Text

Proposed TS 4.1.3.1.4 Re Reactivity Control Sys SR for Scram Discharge Vol Drain & Vent Valve Operability & TS 4.3.1.2 Re Logic Sys Functional Tests
	ML20104A441
Person / Time
Site:	Limerick
Issue date:	09/01/1992
From:	; PECO ENERGY CO., (FORMERLY PHILADELPHIA ELECTRIC
To:	;
Shared Package
ML20104A438	List: ML20104A434; ML20104A441;
References
	NUDOCS 9209110218
	Download: ML20104A441 (103)
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{{#Wiki_filter:. _ _ _ _ _ _ _ _ ATTACHMENT 2 LIMERICK GENERATING STATION Docket Nos. 50-352 50-353 License Nos. NPF-39 NPF-85 1 PROPOSED TECHNICAL SPECIFICATIONS CHANGES (TS page markups only) The affected Unit 1 and Unit 2 TS pages are identified within the associated " group" in. Attachment 1 ~ 9209110218 920901 -PDR ADOCK 0D000352-P PDR

.-..e.---. REACTIVITY CONTROL SYSTEMI {~ :.'. SURVEILLANCE REOUIREMENTS (Continued) 4.1.3'.1.4 The scram discharge volume shall be determined OPERAELE by cemonstratinc-The scram discharge volume drain and vent valves OPERABLE, when a. 4 control rods are scram tested from a normal con' rol red configura-k t .orrejf less than or ecual to 50% ROD DENSITY at leest on:e pc'r ? .g-ppy.ernths, by verifying that the drain and vent valver: [ 1. Close within 30 seconds after rectipt of a sigr 1 for control rods to scra.m, and 2. Open when the scram. signal is reset.. b. Proper level sensor response by performance of a CHANNEL TUNCTIONAL TEST of the scram discharge volume scram and control red block level instrumenta~ tion at least once per 31 days. ~ L: .c l LIMERICK - UNIT 1 3/4 1-E I.". 5 :::. t

3890020620 REACTIVITY CONTROL SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b. At least once per 31 days by: ~ 1. Verifying the continuity of the explosive charge. 2. Determining by chemical analysis and calculation

that the availabic weight of sodium pentaborate is greater than or equal to 5389 lbs; the cont.entration of sodium pentaborate in solution is less tha>1 or equal to 13.8% and within the limits of Figure 3.1.5-1 and; the following equation is satisfied:

C x Q >1 ~ Th wt. 86 gpa where C = Sodium pentaborate solution (% by weight) Q = Two pump flowrate, as determined per surveillance requirement 4.1.5.c. 3. Verifying that each valve (manual, power-operated, or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position. c. Demonstrating that, when tested pursuant to Specification 4.0.5, the JE minimum flow requirement of 41.2 gpm per pump at a pressure of greater 1/s than or equal to J1907sig is met 5 y d. At least once p r Jgm nths during shutdown by: 20 1. Initiating it east one of the standby limid control system loops, including on explosive valve, and verifying that a flow path from the pumps to the reactor pressure vessel is available i ( by pumping demineralized water into the reactor vessel, The L replacement charge for the explosive valve shall be from the } same manufactured batch as the one fired or from another batch j which has been certified by having one of that batch success-fully fired. All injection loops shall be tested in 3 operating

ycles.

2.

- Demonstrating that all heat traced piping is unblocked by pumping from the storage tank to the te,t tank and then draining and n

I flushing the piping with domineralized water, f I 3. Demonstrating that the storage tank heaters are OPERABLE by T verifying the expected temperature rise of the sodium pentaborate solution in the storage tank af ter the heaters are energized. ~

This test shall also be performed anytime water or baron is added to the solu-tion or when the solution temperature drops below 70 F.

$*This test shall also be performed whenever all three heat tracing circuits have i been found to be inoperaL,e and may be performed by any series of sequential, overlapping or total flow path steps such that the entire flow path is included. LIMERICK - UNIT 1 3/4 1-20 y gtg Amendment l 22

l 3/4.3.1 REACTOR PROTECTION SYSTEM INSTRbMENTATION LlHITING CONDITION FOR OPERATION p. 3.3.1 As a minimum, the reactor protection sy. stem instrumentation channels shown in Taole 3.3,?-l shall be OPERABLE with the REACTOR PROTECTION SYSTEM RESPONSE TIME as shown.n Table 3.3.1-2. APPLICABILITY: As shown in Table 3.3.1-1. ACTION: With the number of OPERABLE channels less than required by the Minimum a. OPERABLE Channels per Trip System requirement for one trip system, place the inoperable channel (s) and/or that trip system in the tripped condition

within 12 hours. The provisions of Specification 3.0.4 are l

not applicable. b. With the number of OPERABLE ch'anneis less than required by the Minimum OPERABLE Channels per Trip System requirement for both trip systems, p' ace at least one trip system ** in the tripped condition within 1 hour and take the ACTION required by Table 3.3.1-1. SURVEILLANCE RE0VIREHENTS 4.3.1.1 Each reactor protection system instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECX, CHANNEL FUNCTIONAL TEST and CHANNEL CAllBRATION operations for the OPERATIONAL CONDITIONS and at the c f requencies shown in Table 4.3.1.1-1. ~ 4.3.1.2 LOGIC SYSTEM FUNCTIONAL TESTS and s) ulated automatic operation of all channels shall be performed at-least once mcpths. 4.3 1.3 The REACTOR PROTECTION SYSTEM RESPONTE T1HE of each reactor trip functional unit shown.in limit'at'least once per*@lable 3.3.1-2 shall be demnstrated to be within its I months. Each test shall include at least one ch eN 2 per trip system such that all channels are tested at least once every N tim sW24-months where N is the total numoer of redundant channtis in a specific reacte ~ ~ ~ trip system. ~

An inoperaDie channel need not be placed in the tripped conoition where this would cause the Trip function to occur.

In these cases, the inoperabie channei shall be restored to OPERABLE status within 6 hours or the l ACTION required by Table 3.3.1-1 for that Trip Function shall be taken.

- The trip system naed not be placed in the tripped condition if this would cause the Trip Function to occur. When a trip system can be placed in the tripped condition without causing the Trip Function to occur, place the trip system with the most inoperable channels in the tripped condition; if both systems have the same number of inoperable channels, p' ace either trip system in the tripped condition.

( LIMERICK - UNIT 1 3/4 3-1 Amencment No. 53 DEC 171551 1-------------------

5 TABLE 4e3ol.1-1 (Continued) h e !I '3 REACTOR PROTECTICH SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS 'I n CHANNEL OPERATIONAL Cl!ANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICH-I FUNCTIONAL UNIT CHECK TEST CALIBRATION SURVEILLANCE REQUIRED lp[ Li 9. Turbine Stop Valve - Closure H.A. Q R 1

10. Turbine Control Valve Fast 2

Closure, Trip 011

d Pressure - Lcw N.A.

Q R 1 ~

11. Reactor Node Switch Shutdown Position N.A.

R H.A. 1, 2, 3. 4 l

12. Manual Scram N.f.

W N.A. 1,2,3,4,5 (a) Neutron detectors may be excluJed from CHANNEL CALIBRATION. (b) The IFR and SRM channels shall be determined to overlap for at least 1/2 decades during each startup after entering OPERATIONAL CONDITION 2 and the IRM and APPR channels shall be determined to overlap for a least 1/2 ,i w2 decades during each controlled shutdown, if not performed within the previous 7 days. ~ (c) Within 24 hours prior to startup, if not performed within the previous 7 days. u$ (d) This calibration shall consist of the adjustment of the APRM channel to conform to the power values calculated by p a heat balance during OPERATIONAL CONDITION 1 when THEPRAL POWER > 25% of RATED TriEFRAL POWER. Adjust the APPR channel if the absolute difference is grecter than 2% of RATED THYPRAL POWER. Any AFFR channel gain avusteent made in compliance with Specification 3.2.2 shall not be included in determining the absolute difference. [( (e) This calibration shall consist of the adjustment of the APPR flow biased channel to conform to a calibrated flow signal. (f) The LPRMs shall be calibrated at least once per 1000 effective full power hours (EFPH) using the TIP system. i k (g) Verify measured core flow (total core flow) to be greater than or equal to established core flow at the existing loop flow (APRM % flow). During the startup test program, data shall be recorded for the parameters listed to g provide a basis for establishing the specified relationships. Comparisons of the actual data in accordance with g the criteria listed shall commence upon the conclusion of the startup test program. ,i g (h) This function is not required to be OPERABLE when the reactor pressure vessel head is removed per Specification 3.10.1. 1, %I 1 With any control rod withdrawn. Not applicable to control rods removed per Specification 3.9.10.1 or 3.9.10.2. [ h ((j)) If the RPS 'horting links are required to be removed per Specification 3.9.2, they may be reinstalled for up to 2

y hours fot.equired surveillance. During this time, CORE ALTERATIONS shall be suspended, and no control rod shall e

5m be moved from its existing position. ~ p fa) Required to be OPERABLE only prior to and during shutdown cargin deconstrations as perforced per Specification 4 ~ 10.3. g a elf -u

INSTRUMENT.* TION LIMITlHG CONDITION FOR OPERATION (Continued) ACTION: (Continued) c. With the number of OPERABLE cnannels less than recuired by the Minimum OPERAPLE Channels per Trip System requirement for botn trip systems, place at least one trip system ** in the tripped condition within 1 hour i and taxe the ACTION required by Table 3.3.2-1. SURVEILLANCE REQUIREMENTS 4.3.2.1 Each isolation actuation instrumeidation channel shall be demonstrated ~ OPERABLE by the perfr mance of the CHANNEL CHECK. CHMNEL FUNCTIONAL TEST, and CHANNEL CALIBRATION operations for the OPERATIONAL CONDITIONS and at the f requencies sho,<n in Table 4.3.2.1-1. ^ .3.2.2 LOGIC SYSTEM FUNCTIONAL TESTS and s mulated automatic operation of til / channels shall be performtd at least once er GB' mon hs. 58 4-

o 4.3.2.3 The ISOLATION SYSTEM RESPONSE TIME of each isolation trip function shh 1 in Table 3.3.2-3 shall be demonstrated to be within its limit at litast once erfg months.

Each test shali include at least one channel er trip system such t. "2 '/'", g p all channels are tested at least once every H time months, where H is the I total number of redun3.nt channt:1s in a specific solation trip system. '24 ' v'% t = J c The trip system need not be placed in the tripped :ndition if this wcult cause the Trip function to occur. When a trip sy stem can be pitted in the tripped condition without causing the Trip Function to c::ur, place the tri; system with the most inoperable channels in tne tripped conditicr; if butn systems have the same number of inopa.rable cnannels, place either trip sys;Em in the tripped condition. LIMERICK hMIT 1 3/4 3-10 Amendmeat No. 53 DEC 171!!!

~ g " "A> 1 ~- TABLE 4.3.2.1 _ H OLATION' ACTUATION THSTRUMENTATION SURVEILLANCE REQUIREMENTS- .j C!!ANNEL OPE!!AT JOHAL ' W CliAHMEL FUNCTIONAL CllANNEL CONDITIONS FOR WillC1 4 TiilP FUNCTION _CtiECK TEST CAllBRATION SURVEILLANCE REQUIRE t 1. MAIN STEAM LINE ISOLATION n Reactor Vessel Water Level s g a.

1) Low, Low, level 2 5

Q R 1, 2, 3 2) Low, Low, low - Level 2 S Q R 1, 2, 3 b. MainSteac,yne j Radiation - liigh S Q C 1, 2, 3 c. Main Steam Line Pressure - Low 5 H R 1 d. Main Steam Line Flow - liigh 3 g R 1, 2, 3 a c. Condenser Vacuum - Low 5 H R 3, p**, 3.* 's-f. Outboard MSIV Room w Temperature - High 5 - H R 1, 2, 3 g. Turbine Enclosure - Main Steam Line Tunnel Temperature - High 5 H R ], 2, 3 ~ Hanual Initiatt N.A. R j, p. 2. RHR SYSTEM SHUTDOWN COOLING HODE ISOLATIOK ^ => a. Reactor Vessel Water Leve1 g[ Low - Level 3 S ^ Q R

1. 2. 3 e,

O[ b. ReactcrVessel(RilR{igt-In S q g j p' 3 m ,o Permissive) Pressure - liigh a T 5 Han b Initiation N.A-R y A-1.23 c. n-m e m

1 1

_TAh;3.4.3.2.}-1,(Continued) a, IS01ATION ACTUATION IHSTRUMENTATION SURVEILLANCE REQUIREMENTS I F CilANNEL OPEPATIONAL ,) jif. CIIANNEL FUNCTIONAL CIIANNEL CO?ia!1]DNS idR lui! Cit CllECK TEST CALIBRATION SURUE!LLAHM REQU1Hft) i4 .1 RIP FUNCTIDH 4 b REACTOR WATER CLEAHUP SYSTEM ISOLATION 3. Q S. H k l In 2, 3 / RWCS A Flow - litgh a. 5 H R I, 2, 3 b. RWCS Area Temperature - liigh A Temperature - Ifigh S 14 n 1, 2, 3 [l RWCS Area Ventilation c. l H.A. R N.it 1, 2, 3 S! CS Initiation _ Lcw,_ Low, Ieval 7 ~ S 0 R 1, 2, 3 } l, Reactor Vessel Water Leve1 c. H.A. R H.A. f. . Manual Initiation IIIGli PRESSURE COOLANT IH3ECTION SYSTEH ISOLATION 4. a. IIPCI Steam Line S H R 1, 7, 3 A Pressure - liigh , t' s. b. IIPCI Steam Supply S H R I, 2, 3 lYg Pressure - Low IIPCI Turbine Exhaust Diaphragm 5 H R 1, 2. 3 c. Pressure - lif gh g d. IIPCI Equfpecnt Room S H R I, 2, 3 y ' Temperature - liigh IIPCI Equipment Room S H R I,2,3 e. [ A Temperature - liigh O f. IIPCI Pipe Routing Area S H R 1,2,3 O Temperatur g h II. A. I LA.- ] nual Initiation h. ilPCI Steam Line , H. A.- M R 1, 3 =: A Pressure Timer -m_

3 c, .h - i;gi ) 390i000402 1 TABLE 4.3.2.1-1 (Continued), ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREGES m CilANNEL OPERATIONAL .x CilANNEL FUNCTIONAL Ci%fmEL CONDITIONS FOR WilICH c TRIP FUNCTION CilECK TEST CA!.li3 RATION SURVEILLANCE REQUIRED = ~ 5. REACTOR CORE ISOLATION COOLING SYSTEH ISOLATION w a. RCIC Steam Line A Pressure - liigh .5 H R 1, 2,!3 b. RCIC Steam S'mply Pressure - Low 5_ H R 1, 2, 3 c. RCIC Turbine Exhaust Diaphragm Pressure - liigh 5 -H R 1, 2, 3 s d. RCIC Equipment Room T Temperature - liigh 5 H R 1, 2, 3 0 e. RCIC Equipment Room A Temperature - liigh 5 H R 1,2,3 f. RCIC Pipe Routing Area Temperature - High 5 H R 1_, 2, 3 N. A. 1, 2, 3 Hanual Initiation H. A. R h. RCIC Steam Line' a Pressure Timer N.A. H R 1,2,3 5i "= ma ~ ~ 'u w T e e, m

i TABLE 4.3.2.1-1 (Continued) d: 151?tATION ACTUATIDH TH5TRUMENTATION SURVEILLANCE REQUIREMENTS _ 'I OPERATIONAL CilANNEL EllANNEL FUNCTIONAL CIIANNEL CONDITIONS FOR MilCII"3 Q-DIECK TEST C/,LIBRATION SURVEILLANCE REQUIRI.! TRIP FUNCTI0l{ n r g ~i 6. PRIMARY CONTAIHHEHT IS0tATION Reactor Vessel. Water Level S Q R 1, 2, 3 a. S Q R 1, 2, 3

1) Low, Low - Level 2

2) Low, Low, Low - Level 1 I

S Q R I, 2, 3 l Drywell Pressure #2 - Illgh b. North Stack Effluent S Q R 1, 2, 3 c. Radiation liigh d. Delered w 7 Reactor Enclosure Ventilatien S. H R 1, 2, 3 ~ e. Exhaust Duct.- Radiation - liigh w g Outside Atmosphere to Reactor H.A. H Q I, E, 3 r. Enclosure A Pressure - Low Ocleted g. 5 Q R I, 2, 3 h. Drywell Pressure - liigh/ - Low Reactor Pressure Gas to Drywell A Pressure - Low Q 1, 2, 3 Primary Containment Instrument H.A. H k 1. H.A. R N.A. I, 2, 3 " R R Manual Initiat An ~ S [j. ( ox %,0 -so 1 e

_ _ _ _ _ - _ _ _ - = _ _ _ _ _ _ _ - - - - _ _ _ _ _ _ _ _ - - u_ 1 ABCh4.3.2.1-I (Continued) i~ ISOLATION ACTUATION lNSTRUMENTATION SURVEILLANCE REQUIREMENTS -CHANNEL OPERATIONAL- . r d: CHANNEL. FUNCTIONAL CllANNEL CONDITIONS FOR milch g{3-TEST-CALIBRATION SURVEILLANCE REQUIRED TRIP'FUNCTIONt CHECK L M; ..7. -SECnunacy'enNTAINMENTEISOLAi10N II' 2" L ' 'a. Reactor: Vessel Water Level l i' { y -Low, low'- Level 2. S Q R~ 1, 2,_3 1' ![ -b; DrywellPressurefIf-High S Q R 1, 2, 3

c. I. Refueling Ares Unitli Ventilation

g Exhaust Duct Rcdiation - High

_' 3 M R 2.. Refueling Area Unit 2 Ventilation 4

I Exhaust Duct Radiation High S

M R t ^ l' - d.. Reactor Enclosure Ventilation .S M. -- R 1, 2, 3 i. Exhaust Duct Radiation - High l \\ l h. e. Outside Atmosphere To Reactor 4 i Y,. . Enclosure A Pressure - Low .H.A.- M Q-1, 2, 3 . e-t l 7 f. Outside' Atmosphere To Refueling- [ l M_ Area a Pressure - Low N.A. 'H Q I' g N eactor Enclosure -- I Manual Initiation-N.A. R N.A. 1, 2, 3 l i h. Refueling Area N.A. L ) Manual Initiation N.A. R lg

Required when (1) handling irradiated fuel in the refueling area secondary containment, or (2) during CORE o

j. g' ' ALTERATIONS. or-(3) during operations with.a potential for draining the reactor vessel with the vessel head removed and fuel in the vessel. [ .s i" 3 '.W

- When not-administratively bypassed and/or when any~ turbine stop valve is epen.

i %~ PO

During operation of the associated Unit 1 or Unit 2~ ventilation exhaust. system.

,.*i G *3

1. These trip functions- (la, 2b. 3e, 6a, 6h, and 7a) are comon to the ECCS actuation trip runction.

= w fifThese trip functions (2a.._6b, and'7b)' are comon to the RPS and ECCS actuation trip functions. .L e i: fiffThis trip function (Ib) is comon.to the RPS trip function.- a 4; 4

iN5 au tst m o8 3901038720 3/4.3.3 MEGiHCJ CORI C00tlNai Sv$i!M ACTUU!CN 1457Ruvisiti!Cs ~s. ( (!=! SG CON 0! TION FOR 0:!:1*!N j.3.3 T.,e, eme+;enty ::re :::lin; system (!;05) a:. a t i:n i-s tev er.t a t t:,

na-cris sa:=n in ia:1e 3.3.31 snail :e 0:!RAn. !.it. treir tri: set:::nt.

st* ::.*ststent w.itn int v a l e t s s.* *.* l 's tn e i

i a Set:: 1.a. - :: 19.n f 73:!g ).; j.j an: with EMERGENCY CORE COCL!h*, 5Y37!M R!5PONIE TIMI as s..:.n in ia: 1e 3.3.3 3.

A::t!CA!!LITY: As sa:=n in Ta:1e 3.3.3+1. A C

iC N_ :

a. Vita an ECC3 actuati:n instrumentati:n enannel tri:' set:: In: less c:nservative than the valut sac =n.~in the Allowa:1e values ::1v.n :f Ta lt 3.3.3*2. ce:lare the channel in:cerable until the enannel is resterte t: OPERAlt! status with its trip set:: int a:Juste: c:nsistaa.t with the Trip 5et:: int value. l t. Vita ene-cr mere ICCS actuatica instrumentati:n enanne15 in pera:1ey take tne Aci!CH re:uire: :y Ta:1e 3.3.31. c. Vita eitner A05 tri; system su: system in:; era:lt, rest:re tne in ; era:1e' tri; system to OPERAili status witnin: .1. 7 cays, ;r:vi:ec tnat the hfCl and RCIC systems art OPERA!L!. 3 2. 72 n:urs, 0 ntrvise, te in at least H0i SMUTOCVN witni.n tne next *2 n:urs anc recute-rea:::r'staam c:me :ressura to less than er e:ual 1: 100 psi; witnin :nt f:11:<in; 24 n ers. f SUE'v!!I.L ANCE RIOUIRiHENTS l) 4.3.3.1. iaen [CCS ac'Vati:n hs*.TV entati:n :nannel shall be et". ns'.ratt! ( CPEAAILE ty the perf:rsan t Of tne CMANNEL CMECX,. CHANNEL FUNCTIONAL Ii!I an: - CHANNEL CALIBRATICH c:erati:ns f:r the 07! RATIONAL COH0!i1CNS anc at int f r e:u e n:i e s s hows in T a b l e 4. 3. 3.1 1. I.3.3.2 LOGIC ST TEX FUNCTICMAt. T!!is an: s imu131ay-a utpa ti: ::erati:n :1 A I er9Sr.cntns. all : annels. shall te perf:rmed at Itast enca .2 &V L 4,3.3.3 The ECC5 RE570H5E TIME :f eaen ECCS trip functi:n sa:wn 'ynMia,:1 e' 3. 3. 3-3 }E sna11 te.cemenst.ated i: be_witnin :ne limit at'least en: per[ )mentns. E a :n.. tast. snan in:M:W tt.least.cr.e :.nanneL *tr t i.;. system wrn talt. an : nan,ncis, L' are testic.at least en:e every H timeskmen:tas'vnere N is the ::tal num:s? b l E ' :f recun: ant cnannels-in'a_s:e:ifi: ECC5ltri; system. n 6

9'#~ 0 3 EI LIMERICK'- UNIT ~1 3/4 3*32 1

1 w-- .,+,~+n- --,..,.-n..... -. _ - - - - - - - - - - - - -. - ~ - - ~. -,, nn--.-- .,,w<-,-,

4 }k ' TABLE 4.3.'3.1-1 ,n EMERGENCY CORE: COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE-REQUIREMENTS. ~ CilANNEL OPERATIONAL {- j. . CHANNEL FUNCTIONAL CllANNEL CONDITIONS FOR WHICH ,, TRIP FUNCTION' CllECK TEST-CALIBRATION-SURVEILLANCE REQUIRED i

.g 4

1..

CORE SPRAY SYSTEM'

-a.- ' Reactor. Vessel Water Level'- . Low Low Low, Level 1 S ~Q

R.

1, 2, 3, 4*, 5* t l" Drywell Pressure - High 5 Q R 1, 2, 3 i b. F c.- Reactor VesseLEtessure tw t Q D 1, 2, 3, 4*._5* z [ g Manual Initiation N.A. R N.A. 1, 2, 3, 4*, 2. LOW PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM 1 a.- Reactor Vessel Water Level - . Low' Low Low.itevel.1' S Q R 1, 2, 3, 4*, 5* b. Drywell. Pressure - liigh S Q R 1, 2, 3 c. Reactor Vessel Pressure - Low 5 0 .R 1, 2, 3 1 d. Injection Valve Differential:, { ressure_- Low-(Permissive) S 0 R ' 1, 2. 3, 4*. 5* I . Manual InittatIon N.A. R H.A. 1, 2, 3, 4*, 5 + o 1 3. 'llIGH PRESSURE COOLANT INJECTION SYSTEM *** a.- Reactor Vessel Water Level--- b.' Drywell Pressure - High. S Q R 1, 2, 3 Low Low, tevel 2 5 Q R 1,2,3 c. Condensate Storage Tank Level - g . Low S Q-R

1. 2, 3 l

l ~ 3.g d. Suppression Pool Water level - 'High. ~ 5 Q R 1,2,3 I n c. Reactor Vessel Water Level - I ,F High, level & S Q R 1 3 C _ Manual Initiation M.A. R N.A. 1, 2 w I ~ / y ;by =# %p ,e i e b I ~ 4 m-

.D 9h 9 - "4 -y q' TABLE 4.3".Y.1-1 (Continued) EMERGENCYCORECdDLINGSYSTEMACTUATIONINSTRUMENTATIONSURVEILLANCEREQUIREMENTS s 1, P,, CPANNEL OPERATIONAL 4 Cl!ANNEL FUNCTIONAL CilANNEL CONDITIONS FOR WHICil ] TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REQUIRED a i I AUTOMATIC DEPRESSURIZATION SYSTEM y a. Reactor Vessel Water Level - l. Low 1.ow Low, level 1 5 Q R 1, 2, 3 .b. Drywell Pressure - High S Q R 1, 2, 3 c. ADS Timer H.A. Q Q 1, 2, 3 d.- Core Spray Pump Discharge Pressure - High S Q R 1, 2, 3 l e. RHR LPCI Mode Pump Discharge lA Pressure - High 5 Q R 1, 2, 3 I f. Reactor Vessel Water Level - Low, Level 3 0 R 1, 2, 3 I' g. Manual Initiation H.A. R N.A. 1, 2, n.l Aus urywei O ressure Bypass Timer H.A. Q Q 1, z,.s l t' 5. LOSS OF POWER i Y a. 4.16 kV Emergency Bus Underg, C voltage (Loss of Voltage) N.A. R H.A. I, 2, 3, 4**, 5** b. 4.16 kV Erergericy Bus Under-voltage (Degraoed Voltage) S H R 1, 2, 3, 4**, 5** ..F ~ m n [. When the system is required to be OPERABLE per Specification 3.5.2. l]g Required OPERABLE when ESF equipment is required to be OPERABLE.

5

,5

- - Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 200 psig.

1 Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 100 psig. il loss of Voltage Relay 127-11X is not field setable. 9 4 4

. ~ -- --*.'*.-*-.~%.-~...~.... + !NSTRUMENTATION, 3/4.3.4 RECIRCULATION PUMD TRIP ACTUtTION INSTRUMENTATION ATV5EECIRCULAIIONFUMPTRIPSYSTEMINSTRUMENTATION _ LIMITING CONDITION FOR OPERATION 3.3.4.1 The anticipated transient without scram re:ir:ulation pump trip (ATWS-RPT) system instrumentatien channels shown in Table 1.3.4.1-1 shall be OPERABLE with their trip setpoints set consistent with values sh:wn in the Trip' Setpoint column of Table 3.3.4.1-2. s ' APPLICABILITY:. OPERATIONAL CONDITION 1. ACTION: . [: With an AlyS're:irculation pump t$ rip system instrumentation channel a. trip setpoint less conservative than' the value shown in.the Allowable Value,s column of Table 3.3.4.1-2, declare the channel inoperable until the channel is restored to OPERABLE status with the channel trip _ setpo' int adjusted ' consistent with the Trip Setpoint value, b. With the number of 0?ERABLE channels one less than required by the . Minimum OPERABLE Channels per Trip System recuirement for one or.

both trip systems, pla:e the inoperable channel (s) in the tripped condition within 1 hour.

With the number of OPERABLE channels two or more less than required c; by the' Minimum OPE?AELE Cb=.nneli per Trip System requirement for one ~ trip system and: 1. If the inoperable channels consist of one reactor vessel water level channel and one reacter ve'sel pressure channel, place both s ?

inoperable channels in the tripped c:nditien within 1 hour, or, if this action will initiate a_ pump trip, de:lare the trip system ineperable.

2. If the ineperable channels include two rea:ter vessel water level channels or two reacter vessel pressure enannels, de:lare the trip _ system inoperable, d. With one trip system incperable, restore the ineperable trip system to OPERA 3tE s nus wi:nin 72 hcurs or be in a. least STARTU? within the.nex. 6 hours. With both trip systems ine:eracie, restere at least ene trip system e. to OPERAELE status wi nin 1 h:ur er be in a least STAF.TU? vithin

ne next E hours.

SURVEILLANCE REOUIREMENT5 4.3.4.1.1. Each AiV5 re:ir:ulation pump trip system instrumenta. ion channel shal1~ be demonstrated 0? ERA 3LE by ine performance cf the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION operations n the fr.equen:ies shown in Tabl e 4. 3. 4.1-1. f-s _^ _. 4.3.4.l.2 LOGIC 5"5 TEM FUNCTIONAL TESTS and simula a- ": mati cpernien of all channels shall be perfermed at leas on:e -. :25i m:nt... =yt{q ,j ~ G 5 W, ~ LIMERICX - UNIT 1 3/4 3-42 ......... ~

-O K-l l l 1 INSTRUMENTATION g SUP.VE!LLANCE RE0JIREMENTS-4.3.4.2.1 Each end of-cycle re:irculation pump trip system instrumentation channel shall be demonstrated OPERABLE by the perfor:En:e of the CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION operations at the frequencies shown in itble 4 3 4.2.1-1 i 4.3.4.2.2.. LOGIC SYSTEM FUNCTIONAL TE5TS and simulated automatic coeration of V all channels shall be performed at leest once .7I{0 I ER: s. 3 ( 2. 4.3.4.2.3 The END-OF-CYCLE RECIRCULATION PUMP n... s STEM RESPONSE TIME ef each tr.ip. function shown.:in Table 3.3.4.2-3 shall be der.onstrated to be within Saits-limit 'at'least 'onceWi@conths. Each test shall in:.lude at least the 7.py icgic of one type of channel input, turbine control valve fast closure or turbine stop.yaje closure, such that both types of channel inputs are tested -~ l gEit*1e'isedndepe/f ( $ recent breaker arc $ months. The measured time shall be added to the m suppression time and the resulting END-OF-CYCLE-RECIRCULATION I(fy -PUMP TRIP SYSTEli RESPONSE TIME shall be verifiad to be within its limit. N N l 4.3.4.2.4 The time interval ne:essary for breaker at: -~ Istion of the recirculation pump circuit breaker trip coil shall be caesuredsu:pression frem energi. at least on:e per 60 months. ^ l l LIMERICK - UNIT 1 3/4 3-47 ~ ~i ...a ' * ~

=- INSTRUMENT ATIOl_f 3/a.5.5 R'EA: TOR CORE 150!" TION COOLING SYSTEM ACTUATION INSTRUMENTATION LIMITlwG CDNDITION FOR OPEMTION 3.3.5 The reactor core isolation cooling (PPI'C) system actuation iretrumentation channels rhown in Ta.ble 3.3.5., shall be OPERABLE wit'. their tr .tpointi set consistent with the values shown in the Trip 5etpcir.: ^ column of Table 3.3.5-2. APPLICASILITY: OPERATIONAL CONDITIONS 1, 2, and 3 with reactor steam dome pressure greater than 150 psi: - ACTION: a. With a RCIC system actuation instrumentation channel t-p setpcint less conservative than the value shown in the Allowabi. Values column of Table 3:3.5-2, declare the channel incperable until the channel is restored to OPERASLE status with its trip setpoint adjusted consistent with the Trip Setpoint value. b. With one er more RCIC system actuation instrumentation channels inoperable, take the ACTION required by Table 2.2.5-1. SURVEILLANCE REOUIREMENTS 4.3.5.1 Each RCIC system actuation instrumentation channel shall be demnnstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and CHANNEL CALIERATION operations at the frequencies shown ir Table 4.3.E.1-1. / . ~ ~~,.s W .2 LOGIC SYSTEM FUNCTIONAL TESTS and sic"'6;- atic operatien cf k ali hanneis shall be perfor::ed a. least once per)( m n .s. ~yYt LIMERICK - UNIT 1 3/4 3-52 i ,- = *

r.r. r..m: s,; y, _,,,.,-

TABLb4.3.5.1-1 REACTOR CORE ISOLATION SYSTEM ACTUATION lHSTRUMENTATION ~ ~ SURVEILLANCE REQUIREMENTS CHANNEL CHANNEL FUNCTIONAL CHANNEL FUNCTIONAL UNITS _ CHECK _ TEST CAllBRATION a. Reactor Vessel Water Level - Low Low, Level 2 S Q R [ b. Reactor Vessel Wat?" Level - High, Level 8 S Q R l c. Condensate Storage Tank Level - Low 5 Q R g Manual Initiation N.A. R A .g s{i? s i P LIMERICK - UNIT 1 3/4 3-56 Amendment No. 53 DEC 17 !!91

[:f 1 . f 'l TABLE di3.6-1 l CONTROL R0u OLOCK INSTRUMENTATION SURVEILLANCE REQUIREMENTS h CliANNEL ~ OPERATIONAL /* I 'I CllANNEL FUNCTIONAL CilANNEL CONDITIONS FOR W!!ICli f! TRIP FUNCTION CilECK TEST CALIBRATIOF(a) SURVEILLANCE REQUIRED

j h

1. R0D BLOCK MONITOR S/U(b)(c),(c)/ S/U(b)(c) (c SA 1* N a. Upscale N.A. ^ N.A. 1* b. Inoperative N.A. ~ c. Downscale N.A. S/U(b)(c),,(c) SA 1* 2. APRM a. Flow Biased Neutron flux -- S/U((b) Q SA 1 Upscale N.A. S/U b),Q N.A. 1, 2, 5*** b. Inoperative N.A. S/U(b),Q I SA 1 c. Downscale N.A. S/U b),Q SA 2, 5*** d. Heutron flux - Upscale, Startup H.A. 3. SOURCE RANGE MONITORS t' a. Detector not fuli in H.A. S/U ,W N.A. 2, 5 b. Upscale H.A. S/U ,W SA 2, 5 y c. Inoperative N.A. S/U ,W N.A. 2, 5 d. Dowi. scale N.A. S/U ,W SA 2, 5 4. INTERMEDIATE RANGE MONITORS N ^- 2, 5 a. Detector not full in H.A. S/U ',W Sj y b. !!pscale H.A. S/U f, f c. Inoperative N.A. S/U ,W N.A~ d. Downscale N.A. S/U ,W SA [ 5. SCRAM DISCilARGE VOLUME a. Water Level-liigh N.A. Q R 1, 2. 5** l 5h 6. REACTOR COOLANT SYSTEM RECIRCULATION FLOW a. Upscale N.A. S/U ,Q SA 1 sO D b. Inoperative H.A. S/U ,Q H.A. 1 L, c. Comparator N.A. S/U ,Q 5A 1 u 7. REACTOR MODE SWITCil SIIUTDOWN PDSITION N.A. R H.A. 3, 4 j

INSTRUMENT'ATION /~k: REMOTE SHUTDOWN SYSTEM INSTRUMENTATION AND CONTROLS LIMITING CONDITION FOR OPERATION l - 3.3.7.4 ' The remote shutdown system instrumentation and controls snown in ' Table 3.3.7.4-1 shall be'0PERAEtE. APPLICABILITY: OPERATIONAL CONDITIONS 1 and 2. -ACTION: -a. With the number of OPERABLE remote shutdown system instrumentation l channels less than required by Table _3.3.7.4-1, restore the_ inoperable channel (s) to OPERAELE status within 7 daus or be in at least HOT SHUT 00WN within the next 12 hours. b. With--the number of OPERABLE remote shutdown system controls less than required in Table 3.3.7. 4-1, r-store the inoperable control (s) -to-OPERABLE. status within 7 days.or be in at least HOT SHUIDOWN within the next 12 hours, c. -The provisions'of Specification 3.0.4 are not applicaole. .( SURVEILLANCE REOUIREMENTS l4.3.7.4.1 Each of' the-above required remote shutdown monitoring instrumentation

channels shall be demonstrated ' OPERABLE by. performance of the CHANNEL CHECK and CHANNEL' CALIBRATION operations at the frequencies shown in Table 4.3.7.4-1.

h ~ ~ E4.3.7.4.2 Each of the above remote shutdown control switch (es) and contras - circuits shall be demonstrated OPERABLE, veruying its capability to perform its intended function (s) at least once gerglD,orkne I 14 '- e L LIHERICK Ut4IT 1 3/4 3-75 AUS 0 5195

~ 3901000402 y ~ INSTRUMENTATION _ 3/4.3.9' FEEDWATER/ MAIN TUR31NE IRIP SYSTEM ACTUATION INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.9 The feedwater/ main turbine trip system actuation instrumentation channels shown in Table 3.3.5-1 shall be OPERABLE with their trip setpoints set consister. with the values shown in the Trip Setpoint column of Table 3.3.9-2. ~ APPLICABILITY: As shown in Table 3.3.5-1. ACT10N_: With a feedwater/ main turbine trip system actuation instrumentation a. channel trip setpoint less conservative than the value. shown in.the . Allowable-Values column of Table 3.3.9-2, declare the channel inoper'- able and.either place the inoperable channel in the tripped condition until the channel is -restored to OPERABLE status with ' +1 tr-set-point adjusted censistent with~ the Trip 5etpoint value, or L are the associated system inoperable. With the number of OPERABLE channels one'less than rekuired by the b. - Minimum OPERABLE Channels requirement, restore the inoperable channel 4 to OPERABLE status within 7 days or be-in at least STARTUP within .the next.5 hours. j !With the number of OPERABLE channels two less than required by the c. Minimum OPERABLE Channels requirement, restore at least one of tne inoperable channels to OPERABLE status within 72 hours or be in at least STARTUP within the next 6-hours. . SURVEILLANCE REOUIREMENTS. ,t* - 4 3. c 1- "h feedwater/ main tur:ine tris svstem a:tuation instrumentatien enannei -shall-be demonstratec CPERAELE by the perfermance cf.ne CHANNEL CHECX, CHANNEL FUNCTIONAL TEST, and CHANNEL CALIERATION oceratiens fer-the OPERATIONAL = CONDITIONS and at the; f requencies snown in Table 4.I.5.1-1. l 2 LOGIC SYSTEM FUNCTIONAL TE5TS and simul . hatic coera-icn of \\ all channels shall be perf:rmed at least cnce er Q 6 m: nth. } yq-u I t AUS S SG LIMERICX - UNIT 1 3/4 3-112 l-b 4.

3895241160 REACTOR COOLANT SYSTEM SURVEILLANCE RE0VIREMENT5 4.4.1.1.1 Each pump discharge valve shall be demenstrated OPEKA5LE bv cvciinc each valve throu'gh at least one ccmplete cycle of full travel during 'each ~ startup* prict to THERFAL POWER exceeding 25% of PATED THERFAL POWER. ~ 4.4.1.i.2 Each pump MG set sccep tube mechanical and electrical step shall be demonstrated OPERABLE with overspeed setpoints less than r-+q"- to 10E% and j 107%, respectively, of rated core flew, at least once er tW:ent. s. 4T4. L m 4.4.1~.1.3 Establisn a casenne APRM and LPRM" neutranW noise value within the regions for which; monitoring is required (Specification 3.4.1.1, ACTION c) within 2 hours of entering the region for which monitoring is recuired uniess baselining has previously been performed in the regica since the last refueling cutage. 4.4.1.1.4 With cne reactor coolant system recirculetion lec; not in' operation, at least cnce per 12 hours verify that: Reactor THERPd POWER is 170% of PATED THERMAL POWER,. a. b. The recirculation flow control system is in the Local Manual mcde, and c. The speed cf the operating recirculation pump is 190% of. rated pump ( speed. d. Core flow is greater than 39% when THERMAL POWER is within the restrictac 2cne of Figure 3.4.1.1-1. 4.4.1.1.5 With one reactor coolant system re..rculation loop not in cperatien, within 15 minutes prior to either THERFAL POWER increase er recirculatien ico? flow increase, verify that the felicwing differential temoerature requirements are met if THERMAL POWER is < 30% of RATED THERFAL POWER cr the recirculation locp flow in the opera-ing ricirculation locp is 150% cf rated lecp ficw: a. < 145'P between reactor vessel steam space cecian. and bcttom head iircin line cc Tant, b. < 50 F between the reacter coolant within the lec:. net in cceration and the ccolant in the reacter pressure vessel, and c. < 50 F between the reacter cociant within the 1cce net in coeration and the cperating locp. The dif ferential temperature requirements of Specification 1.4.1.1.5c. anc c. do rot apply when the lecp not in cperation is isolated frca tne reacter pressure vessel.

If not performed wi.hin the previous 31 days.

" Detector levels A and C cf one L RM string per core cc an. plus detecters A and C of one LCRM s. ring in the center of the ccre snould be menitered, k.- LIMERICK - UNIT 1 3/4 4-2 Amencment Nc. ), 30 l JL13 0 Gi

, REACTOR COOLANT SYSTEM _ SURVEILLANCE REQUIREMENTS i 4.4.3.2.1 The reactor coolan't system leakage shall be demonstrated to be within each of the above limits by: Monitoring the primary containment atmospheric gaseous radioactivity at a. least once per 12 hours (not a means of quantifying leakage), b. Monitoring the drywell floor drain sump and drywell equipment drain tank flow rate at least once per eight (8) hours, } Monitoring the drywell unit coolers condensate flow rate at least once c. per 12 hours, d. Monitoring the primary containment pressure at least once per 12 hours (not a means of quantifying leakage), Monitoring the reactor vessel head flange leak detection system at e. least once per 24 hours, and f. Monitoring the primary containment temperature at least once per 24 hours (not a means of ouantifying leakage). ~ 4.4.3.2.2 Each reactor coolan: system pressure isolation valve specified in Table 3.4.3.2-1 shall be demonstrated OPERABLE by leak testing pursuant to Specification 4.0.5 and verifyins the leakage of each valve to be within the specified limit: ff2r-a. At least once er ) /8'r whs, and .m b. Prior to returning the valve to service following maintenance, repair or replacement work on the valve which could affect its leakage rate. The provisions of Specification 4.0.4 are not applicable for entry into OPEPATIONAL CONDITION 3. 4.4.3.2.3 The high/ low pressure-interf ace valve leakage pressure monitors shall be demonstreed OPERASLE with alarm setpoints set less than the allowable values in Table 3.4.3.2-1 by performance of a: a. CHANHEL FUNCTIONAL TEST at least once per 31 days, and b. CHANNEL CALIBRATICH at least once per 18 months. LIMERICK - UNIT 1 3/4 4-10 Amendment No. 49 Apg a 4 im j

.m ENERGENCY C0aE COOLING SYSTEMS SURVElttMCE kEOUIREMENis 3, 4.5.1 The emergen:y c:re c:: ling sys eas snail :n :e castrated 0?!EAILE v-a. At, lees: Onet :er 31 cays: c =. e, r:r t'.e ..u. "e te...u sys tas, a.: tre M;C! sjs e ; e) <erifyinggyventinga: the t.ig. ::in; ven:s :ng: :ne system c1 ping from tne ;t.m: :is:ner:e valvt 1: :ne s~ys:n is:lati:n valve is filled wt:n wate". b) VeHfying t(.at each valve (manual, ;cwer-:;tra:e: Or avt::a:1c) In the flev path taa. is pet lected, setie:, :- o:ner ise secured in positien, is in 1:s c:rre::' p;siti:n 2. For tr.e L?CI system, verifying :n.: t::n (?C! system setsyste, cross-tie valves (HV-51-152 A, 5)'are cicsee witn p:we. ren ve: fr:m tne valve operators. 3. For the HPCI system, verifyingtna't tie HFCI pump ficw c:ntr:iler is in the c:rrect position. 4. For the C55 and 1.?CI system, perfor:ance of a CHANNEL FUNCTIONAL TE5ioftheinjectionheaderopinstrumentation. Verifying that',"When' te'sted pursuarit "ko SpecificatiN 4.0IS: ' b. 1. Each L53 pump 'in each'subiystem devele;s a flow cf at leas t 3175 gpm against a test line pressure c:rrespending to a reat::r vessel to primary containment differential pressure of plus head and line losses. 1 105 : sit ,1 2. Ea:h L?CI pump-in each subsystem ceveleps a flev cf a: leas: 10,000 g;m against a test line pressure c:rresponding :: a reacter vessel to primary c:ntainment differential pressure cf 3 20 psid plus head and line losses. 3, The HPCI pu:p develeps a flew of at least 5500 pm agains; a test line pressure which corresponds -t: a reactor vessel -pressure of 1000 s' lus head and line losses when steam is being sutoli & h at 1000, +20 20 psig.'" c. At least enca p r G8mer*, : l. ?cr the CSS, the L?CI system, anc :ne HFCI systam, cerf: min; a f system functi:nal :es. whi:n incle:es simulate: aut:: ni: ' - q ac.vati:n cf :ne system inr:ugr.cu i n emergen:y c; era.ing saquen:e anc verifying taa: eae.. aut:ma.ic valve in tne ficw path ac: a us t: in c:rre:: ;csi i:n.. Actual injecti:n f I c: clan: in.: t.7.e_ reac:cr vessai may be en:lu:ed fr:a :nis tast. V "Ex:s:: :na: an aut::ati: valve ca a:le of au:::a:ic return :: its E C5 pesiticn wnen an ECC5 ' signal is present may :e in pesi:ica f:r an::ner :::e cf c:eration.

==The pr:visiens cf 5:ecifi:ation 4.0.n are n : a::lica:le, Or:vice: :n* surveillanca is :erf:rmed wi.nin 12 hcurs af er rea: :r steam crassure is icecuata :: :erf:rm :ne us. If 0?ERASILITY is n:: suC:essfully Ce::ns:TE!! 3 within tne 12-heur ;erice,' recute reac;:r stau ::ce pressere :: less ::an 200-esig witnin-:ne fcilcving 72 hcurs. ~LIMERICX - UNIT 1 3/4 5-4 k:end:en: Nc. u .iut 2 2 !!33 m

.nuiUUU4Ud E'HERCENCY CORE COOLING SYSTEMS p SURVEILLANCE RE0VIREMENTS,(Continued) ~_ [. 2. For the HPCI system, verifying that: . i) The syst;m develops a flow of at least 5500 cpm against a test line pressure corresponding to a reactor vessel pressure /j 4 6 of 1200 psig plus head and line losses, when steam is bein; l supplied to the turbine at 200 + 15, - O psig." 1 b) .The suction is automatically transferred from the condensate storage tank to the suppression chamber on a condensate storage tank vater level - low signal and on a s'ppression u chamber water level hich sional, m +_ 3. Performing a CHANNEL CALIBRATION of the CSS, LPCI, and HPCI system discharge line " keep filled" alarm instrumentation. 4. Performing a CHANNEL CALIBRATION of the CSS header AP instru-i mentation and verifying the setpoint to-be < the allowable value of 4.4 psid. 5. Performing a CHANNEL CALIBRATION of the LPCI header aP instru-mentation and verifying the setpoint to be < the allowable value of 3.0 psid........ ~ K.f, /, d. For the ADS: 1. At least once per 31 days, performing a CHANNEL FUNCTkONA1. TEST of the accumulator "kup-ccmpressed gas system low presse, a alarm system. 4 At 1eist on e per3J$h: ' 7 2. I a) Performing a system functional test which includes simulated-lf automatic actuation of the system throughout its emer;ency i operating sequence, but ' excluding actual valve actuation. I b) Manually openi-ng each A05 valve when the reactor stesc. I dome pressure is greater than or equal ta 100 psig" and 4 observing that either: 1 1) The c:ntrei valve er bypass valve position responds / ac:ctdir~ gly, or i 2) There is a ccrresnoncing char.ge in the measured 3.eam flow. c) Perror. ng a Chr.NNEL CALIERATICH cf thUac:uculator backuc ccepressac gas system low pressure alarm system and verifying an alarm se:pcin; of 90 = 2 psig on decreasing pressere. "The provisions of Specification 4.0 4 are not applicable, provided the surveillance is performed within 12 hours after reactor stesa pressure is adecuate to perform the test. If HPCI ur ADS OPERASILI1Y is not successfully demonstrated within.the 12-hour period, reduce reactor steam deme pressure to less than 200 psig or 100 psig, respec-ively ithin the icilowing 72 . hours. I k. LIMERICK - UNIT 1 3/4 5-5 Amendment. No. U, 22 GCi 2 0 3d V

f,

v,

3901000402:

= ;y t

CONTAINMENT SYSTEMS "

(l.$<;$SURVEILLANCE REOUIREMENTS (Continued)

' ~. ~ d. l.. TypeBTan'd: C tests; shal1~ be conducted with gas at P,, 44.0 psig*, 3 [ Jat. intervals no__ greater sthan 24 months 'except for tests.'itMolving: '1:

Air locks, 2.

'Hain stea'mLline: isolation valves, 3. Containment isolation valves in hydro' statically tested lines - which penetrate the primary containment, and Le. - Air locks'shall_ be tested and demonstrated OPERABLE per Surveillance Requirement 4.6.1,3. ~ g g'. /, y. f.. - Main steam line isciation valves _shall be leak tested at least e T - per 14 month g g g g [g g e g 2f g s g g o'(( f Y'I.j, y,. g. Cont'ainment isolatten valves in hydrostatically tested lines which-t penetrate the pripary containment shall be leak. tested at least a - /2 P e rf C0

th5$QYY'$W5I'SY?5$$$?!5EE&fE I"_~#[f?'-

h. _TEelprovi cation 4._0.2 are noi applickb M pecifTea N T ' tions-4 6;1. 2a., __4. 5.1. 2b., 4. 6.1; 2c., 4. 6.1.2d., anli 4. 6.1. 2e. .7 ,Q, ,.. a t: ~. s + r- ..c. "Unless a hydrostatic'.- test is required per Table 3.6.3-1. 4 {t.IMERICK-UNITIL 3/4 6 " Amendment No.%,. 33 OCT 3 0 ISI3 L' [^ r h -' .u. m. gy m._____,__ _ _ _ _ _ _ _ _ _ _, _ _

[ CONTAfNMENT-SYSTEMS .? - MSIV LEAKAGE CONTROL SYSTEM LIMITING C0FDITION FOR OP:. RATION 3.6.1.4 Two iadependent MSIV icakage control system (LCS) subsystems shall be OPERABLE. APPLICABILITY: OPERATIONAL CONDITIONS 1; 2, and 3. ACTION: 'With one MS W. leakage control system sub' system inoperable restore the inopecable subsystem to OPERABLE status within 30 days or be in at least HOT SHUTDOWN within the next 12 hours and in' COLD SHUTDOVH within the folicwing,24 hours. EURVEILLANCE REOUIREMENTS 4.6.1.4 EachMSivleakagecontrolsystemsubsystemshallbedemonstrated OPERABLE: a. At least once per 31 days by: 1. Starting the, blower (s) from the control room and operating the blower (s) for at least 15 minutes. 2. Energizing the heaters and verifying a temperature rise indicat-ing heater operation on downstream piping, b.' During each COLD SHUTDOWN, if not performed within the previous 92 days,,by cycling each motor. operated valve through at least 'one complete cycle of fu L r r., c. At least once erigfr ..s by: 1. Performan, a functiona'l test which includes simulated actua-tion of the subsystem throughout its operating sequence, and ~ verifying that each interlock and timer operates as designed, I each automatic vcive actuates to its correct position and the k blower startc. 5 2. Verifying that the blower (s) develops at least the below required vacuum at the rated capacity: a) Inboard valves, 15" H O at 100 scfc. 2 b) Outboard valves, 15" H:0 at 200 scfm. w -g d. By verifying the operating instrumentation to be OPERABLE by performance of a: 1. CHAT lNEL CHECK at least once per 24 hours, 2. CHANNEL FUNCTIONAL TEST at least or.ce per 31 days, and 3. CHANNEL CALIBRATION at least once per 19 months.

O

- --' ~ LIMERICK - UNIT 1 3/4 6-7 g I ~~,s. -m.~..... .~.. ~ * - ~~ -...c... c ~ ~

i... L.a. --- *-- ) L \\ l l CONTAINMENT SYSTEMS m- ^ SURVEILLANCE REOUIREMENT5 (Continued) I By verifying at least two suppression chamber water level indicators c. .and at least 8 suppression pool water temperature indicators in at least B locations, OPERABLE by performance of a: 1. CHANNEL CHECK at least once per 24 hours, CHANNEL FUNCTIONAL' TEST at least once per 31 days, and 2. 3. CHANNEL CALIBRATION at least once par 1S months, with the water level and temperature alarm setpoint for: -~~~~ ~ 1. High water level 5 24'1\\" ~ 's 2. High' water temperature: a) First setpoint 5 c5'F b) Second setpoint 5 105*F, c) Third setpoint 5 110 F Id d) - Fourthsetpa9? < 120 F - erg)$y~..s by conducting a drywell-to-suppression . //. g.2. /, d. At least once 4 m chamber bypas ley ast at an initial differential pressure of J 4 psi and ver'ifying that the A/[i calctriated from the measured . leakage is within the specified limit. If any drywell-to-suppression i chamber bypass leak test fails to meet the specified limit, the test L schedule for subsequent tests shall be reviewed and approved by the j Commission. If two consecutive tests fail to meet the specified limit a test shall be performed at least every months until two nsecu ive tests meet the specified limit, at ch time the tyfinont test schedule may be resumed. Q^ ,Qti . LIMERICK - UNIT 1 3/4 6-14 ... _. \\ ,*.*,?"#t-

?,t* % % )* f
15 * *?

[*

39010C0402 CONTAINMENT. SYSTEMS SURVEILLANCE REQUIREMENTS ~ 4.6.3.1 Each primary containment isolation valve shed in Table 3.6.3-1 shall be demonstrated OPERABLE prior to returning the valve to service after mainte-nance, repair or replacement work is performed on the valve or its associated actuator, control or power circuit by cycling the valve 'through at ltast one - complete cycle of-full travel and verifying the specified isolation time. 4.6.3.2 Each primary containment automatic isolation valve shown in Table 3.6.3-1 shal e demonstrated OPERABLE during COLO SHUTOOWN or REFUEllNG y { at least once pV / months by verifying that on a containment isolation test signal each automatic isolation valve actuates to its isolation position, l l 4.6.3.3 The isolation time of each primary containment power operated or automatic valve shown-in Table 3.6.3-1 shall be determined to be within its limit when tested pursuant to Specifi:ation 4.0.5. n { 4.6.3.4 Each reactor instrumentation line excess flow check w th n in Table 3.6.3-1 shall be demonstrated OPERABLE at least once M mon s by l l ( verifying that the valve checks flow. ) i 4.6.3.5 Each. traversing in-core probe system explosive isolation valve shall f be demonstrated OPERABLE: i l %p M:n. l At least' once per 31 days by verifying the continuity of the explosive hW a. charge. 2f /20 b. At least once erJo-ths by removing th explosive squib from the l'i explosive valve, uch tnat each explosive squib in each explosive I valve will.be -tested at least once pe months, and initiating the l explosive squib. The replacement charge for the. exploded squib shall ( I-be from the same manufactured batch as the one fired or fecm another batch which has been certified by having at least one of that batch successfully fired. No squib shall remain in use beyond the expiration of its shelf-life and/or operating life, as applicable. x l - L o..J l. LIMERICK - UNIT 1 3/4 6-18 l CCI 3 0 U!S Amendment No. 2, M, 33 1

3901000402 CONTAINMEHi SYSTEMS ,.m 3/4.6.R SECONDARY CONTAINHENT REACTOR ENCLOSURE SECONDARY CONTAINMENI INTEGRITY LIMITING CONDITION FOR OPERATION ~ 3.5.5.1.1 REACIOR ENCLOSURE SECONDARY CONTAINMENT INTEGR 2i.ed. APPLICABILITY: - OPERATIONAL CONDITIONS 1, 2, and 3. ACTION: Vithout' REACTOR ENCLOFURE SECONDARY CONTAINMkNI INIEGRITY, rest:re REACICR ENCLOSURE SECONDARY CONTAINMENT INTEGRITY vithin A h:urs er be in a leas: HC-SHUIDOWN within tne next 12 h:urs and in COLD 5NUID0VN witnin :ne felleving 24 -hcurs. SURVEILLANCE REOUIREMENT3 4.6.5.1.1 REACTOR ENCLOSURE SECONDARY-CONTAINMENT INTEGRITY ' strated by: Verifying at least once per 24 heurs that the pressure wi:nin the a. reacter enclosure secencary containment is greater t..an er equal - to 0.2E inch of vacuum water gauge. b. Verifying at least ence per 31 days that: All' react:r enclosure see:ndary c:ntainment e:ui; en: ha::nes at: l. blew ut panels are closed and sealed. 2. /.t least one c:cr in each ac:ess t: the react:r enclosure se :n:ary stainment is closed. ~ 3. All rea:::r enciesure sec:ndary c:ntainment penetratiens n:: ca:able of being closed by OPERAELE secondary c:ntainment aut:- matic isciatien dam ers/ valves and required :-be clesee curing accident'c:nditions are closed by valves, blin: flanges, sli:e . gate da. pers ej-<triif~tlvatec aut:matic campers /valvu mec-i.- i - p:sitlen.

2. f<

At least'enes er ?E ..ths: l'. Verifying Ja; :ne stancby gas treauen subs w l the reae::r enciesUre sec:neary c:ntainmen: :ys;as. iii craw :: c

grtatar : nan :r e:ual t: 0.2E in:n cf vacuu water _ gauge in less tnan er ecuai ::

121 sec:nes viin tre react:r enc 1:sure recir: system in c: era:i:n. and I k 2. 0:erating ene stan :y gas treauent subsystas f:r ene neur ac: N maintaining greater than er e:ual t: 0.25 inen of va:aum-wa:er gauge in the rea ::r enclosure sec:ndary c:n:aineen: -f a: a fi:w ra:n-ne ex:ee:ing 12E0 cf: witn wind speeds cf 1 7.0 m:n as k. measuren en One wind instrument en icwer 1 eleva;ien 30' :, i if tnat instrumen*. is unavaila:ie, icwer 2, eleva:ica lip. t.!MERICx - UNIT 1 3/4 6-46 Acen:~ent ha 8 G C is m-

-CONTAENHENT SYSTEMS 3901000402 ~ 3/4.6.5 SECONDARY CCHTAINMENT' - REFUELING AREA SECONDARY CONTAINMENT-INTEGRITY t!NITING CONDITION FOR CPEUTICN-

3. 5. 5.1. 2 RE JE'.!NG AREA SECONOARY CCNTAINMENT INT A?:L!CAE!L!"Y: ' 09:iATIONA!. CONDITICN ".

.ec. ACTION: Without-REFUELING AREA SECONDARY CONTAINMENT INTEGR with a potential fer draining tne reactor vessel.irraciated fuel i , suscen: handling cf anc c:e ati: s E tien 3.0.3 are not a::licable. Tne provisiens cf 5:ecifica-SURVEILLANCE RE0VIREMENT5 4.6.5.1.2 - REFUELING AREA SECONDARY CONTAINMEN by: em:nstrated Verifying at least coce per~24 ' hours that the pressure within the ~ a. refueling area secondary containment is greater than er ecual t: ' 0.25 inch of vacuum water gauge, b. Verifying at least cnce per 31 days that: 1. bicwcut panels ~are closed and sealed.All refueling area f,. 2. L ~ At lea.st cne door in each access te the refueline area se centainment is-closed. 3. All refueling area secondary centainment penetratiens cc ca:able of being closed by OPERA 3LE secencary c:ntaitment aute:atic is:- lation campers / valves and required t: be closed during accicen: conditions are closed b damcers er deacrifaTe' y valves, blind flanges, slide gate pe s'i tien. g aut:matic cameers/ valves securec in c, At leasTenca p r-H ..:ns: Ocerating one stancty gas trea ment su: system for One ncur anc main-1 4 taining greater inan or eccal :: 0.25 ixn cf vacuum water gauge in tne refueling area sec:ncary c:ntainment.a: a ficw rate n:: [ 764 cfm. exceecin; =Recuirec wn'en (1) f r aciated fuel is being hancied-in the refueling area sec:ncary c:n.ainment. witn a octancial fer craining :ne reac :r vessel, wi:n :ne vessel heac } L anc fuel in :ne vessel. t I LIgggICx_- UNIT 1 3/4 6.a7 I Amencment he 29 .I i .,, Jh 2 2131

~ -

l

3901000402 CONTAINMENT SYSTEMS - REACTOR ENCLO5URE SECONDARY CONTAINMENT AUTOMATIC I5OLATION VALVE 5 LIMITING CONDITION FOR OPERATION 3.5.5.2.1 The reector enclosure secondary containment ventilation system aut - matic isolation valves shewn in Table 3. 5. 5.- 2.1-1 shall be OPERAELE with isolati:n times less than or ecual to the times shown in Table 3.6.5.2.1-1, 2 APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3. ACTION: With one or more of the reactor secondary containment ventilation system automatic isolation valves shown in Table 3.5.5.2.1-1 ineperable, maintain at least one isolation valve OPERABLE in each af fectec penetration that is open and 'within S hours either: -~ a. Restore the inoperable valves to OPERAELE status, or b. Isolate each affected penetration by use of at least one deactivated valve secured in the isolation ~ position, or c. Isolate each affected penetration by use of at least one closed manual valve, blind flange or slide gate damper., Otherwise, in OPERATIONAL CONDITION 1, 2 or 3, be in at least HOT SHUTOOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hcurs. SURVEILLANCE RE0VIREMENT5 4.5.5.'2.1 Each reactor inclcsure secondary containment ventilation system automatic isolation valve shown in Table 3.5.5.2.1-1 shall be demonstrated 0?ERABLE: Prior to returning the valve to service af:er maintenance, repair er a. replacement work is performed en the valve or its associa:sd a:: vater, control or pewer circui: by cycling the valve thr: ugh at leas: ene conclete. cycle f full travel and verifvin: the saecified is:la:ica - w-s - $1m,. ~<3 b. At-least cnce rer ec. hs by verifying tha: en a containmen; isolatien tes s+casi'esch is:laticn valve actuates to its istiati n ~ position. ^ c. By verifying the is:iaticn time to be within i:a limit a isas en: per 92 days. LIMERICK - UNIT 1 3/4 6-18

, 3 0.313 Acencmen: No. 23, 23 i

( o . _ -. - ~ _. _ _ _. _ _.. _ _ _ - - - - _ _ - - _ _ _. _ _ _ _ - -. _ _ _ _ - -. 'I

3901038720 tCONTAINMENT SYSTEM 5- ~ f+, REFUELING AREA SECONDARY CONTAINMENT AUTOMATIC ISOLATION VALVE 5 v . LIMITING CONDITION FOR OPERATION - 3.6.5.2.2 + The refueling area secondary containment ventilatio6 system automatic isolation valves _ shown in Table 3.6.5.2.2-1 shall be OPERABLE with isolatien times less _than or equal to the times shown in Table 3.6.5.2.2-1. APPLICAEILITY: OPERATIONAL CONDITION *. ACTION: With one or more of the refueling area secondary containment ventilation system-automatic isolation valves shown in Table 3. 6. 5. 2. 2-1 inoperable, maintain at least one isolation valve OPERABLE in each affected penetration that is open and within 8 hours either: _a. Restore the inoperable valves to OPERAELE status, or b. ,: Iso. late each affected penetration by use of at least one deactivated ' valve secured in the isolation position, er ~ c. Isolate each affected penetration by use of at least one closed manual valve, blind flance or slide gate damper. Otherwise, in OPERATIONAL CONDITION *, su, spend handling of irradiated l fuel in the refueling area secondary containment, CORE ALTERATIONS and operations with a potential for draining the reactor vessel. The previsiens of Specification 3.0.3 are not applicable. SURVEILLANCE REOUIREMENTS 4.6.5.2.2 Each refuelino area secondary contain'.ent ventilation system aut - u u. mat.ic isola.ti.cn. valve :Sh5wn in Table 3.6.5.2.2-1 shall be demonstrated OPERAELE: -Prior to returninc the vaive to service af7.cr maintenance, repair er L a. ' replacement w:rk is performed en the valve er its ass::iated ac.ua.:r, control er power cir:uit by cy:iing the valve thr ugh at least ene complete cvcie of fuMavei and verifvine the specified iscla-ica N ~ ~ = tim 7 ~ b. At least ence er ?EY nths by 9 >rifying ina en a c:ntainment ( isolatica test... i each isolatica valve actuates t: its isolati n positien. hM .By verifying the isciation time to be within its limit at least cnce c. per'92 cays. -* Required when (1) irradiated fuel is being handled in the refueiing area -~ .- onc:ndary containment, er (2) during IORE ALTE?ATIONS, cr (3) during cpera-l' tions with a-potential for draining the reacter vessel with the vessel hee: removed and fuel in the vessel. LIMERICK - UNIT 1 3/4 6-50 Amendment No. E, g l MY30im

3901038720 CONTAINMENT $YSTEMS ..s - f. ' ~. _30MILLANCE P.50l'IREM5NTS (Cer. iM) _ _s c,_ r -g, y lim,.fdi'b. At least once p r 9.. r..ths er (1) after any structural maintenance h on the H5?A filt=. or charcoal adsorber housings, or (2) followin: I p.ainting, fire, er chemical release in any ventilatien zene 1l i communicating with the subsystem by: ( 1. Verifying that the subsystem satisfies the in place penetratien and bypass leakage testing acceptance criteria of less than 0.05% ) and uses the test procedure guidance in Regulatory P sitions C.5.a,If C.5.c and C.5.d of Regulatory Guide 1.52, Revisica 2, Mar:n 1975, .( and the system flow rate is 3000 cfm : 10%. 2. Verifying within 31 days a'f ter removal that a laboratory analysis of a representative carbon sample obtained in accordance with Re;ulatory Pesition C.6.b et Regulatery Guide 1.52, Revisien 2, .P. arch.1575, meets the laboratory testing criteria of Regula. cry Position C.E.a of Regulatory Guide 1.52, Revisien 2, March 1575, for a methyl iodide penetration of less than 0.175%; and 3. . Verify that when the fen is. running the subsystem fievrate is 2500 cfm minimum from each reacter enclosure (Zonas I and II) and 2200 cfm minimum frem the refueling area (Zone III) when tested in at::rdance with ANSI H510-1950. 4& p 4. Verify tha tne pressure dreo a:ross the refueling area :: 5Gti C.. prefilter is less.tnan 0.25 inches water gage while cperating at a ficw rate of 2400 cfm : 10%. y c. After every 720 h urs of charcoal adsorber operatien by verifyinc within 31 days after removal that a lacoratory analysis cf a repre- ,sentative carbon sampie cctained in accordance with Regulatcry Positien C.S.b of Regulatory Guide 1.52, Revision 2, March 1575, meets the labera.ory testing criteria of Regulatory P sition C.E.a of Reculatcry Guice 1.52, Revisien 2, March 1578, fer a metnyi icdice penetratien 0IAr9 t_han 0.175%. w i d. At least ence r P..ths by: 1. Verifyinc tha..ne pressure cr:p acrcss the c:mbir.ed H5?A filters and char::ai adscrber banks is less than 5.1 in:nes vater gauge while c: era-ing ne filter rain a; a fi:w ra'e :f .m 0 n,v0 C!m : 34. m ~ ( Y h... ...,.AW EXa Mihl 9M!WMC a IMUVAL 'S W MG. '(sJWd. /h?@dtl3 R15.YE&iGnu~.Ga<ot 1.R, Econ.<a 2, Ahm t ip.. ' LIMERICK - UNIT } 3/4 5-53 Amen cen~ H t;>23 GCi 10 i:.::.

3901038720

CONTAINMENT SYSTEMS l SURVEILLANCE RE0VIREMENTS (Continued)

~ x 4',L E A d. ~ n x 2 Verifying.that the fan starts and isolation valves necessary to draw a suction from the refueling area or the reactor enclosure .. recirculation discharge open on each of the-following test signalsi i a) Manual initiation from the control room, and i I b) . Simulated automatic initiation signal. 3. Verifying that the temperature differential across each heater [ is > 15 F when tested in accordance with ANSI N510-1980. _j' Af ter each complete or_ partial replacement of a HEPA filter bank by e. verifying that the HEPA filter Dank satisfies the inplace penetration and leckage testing acceptance criteria of less than 0.05% in accordance with ANSI N510-1980 while operating the system at a flow ~ rate of 3000 cfm 10%. - f. Af ter each complete or partial replacement of a charcoal.adsorber bank by verifying that the charcoal adsorber bank satisfies the inplace penetrat_ ion and leakage testing acceptance criteria-of less' than 0.05% in accordance with ANSI N510-1980 for a halogenated hydrocarbon refrigerant test cas while operating the system at a flow rate of .3000 cfm 104. Jg g. Af ter any' major system alteration: f 1. Verify that when the.SGTS fan is running the subsystem flowrate is 2800 cfm minimum from each reactor enclosure (Zones I and II) and 2200 cfm minimum from the refueling area (Zene III). 2. Verify that one standby gas treatment subsystem will drawdown reactor enclosure Zone I secondary containment to greater than or equal to 0.25 inch of vacuum water gauge in less than or equal to 121 seconds with the reactor enclosure recirculation system in operation and the adjacent reactor enclosure and refueling. area zones are in their isolation Ndes. r 'v LIMERICK - U'UIT 1 3/4 6-54 Amendment No. 40 [ HM 3 0 MM

~ ^ 3894011970 4 N f CONTAINHENT SYSTEMS ~ P.EACTOR ENCLO5URE RECIPfULATION SYSTEM LIMITING CONDITION FOR OPERATION 3.6.5.4 Two ir. depend.ent reactor evloscre recireviation subsystems shall be OPERAELE. APPLICAEILITY: OPERATIONAL CONDITIONS 1, 2, a.1: 3. ACTION: a. With one reacter enclosure recirculation subsystem inoperabie, rest:re the inoperable subsystem to 0?ERAELE status within 7 days,- cr be in at least HOT SHUT 00WN within the next 12 hours and in COLD 5HUTDOvh within the following 24 hours. b. With both reacter enclosure re:irculatien st.bsystems inoperable, be in at least HOT SHUTOOWN vithin tne next 12 hours and in-COLO SHUTDOWN within the following 24 h urs. ,5URVEILLANCE REOUIREMENTS 4.6.5.4 Each rea: tor en:1csure recir:ulatien subsystem shall be demonstrate: OPERAELE: a. At least c'nce per 31 days by initiating, frem the control room, f;cw throuch the HEPA filters and char: cal adsorbers ar.d verifying that the subsystem cperatee L-5e7TT.) '2fD b. At least once p Mimo or (1) after any structural maintenan:e on tne HE?A filte. ir charcoal adsorter housings, or-(2) following painting, fire, or chemical release in any ventilation :ene communi-cating with the subsystem by: i 1. Verif. ing that the subsys.em satisfies the in place penetra:i:n and bypass leakage testing at:eptance criteria of less tnan.C:.C5% and uses the test precedure guidance in kegulatory Positions C.5.a. C.S.c, and C.E.d of Regulatory Guice 1.52, Revision 2, Maren 1975, and the system flow rate is 50,000 cfm : 10%. 2. Verifying Hthin 31 days after removal that a laboratory analysis of a representative carcen samole cotained in ac::rcan:e with Regulatory Position C.E.b of Regulatory Guide 1.52, Revisica 2 March 1973, meets the laceratory testing criteria of Regulat y Position. C.E.a of Regulatery Guice 1.52, Revision 2, Mar:h 1973 for a methyl iodide penetratica cf less tnan 1%; and 3. Verifying a su: system flow rate of 60,000 cfm : IC" curing system coeration wnen tes.t.ed in a:: rcance with ANSI NE10-19EO. .,g...,.,_.... YAANWlYN .?? hhYhh ? LMyhxca n s h.ht!/.S h $rvasm] 2 A vit.7 ]' ~ LIHERICX - UNIT 1 V 3/4 6-65 ' M5 5 E..

3.... 389401i970 CON [AINMENTSYSTEMS .a. 5URVEILLANCE REOUIREMENTS (Continued _ Af ter every' 720. hours of charcoal acsorber operatinn by verifying c. within 51 days af ter removal that a laboratory antlysis of a repre-sentative carbon sample obtained in accordance with Regulatory Position C.E.b of Regulatory Guide 1.52, Revision 2, Mar:h 1975, meets the laboratory testing criteria cf Regulatory Position C.E.a of Regulatory Guide 1.52, Revision 2, March 1978, for a cethyl iodide penetration c5-4gs than 1%. Ys-d. At'least once eri ~nths by: 1.. Verifying that the pressure dr:p across the combinec 'prefi. iter, upstream and downstream HE?A filters, anc charcoal adsorber banks is less than E inches water gauge while operating the filter train at a flow rate of 60,000 cfn 10%, verifying that the prefilter pressure crop is less than 0.8 inch water gauge and _that the pressure crop across each HEPA is less than 2 inches. vater gauge, 2. Ve-ifying that the filter-train starts and the isciation vaives whicn take suction en and return to the reactor encicsure cpen on each cf the following test signals: 7 a. Manual-initiatica frem the control rocm, and b. . Simulated au::matic initiation signal. I After each completa or partial replacement of a HEPA filter bank by e. verifying that_the HE?A filter bank satisfies the-inplace penetra-i:n and. leakage testin; a::eptance criteria of less -than 0.05% in accordance with ANSI H510-1950 while perating the system at a flow rate of 60,000 cfm 10%. ~ - f. After ea:h ccm lete er partial re:la:enent cf a cnar: cal ads: :e-bank by verifying that.na cher::ai a:scr:er bank satisfies tne inpiace penetration and les.kage testing a::eptance criteria cf less than 0.05% in a::ordance with ANSI H510-1990 for a halegena:ec hy:r - carbon refrigerant test gas while cperating the system at a ficw rate of 50,000~ cfm 1C%. l-L 1 l.IMERIC/, UNIT 1 3/4 E-56 Amiin: men N:. u L i i

L 3892300520 ( CONTAINMENT SYSTEMS 3/4.6.6 PRIMARY CONTAINMENT ATMOSPHERE CONTROL PRIMARY CONTAINMENT HYDROGEN RECOMBINER SYSTEMS LIMITING CONDITION FOR OPERATION 3.6.6.1 Two independent primary containment hydrogen recembiner syst:, shall be OPERABLE. APPLICABILITY: OPERATIONA( CONDITIONS 1 and 2. ACTION: With one primary containment hydrogen recombiner system inoperable, restore the inoperable system to OEERAELE status within 30 days or be in.at least HOT SHUTOOWN within the next 12 hours. 'uEILLANCE REOUIREMENIS 4.;.s.1 Each primary containment hydrocen recombiner system sh:11 be cemon- ~ strated OPERABLE: ~ a. At least once per 6 months by performance of: 1. . A CHANNEL CHECK cf all Control Room Reccmbiner InstrutEntation. 2. A Trickle Heat Circuit chsck. 'f?; 3. A Heater Ceil Check. Ac,. 4. A verification of vaive cperatien by stroking Eli the valves ' ~ ~ to thsir crevWtier.s. '2$ b. At least once ar 36f'..shs by: r 1. Performin; a CHANNEL CALIERATION of ali controi rocm re:cmbiner ~ instrumentatien anc cor. trol circuits. 2. Verifying the inte;rity of all heater electrical c1hcuits by perform-ing a resistance to gr;und test within 30 minutes foileving ths teicw ( requirec functicr.ai test. Ths resistance to ground f:r any heitar j phase shall bs greater inan er equal te one(1) meccha 1l I 2. Verifying threugh a visual examination that there is nc eviden:E :f abnormal c:nditiens within the recombiner enclosure; i.e., le:ss viring or structurai connecticas,.. deposits cf foreign materials, at:. 4. Verifying during a recemoiner system functienal test -hat the minimum heater outlet gas temperature increases to greater than er ecuai : / 1150*.: within 120 minutss and maintained for at least one hour w S.v measuring tne sys M _ge rats: c. 1. As a part of the overail integrated leakage rate test required by Specificaticn 3.5.1 ', er 2. Ey measuring the isaka;s rate of the sy-t, cc: side cf tne c:ntai-- ment iioIaticn Valves a~. P.,11.0 -., en :ne scneduie recuira: :y c 5;ecification 2.6.1.2, snc incluC.ng the measured leakage as a : art cf the leikags cs:erminec in a:::rdance wita specificatien d.E.'_.I. -s-I 1 l LIMERICK - UNIT 1 3/4 E-57 '

I ' UU Amencment No.;g

4 3901038720 PLANT SYSTEM 5 .( .LIKliING CONDITION FOR-OPERATION-(Cont nued) i q l, ACTION:- (Continued)

4. " With three ESW pump / diesel generator pairs ** inoperable, restore at lear, one inoperable E5W pump / diesel generator pair ** to OPERABLE status within 72 hcurs, or. be in at least HOT SHUT 00WN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours.

5. With four E5V pump / diesel generator pairs ** inoperable, restore at least one inoperabia ESW pump / diesel generator pair *" to OPiRABLE states within 8 hours, or be in at least HOT SHUTOOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. b. . In OPERATIONAL CONDITION 4 or E: 1. With only one. emergency service water pump an'd its associated iflovpath OPERABLE, restore at least two pumps with at least ena ' ~ flow path to OPERAELE status within 72 ' hours or declare the ~~ associated safety related equipment inoperable and take the ACTION required by Specifications 3.5.2 and 3.8.1.2. ci - In OPERATIONAL CONDITION" C., 1. With only one emergency service water pump and its associated 'O flow path OPERAELE, restore at least two pumps with at leart one flow path to 0?ERAELE status within 72 hours or verify adequate cooling remains available for the diesel generators required to be 0?ERAELE or-declare the associated diesel generator (s) inoperable and take the ACTION recuired by Soecification 3.E.1.2. The provisions of Specification 3.0.3 a're not applicable. SURVEILLANCE REOUIREMENTS ~

4. 7.1. 2 At 1. east the above recuired emergency service water system loop (s) shall be demonstrated OPERAELE:

At least once per 31 days'by verifying that each valve (manual, power-a. operated, or automatic) that is net locked, sealed, or otherwise secured in oosition. iN O - xtr'+- -24 # b. At least once per M me .s by verifying that: 1. Each automatic valve actuates to its correct position en hs j appropriate E5W pump start signai. 2.. Each. pump.stants automatkAally.when its associated ciesel generator starts. M. 5.When handling irradiated fuel in the secondary containment. 25An:E5W pump / diesel generator Tair consists f an E5W pump and its associated diesel generator. If either an E5W pump er its associated diesei generator beccmes inoperable, nen the E5W pe=p/diesei generator pair is inoper'abl e. LIMERICK - UNIT 1 3/4 7-4 Amendment No. E:, 40 l HM 3 0 HH

3901038720 ~ ~ PLANT SYST_ EMS 3/4.7.2 CONTROL ROOM EMERGENCY FRE5N AIR SUP?tY SYSTEM - COMMON SYSTEM 11MITING CONDITION FOR OPERATION 3.7.2

Two iridependent cor.c 01 room emergency fresh air supply system subsys[ ems i

shall be OPERAELE. APPLICABILITY: All OPERATIONAL CONDITIONS and *. ACTION: In OPERATIONAL CONDITION 1, 2, or 3 with or>e control Tecm 'emercency a. fresh air supply subsystem inoperable, restore the inoperable subsys. m to OPERAELE status withS 7 days or be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTOOWN within tha fc11owing 24 hours. b. In OPERATIONAL CONDITION 4, 5, or *: ~ 2c With one control room emergency fresh air supply subsystem inoperable, restore the inoperable subsystem to OPERABLE status . within 7 days or initiate and maintain operation of the OPERAELE subsystem in the radiation isolation mode of operation. 2. With both control room emergency fresh air supply subsystems inoperable, suspend CORE ALTERATIONS, handling of irradiated fuel in the secondary containment and operations with a potential fer draining the reactor vessel. The provisions of Specification 3.0.3 are not applicable in c. OPERATIONAL CONDITION ". [ SURVEILLANCE REQUIREMENTS 4.7.2 Each control room emergency f resh air. supply subsystem shall be demonstrated OPERASE: At least once per 12 hours by verifyin; the centrol ream air -tempera-a. ' ture to be less than er equal to EE*F effective temperature. b. . At least once per 31 cays on a STAGGERED TEST EASIS by initiating, f r:m the control re m, ficw thr: ugh the HEFA filters and charccal ads:rbers and verifyinc tha W W stem ocerates with the heaters OPERAELE. 24 W r c. At least once erM: m:n cr (1) after any structural maintenance en the HEPA fil -. narcoal adsorber housings, er (2) felicwin; painting, fire, er chemical release in any ventilation zone q communicatinc_with the subsystem by:, 2. Verify.ing.that the subsystem-sat.is1.ies -the.,in place.penetratien and bypass leakage testing ' acceptance criteria of less thah 0.05% and uses the test precedure guidance in Regulatory Fesi-i:. C.5.a, C.5.c, and C.E.d of Regulacery Guide 1.52, Revisjen 2, March 1975, and the syr' am flew rate is 3000 cfm 210%. "Wrnm+ndiated Juel is being handled in the sa:.:ndary men a.inment. ff'Q{.&@uf

wTCAWif InJ.}iiUkg 10 'm GjpfR. fiQpV.&@Q (,,ap}

Amendment No 40 l LIMERICK - UNIT 1 [g'j'/ggip af "(3/4.7-6 44j,gg,f HM 3 01990 w

y etAnT sysTens 3901038720 3URVEILLANCE RE0VIREMENTS (Continued) I 2. Verifying within 31 days af ter removal that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C 6 b of Regulatory Guide 1.52, Revisien 2, March 1978, meets the laboratory testing criteria of Regulatery Position C.6 a of Regulatory Guide 1.52, Revision 2, March 1975, for a methyl iodide penetration of less than 1%; and 3. Verifying a subsystem flow rate of 3000 cfm + 10% during subsystem operation when tested an accordance.with ANSI H510-1980, d. Af ter every 720 hours of charcoal adsorber operation by verifying within 31 days af ter removal that a laboratory analysis of a repre-sentative carben sample obtained in accordance with Regula*ery Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1973, - meets the laboratory testing criteria cf Regulatory Pesition C.E.a of Regulatory Guide 1.52 Revision 2, March 1978, for a methyl iodide penetrati- +dh 1%. ~ //,62,h. At least once p. @ nt Verifying tiila't"tTie pressure drep across the combined prefilter, 1. upstream and downstream HEPA filters, and charcoal adsorber banks is less than 6 inches water gauge while operating the subsyste5 at a flow rate of 3000 cfm 210%; verifying that the prefilter pressure drop is less than 0.8 inch water gauge and that the pressure drop across each HEFA is less than 2 inches water gau;e. k;ft 2. Verifying that on each of the below chlorine isolation mode actuation test signals, the subsystem automatically switches to the chierine isolation mode cf operation and the isolatien valves close within 5 seconds: a) Outside air intake hich chierine, and b) Manual initiation frca the c:ntrol room. 03. Verifying that en each of tha bei w radiation isolation mece actuatien test signals, the subsystem aut:matically switches the radiation isolation mode of cperation and the control r:ce ;5 maintained at a positive pressure of at least 1/8 inch water gau;e relative to the turbine enciesure and auxiliary ecuitment reem and outside atmosphere during subsystem operation.with an cu.d::r air flew rate less than er equal to 525 cfm: a) Outsice air intake high raciation, and b) Manual initiatien frem c:n:r:i room. L LIMERICK.. UNIT 1 3/4 7-7 Amendment He. 5, G l HM 3 0 D.'0

3895235940 x p .9 PLANT SYSTEMS -SURVEILLANCE RE0VIREMEFTS -(Contir.ued) ..n-- ~s' y,7.f. c. At least onc per ff[IE. ths by: J 1. Performing a system functional test which includes simulated automatic actuat:en and restart and verifying that each automatic valve in the flow path actuates to its correct -position. Actual injection of coolant'into the reacter vessel miy be excludsd. 2. ' Verifying that the system will develop a flow of greatar thaR_.. or equal to 600 gpm in the test flow path when steam is 6[ supplied to the turbine at a pressure of 150 + 15, - O psig.* u 1 [' 3. Verifying that the suction for the RCIC system is automatically -transferred from the condensate storage -tank to the suppressien pool on a condensate storage tank water level.lew signal. s 4. Performing a CHANNEL CALIBRATION cf the RCIC systsa discharge f line " keep filled" level alarm instrumentation. ~ ~ 4i s 9 4 m

3-3 1

l} "The provisions of Specification 4.0.4 are not applicable provided the b surveillance is performed within 12 hours after reactor steam prsssure is adequate to perform the tests. If OPERABILITY is not successfully demonstra:ed within the 12-hour period, reduce reactor steam pressure to less than 150 .- psig within the following 72 hours. 1 i ' LIMERICK - UNIT.1 3/4 7-10 Amendment No. " m2e

= I s k. e ptANT SYSTEMS 3891002560 ? , HALON SYSTEMS' LIMITING CONDITION FOR OPERATION l 3.7.'6.4 The following Halon systems shall be OPERABLE with the storage tanks having at least 95*, of full charge weight and 90*. of full charge pressure: Remote Shutdown Panel Area 540, El 289' (Raised Floor), an,d a. b. Auxiliary Equipment Room 542, El 289' (Raised Floor). APPLICABILITY: Whenever equipment protected by the Halon systems is required to be OPERABLE. 3 ACTION: ~ With one or more of the above required Halon systems inoperable, within a. I, -1 hour establish a continuous fire watch with-backup fire suppressica 2 2 equipment for those areas in which redundant systems or components could be _ damaged; for other areas,- est.iblish an hourly fire watch r . patrol. b. The prosisions of Specification 3.0.3 are not applicable. l SURVEILLANLE REOUIREMENTS ,2 ; I: s _ 4.7.6.4 Each of.the above required Halen systems shall ba demonstrated OPERAELE: At least once per 31 days by verifying that each val've.(manual, power-a. -operated, or automatic) in the flow path is in its correct position. s b. At le st once per 6 months by verifying Halon storage tank weight and pressure. c. At.least once per 18 months by: L 1. Performance of a functional test of the general alarm circuit and associa g d interlock devices, and l W ___ =A 2. Per-fermance-cf a system-fbw-4est--to assure no-bhekage-l %sr once. Pca 24 m m gy -l. ?caramans aG A-s u re m n.oa rs s r rv A s,:va E I f A Su wA6E. ~ l .(. LIMERICK - UNIT 1 3/4 7-25 Amendment No. 11 g?! 'l U!! 4 g a 6

\\, i pus 1 systems 3891002560 f 3/4.7.7 FIRE RATED A55EMBtlE5 .x

e LIMITlHG CONDITION FOR OpERtTION 3.7.7 All fire rated assemblies, including valls, floor / ceilings, cable tray enclosures and other fire barriers, separating safe shutdown fire areas cr separating portions of redundant systems important to safe shutdown within a i

fire area, and all sealing devices in fire rated asse:rioly penetration,s, including fire doors, fire vincews, fire dampers, cable, pipin; and ventilati:. duct penetration seals and ven;ilation seals, snall be OPERAELE. APPLICAEILITY: At all times. ACTION: With one er more of the above required fire rated assemblies and/cr a. sealing devices inoperable, within 1 hour establish a continuous fire watch on at least one side of the affected assembly (s) and/or sealing device (s) or verify the OPERASILITY of fire detectors en at least one side of the inoperabl.e assembly (s) and sealing device (s) and establish an hourly fire watch patrol. b. The provisions of Specification 3.0.-3 are not applicable. SURVEILLANCE REQUIREMENTS ^ 4-m_fvm _ 4.7.7.1 sealina devices shall be verified OPERAELE at least onceEachoftheaboverequire tr }& mentis by perferiing a visual inspection of: Kf],'t The exposed surfaces of each fire rated assembly. a. b. Each fire v'rrf5T, fire amper, and asscciated hareware, i 2. 5 f., c. At l e s.,t 16( cf ..n type cf sealed penetration, excep; internai c:r.c;i. seals. p;arent changes in apcearana or ab

m.

decradatic.s 4 are found, a visual inscection of an accitiona i T *4 eacn tvoe cf 12.5 % sealed cenetratica-straji be made. Inis inspect' r:cass sh' ail ) continue unt' a Aye:ple with no a::;arent changes in appearance l l?.6 7a er abncrmai degv.icn is found. rco Sam:;les shall be selsend siTO thi. each penetratica seal wi-il be insoec.ec at least ence oer JYyea(s. r 16 ~ LIMERICK - UNIT 1 3/i 7-31 500C5; NO 1-ICi T 13 3 l _ _ _ _ _,. _ _ _ _ _ - - - - - - - - - - ~ - - " - '

_. _ -..~. I l C-PLANT SYSTEMS 3/4.7.8 HAIN TURBINE BYPASS SYSTEM L1HITING CON 0lTION'FOR OPEMTION 3.7.8 The t..ain turbine bypass system shall be OPEPABLE as determined by the number of operable main turbine bypass valves being greater than or equal to that specified in the CORE OPEPATING LIMITS REPORT. APPLICABILITY: OPEPATIONAL CCHDITION 1, when THEPyAL POWER is greattr than or equal to 251i~of PATED THETsMtl POWER. ACTION: With the main turbine bypass system inoperable, restore the system to OPEP.ABLE status within 1-hour or take the AC110N required by Specification - - - ~ '3.2.3.c. SURVEILLANCE REQUIREMENTS l l 4.7.8 The main turbine bypass system shall be demonstrated OPERABLE at least once l s per: a. 31 days by cycling each turbine bypass valve through at least one com et.e s g-b. rforming a system funct4 r.a1 t

which includes 2 3 3,.,...

simulate automatic actuation, and by verife 90 thet uch rutomatic valve actuales_t its correct position, and

c. '

/#Mbv da ermining TURBINE BYPASS S'. STEM RESPONSE TIM, y less tnan or equal to the value specified in the CORE OPERATING Llh... u l L r l' l LlHERICK'- bri!T 1 3/4 7-33 Anenchent No. 52 l D C T 2 4 :!?t e q, -4 e ~ c-- a a a

3892373290 ELECTRICAL POWER SYSTEMS SURVEILLANCEitE0VIREMENTS 4.8.1.1.1 Each of the above required independent circuits between the offsite transmission network and the onsite Class 1E distribution system shall be: Determined OPERABLE at least once per 7 days by verifying correct a. b.'eaker allereJLts and indicated power avallability, and g Demonstrated OPERABLE at least once per )(months duringhutdown by b. transferring, manually and automatically, unit power cupply from the normal circuit to the alternate circuit. e 4.8.1.1.2 Each of the above required diesel generators shall be demonstrated OPERABLE: a. In accordance with the frequency specified in Table 4.8.1.1.2-1 on a STAGGERED TEST BASIS by: 1. Verifying the fuel level in the day fuel tank. 2. Verifying the fuel level in the fuel storage tank. 3. Verifying the fuel transfer pump starts and transfers fuel from the storage system to the day fuel tank. 4. Verify that the diesel can start" and gradually accelerate to synchronous speed with generator voltage and frequency at 4285 420 volts and 60 1 1.2 HZ. 5. Verify diesel is synchronized, gradually loaded

to an indicated 2700-2800 KWa* and operates with this load for at least 60 minutes.

6. Verifying the diesel generator is aligned to provide standby power to the associated emergency busses. 7. Verifying the pressure in all diesel generator air start receivers to be greater than or equal to 225 psig.

This tes_t shal.1 be conducted in accordance with the manufacturer's recommendations regarding engine pre-lube and warmup procedures, and as applicable regarding loading and shutdown recommendations.
- This band is meant as guidance to avoid routine overloading of the engine.

Loads in excess of this band for special testing under direct monitoring by the manufacturer or momentary variations due to changing bus loads shall not invalidate the test. i ..n LIMERICK - UNIT 1 3/4 8-3 Amendmenc No. 32 l- - S'EP 2 3 E

L ELECTRICAL POWER SYSTEM 5 SURVEILLAtCE REOUIREHENTS (Continued) b. At least once per 92 days and wi;.hin 7 days af ter a battery discharge with battery terminal voltage below 105 volts or battery overcharge with battery terminal voltage above 150 volts, by verifying that: 1. The parameters in Table 4.8.2.1-1. reet the Category B limits, 2. There is no visible corrosion 'at either terminals or connectors, or the connection resistance of these items is less than 150 x 10 5 ohm, and 3. Thu werega ciertenlyte temperature of each sixth cell is 2,60'F. gjg.,/ At least once p r nthsbyverifyingthatC O1. The cells, cell plates and battery racks show no visual indication of physict.1 damage or abnormal deterioration, The cell-to-cell and terminal connections are clean, tight, free of corrosion and coated with anticorrosion material, 3. The resistance of each cell-to-cell and terminal connection is le'ss than or equal to 150 x 10 5 ohm excluding cable intercell connections, and I?n W 4. Tne battery chargers will supply the currents listed below at a s minimum of 132 volts for at least 8 hours: Charcer Current (Amoeres) iBCA1 300 1BCA2 300 1BCB1 300 IBCB2 300 1BCC 75 wel' 75 d. east once per e ths, during shutdown, by verifying tha g g 7,f

01. The battery capacity is adequate to supply and maintain in OPERABLE status all of the actual emergency loads for the design duty cycle when the battery is subjected to a battery service test, or 2.

The battery capacity is adequate to supply a dummy load of the following profile while m.intaining the battery terminal voltage greater than or equal to 105 volts for the nominal 125-volt batteries and 210 volts for the nominal 125/250-volt batteries: 105 8 1p" LIMERICK UNIT 1 3/4 8-11 g ....3.---.---.-

iLECTRICAL POWEF. SYSTEN3 SUR7EltLANCE P.EOUIREMENTS (Continued) LOAD CYCLE (amps) Division Battery 0-1 Min. 1-239 Min. 239-240 Min. I 1A1-546 168 187 1A2 449 129 147 t 11 181 889 158 321 4 182 823 119 282 'III IC ~ ^193 31 31 IV ID 169 21 21 4 Each 125/250-volt battery is rated at 1500 ampere-hours at an pe--cellat77.gF.8-hour dischar e rate, based on a terminal voltage of 1.75 volts- 'Each 125-volt battery is rated at 250 ampere-hours at an 8-hour i discharge rate, based on a terminal voltage of 1.75 volts per-cell at 77*F. At least once per 60 months' during shutdown by verifying tha't the e. battery capacity is at least 80% of the manufacturer's rating when t . subjected to a performance discharge test. At'this once per.60 month interval, this. performance' discharge test may be performed in lieu of _the battery service t ut Mnneificat ion 4.8.2.1.d). -- p N #'#' j - f. At laast once p r)s _nths during shutdown performance discharge tests of batter opacity shall be given to any battery that shows i signs of degradation or has reached 85% of the service life expected i for the application. Degradation is indicated when the battery capacity drops more than 10% of rated capacity from its average on -previous performance tests, or is below 90% of the manufacturer's rating. l . LIMERICK UNIT 1 3/4 8-12 t l .... 2 -. U

..... c... .i..c.

: :...u

...: :.--.... -...... ;... :- ;..., - ;; ;,T;;.- --- ^ \\ ELECTRICAL POWER SYSTEMS g, l m M0707-OcERATED VALVES THERMAL OVERLOAC PROTECTION IMITING CONDTTION FOR OPERATION 3.8.4.2 The thermal overload protection of all Class IE motor operated valves shall be either: Centinously bypassed for all valves with mainteined position c:ntrol a. switches; or, b. Bypassed only under accident conditions for alt valves with sprin,- return-to-normal control switches. APPLICABILITY: 'Whenever the motor-cperated valve is required to be OPERABLE. ACTION: Wjth the thermal overload protection for one or more of the above required valves not bypassed continuously or only under accident conditions, as applicable, resto.re the' thermal overload bypass within 8 hours or declare the affected valve (s) inoperable and apply the appropriate ACT10if statement (s) for the affected system (s). ,s (W."c SURVEILLANCE REOUIREMENTS 4.8.'4c2.1 The thermal overload protection for the above required va'1ves which are continuously bypassed and temporarily placed in force only when the valve motor.is undergoi,ng periodic or maintenance testing shall be verified to be bypassed following periodic pr maintenance testing during which the thermal overload protection was temp 3 placed in force. 12 g9 N v'4. 8. 4. 2. 2 At least once r M.nths, a CHANNEL FUNCTIONAL TEST of all these valves which are bypassed o y-under accident conditions (valves with spring-return-t0-normal control switches) shall be performed to verify that the thermal overload protection will,be bypassed uncer accident ccnditions. t l-1' - \\ ;.. LIMERICr. - UNIT 1 3/4 E-27 g ~ ~ ~ ~. - ...... c.... v...,. ;.....r - =. ~

M 010.58720 CONTAINHENT SYSTEMS sAsts [ '3/4.6.5 SECONDARY CONTAINMENT Secondary containment is designed to minimize any ground level release c' radioactive material which may result frem an accident. The Reactor En:lesure I i and associated structures provide secondary containment during normal cperaticn when the drywell is sealed and in service. At other times the dry. ell may be open and, when required, secondary containment intecrity is specifiedge Establishing and maintaining a vacuum in the reactor engloy secondary containment with the standby gas treatment system once per(1Goo the surveillance of the doors, hat:hes, dampers and valves, is adequate to ensure jj that there at e no violations of the integrity of the secondary containment. w _ The OPERASIUTr of the rea: tor enclosure re:irculation system and the standby cas treatment systems ensures that sufficient icdine removal capability vill be available in the event of a LOCA er refueling accident (SGi5 caly). The reduction in containment iodine inventory reduces the resulting SITE EOUNDARY radiation doses. associated with containment leakage. The cperation of this system and resultant iodine-removal capacity are censistent with the assumptiens used in the LOCA and refueling accident analyses. Provisions have been made to ontinuousl not in use~ y purge the filter plenues with instrument air when the-filters are to prevent buildup of moisture en the adsorbers and the HEPA f,ilters. Although the safety analyses assumes that the reactor enclosure se :ndary-containment draw down time will take 135 se: ends, these surveillance require- + raents specify a draw down time of 121 se: ends. This 14 se:end differen:e is l,e. due to the diesel generator starting and sequence leading celays which is n:t 1' part of this surveillance requirement. The reactor enclosure secondr ry containment draw down time analyses assumes a starting _ point of 0.25 inch of vacuum water gauge and worst case SGi5 dirty filter flow rate of 2500 cfm. The surveillance requirements satisfv this as'- weption byistarting the'drawdovn from ambient conditions and conne"cting the adjacent reactor enclosure and refueling area to the SGT5 to split the exhaust flow between the three zones and verifying a minimum flow rate of 2E00 cfm ft:m the test zone. This simulates the worst case flew alignment and verifies ate-quate flow is available to drawdown the test zone within the re:uired time. The Technical Spe:ification Surveillance Requirement 4.6.5.3 b.3 is intended to be a multi-2one air balance verification without isolating any test 2:ne, j The SGTS fans are sized for three zones'and therefore, when aligned t sing,;e zone or two zones, will have excess capacity to more cuickiy dra dc[: a the affected zones. Tnere is no maximum flow limit to individual zenes er l pairs of zones and the air balance and drawdown time are verified when all three zones are connecteo to the SGT5. The three zone air balance verification and drawdown test will be cene af ter any major system alteration, which is any modificatien which will have } an effect on the SGT5 flewrate such that the ability of the 5GTS to dravdown "the reactor enclosureJto greater than or equal to 0.25 inch cf vacuum wi'er l " gage in less than or equal to 121 seconds could be affected. l LIMERICK - UNIT 1 E 3/4 6.5 Acencuent No. 6, 40 l HM 3 0 DH 4.. 4v--n nu

3901038/20 ELECTRICAL POWER SYSTEMS Y b ten. wdi be_ per omec\\ PL lent once e.very 2t4 r%ntas. Basts L [ _J A.C. SOURCES.. D.C. 50VECES, and ONSITE POWER DISTRIEUTION SYSTEMS (Continued) "Feriodic Testing of Diesel Generato'r Units Used as Onsite Electric Power Systems at tiuclear Power Plants," Revision 1, August 1977 except for paragraphs C. 2. a(3), C. 2. c(1), C. 2. c(2), C.2. d(3) and C. 2.d(4). The { exceptions to Regulatory Guide 1.108 allow for gradual leading of diesel generators during testing and decreased surveillance test frequencies (in response to Generic Letter 84-15). The surveillance requirements for demonstrating the OPERABILITY of the unit batteries are in accordance with the recommendatiens of Regulatory Guide 1.129 " Maintenance Testing and Replacement of Large Lead Storage Batteries fcr ~ fiuclear Power Plants," February 1978 and IEEE Std 450-1950, "lEEE Fr.ccamended Practice for Maintenance Testing, and Replacement of large Lead Storage Batteries for Generatir.g Ltnions and substations."g Verifying aversge electrolyte temperature above the minimum for which the / battery was sized, total btttery terminal voltage on float charge, cennecticn resistance values and the performance of battery service and discharge tests , ensures the ef fectiveness of the charging system, the ability to handle high discharge rates and compares the battery capacity at that time with the rated ' cepacity. Table 4.8.2.11 specifies the normal limits for each cesignated pilet T cell and each connected cell for electrolyte level, float voltage and specific gravity. The limits for the designtted pilot cells float voltage and specific gravity, greater than 2.13 volts rd 0.015 below the manuf acturer's full cherce specific gravity or a battery charger current that had stabilized at a low ~ value, is characteristic of a charged cell with adequate capacity. The normal limits for each connected cell for float voltage and specific gravity, creater than 2.13 volts and net more than 0.020 below the manuf acturer's full charge specific gravity with an average specific gravity of all the connected cells not more than 0.010 below the manuf acturer's full charge specific gravity, ensures the OPERABILITY and capability of the battery. Operation with a ba;tery cell's parameter outside the normal limit but within the allowable value specified in Table 4.8.2.1-1 is permitted for up t: 7 days. During this 7-day period: (1) the allowable value fer electrolyte level ensures no physical damage to the plates with an adequate electron transfer capability; (2) the allowable value for the average specific gravity of all the cells, not more than 0.020 below the manufacturer's reco= ended f"ull charge specific gravity ensures that the decrease in rating will be less than the safety margin provided in sizing; (3) the allowable value for an individual cell's specific gravity, ensures that an individual cell's specific gravity will not be more than 0.040 below.the manuf acturer's full charge specific gravity and that the overall capability of the battery sill be maintained within an acceptable limit; and (4) the allowable value fer an indivicuai tell's float voltage, greater than 2.07 volts, ensures the battery's capa-bility to perform its design function. LIMERICK - UNIT 1 B 3/4 E-2 Amendment No. O l M4 3 0 !!D

ADMINISTRATIVE CONTROLS PROCEDURES AND PROGRAHS (Continued) 6.8.4 Tne following crograms snall be established, implemented, and mair.tained: a. Primarv Coolant Sources Outside Containment A program to reduce leakage fecm those portions of systems outsice containment that could contain highly radioactive fluids during a serious transient or accident to as low as practical levels. ine systems include the core spray, high pressure ccolant injection. reactor core isolation cooling, residual heat removal, post-acticent sampling system, safeguard piping fill system, control roc drive scrsm cischarge system, and containment air monitor systems. The pregram shall include the following: 1. Preventive maintenance and periodic visual inspection j _ requirements, and / 50 #j P 2. Integrated leak test requirements for each system at refuelirg cad "J # cycle intervals or less. d, v _. b. In-Plant Radiation Monitorinj A program which will ensure the capability to accurately deternine the airborna iodine concentratio: in vital areas under accicent c o nc'i t i on s. This program shall include the following: 1. Training of personnel, 2. Procedures for monitoring, and 3. Provisions for maintenance of sampling and analysis equipment. c. ' Post-accident Samoling l A program wnich will ensure the capability to obtain and analyze reactor coolant, radioactive iodines and particul4tes in plant gaseous efflu-ents, and containment atmosphere samples under accident conditions. The program shall include the following: 1. Training of personnel, 2. Procedures for sampling and analysis, and 3. Provisions for maintenance of sampling and analysis equipment. LIMERICK - UNIT 1 6-14 Amendment No 29 JUL 2 2 :c

I REACTIVITY C0tiTROL SYSTEMS g O t SURVEILLANCE REOUIREMENTS (Continued) 4.1.3.1.4 The scram discharge volume shall be determined OPERABLE'by demonstrating: The scram discharge volume drain and vent valves OPERABLE, when control rods are scram tested from a normal control rod configura-l i To'n of less than or equal to 50% ROD DENSITY at least once per P gyJsiponths, by verifying that the drain,and vent valves: 1. Clost within 30 seconds af ter receipt of a signal for control rods to scram, and

2.. Ocen when the scram signal is reses.

-W b. Proper tevei sensor refponse by performance of a CHANNEL FUNCTIONAL. TEST of the scram discharge volume scram and centrol rid block level instrumentation at least once'per 31 days.' i

't l'cj, 9

4 LIMERICK - UNIT 2 3/4 1-5 Ci 3 C

I REACTIVITY CONTROL SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b. /c least once per 31 days by: 1. Verifying the continrity of the explosive charge. 2. Determining by chemical analysis and calculation

that the available weight of sodium pentaborate is greater than er equal to 5389 lbs; the concentration of sodium pentaborate in solution is less than or equal to 13.8% and within the limits of Figure 3.1.5-1 and; the following equation is satisfied:

C Q x ,y 13% wt. 86 gpm ~ where C = Sodium pentaborate solution (% by weight) Q = Two pump flowrate, as determined per surveillance requirement 4.1.5.c. 3. Verifying that each valve (manual, power-eperated, or autcmatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position. Demonstrating that, when tested pursuant to Specification 4.0.5, the c. minimum flow requirement of 41.2 gpm per pump at a pressure of greater than or equal to 1190 psig is met, m d. 5 A9 1. Initiatino a east one of the standby liquid control system I loops, including an explosive valve, and verifying that a flow i path fro, the purf to the reactor pressure vessel is available ~ by pumping demineralized water into the reactor vessel. The h replacement charge for the explosive valve shall be from the same manufactured batch as the one fired or from another batch which has been certified by having one of that batch success-( fully fired. All injection loops shall be tested in 3 operating cycles. 2.

- Demnnstrating that all heat traced piping is unblocked by pumping from the storage tank to the test tank and then draining and flushing the piping with demineralized water.

k 3. Demonstrating that the storage tank heaters are OPERABLE by verifying the expected temperature rise of the sodium pentaborate solution in the storage tank af ter the heaters are energized.

This test shall also be performed anytime water or boron is added to the solu-tion or when the solution temperature drops below 70"F.
- This test shall also be performed whenever all three heat tracing circuits have been found to be inoperable and may be performed by any series of sequential, overlapping or total flow path steps such thtt the entire flow path is included.

LIMERICK , UNIT 2 3/4 1-20 AUS 2 51989

3/4~3 INSTRUMENTATION 3/4.3.1 REACTOR PROTECTION SYSTEM INSTRUMENTATION _ LIMITING CONDITIOR FOR OPERATION 3.3.1 As a minimum, the reactor protection system instrumentation' channels shown in Table 3.3.1-1 shall be.0PERABLE with the REACTOR PROTECTION SYSTEM RESPONS TIME as shown in Table 3.3.1-2. APPLICABILITY: As shown in Table 3.3.1-1. ACTION: With the number of OPERABLE channels less than required by the Minimum a. OPERABLE Channels par Trip System requirement for one trip system, place the inoperable channel (s) and/or that trip system in the tripped condition

Within 12 hours. The provisions of Specification 3.0.4 are j

not applicable. b. With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement for both trip systems. /- place at least one trip system ** in the tripped condition within 1 hour and take the ACTION required by Table. 3.1-1. SURVEILLANCE RE0VIREMENTS A 4.3.1.1 Each reactor protection system instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECX, CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION operations for the OPERATIONAL CONDITIONS and at the .f requencies shown in Table 4.3.1.1-1. 4.3.1.2 LOGIC SYSTEM FUNCTIONAL TESTS and sip?atsqutomatic operation of all channels shall be performed at least once p ,1 lrgon hs. 4.3.1.3 The REACTOR PROTECTION SYSTEM RESPOL t TIME of each reactor trip .' functional. unit.shown..in Table 3.3.1-2 shall be demonstrated to be within its _'l~ l 111mitatleast~once" pef $rmonths. Each test shall include at least one cha 64 ' k[- 2% per trip, system such that all channels are tested at least once every N ti JJ months.where N is the total number of redundant channels in a specific rea trip system. ._ M -

An inoperable channel need not be placed in the tripped condition where this would cause the Trip Function to occur.

In these cases, the inoperable cnannel shall be restored to OPERABLE status within 6 hours or the ACTION required by l -Table 3.3.1-1 f or that Trip Function shall be taken. "The trip system need not be placed in the tripped condition if this would l Lcause the Trip Functicn to occur. When a trip system can be placed in the tripped condition without causing the Trip Function to occur, place the trip system with the most' inoperable channels in the tripped condition; if both systems have the same number of inoperable channels, place either trip system l in the tripped condition. LIMERICK - UNIT 2 3/4 3-1 Amendment No. 17 l rg 3 3 it

e .h TABLE 4.3.1.1-1 (Continued) e-Q. f' REACTOR PROTECTION SYSTEH INSTRUMENTATION SURVEILLANCE REQUIREMENTS d

oj CilANNEL OPERATIONAL h

CHANNEL FUNCTIONAL CllANNEL CONDITIONS FOR WilICil FUNCTIONAL' UNIT CilECK TEST CALIBRATION SURVEILLANCE REQUIRED b E lqi U 9. Turbine Stop Valve - Closure N.A. Q R 1 9 I'

10. Turbine Control Valve Fast 9

Closure Trip 011

i Pressure - Low N.A.

Q P, 1 \\$ / hl.-ReactorModeSwitch f Shutdown Position N.A. R ,H. A. ' 1,2,3,4,5 -12. Manual Scram H.A. W N.A. 1,2,3,4,5 l; e (a) Neutron' detectors may be excluded from CilANNEL CALIBRATION. (b) The IRH and SRM channels shall be determined to overlap for at least 1/2 decades during each startup after entering OPERATIONAL CONDITION 2 and the IRM and APRM channels shall be determined to overlap for a least 1/2 p u D decades during each controlled shutdown, if not performed within the previous 7 days. (c) Within 24 hours prior to startup, if not performed within the previous 7 days. 1! u S (d) This calibration shall consist of the adjustment of the APRM channel to conform to the power values calculated by f-a heat balance during OPERATIONAL CONDITION 1 when THERMAL POWER > 25% of RATED TilERMAL POWER. Adjust the APRM channel if the absolute difference is grerter than 2% of RATED THERMAL POWER. Any APRM channel gain adjustment made in compliance with Specification 3.1 ' shall not be included in determining the absolute difference. j (e) This calibration shall consist of the adje tment of the APRM flow biased channel to conform to a calibrated flow signal. l' (f) The LPRHs shall be calibrated at least once per 1000 effective full power hours (EFPH) using the TIP system. (g) Verify measured core flow (total core flow) to be greater than or equal to established core flow at the existing a 2;- loop flow (APRM % flow). During the startup test program, data shall be recorded for the parameters listed to is provide a basis for establishing the specified relationships. Comparisons of the actual data in accordance with h E the criteria listed shall comence upon the conclusion of the startup test program, j: 8 (h) This function is not required to be OPERABLE when the reactor pressure vessel head is removed per Specification 5 3.10.1. ' m :=: (1) With any control rod withdrawn. Not applicable to control rods removed per Specification 3.9.10;,1 or 3.9.10.2. iE P (j) If the RPS shorting links are required to be removed per Specification 3.9.2, they may be reinstalled for up to 2 'Oy hours for required surveillance. During this time, CORE ALTERATIONS shall be suspended, and no control rod shall be moved from its existing position. j, ~ 1 5" (k) Required to be OPERABLE only prior to and during shutdown margin demonstrations as performed per Specification 3.10.3. A n if 4

? h INSTRUMENTAT!0N t L L LIMITING CONDIT10H FOR OPERATION (Continued) ACTION: (Continued) c. With the aumber of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement for both trip systems, place at least one t-rip system ** in the tripped condition within 1 hour L >nd take the ACTION required by Table 3.3.2-1. SURVE'.LA""I REQUIREMENTS 4.3.2.1 Each isolation actuation instrumentation channei shall be demonstrated i OPERABLE by t' > performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST, and CHANHEL Ct ' L., *.ON operations for the OPERATIONAL CONDITIONS and at the frequencies shown in Table 4.3.2.1.-l. ~ '4.3.2.2 LOGIC SYSTEM FUNCTIONAL TESTS and s me11tey automatic operation of all channels shall be performed at least once p rf)a" months. '?_ t I The ISOLATION SYSTEM RESPONSE TIME of each isolation trip function showz.-i J { '4.3.2.3 4 in Table 3.3.2-3 shall be demonstrated to be within its limit at least once .rK4 < i all channels are tested at letst once every H timje $cer trip system s months. Each test.shall include at least one channyl [ months, where H is the y total number. of redund qt channels in a specific isolation trip system. 1 i ~ 1 i " The trip system need not be placed in the tripped conditien if tnis would cause the Trip Function to occur. When a trip system can be placed in the tripped condition without causing the Trip Function to occur, place the tri;: system with the most inoperable channels.in the tripped condition; if both I systems have the same number of inoperable cnannels, place ei-her trip system in the tripped condition. i 1 ' LIMERICK - UNIT 2 '3/4 3-10 Amendmeat No.17 Ei:!7!HI l x

1. ~ ?me

3 N""

TABLE 4.3.2.1-1 d*' ISOLATION ACTUATION INSTRUMENTATION SURVr1LLANCE REQUIREMENTS CllANNEL OPERATIONAL CilANNEL TUNCTIONAL' CilANNEL CONDITIONS FOR WillCll N . TRIP FUNCTION CilECK TEST CALIBRA110N SURVEILLANCE REQUIREl. e g5 1. MAIN STEAM LINE ISOLATION I# a. Reactor Vessel Water Level l 1) Low, Low, level 2 S Q R 1, 2, 3 2) Low, Low, Low - Level 1 5 Q R 1, 2, 3 b. MainSteapgyne Radiation liigh 5 Q R 1,2,3 ~ c. Main Steam Line Pressure - Low S H R 1 d. Hain Steam Line flow - liigh S H R 1, 2, 3 c. Condenser Vacuum - Low S H R 1, 2'*, 3'* 7 ti f. Outboard MSIV' Room Temperature - liigh S H R I, 2, 3 Turbine Enclosure - Main Steam g. l Line Tunnel Temperature - Illgh S H R I, 2, 3 anual Initiation N.A. R 1, 2, g COOLING MODE ISOLATIO D ^ k 2. RilR Sy III a. " Reactor Vessel Water Level 3% 1 Low - Level 3 5 Q R .I. 2, 3 z ~-=.o S Q R 1, 2, 3 is C b '. ReactorVessel(RllRgt-In ' Permissive) Pressure - liigh ~ N.A. R H.A. 1, 2, 3 I . Manual Initiation c. l ~ l

TADLE 4.3.2.1-1 (Continued) { 'g ISOL'. TION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS .r 9 y CilANNEL OPERAT10NAL II ~ b CilANNEL FUNCTIONAL CilANNEl. CONDITIONS EOR Wit!Cil TRIP FUNCTION I. CllECK TEST CALIBRATION _ SURVEILLANCE REQUIREI E 3. REACTOR WATER CLEANUP SYSTEM IS01ATION d e u a. RWCS A' Flow - liigh S H R 1, 2. 3 3 b. RWCS Area Temperature '- liigh S H R 1, 2, 3 j c. RWCS Area Ventilation ]i A Temp:cature - liigh S H - R 1, 2, 3 SLCS Initiation N.A. R N.A. e. Reactor Vessel Water Level l, Low, Low, - Level 2 S Q-R 1, 2, 3 ~l Har.ual Initiation N.A. R h.A. 1, 2 j .1 t' 4. It!Gli PRESSURE COOLANT INJECTION SYSTEM ISOLATION 1 Y a. IIPCI Steam Line J M A Pressure - liigh - S H R 1, 2, 3 i b. IIPCI Steam Supply Pressure - Low 5 H R 1, 2, 3 c. IIPCI Turbine Exhaust Diaphragm Ip Pressure - liigh 5 H R 1, 2, 3 E d. IIPCI Equipment Room ^ 2. Temperature '- liigh S H R 1, 2, 3 5

x:

e. IIPCI Equipment Room e~ A Temperature - liigh 5 H R

1, 2, 3 g

-i t f. IIPCI Pipe Routing Area g Temperature - Illgh 5 H R 1, 2, 3 S o O [g.

s Hanual Initiation N.A.

R N.A. 1, 2, 3 h. IIPCI Steam Line i S A Pressure Timer N.A. H R 2, 3 lj

f.: "}_ q. TABLE 4 3.2.1-1 (Contintrad) n Et M. ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS 1 . is

1

. Q CilANNEL OPERATIONAL CilANNEL FUNCTIONAL CllANNEL CONDITIONS FOR WillCll TRIP FUNCTION CliECK. TEST CALIBRATION . SURVEILLANCE REQUIRED 1. c.

~

5. REACTOR CORE ISOLATION COOLING SYSTEM ISOLATION 3 m a. RCIC Steam Line 2 A Pressure - liigh 5- 'M R

1. 2, 3 E<

.i ~

b.. RCIC Steam Supply j

Pressure -' Low 5 H R 1,2,3 c. RCIC Turbine Exhaust Otaphragm Pressure - liigh

S.

H R 1,2,3 R d. RCIC Equipment Room i Y Temperature - liigh 5 H R 1,2,3 1 - g e. RCIC Equipment Room A Temperature liigh S' H R 1, 2, 3 f. RCIC Pipe Routing Area Temperature - liigh 5 H R 1, 2, 3 g. Manual Initiation N.A. R N.A. 1, 2, 3 h. RCIC Steam Line R 1,2,3 ~ A Pressure Timer M.A. H 1 a O@ 1 A A I g p

TABLE 4.3.2.1-1 (Continued) F r* ISOLf. TION ACTUATION IHSTRUME!!TATION SURVEILLANCC s'EQUIREHEHTS 3 i r. E CilANNEL OPERATIONAL n CllANNEL FUNCTIONAL CilANNEL CONDITIONS FOR MIICili CilECK TEST CAllDRATION SURVEILLANCEREQUIRE6 TRIP FUNCTION 3 4 k 6. PRIMARY CONTAIRMENT 1501AT10N , j' li Reactor Vessel Water Level 3 9 .R 1,2,3 3 a.

1) ' Low, low - Level 2 3

q g 1, 2, 3 ti 2) Low, low. Low - Level 1

)

ggg 3 g R 1, 2, 3 g b. Drywell Pressure - liigh S Q R 1, 2, 3 ) Horti. Stack Effluent c. t: Radiation - fligh ) t' d. Deleted ) .* \\ S H R 1,2,3 I' Ecactor Enclosure Ventilation Y e. n Exhaust Duct - Radiation - liigh i 8 1, 2, 3 2 f. Outside Atmosphere to Reactor H.A. H Q ~i Enclosure A Pressure - Low Deleted g. l EI - liigh/ h. Drywell PressurcII 5 Q R 1, 2, 3 l [ Reactor Pressure - Low Primary Containment Instrument

3 H.A.

H Q 1, 2, 3 [ 1. Gas to Drywell A Pressure - Low gg N.A. R H.A. 1 O,E Hanual Initiation =c s O e ' M--

5 ~ i @N) [j TABLE 4.3.2.1-1 (Continued) ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS 34 r* ~ CilANNEL OPERATIONAL h, TRIP FUNCTION ' CllANNEL FUNCTIONAL CllANNEL CONDITIONS FOR Wil!Cil 5: CHECK _ TEST CALIBRATION SURVEILLANCE REQUIRED S 7. SECONDARY CONTAINHENT ISOLATION a. Reactor Vessel Water Levelgg e g Low, low - Level'2 S Q R 1, 2, 3 w b. Drywell Pressure ### - High S Q R 1, 2, 3

c. 1. Refueling Area Unit 1 Ventilation Exhaust Duct Radiation - High-S H

R

2. Refueling Area Unit 2 Ventilation li

. Exhaust Duct Radiation - High 5 H I;

I J

d. Reactor Enclosure Ventilation Exhaust Duct Radiation - liigh S H R 1, 2, 3 i w e. Outside Atmosphere To Reactor j D Enclosure A' Pressure - Low N.A. H Q 1, 2, 3 I w f. Outside Atmosphere To Refueling Area A Pressure - Low H.A. H Q Reactor EncT6sirre Manual Initiation N.A. R N.A. 1, 2, 3 j h. Refueling Area p Hanual Initiation H.A. R N.A. !id ( j E

Required when (1) handling irradiated fuel in the refueling area secondary containment, or (2) during CORE 3

ALTERATIONS, or (3) during operations with a potential for draining the reactor vessel with the vessel head removed and fuel in the vessel. f

- When not administrative 1y bypassed and/or when any turbine stop valve is open.

During operation of the associated Unit I or Unit 2 ventilation exhaust system.

~ } ffThese trip functions (la, 2b, 3c, 6a, 6h, and 7a) are comon to the ECCS actuation trip function. //fThese trip functions'(2a 6b, and 7b) are comon to the RPS and ECCS actuation trip functions.

fffThis trip function (Ib) is comon to the RPS trip function.

) ) es INSTRUMENTATION 3/4.3.3 EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3 The emergency core cooling system (ECCS) actuation instrumentation channels shown in Table 3.3.3-1 sht-11 be OPEPJ.BLE with their trip setpoints set consistent with the values shown in the Trip 5etpoint column of Table 3.3.3-2 and with EMERGENCY-CORE COOLING SYSTEM RESPONSE TIME as shown in Table 3.3.3-3. APPLICABILITY: ns sMn in Table 3.3.3-1. ACTION: - ~. a. With an ECCS actuation instrumentation channel trip setooint less conservative than the value shown in the Allowable Valu'es column of Table 3.3.3-2, declare the channel inoperable until the. channel is restored to OPERABLE status with its trip setpoint adjdsted consistent L with the Trip setpoint value. i i b. Vith one or core ECCS actuatien instrumentation channels inoperable, take the ACTION required by 7able 3.3.3-1. Vith e'ther ADS trip system subsystem inoperable, restor'e the c.- , inoperable trip system to OPERABLE status within: 1. 7 days, provided that the HPCI and RCIC systems are OPERABLE. 2. 72 hours. Otherwise, be in at least h0T SHUTOOWN within the next 12 hours - and reduce reactor steam dome pressure to less than or equal to 100 psig within the following 24 hours. SURVEILLANCE REOUIREMENT5 4.3.3.1 Each ECC5 actuation instrumentation channel shall be demonstrated OPERAELE by the performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION cperations.for the OPERATIONAL CONDITIONS and at the L frequencies shown in Table 4.3.3.1-1. I n-M LOGICSYSTEMFUNCTIONALTESTSandsimugtedmatic cperation of 4.3.3.2 all channels shall be performed at least once on hs. ,g I 4.3.3.3 The ECC5 RESPONSE TIME of each ECCS trip unction shown in Table 3.3.3-3 I shallbedemonstratedtobewithinthelimitaticastonceper$ months. Esca test shall include at least one channelaer trip systen such tha all channels are tested at least once every N times' -8, months where N is the t::a1 nem:er of redundant channels in a' specific ECC " trip system. 72 2 LIMERICK - UNIT 2 3/4 3-32 ,.5 2 a..:. : l m. ~

r ki TABLE 4.3.3.1-1 g M EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE ~ REQUIREME e j g

o Cill.NNEL OPERATIONAL y

g CilANNEL TUNCTIONAL CllANNEL CONDITIONS FOR WIIICll d CHECK TEST CALIBRATION SURVEILLA.1CE REQUIRED M i TRIP FUNCTION lI g [ y 1. CORE SPRAY SYSTEH_ h Reactor Vessel Water Level - w Low Low Low, tevel 1 5 Q R 1, 2, 3, 4*, 5* a. b. Drywell Pressure - High S Q R 1, 2, 3 '1, 2, 3, 4*, 5*- Reactor Vessel Pressure - Low 5 Q R nunt TTitr1RTOn -thA. R II. A. - 1, 2, 3, 45, 5 c. LOW PRESSURE COOLANT INJECTION MOUE OF RilR SYSTEM ~4 2. n Reactor Vessel Water Level - Low Low Low, level 1 S Q R 1, 2, 3, 4*, 5* a. 5 Q R 1, 2, 3 R b. Drywell Pressure - liigh Reactor Vessel Pressure - Low S Q R 1, 2, 3 j c. y d. Injection Valve Differential {j P_tessure - Low (Permissive) S Q R

1. ?; L 4*. 5*

FCA. R N.A. 1, 2, 3, 4*,D Manual Initiation j e. 5' tilGH PRESSURE COOLANT INJECTION SYSTEH*** M' 3. 4,f : Reactor Vessel Water Level - S Q R 1, 2, 3 a. Low Low, Level 2 5 Q R 1, 2, 3 b. Drywell Pressure - liigh Condensate Storage Tank Level - S Q R 1, 2, 3 c. i-Low 3' d. Suppression Pool Water Level - 5 Q R 1, 2. 3

4 111 9h R

1, 2, 3 l Reactor Vessel Water Level - y e. S Q liigh_:_ Level 8 N.A. R N.A. 1, z, 3 gg [ Hanual Initiation e me '.i o y: J 6' 's 4 q M

(? 6Q5 ~ ~ ) TABLE 4.M 3.1-1 (Continued) 'i %'~: n j r. EMERGENCY CORE COOLING SYSTEM ACTUATin4 INSTRUMENTATION SURVEILLANCE REQUIREMENTS o CllANNEL OPERATION AL CilAllNEL FUNCTIONAL CilANNEL C0ftDIT10NS TOR Wilitil i TRIP FUNCTION CitECK TEST CALIBRATION SURVEILLANCE REQUIRED I h 4. AUTOMATIC DEPRc350RIZAT1011 SYSTEl4 s N a. Reactor Vessel Water Level - Low Low Low, Level 1 S Q R 1, 2, 3 b. Drywell Pressure.- High S-Q R 1, 2, 3 c. ADS Timer N.A. Q Q 1, 2, 3 d. Core Spray Pump Discharge Pressure - liigh S Q R 1, 2, 3 ) RilR LPCI Mode Pump Discharce Pressure - liigh S Q R I c 2, 3 I. e. f. Reactor Vessel Water Level - L,ow. Level 3 J 0 R 1, 2, 3 I i, 2, 3rj nual Initiation H.A. R N.A.. _1, 2, 3 lv g X ADS Drywell Pressure Bypass Timer H.A. Q Q . s. y 5. LOSS OF F0WER 4.16 kV Emergency Bus Under p a. voltage (Loss of Voltage) N.A. R N.A. 1, 2. 3, 4**, S** b. 4.16 kV Emergency Dus Under-voltage (Degraded Voltage) S H R

1. 2, 3, 4**,

5** a t R i When the system is required to be OPERABLE per Spectricat*on 3.5.2. co o G' C.E Required OPERADI.E when ESF equipment is required to be OPERADLE.- ~ llot required to be OPERABLE when reactor steam dome pressure is less than or equal to 200 psig. 5D Not required to be OPERABLE when reactor steam dome pressure is it.ss than or equal to 100 pstg. 11 Loss of Voltage Relay 127-11X is not fteld setaole. e h.. .s +

t t INSTRUMENTATION 3/4.3.4 RECIRCULATION FUMP TRIP ACTUATION INSTRUMENTATION ATVS RECIRCULATION PUMP TRIP SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION

3. 3. 4.'1 The anticipated transient without scram recirculation pump trip (ATd5-RPT) system instrumentation channels shown in Table 3.3,4.1-1 shall be OPERABLE with their trip setpoints set consistent with values shown in the Trip 5etpoint column of Teble 3.3.4.1-2.

APPLICABILITY: OPERATIONAL CONDITION 1. ACTION. - a. With an ATV5 recirculation pump trip systam instrumentation channel trip setpoint less conservative than the value'shown in the Allowable Values column of Tabic 3.3.4.1-2, declare the channel. inoperable until the channel is restored to OPEPABLE status with the channel trip setpoint adjusted consistent with the Trip 5etpoint value. ~ b. With the number of OPERABLE channels one less than required by the Minimum OPERABLE Channels per Trip System requirement for one or both trip systems, place the inoperable channel (s) in the tripped condition within 1 hour. c. Vith the number of OPEPABLE channels two or more less than required by the Minimum OPERABLE Channels per Trip System requirement for one trip system and: 1. If the inoperable channels consist of one reactor vessel water level channel and on'e reactor vessel pressure channel, place both inopereble channels in the tripped condition within I hour, or, if this action will initiate a pump trip, declare the trip system inoperable. = 2. If the inoperable channels include two reactor vessei water icvel channels or two reactor vessel pressure channels, declare the trip system inoperable. d. With one trip system inoperable, restore the ineperabic trip system to OPERABLE status within 72 hours or be in at leest STARTUP within ~ the next 6 hours. With botn trip systems inoperable, restore at leest one trip system to LPERABLE status within 1 hour or be in at leest STARTUP wi:nin the next 6 hours. SURVjMLANCE REOUIREMENTS. 4.3.4.1.1. Each ATW5 recirculation pump trip system instrumentatien' channel shall be demonstrated OPERAELE by the performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL T*' and CHANNEL CALIBRATION operations at the frequencies snewn in Table 4.3 4 f w.n ( ,4.3.4.1.2 1 5YSTEM FUNCTIONAL TEST 5 and simujatFiNmatic cperation cf all channa r ina11 be performed at least once irQf?mont.s. ghf" i LIMERICK - UNIT 2 3/4 3-42 FM 2 5 T:

l-t. INSTRUMENTATION [g SURVEILLANCE REOUIREMENTS I l i -4.3.4.2.1 Each end of-cycle recirculation pump trip system instrumentation channel sha' 3e demonstrated OPERABLE by the performance of the CNNNEL I FUNCTIONAL TtST and CHANNEL CALIBRATION operations at the frequencies shown in Ta bl e 4. 3. 4. 2.1-1. -^ a 4.3.4.2.2. LOGIC SYSTEM FUNCTIONAL TESTS and s cTatedlytomatic operation of l all channels shall be performed at least once er T(81mont s. ~ Fil 4.3.4.2.3 The END-OF-CYCLE RECIRCULATION PUMP TR STEH RESPONSE TIME of each_triti. function shownJn Table 3.3.4.2-3 shall be demonstrated to be within { {! Ttr^11mit'st'1Fa'it"once pef $ months. Each test shall include at least the l

7*4[ logic of one type of channel input, turbine control valve fast closure or turbine stop valve closure, such that both types of channel inputs are tested f

'Ge*-least"oncep'erQmonths. The measured time shall be added to the most } .ecent breaker arc suppression time and the resulting END-OF-CYCLE-RECIRCULATION { g PUMP TRIP SYSTEM RESPONSE TIME shall be verified to be within its, limit. - _ ~ _ 4.3'.4.2.4 ~ ~ The t me interval necessary for breaker arc suppression from energi-i 'zation of the recircul6 tion pump circuit breaker trip coil shall be measured at least once per 60 months. ' o R.- 7 ) m I i 9 l l l l I.- LIHERICK - UNIT 2 3/4 3-47 ,n e -.. m. s L n. l.- 3

i...*,'...- ~ INSTRUMENTATION 3/4.3.5 REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION LIMITING CONDITION FOR OPERATION 4 3.3.5 Thereactorcoriisolationcooling(RCIC)systemactuation instrumentation channels shown in Table 3.3.5-1 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3.5-2. APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3 with reactor steam ^ dome pressure greater than 150 psig. ACTION: a. With a RCIC systco actuation instrumentation channel tr'ip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3.5-2, declare the channel inoperable' until the channel is restored to OPERABLE status with its trip setpoint adjusted consistent with the Trip Setpoint value.

b. 4 With one or more RCIC system actuation instrumentation channels inopdable, take the ACTION :equired by Table 3.3.5-1.

SURVEILLANCE REOUIREMENTS 4.3.5.1' Each RCIC system actuat(on instrumentation channel shall be demonstrated SPERABLE by the performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3.5.1-1. 453.5.2 LOGIC SYSTEM FUNCTIONAL TESTS and simu 4Gy.atic eparation of all channels shall be performed at least once er Q4f(mont s. '2P L li i l LIMERICK - UNIT 2 3/4 3-52

f,;;im L

' TABLE 4.3.5.Nk ~' vr n tre.vr r n,r urn e n - REACTOR CORE ISOLATION SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQul AEHENTS CHANNEL CHANNEL FUNCTIONAL CHANNEL FUNCTIONAL UNITS CHECK TEST CAllBRATION a. Reactor vessel Water Level - Low Low Level 2 S Q R b. Reactor Vessel Water Level - High, tevel 8. S Q R c. Condensate Storage Tank Level ' Low 5 Q R Manual Initiation N.A. R 7 A. ~_ F s i LIMERICK bHIT 2 3/4 3-56 Amendment No.17 DEC1*l'.!U

A f

J VJs6-1 1 j _ s..N. W ,s - NE -CONTROL RUD BLOCK fNSTRUMEN(ATION SURifEILLANCE'~ REQUIREMENTS h. k CHANNEL. OPERATIONAL J !- 'E ~ CHANNEL:

FUNCTIONAL-CHANNEL CONDITIONS FOR WHICH Y

CHECK -TEST CALIBRATION (a)- SURVEILLANCE REQUIRED. b-l

R'ITRIP FUNCTION To: ...

t_! w -:1.- ROD 1. TCK MONITOR f 1 i x. '.5/U((b)(c), (c .a. . Upscale _ N.A.- 33 3 S/U b)(c) (c b.- Inoperative-N.A.. N.A. 1* -c. Downscale: N.A. S/U(b)(c),(c) SA 1* t. i 2.- APRM_ .a. Flow Blased Neutron flux - Upscale' N.A. S/U ,Q SA 1 b. Inoperative N.A. S/U ,Q N.A. 1,~2, 5*** c. Downstale N.A. S/U ,Q SA-1 E d. Neutron Flux - Upscale. Startup N.A. S/U ,Q SA 2, 5*** I

3..

SOURCE RANGE MONITORS S/U(b) N.A. 2, 5 .S/U(b),W l-R s. Detector not full in N.A. ,W SA 2, 5 b. Upscale N.A. Y c. Innperative N.A. S/U ,W N.A. 2, 5 .T d. Downscale -N.A. S/U ,W SA. 2, 5 4. INTERMEDIATE RANGE MONITORS 4 n. Detector.not full in N.A. S/U ,W H.A. 2, 5 b. . Upscale. H.A. S/U .W SA 2, 5 S/U N.A. 2, 5 .S/U(b),W c.- Inoperative N.A. ,W SA 2, 5 d. Downscale N.A. { 5. SCRAM DISCHARGE VOLUME j = ~ R 1,' 2, 5** j ^ [ a. Water Level-High N.A. Q !:-,3" 6. REACTOR COOLANT SYSTEM RECIRCULATION FLOW C' o a. Upscale N.A. S/U(b) Q SA 1 'J* b), H.A. 1 .S/U(b),Q b. Inoperative. N.A. S/U( ,q 33 g f !'I Cl c. Comparator. N.A. ~ REACTOR MODE SWITCH SHUTDOWN ( ION-N.A. R H.A. 3

(7 IHSTRUH*"NTATION REHOTE SHUTDOW SYSTEM INSTRUMENTATION AND CONTROLS { LIMITINC. CONDITION FOR OPEFATION ~ The remote shutdevn system instrumentation and centrols shown in 3.3.7.4 . Table 3.3.7.4-1 shall be OPEPABLE. APPLICAEILITY: OPE?ATIONAL CONDITIONS 1,and 2. ACTION: Vith 'the~ number of OPERAELE remote shutdown system instrumentatien channels less than recuired by Table 3.3.7.4-1, restore the ineperable a. channel (s) to OPEP.ASLE status within 7 days or be in at least HOT SHUTDOW vithin the r>cxt 12 hours. ( With the numbei of OPEPABLE ' remote shutdown system controls less than l b. required in Tab e 3.3.7.4-1, restore the inoperable control (s) t: OPERABLE status within 7 days or be in at least HOT SHUT 00W vithin . - the next 12 hours. 21icable. The provisiens of Epecification 2.0.4 are nc* c. 1 l SUT.VEILLANCE REOUIREMENT5 ~ t 1 Each of the above required remote shutdown monit: ring instrumentation 4.3.7.4.1 l channels shall be demonstrated OPE?ABLE by performance of the CHANNEL CHECX and CHANNEL CALIERATION cperatic ; at the frequencies shcvn in Table 4.3.7.4-1. l l. 7 Eachoftheabovekemeteshutdevncontrolsvitch(es)andc:nr:i ( b. 4.3.7.4.2 ' circuit: shall be demcas rated OPERABLE by.1yjngitsca:abilitytope-f:. its intended fun :icn(s) at least once p. 94J. men hs. ro'St l I .{ l. M 2 0 UU LIHERICX - UNIT 2 3/4 2-76

1 INSTRUMENTATION 3/4.3.9 'EEDWATER/KAIN TURBINE TRIP SYSTEM ACTUATIJa INSTRUMENTATION LIMITING CONDITION FOR OPERt. TION 3.3.9 The feedwater/ main turbine trip system actuation instrumentation channels shown in Table 3.3.9-1 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip 5etpoint column of Table 3.3.9-2. APPLICABILITY: As shown in Table 3.3.9-1. ACTION: a'. With a feedwater/ main turoine trip system actuation instrumentation channel trip setpoint less conservative than the value shown in the A11cweble Values column of Table 3'.3.9-2, declare the channel inoper-- able and either piace the inoperable channel in the tripped condition until the channel is restored to OPERABLE status with its trip set-point adjusted consistent with the Trip Setpoint v lue, or declare the associated system inoperable. b. With the number of OPERABLE channels one less than reg'uired by the Minimum 0FERABLE Channels requirement, restore the inoperaole channel to OPERABLE status within 7 days or be in at least STARTUP within the next 6 hours, c. With the number of OPERABLE channels two less than required by the Minimum OPERA 5LE Channels requirement, restore at least ene of the inoperable channels to OPERABLE status within 72 hours or be in at least STARTUP within the next 6 hours. , SURVEILLANCE LiOUIREMENTS 4.3.9.1 Each feecwater/ main turbine trip system actuation instrumentation channei ~ shall Le demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL FUNCTI.0NAL TEST, and CHANNEL CALIBRATION operations for the OPERATIONAL CONDITIONS and at the f repuencies shown in Table 4.3.9.1-1. 4.3.9.2 LOGIC SYSTEM FUNCTIONAL TESTS and simallted EDtqmatic cperatien cf all channels shall be performed at least once per))ERmon hs. d I W s LIMERICK - UNIT 2 3/4 3-112 i'." 25E

REACTOR COOLANT SYSTEM SURVEILLANCE REOUIREMENTS .m 4.4.1.1.1 each valve through at least one complete cycle of full trave ,* prior to THERML POWER exceeding 25% of RATED THERMAL POWER. star 4.4.1.1.2 demonstrated OPERABLE with overspeed setpoints less thanEach p 107%. respectively, of rated core flow, at least once p r fdmonths M to 10S% and Mtablish a baNnPRM and FneutdnM se v. within 2 hours of entering the region (or which monitoring i alue within baselining has previously been performed in the region since the last refuelie outage. 4.4.1.1.4 With one reactor coolant system recirculation loop not in operation, at least once per 12 hours verify that: Reactor THERMAL POWER is 5 70% of RATED THERMAL POWER,' a. b. The recirculation flow control system is in th'e Local Manual mode, .+ and The speed of the operating recirculation pump is 1 90% of rated pump - c. speed.' d. Core flow is greater than 39% when THERMAL POWER is within the restricted zone of cigure 3.4.1.1-1, 4.4.1.1.5 With one reactor coolant system recirculation loop not in operation, v9hin 15 minutes prior to either THERMAL 00WER increase or recirculatior. # cop flow increase, verify that the following diffeiential temperature requirerents are met 'if THERMAL POWER is < 30% of RATED THERMAL F0WER or the rec % m w on locp flow in the operating recirculation loop is 1 50% of ated low 145*F between reactor vessel steam space coolant and bottom head a. . ain line corlar.t, b. End the ccMarit in the reactor pressure vessel, and< 50*F b ind the operating loop,< 50 F between the reactor coolant within the loo c. i: The -differential temperature requirements of Specification 4.4.1.1.5b. anc c. i-do not apply when the locp not in operation is isolated from the reacter pressure vessel. 7 L

If nct performtf within the previous 31 days.
- Detector levels A and C of one LPRM string per core octant plus detec-snd C of one LPRM string in the center of.he core should be monitored.. ors A LIMERIt. - UNIT 2 3/4 4-2 AM258

REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS 4.4.3.2.1 Thereactorcoolantsystemikakageshallbedemonstratedtobewithin each of the above limits by: a. Monitoring the primary containment atmospheric gaseous radioactivity at least once per 12 hours (not a merns of quantifying leakage), b. Monitoring the drywell floor drain sump and drywell eouipment drain tank -flow rate at least once per eight (8) hours, l c. Monitort g the. drywell unit coolers condensate flow rate at least once per 12 hours, d. Monitoring the primary containment pressure at least once per 12 hcurs (notameansofquantifyingleakage), o e. Monitoring the reacter vessel head flange leak detection system at least once per 24 hours, and f. Monitoring the primary containment temperature at least once per 24 hours (not a means of quantifying leakage). ~ c ' ' '.'. 2 Er i reactor coolant system pressure isolation valve specified in / f i o..- i.4.3.2-1 shall be demonstrated OPERABLE by leak testing pursuant to h G > -i ication 4.0.5 and verifying the leakage of each valve to be within the sp:.fied limit: i 2+ a. At least once er,1 ths, and b. Prior to returning the valve to service following maintenance, repair or replacement work on the valve which could affect its leakage rate. The provisions of Specification 4.0.4 are not applicable for entry into OPERATIONAL CONDITION 3. 4.4.3. 3 The high/ low pressurt interface valve leakage p'ressure monitors shall be demonstrated OPERABLE with alarm setpoints set less than the allowable values in Table'3.4 3.2-1 by performance of a: a. CHANNEL FUNCTIONAL TEST at least once per 31 days, and b. CHANNEL CALIBRATION at least once per 18 months. LIHERICK - UNIT 2 3/4 4-10 Amendment No.12 An 0 4 M l

4 EMERGENCY CORE C00L1NG SYSTEMS SURVEILLANCE REOUIREMENTS 4.5.1 The emergency core cooling systems shall be demonstrated OPERABLE by: a. At least once per 31 days: 1. For the CSS, the LPCI system, and the H?CI system: a) " Verifying by venting at the high point ver.ts that the system piping from the pump discharge valve to the system isolation valve is filled with water. b) Verifying that each valve (manual, power-operated, or automatic) in the flow path that is not locked, sealed, or othervise secured ir position, is in its correct

position.

2. For the LPCI system, verifying that both th.i system subsystem cross-tie valves-(HV-51-282 A, B) are closed with power removed .from the valve operators. 3. ,For the HPCI system, verifying that the HPCI pump'. flow controller i,s in the ' correct position. ~4 'For the CSS and LPCI systeni, performance of a ' CHANNEL FUNCTIONAL TEST of the injection header AP instrumentation. b. Verifying that, when tested pursuant _to Specification 4.0.5: 1. Each CSS.ounp in each subsystem develops a flow of at least 3175 gpm against a test line pressure corresponding to a reactor vessel to primary cor'.ainment differential p'ressure of > 105 psid plus head and line losses. ~ s 2. Each LPCI pump in ead subsystem develops,a flow of at least 10,000.gpm against a test line pressure corresponding.to a reactor vessel to primai'y containment differential pressure of 1 20 psid plus head and line losses. - 3.- The HPCI pump develops a flow of at least 5600 gpm against a test line pressure which corresponds to a reactor vessel pressure of-1000 psiig plus head and line losses when steam is being suppli ddy tmtuMne at 1000, +20, -80 psig ** At least once p r[8' NIni s: c. 1. For the CSS, e LPCI system, and the HPCI system, performing a system functional test which includes simulated automatic k actuation of the system-throughout its emergency operating sequence and verifying that each automatic valve in the flow path attuates to its correct position. Actual injection of coolant into the reactor vessel may be excluded. from this test.

Except that an automatic valve capable of automatic return to its ECC5 position when an ECCS signal is present may be in position for another. node of operation.

"The provisions of Specification 4.0.4 are not applicable provided the surveillance is performed within 12 hours after reactor steam pressure is adequate to perform the test. If OPERA 61LITY is not successfully demonstrated within. he 12-hour period, reduce. reactor steam dome pressure to less than t 200 psig.within the following 72-hours. LIMERICK - UNIT' 2 3/4 5-4 5 e... ,w

.. n:.

U '. @. c -

EMERGENCY CORE COOLING SYSTEMS-SURVEILLANCE RE0VIREMENTS (Continued) 2. For the HPCI system, verifying that: a) The system develops a flow of at least 5500 gpm against a test line pressure corresponding to a reector vessel pressure of-> 200 psig plus_ head and line losses, when steam is being ) supfliedtotheturbineat 200 + 15, - 0 psig. " ) b) The suction is automatically transferred from the condensate storage tank to the suppression chamber on a condensate storage tank water level - low signal and on a suppression chamber water level - high sional. 3. Performi and HPCI system disch'aFge line " keep filled" alarm instrumentation. 4. Performing a CHANNEL CALIBRATION of the C55 header AP instru- ~ mentation and verifying the setpoint to be 3 the allowable value ~of 4.4 psid. "" ' 75. Performing a CHANNEL CALIBRATION of the LPCI header AP instru-mentation and verifying the setpoint to be'$ the allowable value of 3.0 psid. K.6, /, d. Fo,r th'e ADS: ~ 1. 1 _-At least once per 31 days, performing a. CHANNEL FUNCTIONAL TEST of the ac'cumulator bac n cor ressed gas. system low pressure

l. f alarm system.

g _s 2.- At east once.r)1S' mon 2 'a) Parforming a system functional test'which includes simulated + automatic actuation of the system throughout its emergency j' operatin'g sequence, but excluding actual valve actuation. / b) y Hanually' opening each ADS valve when the reactor steam dome pressure is greater than-or equal to 100 psig** and y , observing that either: The control valve or bypass valve position responds p 1)- a accordingly, or / 2) There is a corresponding change in the measured steam c) Perf rmag a CHANNEL CALIBRATION of the accumulator backup (corr;,ressed gas s'ystem low pressure alarm system and verifying 7 an alarm setpoint of 90 2 psig on decreasing pressure. '"The provisions' of Specification 4.0.4 are nob applicable provided tie surveillance is performed within 12 hours after reactor steam pressure is adequate'to: perform the test. If ADS or_'HPCI OPERASILITY is not successfully -demonstrated within the'12-hour period, reduce reactor steam dome pressure to less than 100'psig or 200 psig, respectfully, within the following 72 hours. 4 -LIMERICK-- UNIT 2 3/4 5-5 fj5 2 5 tii

v m s.. + FCONTAINMENT SYSTEMS o g SURVEILLANCE REOUIREMENTS (Continued): d. - Type B and C. tests shall be conducted with gas at' P,, 44.0 psig*, 1 ' at intervals,no greater than 24 months except for _ tests involving: 1. Lair locks, - 2.- Main steam-line isolation valves, 3[ Containment isolationi. valves Jn hydrostatically tested lined which penetrate the primary containment, and Air 15cks 'shall be tested and demonstrated OPERABLE'per Surveillance I

e/

- Requirement 4.6.1=.3r - p, c, A 2 f.

Main steam: line -isolation valves shall be leak tested.at least on a

} ff[r*5llgg g [ Q J Q jZs Q p.* g Q QLig* ?)3 @ f d. 3-per onti Q 1 -f *1#'4 s g^.~ Cohtainment5isolationivalves in' hydro ~ statically testid: lines which penetrate thel primary containment-shall be' leak tested at least o' a [ l: P.er $j(imenthsg,g g{gfg'f g ((ffpT@ g{. g 4?so!,9&TJ'IfM!fj;, 3;2t; _j ons.vr sprecification 4.0.2 are not applicable-to Specifica-N - h.- e i - tions 4. 6.1. 2a'.', : 4. 6.1. 2b;, 4. 6.1. 2c.. 4. 6.1. 2d..,. and 4. 6.1. 2e.- 4 ~ i o y ~ l55] f'_ . ~ -t s i MUnless azhydrostatic-:-test is required per Table 3.6.3-1. ~ 1u E25E ' LIMERICK -cUNIT '2 3/4.6-4' f f f' 55fk' rpf'O '924t F-T tyM v *i +gsw z'Trh'9F-+ W"d'. " '- %sr- '*z 1-m

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i CONTAINMENT SYSTEMS ,, ~ ~, MSIV LEAKAGE CONTROL SYSTEM LIMITING' CONDITION FOR OPERATION 3.6.1.4 Two independent MSIV leakage control system (LCS) subsystems shall be OPERABLE. APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3. ~ ACTION-With one MSIV leakage control system subsystem inoperable, restore the inoperable subsystem to OPERABLE status within 30 days or be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. SURVEILLANCE REOUIREMENTS l

4.6.1.4 Each MSIV leakage control system subsystem shall be demhnstrated OPERABLE:

j ~ a; '~At least onc'e per 31 days by:" 1. Starting the blower (s) from the control room and operating the blower (s) for et least 15 minutes. ~ 2. Energizing the heaters and verifying a temperature rise indicat-ing heater operation on downstream piping. b. During each COLD SHUTDOWN, if not performed within the previous s 92 days, by cycling each motor operated valve through at least one complete cycle of fulhtrave1. s 4 4-; / [c.Atleastonce r)6mont/sby: ( 1. Performanc 'a functional. test which includes simulated actua-tion of the subsyste.n throughout its operating sequence, and i verifying that each interlock and timer operates as designed, ( -each automatic valve actuates to its correct position and the A blower starts. } 2. -Verifying that the blower (s) develops at least the below required vacuum at the rated capacity: a) Inboard valve:;, 15" H O at 100 scfm. 2 b) Outboard valves,15" H O at 200 scfm. 2 d. By ve ifying the operatin'g instrumentation to be OPERABLE by performance of a: 5 1. CHANNEL CHECK at least once per 24 hours, l 2. CHANNEL FUNCTIONAL TEST at least once per 31 days, and 3. CHANNEL CALIBRATION at least once per 18 months. l \\ l LIMERICK - UNIT 2 3/4 6-7 AUS 2 5 lii' l

CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) c. By verifying at least two suppression chamber water level indicators and at least' 8 suppression pool water temperature indicators in at, least 8 locations, OPERABLE by performance of a: 1. CHANNEL CHECK at least once per 24 hours, 2. CHANNEL FUNCTIONAL TEST at least once per 31 days, and i 3. CHANNEL CALIBRATION at least once per 18 month, with the water level and temperature alarm setpoint for: 1. High water sevel 5 24'1 " K 2. High water temperature: ~ / ^ a) First setpoint 5 95 F b) Second setpoint 5 105*F c) Third setpoint i 110 F ~ d) Fourth s +n tw < 120 F Qsy ef,c.:2,./.d, At least once p r u m ehs by conducting a drywell-to-suppression chamber bypass lea est at an initial differential pressure of k) 4 psi and verifying tha+ the A/[i calculated from the measured leakage is within the specified limit. If *any drywell-to-suppression chamber bypass leak test fails to meet the specified limit, the test {%) schedule for subsequent tests shall be reviewed and approved by the ( Commission. If two consecutive tests fail to meet the specified { limit, a test shall be performed at least everyGfmonths until two nTE tive tests meet the specified limit,, atMich time the I rJ81mont test schedule may be resumed. I W gg.! 7 W LIMERICK - UNIT 2 3/4 6-14 AUG 2 5 E

pq CONTAINMENT SYSTEMS G SURVEILLANCE REOUIREMENTS l 4.6.3.1 Each primary containment isolation valve shown in Table 3.6.3-1 shall be demonstrated OPERABLE prior to returning the valve to service af ter tainte-nance, repair or replacement work is performed on the valve or its associated actuator, enntrol or power circuit by cycling the valve through at least one complete cycle of full travel and verifying the specified isolation time. 4.6.3.2 Each primary containment automatic isolation valve shown in Table 3.6.3-1 shall be demonstrated OPERABLE during COLD SHUTDOWN or REFUELING 1 h y 1 1 least once pe @ tic isolation valve actuates to its isolation position. months by verifying that on a containment isolation test l signal each automa - - sw w-4.6.3.3 The isolation time of each primary containment power opcrated or automatic valve shown in Table 3.6.3-1 shall be determined to be within its limit when tested pursuant to Specification 4.0.5. 4.6.3.4 Each instrumentation line excess flow checbvalve shown in Table 3.6.3-1 -sjall be demonstrated OPERABLE at least once cer'J(mont'hs by verifying th7t the l valve checks flow. ( q 4.6.3.5 Each traversing in-core probe system explosive isolation valve shall be demonstrated OPERABLE: a. At least once per 31 days by verifying the continuity of the explosive l charge. ir N <O /20 s-b. At least once er,16 months by removing th explosive squib from the l explosive valve, Txfi that each explosi,ve. qsquib in each explosive. j) valve will be tested at least once per@d conths, and initiating the 1l k explosive squib. The replacement charge for the exploded squib shall be from the same manufactured batch as the one fired or from another 4 batch which has been certified by having at least one of that batch j successfully fired. No squib shall remain in use beyond the expiration ( of its shelf-life and/or operating life, as applicable. s / LIMERICK -UNIT 2 3/4 6-18 AUS 2 5 IXs l

l CONTAINMENT SYSTEMS 7?4.6.5 SECONDARY CONTAINMENT REACTORENCLOSURESECONDARYCONTAINMENTlNTEGRITY LfMITING CONDITION FOR OPERATION 3,6.5.1.1 REACTOR ENCLO5URE. SECONDARY' CONTAINMENT INTEGRITY shall be maintained. _APPLfCABILITY: OPERATIONAL CONDITIONS 1, 2, and 3. ACTION: Without REACTOR ENCLOSURE SECONDARY CONTAINMENT INTEGRITY, restore REACTOR ENCLOSURE SECONDARY CONTAINMENT INTEGRITY within 4 hours or be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following '24 hours. SURVEILLANCE REOUIREMENTS 4.6.5.1.1 REACTOR ENCLOSURE SECONDARY CONTAINMENT INTEGRITY s. hall be demon-st. rated - by: a. Verifying at least once per 24 hours that the pressure within the reactor enclosure secondary containment is greater than or equal to 0.25 inch of vacuum water gauge. b. Verifying at least once per 31 days that: 1. All reactor enclosure secondary containment equipment hatches and blowout panels are c 3 sed and sealed. 2. At least one door in each access to the reactor enclosure secondary containment is closed. 3. All reactor enclosure secondary containment penetrations not capable of being closed by OPERABLE secondary containment auto-matic isolation dampers / valves and required to be closed during accident conditions are closed by valves, blind flanges, slide gate dampers or aaqivatedautomaticdampers/valvessecuredin positic1. p c; At least once t' ths: 1. -Verifying that one standby gas treatment subsystem will draw down h the reactor enclosure secondary containment to greater than or ] equal to 0.25 inch of vacuum water gauge in less than or equal to 121 seconds with the reactor enclosure recirc system in operation, and 2. Operating one standby gas treatment subsystem for one hour and maintaining greater than or equal tt 0.25 inch of vacuum water gauge in the reactor enclosure secondary containment at a flow I rate not exceeding 1250 cfm with wind speeds of 17.0 moh as-measured on the wind instrument on Tower l' elevation 30' or, if that instrumenc is unavailable, Tower 2, elevatien 159'. ~ ~- LIMERICK - UNIT 2' 3/4 6-46 E'5 2 5 E '

'r. d ;-: .. A :.: M ~ 1 l-l ,( CONTAINMENT SYSTEMS ~ 3/4.6.5 SECONDARY CONTAINMENT .~ REFUELING AREA SECONDARY CONTAINMENT INTEGRITY LIMITING CONDITION FOR OPERATION 3.E.5.1.2 REFUELING AREA SECONDARY CONTAINMENT INTEGRITY shall be maintained. APPLICABILITY: OPERATIONAL CONDITION *. ACTION: Without REFUELING AREA SECONDARY CONTAINMENT INTEGRITY, suspend handling of irradiated fuel in the 4,econdary containment, CORE ALTERATIONS and operations with a potential for draining the reactor vessel. The provisions of Specifica-tinn 3.0.3 are not applicable. SURVEILLANCE REQUIREMENTS 4.6.5.1.2 REFUELING AREA SECONDARY CONTAINMENT INTEGRITY shall be demonstrated by: Verifying at least once per 24 hours that the pressure within the a. refueling ar,ea secondary containment is greater than or equal to' 3 O.25 inch of vacuum water gauge. b. Verifying at least once per 31 days that: 1. All refueling area: secondary containmant equipments hatches.and.... blowout panels.are closed.and: sealed... - At" lea'st one door in each access;te the refueling area secondary-2. . containment is: closed. 3. All' refueling area. secondary containment penetrations:not.capablei .of being closed by OPERABLE. secondary. containment:automaticriso- ' ' lation dampers / valves and requirchto be closed during. accident-conditions are closed by valves, blind flanges, slide. gate. dampers or deactiyate automatic dampers / valves secured.in M -position. e. - v. N.& -w f c. At least once er s: Operating one: andby;gasstreatment su'bsystem-for one. hour;and: main-l taining greater than or equal to- 0.25' inch of' vacuum water.' gauge.. l i n the. re f uel i ng are a. s econda ry : conta inment: at; a fl ow: ra te.. no t: exce edi ng 764 cfmr P

Required when (1) irradiated fuel is being handled in the refueling area secondary containment, or (2) during CORE ALTERATIONS, or (3) during operations with a potential for dr'aining the reactor vessel with the vessel head removed and fuel in the vessel.

LIMERICK UNIT 2 3/4: 6-47~ : .., A. 2 E Le.ir,. r__

' CONTAINMENT 5YSTEMS .'AUTOR ENCLOSURE' SECONDARY CONTAINMENT AUTOMATIC ISOLATION VALVES . LIMITING CONDITION FOR OPERATION 3.5.5.2.1 The reactor enclosure secondary containment ventilation system auto- .matic isolation valves shown in Table 3.6.5.2.1-1 shall be OPERABLE with isciation ' times less than or equal to the times shown in Table 3.6.5.2.1-1. APPLICABILITY: _ OPERATIONAL CONDITIONS 1, 2, and 3. ACTION: With one or more of the reactor secondary containment ventilation system automatic isolation valves shown in Table 3.6.5.2.1-1 inoperable, maintain at least'one isolation valve OPERABLE in each_affected penetration that is open and within 8 hours either:- --- - a. Restore the inoperable valves to OPERABLE status, or b. Isolate each affected penetration by use of at least one deactivated - valve secured in the isolation position, or~ c.- Isolate each affected penetration by use of. at least one closed canual valve, blind. flange or slide gate damper. Otherwise, in OPERA'TIONAL CONDITION 1, 2 or 3, be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours. SURVEILLANCE REOUIREMENTS ~ l 4.6.5.2.1 Each reactor enclosure secondary containment ventilation system automatic isolation valve shown in Table OPERABLE: ~ 3.6.5.2.1-1 shall be demonstrated a. Prior-to t'eturning the valve to service-after maintenance, repair or replacement: work.is performed on the valve or its associated actuator, control or power circuit by cycling the _ valve through at least.one l complete ~ cycle of full 14avel and verifying the specified isolation tim. Gj." ~ b. At least once per Jf' nths by verifying that on a containment isolation test M'_nal each. isolation valve actuates to its isolation . position. / v c. By verifying'the isolation time to be within its limit at least once per 92 days. L LIMERICK - UNIT 2 3/4 6-48 AL: 2 i JU

CONTAINMENT SYSTEMS M REFUELING AREA SECONDARY CONTAINMENT AUTOMATIC ISOLATION-VALVES ~

LIMITING CONDITION FOR OPERATION t

'3.6.5.2.2 The refueling area secondary containment ventilation systim automatic isolation valves shown in Table 3.6.5.2.2-1 shall be OPERABLE with isolation -times-less than or equal to the times shown in Table 3.6.5.2.2-1. . APPLICABILITY: OPERATIONAL CONDITION *. ACTION: 1With ene or more of.the-refueling area secondary containment yentilation system automatic isolation valves shown in Table 3.6.5.2.2-1 inoperable, maintain at least one isolatien valve OPERAELE in each affected penetration that is. open and within B hours-either:.._ -- ~ a. Restore the inoperable valves to OPERABLE status,'or, b. Iselate each affected penetration by use of at least one deactivated valvet secured in the isolation position, or- - c. -Isolate each affected penetration by use of at least one closed manual .~ valve, blind flange or slide gate damper. Otherwise, in OPERATIONAL CONDITION 3 suspend handling of irradiated

fuel in the refueling-area secondary containment, CORE ALTERATIONS and operations with a potential for draining the reactor vessel. The provisions

of Specification ~ 3.0.3 are not applicable.

SURVEILLANCE REOUIREMENTS 4.'6.5.2.2 Each refueling: area secondary containment ventilation system auto-t matic isolation valve-shown in Table 3.6.5.2.2-1 shall be demonstrated OPERABLE: a. Prior. to returning the valve.to service af ter maintenance, repair or replacement work is performed on the valve or its associated actuator, control or power circuit by cycling the valve through at least one complete. cycle of full travel and verifying the specified isolation time.. ~ ^ ,h b. At least once.r98'mo-is by verifying that on a containment isolation test '. ~ each isolation valve-actuates to its isolation position. c. . By verifying.the-isolation time to be within its limit at least once ,ner 92 days.

Required when-(1) irradiated-fuel is being handled in the refueling area secondary containment, or (2) curing COPE ALTERATIONS, or (3) during operations with-a: potential for draining thelrsattor vessel with the vessel head removal and fuel in the vessul.

LIMERICX . UNIT 2 3/4 6-50 C2EE [ ~ L

CONTAINMENT SYSTEMS SURVEILLANCE REOUIREMENTS (Continuedl C ~ y,g,,.0,3.b. At least once er 6 s or (1) after any structural maintenance ). on the HEPA fil charcoal adsorber housings, or (2) following painting, fire; or chemical release in any ventilation zone I h communicating with the subsystem by: I 1. Verifying that the subsystem satisfies the in place penetration and bypass leakage testing acceptante criteria of less than 0.05%- and uses the test procedure guidance in Regulatory Positions C.5.a, I C.S.c and C.5.d of Regulatory Guide 1.52, Revision 2, March 1978, l and the system flowyat.e is 3000 cfm 10%. 2. Verifying within 31 days af ter removal that a laboratory analysis j of a representative carbon sample obtained in'accordance with 1 i Regulatory Position C.6.b of Regulatory Guide 1.5.2, Revision 2, March 1978, meets the laboratory testing criteria.of Regulatory ~ ' Pos ition C.6.a of Regulatory Guide 1,52, Revision 2, March 1978, for a methyl iodide penetration of less than 0.175%; and L 3. Verify thet when the fan is running the subsystem flowrate is-2800 cfm minimu:r from each reactor enclosure (Zones I and II) L and 2200 cfm minimum from the refueling area (Zone III) when tested in'accordance with ANSI N510-1930. 4. Verify that the pressure drop across the refueling area to SGTS prefilter is less than 0.25 inches water gage while operating at a flow rate of 2400 cfm 10%. ~- ~ . After every 720 hours of charcoal adsorber operation by verifying t. withia 31 days af ter removal that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory i L Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978, for a methyl iodide penetration - et than 0.175%. WA 7 .gy 7 d. At least once p r;Jp s by: 1. Verifying that the pressure drop across the combined HE?A filters and charcoal adsorber banks is less than 9.1 inches water gauge while operating the filter train at a flow rate of I 8400 cfm 10%. p x_ { - )(lb.55!1u Dei, wsdhu. O %smeJ n> m 0 a N 6 hu M ' \\ . %I.Aiculhd Nur at: s_ l kcasia; 2, A/$w /1? 2.1 L!2 LIMERICK - UN.IT 2 3/4 6-53 1 1

,(q = 9 fCONTAINMENT SYSTEMS a SURVElt. LANCE REQUIREMENTS-(Continued) %6b3-1 -Verifying that:the fan star ecessary / 'l L draw a suction from the refueling area gr the' reactor eaclosure 7 recirculation-discharge open on each of the following test. signals:, N& -a) -Manual: initiation from the control room, and L 4f b)- Simulated automatic initiation _ signal. IVerifying-that the temperature d.'ferential across. each heater h - ,g L3.. 15 F when test ordance with ANSI N510-1980. . Af ter;each complete or partial replacement of a HEPA filter bank by e.- .'v'erifying that the'HEPA filter bank satisfies the inplace penetration and leakage testing acceptance criteria of less than 0.05% in accordance with - ANSI. N510-1980 while-operating the_ system at a flow rate-of 3000 cfm t'10%. a

f.

After each. complete or partial replacement of a charcoa.1 adsorber ! bank ~.by verifying that the-charcoal; adsorber bank satisfies the inplace -penetration and: leakage: testing acceptance criteria of less than 0.05% J Lin accorda'nce withJANSI N510-1980 for a halogenated hydrocarbon refrigerant test: gas while operating the system at a flow rate of

3000.cfm 1.104.

v.z w;:

g.-

T Af ter any majorg system ' alteration: 'N 11. . Verify that when the.5GTS -fan-is running the subsystem flowrate-4 .is!2800 cfm minimum from each reactor enclosure (Zones I:and 9 II) andi2200 cfm minimum fromLthe refueling area;(Zone III). Verifh thatt one' standby gas' treatment subsystem will drawdown 2. ' reactor enclosure Zone II ' secondary containment to: greater than 'on equal to' 0.25' inch of vacuum water gauge inLless than 'or equal to'1211 seconds with the reactor enclosure recirculation ~ system:in? operation and'the adjacent reactor enclosure and refueling: area zones are in their isolation modes. .a a J, LLIMERICK 3 UNIT 2 3/4 6-54 AUG 2 51939 in (: t

.<.v.'- ~

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.' C0KTAINMENT SYSTEMS _e REACTOR ENCLOSURE' RECIRCULATION SYSTEM LIMITING CONDITION FOR OPERATION 3.6.5.4 Two independent reactor enclosure recirculatien subsystems shall be OPEPABLE. APPLICABILITY: OPEPJ.TIONAL CONDITIONS 3, 2, and 3. ACTION: With one reactor enclosure recirculation subsystem inoperable, restore a. the inoperable subsystem to OPERABLE status within 7 days, or be in at ler.st HOT SHUTDOWN within'the next 12 hours and in COLD SHUTDOWN within the following 24 hours, With both reactor enclosure recirc'ulation subsystems inoperable, be b. in at least HOT SHUTDOWN within the next 12 hours.and in. COLD SHUTDOWN within the following 24 hours. SURVEILLANCE REOUIREMENTS

4. 6. 5. 4 Each reactor enclosure recirculation subsystem shall be demonstrated E

OPEPABLE: At least once per 31 days by initiating,. from the. control room, flow a. through the HEPA-filters an,d charcoal adsorbers.and verifying that the. s ubsystem.operategoerly..< y b. At least; once:p r.ildra ' s: or. (1) af ter any: structural. maintenance: ~ .on the.HEPA:fil ? charcoal:adsorber.housingsT:or-(2) following / painting, firec or. chemical release. in any. ventilation zone communi-cating with-the subsystem by: i 1-Verifying that the subsystem satisfies:the in place penetration ,and bypass < leakage testing acceptance criteria of less than 0.05% . and uses. the. test; procedure: guidance.in Regulatory Positions C.S.a', . C. 5. c,. and. C.5.d'.of Regulatory Guide.1' 52,, Revision 2 c March 1978, arid.the system: flow rate:is' 60,000.cfm. :10%.. 2. Verifying withiri il da'ys after. removal.that.a laboratory analysis 8 ofc a: representa; tve carbon: sample:obtainedcin accordance with' Regulatory Position C.'6.b.of: Regulatory Guide;1.52,- Revision 2,. March 1978'r meets:the: laboratory' testing criteria of Regulatory - Position C.6ia of-Regulatory Guide:1'.52, Revision 2, March 1978, for a methyl iodide penetration of. less than 1%; and

3.. Verifying a subsystem flow rate of 60,000 cfm : 10% during system operation when tested in accordance with ANSI N510-1930.

. Y.. h,.,.........,-.....,...............,.......N ~ TP 9ft4dffl -1 4 M c:ts,A C HtC/ 1 THE'$ui0kG bviD(D'14 1 $i505i5%$ $i5jf[ Adit [U? ? l.'Kiky I h q 8':M i LIMERICK - UNIT 2 3/4 6-55' A'K 2 E M:_

.a............-. 4 CONTAINMENT SYSTEMS ',URVEILLANCE REOUIREMENTS (Continued) l After every 720 hours of charcoal adsorber operation by verifying c. within 31 days af ter removal that a laboratory analysis of a repra-sentative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978 ) meets the lahnratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1975, for a methyl -iodide penetration of less than 1%. m [ d. At least once by: 1. Verifying that the pressure drop across tha combined prefilter, [ ] upstream and downstream.HEPA filters, and charcoal adsorber t banks is less than 6 inches water gauge while operating the filter train at a flow rate of 60,000 cfm 10%,. verifying that { the prefilter pressure drop is less than 0.8 inch water gauge and that the pressure drop across each HEPA is less than 2 inches . water gauge. 2. Verifying that the filter train starts and the isolation valves which take suction on and return to the reactor enclosure open on each o,f the following test signals: 'k a. Manual initiation from the control room, and b. Simulated autonatic initiation sigr.al. After each complete or partial rsplacement of a HEPA filter bank by e. verifying that the HEPA filter bank satisfies the inplace penetration and leakage testing acceptance criteria of less than 0.05% in accordance with ANSI N510-1980 while operating the system at a flow -rate of 60,000 cfm i 10%. f. After each complete or partial replacement of a charcoal adsorber-bank by. verifying that the charcoal adsorber bank satisfies the inplace penetration and leakage testing acceptance criteria of less than 0.05% in accordance with ANSI H510-1980 for a halogenated hydro-carbon-refrigerant test gas while operating the system at a flow rate of 60,000 cfm o 10%. 9 LIMERICK - UNIT 2 3/4 6-56 AUG 2 5 E z-

~ C0NTAINMENT SYSTEMS (. 3/4.6.6 PRIMARY CONTAINMENT ATMOSPHERE CONTROL PRIMARY CONTAINMr.NT HYDROGEN RECOMBINER SYSTEMS LIMITING CONDITION F01 OPERATION 3.6.6.1 Two independent prim ry containment hydrogen recombiner systems shall be OPERABLE. APPLICABILITY: OPERATIONAL CONDITIONS 1 and 2. ACTION: With one primary containment hydrogen recombiner system inoperable, restore the inoperable system to OPERABLE status within 30 days or be in at least HOT SHUID0Fi within the next 12 hours. SURVEILLANCE REOUIREMENTS ~4.6.6.1 Each primary contain'nent hydrogen recombiner system shall be demon-strated OPERABLE: a. At least once per 6 months by performance of: 1. A CHANNEL CHECK of all Control Room Recombiner Instrumentation. 2. A Trickle Heat Circuit check. 3. A Heater Coil Check. ( 4. A verific'ation of valve operation by stroking all the valves to their proper pasilions. [b. At least once y y: g 1. Performing.nd.ANNEL CALIBRATION of all control room recombiner instrumentation and control circuits. e 2. Verifying the integrity of all heater electrical circuits by per ing a resistance to ground test within 30 minutes following the below l l required functional test. The resistance to ground for any heater phase shall be greater than or equal to one (1) megohm. 3. Verifying through a visual examination that there is ro evidence of abnormal conditions within the recombiner enclosure; i.e., loose wiring or structural connections, deposits of foreign materials, etc. 4. Verifying during a recombiner system functional test that the minimum heater outlet gas temperature increases to greater than or equal to ) 1150 F within 120 minates and maintained for at least one hour, y By measuring t.he system leakage rate: c. 1. As a part of the overall. integrated leakage rate test required by Specification 3.6.1.2, or 2. By measuring the leakage rate of the system outside of the contain-ment isolation valves at P, 44.0 psig, on the schedule required by a Specification 4.6.1.2, and including the measured leakage as a part of the leakage determined in accordance with Specification 4.6.1.2. LIMERICK - UNIT 2 3/4 6-57 AUS 2 5 E3

,,=,_z.. i-PLANT SYSTEMS LIPITING CONDITION FOR OPERATION (Continued), ACTION: (Continued) 4. With three E5W pump / diesel gen'erator pairs ** inopera$le, restore at least one inoperable ESW pump / diesel generator pair ** to OPERABLE status within 72 hours or be in at least HDT SHUTDOWN ithin the next 12 hours and in COLD SHUTDOWN within the following 24 hours. 5. With four E5V pump / diesel generator pairs ** inoperable, restore at least one ineperable E5W pump / diesel generator pair ** to OPERABLE status within 8 hours or be in at least HOT SHUTDOWN within the next 12 hours and in COLD SHUTDOWN wit'hin the following 24 hours. b. In OPERATIONAL CONDITIOW 4'or 5: ~ 1. With only one emergency service water pump and its associated flow path OPERABLE, restore at least two pumps with at least one flow path to OPERASLE status within 72 hours or declare the-associated safety relai.ed equipment Tnoperable and take the ACTION required by Specifications 3.5.2 and 3.8.1.2. c. In OPERATIONAL CONDITION

1.

With only one emergency service water pump and its associated flow path OPERABLE, restore et least two pumps with at least one flow path to OPERA 5LE status within 72 hours or verify 1 adequate cooling remains available for the diesel generators required to be OPERABLE or declare the associated diesel genera-tor (s) inoperable and take the ACTION required by Specifica-tion 3.8.1.2. The proyisions of Specification 3.0.3 ara.not appliceble~. SURVEILLANCE REOUIREMENTS ~ 4.7.1.2 At least the above required emergency service water system loop (s) shall be demonstrated OPERABLE: a. At least once per 31 days by verifying that each valve (manual, power-operated, or automatic) that is not locked,. sealed, or otherwise secured in position. is inRmMnct cosition. Wf. er Q6 'mo rt@us by verifying that: b. At least once 1. Each automa Tc valve actuates to its correct position on its appropriate E5W pump start signal. 2. Each pump starts' automatically when its associated diesel generator starts. 3

When handling irradiated fuel in the secondary containment.
- An E5W pump / diesel generator pair consists of an E5W pump and its associated diesel generator.

If either an E5W pump or its associated diesel generator becomes inoperable, then the E5W pump / diesel generator pair is inoperable. LIMERICK - UNIT 2 3/4 7-4 p3 2 i, liii

..~. '.. '.. - .,,'...,a. s. PLANT SYSTEMS -SURVEILLANCE REOUIREMENTS '4.7.2' Each control ' em emergency fresh air supply subsystem shall be demonstrated OPERABL' : t a. At least once per 12 hours by verifying the control room air tempera-ture to be less than or eoual to 85 F effective temperature: b. At least once per 31 days on a STAGGERED TEST BASIS by initiating, from the control room, flow throuah the HEPA filters and charcoal adsorbers and verifyino that t6em operates with the heaters OPERABLE. k At least once p r _. mon $$ ~ '[f t or (1) after any structural maintenance If on the HEPA fil ~ cnarcoal adsorber housings, or (2) following I painting, fire, or chemical release in any ventilation zone Q communicating with the subsystem by: f, . 1. Verifying that the subsystem satisfies the in place penetration l and bypass leakage testing acceptance criteria of less than 1 0.05% and uses the test procedure guidance in Regulatory Positions C.S.a, C.S.c, and C.S.d of Regulatory Guide 1.52, Revision 2, Hmh 1978, and the system flow rate is 3000 cfm i 10%. l I, .e a 5 4., ~ ( $ ? R n.[1 5 (M ill h M N E ?li M R J l ? % % i D 3, I'.. 2 5 '~' LIHERICK - UNIT 2 3/4 7-6a

+ .. _.z~., 7 --,-- e -o PLANT SYSTEMS SURVEILLANCE REOUIREMENTS (Continued) 2. Verifying witdin 31 days af ter removal that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978, for a methyl iodide penetration of less than 1%; and Verifying a subsystem flow rate' of 3000 cfm 10% during subsystem operation when tested in accordance with ANSI N510-1980.- d. Af ter every 720 hours of charcoal adsorber operation by verifying within 31 days af ter removal that a laboratory analysis of a repre-i sentative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision'2, March 1978, meets the laboratory testing criteria of Regulatory P.osition C.6.a of Regulatory Guide 1.52, Revision 2, March 197Z,.for a methyl iodide penetration cuethan 1%. I. At least. once p rg tr by: ) g,7lA e. w-1. Verifying that the pressure drop across the. combined profilter, e upstream and downstream HEPA filters, and charcoal adsorber banks is less than 6 inches water gauge while operating the subsystem at a flow rate of 3000 cfm 10%; verifying that the prefilter pressure drop is less than 0.8 inch water gauge and that the pressure drop across each HEPA is less than 2 inches water gauge. -{ l O2. Verifying that on each of the below chlorine isolation mode actua*lon test signals, the subsystem automatically switches [ to the chlorine isolation mode of operation and the isolation valves close within 5 seconds: a) Outside air intake high chlorine, and b) Manual initiation from the control roca. Verifying that ch each of the below radiation isolation mode 3.1 actuation test signals, the subsystem automatically switches to the radiation isolat. ion mode of operation and the control room l is maintained at a positive pressure of at least.1/8 inch water l gauge relative to the turbine enclosure and auxiliary equipment l room and outside atmosphere during subsystem operation with an outdoor air flow rate less than or equal to 525 cfm: I a) Outside air intake high radiation, and b) Manual initiation from control room. i i 3/4 7-7 LIMERICK - UNIT 2 3.... I

s PLANT SYSTEMS SURVEILLANCE REOUIREMENTS (Continued) /- = - - % 7. 7, c. At least once p s by: j 1. Performing a system functional test which includes simulated I automatic actuation and restart and -verifying that each-. ?k-4 (l' automatic valve in the flow path actuates to-its correct position. Actual! infection of coolant into the -reactor f. vessel may be excluded. 1 2. Verifying that the system.will develop a' flow of greate'r'than +I or equal to 600 gpm in the test flow path when steam is-supplied to the turbine-at a pressure of 150 + 15, O psig

3.

Verifying;that the. suction for the RCIC sys' tem is autcmatically. transferred from the condensate sto. age tank'to. the suppression-l -pool on a condensate storage tank water _ level-lok. signal. w _- 4.= Performing a CHANNEL. CALIBRATION of the RCIC system ^ discharge-i line " keep filled" leveT alarm instrumentation. I x. n v f. ~_ i l

The provisions of Specification 4.0.4 are not applicable provided-the surveillanca is perforaed within 12 hours after reactor stesm pressure is I

adequate to perform the tests. If OPERABILITY is not successfully demonstrated-within the 12-hour pericd, reduce reactor steam deme pressure to less than 150 psig within the.following 72 hours. 1 LIMERICX - UNIT 2 3/4'7-10 . d 2 i l!T:

e e ,. 4 j,.. _ :. l PLANT SYSTEMS g, HALON. SYSTEMS LIMITING CONDITION FOR OPERATION 3.7.6.4 The following Halon systems shall be OPERABLE with the r,torage tanks having at least 95% of full charge weight and 90% of full charge pressure: a. Remote Shutdown Panel Area 540, EL 289' (Raised Floor), and b. Auxiliary Equipment Room 542, El 289' (Raised Floor). APPLIjABILITY: Whenever equipment protected by the Halon systems is required to be CPERABLE. ACTION: - - ~ ~ a. With one or more of the above required Halen systems inoperable, within 1 hour establish a continuous fire watch with backup fire suppression equipment for those areas in_which redundant systems or components could.be' damaged; for other areas, establish an hour _ly. fire watch patrol. b. The provisions of Specification 3.0.3 are not applicable. SURVEILLANCE RE0VIREMENES (' ' 4.7.6.4 Each of the abnve required Halon systems shal'1 be demonstrated OPERABLE: a. At least once per 31 days by serifying that each valve (manual, pcwer-operated, or automatic),in the flow path is in its correct position. b. At lead once per 6 months by verifying Halon storage tank weight and prdsure. c. At least once per 18 months by: 1. Performance of a functional test of the general alarm circuit and associated alarm and interlock devices, and 2. Performance-of-a-system-f4cw-test-to-aswee-no-t4eckage - b-br -l.casr o mg R.t. 21 ~ ru.s er: ) fe,wo.<.~n a ( of 4 s v w' F ce. > 9 tT* To h o nL da d 'o t n o"- t. s l LIMERICK - UNIT 2 3/4 7-25 g.., t 5 B',1

PLANT SYSTEMS w-. 3/4.7.7' FIRE RATED ASSEMBLIES. LIMITING CONDITION FOR OPERATION '.7.7 All fire rated assemblies, including walls, floor / ceilings, cable tray 3 enclosures and other fire barriers, separating safe shutdown fire areas or i separating portions of redundant systems important to safe shutdown within a ' fire area, and all sealing devices in fire rated assembly penetrations, includin; fire doors, fire windows, fire dampers, cable, piping and ventilation duct penetration seals and ventilation seals, shall be OPERABLE. APPLICASILITY: At all times. ACTION: a. . With one or more of the above required fire rated assem'blies. and/or sealing-devices inoperable, within 1 hour establish a ' continuous fire watch on at least one side of the affected, assembly (s) and/or sealing device (s) or verify the OPERABILITY of fire detectors on at -least one side of the inoperable assembly (s) and sealing device (s) and establish an hourly fire watch patrol. b. The provisions,of-Specification 3.0.3 ath not applicable. SURVEILLANCE REOUIREMENTS-I m _ 4.7.7.1 Each of the above required fire rated assemblies and ration sealing devices shall be verified OPERABLE at least once. pg mont s by performing a visual inspection of: The exposed surfaces of each fire rated assembly. a. b. -Each fire fire damper,.and associated hardware, e I?. S '?., ' l' ' c. At le st.10Y each-type of sealed penetration, except internal. condui. -seals.. r apparent changes in appearance or abn egradations y l are found, a visual inspection of an addition-. jW'each type of 12.5 7. [I sealed _plaatr_ati estrE1 This inspec ~on process shall continue until a'Jp)1 be made. ple' with no apparent changes in appearance

12. '&

l-or abnormal deg asion is' found. Samples shall be sele er secd that each penetration' seal will be inspected at least once erJB' yea ml N ~ LIMERICK - UNIT 2 3/4 7-31 p3 ; 5 t.n

1 PLANT SYSTEMS- -3/4.7.8 HAIN TURBINE BYPASS SYSTEM LIMITING CONDITION 70R OPERATION -3.7.8 The main turbine bypass system shall be OPERABLE as determined bv the number of operable main turbine bypass valves being greater than or ec,u'il to that specified in the CORE OPERATING LIMITS REPORT. APPLICABILITY:. OPERATIONAL CONDITION 1, when THERMAL POWER is greater than er equal to 25% of RATED THERMAL POWER. ACTION: With the raain turbine bypass system inoperable, restore the system to OPERABLE status within 1 hoer cr take the ACTION required by Specifica: ion 3.2.3.c. SURVEILLANCE REOUIREMENTS 4.7.8 The main turbine-bypass system shall be demonst' rated'0PERAELE at l' east once pe : a. 31 days by cycling each turbine bypass valve through at least ene coaleta_ cycle -of full travel, w w b. >SM k I y-performing a system functional test which includes ~ TiLiliEf5 Tub'atic actuation, and by verifying that each aut:matic valve i actuates to its correct position, and I EkbydeterminingTURBINEBYPASSSYSTEMRES?ONSETIMEtobe (I c. less than or equal to the value specified in the CORE OPERATING LIMITS I REPORT. a s. LIMERICK - UNIT'2 3/4~7-33 Menda nt No. 15 l OCT24 iii

ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS 4.8.1.1.1 Each'o1 the above required independent circuits between the offsite transmission network and the onsite-Class IE distribution system shall be: Determined OPERABLE at least once per 7 days 'by verifying correct a. breakeralignmentsandindicat_edpoweravaigbility1 and py I. b.- Demonstrated OPERABLE at least unce per 36 months during shutdown by transferring, manually and automatically, unit power supply from the nrma}ci o the alterrate circu 4.8.1.1.2 Each of the above required diesel generators shall be demonstrated OPERAE'.E : a. In accordance with the frequency specified in Table 4.8.1.1.2-1 on a STAGGERED TEST BASIS by: 1. Verifying the fucl level in the day fuel tJnk.- 2. Verifying the fuel level in the fuel storage tank. 3. Verifying the_ fuel transfer pump starts and transfers fuel from the storage system to the day fuel tank. 4. Verify that the diesel can start

and gradually accelerate to synchronous speed with generator voltage and frequency at 4285-420 volts and 60 1 1.2 Hz.

f l 5. Verify diesel is synchronized, gradually loaded

to an -

L indicated 2700-2800 kW** and operates with this load for at least 60 minutes. 6. Verifying the diesel geinerator is' aligned to provide standby power to the associated emergency busses. 7. Verifying the pressure in all diesel generator air start receivers to be greater than or equal to 225 psig.

This test shall be conducted in accordance with the manufacturer's recommendations regarding engine prelube and warmup procedures, and as applicable regarding loading

.id shutdown recommendations.

- This Lband is meant as guidance' to avoid routine overloading of the engine.

-Loads in -excess of this band f.or special testing under direct monitoring by the manufacturer.or, momentary variations due to changing bus loads shall not invalidate the test. ) i L LIHERICK - UNIT 2 3/4 8-3 AUS 2 51989 L p

ELECTRICAL POWER SYSTEMS h..... j ~ SURVEILLA CE REQUIREMENTS (Continued)- b. At least once per 92 days and within 7 days after a battery discharge ~ with battery terminal voltage below 105 volts or battery overcharge with battery terminal ' . age above 150 volts, by verifying that: \\ 1. The parameters in Table 4.8.2.1-1 meet the Category B limits, 2. There is no visible corrosion at either terminals or connectors, j - or-the connection resistance of these items is less than 150 x-10 6 ohm, and j 3. -The 'averace eletrnivte temperature of each sixth cell,s > 60 F. . g y,/ At least once p r onths by verifying that: j '{j The cells, cell plates and battery racks show no visual indication of physical damage or abnormal deterioration, O2. The cell-to-cell and terminal connections are clean, tight, free of corrosion-and coated with anticorrosion material, O3. ~ The resistance of_ each cell-to cell and terminal conne less than,or equal to 150 x 10 5 ohm excluding cable intercell connections, and Th'e battery chargers will supply the currents listed below at a minimum of 132 volts for at least 8 hours: Charger Current (Amperes) ? 2BCA1 '.300.

l'.

. 1, 2BCA2 3M ' 2BCB1 300-1 2BCB2 300 2BCC 75 parn 75 d. At least once p nths, during shutdown, by verifying, that Ig either: @ The battery capacity is adequate to supply and maintain in .0PERABLE status all of the actual emergency' loads for the design duty cycle when the battery is subjected to a battery service test, or-h The battery _ capacity is adequate.to suoply a dummy load of the following profile while maintaining the battery terminal voltage greater than or equal' to 105 volts for the nominal 125-volt batteries and 210 volts for the nominal 125/250-volt batteries: ,:{ E25E . LIMERICK - UNIT 2 3/4 8-11

~

W !.I !~. h ELECTRICAL POWER-SYSTEMS G~ffi SUR'!EILLANCE REQUIREMENTS (Cont'inued) .h r, LOAD CYCLE (amps) Division Battery 0-1 Min. 1-239 Min. 239-240 Min. I-2A1 546 168 187 s' 2A2 449 129 147 W C.- -II '2B1 889 158 321 i 282 823 119 282 tr. i III '2C - 193 31 31 i V.: l IV 20 169 21 21 Each 125/250 volt battery is rated at 1500 amper hours at an. 8-hour' discharge rate, based on a terminal volta of 1.75 volts-per-cell at 77 F. Each 125-volt battery is rated at 250 ampere-hou at an 8-hour i discharge rate', based on a terminal voltage of 1 ~5 volts per-cell .43 at 77 F. Y r, e. At least' once per 60 months during shutdown by v ifying that the battery capacity is at.least 80% o.f the manufact er's rating when subjected-to a performance discharge test. A,t t s once per 60 month interval, this performance discharge test may be erformed in lieu of -the battery serdfra +ast (Soecification 4.8.2.1. <t C ~ .W ) '"~ i 3. 9 ggy,/ f. .At least once er)sponths during shutdown perf mance discharge l tests of batte -apacity shall be given to any ttery that shows signs. of degradation or has-reached 85% of the s vice life expected 1 for the application. Degradation is indicated w n the battery capacity drops more than 10% of rated capacity f m its average on previous performance tests, o'r is below 90% of t manufacturer's rating. 1 L v' l-LIMERICK - UNIT 2 3/4 8-12 MB 2 5 M3 ic

3, g, 7 ;---- - ., a. .w 1.. ELECTRICAL POWER SYSTEMS i MOTOR-OPERATED VALVES THERMAL OVERLOAD PROTECTION LIMITING CONDITION'FOR OPERATION 3.8.4.2 Tha thermal overload protection of all Class Emotor operated valves

shall be either:

I Continously bypassed f6Y all valves with maintained position control a. switches; or, b. Bypassed only under accident conditions for 21 valves with spring-return-to normal control switches. Nheneverthemotoroperatedvalveisrequiredto'beOPERABLE. APPLICASILITY: ACTI0f.. Wik.h the thermal overload protection for one or'more of the above required l valves not bypassed continuously or only under accident conditions, as applicable, restore the thermal overload bypass within 8 hours'or~ declare the affected valve (s) inoperable and apply the appropriate ACTION statement (s) for the affected system (,s). SbRVEILLANCEREOUIREMENTS 4.8.4.2.1 The thermal overload protection for the above. required valves which are continuously bypassed and temporcrily placed in force only when the valve motor is undergoing neriodic or maintenance testing shall be verified to be bypassed following periodic or mai te 'nce testing during which the thermal S overload protection was tempo _rT]y pl ced in force. g, e _- 4.S.4.2.2 At least once .r')Si ans, a CHANNEL FUNCTIONAL TEST of all those valves which are bypassed o y under accident conditions (valves with spring-return-to normal control switches) shall be performed to verify that the thermal overload protection will be bypassed under accident conFtions, h- -LIMERICK - UNIT z 3/4 E-27 5252

- - - = - -. Subs:.di6ns e.xa i Oc_ FA b Per " E 34 7 ELECTRICAL POWER SYSTEMS (s i m t once ave.ry 2.4 4 BASES \\ s ___ A A.C. SOURCES, D.C. SOURCES, and ON511E POWER DISTRIBUTION SYSTEMS (Continued) Supplies," March 10, 1971, Regulatory Guide 1.137 " fuel-Oil Systems for Standby Diesel Generators," Revision 1, October 1979 and Regulatory Guide 1.108, " Periodic Testing of Diesel Generator Units Used as Onsite Electric Power Systems at Nutlear Power Plent<," Revision le August 1977, except for paragraphs C.2.a(3), C. 2. c(1), C.2.c(2), C.2.d(3) and C.2.d(4). The exceptions to Regulatory Guide 1.108 allow for gradual leading of diesel generators during testing and decreasca seveillance test frequencies (in response to Generic Letter E4-15). The surveillance requirements for demonstrating the OFERABillTY of the unit batteries are in accordance with the recommendations of Regulatory Guide 1.129 " Maintenance Testing and Replacement of Large lead Storage Batteries for Nuclear Power Plants," hbruary 1978 and IEEE Std 450-1930, "lEEE Recommended / Practice for Maintenance, Testing, and Replacement of Large Lead Storage Batteries for Generating Stations and Substations."g Verifying average electrolyt.e temperature above the minimum for which the battery was sizec, total be'.tery terminal voltage on float charge, connection resistarce values and the performance of battery service and discharge tests ensures the effectiveness of the charging system, the ability to handle high discharge rates and compares the battery capacity at that +ime with the rated capacity. Table 4.8.2.1-1 specifies the normal limits for eat designated pilot ' cell and each connected cell for electrolyte level, floa, voltage and specific gravity. The limits for the designated pilot cells float voltage and specific gravity, greater than 2.13 volts and 0.015 below the manuf acturer's full charge specific gravity or a battery charger current that had stabilized at a low value, is characteristic of a charged cell with adequate capacity. The normal limits for each connected cell for float voltage and specific gravity, greater than 2.13 volts and not more than 0.020 below the manuf acturer's full charge specific gravity with en average specific gravity of all the connected ceiis not more than 0.010 below the manufacturer's full charge specific gravity, ensures the OPERABILITY and capability of the battery. Operation with a-battery cell's parameter outside the normal limit but within the allowable value specified in Table 4.8.2.1-1 is permitted for up to 7 days. During this 7-day period: (1) th' allowable value for electrolyte level ensures no physical damage to the plates with an adequate electicn trar.sfer capability; (2) the allowable value for the average specific gravity of all the cells, not more than 0.020 below tha :.ianuiccturer's recommended f eil charge specific gravity 2nsures that the dectease in nting will be less thar. the safety margin provided in sizing; (3) the allowable veh wr en incividuai cell's specific gravity, ensures that an individual cell's specific gravity will not be more than 0.040 belew the manufacturer's full charge specific gravity and that the overall capability of the battery will be maintaine: within an acceptable limit; and (4) the allowable value for an indisidual cell's float voltage, greater than 2.07. volts, ensures the battery's capa-bility to perform its design function. LIMERICK - UNIT 2 B 3/4 8-2 M*25 C

i s. .e. CONTAINMENT SYSTEMS BASES 3/4.6.5_ SECONDARY CONTAINMENT Secondary containment is designed to minimize any ground level release of radioactive material whic'h may result from an accident. The Reactor Enclosure and associated structures provide secondar when the drywell is maled and'in ser*vice.y containment during normal operation At other times the drywell may be open and, when required, secondary containment integrity is specified FM_ Establishing and maintaining a vacuum in the reactor enclosure / secondary cor.tainment with the standby ges treatment system once per1STmonths, along with the surveillance of the doors, hatches, dampers and valves, is adequate to ensure that thern are no violations of the integrity of the' secondary containment. The OPERABILITY of the reactor enclosure recirculation system and the standby gas-treatment-ystems ensures that sufficient iodine retovai cap;oility will . be-available in the event of a LOCA or refueling accident ($GTS.mly).- The reduction in containment iodine inventory reduces the resultinc, SITE BOUNDARY radiation doses associated with containment leakage. The operation of this system and resultant iodine removal capacity are consistent w th the assumptions used in the LOCA and refueling accident analyses. Provisions have been made to continuously purge the filter plenums with instrument air when the filters are not in use to prevent buildup of moisture on the adsorbers and the fiEPA filters. .y. Although the safety analyses assumes that the reactor enclosure srcondary containment draw down time will take 135 seconds, these surveillance require-ments specify-a draw down time of 121 seconds. This 14 second difference is due to the' diesel oenerator starting 'and sequence loading delays which is not part of this survelliance requirement.- The reactor enclosure. secondary containment draw down time. analyses ass'umes a starting-point of 0.25 inch of vacuum water gauge and worst case SGTS dirty f filter. flow rate of-'2800 cfm._ The surveillance requirements satisfy this as-sumption.by starting the drawdown from ambient' conditions and connecting the adjacent reactor enclosure and refueling area to the SGTS to split the exhaust flow between the three zones and verifying a. minimum flow rate of 2800'efm from the test zone. ' This simulates the worst case flow alignment'and verifies ade-quate flow.is available to drawdown the test zone within the reqrired time. L - The Technical Specification Surveillar:e Requirement 4.6.5.3.b.3 is intended to be a multi-zone. air balance verification without isolating a v test zone. The SGT5 is common to Unit I and 2 and consists of two independent subsystems. The. power suppif es-for the common portions of.the subsys' ms are from Unit-1 safeguard busses, therefore the inoperability of these Un t-1 supplies are addressed in the SGT5 ACTION statements in order to ensure adequate onsite power sources to SGT5 for its Unit 2 function during a loss nf offsi$ l power event. - The allowable out of service times are consistent with those in --the Unit-1 Technical Specifications for SGTS and AC electrical power supply out of service condition combinations. l LIMERICK - UNIY 21 B 3/4 6 ' 25251R i e w + w w.i--w.e-- e + s ~ = ,e,.:,-e--- --we w

ADMINISTRATIVE CONTROLS PROCEDURES AND PROGRAMS (Continued) 6.8.4 The 'following programs shall be established, implemented, and maintained: a. Primary Coolant Sources Outside Containment A program to reduce 1:akage from those portions of systems outside containment that could contain highly radioactive fluids during a i serious transient or accident to as low as practical levels. The systems include the cors spray, high pressure coolant injection, reactor core isolation cooling, residual heat removal, post-accident sampling system, safeguard piping fill system, control rod drive scram discharge system, and containment air monitor systems. The program shall include the following: 1. Preventive maintenance and periodic visual inspectir1 requirements _,g fja # d 2. Integra'ted leak test requiremen'ts for each system at refueling i c f urf c

cycle intervals or less.

b. In-Plant Radiation Monitoring A program which will ensure the capability to accurately determine the airborne itdine concentration in vital areas under accident conditions. This program shall include the following: 1. Training of. personnel, 2. Procedures for monitoring, and 3.- Provisions for maintenance of sampling and analysis equipment. c. Post-accident Sampling A prograia which will ensure the capability to obtain and analyze reactor coola~nt, radioactive iodines and particulates in plant gaseous efflu-ents, and containment atmosphere samples under accident conditions. The program shell include the following: 1. Training of personnel, 2. Procedures for sampling and analysis, and 3. Provisions for maintenance of sampling and analysis equipment. / -s LIMERICK - UNIT 2 6-14 AUG 2 5193) .}}

ML20104A441

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