ML20041A271
| ML20041A271 | |
| Person / Time | |
|---|---|
| Site: | Summer  |
| Issue date: | 05/18/1981 |
| From: | SOUTH CAROLINA ELECTRIC & GAS CO. |
| To: | |
| Shared Package | |
| ML20041A267 | List: |
| References | |
| EOP-2, NUDOCS 8202190351 | |
| Download: ML20041A271 (14) | |
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SOUTH CAROLINA ELECTRIC AND GAS COM? ANT TIRGIL C. SUMMER NUCLEAR STATION NUCLEAR OPERATIONS YJCL%R OPE 7ARONS coer no.....j.s............
MERG35CT OPERATING PROCEDURE 30P-2 MAIN ST3AM LINE OR F33DWATER LINE 3REAK WITHOUT SAF3TT INJECTION
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REVISION 1 NOVEMBER 4,1980 NtAS:t a
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PAGE i REVISION t 11/04/80
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C LIST OF EFFECTIVE PAGES PAGE REVISION 1
1 11 1
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3 1
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' l E0P/2 PAGE'11 REVISION 1
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11/04/80
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TA3LE OF CONTINTS
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PAGE List of Effective Pages i
1.0 Purpose 1
2.0 References and Glossary 1'
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2.1 References 1
2.2 Glossary 1
23 Abbreviations 1
3.0 Symptoms 3
4.0 Automatic Actions 4
5 0 Immediate Operator Actions 5
6.0 Pollow-Up Actions 6
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7.0 Final C r$1tione 10 e
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j 30P-2 PAGE 1
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REVISION t 11/04/80 1.0 PURPOSE 1.1 The purpose of this procedure is to establish the conditiora, symptoms, automatic actions, immediate operator actions and follow-up action to be taken in the event of Main Steam line or-Feedvater line break without safety injection initiation.
2.0 REFERENCES
AND GLOSSART 2.1 References.
2.1.1 T.
C'.
Sonner Nuclear Station Technical Specificationar.
2.1.2 30P-1, Safety Injection.
2.13 GOP-4, Power Operation.
2.t.4 00P-5, Plant Shutdown from Minimum Load to Hot Standby.
2.1 5 GOP-6, Plant Shutdown from Hot Standby to Hot Shutdown.
2.1.6 GOP-7, Plant Shutdown from Hot Shutdown to Cold Shutdown.
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2.1.7 SOP-201, Main Steam System.
2.1.8 Feedwater System.
i 2.2 Glossary.
2 2.1 Intermediate secondary line rupture - lover bounded by those signs in which the normal plant control systems are unable to maintain approximate nominal plant oporating corditions and Safety Injection has not been initiated.
23 Abbreviations.
l 271 EIT - Boron Injection Tank.
232 DA - Deserstor.
233 DW - Ded neralised Vater.
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307-2 PAG 3 2 83YISICK 1 11/04/80 234 3FP - Emergency Feedvater Pump.
235 3SF - Engineered Safety Features.
236 3SFLS - Engineered Safety Features Loading Sequence.
237 FSAR -
T. C. Summer Nuclear Station Final Safety Analysis Report.
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239 FWF - Feedwater Flov 2 310 FWI27 - Feedwater Isolation Bypass Yalve.
2 3 11 FWIT - Feedwater Isolation Yalve.
2 3 12 FWP - Feedwater Pump.
2 3 13 ETAC - Heating, Tentilating, and Air Conditionin'g.
231413-Intermediate Building.
2 3 15 MS - Main Stesa 2 3 16 MSIT - Main Steam Isolation Yalve.
~l 2 317 PA - Public Address 2 3 18 PZR - Pressuriser.
2 3 19 R3 - Reactor Ikilding.
2 3 20 R3Ctr - Reactor Building Cooling Unit 2 3 21 RCS - Reactor C,Jolant Systea 2 3 22 RER - Residual Heat Renoval.
2 3 23 S/G - Steam Generator.
l 2 3 24 SI - Safety Injection.
2 3 25 SIS - Safety Injection System.
2 3 26 STF - Steam Flov l
2 3 27 Tavg - Average reactor coolant temperature.
2 3 28 Tref - Reference Temperature (based on turbine load).
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2 3 29 iP - Difference in pressure.
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r 30P-2 PAGE 7 REVISION'1 11/04/80 3 0.STMPTOMS 31 Decreasing S/G level, resulting in steam generator level deviation alarm and steam generator lov level alarm.
32 FW pump speed. increases to maximum speed (4630 rpm) and condensate pump discharge flow increases to maximum (8800 gyn).
3 3~
Decreasing main condenser 3 level (LI-3010-CO), resulting in condenser hotwell low level alarm.
34 Decreasing condensate storage tank level (LI-3621, 3631-00),
resulting in condensate storage tank, low / low-low level alarm.
35 Increasing RB temperature and pressure, if the riipture is inside the reactor building.
36 RB cooling unit drain high flow alarm, if the rupture is inside the reactor building.
37 Reactor Buidling sump high level alarm, if the rupture is inside the reactor building.
High intermediate building main exhaust fan discharge temperature h
38 alarm, if the rupture is 1.n the intermediate, building.
NOT3:
The'following symptoms (3 9-3 10) any additionally be used to further determine if the rupture is a feedline rupture.
39 PW line break alarm.
310 Steam generator flow mismatch FWF > STP alarm.
NOT3:
The following symptoms (3 11-3 15) may additionally be ussd to further determine if the rupture is a steamline rupture.
311 Increased S/G steam flow one or more S/G's.
3 12 Steam generator flow mismatch ST? > FWF alarm.
313 Slowly decrossing MS line pressure or S/G pressure in one or more loops.
3 14 Decreasing loop TAVG in one or more RCS loops, resulting in A
high/ low deviation alarm, and RCS lov RCST{G-TT yg a arm. REF A
315 Increasing reactor power level, which may result in a pcwer range
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high fluz high setpoint alarm.
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I 30P-2
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PAGE 4 REVISION 1 11/04/80 3 16 3=nk D fun rod withdrawal interlock alarm.
3 17 Decreasing pressuriser level, resulting in pressurizer level control signal high/ low deviation alara, and pressurizer level control signal. low block heaters. isolate letdown alarm.
318 Decreasing pressuriser pressure, resulting in pressuriser ml pressure control signal low backup heaters on alars, and i
pressuriser high/ low pressure alarm.
40 AUTOMATIC ACTIONS
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4.1 Automatic makeup to the main condenser hotveu, upon condenser hotwen low level alarm.
42 Automatic makeup to the condensate storage tank, upon condensate storage tank low / low-low level alara.
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43 R3 sump pumps start automaticany, upon reactor building sump l
high level alara.
NOT3:
The following automatic actions (4 4-4 5) may additionally take place during a steaaline rupture.
4.4 Control rods step out to compensate for the TAVG decrease, if rod control is in automatic, and Bank D control rods are less than 220 steps withdrawn.
45 Charging flow automaticany increases, due 'to the decreasing pressuriser level, resulting in automatic makeup to the YCT.
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50TE:
With high s/s flow from z/3 steam headers in l
conjunction with low-low TAVG from 2/3 RCS loops, l stenaline isolation will be initiated.
l ROTE:
The rollowing automatic actions may occur 5 minutes or longer after the onset of the accident condition.
4.6 One of the following reactor trips may occur.
A.
Overpower T reactor trip.
3.
Overtemperature T reactor trip.
C.
Steam generator low-low level reactor trip.
D.
Pressurizer high pressure reactor trip.
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REVISION 1 11/04/80 t
47 Both motor driven emergency feed pumps start automatically, when there is 2/3 steam generator low-lov level signals in any steam generator.
NOT3:
If no operator action is taken to prevent the necessity of a safety injection, one of the following safety injections will,be actuated.
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i 1.
Pressuriser Lov Pressure Safety Injection Reactor Trip.
2.
Low Stemaline Pressure S.I. Reactor Trip.
J.
Steam Generator Steamline for High.
AP S.I. Reactor Trip.
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50 IMMEDIATE OPERATOR ACTIONS CAUTION:
Jo ain &s plant parameter shoulf be relieti upon for evaluating the plant status un(er a cident conditions.
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Redundant channels should be checked for consistency while performing the steps of this procedure.
NOTE:
If an automatic reactor trip or safety injection
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actuation has occured proceed to 30P-5 (for reactor trip)
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or 30P-1 (for safety injection).
If parameters are approaching or at the reactor trip or safety injection setpoint manually initiate the required protective function and proceed to 30P-5 (for reactor trip) or 30P-1 (for safety injection) as required.
51 Evaluate plant parameters inorder to determine type rupture and plant conditions.
52 Announce the type ripture over the site PA system, and give l
location if known.
- 53 I7 time and conditions permit ernduce turbine generator lead to a no' load condition as soon as reasonably possible by rotating the l
load limit set potentiometer in the decre u e (counter-clockwise) l direction.
i 54 When the turbine generator has been unloaded or when conditions are approaching a reactor trip setpoint manually trip the reactor from the main control board and proceed to 20P-5 55 Shut the MS line isolation valves and check shut the MS line bypass isolation valves.
551 PVM-2801A and PTM-2869A for S/G A.
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552 PVM-28013 and PYM-28693 for S/G 3.
553 PVM-2801C and PYM-2869c for S/G c.
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e 30P-2 PAGE 6 REVISION 1 11/04/80
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56 Start or verify running the motor driven emergency feedvater pumps.
CAUTION:
Watter should not be permitted to be introduced to a steam generator that has boiled dry, until it has been cooled down.
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57 Shut or verify shut the S/G 7v isolation valves and Fw isolation f
valve bypass valves.
l 5 7.t PYG-1611 A and PYT-167BA for S/G A.
5 7 2, PYG-16113 and PYT-16783 for S/G 3.
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573 PYG-1611C and PYT-1678C for S/G C.
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58 If the MS line pressure or S/G pressure indications for 3 and/or C
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S/G's are still decreasing then shut the MS loop 3 to EP turbine valve MYG-2802A-MS and/or the'MS loop C to EP turbine v,alve MYG-28023-MS.
6.0 FOLLOW-UP ACTIONS (j -
NOT3:
Emergency operating procedure actions may be terminated whenever the break has been located, isolated and normal control functions restored.
NOT3:
Check or initial steps as indicated when they have been completed.
6.1 Verify completion of Immediate Opurator Actions.
6.2 Record the following data to aid in identifying the faulted S/G.
- 6.2.1 S/G Pressures S/G A PI-474 PI-475 PI-476
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S/G B PI-484 PI-485 PI-486 S/G C PI-494 PI-495 PI-496 6.2.2 S/G Levels S/G A LI-474 LI-475 LI-476 S/G B LI-484 LI-485 LI-486 S/G C LI-494 LI-495 LI-496 6.2 3 Emergency Peedvater Flow S/G A PI-3*41
.S/G 3 FI-Z.1
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S/G C ?I-3581 O
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1 30P-2 PAGE 7 REVISICII 1
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'11/04/80
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50T3:
Emergency feedvater flow may have been automatically t
isolated from the faulted loop due to high flow.
63 Determine the location of the fault.
CAUT105:
High pressure steam and, high temperature and high pressure feedvater are personnel hazards; appropriate i
care should be-taken when searching for the steamline or feedline ruptures.
, 6.J.1 A low steam generator pressure as compared to the other-two steam generators indicates that loop as faulted.
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'652-A decreasing steam generator level as compared to the other two steam generators indicates that loop as fanited.
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~ 633 ~ If all steam generator pressures are approximately the same and/or are increasing after main steam and feedvater isolation, the fa1ilt may be down stream of the MS line i
isolation valves or on a feedvater line.
This can be verified by visual observation by an outside operator.
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CAUT105:
If all af e's are depressurized or depressurizing
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DO N0f isolate emergency feedvater to any S/G until the faulted loop is identified.
6.4 Isolate the faulted S/G loop.
NOT3:
If the rupture has already been isolated due to closure of the MS line isolation valves and the S/G PW isolation valves this step may be omitted.
6.4.1 Stop Emergency Peedvater flow to the faulted S/G.
A.
Reset all 37 isolation from the turbine driven pu=p to S/G's and 3F isolation from motor driven pump to S/G's valves by going to R383T on both Train A and Train 3 EP flow control reset svitches.
3.
Place all 37 isolation from the turbine drived pum to S/G's and EP isolation from moter driven pump to S G's in manual.
1).
I?Y-3536 and I77-3531 for S/G A.
2).
IPY-35A6 and I?7-3541 for S/G 3.
3).
I?Y-3556 and I?Y-3551 for S/G c.
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PAGE 8 REVISICN 1 11/04/80 C.
Close the respective IM manual controller to the faulted S/G.
1).
I?Y-3531 and I?Y-3536 for S/G A.
2).
IFY-3541 and,IFY-3546 for S/G 3.
3).
ITY-3551 and I77-3556 for S/G C.
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6.4.2 Terify CLOSED or CLOSI the respective MS line isolation valve and MS line bypass isolation valve for the faulted S/G.
A.
PYM-2801A and PYM-2869A for S/G A.
3.
PYM-28013 and PYM-28693 for S/G 3.
C.
PYM-2801C and PYM-2869C for S/G C.
643 Transfer MS line SD/PWR Relief Yalve for the faulted S/G to the POWER RELIEP mode, set the auto-manual controller to MANUAL and CLOSE.
A.
IPV-2000 for S/G A.
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3.
IPY-2010 for S/G 3.
C.
IPY-2020 for S/G C.
CAUTION:
If a 5/G power operated relief valve is stuck open it must be-isolated locally by closing the manual isolation valve.
l ITG-2808A-MS for S/G A, 436 West Penetration Area L
IYG-28083-MS for S/G 3, 436 Intermediate i
. - -- Building IYG-280ac-MS for S/G C, 436 Nast Penetration Area 6.4.4 If S/G 3 or C is faulted C1083 the MS loop 3 (MYG-2802A) or C (MYG-28023) to IP turbine isolation valve.
maintain 25% gency feedvater flow to the non-faulted S/G's to 65 Regulate emerS/G 1evel in the narrow range.
651 Reset all 33 isolation from turbine driven pump to S/G's and EP isolation fres motor driven pump to S/G's valves by goin6
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to RESET on both Train A and Train 3 EP flow contal reset switches.
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PAGE 9 REVISION 1 11/04/80 652 Place all EF isolation from the turbine driven pump /G's to S/G's and EP isolation from motor driven pump to S valves (6 valves), to the respective S/G, in the MANUAL position.
A.
IM-3536 and IFY-3531 for S/G A.
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3.
IFT-3546 and IN-3541 for S/G 3.
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C.
177-3556 and IFT-3551 for s/G c.
6 5.5 Adjust the respective IFY manual controller as necessary.
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A.
177-3536 and IFY-3531 for s/G A.
I77-3546'and IFT-3541 for s/G 3.
3.
C.
IFT-3556 and IFT-3551 for s/G C.
6.6 If feedwater flow in unavailable implement E0P-14 inade'quate
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core cooling concurrently with this procedure.
67 Monitor condensate Storage Tank level.
(l 6.7.1 It condensate pumps are running th.n ensure automatic makeup occurs when the CST low / low-low level alarm sounds.
A.
Condenser hotwell high level alarm.
B.
Flow indication on reject to condensate flow recorder 3019 672 If condensate pumps are not available then fill the condensate storage tank as follove.
A.
Close ITT-643-C0 (local valve, 436 Turbine Building).
B.
Open ITT-668-C0 (local valve, 436 Turbine Building).
C.
Start or verify running domineralized water pump in the water treatment building.
673 If condensate grade water is not available, when CST to EPP low / low-low level alarm is annunciated.
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30P-2 PAGE 10 4
REVISION 1 11/04/80
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CAUTION:
Automatic transfer to service Water Supply for 3mergency Feedvater is actuated on low emergency feedvater suction header pressure.
This may not be fast enough to prevent pump damage and should not be depended on.
A.
Open SV Loop A to motor driven emergency feed pump A E
valve MYG-1001 A and SW Loop A to emergency FW valve MYG-1037A.
3.
Open SV Loop 3 to motor driven emergency feed pump 3 valve NYG-10013 and SW loop 3 to emergency FW valve NYG-10373.
6.8 Maintain > 50*F subcooling of RCS by dumping steam from non-faulted S/G's.
6.8.1 I? condenser is available and no uncontrolled st'eam release.
Ell occur by cpening MS line isolation valve.
A.
RESET and 3 LOCK ST3AMLIN3 SAF3TT INJ3CTION Train A and Train 3.
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3.
Open MS line bypass isolation valve for at least one*
intact S/G.
1).
PYM-2869A for S/G A.
2).
PYM-28693 for S/G 3.
3).
FYM-2869C for S/G C.
C.
Allow the pressure between the steam header (PI-464A) l and the MS line being placed in service to equalize (t 50 psig).
1).
PI-476 for MS line A pressure.
2).
PI-486 for MS line 3 pressure.
3).
PI-496 for MS line C pressure.
D.
Open the MS line isolation valve for the MS line being placed in service.
1).
PYM-2601A for S/G A.
2).
PYM-28023 for S/G 3.
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3).
PTM-2802C for S/G C.
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30P-2 PAGE 11 RIVISICN 1 11./04/80 3.
Shut the MS line bypass isolation valve once the MS line isolation valve is open.
1).
PYM-2869A for'S/G A.
2).
PYM-28693 for S/G 3.
3).
PYM-2869C for S/G C.
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Transfer steam dump mode select switch to STM PRESS
- I mode.
G.
Adjust the steam dump auto-manual controller as necessary to establish a cooldown rate not to exceed i
100*F/hr above 200*F RCS temperature or 50*F/hr below 200*F RCS temperature.
6.8.2' NE line isolation valves or thTMS 13se isolation valves I7 condenser is not available or rupture is downstream of cannot be opened.
A.
Transfer the MS line shutdown /pover relief' valve
- i controls, to the intact S/G's to the POWER RELIEF 6
mode.
3.
Adjust the MS FWR RLF controller as necessary/hr above to
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establish a cooldown rate not to exceed 100*F 200*F RCS temperature or 50*F/hr below 200*F RCS temperature.
69 IF RCS subcooling cannot be maintained manually initiate Safety Injection and go to 30P-1.
1 6.10 Borate RCS to maintain the required shutdown margin.
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6.10.1 Sample the RCS, and pressurizer for boron concentration.
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6.10.2 Borate RCS and pressuriser to the desired boron l
concentration in accordance with SOP-106 step 4.4.
6.10 3 At the completion of boration set the automatic makeup
-control for the required concentration in accordance with SOP-106 step 4 1.
I 6.11 Establish the necessary auxiliary systems and cooldown to cold shutdown per GOP-6 and 7 l
.m 70 FINAL CONDITIONS
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71 The plant is stabilized and being coole'. down as per GOP-6 and 7
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