ML20205A401
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STATIONPROCEDURECOVERSHEET A.
IDENTIFICATION Numberr E0P 2537 Rev.
4,
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Title:
LOSS OF ALL FEE 0 WATER Prepared By: STEVE BRINKMAN B.
REVIEW I have reviewed the above procedure and have found it to be satisfactory.
TITLE SIGNATURE DATE 2e/gf DEPARTMENT HEAD s
o, m e- -
chran sw u
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C.
SPECIFIC UNREVIEVE0 SAFETY OSdSTION EVALUATION REQUIRED:
Modifies intent of procedure and changes operation of systems as described in design documents.
YES [ ]
NO %
(If yes, perform written USQ determination and Safety
- Evaluation, and contact Manager, Safety Analysis Branch to determine need for Integrated Safety Evaluation.)
t ENVIRONMENTAL REVIEW REQUIRED (Adverse environmental impact)
YES ( )
NO (>d I
0.
SPECIFIC SAFETY EVALUATION REQUIRED Affects response of safety systems, performance of systems which may have been credited in the i
safety analysis or non-credited systems which may indirectly affect safety system response.
YES ( )
NO %)
l (If yes, perform uritten Safety Evaluation an'd contact Manager, Safety Analysis Branch to determine i
need for Integrated Safety Evaluation.)
i j
E.
INTEGRATED SAFETY EVALUATION REQUIRED YES ( )
NO ()c]
j F.
PROCEDURE REQUIRES PORC/50RC REVIEW (In addition to review, items with a YES response must be documented in the PORC/50RC meeting minutes.)
YES @()
NO ( )
i G.
PORC/SORC APPROVAL PORC/50RC Meeting Number W 'l bl
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H.
APPROVAL AND IMPLEMENTATION L
The attached procedure is hereby approved, and effective on the date below:
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k $ /hMw Y7f Shtion/ Service /UnitSuperintendent Effective Date i O SF301/9/5/SES/87-12/lof1 0010250504 881007 1
PDR ADOCK 05000213 P
PDR 4
UNIT 2 LOSS OF ALL FEE 0 WATER Page No.
Ef{. Rev.
1 - 16 4
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G E0P 2537 Page 1 Rev. 4
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PURPOSE 4
To provide the subsequent operator actions which must be accomplished in the event of a loss of maic and auxiliary feedwater.
These actions are taken after completion of the Standard Post Trip Actions and a loss of all feedwater has been diagnosed.
The actions of this procedure are necessary to ensure that the plant results in a stable ssfe condition.
2.
ENTRY CONDITIONS a.
The Standard Post Trip Actions have been accomplighed and b.
Plant conditions indicate that a loss of all f'edwater has occurred by one e
or more of the following i
1.
Decreasing steam generator water level (C05) 11.
Motor driven auxiliary feedwater trip / lockout (C05) j.
iii. Low-low conden' sate storage tank level (C05) j 3.
OPERATOR ACTIONS Instructions Contingency Actions 3.1 Verify Standard Post Trip Actions, 3.1 Perform Standard Post Trip E0P 2525, have been pe,rformed.
Actions, E0P 2525.
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E0P 2537 Page 2 Rev. 4
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Instructions contingency Actions CAUTION SS/SCO must be notified immediately of any safety function criteria not satisfied.
3.2 Perform Safety Function Status
- 3. 2 Checks a.
If safety function status a.
Complete OPS Form 2537-1
, check acceptance c'riteria at approximately 10 minute not satisfied, Then intervals until plant conditions i.
Attempt event stabilize diagnosis and 11.
Go to appropriate
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b.
Direct STA qualified indi-procedure vidual to review data b.
I,f plant not responding and verify acceptance as expected or diagnosis criteria satisfied of one event not appar-ent, Then go to Func-tional Recovery, E0P 2540 3.3 Stop two RCPs 3.3 Continue with this (one in each loop A & C preferred) procedure.
(C03) l 3.4 Close steam generator 3.4 Manually close valves blowdown and sample (local).
valves (C05).
E0P 2537 Page 3 Rev. 4
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Instructions Contingency Actions CAUTION 1.
The loss of all feedwater is a time sensitive event.
The success path of last resort, when steam generator heat removal is not available, is once through RCS cooling via the PORV's (EOP 25400, Section 3.4).
If it becomes apparent that feedwater will not be restored within minutes, then consideration should be given to use the remaining S/G inventory to cooldown.
2.
When restoring steam generator level, add feedwater slowly to avoid a.
excess pressurizer level and pressure transient b.
excessive cooldown rate e
c.
overfilling steam generators d.
Waterhammer in feed sparger Ob NOTES 1.
Auxiliary Feed Auto Start is actuated if either steam generator level falls below 12% for 3 minutes and 25 seconds.
2.
Steam driven auxiliary feed pump speed control can be from C21 or C05.
The selector switches on C21 must be in normal for control to be at C05.
O E0P 2537 Page 4 Rev. 4
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- 3. 5 Take action to restore feedwater 3.5 If unable to restore flow.
Attempt to start one main main feedwater, Then feed pump by the following a.,
Check open main feed pump discharge isolation valve 2-FW-38A (B) (C05) (CR 0486-01) b.
Verify speed controller b.
Dispatch an operaar potentiometer is turned to verify integrity fully counter clockwise (C05) of feedwater system c.
Position motor speed and changer switch to "fast c.
Refer to Main Feed-lower" until low speed water, OP 2321 s+op (green light) is observed (C05) d.
Depress reset pushbutton.(C05)
Pos'ition motor speed changer e.
to the "fast raise" position 0,
until high speed stop (red light) is observed (C05).
O E0P 2537 Page 5 Rev. 4
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}Istructions Contingency Actions f.
Adjust speed controller potentiometer to maintain main feed pump discharge pressure 50-150 psi greater than steam generator pressure (C05) 3.6 ff main feedwater is restored, 3.6 Close feed pump discharge Then go to step 3.12.
isolation valves 2-FW-38A and 2-FW-388 (C05) 3.7 Verify suction flowpath to
- 3. 7 auxiliary feedwater pumps by.
(m,)
a.
CST level greater tts1 16% (C05) a.
If CST level is less than 16%, Then i.
Open 2-FIRE-34, fire main stop valve to auxiliary feed pumps (local) ii.
Stop any auxiliary feed pumps (C05) and iii. Align the desired pump for operation on the fire water tank per OPS Form 2537-3 iv.
Start the desired pump and reestablish feedwater flow to at least one steam generator by operating s_
Feed Regulating Valves 2-FW-43A and 2-FW-43B E0P 2537 Page 6 Rev. 4
l b.
Proper valve lineup.
v.
Replenish CST per Complete OPS Form 2537-2 Condensate Storage and Transfor, OP 2319B t
and b.
When CST level is restored to greater than 16%, Then
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re-establish auxiliary feedwater pump suction r
from CST l
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E0P 2537 Page 7 Rev. 4
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Instructions Contingency Actions n,-
CAUTION If feedwatcr flow has been lost for greater than 5 minutes, limit feedwater flow to 600 gpm until level is greater than 45%.
3.8 Attempt to start "A" or "B" 3.8 Continue with this procedure auxiliary feed pump (s) and control feedwater flow rate by operating auxiliary feed regulating valves, 2-FW-43A and 2-FW-43B (C05) 4.9 M auxiliary feedwater is restored, 3.9 Continue with this procedure then go to step 3.12 3.10 Attempt to start steam d' riven 3.10 M unable to start auxiliary auxiliary feed pump by the feedwater, Then following a.
Opening combined steam a.
Dispatch an operator stop inlet to steam driven to verify integrity auxiliary feed pump (C05) of auxiliary feed-b.
Increase turbine speed water system until feed pump discharge and pressure is 50-150 psi b.
Refer to Auxiliary above steam generator Feedwater System, pressure (C05)
OP 2322 c.
Control Feedwater flow-rate by operating aux-iliary feed regulating valves, 2-FW-43A and 2-FW-438 (C05)
O E0P 2537 Page 8 Rev. 4
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CAUTION The path of last resort when steam generator. heat removal is not available is once through RCS cooling via the PORV's (EOP 25400, Section 3.4).
The use of this success path is time sensitive.
If it beco:aes apparent that feedwater will not be restored within minutes, then consideration should be given to use the remaining S/G inventory to cooldown.
3.11 if feedwater has been restored, 3.11 if unable to restore feedwater Then perform steps in the remainder
' system to operation, Then of this procedure go to Functional Recovery, E0P 2540 (v
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E0P 2537 Page 9 Rev. 4
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Instructions Contingency Actions i
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CAUTIONS i
1.
When restoring steam generator level, add feedwater slowly to avoid j
a.
excessive pressurizer level and pressure transient t
b.
excessive cooldown rate j
c.
overfilling steam generators d.
Waterhammer in feed sparger l
2.
If feedwater flow has been lost for greater than 5 minutes, limit feedwater flow to 600 gpm until level is greater than 45%
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i 3.12 Manually control main feedwater 3.12 Manually control auxiliary
[
flow to return and maintain feedwater flow to return steam generator level 70-80% (C05) and maintain steam generator l
level 70-80% (C05) t 3.13 Verify proper steam generator 3.13 L
heat removal by steam dump and a.
Manually operate valves.
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bypass or atmospheric dump g
l valves functioning to return b.
Verify steam generator f
Tavg to 530-535'F (C04/5)
Safeties are functioning t
to restore and maintain T at 540-550*F (C04) j c
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E0P 2537 Page 10 I
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Instructions Contingency Actions 3.14 Verify RCS Inventory Control by 3.14 a.
Pressurizer level trending a.
Manually control charging to 35-4C% (CO3) and letdown (CO2) and and b.
RCS Th greater than 30'F b.
'E pressurizer level subcooled (ICC display) control is lost, Then refer to Functional Recovery of RCS Inventory and Pressure, j
2540C e
3.15 Verify RCS pressure control by 3.15 Pressurizer pressure trending a.
Manually control heaters to 2225-2300 psia (CO3) and spray (CO3) and b.
H pressurizer pressure control is lost, Then refer to Functional Recovery of RCS Inventory and Pressure, 25400 3.16 Ensure CST level greater than 3.16 Replenish per OP 23198, 70% (C05)
Condensate Storage and Transfer i
3.17 As time permits, refer to 3.17 Not applicable, Reactor Trip Recovery E0P 2526, and perform additional j
steps as required, f
I E0P 2537 Page 11 d
Rev. 4
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FIGURES 4.1 Break Identification Chart j
4.2 RCS Pressure / Temperature Limits
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E0P 2537 Page 12 i
Rev. 4
O FIGURE 4.1 BREAK IDENTIFICATION CHART INITIAL CONDITION:
PRESSURIZER PRESSURE DECREASING EITHER
, YES S/G PRESSURE NO-
<.,800 psi?
CONTAINMENT YES NO PRESSURE INCREASING?
CONTAINMENT NO YES PRESSURE INCREASING 7 O
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SECONDARY SECONDARY SJAE OR BLOWDOWN BREAK BREAK N
YES INSIDE OUTSIDE RAD torilTORS CONTAINMENT CONTAINMENT ALARitlNG?
PRIMARY PRIMRY BREAK BREAK t
INSIDE OUTSIDE CONTAINMINT CONTAINMENT 1
J E0P'2532 E0P 2534 E0P 2536 EXCESS LOSS OF STEAM GENERATOR STIAft PRIMARY TUBE RUPTURE DEMND COOLANT UNIOUESYMPTOM5:
- EITHER 5/G PRESSURE LOW
- HI RAD IN CONTAINMENT eHI RAD IN SECONDARY OR AUX BUILDING PLA!iT
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- NO RAD INCREASE
.tiORML CONTAINMENT CONDITIONS E0P 2537 Page 13 Rev. 4
FIGURE 4.2 RCS PRESSURE / TEMPERATURE LIMITS CN
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2500-V r
hot
_ /CCE PTABLE -
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AccG PTABLI.
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2000 j
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1 %
n h[
J f
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f cd 500-l f
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5h000-c c
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%g
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- a...
yiy
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.. i i :_ L L.,
A ' Noi Ac.c.c.tT A BLE.
500 f
s
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't Tb~_'. ~.2.' _T[l'~2
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,g p
i g-200 300 400 500 600 0
i RCS TEMPERATURE (F)
- This curve supercedes the 100F/HR cooldown curve any time the RCS has experienced l
an uncontrolled cooldown to below 500F.
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" This' curve supercedes the 30F subcooling curve if, at any time, the containment l
t pressure has exceeded Spsig.
E0P 2537 Page 14 Rev. 4
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RCS PRESSURE / TEMPERATURE LIMIT DATA DATA SHEET 1 PTS LIMIT 100'F/HR
.30*F DEGRADED 200*F C00LDOWN
$UBC00 LED CTMT SUSC00 LED CURVE RCS 5ATURATION MINIMUM MINIMUM MAXIMUM MAXIMUM TEMP PRES 5URE PRES 5URE PRESSURE PRES 5URE PRESSURE
('F)
(psia)
(psia)
(psla)
(psia)
(psia) 600 1543 1919 1919 upper Limit of 595 1487 1852 1852 2350 590 1432 1787 1787 565 1378 1723 1723 hs0 1326 1662 1662 595 1276 1602 1602 570 1227 1543 1543 565 1180 1487 1487 560 1133 1432 1432 555 1089 1378 1376 550 1045 1326 1326 545 1003 1276 1276 540 963 1227 1227 O,
535 924 1180 1180 530 885 1133 1133 e.
525 848 1089 1089 i
520 813 1045 1045
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l 515 778 1003 1003 510 744 963 963 505 712 924 924 500 681 885 885 495 650 848 848 490 621 813 813 485 593 773 773 480 566 744 744 475 540 712 7 12 470 515 681 647 0
465 490 650 657 i
460 467 621 633 2350 455 434 593 607 2286 450 423 566 582 2208 445 402 540 561 2133 440 382 515 540 2060 435 362 -
490 522 1989 430 344 467 502 1919 425 326 434 483 1852 4fD 309 423 467 1787 415 292 402 451 1723 y
410 277 392 436 1662 O
405 262 362 408 1602 400 247 344 406 1543 E0P 2537 Page 15 Rev. 4
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Ok RCS PRESSURE / TEMPERATURE LIMIT ONfA DATA SHEET 1 (Continued)
I PTS LIMIT 100*F/HR 30'F DEGRADED 200*F C00LDOWN 5U8C00 LED CTNT SUSC00 LEO CURVE RCS SATURATION MINIMUM MINIMUM MAXIMUM MAXIMUM
=
TEMP PRESSURE PRES 5URE PRES 5URE PRE 55URE PRESSURE
(*F)
'(psia)
(psia)
(psia)
(psia)
(psia) l l
395 233 326
~ 392 1487 Upper Limit 390 220 309 378 1432 of 2350 385 208 292 366 1378 1
380 196 077 353 1326 375 184 P62 340 1276 370 173 2 47 329 1227 1
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365 163 233 319 1180 360 153 220 309 1133 355 144 208 299 1019 350 135 196 249 1045 345 126 184 281 1003 340 118 173 275 963 335 110 163 265 924 330 103 153 256 885 O
325 96 144 251 848 813 370 90 135 242 315 84 126 236 778 4
310 78 118 230 744 305 72 110 224 712 300 67 103 219 681 395 62 96 214 650 C
I 290 58 90 210 621 2230 285 53 84 205 593 2100 l
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280 49 78 _
202 566 1970 i
275 45 72 lit 540 1850 l
270 42 67 196 515 1730 265 39 62 192 490 1620 260 35 58 190 467 1530 255 32 53 188 434 1450 250 30 49 184 423 1370 402 1300 l
245 27 362 1230 240 25 362 1170
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235 23 344 1100 230 21 326 1040 225 19 309 980 i
220 17 292 930
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215 16 277 880 l
l 210 14 262 840 205 13 247 800 200 12 l
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l E0P 2537 Page 16 Rev, 4
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APPROVED F STATION SUPERINTENDENT EFFECTIVE DATE PORC MTG NO.
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LOSS OF ALL FEE 0 WATER SAFETY FUNCTION STATUS CHECK NOTES:
1.
The purpose of this form is to ensure that all necessary information is reviewed when using E0P 2537, Loss of All Feedwater.
The safety function status check verifies that the operator is using the correct procedure, j
It also assures that the procedure is satisfying all relevant safety
{
functions and maintaining adequate core cooling.
2.
Safety function status is considered Jatisfied when all of the parameters of any one condition meet their criteria.
3.
With the integrated computer system functional, the safety function status may be determined from the SPOS displays.
The SS/SCO shall ensure the correct recovery E0P number is selected at the SPOS CRT.
The safety function status should be logged below approximately every 10 minutes until plant conditions stabilize.
Safety Fustion Status (YES/NO)
Reactivity Inventory Pressure Heat Remova)
Containment Integrity Vital Auxiliaries Time 4.
If the integrated computer system is not functional, then completion of the rest of this form is necessary at approximately 10 minute intervals until the plant conditions stabilize.
5.
Parameters marked with an asterisk require meter readings to be logged.
All other parameters are responded to by yes or no.
OPS Form 2537-1 Rev. 3 Page 1 of 6
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LOSS OF ALL FEEDWATER SAFETY FUNCTION STATUS CHECK CAUTION SS/SCO must be' notified immediately of any safety function criteria not satisfied.
TME*/ DATA ACCEPTANCE PARAMETER CRITERIA
/
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1.
REACTIVITY CONTROL CONDITION 1 - CEAs Inserted i
a.
Reactor Power a.
(C04) 1.
< 5%
v and li, decreasing b.
CEA Position b.
No more than one i
CEA not l
inserte.
1 4
i OPS Form 2537-1 Rev. 3 Page 2 of (
?M 14 T37
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ACCEPTANCE PARAMETER CRITERIA DATA 1.
REACTIVITY CONTROL (cont)
_ Condition 2 - Boration a.
Reactor Power a.
(C04) 1.
< 5%
and 11.
decreasing b.
BAST b.
(CO2)
- 1. level A
decreasing
E
- 11. Shutdown margin established per CPS Form 2208' 13 O
OPS Form 2537-1 Rev. 3 Page 3 of 6
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ACCEPT NCE PARAMETER CRITERIA DATA 2.
RCS INVENTORY CONTROL a.
Pressurizer level a.
> 20%*
(CO3) b.
All RCS subcooling b.
> 30*Fa I
(ICC Summary Display or ICC cabinets) 3.
RCS PRESSURE CONTROL a.
Pressurizer Pressure a.
1900-2350 psia" (CO3) and b.
Trending to
/l 2225-2300 psia C/
r OPS Form 2537-1 Rev. 3 Page 4 of 6
"* ?, ; ; 1537
e ACCEPTA'NCE PARAMETER CRITERIA DATA t
k 4.
RCS HEAT REMOVAL i
t I
Condition 1 - Feedwater Restored i
a.
RCS Tavg a.
530-550*F"
[
(C04) b.
level (feed flow) 1.
10-80%* A j
(C05) (One and B
S/G may be out Trending A of spec.)
to 70 B
l to 80%
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- 11. Feed A
t Flow B
c.
CST level c.
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(C05) 1.
> 70%*
l or i
i
- 11. action i
i being l
taken
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I to i
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restore i
level t
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Condition 2 - Feedwater Being Restored i
l a.
RCS Tave (C04)
- a. < 550*F*
b.
Efforts Underway b.
Yes/No j
to Restore Feedwater i
2
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k OPS Form 2537-1 j
Rev. 3
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Page 5 of 6
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ACCEPTANCE PARAMETER CRITERIA DATA 5.
CONTAINMENT INTEGRITY
- a. Containment t
Pressure (C01) 2 psig Sump Level (C06) no abnormal increase Normal Radiation (RC14) alarm setpoint Area Radiation (C101) alarm setpoint b.
Secondary Plant Radiation SJAE (RC14) alarm e
setpoint Blowdown (RC14) alarm setpoint Main Steam Line (RC05E) alarm setpoint c.
Stack Radiation Unit 1 Wide Range alarm setpoint Unit 2 Wide Range (C101) alarm setpoint 6.
VITAL AUXILIARIES a.
Buses, 24C or a.
Energized 240 (C08) b.
125VDC Buses, b.
Energized 201A or 201B (C08) c.- Instrument Air c.
> 90 psig Pressure (C06)
O OPS Form 2537-1 Rev. 3 Page 6 of 6
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f?//f l's9-i bI FORMAPPyVEDBYUNIT2 SUPERINTENDENT EFFECTIVE DATE PORC MTG. NO.
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AUXILIARY FEEDWATER FROM CST VALVE LINEUP Valve Valve Required Name Number Position Check CST Suction 2-CN-25 Open CST Suction 2-CN-26 Open Suct. Hdr. Isol.
2-CN-27A Open Suct. Hdr. Isol.
2-CN-278 Open "A" Pump Suction 2-CN-29A Open "B" Pump Suction 2-CN-298 Open Steam Pump Suction 2-CN-30 Open "A" Pump Discharge 2-FW-9A Open "B" Pump Discharge 2-FW-98*
Cpen Steam Pump Discharge 2-FW-9C Open Pump Disch X-Comm 2-FW-44 Open Feed Reg. Valve 2-FW-43A Open Feed Reg. Valve 2-FW-438 Open Feed Reg. Isol.
2-FW-10A Open Feed Reg. Isol.
2-FW-11A Open Feed Reg. Isol.
2-FW-108 Open Feed Reg. Isol.
2-FW-118 Open O
OP5 Form 2537-2 Rev. 1 Page 1 of 1