ML20236N466
| ML20236N466 | |
| Person / Time | |
|---|---|
| Site: | Point Beach  |
| Issue date: | 03/19/1987 |
| From: | WISCONSIN ELECTRIC POWER CO. |
| To: | |
| Shared Package | |
| ML20236N340 | List: |
| References | |
| EOP, EOP-0, NUDOCS 8711160176 | |
| Download: ML20236N466 (22) | |
Text
_ _ _ _ _ _ _ _ _ - _ _ _.
p ATTACHMENT 5-V-
E0P-0 MAJOR Revision 1 03-19-87 REACTOR TRIP OR SAFETY INJECTION A.
PURPOSE This procedure'provides directions to verify proper response of the automatic protection systems following manual or automatic actuation of a reactor trip or safety injection, assess plant conditions, and direct the operator to the appropriate recovery procedure.
B.
SYMPTOMS OR ENTRY CONDITIONS 1.
a) Any reactor trip or condition requiring a reactor trip l
b) Rapid decrease in neutron level indicated by nuclear i
instrumentation.
l I
c) All shutdown and control rods are fully inserted. Rod bottom lights are lit.
1 2.
Safety Injection 1
a) Any safety injection or condition requiring a safety injection l
b) SI safeguards equipment sequencing initiated l
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D F
Continued I
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- REACTOR TRIP OR. SAFETY INJECTION Page~2 1
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' STEP ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED
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. NOTE:- E ADVERSE CONTAINMENT: CONDITIONS-EXIST, THEN USE NUMBERS IN BRACKETS ~
-TO SATISFY THE PROCEDURE STEP. ADVERSE' CONTAINMENT' CONDITIONS ARE
I
- NOTE: THE STEPS OUTLINED WITH BOXES ARE ONLY TO BE DONE IF.A LOSS OF'0FFSITE AC HAS OCCURRED.
,. NOTE: FOLDOUT PAGE SHOULD BE OPEN.
1 NOTE: ' STEPS 1 THROUGH'22 ARE IMMEDIATE ACTION STEPS.
1
. NOTE ' NOTIFICATION OF.DCS,oDTA, AND IMPLEMENTATION OF EMERGENCY PLAN,
'(EPIP 1.1) SHOULD BE PERFORMED AS.SOON AS POSSIBLE.
1:
Verify Reactor Trip Manually. trip' reactor.
E reactor will not trip,
, Rod bottom lights. lit THEN go to CSP-S.1,:" Response to Nuclear Power Generation /ATWS."
Reactor' trip breakers open Rod position indicators zero Neutron' flux' decreasing
.2 Verify Turbine Trip a.
Turbine stop valves shut a.
Manually trip turbine.
i 3
Verify Safeguards Buses Energized.
a.
Safeguards buses a.
Try to; restore power to energized safeguards buses.
(A05,'A06, B03, B04)
E no 480 V AC bus can be energized, THEN go to ECA-0.0,
" Loss of All AC Power,"
i Step 3 (inventory).
1 Continued 1
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E0P : REACTOR ' TRIP - OR - SAFETY. INJECTION:
- Page 3 1 STEP ACTION / EXPECTED RESPONSE =
RESPONSE NOT OBTAINED, i
i
- 4 Check'if SI is Actuated
' Check if SI is_ required.
IF SI is required,LTHEN manually-
.a.
'Checkfif any of the
-actuate.
following annunciators are lit: '
IF SI'is not required, THEN go to; u
E0P-0.1, " Reactor Trip Response.":
Steam line 1;.o
-pressure i
a-
- )
-- - Pressurizer low pressure SI Containment pressure high
_ Manual ~SI 5
. Verify'SI> Pumps Running-
. Manually start pumps.
6 Verify RHR Pumps Running-Manually start pumps.
1
?7' LVerify Proper SI Valve Alignment-
>i a.
BAST to SI-pump suction a.
Mar.ually open valves, valves open (MOV-826A,'L, C)
IF suction from BAST not
.i established, THEN verify RWST suction valves open
]
(MOV-825A,B).
]
b.
Core deluge valves open b.
Manually open valves.
(MOV-852A, B) 1 1
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Continued i
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. REACTOR TRIP OR. SAFETY INJECTION ~
.Page 4:
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STEP ACTION / EXPECTED RESPONSE-
~ RESPONSE'NOT OBTAINED a
NOTEi H: INDICATED SI FLOWS ARE NOT APPROXIMATELY EQdAL,'THEN NOTIFY DSS / DOS'
~
AND USE. VISUAL' VERIFICATION RATHER THAN INSTRUMENTATION PRIOR TO l
ISOLATING A FAULTED SI, PATH.
8
' Verify SI Flow a.
RCS pressure <l400 psig a.
Go to Step 9 (AFW).
b.
Verify high head'SI flow.
- b.. Manually start pumps and align valves as.necessary.
c.
RCS pressure <l25 psig
.c.
Go to Step'9 (AFW).
d.
. Verify low head SI flow' d.
Manually start pumps and align valves as necessary.
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- 9 Verify AFW Pumps Running a'.
Motor-driven AFW pumps-a.
Manually start pumps.
running j
b.
Steam-driven AFW pump-b.
Manually open steam supply running if necessary
' valves.
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10 Verify AFW Flow Isolated Go to pullout and shut on both AFW l
to Unaffected Unit pump discharge valves for the unaffected unit.
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11 Verify Total AFW Flow at
~ Manually start pumps and align l
Least 200 apm valves as appropriate.
I E total AFW flow remains <200 gpm, THEN go to CSP-H.1, " Response to Loss of Secondary Heat Sink."
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Continued
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n' E0P-0 REACTOR: TRIP OR SAFETY INJECTION
.Page 5 l
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. STEP >: ACTION / EXPECTED RESPONSE RESPONSE NOT-0BTAINED i
6'
)
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'12-Verify at'Least Four' Manually start pumps, l
!SW Pumps Running; IF four pumps can not be started, l
THEN verify service water isolation.
13.
. Verify containment: Accident 1
N Cooling Units Running-1 a.
.All_ accident fans running
'a.
Manually start fans.
(W1A1,-W181, W1C1, W1D1)
'b.
Containment vent cooler.
. b.' Manually open vent cooler
- valves.open.
valves.
(MOV-2907, 2908) 14'
-Verify containment Isolation Press containment isolation Actuated manual pushbutton.
15'
-Verify Containment Spray Not Required a.
.. Verify containment a.
Verify containment spray'has
- pressure has remained actuated.
<25 psig.
Containment spray pumps start 1
Spray pump discharge valves open (MOV-860A,.B, C, D)
NaOH addition after two minutes IF, containment spray has not i
actuated, THEN start pumps and align valves as required.
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Continued
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E0P-0 REACTOR TRIP OR SAFETY INJECTION Page 6 f
STEP ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED 16 Verify Safeguards 480 V Bus Lockout Relays Tripped a.
Lockout in tripped a.
Trip non-essential loads to position maintain diesel generator within rated capacity.
17 Verify Diesels Start IF emergency power is required, THEN star t diesels.
18 Verify CCW Pumps Running Turn switch to off and then on l
to manually start pumps.
j 1
1 19 Verify Feedwater Isolation I
a.
Feed reg valves shut a.
Shift to manual and shut valves.
b.
Feed reg bypass valves b.
Shift to manual and shut valves.
l shut I
c.
Main feed pumps tripped c.
Manually trip pumps.
20 Check if Main Steam Lines Should be Isolated a.
IF high steam flow, and a.
Manually shut main steam RCS temperature <543 F isolation valve.
THEN verify affected main steam isolation valve has shut, b.
IF high-high steam flow, b.
Manually shut main steam THEN verify affected main isolation valve.
steam isolation valve has shut.
c.
IF containment pressure c.
Manually shut both main steam
>15 psig, THEN verify both isolation valves.
main steam isolation valves shut.
Continued
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m-u E0P-0 I
h REACTOR TRIP OR SAFETY INJECTION.
Page:7 i-l
^ ' "
STEP ACTION / EXPECTED RESPONSE RESPONSE !!OT OBTAINED ~
q L--
'21 Verify Generator Output and IF one minute has, elapsed, THEN Field Breakers Open manually trip generator output
]
w and field breakers.
- 22 Verify Auto Bus Transfer-
. Manually reenergize buses.
9 23 Verify Radwaste Steam' I_F Unit 1 affected, THEN shut SA-9.
F Isolated.from Affected Unit
'IF Unit 2 affected,. THEN shut SA-10, i
24 Check RCP Cooling i
i a.
THEN trip the RCP.
b.
Seal injection normal
- b. Verify adequate power available to run one charging pump.
and Start one charging pump at.
l minimum speed for seal i
inj:ction.
i 25 Check if RCPs Should be' t
Stopped a.
Check at least one SI a.
Go to Step 26 (containment)~.
Pump runr.ing.
b.
ECS subcooling <30'F [60*F) b.
Go to Step 26 (containment).
based on core exit thermocouple c.
Stop both RCPs.
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l Continued i
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REACTOR TRIP'OR SAFETY INJECTION Page 8 STEP ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED
'26 Verify containment Isolation a.
Verify valves in-a.
Shut valve (s).
]
Appendix A shut.
b.
Control = room. ventilation
- b. -Initiate control room in recirculation recirculation (Mode 2).
c.
Verify manual valves shut:
c.
Shut valve (s).
i Any valve which may be open under administrative control with a designated operator 27 Check Pressurizer PORVs and Spray Valves a.
PORVs shut a.
IF pressurizer pressure
<2335 psig, THEN manually shut PORVs.
IF any valve can~not be shut, THEN manually shut.its block ~
valve.
IF block valve can not be shut, THEN go to E0P-1, " Loss of-Reactor or Secondary Coolant."
b.
Pressurizer spray valves b.
IF pressurizer pressure shut
<2010 psig, THEN manually shut valves.
IF valves can not be shut, THEN stop RCP(s) supplying failed spray valve (s).
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Continued
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l E0P-0 REACTOR TRIP OR SAFETY INJECTION Page 9 l
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STEP ACTION / EXPECTED RESPONSE RESPONSE NOT-OBTAINED l
NOTE: Tavg IS NOT A QUALIFIED INSTRUMENT.
28 Check RCS Temperature Stable E RCS temperature <S47 F and at or Trending to 547 F decreasing, THEN:
a.
Stop dumping steam l
b.
IF cooldown continues, THEN l
Entrol total feed flow.
Maintain total feed flow
>200 gpm until level >8% (28%]
j in at least one steam generator.
1 c.
IF cooldown continues, THEN shut main steam isolation valves.
E RCS temperature >547'F and increasing, THEN:
Dump steam to condenser SE Use atmospheric steam dumps 29 Check Secondary System Intact a.
Check steam generator a.
Go to E0P-2, " Faulted Steam pressures:
Generator Isolation."
No steam generator pressure decreasing in an uncontrolled manner No steam generator completely depressurized Continued
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' REACTOR TRIP OR SAFETY INJECTION Page 10-1 4
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' STEP ACTION / EXPECTED RESPONSE. >
RESPONSE NOT OBTAINEDL s
3.
e i
'301 Check-if Steam Generator Tubes are Intact
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.a.
Use'all'of the-following:
a.
Go to EOP-3, " Steam Generator i
'f Tube Rupture."
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- No' condenser air ejector-RMS high alarms (RE-215, RE-225)
-l q'.
blowdown RMS high.
.l alarms'(RE-219, RE-222)
- 1 No main steam line RMS high alarms (RE-231,.RE-232)~
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.31 Check if RCS is Intact
- a..Use all'of the followings.
a.
Go to E0P-1, " Loss of Reactor or Secondary Coolant."
j No. containment high' range radiation alarms-
-)
(RE-126,RE-127,~RE-128)
'1
).:
No' containment RMS
- l
'high' alarms
_(RE-102, RE-107) 1 1
-. Containment pressure
.:<3 psig No containment recircu-lation Sump "B" or Sump "A" level l
Continued
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E0P-0 REACTOR TRIP OR SAFETY INJECTION Page 11-
.)
1 s
.l STEP ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED d
n
~
32
. Check if SI Should be' Terminated j
4 a..
RCS'subcooling >35 F based
- a. ~Do not stop SI pumps. Go to on core exit thermocouple Step 34 (status trees).
j b.
. Secondary heat sink b.
IF neither-condition satisfied, THEN do not stop SI pumps.
Total feed flou to
.Go to Step 34 (status trees).
i steam generators >200 gpm or Level in at least one steam generator >8%
c.
RCS pressure >1600 psig c.
Do not stop SI pumps. Go to a_nd stable or increasing Step 34 (status trees).
n d.
Pressurizer level >14%
d.
Do not stop SI pumps.
Increase charging flow.
Go to Step 34 (status trees) 33 Go to E0P-1.1, "SI Termination" 34 Initiate Monitoring of Critical Safety Function Status Trees I
I Continued
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EOP-0 REACTOR TRIP OR; SAFETY INJECTION Page 12 STEP ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED CAUTION:
I_F OFFSITE POWER IS LOST AFTER SI RESET, THEN MANUAL ACTION MAY BE i
F REQUIRED TO RESTART SAFEGUARDS EQUIPMENT.
-l 1
35 Reset SI-I 36 Reset Containment' Isolation 37 Reset Safeguards 480 V Bus Lockout Relays NOTE: DO NOT OPEN ANY CONTAINMENT ISOLATION VALVE WITHOUT DUTY SHIFT SUPERINTENDENT AUTHORIZATION.
.{
CAUTION: REESTABLISHING INSTRUMENT AIR TO CONTAINMENT COULD CAUSE REDUCED l
INSTRUMENT AIR HEADER PRESSURE TO THE UNAFFECTED UNIT.
38 Reestablish Instrument Air to Containment f
a.
Verify compressor running.
a.
Start compressor (s) b.
Cycle then open instrument b.
Manually hold open valve (s) air isolation valves, if required.
(CV-3047, CV-3048).
Continued
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E0P-0 REACTOR TRIP OR SAFETY INJECTION Page 13 i
STEP ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED CAUTICN: E CST LEVEL DECREASES TO <4.5 FEET, THEN ALTERNATE WATER'SdURCES FOR AFW PUMPS WILL BE NECESSARY.
39 Check Steam Generator Levels a.
Narrow range level >8%
a.
Maintain total feed flow
>200 gpm until level >8% in
]
at least one steam generator.
1 b.
Control feed flow to b.
E narrow range level in any maintain level between steam generator continues to 8% and 50%
increase in an uncontrolled manner, THEN go to E0P-3,
" Steam Generator Tube Rupture."
40 Check Secondary System H, conditions appear to indicate Radiation Normal a steam generator tube rupture, THEN go to E0P-3, " Steam Generator No condenser air ejector Tube Rupture."
RMS high alarms (RE-215, RE-225)
No steam generator blow-down RMS high alarms (RE-219, RE-222)
No main steam line RMS high alarms (RE-231, RE-232) l 1
Sample steam generators Portable survey instruments I
1 Continued
'*i E0P-0 REACTOR TRIP OR SAFETY INJECTION Page 14-1 STEP ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED 41 Check Auxiliary Building Evaluate cause of abnormal conditions.
Radiation Normal IF the cause is a loss of RCS j
inventory outside containment, THEN go to ECA-1.2, "LOCA Outside f
Containment."
j j
42 Verify Pressurizer Relief Evaluate cause of abnormal conditions.
Tank Conditions Normal f
CAUTION:
E RCS PRESSURE DECREASES TO <200 PSIG AT ANY TIME, THEN THE RHR l
PUMPS MUST BE MANUALLY RESTARTED TO SUPPLY WATER TO THE RCS.
1 43 Check if RHR Pumps Should be Stopped a.
RCS pressure >200 psig a.
Go to E0P-1, " Loss of Reactor or Secondary Coolant."
b.
RCS pressure stable or b.
Go to Step 44 (diesels).
increasing i
k c.
Stop RHR purps NOTE: DIESEL GENERATOR CAPABILITY IS 2850 KW CONTINUOUS, 3050 KW FOR 30 MINUTES.
NOTE: WHEN SHEDDING NON-ESSENTIAL LOADS, AVOID SERVICE WATER ISOLATION BY q
MAINTAINING FOUR SERVICE WATER PUMPS RUNNING IF POSSIBLE.
1 l
44 Check Diesels Status a.
Verify diesel voltage and a.
E necessary, THEN take manual frequency normal.
control per OP-11A, " Emergency Diesel Generator," and control the output to 4160 V and 60 Hz.
b.
Secure unnecessary plant f
equipment.
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Continued I
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N E0P-0 I
REACTOR TRIP OR SAFETY. INJECTION Page 15
.3
.a
- STEP. ACTION / EXPECTED RESPONSE,',
RESPONSE NOT OBTAINED-45 Verify Charging Flow l
a.
At least one charging a.
Perform the-following:
(
pump running l
barrier.is lost,.THEN isolate'-
seal injection to affected j
RCP(s) before starting l
charging pumps.
j
'l
- 2) Start charging' pumps as j
necessary.
- )
b.
Establish charging i
flow.
46 Check if Diesels Should be 1
Stopped-
.{
a.
Verify 480 V AC safeguards a.
Try to restore offsite power to
.j buses energized by offsite 480 V AC safcquards buses, power.
j b.
Stop any unloaded diesel
-per OP-11A., " Emergency Diesel Generator."
)
47 Return ~to Step 27 (PORVs)
)
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- END -
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.j u ECP-0~
Page l' APPENDIX "A" 1.'O CONTAINMENT ISOLATION VALVES l
't a,
.The following valves have position indication on the isolation panels.
A.
CV-371 Letdown line isolation d
CV-371A Letdown line isolation t
,SC-966A-Sample line isolation (pressurize.r steam)
SC-966B' Sample line isolation (pressurizer liquid) l SC-966C
' Sample line isolation (hot leg)
)
RC-538 Gas analyzer isolation from pressurizer j
relief tank f
RC-539 Gas analyzer isolation from pressurizer relief-tank
(
WL-1003A RCDT pump suction isolation i
WL-1003B RCDT pump suction isolation I
WL-1721.
RCDT pump common suction isolation l
{
WL-1698 RCDT pump suction line.to -19 ft sump-j CV-1296 Auxiliary charging line isolation WL-1728 Sump "A" to -19 ft sump isolation i
1 WL-1723 Sump "A" to -19 ft sump isolation WL-1786 Vent header isolation from RCDT l
WL-1787 Vent header isolation from RCDT WL-1788 Gas analyzer isolation from RCDT t.
... Continued on next page...
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-h E0P-0 i
Appendix '.'A" 4
Page 2 i
l A.
... Continued'from Previous Page...
E
. WL-1789 Gas: analyzer isolation'from RCDT
.CV-313 Reactor coolant pump seal return line t
isolation I
CV-313A Reactor coolant pump seal return line' isolation lt RC-508
-Reactor makup water to PRT SI-846 Accumulator nitrogen fill isolation t
CC-769 Component cooling water return from-excess letdown heat exchanger i
CV-3200A
.RE-211/RE-212 radiation monitor supply
'f CV-3200B PE-211/RE-212 radiation monitor supply
~CV-3200C RE-211/RE-212 radiation monitor supply CV-3047 Instrument air isolation l
CV-3048 Instrument air isolation
.CV-2083 Blowdown sample isolation CV-2084-Blowdown sample isolation' CV-5958 Blowdown isolation
{
CV-5959 Blowdown isolation
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.g hh' E0P-0 Appendix "A" Page 3
.B.
The' followings valves'do not have position indication on'the isolation par.els Position Indication SC-951 Sample line isolation (pressurizer steam)
Outside Unit 1 and SC-953 Sample line isolation Unit. 2 Sample Rooms, (pressurizer liquid)
El. 26 ft Y
SC-955
. Sample line isolation.(hot' leg)
SV-4852 Shifts control room ventilation' C67 Control Room
~!
to 100% recirculation (Mode 2)
Ventilation Panel I
2.0 CONTAINMENT' VENTILATION ISOLATION VALVES A.
The following valves have position indication on the isolation panels.
HV-3244 containment purge' supply isolation HV-3245 Containment purge supply isolation s
HV-3212 Containment purge exhaust isolation k
HV-3213-Containment purge exhaust isolation i
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E0P-0 Page 1 i
APPENDIX "B" j
)
COOLING LOADS ISOLATED IF LESS THAN FOUR OF SIX SERVICE WATER PUMPS START 3.0 O
3.1 Train "A" 3 1.1 SW-2816, service building air conditioning
]
3.1.2 SW-2930A, spent fuel pit heat exchanger 3.1.3 A0V-LW-61, service water to overhead condensers of blowdown j
evaporators and steam generator blowdown tank vent condensers.
3.2 Train "B" 3.2.1 ISW-2880, Unit 1 turbine building feeder (Unit 1 SI only) i f
3. 2-. 2 2SW-2880, Unit 2 turbine building feeder (Unit 2 SI only) 3.2.3 EW-2817, water treatment area 3.2.4 A0V-LW-62, service water from overhead condensers of blowdown evaporator and steam generator blowdown tank vent condenser.
(
3.2.5 SW-2930B, spent fuel pit heat eFchanger
)
)
4.0 NON-ESSENTIAL EQUIPMENT STRIPPED FROM SAFEGUARDS BUSE,S-B03/B04 LOCKOUTS
]
4.1 Component cooling water pumps are tripped if safety injection is j
coincident with an undervoltage on the cafeguards buses, j
i 4.2 Pressurizer heater backup groups "C" and "D" and the control group "E".
i 4.3 Electric fire pump (Unit 1 SI only) (1903).
3 i
4.4 480 volt bus tie breakers B52-15C, 852-16C, B52-18C (B52-26C, BS2-39C, B52-40C).
4.5 Auxiliary and service building motor control centers (Unit 1 - IB31, B43; Unit 2 - 2B31, 821, B33) 4.6 Service air compressor K3A (Unit 1 SI only) (1B04)
Service air compressor K3B (Unit 2 SI only) (2B04) 4.7 Turbine building crane (Unit 2 SI only).
w s.r u.
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'W EOP-0 Page 1 1,
f APPENDIX "C"
- 1. 0.
REACTOR-TRIPS 1.1 ' ' NIS power range e
1.2 Turbine trip 1.3-AT overtemperature-1.4 AT overpower'
-1.5 Reactor-Coolant Flow
- a.. Pump Breaker Trip
- 1) Low voltage
- 2) Low' frequency
- b. -Low flow-1.6 LSteam generator' low-low. level 1.7 Steam flow / feed flow mismatch plus low steam generator level
'1.8 Safety injection-1.9 Pressurizer pressure low
-1.10'~ Pressurizer pressure high 1.11' NIS Startup Trips a.
NIS source range b.
NIS intermediate range
- c..NIS power range low setpoint 1.12 Pressurizer level high 1.13 Manual 2.0 SAFETY INJECTION
.s.1 -
Pressurizer pressure low-2.2 ' Steam line pressure low 2.3 containment pressure high 2.4 Manual safety injection
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.I FOLDOUT FOR E0P-0 SERIES l
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'1.
R_CP Yrip~ Criteria Trip both RCPs if both conditions listed below occur:
At least one-SI pump running.
RCS subcooling <30*F [60*F] based on core exit thermocouple.
2.
SI Actuation Criteria i
E either condition listed below occurs, THEN actudte SI and go to E0P-0, " Reactor Trip or Safety Injection."
^RCS subcooling <35*F [80*F] based on core exit'thermcouples
.l or i
q Pressurizer level cannot be maintained >14% [34%)
3.
Red Path Summary t.
Suberiticality nuclear power >5%
b.
Core cooling
- core exit thermocouple >1200*F
- o. r,
- core exit thermocouple >700*F and reactor vessel level narrow range <29 ft with j
no RCPs running i
c.
Heat sink
- wide range level in both steam generators <200 in, and total feedwater flow <200 gpm.
d.
Integrity
- cold leg temperature decrease >100*F in last 60 minutes and RCS cold leg temperature <283*F.
j e.
Containment
- containment pressure >60 psig.
)
- 4.
AFW Supply Switchover Criterion I
E CST level decreases to <4.5 feet, THEN switch to alternate AFW supply.
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- l ATTACHMENT 6
~ ST-1 '
Major _
' l SUBCRITICALITY.
Revision 0,
'07-01-85
..0:
'GO TO -
CSP S.1 1
GOTO.
ME E
CSP S.1 NO l
POWER RANGE 1.ESS THAN 5%
a
.GOTO~
09 YES CSP S.2 1
g O
E
)
l INTERMEDIATE NO
/
NO RANGE SUR i
MORE:.
SOURCE NEGATIVE 1
- O..
RANGE SUR THAN -0.2 DPM YES l
ZER0 0R NEGATIVE YES CSF i
SAT NO SOURCE RANGE ENERGlZED YES j
Yh GO TO -
f CSP S.2-O NO SOURCE RANGE SUR ZERO OR NEGATIVE YES CSF SAT
- - - -.