ML20063M583
| ML20063M583 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 09/13/1982 |
| From: | MISSISSIPPI POWER & LIGHT CO. |
| To: | |
| Shared Package | |
| ML20063M579 | List: |
| References | |
| NUDOCS 8209150249 | |
| Download: ML20063M583 (7) | |
Text
_
TABLE 1.6.4-1 (Continued)
C0tlTAIrl!4ErlT Afl0 DRYWELL ISOLATI0?l VALVES MAXIMUM SYSTEM AND PENETRATION ISCLAT!C1 TDIE VALVE flUMBER flVMBER VALVE GROUPS,a) ggec r jg)
Containment (Continued)
RHR Heat Exchanger E12-F028A-A 20(I)(c) 5 78 "A" to LPCI RHR Heat Exchanger E12-F037A-A 20(I)sc) 3 63 "A" to LPCI RHR Heat Exchanger E12-F0423-B 21(1)(c) 5 22 "B" to LPCI RHR Heat Exchanger E12-F0288-B 21(I)(C) 5 73 "B" to LPCI RHR Heat Exchanger E12-F0378-B 21(I)(c) 3 63 "B" to LPCI RHR "A" Test Line E12-F024A-A 23(0)(d) 5 93 to Supp. Pool RHR "A" Test Line E12-F011A-A 23(0)(d) 5 27 to Supp. Pool RHR "A" Test Line E12-F290A-A 23(0)(d) 6 8
to Supp. Pool RHR "C" Test Line E12-F021B-B 24(0)(d) 5 W /C/
to Supp. Peol HPCS Test Line E22-F023-C 27(0) 6 60 RCIC Pump Suction E51-F031-A 28(0) 4 38 RCIC Turbine E51-F077-A 29(0)(c) g yg Exhaust LPCS Test Line E21-F012-A 32(0) 5 101 Cont. Purge and M41-F011 34(0) 7 4
Vent Air Supply Cont. Purge and M41-F012 34(I) 7 4
Vent Air Supply Cont. Purge and M41-F034 35(I) 7 4
and Vent Air Exh.
Cont. Purge and M41-F035 35(0) 7 4
and Vent Air Exh.
Plant Service P44-F070-B 36(I) 6 24 Water Return Plant Service P44-F069-A 36(0) 6 24 Water Return Plant Service P44-F053-A 37(0) 6 24 Water Supply Chilled Water P71-F150 36(0) 6 30 Supply Chilled Water P71-F148 39(0) 6 30 Return i
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EMERGE"CY CORE CCOLIMG SYSTEMS f
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SL'RVEILLANCE RECUIREMENTS 4.5.1 ECCS division 1, 2 and 3 shall be demonstrated OPERAELE by:
At least once per 31 days for the L?CS, LPCI and HPCS systems:
a.
1.
Verifyi.ng by venting at the high point vents that the system piping from the pump distnarge valve to the system isolation valve is filled with water.
2.
Perfor?.ance of a CHAMMEL FUMCTICMAL TEST of the:
a)
Discnarge lir.e " keep filled" pressure alarm instrumentation.
and b)
Header celta P instrumentation.
3.
Verifing that esca valve, manual, power coerated er autcmat'c, in the ficw path that is not locked, sealed, or otherwise secured in position, is in its correct position, b.
Verifing that, when tested pursuant to Specification 4.0.5, each:
1.
LPCS pumo develcps a ficw of at least 7115 gpm against a test line pressure greater than or equal to 128 psid.
2.
LPCI pump deveicos a flow of at least 7450 gpm against a test line pressure greater than or equal to 24 psid.
(
3.
HPCS pump develcps a flow of at least 7115 gpm against a test line pressure greater than or equal to 200 psid.
For the LPCS, LPCI and HPCS systems, at least once per 13 months:
c.
1.
Performing a system functional test whicn includes simulated automatic actuation of the system throughout its emergency operating sequence and verifying that each automatic valve in the flow path actuates to its correct position.
Actual injec-tion of coolant into the reactor vessel may be excluded frca this test.
2.
Performing a CHANNEL CALIBRATION of the:
a)
Discharge line " keep filled" pressure alarm instrumentation and verifying the:
1)
High pressure setpoint 1 J tb_ 1:, pr-::n c :
p;'-t of the:
(a)
LPCS system to be 580 + 20, - 0 psiggand
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- ._eme,
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(b)
L?CI subsystems to be 480 + 20, - 0 psig;:nd
')
_ 10 E psig,
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3 GRAND GULF-UMIT 1 3/4 5-4
E?>ERGE?lCY CCRE COOLING SYSTE!15
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SURVEILLANCE RECUIREMENTS (Continued) 2)
Low pressure setpoint
_ _ __,.5;,.
f b)
Header delta P instrumentation and verifying the setpoint
^
of th.e HPCS system and'LPCS system and LPCI subsystems ::
be 1.2 : 0.1 psic change from the normal indicatad 2P.
3.
Verifying that the suction for the HPCS system is aut0matically transfarred from the concensate storage tank to the suporessicn pool on a condensate storage' tank lou water level signal anc :n a scopression pool nign water level signal.
For the ADS at least ar.ce per 13 months by:
c.
1.
Performing a system functional test ahich ir.cludes simulsted autcmatic actuation of tne system tnrougnout its emergency g
operating sequence, but excluding actual valve actuation.
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2.
Manually cpening each AD3 valve ahen the reactor steam cc :e pressure is greater than or equal to 100 psig* and observing that either; k- %
a)
The control valve or bypass valve position responas accordingly, or b)
There is a ;orresponding change in the measured steam flow.
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n The provisions of Specification 4.0.4 are not applicable provided the surveillance is performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure is adequate to perform the test.
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GRAND GULF-UNIT 1 3/4 5-5
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TABLE 3.8.4.1-1 (Continued) 3 n
g/9 PRD!ARY CONTAlt! MENT PENETRATION CONOUCTOR OVERCURRENT PROTECTIVE DEVICES
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- 480 VAC Molded Case Circuit Breakers _(Centinued) 4 3.
Type MSCP BEEAKER SYSTEM / COMPONENT FUSE TYPE
. NUMBER AFFECTED E2-12202 MSCP-W CONTAINMENT CCOLING FILTER TRAIN HEATER (N1M410002E-N) 52-12209 MSCPp/
CONTAINMENT POLAR CRAh!
Y (Q1F13E001-l1) 52-11502 MSCP-W
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CONTAINMENT CLG FILTER
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TRAIN HEATER (illM41D002A-N).
52-15105 MSCP-X v ORYWELL PURGE COMPRESSOR n>
(Q1E51C001A-A) e..A v 7 52-16204 MSCP-X Y DRYWELL PURGE COMPRESSOR
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(Q1E51C0018-B)
~52-15404 MSCP-W HYDROGEN RECOMBINER (Q1E51C0038-B) i n e.
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- 3. a. 9.1 Two' shutdown coolin j coce leccs of the residual heat removal (RER) system shall be CPERABLE anc at least one snutdown cooling moce locp shall be aa in coeratien^'"" with each Icco consisting of at least:
3.
One OPERAELE RHR pump, anc b.
One OPERAELE RHR heat excninger.
A?:LICAEILITY:
C?ERATICMAL C^NDITICN 3, with reactor vessel pressura les3
. 2-
- ne ann cut-:n cermissive 13tccint.
e t i. _.,l :
Wita less than the scove reccirec HR snutcc n cooling acce locps C?ER;3'_E.
3.
immeciately initiate corrective action to return the recuired locos to 0.ERABLE status as soon as cossible.
Within one hour and at least once per la hours tnereaf t2r, demonstrate the operioility of at least one altarnate metnad cacco!e of dacay heat removal for eacn incperacie RHR snutccwn cooling mode icco.
Ee in at least COLD SHUTDC' N within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. (
b.
With no RHR snutdown cooling mcde loop in operation, immediately initiate corrective iction to return at least one loop to operation as soon as possible.
Within ene hour c',tablish reactor ccolant circulation by an alternate method and monitor reactor coolant temperature and pressure at least once per hour.
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J.J.3.1 At least one shutdown cooling mode loop of the residual heat remova:
system or alternate method shall be determined to be in operation and circuisting reactor coolant at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
"One RHR shutco <a cooling mode loco may be inoperable for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillanca testing provided the other loop is OPERABLE and in operation.
...ine snutdown cooling pump may be removeL, trcm operation ror up to c, hours per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period proviced the other locp is OPERABLE.
- The RHR shutdown cooling mode locp may be removed frcm operation during hycrostatic testing.
"Shenever ; o or more RHR subsystems are incoerable, if unable to attain COLD SHUTO:'..N as recuirec by tais ACTICN, maintain reactor coolant temperature as icw as practical by use of alternate heat renoval methocs.
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COLD 5 HUT 00'<!N
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LIMITING CONDITION FOR OPERATION i
Two# shutdown coolins made loeps of the residual heat removal (RHR) 3.4.9.2 system shall be OPERABLE and at least one shutdown cooling mode loop shall te au in operation *'"" with each loop consisting of at least:
a.
b.
One OPERABLE RHR heat exchancer.
(
APPLICABILITY:
OPERATIONAL CONDITICH 4.
i ACTION:
With less than the above required RHR shutdown coolino mode lcoos GFERAELi, a.
within one bour and at least once oer 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> therea?ter, demonstrate the coeracility of at least one alternate method cacaole of decay hea.
j removal for esca inoperable RHR shutdown cooling mode loop.
]
b.
'elith no ~RHR shutdown cooling mode locp in operation, within cne hour establish reactor coolant circulation by an alternate method and monitor reactor coolant temperature and pressure at least once per hour.
A.
s.
1
]
]
SURVEILLANCE REQUIREMENTS I
4.4.9.2 At least one shutdown cooling mode loop of the residual heat removal f
system or alternate method shall be determined to be in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
4' i
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"One RHR shutdown cooling mode loop may be inoperable for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing provided the other loop is OPERABLE and in operation.
j
^The shutdown cooling pump may be removed from operation for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> per 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period provided the other loop is OPERABLE.
)
- The shutdown cooling mode loop may be removed from operation during j
hydrostatic testing.
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GRAND GULF-UNIT 1 3/4 4-25
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