ML20080B370
| ML20080B370 | |
| Person / Time | |
|---|---|
| Site: | LaSalle  |
| Issue date: | 08/02/1983 |
| From: | COMMONWEALTH EDISON CO. |
| To: | |
| Shared Package | |
| ML20080B363 | List: |
| References | |
| 3212L-RR, PROC-830802-01, NUDOCS 8308050447 | |
| Download: ML20080B370 (25) | |
Text
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SUMMARY
OF CORRECTIONS TO IST EDITION LaSalle Unit 1
" Inservice Inspection Program" Vol. 2 Part B.
Tab 3:
Pg. 6 Notes 9 and 10 Pg. 7 Note 13 Tab 4:
HP Pg. 1 Tab 5:
RP-07 Tab 6:
DO Pg. 1 HP Pg. 1 IN Pg. 2 LP Pg. 1 MS Pg. 7 NB Pgs. 1 and 2 RE/RF Pg. 1 RH Pgs. 4, 5, 6, and 11 Tab 7:
RV-01 RV-02 Pgs. 1 and 2 RV-10 RV-16 RV-21 Pgs. 1 and 2 RV-33 RV-35 Corrected pages are attached.
3212L/rr 9308050447 830002 PDR ADOCK 05000373 p
REVISION 1 JULY 1983 III NOTES - CON'T
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(9) To satisfy the requirements of General Design Criterion 56 and to perform their function, these instrument lines have been designed to meet the requirements of Regulatory Guide 1.11 (Safety Guide 11).
These lines are Seismic Category I and terminate in instruments that are Seismic Category I.
They are provided with manual isolation valves and excess flow check valves.
The integrity of these lines is to be tested during the Type "A" Test.
These lines and their associated instruments will be pressurized to P -
a Surveillance inspections will be performed to ensure the leaktight integrity of these lines and their associated instruments.
Additional inservice inspection is included in the Technical Specifications.
This inservice inspection verifies the function of the excess flow check valves.
Isolation is provided by the excess flow check valve.
In the event of a line rupture downstream of the check valve and a containment pressure above 2 psig, this valve would close to limit the amount of leakage.
(From FSAR Table 6.2-21, Note 32).
The exercise and leak test procedure confirms valve operability through a visual observation of a marked decrease in the instrument line's flow rate.
f)
(10) To perform their function and to satisfy the requirements of General V
Design Criterion 55, these instrument lines have been designed to meet the requirements of Regulatory Guide 1.11 (Safety Guide 11).
These lines are Seismic Category I and terminate in instruments that are seismic Category I.
They are provided with flow-restricting orifices, manual isolation valves, and excess flow check valves.
The flow-restricting orifice is sized to assure that in the event of a postulated failure of the piping or component, the potential offsite exposure will be substantially belcw the guidelines of 10 CFR 100.
Isolation is provided by the excess flow check valve.
In the event of a line rupture downstream of the check valves, this valve would close to limit the amount of leakage.
The integrity of these lines will be tested during the Type "A" Test.
Surveillance inspections will be performed to ensure the leak-tight integrity of these lines and their associated instruments. Addi-tional inservice inspection is included in the Technical Specifications.
This inservice inspection verifies the function of the excess flow check valves (From FSAR Table 6.2-21, Note 33).
The exercise and leak test procedure confirms valve operability through a visual observation of a marked decrease in the instrument line's flow ra rate.
Lj Page 6 1
i REVISION 1 JULY 1983 III NOTES - CON'T (11) The ECCS and RCIC suction lines are normally filled with water on both the inboard and outboard side of containment, thereby forming a water seal to the containment environment.
The valves are open during post-1.0CA conditions to supply a water source for the ECCS pumps. Since a break in an ECCS line need not be considered in conjunction with a DBA, the only possible situation requiring one of these valves to be closed during a DBA is an unacceptable leakage in an ECCS.
- However, because these ECCS systems are constantly monitored for excessive leakage, this is not a credible event for design.
However, at the insistence of the NRC, these valves will receive a leakage test as part of the low pressure system leakage test described in Note 29.
(From FSAR Table 6.2-21, Note 39).
(12) The leakages through the Main Steamline valves will not be included in establishing the acceptance limits for the combined leakage in accordance with the 10 CFR 50, Appendix J, Type B and C tests.
Because the Main Steamlines are provided with a leakage control system, the leakage through these valves will not be added into the combined leakage rate. This exclusion is in accordance with Article III.C.3 of 10 CFR 50, Appendix J.
(From FSAR Table 6.2-21, Note 30).
(13) These penetrations are provided with removable spools outboard of the outboard isolation valve.
During operation, these lines will be blind flanged using a double 0-ring and type-B leak tested.
In addition, 3
the packing of these isolation valves will be soap bubble tested to ensure insignificant or no leakage at containment test pressure each refueling outage.
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@ Commonwealth Edison LaSalle County Nuclew Station Unit i PUMP & VALVE TESTING Page 1 of 1 RELIEF REQUESTS REVISION 1/ JULY 1983 g
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So ASME 33 PUMP OH
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FUNCTION TEST HEOUlHEMENT D ASIS FOR HELIEF ALTERNAllVE TEST o
00 01 02 03 04 0$
06 RP-07 All pumps in NA NA The requirements When a pump parameter The acceptance of IST plan.
of IWP-3230(c),
falls in the Required pump operability will Corrective Action.
Action Range, as an be based on the alternative to pump limits specified in repair,IWP-3230(c) the Limiting Condi-allows an analysis using tions for Operation the test data to prove found in the Plant that the pump will still Technical Specifi-s cations. The pump fulfill its function.
will remain operable if it meets all Tech.
Spec. requirements.
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OLa lesel Oil INSERVICE TESTING PLAN sysi m e
nty N I a Sta io Unit 1
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00 01 02 03 04 05 06 07 08 09 10 11 12 13 000002 1.5 85-1 D4 3/C NT C
E Q
A thit 0 OG Fuel 011 Transfer Pump Discharge Check 000004 1.5 85-1 D4 3/B GT m
C FS Q
RV-02 A
thit 0 DG Day Tank Inlet Stop Valve 100002 1.5 85-l D6 3/C NT C
E Q
A thit lA DG Fuel 011 Transfer Pung discharge check 100004 1.5 85-1 E6 3/B GB S0 C
FS Q
RV-02 A
thit 1 Day Tank Inlet Stop Valve 100012 1.5 85-1 D1 3/C NT C
E Q
A thit 10 OG Fuel Ull Transfer Pung Discharge Check 100014 1.5 85-1 El 3/8 GB S0 C
FS Q
RV-02 A
thit IB Day Tank Inlet St(p Valve 100024 2
85-1 02 3/8 GB SO C
FS Q
HV-02 A
Diesel Fire Fuel Transfer Pump Inlet Stop l
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REVISION 1/ JULY 1983 e, '
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00 01 02 03 04 05 06 07 08 09 10 11 12 13 lE22-F001 14 95 A4 2/B GT P10 0
FS.ST Q
140 A
HPCS Pump Suction Stop From CST lE22-F002 24 95 84 2/C CV C
E Q
A HPCS Pump Suction Stop from CST 1E22-F004 12 95 D6 1/A GT M0 C
FS,ST Q
14 RV-19 A
HPCS Injection Line Stop LT RR (M11)(See Note 5,4) lE22-F005 12 95 D7 1/AC NSC A0 C
E CS RV-19 A
HPCS Injection Line Test-PIT RR RV-35 able (M-ll) (See Note LT RR 5,7 )
lE22-F012 4
95 C3 2/A GT M0 C
FS,ST Q
22 RV-19 A
HPCS Pump Minimum flow LT RR bypass line stop (See Note 4,6,8)
IE22-F014 lx2 95 B5 2/C RV C
RV RR A
HPCS Water leg Discharge relief (See Note 2,4,8, 6) lE22-F015 18 95 86 2/A GT M0 C
FS,ST Q
99 RV-19 A
HPCS Stop Pump Suction LT RR from Suppression Chamber (See Note 4,6, 11)
GE-T2 1180
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' HR RV-02 A
lip Indexer Purge-Fall FST RR RV-12 Close (See Note 1,4 LT nn n'!-19 61 IB21-F024A
.75 66-2 F6 3/C NT 0
E RR RV-16 A
MSIV IN CllECK (See Note 1) 1021-F0248
.75 66-2 F7 3/C NT 0
E RR RV-16 A
MSIV IN CitECK (See Note 1) 1021-F024C
.75 66-2 F4 3/C NT 0
E RR RV-16 A
MSIV IN CilECK (See Note 1)
IB21-F0240
.75 66-2 F5 3/C HT 0
E RR RV-16 A
MSIV IN CllECK (See Note 1)
IB21-F040C
.50 66-2 82 3/C HT 0
E RR RV-16 A
AOS IN CllECK (See Note 1)
IB21-F040D
.50 66-2 B4 3/C HT 0
E RR RV-16 A
ADS IN CllECK (See Note 1)
IU21-F040E
.50 66-2 07 3/C H5C 0
E RR RV-16 A
ADS IN CllECK (See Note 1) 8f I2 $ INIS
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@ LaSalle County Nuclear Station Unit 1 Commonwealth Edison INSERVICE TESTING PLAN system LP-Low Pres. Core Spray page ]
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REVISION 1/ JULY 1983 4
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00 01 02 03 04 05 06 07 08 09 10 11 12 13 1E21-F001 24 94 B6 2/A GT M0 0
FS,ST Q
132 RV-19 A
LPCS Suction From LT RR Suppression Pool Stop (M-68)(See Note 4,6,11) lE21-F003 16 94 C2 2/C NSC C
E Q
A LPCS Pump Discharge Check lE21-F005 12 94 D6 1/A GT M0 C
LPCS Injection Line Out-LT RR RV-19 board Stop (M-10) (See Note 1,5,4) g IE21-F006 12 94 C6 1/AC NSC A0 C
E CS RV-21 A
LPCS Injection Line PIT RR RV-19 Testable Check Valve LT RR (it-10)(See Note 1,5,7) lE21-F0ll 4
94 C3 2/A GT M0 O
FS,ST Q
4 RV-19 A
LPCS Min Flow Bypass Stp LT RR (See Note 4,6,8) l E21-F018 3x4 94 DS 2/C RV C
RV RR A
LPCS Pump Discharge Relief (See Note 2,4,6,8) lE21-F031 1x2 94 B4 2/C RV C
RV RR A
LPCS Pump Suction Relief (See Note 2,4,6,8) lE21-F033
.75 94 C3 2/C NSC 0
E Q
A LPCS Water Leg Pump Discharge Check Valve I
GE 12 1180
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O Commonwealth Edison INSERVICE TESTING PLAN system MS-MIN STEAM tasalle County Nuclear Station Unit 1
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'II VALVES REVISION 1/ JULY 1983 8
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00 01 02 03 04 05 06 07 08 09 10 11 12 13 lE32-F001A 2.5 55-8 F3 1/A GT M0 C
MS Loop A Bleed Vr.lve LT RR RV-19 Outboard (See Note 1,4.12) 1E32-F001E 2.5 55-8 E3 1/A GT M0 C
MS Loop B Blt.ed Valve LT RR RV-19 Outboard (See Note 1,4,'12) 1E32-F0013 2.5 55-8 C3 1/A GT M0 C
MS Loop C Bleed Valve Li RR FN-19 Outbo&rd(See Note 1,4,12) lE32-F00lN 2.5 55-8 C3 1/A GT M0 C
MS Loop D Bleed Valve LT RR RV-19 Outboard'See Note 1.4.12)
IE32-F003A 2
55-8 F4 2/B GB M0 C
MS Loop A Bypass to Steam tinoel. (See Note 1) lE32-F003E 2
55-8 04 2/8 GB M0 C
MS t.mp B Sypass to Steam tunnel (See Note 1) lE32-F003]
2 55-8 C4 2/B GB M0 C
HS Loop C Bypass to Steam ttnnel (See Note 1) lE32-F003N 3
55-8 B4 2/B GT M0 C
MS Loop D Byrnss to Steam ttonel (See Note 1) l lE32-F002A 2.5 55-8 F3 2/B GT M0 C
MS Loop A Bleed Valve (See Note 1) i t
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Commonwealth Edison INSERVICE TESTING PLAN system NB-Nuclear Boi1er LaSalle County Nuclear Station Unit 1 page 1
ee 3
REVISION 1/ JULY 1983 00 01 02 03 04 05 06 07 08 09 10 11 12 13 1821-F346
.75 93-3 B6 2/AC EFC 0
E LT RR RV-34 A
See Note 10 IB21-F348
.75 93-3 A6 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 1821-F350
.75 93-3 A6 2/AC EFC 0
E LT RR RV-34 A
See Note 10 s
.75 93-3 B3 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 1821-F353
.75 93-4 A5 2/AC EFC 0
E LT RR RV-34 A
See Note 10 IB21-F355
.75 93-4 B5 2/AC EFC 0
E.LT RR RV-34 A
See Note 10 1821-F357
.75 93-4 05 2/AC EFC 0
E LT RR RV-34 A
See Note 10 1821-F359
.75 93-4 C5 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 1821-F361
.75 93-4 DS 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 IB21-F363
.75 93-4 C5 2/AC EFC 0
E LT RR RV-34 A
See Note 10 IB21-F365
.75 93-4 E5 2/AC EFC 0
E,LT RR RV-34 A
See Note 9 IB21-F367
E,LT RR RV-34 A
See Note 9 IB21-F370
.75 93-5 A6 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 1821-F372
.75 93-5 C6 2/AC EFC 0
E.LT RR RV-34 A
See Note 10 GE-12 1180
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- t. E U [O's$.Iunni INSERVICE TESTING PLAN system NB-Nuclear Boiler REVISION 1/ JULY 1983 8
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a 00 01 02 03, 04 05 06 07 08 09 10 11 12 13 IB21-F374
.75 93-5 06 2/AC EFC 0
E.LT RR RV-34 A
See Note 10 j
1821-F376
.75 93-5 C6 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 1821-F378
.75 93-5 E6 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 1821-F380
.75 93-5 A6 2/AC EFC 0
E,LT RR RV-34 A
See Note 9 1821-F382
.75 93-5 F6 2/AC EFC 0
E,LT RR RV-34 A
See Note 9 1821-F437
.75 93-3 E3 2/AC EFC 0
E LT RR RV-34 A
See Note 10 1821-F439
.85 93-3 E3 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 1821-F441
.75 93-3 D3 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 1821-F443
.75 93-3 D3 2/AC EFC 0
E,LT RR RV-34 A
See Note 10
't 1821-F445A
.75 93-3 03 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 1B21-F4458
.75 93-3 D3 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 I B21-F447
.75 93-3 C3 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 I B21-F449
.75 93-3 C3 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 1821-F451
.75 93-3 C3 2/AC EFC 0
E,LT RR RV-34 A
See Note 10 GE-T2 1180
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LaSatte County Nuclear Station Unit 1 1
I VALVES REVISION 1/ JULY 1983 8
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IRE 024 2
91-4 B4 2/A CNV A0 C
FS,ST Q
20 RV-19 A
(M-96) Drywell Equipment Drain simp )
LT RR suction.(See Note 4,6 1RE025 2
91-4 C4 2/A NV A0 C
FS,ST Q
20 py_19 A
(M-96) Drywell Equipment Orain sump)
LT RR suction.(See Note 4 1RE026 1
91-4 05 2/A CNV A0 C
FS,ST Q
20 RV-19 A
(M-97) Gland Seal LT RP Reservoir Drywell Equipment (See Note 4) 1RE029 1
91-4 05 2/A CNV A0 C
FS,ST Q
20 RV-19 A
(M 97) Gland Seal LT RR F.eservoir Drywell Equipnent (See Note 4) 1RF012 2
91-4 A4 2/A CNV A0 C
FS,ST Q
20 RV-19 A
Floor Drain (Drywell)
LT RR Sump Suction (M-98) F.C.
(See Note 4) 1RF013 2
91-4 B4 2/A CNV A0 C
FS,ST Q
20 RV-19 A
Drywell Floor' Sump LT RR Suction (M-93) F.C.
(See Note 4)
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00 01 02 03 04 05 06 07 08 09 10 11 12 13 lE12-F026B 4
96-4 B6 2/B GT M0 C
FS,ST Q
40 A
RHR Heat Exchanger Steam Condensing Outlet Stop to RCIC Pump Suction 1E12-F027A 4
96-1 C5 2/A GT M0 C
FS,ST Q
30 RV-19 A
RHR Suppression Chamber LT RR Spray Isolation (M-73)
(See Note 4,6,8) 1E12-F027B 4
96-2 C4 2/A GT M0 C
FS,ST Q
30 RV-19 A
RHR Suppression Chamber LT RR Spray isolation (M-74)
(See Note 4,6,8) lE12-F030 lx2 96-2 B4 2/C RV SP C
RV RR A
RHR System Drain Header Relief (M-91) (See Note 2,4,6,8) lE12-F031A 18 96-1 A4 2/C CV C
E Q
A RHR Pump A Discharge Chk lE12-F031B 18 96-2 C3 2/C CV C
E Q
A RHR Pump B Discharge Chk lE12-F031C 18 96-3 B4 2/C CV C
E Q
A RHR Pump C Discharge Chk lE12-F041A 12 96-1 D7 1/AC NSC A0 C
E CS RV-21 A
RHR LPCI Testable Chk PIT RR RV-19 Inboard Stop (ft-13)
LT RR (See Hote 1,S,7 )
GE-T2 - 1180
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00 01 02 03 04 05 06 07 08 09 10 11 12 13 IE12-F0410 12 96-2 E7 1/AC NSC A0 C
E CS RV-21 A
RR LPCI Testable Chk PIT RR RV-19 Inboard Stop (M-14)
LT RR (See Note 1,5,7) lE12-F041C 12 96-3 E7 1/AC NSC A0 C
E CS RV-21 A
RR LPCI Testable OA PIT RR RV-19 Inboard Stop (M-12)
LT RR (See Note 1,5,7)
IE12-F042A 12 96-1 D5 1/A GT M0 C
RR LPCI Injection Line LT RR 20 RV-19 Outboard Stop (M-13)
(See Note 1,5,4) lE12-F0420 12 96-2 E6 1/A GT M0 C
RlR LPC1 Injectton Line LT RR RV-19 Outboard Stop (M-14)
(See Note 1,5,4) lE12-F042C 12 96-3 E6 1/A GT M0 C
RR LPCI Injection Line LT RR RV-19 Outboard Stop (M-12)
(See Note 1,5,4) lE12-F046A 8
96-1 BS 2/C CV C
E Q
A RlR Pump Minlan Byruss Check IE12-F0460 8
96-2 C2
?/C CV C
E Q
A RIR Pump Mininn flow HyInss Check f il f7 ffMO
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00 01 02 03 04 05 06 07 08 09 to 11 12 13 IE12-F046C 8
96-3 B3 2/C CV C
E Q
A RR Pump Minium Flow Bypass Check lE12-F047A 18 96-4 E4 2/8 GT M0 O
FS,ST Q
180 A
R R Heat Exchanger Inlet Stop lE12-F047B 18 96-4 ES 2/8 GT M0 O
FS,ST Q
180 A
RR t*-at Fxchanger Inlet Stop IE12-F048A 18 96-4 01 2/B GB MO O
FS,ST Q
270 A
R R Heat Exchanger Bypass Stop IE12-F0488 18 96-4 08 2/8 GB M0 O
FS,ST Q
270 A
RtB Heat Exchanger Bypass Stop IE12-F049A 3
96-4 C1 2/B GT M0 C
FS,ST Q
30 A
R R Heat Exchanger Blowdown Upstream Isolation to RB EDT lE12-F049B 3
96-4 C8 2/B GT M0 C
FS,ST Q
30 A
Upstream Isolation to RB EDT lE12-F050A 12 96-1 07 1/AC NSC A0 0
E CS RV-04 A
Rift Shutdown Ce(ding LT RR RV-1J Testable Check (M-8)
(See Hote 1,5,7)
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@ Lesene county Nuclew station Unit 1 Commonwealth Edison RH-Residual Heat Removal INSERVICE TESTING PLAN srei.m p.g.
jj og jj REVISION 1/ JULY 1983 O
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00 01 02 03 04 05 06 07 08 09 10 11 12 13 lE12-F313B 3x4 91-3 C3 2/C RV C
RV RR A
RHR Heat Exchange Relief (See Note 2) 1E12-F023 6
96-1 F6 1/A GB M0 C
RHR to Head Spray (See LT RR RV-19 Note 1,4) lE12-F024A 18 96-1 E2 2/A GB M0 C
FS,ST Q
297 RV-19 A
RHR Test Line for D2 LT RR Suppression Pool Cooling (See Note 4,6,8) lE12-F024B 18 96-2 E2 2/A GB M0 C
FS,ST Q
297 RV-19 A
RHR Test Line for LT RR Suppression Pool Cooling (See Note 4,6,8)
GE T2 -1180
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@ Commonwealth Edison Lasane county Nuclear Station Unit i PUMP & VALVE TESTING Page 1 of 1 RELIEF REQUESTS REVISION 1/ JULY 1983 b@
So ASME 3>
PUMP OH
$0 SECTION XI VALVE NO.
FUNCTION TEST HEOUlHEMENT BASIS FOR RELIEF AllERNATIVE TEST 00 01 02 03 04 05 06 RV-01 ODG-009 3/B Cooling Water Full stroke and These valves open in Perform a full stroke Discharge stroke time quarter.. response to an auto-exercise once per ly backwash logic signal quarter produced by an abnormally 1DG-Oll 3/8 Strainer Backwash high differential Valves pressure across the CSCS service water strainers.
lE12-F336A 3/B RHR Service Water These fast acting, auto-Pump Strainer l A matically controlled Backwash Outlet valves only open to 10%
Stop of full stroke making an accurate stroke time 1E12-F336B 3/B RHR Service Water measurement very diffi-Pump Strainer IB cult to obtain.
Further-Backwash Outlet more, the stroke time Stop of these valves is not considered a meaningful lE22-F319 3/B HPCS Diesel indicator of operational Cooling Water readiness.
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@ Commonwealth Edison LaSalle County Nuclear Station Unit i PUMP & VALVE TESTING Page 1 of 2 RELIEF REQUESTS REVISION 1/ JULY 1983 5
ASME 33 PUMP OR QO SECTION XI VALVE NO.
FUNCTION TEST REQUIREMENT D ASIS FOR RELIEF ALTERNATIVE TEST o
00 01 02 03 04 05 06 RV-02 IIHU17 2/A Drywell Pneumatic Full Stroke and These valves are designed Perform a full stroke to Drywell -
Stroke Time to stroke rapidly with-exercise quarterly.
Fail Close Quarterly in a specified time range.
Verification 11N074 2/B Dryer Purging Vahe that the valve strokes
- Fail Close within the time ran y is 11N075 2/B essential, but due.:.
the inaccuracies involved IINO31 2/A TIP Indexer Purge with measuring short time intervals, stroke time trending provides 1B33-F019 2/A Process Sampling no useful information Valve IB33-F020 2/A and leads to useless and unnecessary mainten-000004 3/B Diesel Oi! Transfer ance operations.
Pump Stop Valve Therefore, the stroke 1D0004 3/B times of these valves will not be trended, but will be verified to 100014 3/B not exceed 5 seconds.
100024 3/B 1CM017A 2/A Containment Moni-toring Valve ICM017B 2/A 1CM018A 2/A 1CM318B 2/A 1C"019A 2/A c.
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@ Commonwealth Edison LaSaHe County Nuclear Station Unit 1 PUMP & V ALVE TESTING Page 2 of 2 RELIEF REQUESTS REVISION 1/ JULY 1983 E
ASME 33 PUMP OH MO SECTION XI mO VALVE NO.
FUNCilON TEST REQUlHEMENT DASIS F OR RELIEF ALTERNATIVE TEST Eg o o 00 01 02 03 04 05 06 RV-02 1CM019B 2/A Containment Monitor-(cont'd) ing Valve ICM020A 2/A 1CM020B 2/A 1CM021B 2/8 1CM022A 2/B ICM023B 2/B 1CM024A 2/B 1CM025A 2/B 1CM026B 2/B ICM031 2/A l
ICM032 2/A 1CM033 2/A 1CM034 2/A l
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@ Commonwealth Edison LaSaHe County Nuclear Station Unit 1 PUMP & VALVE TESTING Page 1 of 1 RELIEF REQUESTS REVISION 1/ JULY 1983 F
So ASME 33 PUMP OH
$O SECTION XI VALVE NO.
FUNCTION TEST REQUlHEMENT DASIS FOR RELIEF ALTERNATIVE TEST 00 01 02 03 04 05 06 RV-10 lE22-F016 2/C Suppression Pool Exercise Quarterly The HPCS system is demon-Exercise each refuel-i Suction Check strated to be operable ing outage during each quarter by taking a HPCS alternate flow suction from, and dis-path test.
charging back to the cycled condensate storage tank.
Cycled conlensate is reactor grade water, however, this is not necessarily true of suppression pool water.
Valve F016 can be exer-cised by aligning the HPCS pump suction to the suppression pool. Allow-ing suppression pool water to enter the HPCS system permits the possibility of cycled condensate con-tamination which would cause many of the units' systems to become contami-nated.
This situation is undesirable at all times, but may be guarded against if tested during refueling nutages.
Therefore, it is requested that this valve be full stroke exercised during each refueling outage.
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@ Commonwealth Edison LaSane County Nuciew Station Unit t PUMP & V ALVE TESTING Page 1 of 1 RELIEF REQUESTS REVISION 1/JUL Y 1983 M
So ASME 33 PUMPOrt 50 SECTION XI wO VALVE NO.
M FUNCTION TEST IlEOulHE MENT DASIS FOIL FIELIEF ALTEllNATIVE TEST Kg 040 00 01 02 03 04 05 06 RV-16 IB21-F024A 3/C MSIV Accumulator Exercise Quarterly Entry into the drywell Exercise during Check Valves is required to confirm reactor refueling i
the closure of these outage.
1821-F024B 3/C check valves.
Since the drywell atmosphere is 1821-F024C 3/C normally inerted with nitrogen gas at all IB21-F024D 3/C times except refueling outages, these valves 1821-F040C 3/C ADS Accumulator may be exercised only Check Valves daring refueling outages when drywell 1821-F040D 3/C entry is possible.
1B21-F040E 3/C 1821-F040R 3/C 1821-F0405 3/C 1821-F040U 3/C 1821-F040V 3/C i
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@ Lasane county Nuclear Station UnH I Commonwealth Edison PUMP & VALVE TESTING Page 1 of 1 RELIEF REQUESTS REVISION 1/J'JLY 1983 So ASME 33 PUMP OR
$O SECTION X1 VALVE NO.
FUNCTION TEST HEOulHEMENT DASIS FOR RELIEF ALTERNATIVE TEST 00 01 02 03 04 05 06 RV-33 IB21-F013C 1/BC ADS Relief Valve Exercise Quarterly Vendor specifications for Perform an 'in place' these ADS safety relief exercise at each 1821-F013D 1/BC valves require steam refueling outage.
pressure.behind the 1821-F013E 1/BC disk before cycling.
Thus, the plant must be 1821-F013R 1/BC in an operating or startup condition with IB21-F013S 1/BC the required steam pressure in the main 1821-F013U 1/BC steam lines.
Since the valves are located IB21-F013V 1/BC inside the drywell, and considering the possibility of a stuck open valve, it is preferable that they be exercised either preceed-ing or following each refueling outage when the containment atmos-
. phere is de-inerted.
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@ Commonwealth Edison LaSane County Nuclear Station Unn 1 PUMP & VALVE TESTING Page 1 of 1 RELIEF REQUESTS REVISION 1/ JULY 1983 N
$0 SECTION XI VA; VE NO.
FUNCTION TEST HE0UlHEMENT BASIS FOR RELIEF ALTERNATIVE TEST o
00 01 02 03 04 05 06 RV-35 1E22-F005 1/C HPCS Injection Exercise Quarterly These normally closed Perform a full stroke Inboard Testable testable check valves exercise during each Check Valve serve as the first isola-cold shutdown.
tion valves in the event lE51-F066 1/C RCIC Injection of a system line break.
Inboard Testable Testing could be performed Check Valve during power operation, however, a real possibility lE21-F006 1/C Primary Containment exists that these valves, Inboard Isolation or their bypass test valves, may not properly 1E12-F041 A l/C reseat, rendering them incapable of perfonning lE12-F041B 1/C their isolation function.
Since the drywell is 1E12-F041C 1/C inaccessible during power operation, the affected penetration would need to be isolated, causing the system to be unavailable for its emergency function The risk involved with the cycling of these valves during power oper-ation is much greater than the assurance of operability gained by quarterly testing.
The valves will be exercised at cold shutdown when thei isolation function is not regiurea.
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