ML040130215
| ML040130215 | |
| Person / Time | |
|---|---|
| Site: | Turkey Point  |
| Issue date: | 01/15/2004 |
| From: | Ernstes M Operator Licensing and Human Performance Branch |
| To: | Stall J Florida Power & Light Co |
| References | |
| 50-250/03-301, 50-251/03-301 50-250/03-301, 50-251/03-301 | |
| Download: ML040130215 (78) | |
See also: IR 05000250/2003301
Text
Post-examination Comments
TURKEY POINT DEC. 2003
EXAM 50-25012003-3QI
-
DECEMBER 3 15,2003
e 5 9
I 8 2.003
Mr. Luis A. Reyes
Regional Administrator, Region II
Attn: Michael E. Ernstes
U. S. Nuclear Regulatory Commission
Sam Nunn Atlanta Federal Center
61 Forsyth Street, S. W., Suite 23T85
Atlanta, GA 30303
We: Turkey Point Units 3 and 4
Docket Nos. 50-250 and 50-251
SRO Written License Examination Comments
The provisions of NUREG-1021, Operator Licensing Examiner Standards, Examiner Standards
FS-402, Administering Initial Written Examinations, allow the opportunity for submittal of
comments on the written portion of the SRO License Examination to the NRC.
This letter documents that Florida Power and Light CO.is submitting comments and
recomiendations for your review and approval for questions #I and # 46 related to the site-
specific written examination administered at Turkcy Point on December 15,2003. Additionally,
question #33 is being subniitted for consideration for applicant Timothy Scott. Mr. Scott
inadvertently bubbled in the wrong item on his scantron answer sheet. The supporting
information for these questions is enclosed.
Should there be any questions, please contact Gregory Laughlin at (305)2464274.
Terry Jones
Vice Resident
Turkcy Point Nuclear Plant
cc: Michael E. Emstes, Chief, Operator Licensing and Human Performance Branch, Region
II,USNRC
Chief Examiner, Region U, USNRC
Senior Resident Inspector, USNRC, Turkey Point Plant
Document Control Desk, USNRC, Washington, D.C.
Turkey Point 2003 NRC Written SRO E x m
Post-Exam Review Recommendations
December 18,2003
Q# 1) Accept either E? or C response as correct.
C response is correct per the answer key. It is supported by its reference: BD-
ONOP-003.6, Page 6 .
Post-exam review revealed that Bresponse is also corrxt. Refer to 3-ONOP-
003.6, CAUTION on Page 22 which states Pressurizer level should be
monitored closely on the operable instrumentation duringpecformunce of the
following steps to avoid uncovering the pressurizer hecaters or causing a high
level trip.
The following steps referred to in the CAUTION are steps associated with
maintaining pressurizer level and pressure control.
This CAUTION clearly states that operators must use care when controlling
pressurizer level (via chaging pump speed control) to prevent a reactor trip on
high pressurizer level. This concern forms the kasis for the B response, making
the B response also correct.
Note that the distractor analysis says that >ressurizer level is not a concern
hecause pressure will increase to the PORVsetpoint prior to pressurizer level trip
criteria being reached. The distractor analysis is correct in that pressure will
likely increase to 2335 psig as level increases. POKV-456 will auto-open and
relieve pressure down to 23 15 psig at which time it will close. The PORV will
then cycle open and closed between these pressure values while level continues to
rise. Level will increase to its auto-trip setpoint of 92% or until operators
manually trip the reactor at 80% level as directed by their Operations Department
Instruction (ODI) #23. Therefore the distrac.toranalysis is flawed because
pressurizer level remains a concern even while the PORV is cycling.
Finally the issue of identifying the ultimate basis for minimizing charging flow
must be addressed. With letdown isolated as a result of the loss of3P06,
pressurizer level and pressure will continuously rise at a rate dictated by the
charging flow rate. An ONOP-003.6 objective is to maintain stable conditions
with near normal parameter values until 3P06 can be restored. Either event
(PORV cycling or reactor trip on high level) is undesirable and the procedure
gives guidance to minimize charging flow to preclude both. Therefore precluding
both events becomes the ultimate basis of reducing charging flow.
References Provided:
3-ONOP-003.6, Loss of 120V Vita1 Instrument Panel 3P06
3-ONOP-004.6, Basis Document
ODI-CO-023, Manual Reactor Trip Guidelines
Simulator generated curve: PKZ. Pressure & Level foliowing loss of 3P06
~ _.
Turkey Point Nuclear Plant 2003-301
SRO hital Exam
1.
Which ONE of the following is the basis for reducing charging flow to the minimum
required to maintain RCP Seal Injection foollowing a loss of i2OV Vital Instrument Panel
3PO6,as required by Step 3.a, of 3-ONOP-003.6, "Loss of 120V Vital Instrument Panel
3P06?"
A. Reducing charging fiow assures proper back pressure on the RCP # 2 seal and
ensures the # 2 seal is not cocked.
B. Reducing charging flaw extends the time for recovery without tripping the Reactor
on high pressurizer level.
C. Minimizing the fill rate of the pressurizer extends the time for recovery without lifting
a pressurizes PORV due to compressing the bubble.
D. Minimizing charging pump speed ensures that a loss of charging does not occur
due to low oil pressure to ensure that RCP Seal Injection is maintained.
1 . 004A1.04 1 SRO
Which ONE of the following is the &?stybasis for reducing charging flow to the
minimum required to maintain RCP Seal Injection tl
-following a loss of 120V Vital Instrument Panel 3P06, as required by
Step 3.a, of 3-ONOP-003.6, "Loss of 120V Vital Instrument Panel 3P06?"
A. Reducing charging flov.' m a m d p & M assures proper back pressure on the RCP
- 2 seal and ensures the # 2 R W seal is not cocked.
3. Reducing charging flow d l y - w t l l extends the time Zkme for recovering without
tripping the Reactor on high pressurizer level.
C. Minimizing the fill rate of the pressurizer ml,istuY.w&l extends the time hame for
recovery without lifting a tke pressurizer PQRV due to compressing the bubble.
6). Minimizing charging pump speed RWW&&W~ ensures that a loss of charging does
not occur due to low oil pressure tu ensure that RCP Seal Injection is maintained
ftstieft.
Distractor Analysis:
A. Incorrect. This is the basis for having RCS pressure greater than 325 psig.
B. Incorrect. In this case pressurizer level is not a concern because pressure
will increase ___
~ - _
to the PQKV _ prior to pressurizer level
setpoint ~- trip criteria being -.
reached.
C. Correct. The loss of 3P06 directly affects the normal control of the
pressurizer pressure and level. Operator attention is necessary to maintain the
pressurizer in normal level and pressure.
D. Incurrect. Operational experience at PTN has shown that Charging pumps
are prone to auto trip on low uil pressure when the speed of the charging pump is
reduced to low values of less than 20% demand .
Answer: c
Reason for Revision: Eliminated unnecessary words. Minor wordsmithing.
Plorida Power & Light Company
Turkey Point Nuclear Plant
Unit 3
LOSS of 120V Vital Instrument Panel 3PO6
Responsible Department. Operations
Revision Approval Bate: 7131/03
97-0752P, 97-1334P, 97-1417P, 98-0851P,9R-I272i? OO-O439P,
02-0294P, 02-0593P, 03-0467P
OTSC 0547-00
PC/MS93-005,94-034.95-102, 97-036.98-025
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I
- _
LIST OF EFFECTIVE PAGES
Revision
Date
1 0713 1/03
2 07/31/03
3 10/07/02
4 10107/02
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6 10/07/02
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8 10/07/02
9 10/07/02
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11 10/07/02
12 10107Kl2
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21 IO/O7102
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23 10/07!02
Foldout Page 10~07/02
1.0 PURPOSE
This procedure provides instructions to be followed upon receipt of Loss of 120V Vital
Instrument Panel 3P06.
2.0 SYMPTOMS OR ENTRY CONDITIONS
2.1 Indications
2.1.1 Power Range N-41 Failure (NIS Racks Channel I Lights Out)
2.1.2 Loss of Channel I Vital Instrumentation/Indic.a~io~~s
3.1.3 Transfer of Feedwater Control from Automatic to Manual for Steam Gcnerator A
2. I .4 Loss of Power to Pressurizer pressure control AutoiManual Station (auto lockup)
2.1.5 Loss of Power to the Pressurizer Spray Valve Auto/Manual Station (auto 1oc.kup)
2.1.6 Loss of Pressurizer IIeaters (Control and Backup)
2.1.7 Isolation of CVCS Letdown Flow
2.1 .S Loss of Iower to Pressurizer Level AutoiManual Station (auto lockup)
2.1.9 Loss of Power to 3A Charging Pump AutoiManual Station (auto iockup)
2.1.10 RCP Thermal Barrier Cooling Wakr Valve, MOV-3-626, closes
2.1.1 1 PORV-456 Auto Open Disabled (if in OMS I,OW PRESSURE OPS)
2.1.12 Loss of Power to S t e m Generator C Auto/h,lanual Station (auto lockup)
2.2
2.2.1 F 112, VITAL AC. BUS INVERTER TROUBLE
2.2.2 I3 6i5, POWER R4NGE LOSS OF DETECTOR VOLTAGE
2.2.3 3 7/1: NIS/RPI ROD DROP R01) STOP
2.2.4 C 6i1, Sd; A LEVEL IPFiVIATION
2.2.5 h 1/5 KCP SEAL LEAKOFF III FLOW
2.2.6 A 6i4, RCP SEAL WATER LO DP
2.2.7 A 7i6,RCP C SEALWAIERBYPASS LO FLOW(ifCV-3-307 Open)
2.2.8 I I 415, CSP A/B COOLING WATER LO FLOW
2.2.9 A 1/1, KC'P THERMAL BARR COOLING WATER III FLOW
2.2.10 H 612, RHRIIX m . 0 ~ 1 m 7
2.2.1 1 X 4/1, ARMS HI RADIAlION
2.2.12 H 112, SFP HI TEMP
2.3 General
2.3.1 I,oss of the 120V Vital Instrument Panel 3P06 results in a loss of automatic
feedwater control, and a loss of power to all channel I instrumentation.
ENC1,OSIJRE 1 of this procedure contains a list of instrumentation lost in the
Control Room due to the loss of Vital Instrunlent Panel 3P06.
2.3.2 As with any loss of a vita1 AC p<mel,early diagnosis and recovery is of greatest
assistance toward unit restoration.
1.0 KE:FERENCES/RECOKI9SREOUIRED/COMMITMENT DOCUMENTS
3.1 References
3.1. I Technical Specifications
1. Section 3.3.2. ESFAS Instrumentation
2. Section 3.8.1.1, Diesel Generators
3. Section 3.8.3.1, Onsite Power Distribution
4. Section 3.4.9.3, Overpressure Mitigating Systems
3.1.2 FSAR
I. Section 8.2-7, Electrical
3.1.3 Plant Drawings
I. 5610-E-855, Breaker List
Procedure KO.: Procedurc l i l l e :
3.1.4 Procedure2
1. 3-GOP-103, Power Operation to Hot Standby
2. 3-EOP-E-0, Reactor Trip or Safety Injec.tion
3. 0-OP-003.3, 120V Vital Instrument System
3. I .5 Plant ChanpeModificaticns
1. PC/M 93-005, Elimination of Turbine Kunback Ilropped Rod
2. PC/M 94-035, RTDP Related RPSESFAS Setpoint Changes
3. PC/M 95-102, Abmdonment of the CO7 Panel and Sample Train
Reconfiguration
4. IpC:M97-036, Quarterly AEP
5. PC/M 98-025, Repowering Of KHR Pressure Interlock (PC-3/4-600X)
3.2 Records Reauired
3.2.1 The date and time procedure completed shall be logged in the Reactor Contrc
Operator (RCO) logbook(s1. Also, any problems encountered while performing
the procedure should be logged (Le., malfunctioning equipmcnt, delays due to
changes in plant conditions, etc.).
3.3 Commitment lloc,uments
3.3.1 CTRAC: 90-0248
N97:bciswiswirnrs
If fhe pressurizer spray valves were open prior to the loss of 3P06, a
Reactor Trip may occur due to QTAT or low pressurizer pressure.
I
'
I
I
I
s
Step I is an immediate action step.
All 3PQ6 (RED) channel indication/controls are affected by failure of
3PQ6. Endosure 1 provides a listing of losf functions, indications, and
controls.
I
f,
1
I I,-,,-,-------- I
1 Check If A Reactor Trip Has Occurred Perform the following:
a. E a reactor trip is required, THEN
manually trip the reactor perform
3-EOP-E-0, REACTOR TRIP OR
SAFETY INJECTION, while continuing
with this procedure.
b. E reactor trip is N8T required, THEN
go to Step 2.
2 Check Unit Operating In Modes 1 Through 3 Perform the following:
Prior TO LOSS Of 3806
a. E RCS solid, THEN perform the
fallowing to prevent RCP damage & J
J
maintain RCS pressure:
1) Stop All RCPs
2) Stop and start charging pumps as
necessary to maintain RCS
pressure
b. E RHR cooling is in service, AND
MOV-3-750 is closed or stroking closed,
THEN stop the operating RHR pump(s)
-
AND go to 3-ONOP-050, LOSS OF
RHR, while continuing with this
procedure.
-
AND PORV-3-456 is required to be
open for pressure control, THEN
manual action shall be taken to control
RCS pressure.
I W97:bclswlswlmrg
ACTIONEXPECTED RESPONSE I I RESPONSE NOT OBTAINED c
3 Control Pressurizer Pressure As FOIIOWS:
a. Reduce charging flew to minimum required
to maintain RCP seal injection using the 38
-
OR 3C charging pumps in MANUAL speed
control
b. Check Pressurizer PORVs - CLOSED b. PRZ pressure less than setpoint,
THEN manually close PORVs. any
PRZ PORV can NOT be closed, THEN
manually close its block valve.
I STEP I I ACTlONlEXPECTED RESPONSE I I RESPONSE NQT OBTAINED I
I II
' 0 VCT Temperature indicafion, W3-116, should be monitored in lieu of
Excess Letdown, T/-3-139, which is de-energized.
I I
I Excess letdown flow must be established slow& to minimize thermal I
I stresses on the Excess LTDN Heat Exchanger (5 to 10 minutes). I
4 Maintain Pressurizer Level As FO~~OWS:
a. Place Pressurizer Level control switch in
Position 3 (Ch 2 8, 3)
b. Place Excess Letdown in service as follows:
1) Verify Excess LTDN HX CCW Outlet,
CV-3-739, open
2) Verify Excess LTDN Divert to WBS,
CV-3-389, is aligned to the VCT (switch
to NORMAL)
3) Open Excess LTBN Stop Valve,
cv-3-38?
4) Open Excess LTDN Flow Controller,
HCV-3-137 AND adjust flow to control
Pressurizer Level
ACTlONlEXPECTED RESPONSE 1 I RESPONSE NOT OBTAlNFn
CAUTIONS
e Reduchg feed flow to less than steam flow by 655,000 lbshr will
result in a reactor trip due to low level trip Iogic on Channel 1 of
each steam generator.
e Steam Generator 3A leveel controls are in MANUAL and 3A FIN
Bypass Waive fails closed.
e 3A Steam Generator Level Recorder is DE-ENERGIZED
Steam Generator 3C !eve1 controls are in AUTO LOCKUP
5 Control Steam Generator Water Levels As
FO~~OWS:
3A Steam Generator by manual control of
Feedwater flow
3C Steam Generator by adjusting the
following parameters:
Blowdown flow
Feed flow
Turbine load
Steam Flow
6 Maintain The Following Plant Parameters - any reactor trip setpoint is approa ?d or
STABLE: exceeded, THEN manually trip the reactor
perform 3-EOP-E-0, REACTOR TRIP
Tavg OR SAFETY INJECTION, while continuing
Reactor power with this procedure.
o Pressurizer Pressure
Pressurizer Water level
Steam Generator Water level
7 Check Power Restored bo 3P06 Perform the following:
a. Continue efforts to restore power to
3P06.
b. power can be restored to 3P06
within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, _THEN perform the actions
required by Technical Specifications as
directed by the NPS.
c. Return to Step 1
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ACTIONIXPECTED RESPONSE RESPONSE NOT OBTAINED
I Auto/Manual controllers shouid NOT be returned to AUTO untll vital
power has been complefdy restored.
I
I When power is restored io a Manual/Aufo station, the AUTO light should I
turn on, affer appvxirnafely 15 seconds the MANUAL [ight should turn OR.
When fhe MANUAL right turns on, manual control of the process is I
I
I available.
~-- -- -- -- ~- -- -- -- A -- ~- ~- -
8 Restore Equipment Bo AUTOMATIC
Controls As FOllOWS:
a. Pressurizer Pressure Control using section
2 of ATTACHMENT 4
b Steam Generator bevel control as follows:
2 ) Manually control feed flow to return
steam generator to required band for
plant operating mode
2) Manually adjust feed flow to match
steam flow
3) Place the steam generator level
controls to AUTO
4) Repeat Steps 8.b.l) through 8.b.3) until
all steam generator controls are in
AUTO
c. Direct the Operators to return all controls c. AUTOMATIC control is
listed on ENCLOSURE 1 to AUTOMATIC available desired. T#EN maintain
using appropriate plant procedures controls in MANUAL.
d. Verify all annunciators indicate correctly for d Perform the actions of the appropriate
the current plant status Annunciator Response procedure for
the affected alarms.
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9 Go To Appropriate Procedure As
Determined By The Nuclear Plant
Supervisor
END OF mxT
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ENCI,OSUKE I
(Page 1 of 4)
CONTROL ROOM FUNCTIONS AND INDICATIONS
LOST ON LOSS OF 3P06
FL.rNCI'IONS, Ooerating
1,ock up of Pressurizer Pressure Controllers causing spray valves to stay as is
Lose Auto and Manual Ccntrul of C Feedwater Control Valve, FCV-3-498
Lose Auto Control of A Feedwater Control Valve, FCV-3-478
IdoseKCP Thermal Barrier Cooling Water, MOV-3-626 closes
I.ose Auto and Maiinal 3A Charging Pump Control causing Auto Lock-up
Lcse Auto Speed Control of 3B and 3C:. Charging Pumps
Lose the Auto Makeup Control to the Volume Control Tank
Lose power to Control Relay from MOV-3-115C which opens LCV-3-1133
L,etdown Isolation
Pressurizer heaters de-energize
Lose Auto and Mmual control of PCV-3-145, Letdown Pressure Controller
1,oss of 3B Diesel Load Sequencer, 3C23B-1 deenergized
Lose AMSAC A Processor
Lose the Ability to Block the Source Range Trip
Lose Feedwater Isolation signal (Reactor Trip with 'l'avg 1554°F)
p - - _ - _ - - - - - _ - - - s - - - _ - - - - -
I NOTES I
I The following conditions exist which affect Pressuflzer Pressure control:
I
Pressurizer Pressure Confmller PC-444J - AUTO LOCKUP
I PZR Spray Valve Controllers -AUTO iOCKUP
I * PZZR heaters deenergized
1 Letdown isoiatisn
I 3A charging pump -AUTO LOCKUP
38 AND 3C Charging pump loss of auto speed control
I
' Minimum charging flow for seal injection should be maintained due to
I
I loss of thermal barrier cooling water caused by closure of MOV-3-626. 1
NS7:bciswlswlmrg
ENCLOSURE 1
(Page 2 of 4)
CX)NTKOI, ROOM FUNCTIONS AND INDICATIONS
L O S l ON LOSS OF 3P06
r- n - -1
NOTEg
I I
With vital panel 3P06 deenergined, 3B bus sequencer is out of service
b resulting in the foilowing Tech Spec implications: I
I I
f
?. AFW actuation from bus stripping on 35 4KV bus will NOT be 1
generated, piacing the unit in a shufdown action statement (Tech
I Spec 3.3.2, Table 3.3-2, functional unit 6.d action 23 invokes Tech
I Spec 3.0.3.) I
I
2. Loss of Power signais are lost via the 38 bus sequencer, placing the I
I unit in a shutdown action stafement (Tech Spec 33.2, Tabie 3.3-2,
Functionai Unit 7a, b and c)
I
I I
I 3. Bus sfripping wiN NOT automatically occur, 38 EDG will NOT 1
I automatically close in on the bus and is out service; actions of Tech I
Spec 3.8.I. 1 apply.
!,,,,,,,,-,,,,-,-,--,,--,,, I
INDICATORS
'1'1-3-401 Rx Vessel Leak of Temp
TI-3-133 Seal Water Return Temp
TI-3-139 Excess L'I'LIN HX Temp
PI-3- 121 Charging Pumps Disch Press
TI-3-123 Kegen IIx Outlet Temp
'rl-3- 141 LTIIN Kelief To PRY Temp
TI-3-143 Non-Regen HX LTDN Temp
FI-3-150 I,ow Pressure 1,etdoun Flow Indication
FR-3-1540 #I Seal Leakoff Recorder Low Range (Fails As Is)
FR-3-154.4 #1 Sed Leakoffliecorder High Ibnge (Fails As Is)
PI-3- 128A B RCP Thermal Barrier AP
PI-3-402 RCS Press NR
PI-3-403 RCS Press U'R
1'1-3-465 Pzr Safety Valve Temp
1'1-3-467 Pzr Safety Valve Temp
TI-3-469 Pzr Safety Valve Temp
TI-3-463 PZR Relief Temp
TI-3-45? PZK Spray Loop B 'l'emnp
1'1-3-45 1 P7.R Spray Loop C Temp
TI-3-4 12B A I m p Ovpwr AT
TI-3-412A A Loop AT
TI-3-412C A Loop Ovtemp Xi'
ENCLOSURE 1
(Page 3 of 4)
CONTROL ROOM FUNCTIONS AND INDICATIONS
LOST ON LOSS OF 3P06
I m I cAims
~i-3-412~ A Loop Temp Avg
PI-3-455 PZR Press Ch I
I'I-3-459A PZR Level ProtKont.
PI-3-414 RCS Flow Loop A
F1-3-4'24 RCS Flow Loop B
F1-3-434 KCS Flow 1,oop C
TR-3-412 Delta-T Recorder
NR-3-46 NIS Ovevower Recorder
LI-3-474 A Stm Gen L.evel
LI-3-484 B Stm Gen Level
IJ-3-494 C Stm Gcn Level
IR-3-477 Stm Gen Wide Range Level (Pails As Is)
FR-3-478 3 4 Stcam Generator Recorder
LI-3-470 Pzr Relief Tk Level
TI-3-471 P n Relief Tk Temp
1'1-3-472 PZR Relief Tank Pressure
PC-3-444H Auto Manual Station for Pzr Spray Vaive PCV-3-455H
PC-3-444G .4uto Manual Station for Pzr Spray Valve PCV-3-455A
PC-3-444J Auto Manual Station for Pressurizer Pressure Controller
SC-3-15111 Auto Manual Station Charging Puinp A Control
PC-3-145B Auto h?anual Station I,ow Pressure Letdown Pressure
FC-3-113A Auto Manual Station Boric Acid to Blend System
NI-3-664913 1/B2 Gammametrics kickup NIS
N-3-3 I Source Range Counts and Source Range Startup Rate
N-3-35 Inter Range Current Current and Startup Rate
N-3-41 Power R m g e and Axial Flux Diff-trencc
LC-3-478A Stm Gcn A Control Valve Controller, Lose Inst, MAN Control Only
FCV-3-479 3A FW Bypass Valve
11-3 Pressurizer Safety Valve Acoustic Monitoring System
NIS Rack Ch 1 o\J-31, N-3Si N-41)
RI-3-6311B Containment High Radiation
TI-3-610B CCW Pump Inlet Temp
Ti-3-609B B CCW HX Outlet Temp
RI-3-6311B Containment IIigh Radiation (VPC)
ALARMS
A 111, RCP THERMAI, BARR COOLING WATER HI FL.OW
A 1/5, KCP SEAL LEAKOFF HI FLOW (C RCP only)
A 614, RCP SEAL WATER 1.0 DP (C RCP)
C hi1 . Sd; A L.EVEI, DEVIAI'ION
H 112, SFI' ITEMP
I I 413, RIIR PP A C'OOLING WATER LO FLOW
H 715, CSP A B COOLING WATER L.0 "IOW
X 316. SI PP COOLING WATER LO FLOW
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ENCLOSURE f
(Page 4 of 4)
CONTROL ROOM FUNCTIONS ANI) INDICATIONS
LOST ON LOSS OF 3P06
r'-"-"-"s's'-'-'-"-'-'-' 9
E
=
I I
I The following [isfed are shutdown mode concerned failures, and are in I
I addition io power mode failures. I
L,,-,,,--s-----m----'-s-- J
FIJNCTIONS, Shutdown
Lose KHR Suction, MOV-3-750 closes from 1,oss of IT-3-403
Lose AutoiManual Control of FCV-3-605
1,ose Pressure Control by IICV-3-142, fails closed.
POKV-3-456 Auto Open signal from OMS is defeated, consult Teeh Specs if OMS is required to he
Lose ability to open MOV-3-862Bi863R due to a loss of power to l'C-3-600X
Lose B Gammametrics
PT-3-403 RCS pressure
HIC-3-142 REIR Lrrm TO cvcs
FC-3-605C Auto Manual Station RHR Ht Iixchanger Bypass I k w Control
I Amber Safety Injection Lights for the following valves:
MOV-3-744B
MOV-3-843B
MOV-3-862B
MOV-3-863H
MOV-878A
MOV-3-865B
MOV-3-860R
MOV-3-861I3
MOV-3-864B
I
h.IOV-3-866B
ALARMS
I 1R, SFP I11 TEMP
I 7/3. IGIR PP A COOLING WAI'ER LO FLOW
X 3/6; SI PP COOLING W'ATER LO FLOW
ATTACHMENT 1
(Page 1 o f 2 j
RESTORATION OF 3PO6 VITAL INSTRUMENT AC: BUS
1. In the Inverter Room, perform the following:
a. Proceed to the 3C inverter.
b. Open the 3C inverter System Output breaker, CB6.
2. In the Cable Spreading Room, perfimn the following:
a. 4 t Vital Instrument Panel 3P06, place all breakers to OFF.
b. At Subpanel 3P21, place all breakers to OFF.
3. Check 4P06 being powered by CS Inverter at 4I06A Vital Instrument AC Selector
Switch in the Cable Spreading Room.
4. -
IF 4PO6 is powered by the CS; Inverter, THEN notify the Nuclear Plant Supervisor.
CAUTION
DO NOT proceed with this procedure if 4P06 is powemd by the CS
Inverter.
5. -
IF 4P06 is NOT powered from CS Inverter, TIIEN place SPARE inverter C S in
service to supply 3P06 Vital Instrument AC Bus load as follows:
a. At Vital Instrunlent Panel .1POtiA in the Cable Spreading Room, place Vital
Instrument AC Selector Switch 3P06A to the ALIERNAIE SUPPLY
STANDRY STAIIC INVERTER CS position.
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ATTACHMENT 1
(Page 2 of 2)
RESTORATION OF 3P06 VITAL INSTRUMENT AC: BUS
!
I
If System Outpout Breaker, CB6, has fr/pped, this would indicate an
overcurrent condition and the amps should be monitored when each I
breaker on the Vital and Subpenel is closed. Amps should stabilize at I
Iess than 63. This wiN require a second operator at the CS inverter or I
at ERDADS to monitor amperage. I
6. Notify the Control Room that circuits on 3P06 are about to be energized.
7. At Vital Instrument Panel 3P06, place the following breakers in the OK position:
a. 3PO6 - Main
b. 3PO6-4, (energizes LC460CX).
c. 3PO6-8, (energizes Al JTO/MANI!AL station for Steim Generator Cj.
8. At Panel 3P06, place the remaining bre'akers in the ON position using Attachment 2. I
~ANI) allowing five (5j seconds between each breaker. I
9. At Subpanel 3P21, place breakers in the ON position using Attachn~ent3 ANI)allowing I
five (5) seconds between each breaker. I
10. In the Inverter Room, at the (locked) AIternate Source Transfer Switch 3Y05B. perform the
following:
a. Unlock Alternate Source Transfer Switch place in the BACKIJP TO SPARE
INVERTER CS position.
11. At Spare Inverter CS (3Y06j, place the Synch Selector Switch inside the inverter panel in the
NORMAL (down) position.
12. Notify the Control Rooin when all breakers are closed.
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ATTACHMENT 2
(Page 1 of 2)
120V AC VITAL INSTRUMENT PANEL 3PQ6NORMAL ALIGNMENT
I Instrument AC Selector Switch I ALTERKATI
-1 i
~
E 6 - 6 3QR10 - Process Protection Kack 10 ON
TB3134 - CCU From RCI Hi Flow FC-3-626
and TIC-3-651 S l P Cooling 1Ii Tenm 1 ON
(3PO6-13 I 3QR59 - Nuc Jnst Rack 59 (Ch 1 Source & Inter I ON
- Kote: All breakers shall be in the ON position to reduce confusion and have conformity.
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ATTACHMENT 2
(Page 2 of 2)
12OV AC VITAL INSTRUMENT PANEL 3P06 NORMAL ALIGNMENT
3106-1 6 I 3QR30 - Area Radiation Monitor Rack 30 I ON I
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ATTACHMENT 3
(Page 1 of 1)
120V VITAL INSTRUMENT AC SUBPANEL 3P21 NORMAL BREAKER ALIGNMENT
13'221-1 I RAT-3-6311B Ctmt Hi Range k4onitor
I 3p21-4 I RR-3-63 11R Ctmt Kadiation & Hydrogen
Recorder E ON I
Relay Rack 3QK47 Power - RHR Interlock
I Charcoal Filter Dousing Valve Actuation Flow
Switches at C281H
~
'Kate: All breakers shall be in the ON position to reduce confusion and have conformity.
N97:bciswlswlmrg
I
ATTACHMENT 4
(Page I of 2)
PIU1:SSURIZER IXVEL AND PRESSURE CONTROL WITH 3P06 DE-ENERGIZED
SECTION 1
Pressurizer leveel should be monitored closely on the operable
instrumentation during performance of the folbwing steps to avoid
uncovering the pressurizer heaters or causing a hi Eevel Wp.
- - - _ - - - - - - - - - o - - - - - _ - - - _ -
I NOTE I
I PCV-3-145 is in AUTO-LOCKUP. The letdown orifice which was in service
I
I I
prior f~ the loss of 3P06 should be used when restoring letdown
I _- - - _- - - - - _- - - _- _- - - _-
- I --
1. Perform the following:
a. Verify Pressurizer PORVs are closed.
b. Verify Pressurizer Level control selector switch in Position 3 (CII 2, & 3 ) .
c. Proceed to Rack 46 (Front) AND manually hold in Relay LC 460 CX.
d. Operate heaters as necessary to return pressure to normal.
e. Restore letdown as follows:
1j Verify Letdown orifice isolation valves - CLOSEI)
2) Open Letdown From Regen Heat Exchanger Isolation CV-3-204
3) Open EIigh Pressure Letdown Isolation From Imop R Cold Leg, I,CV-3-460
4) Open letdown orifice isolation valve to establish desired flow.
2. -IF pressure is increasing with heaters energized, TIIEN proceed to Rack 20 front
remove the power fuse from the front of PC-444 C&D to close the Pressuri7er Spray Valves.
ATTACHMENT 4
p a g e 2 of 2)
PRESSURIZER LEVEL AND PRESSI;RE CONTROL WITH 3P06 DE-ENERGIZED
3. IF the above preferred method of energizing pressurizer heaters AND restoring letdown flow is
_ I successful, proceed as follows:
a. Proceed to the linit 3 West electrical penetration room AND perform the following:
1) Select LOCAI, control of 3A Backup Group Pressurizer heaters.
2) Push S?ART/S?OP pushbuttons as necessary to control heater operation.
h. E necessary, THEN restore Letdown flow by holding valve handswitches in the OPEN
position to initiate normal letdown,
SECTION 2
I. WHEN power to the Vital AC bus is restored, THEN perform the following:
a. -IF relay I,C460CX in Rack 46 is being held in, THEN release hold on relay.
b. E the power fuses for Pressurizer Spray valves were removed in Section 1, Step 2, THEN
replace the power fuses for PC-444C and PC-444D in Rack 20.
c. Restore pressnre control using 3-OP-041.2, PRESSI:RIZER SYSTEM.
FINAL PAGE
iN97:bchwlswlrnrg
FOLDOUT PAGE FOR PROCEDURE 3-ONOP-003.6
1. Dispatch an operator to restore power to 3P06 using Attachment 1. i
2. Rispatch an operator to restore pressurizer pressure level controls using Attachment 4. i
3. a Reactor Trip has occurred, THEN perform the following: 1
a. Close MOV-3-1407
b. Close MOV-3-1408
b. Close MOV-3-1409
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a Bower & Light Company
Turkey Point Nuclear Plant
Unit 3 & 4 (Master)
FOR:
- -ONOP-083.6
DATED:
10/7/02
TITLE:
Loss of 120V Vital Instrument Panel *PO6
W97:lbclsw
Page 2
BD-ONOP-003.6 Loss of 12OV Vital Instrument Panel "PO6 10/7/02
BASIS DOCUMENT
LIST OF EFFECTIVE PAGES
Revision
Date
1 10/07102
2 iOi07/02
3 10!07/02
4 10/07102
5 10/07102
6 10/07/02
7 10/07/02
n 10/07/02
9 10/07/02
10 10/07/02
11 10/07/02
12 10/07/02
13 10/07/02
14 10107!02
15 10/07/02
t 1
The intent of this document is to provide justification and explanations for selected
I procedural information. The Basis Document does not contain the procedure content as a 1
, whole and will not be re-dated unless the procedure change affects the content of this B
_ - _ s - - - - _ - _ P - - - - - - - - - - - P - -
1
Page 3
BD-ONOP-003.6 Loss of 120V Vital Instrument Panel "PO6 10/7/02
BASIS DOCUMENT
1.0 PIJRPOSE
1.1 Self-explanatory
2.0 SYMPTOMS OR ENTRY CONDITIONS
2. i Indications
.------l_-_p----------------
I I
I The indications lisfed are plant parameters and system responses caused by a loss of
12OV Vital Instrument Panei *PO6 Many indications will be received, however only those
indications requiring immediate operator attention are referenced. I
c I
2.1.1 Instrument bus *PO6 supplies power to the NIS rack PR-N41 module.
2.1.2 Loss of instrument bus *PO6 results in the loss of all Channel I Vital
Instrumentatiodhdications (Se.c Enclosure 1).
2.1.3 Instrument bus *PO6 supplies power to Steam Generator *A Feedwater
Controller (FC-47Sj9located in Process Control Rack 6. Upon loss of *P06,
Steam Generator *A feedwater flow control automatically transfers to
manual. This transfer is indicated by lights on Steam Generator *A Auto
Manual Station (FC-478F), on thc console. Specifically, the Auto light goes
out and the Man light comes on.
2.1.4 Instrument bus *PO6 supplies power to the Pressurizer Spray Valve Auto
Manual Station (PC-444J), located on the console. All lights at PC-4445 go
out, while the associated automatic controller (PC-444A), located in Process
Control Rack 2.0, transfers to auto lockup.
2.1.5 Instrument bus *PO6 supplies power to the Pressurizer Pressure Controls
Auto Manual Stations (PC-444G and PC-444EI), located on the console. All
lights at PC-444G and PC-444H go out while. associated automatic
controllers (PC-444C and PC-444D), located in Process Control Rack 20,
transfer to auto lockup. As a consequence, pressurizer spray valves
PCX-455A and PCV-4SSR remain as is. Closure of pressurizer spray valves
upon loss of *PO6 is covered in a later section of this document.
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Page 4
BD-(DNOP-003.6 Loss of 12UV Vital Instrument Panel *PO6 10/7/02
2.1 .ti Instrument Bus 'PO6 supplies pourer to the Pressurizer Level Comparator,
LC-3-46OC. During nornial operations, L.C-460C de-energizes relay
LC-46OX at 14 percent pressurizer level to trip all Control and Backup
pressurizer heaters should they become uncovered. On a loss of *FO6,
LC-46UX is de-energized, tripping all pressurizer heaters regardless of
pressurizer level.
2.1.4 De-energizing LC-460X on a loss of 'PO6 also isolates CVCS Letdown
flow. Letdown flow is isolated by the closure of orifice isolation valves
200A, 20OR and 200C and letdown isolation valve, LC.V-460. During
normal operations, isolation would occur at 14 percent pressurizer lcvel to
prevent loss of reactor coolant inventory.
2.1.8 Instrument Bus *PO6 supplies power to Pressurizer Level Auto ,Manual
Station, LC-459G. Loss of *PO6 results in all lights at LC-459G going out
and Pressurizer Level Controller LC-459F, transferring to auto lockup.
Manual operation of charging pumps may be necessary.
2.1.9 Instrument Bus *PO6 supplies power to *A Charging Fump Auto Manual
Station, SC-I5IA. Loss of *FOG rcsults in all lights at SC-151A going out
and +A Charging Fump controller transferring to auto lockup.
2.1.10 Instrument Bus PO6 supplies power to FIC-*-626, which fails high when it
loses power, resulting in MOV-*-626 going closed.
2.1.11 Loss of power to PT-*-403 prevents the automatic functions of PORV-*-456
from opening the valve.
2.1.12 (Unit 3) Instrument Bus 3P06 supplies power to Steam Generator 3C Auto
Manual Station (FC-3498F): located on the console. Loss of 3P06 results in
all lights at FC-3-498F going out and Stcam Generator 3C Feedwater Flow
Controller (FC-3-498) in the process control racks transferring to auto
lockup.
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Page 5
BD-ONOP-QQ3.6 Loss of l2OV Vital Instrunlent Panel PO6 10/7/02
BASIS DOCUMENT
2.2 Alarms
2.2.1 Panel F, Window 1i2 is a common annunciator indicating the receipt of any
of several local inverter alarms.
2.2.2 Panel B, Window 6/S reflects a loss of voltage to a NIS power range module.
2.2.3 Panel 3, Window 7il reflects the actuation of an NIS Rod Drop Relay which
in turn generates an auto rod withdrawal stop signal. (NC-41KX).
2.2.4-
2.2.12 Alarms are the result of a ioss of power to the relays allowing them to
makeup the alarm circuits.
2.3 General
2.3.1 Self Explanatory
2.3.2 Self Explanatory
3 .O ImFERENCES/RECOKDS REOUIRED/COMMITMENIDOCUMEKTS
Self explanatory
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Page 6
BD-BNOP-003.6 Loss of lZOV Vital Instrument Panel *PO6 10/7/O2
BASIS DOCUMENT
PROCEDURE STEPS
I This cawfion alerts the operator to a potential automatic reactor trip.
I
. . . . . . . . . . . . NOTES ............ 1
I I
I
,I
Immediate actions are those actions which the operator should be able to perform
e
before opening and reading the emergency procedures. Alfhough the operator
I
should memorize immediate actions, they need not be memorized verbatim. The
I operator should know them well enough to complete the intent of each step. I
@ I
Provides reminders that *PO6 is the RED channel and that Enclosure I is available to
1 determine what functions, indications, and controls are lost. I
.........................
I. This step checks if a reactor trip has occurred. If a reactor trip has not occurred the operator
is directed to check if a reactor trip is required. If a reactor trip is required, the operator is
directed to manually trip the reactor and perform EOP-E-0 concurrentiy. If a trip is not
required, the operator is directed to the applicable procedure step.
2. This step is written to direct the operator to check for loss of RHR if the unit is not
operating in MODES 1-3. hUtOmdtiC RIIR flow control is lost. MOV-*-750 fails closed
when PC-*-403 loses power and PCV-*-142 fails closed which may lead to an RCS
overpressure condition.
I
3. The loss of *PO6 directly affects the normal control of pressurizer pressure and level.
Operator attention to the pressurizer is necessary to maintain pressure and level in nonnal
ranges.
a. Minimizing the fill rate of the pressurizer will extend the time frame for recovery
without lifting a PZR PORV due to coniprcssing the bubble.
b. Power operated relief valve, PCV-455C, receives its control signal from prcssure
comparator, PC-444A. Upon loss of *PO6, PC-444A output signal locks up as is,
with the possibility of maintaining PCV-455C in the open position. For this reason,
pressurizer PORVs should be verified shut to prevent inadvertent depressurization of
the RC.S.
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Page 7
B%)-ONOP-003.6 Loss of 12OV Vital Instrument Panel "PO6 10/7/02
BASIS DOCUMENT
PROCEDURE STEPS
I e
Provides the operator with an alternate temperature indication for the VCT. I
I
e Reminds the operator to use caution when changing Excess Letdown Heat
I Exchanger temperatures. I
~,,,-------------------
4. Gives actions that must be taken to restore manual control of PRZ pressure.
a. The function of the Pressurizer Level control swFitch is to transfer the output of
pressurizer level channels I, II and 111 to level comparators LC-459C and I,C-46OC.
This allows flexibility of operation for testing and loss of channei conditions. On loss
of "'1'06, both pressurizer level channei I and IG46OC arc de-energized. Placing the
switch in CK3, CII? (position 3 ) selects out de-energized channe1 I lever transmitter,
LT-459, although LC-46OC remains de-energized.
b. Excess letdown is available and placing it in service wil1 assist in maintaining
pressurizer level.
e Channel I level protection circuits for A, B, and C Steam Generators introduce
a iow-low level signal ( I O percent) to the trip matrix upon loss of poweri
Reducing feed flww less than steam flow by 20 percent of full flow (0.665 x 10
b n l h r ) would compEete the reactor trip logic, even though 'steam generator
levels may &e normal. Caution must be used when reducing feed flow less
than steam flow to prevent a reactor trip.
e Self explanatory
8 Self explanatoay
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Page 8
BD-ONOP-003.6 Loss of 120V Vital Instrument Panel *PO6 10/7/02
BASIS DOCUMENT
PROCEDURE srws
I
I
5. Monitoring steani generator levels is important since *A Feedwater Flow Controller is in
manual. The operator must maintain manual control of *A Steam Generator lcvel to
prevent a reactor trip.
(Unit 3) The operator must maintain control of 3C Steam Generator level to prevent a
reactor trip. Monitoring steam generator levels is important since 3C Feedwater Flow
Controller is locked up at signal prior to vital bus loss. However, since no turbine runback
has occurred, feed!steam mismatch is slight or non-existent and any change in steam
generator level will be slow. Steam Generator 3C level adjustments may be made using
careful control of all steam generator parameters.
6. The operator is directed to niaintain key plant parameters stable.
7. The operator is directed to check if power has been restored to "P06. If conditions stabilize
and *PO6 is still not recovered, the operator is directed to perform the following:
a. Continue efforts to restore *PO6.
b. If pourer cannot be restored within the prescribed time frame a unit shutdown is
commenced to ensure compliance with Tech Specs. If the NPS determines the unit
cannot be shut down safely with the manual controls, the unit may be tripped and
stabilized using the EDP network.
c. If one hour has not elapsed and power is not restored to 'P06, the operator is looped
back to Step 1 to maintain the unit stable.
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Page 9
BD-OXO!?-003.6 Loss of 120V Vital Instrument Panel "PO6 10/7/02
BASIS DOCUMENT
PROCEDURE STEPS
It is possible to shin the controller to AUTO approximately 95 seconds after the
MANUAL rigfit comes on; however, the controlkr should remain in MANUAL until
vital bus power has been completely restored. This prevenfs operating the
controller in AUTO with deeflergized controiier input signals and a k a allows iflput
signals to stabilize.
'
I
e When power is restored to a ManualMuto station, the AUTO light comes on. In
approximately 15 seconds, the MANUAL light comes on and the AUTO light goes off. I
I
I Manual control is available at the time the MANUAL Light comes on. I
' During Law Pressure OPS (Shutdown) PORV-456 has dual power feeds. boss of
I
I
I *PO64 will cause PT-403 to de-energize and disable the auto open feature of this
PORV. This loss will not result in an indication in the Control Room for the PORV.
I
Refer to Technical Specification for PORV operability.
~ , , _, __ _- __ - _ __ __ - - _- - _ - J
8. When the Vital AC bus is restored, all altered controls should he returned to normal
alignnients before continuing power operations.
a. Manual control of pressurizer level is restored using Attachment 4.
b. Steam generator level control is restored by matching steam flow and feed flow on
each steam generator and then placing the feedwater regulating valve controls to
automatic.
c. The operators are directed to use Enclosure I to restore the remaining affected
controls to automatic. Caution should be used to ensure the process signals are stable
and ready to be returned to automatic.
d. Self explanatory
9. The Kuclear Plant Supervisor will determine the appropriate plant procedure to be used for
continued operation.
Page 10
BD-ONOP-003.6 Loss of 120V Vital Instrument Panel "PO6 10/7/02
ENCLOSCRE 1
Provides a comprehensive list of lost functions, indications. and controls not specifically addressed
in the procedure. Knowledge of' these functions, indications, and controls is important if vital
instrument power is not restored promptly.
ATTACHMENT 1
1. This step directs the operator to attempt to restore *POA.
a. Inverter *C is located in the Inverter Room adjacent to the Chtrol Room,
b. Opening inverter *C output breaker isolates the failed inverter from *PO6
2. This step prepares *PO6 for restoration.
a. Opening all breakers on *PO6 prevents current surges when *PO6 is reenergized,
b. Opening *P21 breakers also prevents current surges upon reenergizing the vital bus.
3. Ensuring the &PO6 is not being powered by the CS inverter prevents parallel powering of
3PO6 and 4POh. If CS inverter is powering &PO6, discontinue this procedure.
4. If &PO6 is being powered by CS inverter, the Nuclear Plant Supervisor should be notified.
The course of action at this time will depend on the status of LJnit & and the &C inverter.
WB7:lbclsw
Page 11
RD-ONOP-003.6 Loss of 12OV Vital Instrument Panel "PO6 10/7/02
AI'TACIIMENT 1 (Cont'd)
It is possible to align the output of the spare inverter CS to vital buses 3P06 and
4806 simultaneously. Adthough inverter CS load capacity is sufficient to power both
buses, parallel operation of two vital buses on one inverter is prohibited. This
prevents a single failure (inverter CS) fr5m impacting h : h units (3806 and 4P06)
simultaneously.
5. If available, the step transfers "PO6 to the spare inverter by providing instructions
for placing the spare inverter in service.
a. Designated switch operation is performed at Vital Instrument Panel "P06A. Placing
the Vital Instrument AC ScIector Switch *P06A to the ALTERNATE SUPPLY
Sl'ANDBY INVEKTER CS position, places the C S spare inverter in service.
I
b. Alternate source Transfer Switch *Y05R is located in the Inverter Room.
(1) Placing the Alternate Source Transfer Switch in the BACKUP TO SPARE
IXVERTER C S position, ensures that the CVT will be available to carry Vital
Instrument AC loads in the event Spare Inverter CS fails.
c. Placing the Synch Selector Switch in the NORMAL position, enables the inverter to
adjust its frequency to match that of the *Y053CVT.
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Page 12
BD-ONOP-003.6 Loss of 12UV Vital Instrument Panel *PO6 10/7/02
BASIS DOCUMENT
ATTACHMENT I (Cont'd)
Warns the operator about amperage !imitations.
6. Keeps the Control Room aware of what actions are being taken or are about to be taken in
the field.
7. With CS inverter supplying power to *P06, vital loads may be energized by plac.ing the
fiollowing breakers to the ON position:
a. Placing *P06-Main to ON energizes the supply side of all *PO6 ioad breakers.
b. *PO6-4 energizes relay LC-46OCX. Manual operation of LC-46OCS may now be
discontinued.
c. 3PO6-8 energizes Steam Generator 3C Auto Manual feedwater controller. Steam
Generator 3C: may then be controlled in manual. (Unit 3 ONLY)
8. Attachment 3 lists loads on Vital Panel *PO6.
9. Attachment 2 lists loads on Sub-panel "P2I.
IO. This notification permits the Control Room to return to normal indication and control of
reactor plant parameters.
ATIACMMENT 2
Provides the required breaker alignnrent for panel *P06.
A'I'TACHMENT 3
Provides the required breaker aiignmcnt for panel *P2 1
ATTACHMENT 4, Seetion 1
?'his attachment gives necessary instructions for mariually controlling pressurizer pressure and
level when *PO6 is de-energized, and for restoring pressurizer level and pressure controls when
- PO6 is restored.
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Page 13
RD-ONOP-003.6 Loss of 120V Vital Instrument Panel *PO6 10/7/02
BASIS DOCUMENT
ATTACHMENT 4, Section 1 (Contd)
Self explanatory
..---------
1. The loss of *PO6 directly affects the normal control of pressurizer pressure and level.
Operator attention to the pressurizer is necessary to maintain pressure and level in normal
ranges.
a. Power operated relief valve, PCV-45SC, receives its control signal from pressure
comparator, PC-444A. PC-444A output signal locks up as is on loss of power with
the possibility of maintaining PCV-455C in the open position. For this reason.
pressurizer PORVs should be verified shut to prevent inadvertent depressurization of
the RCS.
b. On loss of *P06, both pressurizer level channel I and LC-460C are deenergized.
Placing the switch in CH3, CH2 (position 3 ) selects out de-energized channel I level
transmitter, LT-459, although I,C:-460C remains de-energized.
e. *PO6 supplies power to the pressurizer level comparator, I.C-4hOC. On loss of *PO6
and I,C-460C:, pressurizer level c.omparator relay LC-460CX de-energizes and
operates contacts in the control circuits for letdown isolation valve LCV-460, orifice
isolation valves, 2 0 0 4 200B and 200C, control group heaters and backup group
heaters. As a result, all pressurizer heaters are de-cnergized and letdown flow is
isolated. Io regain normal control of pressurizer heaters and letdown flow,
LC-460C.X must be operated manually. LC-46OCX is a type BF re.lay located
adjacent to LC-459CX in the front of h x . Relay Rack 46. The relay is manually
operated by depressing the pushbutton located on the relay face. This method of
regaining pressure control was chosen because it does not defeat the low level
protection feature. If an actual low level signal is present, reiay LC-459CX will
de-energize pressurizer heaters, preventing heater damage. It is important here to
note that only relay LC-46OCX should be held in. Do not attempt to hold in both
relays.
Page 14
BD-ONOP-003.6 I,oss of 120V Vital Instrument Panel "PO6 10/7/02
BASTS DOCUMENT
ATTACHME:NT 4, Section 1 (Cont'd)
d. Noma1 control of pressurizer heaters is now available and may be operated if
necessary to return pressure to normal.
e. Actions required to restore letdown,
2. If operating pressurizer heaters does not increase RCS pressure, Pressurizer Spray Valves,
PCV-45SA and 13 may he partially open. On loss of *P06, Spray Valve Auto Manual
stations (PC-444G and H) are de-energized, causing their associated automatic controllers
(PC-444C and D) to lock up as is. The spray valves then remain in the same position as
they were when *PO6 was lost. To shut PCV-455A and B, proceed to the front of Rack 20
and de-energize PC-444C and D by removing the power fuses located on the face of each
controller. Spray Valve proportional controllers now sense a zero volt input and shut the
spray valves.
3. If the preferred method of restoring pressurizer heaters and letdown flow are not successful,
the operator is given alternate methods below.
a. Provisions have been made for local control of pressurizer heater backup group A in
the IJnit 3 West (Unit 3 Worth) electrical penetration room. A localiremote selector
switch and startktop pushhuttons are located near heater group A breaker panel. To
gain local control, place the selector switch in the local position. Operate the heater
group with the start.r(istoppushhuttons as needed to control pressurizer pressure. Iocal
status lights indicate breaker position. An annunciator at Panel F in the Control
Room indicates local control of hackup group A. This method of heater control
bypasses low pressurizer level heater protection. The heaters must he manually
de-energized if pressurizer level drops below 14 percent.
b. Holding the control switches in open will bypass LC-46OCX contacts in the valve
control circuits, allowing valves to open.
ATTACHMENT 4 Section 2
1, Provides actions to restore pressurizer controls.
a. With power restored LC-46OC and pressurizer level is greater than 14 percent, noimal
pressurizer heater and letdown c.ontro1 should he available.
b. This action will restore normal operation of the pressurizer spray valves.
c. Self explanatory
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Page 15
BD-ONOP-003.6 Loss of 120V Vital Instrument Panel *PO6 10/7/02
FOLDOUT PAGE
1. Self explanatory I
2. Self explanatory I
3. Feedwater isolation will not occnr following a reactor trip with Tavg less than
554°F because power is lost to the feedwater isolation circuit. Therefore, if a reactor
trip has occurred, feedwater isolation is provided by closing the feedwater isolation
MOVs.
W97:lbclsw
1 of3
Florida Power 8r Light Company
Plant Turkey Point - Nuclear
1.8 REVIEW AND APPROVAL
Operations Supervisor: 4 .--, -
J -&-CI-eq
Date .
Operations Manager:
Date
THIS INSTRUCTION EXPIRES FEBRUARY 13,2004
2.1 To provide the Control Room Operators Manual Reactor Trip Guidelines to
be used during operation of the plant. Guidelines which will allow the
operator to manually trip the reactor and turbine pgor ta reaching an
automatic trip setpoint.
3.69 SCOPE
3.1 This instruction applies when either wit is in Modes 1 or %
3.2 This instruction does not conflict or supersede any approved p l m t
procedures OF Quality Instructions.
3.3 On-Shift personnel shall adRere to the following guidelines during operation
of the plant to allow precluding an Automatic Trip.
.
4.0 RESPONSIBILITIES
4.1 The Nuclear Plant Supervisor is responsible for:
4.1.1 Ensuring that all On-Shift personnel diligently monitors the Control
Room and Plant instrumentation for adverse trends.
4.1.2 Ensuring that if one of these setpoints is reached or if control d the
plant is in question that a preemptive trip is called for. h p i d l y
changing parameters need not requlre reachrng one of these setpoints
prior to ordering a Manual Reactor Trip.
4.2 All &-Shift Licensed Operators are responsible for:
4.2.1 Taking timely and proper actions to ensure safe operation of the
facility.
4.2.2 Initiating Engineered Saf~guardsFeatures or Reactor a%ipActuation
if indicators exceed automatic setpoints.
4.2.3 Informing the NFWANPS, and taking action should amy Manual %p
Guideline be exceeded.
__
5.0 _INSTRUCTIONS
_ __ ~ ~ - - ~- _ . _ _ -
5.1 IF one of these setpoints is reached or a preemptive trip is called for %HE
?hip the Reactor and Turbine AND go to E-0 Reactor Trip or Safety
Injection.
33Ee MANUAL SETPOINT
Source Range Hi Flux Any unex lained increase in
Intermediate Range Hi Flux
8
Reactor ower, IR amps, or
Source Counts
Power Range Hi F l u Lo Setpoint
Power &nge Hi Flux Hi Setpoint Power at 103%and increasing
Pressurizer Lo Pressure 2000 psig decreasing
Pressur6zer I%iPressure 2350 psig
ko Steam Generator Level 15%Narrow Range
Pressurizer High Level At 80% on 2/3 channels
e +
3of3
ODI-CO-023 M L 4 N U A L ~ W O RTRIP GuBlELINEs
04/01/82
8
5.2 IF an of these idelines are exceeded and Reactor Power is ABOVE 10%
9
THEd !l%p the eactor AND Turbine and go to E-0, Reactor Tsip or Safety
Injection:
TaDp W A I L SETpOllyT
24.5 Inches of Vacuum
.
Lo Vacuum Rgwe
Decreasing< 531
22 ~nchesoTVacuum Decreasing >
531 W e
S/G Hi Level 75%N a m w Range
5.3 IF an of these guidelines are exceded AND Reactor Powqr is BELOW 18%
T I d , Trip the Turbine and Maintain Stable plant condltlons
'PRIg MANUAL SETPOINT
LO Vacuum 24.5 Inches of Vacuum Decreasing
S/G Hi Level 75%Narrow Range
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Turkey Point 2003 NRC Written SRO Exam
Post-Exam Review Recommendations
December 18,2003
Q# 3 3 . Irovide credit to Tim Scott for this question.
At the conclusion of the written exam, the proctor collected all exam materials
from each appricant, including Tim Scott. Subsequently during an informal
grading ofthe exams, it was noted by the grader that Mr. Scott had correctly
identified response con his exam but had bubbled in response D on his
scantron form.
It was noted that Mr. Scott had annotated Stm Space LOCA on his question,
indicating that he understood what the question was trying to test.
It was also noted that Mr. Scotts error may have been his lack of experience with
5-response type scantron forms. Ail scantron graded exams at Turkey Point w e
4-response forms. On a 4-response form, the C response is the second from the
right. Mr. Scott filled in the response that was second from the right.
IJnfortumteiteiy on a 5-reponse scantron form, the second-from-right response is
D.
Mr. Scotts original Q# 33 is attached. Note that this error was discovered
immediately following the time when he turned the exam in. This original Q#33
was removed from the rest ofthe exam and has been under our control, stored in
the exam room vault since that time. Mr. Scott has not had access to this question
since turning his exam in.
A comparison of ail of the questions on Mr. Scotts exam and his scantron sheet
revealed no additional errors of this nature.
Document Provided:
Tim Scotts original Q# 33
Turkey Point Nuclear Plant 2003-301
SRQ inital Exam
33.
The crew is FeSpOfldiflg in accordance with E-1, Loss of Reactor or Secondary Coolant.
Pressurizer level has risen continuously even though the RCS pressure has been
dropping steadily. All Reactor Coolant pumps are in operation.
Which ONE of the foilowing leak locations is consistent with the plant conditions just
described? :.
-.,?I ,:.r
. L
c:
,, \.,6.,(.: *. .<, [ : , /&
Weld break on:
%<the pressurizer(r sample line.
\
-.
EL,, one of the CRBM nozzle penetrations
6.the line to Pressurizer PORV Block valve MQV-536.
9:the Charging header connection to the WCS.
i
Turkey Point 2003 NKC Written SRO Exam
Post-Exam Review Kecommendations
December 18,2003
Q# 46. Accept either c or D response as correct.
Note that the question stem states that RCS temperature is increasing, implying 3
changing, dynamic plant condition.
As the operators progress through ONOP-050 unable to start any m R pumps,
Step 5 RNO will transition them forward to Step 20.
At Step 22 with two Steam Generators available, they d l establish secondary
fecd and open steam dump to atmosphere valves to stabilize RCS temperatures.
This admission of secondary feed to the steam generators and opening stem1
dump valves will quickly cool steam generators which will automatically
establish natural circulation.
These very same actions also remove the last impediment to starting an RCI (S/G
secondw water 20 higher than RCS temps) allowing RCI start.
Katural circulation is the preferred method of heat removal; until the process of
starting an RCP is compkte. Then the prefemd method will be forced circulation
via the running RCP.
Responses c and D are both correct.
References Provided:
3-ONOP-050, LOSS of RHR.
Florida Power & Light Company
Turkey Point Nuclear Plant
Unit 3
Title:
P
I
Responsible Department:
Revision Approval Date:
Operations
2 0116/98C 1
RTSS 93-1422P, 94-0349P. 94-1102P, 95-0957P, 95-1022P, 96-1534P
I
I
96-1456P, 98-0588P, 98-0929P
BClM 89-332;96-081
OTSC 0412-95
LIST OF EFFECTIVE PAGES
Revision
Date
1 10116198C1
2 10/16/98C1
3 lO/l6/98
4 1Oil 6/98
S 1O/ 16/98
6 10/16/98
4 10/16/98C
8 I0/16/98
9 10/16/98
10 I0/16/98
11 10/16/98
12 1O/l6/98C
13 10/16/98
14 10/16/98
1s 1O/I6/98C
16 10/16/98C
14 10/16/98
18 10116198
19 1Oil 6/98
20 10/16/98
21 10116/98
22 1O/l6/98
23 10/16/98
24 1O/ 16/98
25 1Oil 6/98C'
26 10/16/98
27 10/16/98
PURPOSE
1.I This procedure provides instructions to be followed in the event o f a loss offlow in the
RIlR system.
SYMYI'OMS OR EWI'RY CON1)I'I'IONS
2.1 Annunciators
2.1.1 H 612, RIIR HX HL'LCP FLOW
2.1.2 H 6/4, RHR PP MB TRIP
2.1.3 I 716, RHK SUMP PUMP ROOM A 11LEVEL
2.1.4 I 816, KHR SUMP PUMP ROOM B HI LEVEL
2.1.5 I3/6,RHR SUMPIIX ROOMEIELEVEI.
2.1.6 I 713, RX VESSEL DK4INDOWK ID-LO-LEVEL
2.1.7 A 711, PRT IWLO LEVEL HI PRESS1TEMP
2.1,s A 916, RKK MOV-750i751 LETDOWN ISOLATION
2.2 Indications
2.2.1 Neither RHR pump is operating when required for decay heat removal
2.2.2 Loop 3C RHR Suction Stop Valve(<), MOV-3-750 or MOV-3-751, indicate
closed when RHR is required for dec.ay heat removal
2.2.3 Rapid increase in RCS pressure and OMS actuation when the KCS is solid
2.2.4 I n w flow indicited on FI-3-605
REFKRENCEWRECORDSKEOCIRED/COMMII~~ENT nocmiEms
3.1 References
3.1 . I Technical Specifications for Turkey Point IJnit 3 and IJnit 4
3.1.2 'Turkey Point Unit 3 and Unit 4 Final Safety Analysis Report
3.1.3 Ooerating Diagrams
I. 5613-M-3050, Residual Heat Removal System
I 2. 5613-M-3062, Safety Injection System
3.1.4 Procedures
1. 3-ONOP-030, Loss of Component Cooling Water
2. 3-ONOP-011.3, Excessive Reactor Coolant System l.edkage
3 . 3-ONOP-041.8, Shutdown LOCA [Mode 5 or 61
4. 3-OP-04 1.I Reactor (:oolant Pump
I
5. 3-OP-050, Residual Heat Removal System
6. 3-OP-073, Condensate System
7. 0-OP-074.1, Standby S/G Feedwater System
3.1.5 Plant Change!Modifications
1. PC/M 89-332, Generic Letter 88-17, Loss of Decay Heat Removal
Programmed Enhancement - RCS Redundant Level Monitors
2. PC!M 96-081, Setpoint Change for RCP Seal Leakoff Low Flow
3.1.6 Miscellaneous Documents
1. JPK-PTN-SEMJ-89-094, Adequacy of Core Cooling
2. JPN-PlN-SEEP-92-009, Substantial Safety Hazards Evaluation Related to
Pressurizer Vents at Cold Shutdown
3 , Westinghouse Technical Bulletin ESBU-TU-93-01~Revision 1
4. Westinghouse EOP Rev 1C Changes
3.2 Records Reauired
3.2.1 None
3.3 Commitnient Documents
3.3.1 NRC Inspection Report 89-053, March 14, 1990
3.3.2 NRC IEIN No.86-101, Loss of Decay Heat Removal Due to Loss of Fluid Levels
3.3.3 NRC Generic Letter 88-17, L.oss of Decay Heat Removal
3.3.4 NRC IN-92-16, L.oss of Flow from the Residual Heat Removal Pump During
Refueling Cavity Draindown
3.3.5 INPO SOER 85-4, Loss or degradation of Residual Heat Removal Capability in
PWRS (CTRAC No. 85-1178-34)
3.3.6 INPO SER 17-86, Loss of Shutdown Cooling Flow (C1'RAC No. 87-0823)
3.3.7 INPO SER 23-86, Loss of Decay Heat Removal FIow (CTRAC No. 86-0982)
3.3.8 INPO OE-1744, RRR Gas Binding Due to Erroneous Half Loop Indication
(CTKAC NO. 85-1 178-34)
3.3.9 N P O SER 9-92, Loss of Residual Heat Removal with Reduced Reactor Vessel
Water Level
3.3.10 JPN-PTN-SE.NP-9.f-026,CCW Flow Balance and Post-Accident AIignment
Requirements to Support Thermal Up-Rate (LER 250!95-006)
RESPONSE NOT OBTNNED
I
I If leakage from the RHR system is discovered, the leak should be isolated using
3-ONOP-041.3, EXCESSIVE REACTQR COOLANT SY§TEM LEAKAGE.
I
1 e If loss of RHR is due to a loss of off-site power capability, power and RHR flow should I
I be restored utilizing 3-ONOP-004, LOSS OF OFFSITE POWER or 3-EOP-ECA-0.0. I
LOSS OF ALL AC. Buring a loss of power, this procedure should be used to establish
I containment closure and alternate cooling if RHR flow remains unavailable. I
L,-------..---------------
1 Dispatch An Operator Po Monitor W H W
Pwrnps AB Follsws:
a. Obtain radio
b. Monitor RHR pump locally
e. Maintain communication with control rcom
d. Stay near RtiR pump until normal RHR
flow is restored
ACTlONlEXPECTED RESPONSE I I RESPONSE NOT OBTAINED
~--"---s,---,---,--a----
-E
NOTE
I RCS heatup rate is required to be monitored by the Shift Engineer or any availabie
I
operator while efforts continue to restore RHR cooling.
I
- - - - - - - _ - - _ L - - - - _ - - - _ _ - - - -
I
2 Monitor RCS Heatup Rate As FOIIOWS:
a. Plot core exit temperature every minute a. E core exit temperatures are
for 5 minutes available, lJ&l perform the following:
1) Assume a 12°F per minute heatup
rate unless the refueling cavity is
flooded. the refueling cavity is
flooded, T#EN use 4°F per minute.
2) Observe NOTE prior to Step 3 AND
go to Step 3
b. Calculate RC§ heatup rate
c. Determine time required to reach
saturation in RCS
d. Report results to unit RCO and NPS
e. Repeat this step every 15 minutes until
RHR cooling is Restored
Y97IDHldaj
II ACTlONlEXPECTED RESPONSE I I RESPONSE NOT OBTAINED I
II 1 interrupt feafure for MOV-3-750 and MOV-3-751 is only functionai with OMS in LO PRESS I
I OQS.
..........................
I
3 Check Loop 36 RHR Pump Suction Stop
Valves OPEN
~
Perform the following
a. Stop RHR pumps.
MBV-3-750
- MBV-3-751 b. E a momentary pressure spike has
caused either or both valves to start
closing, THEN perform the following at the
Pushbutton Interrupt switches:
1) Determine affected valve(s).
a Yellow light -ON
2) Verify over pressure signal NOT
present:
Blue light -ON
3) Push Interrupt Pushbutton for affected
valve(s).
4) Verify yellow light DE-ENERGIZES.
5) blue light BE-ENERGIZES ,
r"verify affected valve(s) - OPEN.
6) Go to Step 4.
c. E RCS pressure GREATER THAN
525 psig, TnEN perform the following:
1) Stop the charging pump(s).
2) Reduce RCS pressure to 450 psig
d. Loop 3C RHR Pump Suction Stop
Valve(s) were NOT closed to isolate
system leakage, THEN reopen RHR Loop
Suction Stop Valve(s). either valve can
-
NOT be opened, THEN direct an operator
to locally reopen Loop 3C RHR Pump
Suction Stop Valve(s).
e. either valve can NOT be reopened,
THEN observe NOTE prior to Step 20
-
AND go to Step 20.
..
5 Check RHR Bumps- ANY RUNNING Perform the following:
Close RHR Heat Exchanger Outlet Flow
valve, HCV-3-758.
Close RHR Heat exchanger Bypass Flow
valve, FCV-3-605.
Verify MOV-3-750 and MOV-3-751 -
OPEN
Attempt to restart previously running RHR
Pump.
IF previously running RHR pump can
be started, THEN start alternate RHR
Pump.
-
IF neither RHR pump can be started,
THEM perform the following:
1) Direct appropriate personnel to
restore at least one RHR pump to
operable status.
2) Observe NOTE prior to Step 20 &Q
go to Step 20.
Return RHR Heat Exchanger Bypass
Flow valve, FCV-3-605, to AUTOMATIC
operation at desired flow.
Open RHR Heat Exchanger Outlet Flow
valve, HCV-3-758, as necessary to
maintain desired RCS temperature.
6 Verify RHR Pump NOT Cavitating Go to Step 42
e Running RHR pump amps - STABLE
c RHR flow - STABLE
RHR pump noise level - NORMAL
7 Check For WHR Flow Control Valve Failure
a. Verify RHR Heat Exchanger Bypass Flow. a. Go to Step 8.
FCV-3-605 - MAINTAINING DESIRED
FLOW IN AUTOMATIC
b. Go to Step I 8
ACTIONIEXPEGTED RESPONSE RESPONSE NOT OBTAINED
8 Control RHR Bypass Flow
a. Manually control RHR Heat Exchanger a. Perform the following at the 10 foot
Bypass flow, FCV-3-605. to establish elevation platform in the RHR Heat
desired flow Exchanger room to locally control RHR
flow:
1) Remove seal and place Safe
shutdown FCV-3-605 Manual Control
Air Isolation Valve, 3-40-1895. in
MANUAL.
2) Verify Safe Shutdown FCV-3-605
Manual Control Air Vent Valve,
3-40-1896. in NORMAL.
3) Adjust Safe Shutdown FCV-3-605
Manual Controller, PCV-3-605, to
establish desired flow.
4) Observe CAUTION prior to Step 9
ANB) go to Step 9.
b. Go to Step 10
V37IDHldaj
RESPONSE NOT OBTAlNED
I
I If only two CCW Heat Exchangers are in sewice and MOV-3-74$,4 and MOV-3-7498
are pen, two CCW Bumps are required to be maintained in PUU-TO-LOCK~
I
9 Check Desired RHR Heat Exchanger Perform the following:
-
Bypass Flow, FCV-3-605 BEING
MAINTAINED USING SAFE SHUTDOWN a. Close RHR Heat Exchanger Bypass Flow
MANUAL CONTROL valve, FCV-3-605.
b. Open RHR Heat Exchanger Outlet Flow
Value, HCV-3-758. to establish between
3500and3700gpm.
c. Locally open breakers for RHR Heat
Exchanger Outlet Component Cooling
Water valves.
- 30617 for MOV-3-749B
- 30721 for MQV-3-749A
d. Control the cooldown by locally throttling
both of the RHR Heat Exchanger outlet
Component Cooling Water MOVs while
maintaining CCW flow through both RHR
Heat Exchangers.
- MOV-3-749A
- MOV-3-7498
10 Notify Appropriate Personnel To Correcl
RHR Flow Control Failure
I1 Verify RHR Pump NOT Cavitating Go to Step 12
a. Running RHR Pump
Amps STABLE
e Flow STABLE
- Noise level - NORMAL
b. Go to SteD 14
Y99iDHidaj
12 Reduce RHR Flow To Stop Cavitation
a. Adjust automatic setpoint for RHR Heat a. Perform the following:
Exchanger Bypass Flow, FCV-3-605, to
establish RHR flow between 1000 and 1) Take manual control of RHR Heat
1500 gprn Exchanger Bypass Flow, FCV-3-605,
to establish between 1000 and
1500 gprn.
2) manual control can NOT be
established, THEN perform the
following:
a) Remove seal and place SAFE
SHUTDOWN FCV-3-605
MANUAL AIR ISOLATION
VALVE, 340-1895, in MANUAL.
b) Verify SAFE SHUTDOWN
FCV-3-605 MANUAL CONTROL
AIR VENT VALVE, 3-40-1896, in
NORMAL.
c) Adjust SAFE SHUTDOWN
FCV-3-605 MANUAL
CONTROLLE R, PCV-3-605, to
establish between 1000 to 1500
wm.
13 Verify RHR Pump Cavitation Has Stopped Perform the following:
a Running RHR pump amps - STABLE a. Stop RHR pumps
- RHR flow - STABLE
RHR pump noise level - NORMAL b. Observe NOTE prior to Step 20 AND go
to Step 20.
V97lgrHidaj
14 Establish RHR Flow
a. Check RKR pumps -ALL STOPPED a. Go to Step 15.
b. Verify RCS temperature - LESS THAN b. Observe NOTE prior to Step 20 go
350°F to Step 20.
c. Close RHR Heat Exchanger Outlet Flow
valve, HCV-3-758
d. Close RHR Heat Exchanger Bypass Flow
valve, FCV-3-605
e. Start previously running RHR pump e. Start alternate RHR pump. neither RHR
pump can be started, TnEN observe
NOTE prier to Step 20 go to
Step 20.
f. Establish 1500 gpm RHW flow as fellows:
- Slowly open RHR Heat Exchange1
Outlet Flow valve, HCV-3-758
g. Check RHR Pump Cavitating g. Return to Step 22.
Check RHR pump amps - STABLE
Check RHR flow - STABLE
e RHR pump noise level - NORMAL
15 Increase RHR Flow
a. RHR flow is less than desired flow, a. E FCV-3-605 is fully open. THEN open
increase RHR Flow 500 gpm from RHR Heat Exchanger Outlet Flow valve,
current value as follows: HCV-3-758, to establish desired flew.
Adjust RHR Heat Exchanger Bypass
Flow valve, FCV-3-605
b. Verify RHR pump NOT Cavitating b. Perform the following:
Running RHR pump amps -STABLE 1) Decrease RHR flow 500 gpm from
Check RHR flow - STABLE current value.
e RHR pump noise level NORMAL
2) Return to Step 12.
c. Check RHR flow - GREATER THAN c. Perform the following:
EQUAL TO 3000 GPM
-
IF RHR flow is less than 3000 gpm
BUT increasing, THEN return to
Step 15a.
-
-
IF RHR flow can NOT be restored,
go to Step 16.
d. Go to Step 18
16 Check if RCS OPERATING DRAINED
~
Qbserve NOTE prior to Step 20 @Q go to
Step 20.
DOWN (LESS THAN 10% COLD GAL PZR
LEVEL)
17 GO TO ~ - O M Q P - O SnumowN
~~.~, LQCA
[MODE 5 OR 61
18 Maintain Stable Plant Conditions
a. Verify RCS temperature - STABLE SR a. Perform the following:
DECRASING
e Adjust HCV-3-758 to obtain desired
cooldown rate.
m Adjust FCV-3-605 to maintain desired
RHR flow rate.
b. Verifv RCS temmrature - LESS THAN b. Observe NOTE prior to Step 20 AND go
20o+ trending to NPS DESIRED to Step 20.
TEMPERATURE
19 Go to Step 34
N97/DHldaj
I RCS heatup rate is required to be monitored by the Shift Engineer or any other available
operator while efforts continue to restore RHR cooling.
II 1
b,-----------------------J
20 Continue To Monitor RCS Heatup Rate As
Follows:
a. Plot core exit temperature every minute a. core exit temperatures are NOT
for 5 minutes available, THEN perform the following:
1) Assume a 22°F per minute heatup
rate unless the refueling cavity is
flooded. the refueling cavity is
flooded, THEN use 4°F per minute
2) Go to Step 21
b. Calculate RCS heatup rate
c. Determine time required to reach
saturation in RCS
d. Report results to unit RCO and NPS
e. Repeat this step every 15 minutes until
RHR cooling is restored
V97iDHldaj
Isolate Containment If Required
a. Direct appropriate personnel to close any
open containment penetrations:
e Equipment hatch
Airlocks
Refueling transfer tube
0 Any other openings
b. Direct personnel to stop work on all RCS
openings
I
c. Check RCS temperature - GREATER c. WHEN RCS temperature is greater than
THAN 200°F 200T, =do Steps 21d, 21e, 21f, 219
and 21h. Continue with Step 22.
d. Announce over the plant PA system: d. Request NPS pass supervisory
announcement over radio to order
personnel out of containment.
Attention all personnel inside
Unit 3 Containment Evacuate Unit 3
Containment
e. Actuate Containment Evacuation Alarm
Announce over the plant PA system: f. Request NPS pass supervisory
f.
announcement over radio to order
personnel out of containment.
Attention all personnel inside
Unit 3 Containment Evacuate Unit 3
Containment
I 9. Actuate Containment Isolation Phase A:
1) Manually actuate containment
isolation phase A
2) Containment isolation phase A valve
2) E any containment isolation phase A
valve is MQT closed, TnEN manually
white lights on VPE -ALL BRIGHT close valve. E valve(s) can NOT be
manually closed, THEN manually or
locally isolate affected containment
h. Reset Phase A Containment Isolation
ACTIONEXPECTED RESPONSE I II RESPONSE NOT OBTAINED I
22 Establish Secondary Heat Sink
a. Verify at least two SIGs available: a. Perform the following:
Secondary side nianways - 1) e%: RCS temperature is decreasing,
INSTALLED THEN continue efforts to restore RHR
SM; hot leg manway - INSTALLED cooling AND go to Step 32.
Ll-3462 -GREATER THAN 10%
e RCS Loops - FILLED 2) RCS temperature is increasing,
THEN go to 3-ONOP-041.8.
b. Establish SIG makeup to the available b. Perform the following:
SIGs using one of the following methods:
I)E RCS temperature is decreasing,
- Start a standby feedwater pump using THEN continue efforts to restore RKR
0-OP-074.1, STANDBY STEAM cooling AND go to Step 32.
GENERATOR FEEDWATER
SYSTEM 2) E RCS temperature is increasing,
THEN go to 3-QNOP-041.8.
SHUTDOWN LQCA [MODE 5 OW 61
- Start a condensate pump using
3-OP-073, CONDENSATE SYSTEM
-
- Start a condensate transfer pump
aligned to SIG fill line
c. Open available SI6 Steam dump to
atmosphere valves as necessary to
maintain desired RCS temperatures
I RESPONSE NOT OBTAINED
I I The effectiveness of steaming the available SlGs may NOT be readily apparent during
I natural circulation. Rant conditions should be allowed to stabilize prior to performing
1
23 Determine if Blowdow~aShould Be
Established
a. Core exit temperatures - INCREASING a. Go to Step 26
b. Available SIG steam dump to atmosphere b. Open available SIG Steam dump to
valves FULL OPEN
~ atmosphere valves as necessary to
maintain desired RCS temperatures.
RCS temperature can be controlled using
steam dump to atmosphere valves, THEN
go to Step 26.
I I &proval Date: I
ACTIONIEXPECTED RESPONSE I I RESPONSE NOT OBTAlNED I
24 Align Blowdown From Available S/G(s)
a. Verify RE-19, SIG Blowdown Radiation a. Direct Nuclear Chemistry to sample
Monitor. - INSERVICE available SIG(s) for activity.
6. Prepare for blowdown: b. Go to Step 26
1) Place blowdown keylock switch(s) for
available SIG(s) in DRAINIFILL
position:
HS-3-1427X for SIG A
HS-3-2426X for SIG 5
e HS-3-1425X for SIG C
2 ) Verify S I 6 Liquid Sample valve(s) on
availabie S/G(s) -OPEN:
MOV-3-1427 for SIG A
MOV-3-1426 for SIG E
0 MOV-3-1425 for SI6 C
3) Verify Blowdown Flow valves
CLOSED:
FCV-3-62788
FCV-3-6278B
FCV-3-6278C
4) Locally close SIG blowdown Manual
Containment Isolation valve(s) on
available SIG(s):
SGB-3-007 for SIG A
SGB-3-008 for SIG B
SGB-3-009 for SIG C
5) Open Blowdown Containment
Isolation valve(s) on available SIG(5):
CV-3-6275A for S/G A
CV-3-6275B for SIG B
CV-3.62756 for SIG C
6 ) Locally open SIG Blowdown Manual
Containment Isolation valve(s) on
available S/G(s):
0 SGB-3-007 for S/G A
SGB-3-008 for SIG 5
= SGB-3-009 for SIG C
I STEP I i ACTIONIEXPEGTED RESPONSE I 1 RESPONSE NOT OBTAINED
I I
II
25 Establish Blowdown From Available SIG(s)
a. Align blowdown to discharge canal:
1) Open Blowdown Tank Vent To
Atmosphere, CV-3-6267A
2) Close Blowdown Tank Vent To
Feedwater Heaters, CV-3-6267B
3) Close Blowdown Tank To Condenser,
HIS-3-6265A
4) Open Blowdown Tank to Canal, HIS-
3-62658
b. Locally throttle open Blowdown Flow
Valve on available S/G(s)to obtain
maximum flow
e FCV-3-62788 for S/G A
FCV-3-6278B for SIG B
FCV-3-6278C for S/G 6
26 Maintain Level In Available S/G(s)
2. Check narrow range levels GREATER
~
a. Increase SIG makeup to available S/G(s).
THAN 6%
b. Continue SIG makeup to maintain narrow
range level between 6% and 50%
27 Determine If One RCP Should Be Started
a. RCS - INTACl a. Go to Step 32
b. Verify RCS Cold Leg Temperature s
b. Perform the following:
GREATER THAN 275°F
1) Locally obtain S/G secondary
temperature measurements. Refer to
3-OP-041.I, Reactor Coolant Pump,
for methods of obtaining S/G
temperatures.
2) any SIG secondary water
temperature is greater than 10°F
above any RCS cold leg temperature,
V go to Step 32.
2% Check Plant Conditions For Starting Perform the following:
Desired RCP
1. Verify natural circulation using
a. A or B 4KV bus - ENERGIZED FROM ATTACHMENT 1. natural circulation
STARTUP TRANSFORMER can NOT be verified, THEN increase
dumping steam.
b. Number one seal AP - GREATER THAN
200 PSIB 2. Go to Step 32.
c. Thermal barrier AP -GREATER THAN
0 INCHES OF WATER
d. Verify proper number one seal leak-off
flow - GREATER THAN 0.8 GPM
e. RCP number one seal leak-off
temperature LESS THAN 225°F
RESPONSE NOT OBTAINED
I
CCW System load requirements of 3-OP-O3Or COMPONENT COQLlNG WATER
SYSTEM, shall NOTbe exceeded.
29 Maintain Proper CCW System Alignment
For RCP Operation
a. CCW Heat Exchangers THREE IN a. Perform the following:
SERVICE
1) Start or stop CCW pumps as
necessary to establish ONLY ONE
RUNNING CCW PUMP.
2) E MOV-3-749A and MOV-3-749B are
open, stop and place in PULL-
TO-LOCK all except one running
CCW pump.
3) 60 to Step 2 9 ~ .
b. CCW pumps - ONLY TWQ RUNNING b. Start or stop CCW pumps as necessary to
establish ONLY TWO RUNNING CCW
PUMPS.
c. Check CCW from RHR Heat Exchangers c. Perform the following:
- A T LEAST ONE CLOSED
1) Isolate one Emergency Containment
e MOV-3-749A Cooler by placing one ECC Control
e MOV-3-749B Switch in STOP, then go to Step 29d
2) unable to isolate one ECC, THEN
stop all RCP's verify natural
circulation using ATTACHMENT 1.
Go to Step 32.
d. Verify B CCW header flow - NORMAL d. Perform the following:
1) Verify natural circulation using
ATTACHMENT 1. E natural
circulation can be verified,
increase dumping steam.
2) Go to Step 32
Y97/DH/daj
ACTlONlEXPECTED RESPONSE RESPONSE NOT OBTAINED
30 Establish Proper CXW Vatve Alignment For
RCP Operation
a. RCP Thermal Barrier CCW Outlet, a. E containment isolation phase B
MOV-3-626 -OPEN actuated, CCW radiation levels are
normal. and RCP number one seal Ieak-
off temperature is less than 225"F, THEN
manually open MOV-3-626.
MOV-3-626 can NOT be manually
opened, THEN direct the operator to
locally open MOV-3-626.
6. Verify the following valves - OPEN b. containment isolation phase 5 NOT
actuated, THEN manually open MOV(s).
IF MOV(s) can NOT be manually opened,
THEN direct operator to locally open
MOV-3-730, RCP Bearing CCW MOV(s).
Outlet
c. Open CCW Po Normal Containment
Cooler valves
MOV-3-1417
- MOV-3-1418
d. Reset and start normal containment
coolers
rV97lDHidai
RESPONSE NOT OBTAINED
I
I P
1 if possible, RCPs B or C should be run to provide normal PZR spray. RCP A does MOT I
I provide adequate spray flow. 1
b-,,,,,-,,--,------------~
31 Try To Start One RCP
a. Start oil lift pump
b. Check that the oil lift pump has been b. WHEN 2 minute oil lift pressure time delay
running - AT LEAST 2 MINUTES is satisfied, THEN verify Permissive To
Start light ON &Q perform Steps 31c,
31d and 31e. Continue with Step 32.
c. Start one RCP c. Perform the following:
1) Verify natural circulation using
ATTACHMENT 1. E natural
circulation can be verified, THEN
increase dumping steam.
2) Stop oil lift pumps.
3) Go to Step 32
d. Check that the RCP has been running - d. WHEN RCP has been running greater
GREATER THAN 1 MINUTE than 1 minute, THEN stop oil lift pump
AND continue at Step 32.
e. Stop the oil lift pump
32 Maintain Stable Plant Conditions:
a. Maintain PZR pressure - STABLE
b. Maintain PZR level - STABLE b. PZR level can NOT be maintained,
-
THEN perform 3-ONOP-044.3,
EXCESSIVE REACTOR COOLANT
SYSTEM LEAKAGE while continuing with
this arocedure.
c. Maintain intact SIG narrow range levels -
STABLE
d. Maintain RCS average temperature -
STABLE AT DESIRED TEMPERATURE
N97IDHMaj
33 Verify RHR Flow Restored Return to Step 14
34 Go To Appropriate Plant Procedure As
Determined By The Nuclear Plant
Supervisor
END OF TEXT
ATTACHMENT I
(Page 1 of 1)
NATURAL CIRCULATION INDICATIONS
The following conditions support or indicate natural circulation flow:
D RCS subcooling based on core exit TCs - GREATER THAN 3O"F[21O0F]
SIG pressures - STABLE OR DECREASING
B RCS hot leg temperatures -STABLE OR DECREASING
Core exit TCs -STABLE OR DECREASING
RCS cold leg temperatures WITHIN 35°F OF SATURATION TEMPERATURE FOR SIG PRESSURE
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