAS ACTUATION
- 8. On C19, perform the following:
A. Verify LPI (Decay Heat) Room Cooler running in each Decay Heat Room:
P34A Room P34B Room VUC1A or B VUC1C or D B. IF RB Spray has actuated, THEN verify SW to RB Spray P35A and P35B LO CLRs open:
- CV-3804
- CV-3805
- 9. IF all RCPs are off AND RCP Seal INJ Block (CV-1206) is closed, THEN place RCP Seal Bleedoff (Alternate Path to Quench Tank) controls in CLOSE:
- SV-1271
- SV-1273
- SV-1270
- SV-1272
A. Verify all four RB Cooling Fans running:
- VSF1A
- VSF1C
- VSF1B
- VSF1D B. Verify RB Cooling Coils Service Water Inlet/Outlet valves open:
- CV-3812/CV-3814
- CV-3813/CV-3815 C. Verify key-locked Chiller Bypass Dampers unlatched:
- SV-7410
- SV-7412
- SV-7411
- SV-7413 Page 37 of 43
Appendix D Scenario Outline Page 6 of 7 VERIFY PROPER ESAS ACTUATION
- 12. Verify each component properly actuated on C26.
- 13. Verify the following sample valves closed on C26:
- Pressurizer Steam Space Sample Valve (CV-1814)
- Pressurizer Water Space Sample Valve (CV-1816)
- Hot Leg Sample (SV-1840)
- 14. Verify the following High Point Vents closed:
A Loop B Loop Reactor Vessel Pressurizer SV-1081 SV-1091 SV-1071 SV-1082 SV-1092 SV-1072 SV-1077 SV-1083 SV-1093 SV-1073 SV-1079 SV-1084 SV1094 SV-1074
- 15. IF AUX Lube Oil pump for running HPI pump fails to stop after 20 second time delay, THEN within one hour of ESAS actuation dispatch an operator to stop AUX Lube Oil pump locally at breaker while continuing:
P64A P64B P64C B5721 B5722/B6515 B6514
- 16. Place running Low Pressure Injection (Decay Heat) Pump (P34A/P34B) hand switches in NORMAL-AFTER-START to enable DECAY HEAT PUMP TRIP (K09-A7) alarm:
- P34A
- P34B
- 17. Monitor ENGINEERED SAFEGUARDS ACTUATION SYSTEM alarms on K11.
Page 38 of 43
Appendix D Scenario Outline VERIFY PROPER ESAS ACTUATION
- 18. IF any of the following components/systems are in service:
- Condensate Pumps
- Condenser Vacuum Pumps
- Waterbox Vacuum Pumps
- Seal Oil System
- Control Room Chillers THEN coordinate with CRS/SM to secure components and/or systems, as time permits.
- 19. Coordinate with CRS/SM to re-verify component actuation with another operator.
END Page 39 of 43
Appendix D Scenario Outline RT-14 CONTROL RCS PRESS NOTE
- PTS limits apply if any of the following has occurred:
- RCS C/D rate > 100°F/hr with Tcold < 355°F
- RCS C/D rate > 50°F/hr with Tcold < 300°F
- Once invoked, PTS limits apply until an evaluation is performed to allow normal press control.
- PZR cooldown rate <100°F/hr.
- 2. IF RCS press is controlled AND will be reduced below 1650 psig, THEN BYPASS ESAS as RCS press drops below 1700 psig.
- 3. IF PZR steam space leak exists, THEN LIMIT RCS press as PZR goes solid by one or more of the following:
A. THROTTLE makeup flow.
B. IF SCM is adequate, THEN THROTTLE HPI flow by performing the following:
- 1) ENSURE both HPI Recirc Blocks open:
- CV-1300
- CV-1301
- 2) THROTTLE HPI.
C. RAISE Letdown flow.
- 1) IF Letdown is isolated AND SCM is adequate, THEN unless fuel damage or RCS to ICW leak is suspected, RESTORE Letdown per RT-13.
D. Using ERV:
- 1) ENSURE Electromatic Relief ERV Isolation (CV-1000) open.
- 2) CYCLE Electromatic Relief ERV (PSV-1000).
Page 40 of 43
Appendix D Scenario Outline CONTROL RCS PRESS
- 4. IF RCS press is high, THEN LIMIT press using one or more of the following:
A. THROTTLE makeup flow.
B. THROTTLE HPI flow by performing the following:
- 1) CHECK adequate SCM AND any of the following conditions met:
- CET temps dropping
- 2) ENSURE both HPI Recirc Blocks open:
- CV-1300
- CV-1301
- 3) THROTTLE HPI.
C. IF RCP is running, THEN OPERATE Pressurizer Spray Control (CV-1008) in HAND.
D. PLACE Pressurizer Heaters in OFF.
E. RAISE Letdown flow.
- 1) IF Letdown is isolated AND SCM is adequate, THEN unless fuel damage or RCS to ICW leak is suspected, RESTORE Letdown per RT-13.
CAUTION Quench Tank pressure of 100 psig will blow the Quench Tank rupture disk.
F. Using ERV:
- 1) ENSURE Electromatic Relief ERV Isolation (CV-1000) open.
- 2) CYCLE Electromatic Relief ERV (PSV-1000).
G. CYCLE both valves for Pressurizer Vent to Quench Tank:
- SV-1077
- SV-1079 (4. CONTINUED ON NEXT PAGE)
Page 41 of 43
Appendix D Scenario Outline CONTROL RCS PRESS
- 4. (Continued)
H. IF PZR AUX Spray is in service, THEN THROTTLE Pressurizer AUX Spray (CV-1416) open.
I. IF desired to secure HPI pump(s), THEN:
P36A P36B P36C P64A P64B P64C
- 2) STOP desired HPI pump(s):
- P36A
- P36B
- P36C
- 3) CLOSE all associated HPI Block valves:
P-36A/B P-36B/C CV-1219 CV-1227 CV-1220 CV-1228 CV-1278 CV-1284 CV-1279 CV-1285
- 5. IF RCS press is low, THEN RAISE press using one or more of the following:
A. RAISE makeup flow.
B. RAISE HPI flow or initiate HPI per RT-2.
C. IF RCP is running, THEN ENSURE Pressurizer Spray Control (CV-1008) closed.
D. IF PZR AUX Spray is in service, THEN THROTTLE Pressurizer AUX Spray (CV-1416) closed.
E. REDUCE Letdown flow.
F. PLACE Pressurizer Heaters in MANUAL.
(5. CONTINUED ON NEXT PAGE)
Page 42 of 43
Appendix D Scenario Outline CONTROL RCS PRESS
- 5. (Continued)
CAUTION If HPI cooling is in progress, Electromatic Relief ERV Isolation (CV-1000) is left open until HPI cooling is no longer required.
G. ENSURE Electromatic Relief ERV (PSV-1000) or Electromatic Relief ERV Isolation (CV-1000) closed.
H. ENSURE both Pressurizer Vent to Quench Tank valves closed:
- SV-1077
- SV-1079 CAUTION With RCS solid, 1°F temp change can cause 100 psig press change.
- LOWER RCS temp to lower RCS press NOTE Adjusting Pressurizer Level Control setpoint and HPI as necessary to maintain normal makeup flow on-scale will allow CV-1235 to automatically compensate for small changes in RCS leak rate and cooldown rate.
- 7. IF normal makeup is in service AND HPI is in service, THEN ADJUST Pressurizer Level Control setpoint and HPI as necessary to maintain normal makeup flow on-scale.
END Page 43 of 43
Appendix D Scenario Outline Facility: ANO-1 Scenario No.: 5 R0 Op-Test No.: 2020-1 Examiners: ____________________________Operators: _____________________________
Initial Conditions:
- IC205 - Beginning of Life - Run Scenario 5 Schedule File R0 5% Power. -
- Boron 1710 ppm Turnover:
- Place A MFWP in service - Provide figures / attachments for
- Raise power to 10% startup Event Event Event Malf. No.
No. Type* Description N-(ATC) 1 N/A N-(BOP) Place A MFWP in service and secure P-75 Aux FW Pump N-(SRO)
N-(BOP) 2 N/A Reset ARTS N-(SRO)
I-(CRS) 3 TR596 A OTSG EFIC Low Range Level fails low TS R-(ATC) 4 N/A Raise power to 10%
R-(SRO)
C-(ATC)
C-(BOP) Group 7 Rods do not sequence on resulting in no overlap 5 RD271 C-(SRO) between Groups 6 & 7 TS C-(ATC)
C-(BOP) 6 ED452 Loss of ICS Power C-(SRO)
AOP 7 ED183 M-(ALL) Loss of Offsite Power C-(BOP) 8 DG174 #2 EDG Failure C-(SRO)
C-(ATC)
P-7A EFW Pump trips on trip throttle linkage failure.
9 FW076 C-(SRO)
Control EFW flow with P-7B when #1 EDG is recovered.
CT C-(BOP) 10 DG175 C-(SRO) #1 EDG fails to auto start CT
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 41
Appendix D Scenario Outline Target Quantitative Attributes (Section D.5.d) Actual Attributes Malfunctions after EOP entry (1-2) 2 Abnormal Events (2-4) 2 Major Transients (1-2) 1 EOPs entered requiring substantive actions (1-2) 2 EOP contingencies requiring substantive actions ( 1per 1 scenario set)
Critical Tasks (2) 2 SCENARIO 5 OBJECTIVES
- 1) Evaluate individual ability to perform placing Main Feedwater Pump in service and securing Aux Feedwater Pump.
- 2) Evaluate individual ability to perform Anticipatory Reactor Trip System (ARTS) Reset.
- 3) Evaluate individual ability to perform Power Escalation.
- 4) Evaluate individual ability to recognize and respond to failure to have proper overlap between Group 6 and Group 7 control rods.
- 5) Evaluate individual ability to recognize and respond to a loss of ICS power.
- 6) Evaluate individual ability to recognize and respond to Electrical Distribution Annunciators on K-02.
- 7) Evaluate individual ability to perform an RCS Leakage Investigation.
- 8) Evaluate individual ability to recognize and respond to Excess RCS Leakage.
- 9) Evaluate individual ability to recognize and respond to Degraded Power.
- 10) Evaluate individual ability to recognize and respond to EDG failure to start.
- 11) Evaluate individual ability to perform DG1 Start from Control Room.
Page 2 of 41
Appendix D Scenario Outline SCENARIO 5 NARRATIVE Event One: Place A MFWP in service and secure P-75 Aux FW Pump The SRO will direct the ATC to place the A MFW pump in service as directed in 1102.002 Plant Startup Procedure. When the A MFW pump is supplying feedwater to the steam generators, the SRO will direct the BOP to secure P-75 the Aux. FW pump.
(ATC-N) (BOP-N) (SRO-N)
Event Two: Reset ARTS The SRO will then direct that the Anticipatory Reactor Trips (ARTS) reset in RPS for the A MFW pump. Failure to perform the ARTS reset will result in a reactor trip when reactor power exceeds 7% power. ARTS must be reset prior exceeding 7% NI Power.
(BOP-N) (SRO-N)
Event Three: A OTSG EFIC Low Range Level fails low This failure will result in a half trip of EFIC as indicated by K12-C7, EFIC System Trouble. As a result of the failure, the SRO will enter T.S. 3.3.11 Condition A and direct the BOP to take EFIC Channel A to Maintenance Bypass in order to reset the half trip.
(ATC-C) (BOP-C) (SRO-C) ACA, TS Event Four: Raise power to 10%
When ARTS is reset, the SRO will then direct that plant power will be raised to ~10% power.
(ATC-R) (SRO-R)
Event Five: Group 7 Rods do not sequence on resulting in no overlap between Groups 6 & 7 As reactor power is raised, a failure of the group 7 Control Rod Sequencing circuit will result in group 7 Control Rods not withdrawing when group 6 Control Rods are between 75% and 85%.
This should be recognized by the ATC and/or BOP and the SRO should be notified. The SRO should direct that rod withdrawal be stopped and then reference Tech Specs.
(ATC-C) (BOP-C) (SRO-C)TS Event Six: Loss of ICS Power Once the Tech Spec entry is announced to the crew, a Loss of ICS power will occur which will require entry into 1203.001, ICS Abnormal Operations AOP. The CRS will direct a manual reactor trip and will continue in the AOP while also performing 1202.001, Reactor Trip EOP (ATC-C) (BOP-C) (SRO-C) AOP Event Seven: Loss of Offsite Power Once the immediate actions are completed in Reactor Trip and the Atmospheric Dump Isolation valves are opened by the AOP, a Loss of Offsite Power will occur and the SRO will direct actions from OP-1202.007, Degraded Power. If asked, Unit 2 will report that the Alternate AC Diesel Generator is not available due to governor control issues and maintenance has been contacted for investigation.
(ATC-C) (BOP-C) (SRO-C) EOP Event Eight: #2 EDG Failure Shortly following the loss of offsite power, the #2 EDG will trip resulting in a momentary station blackout if the #1 EDG wasnt already started.
(BOP-C) (SRO-C) EOP Page 3 of 41
Appendix D Scenario Outline Event Nine: P-7A EFW Pump trips on trip throttle linkage failure. Control of EFW flow with P-7B when #1 EDG is recovered Shortly after the loss of offsite power, P-7A steam driven EFW Pump will trip due to a trip throttle linkage failure. Mechanical maintenance assistance will be required for repairs of the linkage and the pump will be unavailable for the duration of the scenario. In addition to the linkage failure, P-7B electric EFW Pump will not be available due to a failure of the #1 EDG to automatically start. The BOP will start the diesel which will energize P-7B. Due to the failed EFIC level transmitter, P-7B will be feeding full flow to the A Steam Generator. The ATC will identify this and manually control EFW flow. This is a CRITICAL TASK to be completed prior to the steam generator level reaching 400 inches.
(ATC-C) (SRO-C) CT CT Justification: CT-16 Safety significance - Excessive primary to secondary heat transfer due to overfeeding faulted steam generator.
Initiating Cue - RCS overcooling in progress, lower than normal steam generator pressure, skewed EFW flow to faulted steam generator.
Measurable Performance Standard - Manually isolate all FW flow (MFW and EFW) to the faulted steam generator prior to steam generator reaching 400 inches (Carry-over into main steam lines)
Event Ten: #1 EDG fails to start During verification of RT-21, Check EDG Operation, the BOP will identify that the #1 EDG failed to start automatically and he will start the associated EDG from C10. Starting #1 EDG is a CRITICAL TASK to ensure a 4160 Volt power supply remains available to a vital bus.
(BOP-C) (SRO-C) CT CT Justification: CT-8 Safety significance -Prevent degradation of the mitigative capability of the plant Initiating Cue - Loss of Offsite Power, A3 de-energized, normal lighting in the control room off.
Measureable Performance Standard - BOP will start the #1 EDG within 15 minutes of Blackout.
EAL escalation is required if the EDG is not started within 15 minutes.
Performance Feedback - Change of status lamps on control console for #1 EDG, components on C18 and normal lighting returns for the control room.
The scenario can be terminated at the discretion of the lead examiner.
Page 4 of 41
Appendix D Scenario Outline Simulator Instructions for Scenario 5 Reset simulator to BOL ~2-5% power IC steady state Ensure malfunctions agree with scenario guide (either schedule file or IC)
Event Time Event Description No. Type N-(ATC) 1 T=0 N-(BOP) Place A MFWP in service and secure P-75 Aux FW Pump N-(SRO)
N-(BOP) 2 T=15 Reset ARTS N-(SRO)
I-(BOP) 3 T=20 I-(CRS) A OTSG EFIC Low Range Level fails low TS R-(ATC) 4 T=40 Raise power to 10%
R-(SRO)
C-(ATC)
C-(BOP) Group 7 Rods do not sequence on resulting in no overlap between 5 T=60 C-(SRO) Groups 6 & 7 TS C-(ATC)
C-(BOP) 6 T=65 Loss of ICS Power C-(SRO)
AOP 7 T=70 M-(ALL) Loss of Offsite Power T=70 C-(BOP) 8 #2 EDG Failure C-(SRO)
T=70 C-(BOP) 9 C-(SRO) #1 EDG fails to auto start CT C-(ATC)
P-7A EFW Pump trips on trip throttle linkage failure.
10 T=75 C-(SRO)
Control EFW flow with P-7B when #1 EDG is recovered.
CT Page 5 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __1/2__
Event
Description:
__Place A MFWP in service__________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: 1102.002 Step 17.16, was the starting point for the following.
T=0 SRO Directs the following:
17.16.1 PERFORM 1106.016, Placing MFWP Into Service section to place a MFP into service and stop the Aux Feed Pump EXAMINER NOTE: 1106.016 will be place kept up to step 15.3.
SRO Directs BOP to place A MFW Pump into service per 1106.016 Section 15.
ATC 15.3 To ensure the MFWP to be placed into service first is supplying feedwater, RAISE MFWP speed until associated Startup Control Valves or Low Load Control Valves start to close:
- Startup Valve Loop A (CV-2623)
- Low Load Valve Loop A (CV-2622)
- Startup Valve Loop B (CV-2673)
- Low Load Valve Loop B (CV-2672)
BOP 15.4 STOP Aux Feedwater Pump (P-75).
BOP 15.5 RESET RPS trips per 1102.002, Plant Startup for the first MFWP, Attachment E, Anticipatory Reactor Trip System (ARTS) Reset.
EXAMINER NOTE: Steps for resetting ARTS (1102.002 Attachment E).
Only the A RPS Cabinet is modeled, B, C, and D just have a toggle switch for resetting ARTS.
BOP 1.0 CIRCLE MFW Pump started: A / B 2.0 RESET RPS channels as follows:
- In RPS Channel A Cabinet (C41), using SRO/RO concurrent verification:
A. DEPRESS test switch labeled RESET on contact buffer lower module for the started Main Feedwater Pump.
B. CHECK two red lamps on contact buffer change state (top lit, bottom off).
C. CHECK white lamp MFWP A (B) TRIPPED (for the started MFWP) is dim.
EXAMINER NOTE: BOP should reset the ARTS bistable in the other three cabinets, but if they have problems (since it isnt like the plant) inform the booth operator and I will reset the other channels.
Continued Page 6 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __1/2__
Event
Description:
__Place A MFWP in service__________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: Return to 1102.002 Step 17.16.3. Most likely the SRO will direct placing the MFWP into automatic however, both methods are included below.
N/A 17.16.3 IF CRS directs control of the in-service MFWP in MANUAL, THEN ENSURE the following:
- In-service MFWP HAND/AUTO station in HAND
- BOTH Main Feedwater Block valves closed (CV-2625 and CV-2675)
- MFWP speed adjusted to maintain discharge pressure between 1025 and 1075 psig.
(CR-ANO-1-2018-3238, CA-11, CAPR)
Concurrent Verifier:
17.16.4 IF CRS directs control of the in-service MFWP in ATC AUTO, AND power escalation to greater than 10%
will commence, THEN:
A. IF B Main Feed Pump (P-1B) is in service, N/A B. SELECT MEAS VAR on the following and MONITOR SU valve DPs:
- A MFW Pump H/A station
- B MFW Pump H/A station C. While monitoring flow and valve positions, ADJUST the in-service pump speed until the lowest DP is 70 - 80 psid.
D. DEPRESS AUTO pushbutton.
E. CHECK MFP controls lowest DP 60 - 80 psid.
F. MONITOR the following Polisher parameters:
- Polisher DP (63 psid max)
- Polisher flow (1500 to 3550 gpm)
- Polisher resin trap DP (10 psid max)
NLO EXAMINER NOTE: Step 17.17 is already completed and signed off.
ATC 17.18 WHEN a MFP is in service, THEN BEGIN reactor power escalation to 6 to 10%.
Continued Page 7 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __1/2__
Event
Description:
__Place A MFWP in service__________________________________
_Continued________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: Step 17.19 - 17.20 are already in progress / completed.
17.21 WHEN in Mode 1, THEN:
17.21.1 MAKE a station log entry for entering Mode 1.
SRO 17.21.2 MAKE a station log entry that RCS lithium is required to be in its control band within next 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, or upon reaching equilibrium xenon (enter time required).
17.21.3 MAKE shift turnover sheet entry of time and date that lithium is required to be in spec.
17.21.4 IF CRS/SM directs Diamond Panel to be placed in AUTO, ATC THEN PLACE Diamond Panel in AUTO per 1105.004, Integrated Control System.
17.22 CHECK following alarms clear at 9% reactor power:
ATC - TRIP ON LOSS OF MFP BYPASSED (K08 F4)
- REACTOR TRIP ON LOSS OF FEEDWATER BYPASS/TROUBLE (K15 B1)
N/A 17.23 REVIEW Temp Mod Logbook for acceptability of active Temp Mods in Mode 1.
SRO 17.24 IF turbine will be placed in service during this startup, THEN CONTINUE to Turbine Startup And Power escalation To 25%
section.
End of Event NOTES:
Page 8 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __3__
Event
Description:
__A OTSG EFIC Low Range Level fails low______________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: The SRO should direct the BOP to place Channel A into Maintenance Bypass and then re-arm EFIC.
ATC Announce and acknowledge EFIC System Trouble, K12-C7 ALL 1. IF due to half trip of EFW or MSLI, THEN DETERMINE validity of actuation N/A 2. IF EFIC system trouble is due to a valid EFW actuation, N/A N/A 3. IF EFIC system trouble is due to a valid MSLI actuation, ...N/A BOP 4. IF EFIC system trouble is due to an invalid actuation signal, THEN ENSURE EFIC is re armed for actuation per 1105.005, Emergency Feedwater Initiation and Control.
SRO 5. REFER TO Technical Specifications and 1105.005, Emergency Feedwater Initiation and Control, Appendix A, Operability.
N/A 6. IF due to loss of power supply to a C37 EFIC cabinet, N/A N/A 7. IF due to loss of power to an EFIC System Cabinet (C186 or C187), N/A N/A 8. IF alarm due to C186 or C187 local controls, N/A N/A 9. IF cause of alarm NOT apparent, THEN ENSURE Condition Report is initiated.
Continued NOTES:
Page 9 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __3__
Event
Description:
__A OTSG EFIC Low Range Level fails low______________________
_Continued________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: 1105.005, provides direction for placing a channel into Maintenance Bypass.
SRO Direct placing Channel A into Maintenance Bypass per 1105.005 Section 20.0 20.1 Placing an EFIC channel in Maintenance Bypass BOP 20.1.1 IDENTIFY the EFIC channel to be bypassed: A BOP 20.1.2 OBTAIN EFIC Maintenance Bypass key.
20.1.3 PERFORM the following to comply with Tech Spec:
SRO A. ENSURE Tech Spec 3.3.11 Condition A is entered for this TS condition.
B. IF Tech Spec 3.0.5 is applicable, THEN ENTER Tech Spec 3.0.5.
20.1.4 PERFORM ONE of the following:
BOP A. IF NO RPS Channel is in Manual Bypass, THEN CHECK the Maintenance Bypass indicator light on the alarm panel in EACH EFIC channel is ON solid.
N/A B. IF an RPS Channel is in Manual Bypass, N/A BOP 20.1.5 ROTATE EFIC Maintenance Bypass key clockwise to bypass the channel identified above.
BOP 20.1.6 CHECK Maintenance Bypass lamp for the bypassed channel is flashing.
BOP 20.1.7 OBSERVE EFIC MAINTENANCE BYPASS (K12 F7) is in alarm.
BOP 20.1.8 OBSERVE appropriate computer point in alarm:
N/A 20.1.10 Prior to performing maintenance or further manipulations on EFIC, REFER TO Tech Specs for the specific situation.
Continued Page 10 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __3__
Event
Description:
__A OTSG EFIC Low Range Level fails low______________________
_Continued_______________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: 1105.005, provides direction for returning EFIC to normal automatic condition following half trip condition. The trip was due to maintenance personnel, no external trip nor bistables will need to be reset.
14.0 RETURNING EFIC SYSTEM TO NORMAL AUTOMATIC CONDITION FOLLOWING HALF TRIP CONDITION ATC / 14.1 Using EFIC cabinet bistables, alarm panels and control room BOP indications, ENSURE that parameters responsible for half trip condition are in normal control bands.
SRO 14.2 REFER TO the following:
- Technical Specification applicability for condition causing half trip
- Appendix A, Operability N/A 14.2.1 CONSIDER 14.3 IF initiating signal contacting Licensing came from externalfor additional trip guidance.
(indicated by trip lamps off for EXT TRIPS ESAS or MFP on EFIC cabinet alarm panel or DROPS [AMSAC] C498), THEN ENSURE trip signal clear.
N/A 14.4 IF Bistable tripped, THEN:
14.4.1 At affected bistable, RESET Bistable Tripped memory lamps on the following:
- EFIC C cabinet (C37 3)
- EFIC A cabinet (C37 1)
- EFIC D cabinet (C37 4)
- EFIC B cabinet (C37 2) 14.4.2 OBSERVE Bistable Tripped memory lamp is flashing (bright to dim) to dim upon reset on the following alarm panels:
- EFIC C cabinet (C37 3)
- EFIC A cabinet (C37 1)
- EFIC D cabinet (C37 4)
- DEPRESS EFW Reset pushbutton for actuated bus on remote switch matrix:
- Train A
- Train B
- EFIC A cabinet (C37 1)
- EFIC B cabinet (C37 2)
Continued Page 11 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __3__
Event
Description:
__A OTSG EFIC Low Range Level fails low______________________
_Continued_______________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: 1105.005, provides direction for returning EFIC to normal automatic condition following half trip condition.
14.6 CHECK the following:
- EFW Bus actuated lamps on remote switch Train A matrix are off.
- EFW Bus actuated lamps on remote switch Train B matrix are off.
SRO 14.7 IF Tech Specs were entered due to EFIC half trip, THEN EXIT Tech Specs.
End of Event NOTES:
Page 12 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __4__
Event
Description:
________Raise power to 10%_________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: Step 17.19 - 17.20 are already in progress / completed.
SRO 17.21 WHEN in Mode 1, THEN:
17.21.1 MAKE a station log entry for entering Mode 1.
17.21.2 MAKE a station log entry that RCS lithium is required to be in its control band within next 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, or upon reaching equilibrium xenon (enter time required).
17.21.3 MAKE shift turnover sheet entry of time and date that lithium is required to be in spec.
17.21.4 IF CRS/SM directs Diamond Panel to be placed in AUTO, ATC THEN PLACE Diamond Panel in AUTO per 1105.004, Integrated Control System.
ATC 17.22 CHECK following alarms clear at 9% reactor power:
- TRIP ON LOSS OF MFP BYPASSED (K08 F4)
- REACTOR TRIP ON LOSS OF FEEDWATER BYPASS/TROUBLE (K15 B1)
N/A 17.23 REVIEW Temp Mod Logbook for acceptability of active Temp Mods in Mode 1.
SRO 17.24 IF turbine will be placed in service during this startup, THEN CONTINUE to Turbine Startup And Power escalation To 25%
section.
End of Event Page 13 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __5__
Event
Description:
__Group 7 Rods do not sequence on resulting in no overlap between___
__ Groups 6 & 7____________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: When Group 6 is withdrawn 75% - 85% (25% to 15% overlap) Group 7 should start to withdraw.
ATC Diagnose and report that Group 7 rods did not energize in the appropriate sequence overlap setting.
SRO Direct the ATC to stop power escalation.
SRO Reference Tech Specs and enter T.S. 3.2.1 Condition C TS BOOTH OPERATOR: If Reactor Engineering is contacted, tell the CRS to maintain current rod configuration until notified.
EXAMINER NOTE: The following steps are not procedurally required therefore the CRS may not direct it to be performed to exit the TS condition.
SRO Directs the ATC to insert Group 6 Control Rods (reduce power) to return the Control Rods to <85% withdrawn to return to within tech spec limits.
ATC Inserts Group 6 Control Rods by placing the Tee-Handle on the Diamond Panel to insert.
ATC Notifies the CRS when Group 6 Control Rods are <85% withdrawn.
End of Event NOTES:
Page 14 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __6__
Event
Description:
__Loss of ICS Power_________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: Crew should recognize loss of both AC and DC power to ICS.
ATC Diagnose and report K07-A4, ICS/AUX SYS POWER SUPPLY TROUBLE due to a loss of ICS power.
SRO Enter 1203.001 ICS Abnormal Operations AOP, Section 3.
- 1. TRIP the reactor.
- 2. While continuing with this section, PERFORM 1202.001, Reactor Trip EXAMINER NOTE: Actions from Reactor Trip.
ATC 1. Depress Reactor Trip PB.
A. Verify all rods inserted AND Reactor power dropping.
BOP 2. Depress Turbine trip PB.
A. Check Turbine throttle and governor valves closed.
ATC 3. Check adequate SCM.
SRO 4. Perform the following:
- Advise Shift Manager to implement Emergency Action Level Classification (1903.010).
- Direct Control Board Operators to monitor floating step ATC 5. Verify Orifice Bypass (CV 1223) demand adjusted to zero.
BOP 6. Open BWST T3 Outlet (CV 1407 or CV 1408) to operating HPI ATC pump.
- 7. IF Emergency Boration is not in progress, THEN adjust Pressurizer Level Control setpoint to 100.
ATC 8. Control RCS press within limits of Figure 3 (RT 14).
BOP 9. Check for proper electrical response (RT 19).
ATC 10. Check normal Makeup and Seal Injection are in service ATC 11. Check both SG levels remain < 410".
ATC 12. Check Instrument Air Header Press > 75 psig.
ATC 13. Check NNI and ICS power available (RT 20).
Continued Page 15 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __6__
Event
Description:
__Loss of ICS Power_________________________________________
__Continued_______________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: Actions from Loss of ICS Power AOP.
ATC / 3. TRIP operating Main and Auxiliary Feedwater Pumps:
- Main Feedwater Pump (P-1A)
- Main Feedwater Pump (P-1B)
- Auxiliary Feedwater Pump (P-75)
ATC 4. PERFORM RT-5, Verify Proper EFW Actuation and Control.
ATC 5. OPEN BOTH ATM Dump Isols:
- SG-A ATM Dump Isol (CV-2676)
- SG-B ATM Dump Isol (CV-2619)
ATC 6. ENSURE ATM Dump Control System maintains SG pressures 1000 to 1040 psig.
EXAMINER NOTE: At lead examiner direction, insert Loss of Offsite Power malfunction.
End of Event NOTES:
Page 16 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __7__
Event
Description:
__Loss of Offsite Power______________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: The #2 EDG will trip shortly after the loss of offsite power. The #1 EDG must be manually started within 15 minutes to satisfy the CRITICAL TASK.
SRO 1. Perform the following:
- Record time of Degraded Power: ______
Direct Control Board Operators to monitor Floating Steps.
BOP 2. Verify proper operation of both EDGs (RT-21).
CT A. IF an EDG is operating, THEN verify proper operation of EDG (RT-21).
BOP B. Verify 480V MCC B55 and 56 power supply is selected to operating DG.
C. Align SW as follows:
- Close ACW Isolation (CV-3643).
- Close Service Water to ICW Coolers Supply associated with operating EDG:
DG1 DG2 CV-3820 CV-3811 D. Attempt to restore non-running EDG using Annunciator K01 Corrective Action (1203.012A) and Emergency Diesel Generator Operation (1104.036), while continuing with this procedure.
Continued Page 17 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __7/8/9/10__
Event
Description:
__Loss of Offsite Power / #2 EDG Failure________________________
__P-7A EFW Pump trips on trip throttle linkage failure / Restore EFW Flow with P-7B when
__#1 EDG is recovered / #1 EDG fails to auto start________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: The Alternate AC (AAC) Diesel Generator will be available IF #1 EDG has been started, otherwise it will not be available. In other words, the AAC Gen can not get the crew out of Blackout. The #1 EDG must be manually started to meet the critical task.
BOP E. IF AAC Gen is available, THEN perform the following:
- 1) Energize vital bus using ES Electrical System Operation (1107.002), "Placing Alternate AC Generator on bus A3 (A4)"
section, while continuing with this procedure.
- 2) GO TO step 3.
F. IF AAC Gen is not available, THEN perform the following:
a) IF P36B MOD was transferred, THEN dispatch an operator to perform Attachment 3, Makeup Pump P36B Alignment to Operating EDG, while continuing with this procedure.
- 3) IF SG press associated with de-energized ATM Dump ISOL is > 1040 psig, THEN as time permits, dispatch an operator with a radio to hand jack associated ATM Dump CNTRL to maintain SG press 1000 to 1040 psig. (Refer to Alternate Shutdown (1203.002), Exhibit A).
BOP 3. Verify SERV WTR to DG1 and DG2 CLRs open to operating EDGs:
- CV-3806
- CV-3807 BOP 4. Verify a Service Water pump running on each operating DG, after 15-second time delay (P4A, P4B, P4C).
Continued Page 18 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __7/8/9/10__
Event
Description:
__Loss of Offsite Power / #2 EDG Failure________________________
__P-7A EFW Pump trips on trip throttle linkage failure / Restore EFW Flow with P-7B when
__#1 EDG is recovered / #1 EDG fails to auto start________________________________
_Continued________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: This page is from 1107.002 for placing the AAC Generator onto A-4.
NOTE: A Service Water pump will not automatically start when an AAC Gen is supplying the bus. The BOP will have to manually start P-4C.
BOP 38.0 Placing Alternate AC Generator (2K9) on Bus A4 38.1 IF in Mode 1 - 4, AND Bus A3 and A4 will be crosstied, THEN ENTER TS 3.8.9 Condition A.
BOP 38.2 PLACE DG2 Output (A-408) in PULL-TO-LOCK.
BOP 38.3 ENSURE A2 Feed to A4 (A-409) open.
BOP 38.4 IF Alternate AC Generator is NOT supplying bus A3, THEN ENSURE A3-A4 Crossties (A-310 and A-410) open.
BOP 38.5 CHECK A4 L.O. RELAY TRIP (K02-B7) clear.
BOP / 38.6 REQUEST Unit 2 CRS/SM perform the following:
SRO 38.6.1 START Alternate AC Generator (2K9) 38.6.2 CLOSE AAC Generator to A3/A4 (2A-901).
N/A 38.7 IF ES is actuated, THEN:
38.7.1 OBTAIN CRS/SM permission to override ES.
38.7.2 Momentarily DEPRESS ES Electrical Alignment MAN PB on C16.
BOP 38.8 PLACE A3-A4 Crossties (A-310 and A-410)
Synchronize switch to ON.
BOP 38.9 WHEN Unit 2 reports Alternate AC Generator is ready for loading, THEN CLOSE A4-A3 Crosstie (A-410).
BOP 38.10 PLACE A3-A4 Crossties (A-310 and A-410)
Synchronize switch to OFF.
BOP 38.11 COORDINATE with Unit 2 to ensure Alternate AC Generator is not overloaded when starting loads on bus A4.
BOP 38.12 IF directed by CRS, THEN START Service Water Pump P-4B or P-4C per 1104.029, Service Water and Auxiliary Cooling System or applicable Emergency Operating Procedure.
Continued Page 19 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __7/8/9/10__
Event
Description:
__Loss of Offsite Power / #2 EDG Failure________________________
__P-7A EFW Pump trips on trip throttle linkage failure / Restore EFW Flow with P-7B when
__#1 EDG is recovered / #1 EDG fails to auto start________________________________
_Continued________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE: (Back to EOP) If Instrument Air pressure is low, the ATC will direct the NLO to control steam generator pressure using local control of the ADVs.
ATC 5. Actuate MSLI for both SGs AND verify proper actuation and control of EFW and MSLI (RT-6):
A. Check Instrument Air Header Press > 60 psig.
BOOTH A. Operate ATM Dump CNTRL valves in HAND to minimize cycling and conserve Instrument Air.
ATC 5. Actuate MSLI for both SGs AND verify proper actuation and control of EFW and MSLI (RT-6):
B. Check Instrument Air to ATM Dump CNTRL valves remains available.
ATC / B. IF Instrument Air to ATM Dump CNTRL valves is lost, THEN:
BOOTH
- 1) IF ATM Dump ISOL valve is de-energized, THEN dispatch an operator with a radio to hand jack associated ATM Dump CNTRL valve to establish SG press to maintain 1000 to 1040 psig. (Refer to Alternate Shutdown (1203.002), Exhibit A).
- 2) IF ATM Dump ISOL valve is energized, THEN establish SG press control using ATM Dump ISOL valve in MANUAL.
a) Dispatch an operator with a radio to place ATM Dump CNTRL valve on hand jack and fully open. (Refer to Alternate Shutdown (1203.002), Exhibit A).
b) Maintain SG press 1000 to 1040 psig using ATM Dump ISOL valve.
Page 20 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __7/8/9/10__
Event
Description:
__Loss of Offsite Power / #2 EDG Failure________________________
__P-7A EFW Pump trips on trip throttle linkage failure / Restore EFW Flow with P-7B when
__#1 EDG is recovered / #1 EDG fails to auto start________________________________
_Continued________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE:
ATC 6. Check RCS press remains ³ 1700 psig AND PZR level remains ³ 30".
BOP 7. Isolate Letdown by closing either:
- Letdown Coolers Outlets (RCS):
- CV-1214 CV-1216 ATC 8. Check OP and STBY HPI pumps off.
BOP 9. Place RCP Seals Bleedoff (Alternate Path to Quench Tank) controls in CLOSE:
- SV-1270
- SV-1271
- SV-1272
- Close RCP Seal Bleedoff (Normal) Return (CV-1274)
- Close RCP Seal Bleedoff (Normal) from P32A/B/C/D:
- CV-1270
- CV-1271
- CV-1272
- CV-1273 Continued Page 21 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __7/8/9/10__
Event
Description:
__Loss of Offsite Power / #2 EDG Failure________________________
__P-7A EFW Pump trips on trip throttle linkage failure / Restore EFW Flow with P-7B when
__#1 EDG is recovered / #1 EDG fails to auto start________________________________
_Continued________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE:
ATC 11. IF PZR level is ³ 55", THEN verify Proportional Control Pressurizer Heaters operating in AUTO.
- 12. Verify the following handswitches in PULL-TO-LOCK:
- A1 and A2 feeder breakers Bus A1 Bus A2 BOP A-111 A-211 A-112 A-212 A-113 A-213
- H1 and H2 feeder breakers Bus H1 Bus H2 H-13 H-23 H-14 H-24 H-15 H-25
- Condensate Pumps:
o P2A ATC o P2B o P2C
- ICW Pumps:
o P33A o P33B o P33C Continued Page 22 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __7/8/9/10__
Event
Description:
__Loss of Offsite Power / #2 EDG Failure________________________
__P-7A EFW Pump trips on trip throttle linkage failure / Restore EFW Flow with P-7B when
__#1 EDG is recovered / #1 EDG fails to auto start________________________________
_Continued________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE:
- 13. Place OP or STBY HPI pump in service as follows:
ATC A. Verify RCP Seal INJ Block (CV-1206) closed.
B. Close RCS Makeup Block (CV-1233 or CV-1234).
BOP C. Verify BWST T3 Outlet to OP HPI pump (CV-1407 or CV-1408) open.
D. Start AUX Lube Oil pump for OP or STBY HPI pump.
E. Start OP or STBY HPI pump.
F. Stop AUX Lube Oil pump.
G. Operate HPI Block valve associated with OP HPI pump (CV 1220 or CV 1285) as necessary to maintain PZR level > 55".
ATC 14. Restore Seal Injection as follows:
A. Check Instrument Air Header Press greater than 60 psig.
A. Perform the following:
SRO 1) Dispatch an operator to LNPR to close Seal INJ CV-1207 Inlet (MU-1207-1).
- 2) Place RCP Seal INJ Block (CV-1206) in OVRD AND open.
- 3) Direct dispatched operator to slowly (over a period of two SRO minutes) throttle open Seal INJ CV-1207 Bypass (MU-1207-3) until RCP Seals Total INJ flow is 8 to 12 gpm.
SRO 4) Record current time for reference in step 85:
- 5) GO TO step 15.
Continued Page 23 of 41
Appendix D Scenario Outline Op-Test No.: __1__ Scenario No.: __5__ Event No.: __7/8/9/10__
Event
Description:
__Loss of Offsite Power / #2 EDG Failure________________________
__P-7A EFW Pump trips on trip throttle linkage failure / Restore EFW Flow with P-7B when
__#1 EDG is recovered / #1 EDG fails to auto start________________________________
_Continued________________________________________________________________
Time Position Applicants Actions or Behavior EXAMINER NOTE:
ATC 15. Check ESAS ACTUATION alarms clear on K11.
BOP 16. Check Spent Fuel Pool cooling in service.
NLO 16. Perform Unit 1 Spent Fuel Pool Emergencies (1203.050) in conjunction with this procedure. [INPO IER L1 11-2]
BOP 17. Maximize RB cooling (RT-9).
ATC 18. Check adequate SCM.
ATC 19. Check RCS T-cold ³ 540°F.
ATC 20. Check SG press ³ 900 psig.
ATC 21. Check CET temps < 610°F.
ATC 22. Check SG tube integrity (RT-18).
End of Scenario Page 24 of 41
Appendix D Scenario Outline 1102.002 CAUTION
- DT between FW inlet temperature to SGs and SG downcomer temperature is maintained less than 350°F to avoid thermal shock.
- When Main Steam is heating E-2 Feedwater Heaters, E-2 and Heater Drain Tank T-40 levels can fluctuate undesirably due to the Main Steam supply piping arrangement. Minimizing Main Steam heating and utilizing SU Boiler as much as possible will reduce undesired fluctuations.
CR-ANO-1-2003-1229 17.14ENSURE main steam is aligned to FW heaters (E-2A and E-2B) per 1106.016, Aligning Main Steam to FW Heaters (E-2A and E-2B) During Plant Startup and Shutdown section.
NOTE MFWP minimum speed is typically near 3000 rpm.
17.15 Starting MFWP to minimum speed:
17.15.1 PRIOR to opening FW Pump recirc, ENSURE Main Steam is aligned to E-2s.
17.15.2PERFORM ONE of the following sections of 1106.016, for the pump to go into service first, while NOT placing the MFWP into service:
- Startup of MFWP (P-1A) to Minimum Speed
- Startup of MFWP (P-1B) to Minimum Speed (CIRCLE one)
A / B MFWP minimum speed _________ rpm.
17.16 WHEN the second condensate pump is running, THEN PERFORM the following in the order listed:
{4.2.4}
CAUTION Placing MFP H/A station in auto prior to being called for in Turbine S/U and Power Escalation to 25% section of this procedure could result in MFP oscillations.
17.16.1PERFORM 1106.016, Placing MFWP Into Service section to place a MFP into service and stop the Aux Feed Pump.
17.16.2PERFORM Attachment E, Anticipatory Reactor Trip System (ARTS) Reset for the first MFW Pump.
Page 25 of 41
Appendix D Scenario Outline NOTE
- With the operating MFWP H/A station in HAND, discharge pressure is controlled between 1025 and 1075 psig to ensure SGs are fed following a reactor trip when the 100 psig turbine bypass valve bias is instated.
- Plant Computer points P2832 & P2834 (for P-1A) and P2833 & P2835 (for P-1B) have sufficient upper range for proper discharge pressure points monitoring.
- MFWP setback on high discharge pressure setpoint: 1275 psig (two transmitters).
- MFWP trip on high discharge pressure setpoint: 1350 psig (2 of 3 transmitters).
- When controlling MFWP in MANUAL, MFWP discharge pressure is a critical parameter per EN-OP-115, Conduct of Operations. (CR-ANO-1-2018-3238, CA-11, CAPR)
- Concurrent Verification of MFWP operation at this time is used since the plant is vulnerable to a Reactor Trip on single failure of the operating MFWP.
(CR-ANO-1-2018-3238, CA-11, CAPR)
- If main feedwater block valve is closed, MFWP H/A station MV reads valve DP (0-100 psi).
MFWP H/A station MV should indicate maximum across both MFWP H/A stations when maintaining MFWP discharge pressure between 1025 and 1075 psig.
- Raising MFWP speed with main feedwater block valve closed will raise MFWP discharge pressure. Monitoring of diverse/multiple indications is used when manually controlling MFWP in MANUAL. (CR-ANO-1-2018-3238, CA-11, CAPR)
- At low power levels, main feed pump recirc controller maintains a minimum suction flow of 2000 gpm. Few MFWP speed adjustments are needed until feedwater flow exceeds 2000 gpm and recirc control valve is closed.
17.16.3 IF CRS directs control of the in-service MFWP in MANUAL, THEN ENSURE the following:
- In-service MFWP HAND/AUTO station in HAND
- BOTH Main Feedwater Block valves closed (CV-2625 and CV-2675)
- MFWP speed adjusted to maintain discharge pressure between 1025 and 1075 psig. (CR-ANO-1-2018-3238, CA-11, CAPR)
Concurrent Verifier:
Page 26 of 41
Appendix D Scenario Outline 17.16.4 IF CRS directs control of the in-service MFWP in AUTO, AND power escalation to greater than 10% will commence, THEN:
NOTE
- POS reads MFP demand.
- If Main Feed Block valve is closed, MV reads valve DP (0-100 psi).
- Bumpless transfer logic for the MFPs does NOT drive the station input (FW40) to match HAND demand (FW42) when the MFP is in HAND. Tracking action occurs but is not visible from panel or computer indications.
A. IF B Main Feed Pump (P-1B) is in service, THEN ENSURE A Main Feed Pump (P-1A) is tripped.
B. SELECT MEAS VAR on the following and MONITOR SU valve DPs:
- A MFW Pump H/A station
- B MFW Pump H/A station C. While monitoring flow and valve positions, ADJUST the in-service pump speed until the lowest DP is 70 - 80 psid.
D. DEPRESS AUTO pushbutton.
E. CHECK MFP controls lowest DP 60 - 80 psid.
F. MONITOR the following Polisher parameters:
- Polisher DP (63 psid max)
- Polisher flow (1500 to 3550 gpm)
- Polisher resin trap DP (10 psid max)
Page 27 of 41
Appendix D Scenario Outline 17.17 PRIOR to exceeding 2% reactor power:
17.17.1ENSURE SG drains are isolated per Attachment M, Isolating Steam Generator Drains.
17.17.2ENSURE TS 3.6.3 Condition A entry removed from eSOMs LCO Tracker database.
NOTE
- Reactor Demand H/A station output follows actual neutron power when Diamond is in MANUAL.
- During power escalation in manual, Reactor Power is a critical parameter per EN-OP-115, Conduct of Operation.
- As power is raised, Tave will rise approximately 2°F per percent power, causing RCS inventory to swell. Effect on RCS pressure is minimized by maximizing letdown flow, raising power gradually, and coordinating pressurizer level adjustments with changes in plant power.
17.18 WHEN a MFP is in service, THEN BEGIN reactor power escalation to 6 to 10%.
17.19 Preparation for turbine startup:
NOTE TG Lube Oil Cooler (E-15B) is the preferred cooler to place into service to prevent the cooler from becoming a trap for contaminants.
17.19.1ENSURE a TG Lube Oil Cooler (E-15A or E-15B) is in service (manual valves aligned) with temperature control established at Main Lube Oil Temp Control (TIC-4026) on C19.
17.19.2ENSURE Generator Hydrogen coolers are in service (manual valves aligned) with temperature control established at Gen H2 Temp Control (TIC-4018) on C19.
CAUTION Temperature transients associated with the Hydrogen Seal Oil System during turbine startup and roll can cause pipe rust and scale to be released which can quickly lead to high differential pressures across seal oil filters. This can be severe enough to cause a loss of seal oil pressure at the seals and subsequent loss of generator hydrogen. A dedicated operator can provide early warning of high differential pressure on seal oil filters.
17.19.3Locally MONITOR the following hydrogen seal oil system parameters until system parameters stabilize:
- Temperatures
- Oil pressures
- Filters (may need swapping)
Page 28 of 41
Appendix D Scenario Outline 17.20BEGIN turbine startup per 1106.009, Turbine Startup (Warmup & Roll), Turbine Startup, Operator Auto section. Do NOT intentionally roll turbine above 100 rpm until directed by Turbine Startup and Power Escalation to 25% section of this procedure.
NOTE During plant startup, RCS lithium out of spec hours begin to accumulate 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after entry into Mode 1, or upon reaching equilibrium xenon, whichever occurs first. CR-ANO-2-09-3177 17.21 WHEN in Mode 1, THEN:
17.21.1 MAKE a station log entry for entering Mode 1.
17.21.2MAKE a station log entry that RCS lithium is required to be in its control band within next 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, or upon reaching equilibrium xenon (enter time required).
17.21.3MAKE shift turnover sheet entry of time and date that lithium is required to be in spec.
17.21.4 IF CRS/SM directs Diamond Panel to be placed in AUTO, THEN PLACE Diamond Panel in AUTO per 1105.004, Integrated Control System.
NOTE The following indicates RPS trip is armed for loss of MFWPs.
17.22 CHECK following alarms clear at 9% reactor power:
- TRIP ON LOSS OF MFP BYPASSED (K08-F4)
- REACTOR TRIP ON LOSS OF FEEDWATER BYPASS/TROUBLE (K15-B1) 17.23 REVIEW Temp Mod Logbook for acceptability of active Temp Mods in Mode 1.
17.24 IF turbine will be placed in service during this startup, THEN CONTINUE to Turbine Startup And Power escalation To 25% section.
This section has been reviewed and is adequately complete to continue to next section. Reviewed by CRS/SM: Date Concurrence by SM Date 17.24 IF turbine will be placed in service during this startup, THEN CONTINUE to Turbine Startup And Power escalation To 25% section.
This section has been reviewed and is adequately complete to continue to next section. Reviewed by CRS/SM: Date Concurrence by SM Date This section has been reviewed and is complete.
Reviewed by CRS/SM Date Page 29 of 41
Appendix D Scenario Outline 1106.016 15.0 PLACING MFWPS INTO SERVICE 15.1 Initial Conditions:
- CHECK At least ONE MFWP (P-1A or P-1B) at minimum speed.
- CHECK TWO Condensate Pumps running.
NOTE When only 3 RCPs are operating, the MFWP on the loop with 2 RCPs is placed into service first.
15.2 IF only 3 RCPs are operating, THEN PERFORM the following to select which MFWP will be placed into service first:
- IF RCPs P-32A and B are running, THEN SELECT MFWP P-1B to be placed into service first.
- IF RCPs P-32C and D are running, THEN SELECT MFWP P-1A to be placed into service first.
NOTE
- Plant Computer points P2832, P2834 (for P-1A), P2833 and P2835 (for P-1B) have sufficient upper range and are preferred discharge pressure points to monitor.
- MFWP setback on high discharge pressure setpoint: 1275 psig (two transmitters).
- MFWP trip on high discharge pressure setpoint: 1350 psig (2 of 3 transmitters).
15.3To ensure the MFWP to be placed into service first is supplying feedwater, RAISE MFWP speed until associated Startup Control Valves or Low Load Control Valves start to close:
- Startup Valve Loop A (CV-2623)
- Low Load Valve Loop A (CV-2622)
- Startup Valve Loop B (CV-2673)
- Low Load Valve Loop B (CV-2672) 15.4 STOP Aux Feedwater Pump (P-75).
15.5 RESET RPS trips per 1102.002, Plant Startup for the first MFWP, Attachment E, Anticipatory Reactor Trip System (ARTS) Reset.
15.6 CLOSE Aux FW Pump Recirc to E-11A (FW-1).
Page 30 of 41
Appendix D Scenario Outline ATTACHMENT E Page 1 of 6 ANTICIPATORY REACTOR TRIP SYSTEM (ARTS) RESET First Main Feedwater Pump ARTS reset 1.0 CIRCLE MFW Pump started: A / B 2.0 RESET RPS channels as follows:
CAUTION Depressing TRIP switch will trip the channel even if feed pump trip function is bypassed.
- In RPS Channel A Cabinet (C41), using SRO/RO concurrent verification:
A. DEPRESS test switch labeled RESET on contact buffer lower module for the started Main Feedwater Pump.
B. CHECK two red lamps on contact buffer change state (top lit, bottom off).
C. CHECK white lamp MFWP A (B) TRIPPED (for the started MFWP) is dim.
- In RPS Channel B Cabinet (C42), using SRO/RO concurrent verification:
A. DEPRESS test switch labeled RESET on contact buffer lower module for the started Main Feedwater Pump.
B. CHECK two red lamps on contact buffer change state (top lit, bottom off).
C. CHECK white lamp MFWP A (B) TRIPPED (for the started MFWP) is dim.
- In RPS Channel C Cabinet (C43), using SRO/RO concurrent verification:
A. DEPRESS test switch labeled RESET on contact buffer lower module for the started Main Feedwater Pump.
B. CHECK two red lamps on contact buffer change state (top lit, bottom off).
C. CHECK white lamp MFWP A (B) TRIPPED (for the started MFWP) is dim.
- In RPS Channel D Cabinet (C44), using SRO/RO concurrent verification:
A. DEPRESS test switch labeled RESET on contact buffer lower module for the started Main Feedwater Pump.
B. CHECK two red lamps on contact buffer change state (top lit, bottom off).
C. CHECK white lamp MFWP A (B) TRIPPED (for the started MFWP) is dim.
Page 31 of 41
Appendix D Scenario Outline ATTACHMENT E Page 2 of 6 3.0Performing independent verification of ARTS reset for first MFW Pump placed into service:
3.1 CIRCLE MFW Pump started: A / B
- In RPS Channel A Cabinet (C41), independently CHECK:
- Contact buffer for the started Main Feedwater pump TOP red lamp is lit.
- White lamp MFWP A (B) TRIPPED (for the started Main Feedwater pump) is dim.
- In RPS Channel B Cabinet (C42), independently CHECK:
- Contact buffer for the started Main Feedwater pump TOP red lamp is lit.
- White lamp MFWP A (B) TRIPPED (for the started Main Feedwater pump) is dim.
- In RPS Channel C Cabinet (C43), independently CHECK:
- Contact buffer for the started Main Feedwater pump TOP red lamp is lit.
- White lamp MFWP A (B) TRIPPED (for the started Main Feedwater pump) is dim.
- In RPS Channel D Cabinet (C44), independently CHECK:
- Contact buffer for the started Main Feedwater pump TOP red lamp is lit.
- White lamp MFWP A (B) TRIPPED (for the started Main Feedwater pump) is dim.
Performed by: _____________________________________
IV by: _____________________________________Date/Time: __________/_________
Page 32 of 41
Appendix D Scenario Outline RT-21 CHECK EDG OPERATION PAGE 1 OF 1
- 1. ENSURE running EDG(s) supplying associated ES bus(es) with proper voltage, frequency, and loading:
- 4100 to 4200 V
- 59.5 to 60.5 Hz
- Less than or equal to 2750 KW
- 2. DISPATCH an operator to monitor EDG operation.
- 3. ENSURE SERV WTR to DG1 and DG2 CLRs open to running EDG(s):
- CV-3806
- CV-3807
- 4. IF Service Water can NOT be aligned to EITHER DG, THEN ESTABLISH criteria to place affected DG into LOCKOUT.
- 5. IF EDG(s) failed to start, THEN:
A. NOTIFY CRS/SM of EDG status.
B. OBSERVE associated EDG alarms clear:
DG1 DG2 K01-A2 K01-A4 K01-B2 K01-B4 K02-B6 K02-B7 C. IF associated EDG alarms clear, THEN:
- 2) ATTEMPT to start associated EDG at C10.
END Page 33 of 41
Appendix D Scenario Outline RT-6 PROPER MSLI AND EFW ACTUATION AND CONTROL VERIFICATION PAGE 1 OF 6
- 1. ENSURE MSLI actuation indicated for affected SG on C09:
Train A: Train B:
- Bus 1
- Bus 1
- Bus 2
- Bus 2
- 2. ENSURE EFW actuation indicated on C09:
Train A: Train B:
- Bus 1
- Bus 1
- Bus 2
- Bus 2
- 3. ENSURE affected SG MSIV, Main Feedwater Isolation, Main Feedwater Block, Low Load, and Startup valves closed:
SG A SG B CV-2691 MSIV CV-2692 Main CV-2680 Feedwater CV-2630 Isolation Main CV-2625 Feedwater CV-2675 Block CV-2622 Low Load CV-2672 CV-2623 Startup CV-2673
- 4. IF SG is NOT depressurizing, THEN ENSURE affected SG ATM Dump Control System operating to maintain SG press 1000 to 1040 psig:
SG A SG B ATM Dump CV-2676 CV-2619 ISOL ATM Dump CV-2668 CV-2618 CNTRL Page 34 of 41
Appendix D Scenario Outline PROPER MSLI AND EFW ACTUATION AND CONTROL VERIFICATION PAGE 2 OF 6
- 5. IF EITHER vector isolation criterion is met:
- DP between SGs is greater than 150 psig and BOTH SGs less than 600 psig, THEN ENSURE EFW ISOL and EFW CNTRL valves to BAD SG closed:
SG A SG B CV-2627 CV-2670 ISOL CV-2620 CV-2626 CV-2645 CV-2646 CNTRL CV-2647 CV-2648 NOTE Table 1 contains EFW fill rate and level bands for various plant conditions.
- 6. Ensuring proper flow response:
- IF BOTH SGs are less than or equal to 600 psig AND DP is less than or equal to 150 psig, THEN ENSURE flow provided to BOTH SGs from EFW or CFW.
- 7. IF SCM is NOT adequate, THEN:
A. SELECT Reflux Boiling setpoint for the following:
- Train A
- Train B (7. CONTINUED ON NEXT PAGE)
Page 35 of 41
Appendix D Scenario Outline PROPER MSLI AND EFW ACTUATION AND CONTROL VERIFICATION PAGE 3 OF 6
- 7. (Continued)
NOTE
- Table 2 contains examples of less than adequate/excessive feed flow.
- A SG is considered available if it has the capability to be fed and steamed.
B. ESTABLISH and MAINTAIN SG levels at 370 to 410 inches using EFW or CFW as follows:
- 1) IF BOTH SGs are available, THEN:
a) ENSURE SG level rising until 370 to 410 inches is established.
b) IF feed flow is less than adequate, THEN CONTROL flow to applicable SG manually to maintain greater than or equal to 340 gpm to applicable SG until level is 370 to 410 inches.
c) IF feed flow is excessive AND greater than 340 gpm to EITHER SG, THEN
- 2) IF only ONE SG is available, THEN FEED available SG manually at greater than or equal to 570 gpm until SG level is 370 to 410 inches.
- 3) IF feed flow is being controlled manually AND SG press drops below 720 psig due to EFW/CFW flow-induced overcooling, THEN:
a) CONTINUE feeding at required minimum rate.
b) On Initiate module in EACH EFIC cabinet, PLACE each SG Bypass toggle switch in BYPASS and RELEASE to bypass MSLI:
- C37-3
- C37-4
- C37-1
- C37-2 (7. CONTINUED ON NEXT PAGE)
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Appendix D Scenario Outline PROPER MSLI AND EFW ACTUATION AND CONTROL VERIFICATION PAGE 4 OF 6
- 7. (Continued) c) PLACE applicable EFW CNTRL valves in VECTOR OVERRIDE:
SG A SG B CV-2645 P7A CV-2647 CV-2646 P7B CV-2648 d) PLACE applicable EFW ISOL valves in MANUAL:
SG A SG B CV-2627 P7A CV-2620 CV-2670 P7B CV-2626
- 8. IF SCM is adequate, THEN:
A. ESTABLISH and MAINTAIN applicable SG level band per Table 1 using EFW or CFW.
CAUTION Excessive EFW/CFW flow can result in loss of SCM due to RCS shrinkage.
NOTE
- Table 2 contains examples of less than adequate/excessive feed flow.
- CETs are expected to rise until natural circ conditions are established. If manually controlling EFW/CFW flow, additional flow might not be necessary to prevent rising CETs until natural circ is established.
B. IF feed flow is less than adequate OR feed flow is excessive, THEN CONTROL flow to applicable SG manually as necessary to ensure the following:
- MAINTAIN sufficient flow to prevent rise in CET temp.
- MAINTAIN continuous flow until applicable level band is reached.
- MAINTAIN sufficient flow to ensure SG level is either stable or rising until applicable level band is reached.
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Appendix D Scenario Outline PROPER MSLI AND EFW ACTUATION AND CONTROL VERIFICATION PAGE 5 OF 6
- 9. IF a Condensate pump is running, THEN DISPATCH an operator to close bad SG Startup FW Control Valve Bypass while continuing:
- 10. IF ALL RCPs are off, THEN MONITOR for primary to secondary heat transfer as indicated by ALL of the following:
- T-cold tracking associated SG T-sat (Fig. 2)
- T-hot tracking CET temps
- T-hot/T-cold DT stable or dropping
- 11. MONITOR applicable alarms:
- IF CFW is in service, THEN SPDS PROGRAMMABLE ALARM NO.1 (K09-D1).
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Appendix D Scenario Outline PROPER MSLI AND EFW ACTUATION AND CONTROL VERIFICATION PAGE 6 OF 6 Table 1 EFIC Automatic Level Control Setpoints Condition Level Band Automatic Fill Rate Any RCP running 20 to 40 No fill rate limit All RCPs off and Natural Circ selected 300 to 340 2/min to 8/min All RCPs off and Reflux Boiling selected 370 to 410 2/min to 8/min Table 2 Examples of Less Than Adequate EFW/CFW Flow Indications
- SG level less than 20 inches and no flow indicated
- All RCPs off and EFIC level not trending toward applicable level band Examples of Excessive EFW/CFW Flow Indications
- SG press drops greater than or equal to 100 psig due to flow induced overcooling
- SCM approaching minimum adequate due to flow induced overcooling
- EFW CNTRL or CFW valve open with associated SG level greater than applicable setpoint level band END Page 39 of 41
Appendix D Scenario Outline RT-9 MAXIMIZE RB COOLING PAGE 1 OF 1
- 1. ENSURE ALL four RB Cooling Fans running:
- VSF1A
- VSF1C
- VSF1B
- VSF1D
- 2. OPEN RB Cooling Coils Service Water Inlet/Outlet valves:
- CV-3812/CV-3814
- CV-3813/CV-3815
- 3. UNLATCH key-locked Chiller Bypass Dampers:
- SV-7410
- SV-7412
- SV-7411
- SV-7413 END Page 40 of 41
Appendix D Scenario Outline RT-18 CHECK SG TUBE INTEGRITY
- 1. Check the following indications:
- None of the following radiation monitor indications rising OR in alarm:
- Main Condenser process monitor (RI-3632)
- Either OTSG N-16 Gross Detector:
¨ RI-2691
¨ RI-2692
- Either Steam Line High Range Radiation Monitor:
¨ RI-2681
¨ RI-2682
- No report from Nuclear Chemistry that SG tube leak exists.
- No rise in unidentified RCS leakage accompanied by:
- Higher than expected SG level
- Lower than expected FW flow rate END Page 41 of 41