ML20077L412
| ML20077L412 | |
| Person / Time | |
|---|---|
| Site: | Salem  |
| Issue date: | 08/02/1991 |
| From: | Public Service Enterprise Group |
| To: | |
| Shared Package | |
| ML18096A198 | List: |
| References | |
| NUDOCS 9108120212 | |
| Download: ML20077L412 (105) | |
Text
Paf: IG 90-15 ATDOMNr 2 INSERIS AND MMUTD-UP 'IS PNES o108120212 910802.{.:,
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F
l keference: LCR 90-15 INSERTS FOR LICENSE CONDITIONS AND TECilNICAL SPECIFICATION - 6 9_.3 INSERT 1 - LICENSE CONDITION 2.C. (S) FOR UNIT 1 AND 2.C. (10) FOR UNIT 2 "PSE&G shall implement and maintain in effect al'1 provisions of the approved fire protection program as described in the Updated Final Safety Analysis Report for the facility through Amendment 12 and as described in its submital dated August 2, 1991 and as approved in the Sr.R dated (.....
to be inserted by NRC.....), subject to the f ollowing provision:
PSE&G may make changes to the approved tire protection program with out prior approval of the Commission only 11 those changen would not; adversely affect the ability to achieve and maintain safe shutdown lu the event of a fire."
INSERT 2 - T_S 6.9.3 "6.9.3 Violations of the requirements of the fire protection program described in the Updated Final Safety Analysis Report which would have adversely affected the ability to achieve and maintain sate shutdown in the event of a fire shall be submitted to the U. S. Nuclear Regulatory Commission, Document Control Desk, Washington, DC 20555, with a copy to the Regional Administrator of the Regional 0111ce of the NRC via the License Event Report System within 30 days."
INDEI LIMITING CON 0!TIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS SECTION PAGE 3/4.7 PLAMT SYSTEMS 3/4.7.1 TURBINE CYCLE Safety Valves.....................
3/4 7 Auxiliary Feedwater System 3/4 7-5 Auxiliary Feed Storage Tank..........
3/4 7 7 Activity-3/47-8 Main $ team Line Isolation Valves....-.......
3/4 7-10 3/4.7.2 STEAN GENERATOR PRESSURE / TEMPERATURE LIMITAT'!ON 3/4 7-14 3/4.7.3 COMPONENT COOLING WATER SYSTEM 3/4 7-15 3/4.7.4 SERVICE WATER SYSTEN 3/4 7-16 3/4.7.5-FLOOD PROTECTION 3/4 7-17 3/4.7.6 CONTROL ROOM EMERGENCY AIR CONDITIONING SYSTEM.....
3/4 7 18 3/4.7.7 AUXILIARY BUILO!NG EXNAUST AIR FILTRATION SYSTEM
- 3/4.7-22 3/4.7.8 SEALED SCURCE CONTAMINATION.....
3/4 7 26 3/4.7.9
_ SNUBBERS 3/4 7-28 g
/
-?f4Tf710 FIRE SUFF^ES5ieM-5YSTEMS-Fir; !vepreest:n.Wter Sy$ tem -.
U4-M4-
..-r.
3;r:y--and/se-Sp*' M !e-System........
344_.l 2L Low Pr;;sure C0g Systems '...............
H+-MF "lft Meie Stet 4999
.i.....
3 P 7-10 3/4.7.14
?CNE-TR Aff0M-fiRC-BARRIERS W 4-7 42-l i
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SALEM - UNIT 1 V[I Amendment No. 59 i:
9 INDEX St. sis SECTION PAGE 3/4.7 PLANT SYSTEMS 3/4.7.1 TURS I NE CYCLE
.................... B 3/4 7-1 3/4.7.2 STEAM GENERATOR PRESSURE / TEMPERATURE LIMITATION.... B 3/4.7.3 COMPONENT COOLING WATER SYSTEM
............ B 3/4 7 4 3/4.7.4 SERVICE WATER SYSTEM
.............. S 3/4 7 4 3/4.7.5 FLOC 0 PROTECTION
................... B 3/4 7-5 3/4.7.5 CONTROL ROCM EMERGENCY AIR ' CONDITIONING SYSTEM S3/47-5 x
3/4.7.7 AUXtLIARY BUILDING EXHAUST AIR FILTRATION SYSTEM B 3/4 7-5 3/4.7.3 SEAL!D SOURCE CONTAMINATION.........
B 3/4 7-5 3/4.7.9 SNUBBERS
....................... B 3/4 7-6 t/
3/4.7.10 7:RC 17?RES-SIO" SYCS" J..
3/1 7 7 -
3/1.7.11
?CMETRATI M-ffRE 4 ARefERS............... 5 -ttt 7 3/4.3 ELECTRICAL POWER SYSTEMS 3/4.3.1 A. C. SOURCES and ANO 3/4.3.2 CNSITE PCWER OISTRIBUTION SYS7 EMS..........
B 3/4 3-1 IALIM - wi!T 1
( ;'t amencren: No. 59 c
k JNSTRUMENTATION BASE 5 c
'1
.3.5 FIRE DETECit0N INSTRUMENTATION OPERASILITY o.- fire cetection instrumentation ensures th quato arnias capability is ava1ID%-Qr tne prompt detection of 'pae'4This capacility is required in order to detect.
locate fires i htTr early stages. Dromet te-taction of fires ntll reduce the p i
damage to safety related equis-ment and is an integral element ir,a ov.qility fire protection :cogrim.
In the event tnat a a
.. n of :ne fire detection insI?%
ation is inocerable, the establi jsne.
frequent firt patrols in the affected are requirec to provid netTction capability until the inoperable instrumentation is.
- orec to J-IL ITY.
3/4.3.3.7 ACCIDENT MONITOR!NG. INSTRUMENTATION The CPERABILITY of the accident monitoring instrumentation ensures that suf fi-cient infornation is available on, sal.ected prant carameters to monitor and assess these variables following an acticent. This cacability is consistent with the Recommendations of Regulatory Guide 1.97, " Instrumentation for Lignt.
Water-Cooled Nuclear Dower Plants to Assess plant Conditions During and Tollowing an accident,' Oecemoer 1975.
3/4.3.3.5 RA0!0 ACTIVE L10010 EFFLUENT MONITORING INSTRUMENTATION The radicactive liquid effluent instrumentation is provided to monitor anc con.
trol, as acclicaole, the releases of radioactive materials in liquid effluents during actual or potential releases of liquid ef fluents. The alarm / trip set-
~
acints for tnese instruments shall be calculated and adjusted in accordance nita the procedures in the 00CM to ensure that the alarm /tric will occur prior to exceecing the limits of 10 CFR part 20. Tne OPERABILITY and use of tnis instru-mentation is consistent with the requirements of General Design Criteria 50, 53, c
and 64 of accencix A to 10 CFM part 50. The purcose of tant level indicating devices is to assure tne detection anc control of leats tnat if not :ent.ollee coulc cotentially result in tne transport of radioactive materials to UNRESTRICTED AREAS.
3/4.3.3.9 RA010ACitVE GASECUS EFFLUENT MONITORING tN5TRUMENTATIO,N The racioactive gaseous ef fluent instrumentation is provided to monitor anc :en-trol, as applicaole, tne releases of radioactive mateciais in gaseous ef flueats curing actual or potential releases of gaseous ef fluents. The alarm /tric set-points for these instruments snall be calculatest and Jajusted in accordance niin the ;rocedures in tne 00CM to ensure that the alarm / trip.tll occur crior to eaceeding cne limits of 10 CFR Part 20.
fhis instruman acion also incluces :ro-visions for menttoring (and controlling) the concentestions of cotantially exolosive gas mixtures in tne aste gas helduo systen. The Op!RASILIT aad ase of int s instrumentation is consistent air.n :no requirements of 3eneral test;n Oriteria 60, 53, sne 54 of accendix 1 to 10 CFR set in.
3ALEM - UNIT !
3 3/a 3-3
- mencment No. 39 l
PLANT SYSTEMS I
BASES SNUBBERS (Continued)
To provide assurance of snubber functional reliability, a representative I sample of the instC led snubbers will be functionally tested during plant shutdowns at 18-month intervals.
Observed failures of these cample snubbers l
shall require functional testing of additional units.
Permanent or other exemptions frem the surveillance program for individual snubbers may be granted by the Comission if a justifiable basis for exemption is presented and, if applicable, snubber life destructive testing was performed to qualify the snubbers for the applicable design conditions at either the completion of their fabrication or at a subsecuent dats.
Snubbers so exempted shall be lirted in the list of individual snubbers indicating the extent of the exemptiona.
Hydraulic snubbers and mechanical snubbers may each be treated as a different entity for the above surveillanco program.
The service life of a snubber is evaluated via manufacturer input and information through consideration of the snubber service conditions and associated installation tr.d maintenance records (newly installed snubber, seal r9placed, spring replaced, in high radiation area, in high temperature area, etc...).
The requirement to conitor the snubber service life is included to annure that the snubbers puriodically undergo a performance evaluation in view of their aga and operating conditions.
These records will provide statistical bases for future consideration of snubber service life.
The requirements for the maintenance of records and the snubber service life review are not intended to affect plant operation.
y 54.7.10 FIRESUppRESSIONSYSTBdf T
ERABILITY of the fire suppression systems ensures that
'a t e fire sware on capability is available to confine and extin
.uipment is l
ires occurringinan) ortion of the facility where safety-relat located. The fire ression system consists of the se system, spray l
and/t.,r sprinklers, CO2, d fire hose stations.
The lective capability of I the fire suppression system 4s adequate to mini potential damage to safety-related equipment and is major elem in the facility fire protection program.
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I In the event that portions of a fir uppression systems are inoperaole,l ;
alternate backup fire fightin
.uipmentisrDdredtobemadeavailablein the affected areas until t inoperable equipment restored to service.
In the event fire suppression wat6r system become noperable, immediate corr ve measures must be taken since this systeri vides the major fire pression capability of the plant.
The requirement b r a 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> i report he Comission provides for prompt evaluation of the acceos ty of corrective measures to provide adequate fire suppression capabili
'or continued protection of the nuclear' plant.
SALEM - UNIT 1 B 3/4 7-7 Amendment No. 93
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PLANT SYSTEMS BASES-37t:4J1 PENETRATION FIRE BARRIERS The-funct integrity of the penetration fire b 1s ensures that fired will be confin adequately retarded fro ending to adjacent portions of the facility, design feat single fire rapidly involving se e 1 nimizes the possibility of a s of the facility prior to detection and extinguishment.
The penetr the facility fire protect triers are a passive element in rogram and are et to periodic inspections.
During p.ap s of time when the barriers are not fun kat. a l
continyous' Tire watch is required to be maintained in the vicinTty
_ghtled barrior until the barrier is restored to functional status.
the 2
SALD4 - UNIT 1 B 3/4 7-8 Amendment No. 93
l 20MIMISTRAf tyt CONTROLS 6.1 RES PONS!BILIT t The General Eanager - Salem Ocerations shall te responsible for wer 11 e l.1 f acility operation and snall celegate in = citing the sue:ession to tnis. es:en.
sicility during his absence.
6.1.2 The Senior Nuclear Shift Supervisor or, during his aosence from tne Control Roorn, & otsignated individual shall be responsible for the Control Room cortnand function. A managernent directive to this ef fect. Signed by the Vice President - Nuclear, snall be reissued to all station personnel on an annual basis.
6.2 ORGAN @ TION OFF5 TTY 6.2.1 The of fsite organization. for facility ennagement and technical support shallc be as stuwn on Figure 6.2-1.
FACILITY STAl[8 6.2.2 The Facility organization shall to as shown on Figure 6.2-2 and Eaca on duty shif t shall be comoosed of at least the minimum snitt a.
crew cwposition shown in Table 6.2.L.
At least one licensed Operator shall be in the control room when fuel b.
is in the reactor. In addition, at least one licensed Senior Reactor Ocerator shall be in the Control Room area at all tirnes.
l A health pnysics techniciand shall be on site when fuel is in the c.
re actor.
d.
ALL CORE ALTERATIONS shall be observed and directly sucervised 3y a licensed S'enior Reactor Operator who has no otner concurrent responsi-0111 ties during this operation.
144E. ire Brigade of at least 5 members snall te rei aimed-eMTft at all tinehf4 Brigaoe shal1Jat tmekter" neers of the minimum shift crew ney
'Qtdown 6f the unit or any 1
perso Dnnekut*T$r other essential funciiiun.Qfire i
-. - -e'efriiiincy.
N f.
.The amount of overtime wrked by p1 ant staff caneers pseforming safety-related functions mst be limited in accordance witn the NRC Policy Statteent on wrking hours (Generic Latter No. 82-12).
Eneaita onysics tec.nnician aee-F4re-Brigede-camposition may te less than the I
minimum requirements tor a period of tima rot to exceeo 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> in orcer to accorrwodate unexpected absence of the health pnysics tecnnician and/or Fire 3rigade meneers provided insnediata action is taken to restore the health pnysics tecnnician and/or Fire Brigace to within the minimure requirements.
1 SALM - uMIT 1 6-1 k mndment No. 62 1
aCMINI5rzaTIVE COMTROLS
(
- 6. 2.' 3 SHIFT TECHNICAL 20VISCR 6.2.3.1 Ibe Shif t Technical Advisor shall tarve in an advisory CADacity O *e Shift sucervisor on satters percatning to tr.a engiretring ascocts assuring saf e operation of tua unit.
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5.2.3.2 The Shift Technical Advisor shall have a Bacnolor's Degree nr equivalent in a scientific or engineering disctDline~with $0ecific triining 11 plant casign and response and analys11 of the plant for transients and accidents..
6.3 Fac tLITY STAFF CtL4LIFICAT10h5 5.3.1 Eaca namner of the facility staf f snall met or exceed tra mnir um quali fications of ANSI M18.1-1971 for <nsparaole positions and tne supolecental recutrements soec1f ted in Sections A and C of Enclosure L of toe.'*aren 28, 1960-MAC letter ' en all I tcansees except for tne Raat atton Protection Engineer am snall met or_ exceed tne qualif1 cations of Regulatory-Guide 1.8. Septemeer i.975.
5.4 Tu !NING' i
6.4.1 A retraining and reclacament training program for the facility staf f snall ce cooroinacee by each functional letel manager -(Department Head) at tne ficti f ty and _ neintained under the direction of the Manager - Nuclear _ Testning and snall meet or 'excaed the requirements ar i recereendations of Section 5.s tf AN5! N18.14971 and Appendix *A* a f 1.0 CFR Pet 55 and-the -supplerental esquireweents scacifieduin Sections A:and C of Enclosure 1 of tne Maren 23, 1980 NRC Tetter to all-- licensee 1. and shall incluae familiarization witn relevant ircustry operational experience.
v.rM w g r the Fire Brigace shall ta g i W we C.e 6.4.2 4
direction of the Manager
.mu,;r M m-t.Wmet _or excnec tre requiremnts of Sec+1on._21M Mm boe,. < 6 m.Mg,,f t re Brigace ' traini ng c
,, g s ito w arr 5 a 1 ee Held at least quarterly.
m,
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3 SALEN - tJNIT t=
6-4
,eencuent No. 52 i
..1-w
j gtNt37tATQtCONTROL3 s.
Type of container (e.g.. L3A, Type A, Type B. Large Quantity), and f.
Self df ficatim agent or esorbent (e.g., cement, urse formaldahyde),
the Radioacttw (ffluent Release Roorts sh411 intlade a list of description of unplanned releases frtue t.he sit 4 te UNR13TRICTI(D AR8A3 of radtsactive materials in gaseous and 11guld effluents medo 4 ring the esperting perled.
Tim Radinesttn Iffluent Release Reports shall tn'tlade my canged mede durkng the tworting period to the P90CE33 Colmt0L PR04l TAM (pCP) and to the OFF3!TT 0038 CALCR.4t!ON MMWAL (0008), as well as a itsting of new locations for dos.
caleeletisme and/or envirgamental menttoring identified Iqr the lud use census pursuaMt to Specificatten 3.12.2.
'.EIGMi EEU.
(.9.2 Special' reports shall ~ be subsitted to the Adaintstrator of the dagional Offism withfe the staa perfod speciftet for each report.
~
INSER 2 g,1g agqq q agyggygga
!a.nm. = thu 4.piioni. rund retenti. re,uir nts a Tiue lo. c e a Federti Rossistimts, the folloarteg regards shall be retined far at least-the af alama period imettated.
(.10.1 1% following rearen shall be retained fnr at least five yearn; a.
Records and legs of mit operation covecing time interval at each power level.
D.
Records et less of prin41541 maintenance activities inspsettons,
~
re$str and replacement of principal itses of equipment related to nuclear safety.
c.
ALL 200RTAat.E GCOntR8M25 submitted to me Camrtsrion.
d.
Reearts $f survet1lanca. activities, inspections ud calibrettens requiref. Iqf these fecanical Joecif1castass.
Esseres of encter tests and neeriennes.
f.
Eweres of danges ivede to Operatttty Procedums required by
$peciffcwton 6.4,1.,
g.
Recsets of rodfeactive shipments.
.t.
P.ecards af sealed saurea and fission detector lean tests and results.
f.
Records of annual pnysical inventary of all setled source antarial of rscar tf.
3M.Dt. UNIT 1 6 21
.Moncment No.
m m
..~
INan_
UNITimt ccMot71CNS FOR OPf.tATION AND WRYTILLANCE REQUtR&DTS stertes
!ag
-3/4.2 PfwtR 07.sntarrtex _ LIMIT 3 3/4.2.1 A2!M, F1M 01FFULDCE.............*...
3/4 2-l' 3/4 3-5 3/4.2.2 HEAT FLUX HOT CMMtNEL FACTOR 3/4.2.3 AC3 FLGi RATE MS R.........
3/4 2-1
' 3/4.2.4 UUADRANT POWER TILT RATIO...............
3/4 2 13 3/4 2 16 3/4.2.5 ONS PAROdTERS.......,............
3/4.3 tMS_TRt M NTATION 3/4.3.1 REACICR 317 $YSTM IM1TRUMENTATION..........
3/4 3-1 3/4.3.2 EM1*TtED SAFETY FtATURE ACTUATION 37572 3/4 3-14 IRSTRemETTAtt3t...................
3/4.3.3 MMITmtING IM3TR'MD(TATICN Nadiation Monitatig Inst 56 tion 3/4 3 38 3/4 3 42 Mcvaale Iacott De*,wtars....,..........
3/4_3 43 V
Ramste 3Am tastruega_ tat 1_on...
... x,...
2/2 2 't
'}
--F4.9 *r rie:: L. t. - - net:::.... wr r.-v r.
~~~~3sifiest Manitoring Instnmaatation..........
3/4 3-50 Radieestive Liarid Effluent Monitsetag Instrumentatina.
3/4 3-53 Radteacttwo $4was Eff%wt Noaitertny tastnamentatica 3/4 3 59 i
3/4.3.4 TUR81NE OVERSPt2 Pikmer,iiC4 3/4 3-45 SALIM - UNIT 3 IV heenement No. 28 l
l
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.x IN0(1 L!M!TthG C0ytTION,$ FCR 070Af!0N AMG $URYtfLLAnct tt0V!Rt*OTS,
$1 city 8AGt 3.4Er punt sYsrtM_s, 3/4.7.1 T1Jd8txt CYCLE 5NatyValves.....................-
3/4 1 1 3/4 1 5 Awatifary Feedwater Systan Aus f 1 t a ry Feed S t orag e Ta r*..............
3/4 1.7 3/4 7 8 Activity Male. Steam Line Isotation V4fv,3 3/4 1.to 3/4.7.2
$ TEM GODAWR r:lt3.SURE/TEMPUATURE LIMITATION....
3/4 7 11 3/4.1.3 Cb:4P0hMT COOLING WAftA $YSTDI 3/4 7 12 1/4.7.4
$tRYtCE WAftX SYSTEM 3/4 7 13 3/4.T.S A.000 PROTICT!ON 3/4 7 14 3/4.7.6 CCNTROL ROOM cMUGENCT AIA CCN0!Tt0 MING SYSTEM 3/4 7-15 l
3/4.7.7 AU2t!.tARY 80!!.CtnG _IIHAUST AIR FILTRATION SYSTEM 3/4 7.18 l
3/4.7.8 5DLED 50VRCE CONTAMINAf t0M.......
3/4 7 71 3/4 7 23 3/4.7.9-5m:88tt$.......................
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~~1/tt:10-f ttt1PMt!$2ftlWtiY$T9tfr- --
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1/a 7.31 484+-4*eeeeeaten Jeatsr4ystas- ;
-3f44=P Set'et-entfer4tr4rmfer-Systen.
-- --Lre*4**Sevee-40 4ystems--,. v
.1/L l.1A t
---.-54 e*4ew,$44t(ev..
1/L2 lt h
--4/44rH-4(MGRAT10M4 sat-ilAAAIGS, r.
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$AttM. un!T 2 vt!
Amendment No. 28 i
I d
INDEI iAsts
=
E cg PAG lt E
3/4.7 9t,,/MI,, E74, 3/4.7.1 TUWstM CTCLE,.... o..............., 8 3/4 7-1 3/4.7.f.
STIM MNDAT!51 PRt33URE/T1DWtRATURE LIMITATION.... 4 3/4 7 4 I 3/4 7.4 3/4.7.3 f.twCNENT CDOLIM EftR SYSTIM
=,.........
R 3/4 7 4 3/4.7.4 35VICE ETIR SYSTIM
'3/4.7.8
. Pt000_ PROT CTION_.........-.......... I 3/4 7-8 3/4.7.8 CONTROL ADON EMER4DCT AIR CON 0!TIch!M 3YsTEM...
8 3/4 7-5 ts 3/4.7.7 A411!L!ARY WILO!M CmAUST AIR FILTRATION $YSTEM 8 3/4 7-5 3/4.7.4 SEALED SURG CCNTANINATION.. -....,........ 8,3/4 7-5 3/4.7.9 w tetRS......................
8 3/4 7 L/
w
/44r19-FIAG-mPPA&51144-575fEMB.,
.....,...... - 44/4-N-
'3 /.4. 7.11 -- PtMTRATION FIRE 8AAR!ERS............... 3 3/4 7-4 3/4.8 ELECTRfCAL POWR inivii 3/ 4.2.1 :
A. C. SOURCE 3 amt AM
'3/4.8.2 QNSITE POWR QISTRIBUTION STTTEMS........... 8 3/4 8-1 3/4.3.1 TLECTRICA !QUIPMENT PROTICTIVE DEVIC 13........ B 3/4 8.1' i
SALEM - UMtf 3 XIV Amendaant No. 28 i
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4 INSTRUMENTATION BASES 3/4.3.3.2 MOVAOLE INCORE DETECTORS The OPERABILITY of the movable incore detectors with the specified minimum complement of equipment ensures-that the measurements obtained from use of this system accurately represent the spatial neutron flux distribution of the reactor core.
The OPERABILITY of this system is demonstrated by irradiating each detector used and normalizing its respective output.
N For tSe purpose of measuring f (Z) or F a full incore flux esp is used.
q g
Quarter-c. ore flux maps, as defir.ed in WCAP-8648, June 1976, may be used in recalibration of the excore neutron flux detection systes, and full incare flux maps or syneetric incore thimbles may be used for monitoring the QUADRANT POWER TILT RATIO when one Power Range Channel is inoperable.
3/4. 3.3. 3 - SEISM'.C INSTRUMENTATION NOT REQ!!! RED 3/4.3.3. 4 METEOROLOGICAL INSTRUMENTA110N NOT REQUIRED 3/4.3.3.5 REMOTE SHUTDOWN INSTDUMENTATIDH The OPERABILITY of the remote :hutdown instrumentation ensures tnat sufficient' capp111ty is availaDie to p9rmit shutdown and asintenance of HOT STAN00Y of _ the facility from locations outside nf the centrol room.
This capability is required in the event control roca habitability is lost and is J
consistent with General.DesiDn Criterion 19 of 10 CFR Part 50.
v/
./
4,144.6, FIRE DETE0 TION INSTRUMEMTATION
',k OPERMill1TV4f the fire detection irstrumentatinn ensures th3badt4u' ate warning capability Tn-atallable for tha prompt detection o[J4rifs.
This capabilit.y is requ!rud in'?ndetto detect and locataJifss in their early
=ta(jes. Prompt detection of fireVwQ1_ redurs-ttfe' potential fur damage to safety related equipment and in an 1 te@rtLalpN ment in the overall facility fire protection program.. y'3 In the event that-a' portion of the fire detectioDristnoent& tion is innperculeJa'e,stablishment of frequent fire patrols in the It'fectqd areas is 'eguireid to provide detection capabi'lity until the inoperable instrumentation is~ restoreOL,0PEHABILITY.
[]5, 3/4.3.3.7 ACCIDENT MONITORING INSTP.UMENTATION The OPERAGILITY of the accident monitoring instemanntation ensures that sufficient information is available on selected plant p Arnmeters to monitor and assess these variables following an accident..This capability is consistent wit.h the Reccessendations of Regulator Guide 1.97, " Instrumentation for Light-Water Cooled l<uclear Power Plants to Assess Plant Conditions During and Followint; and Accident? Decembr 197S and NJREG-0578, "T14I-2 Lessons Learned Task Force Status Report and Short-Term Reconoundations."
SALEM - UNIT 2 8 3/4 3-2
ase.
PLANT SYSTEMS 1
BJSES SNU88ERS (Continued)
The service life of a snubber is evaluated via manufacturer input and information through consideration of the snubber service conditions and associated fastailatior, and maintenance records (newly installed snubber, seal replaced, spring replaced, in high radiation area, in high temperature area, etc...).
The requirement to monitor the snuuber service life is included to ensure that the snubbers periodically undergo a performance evaluatinn in view of their age and operating conditions.
These records will provide statistical baser, for future consideration of snubber service life.
The requirements for the maintenance of records and the snubber service life review not intended to affect plant operation.
//
' c__
, 3#. 7.10 FIRE SUPPRESSION SYSTEMS
,/'
s s
The,0PERA0!LITY ci the fire suppression systems ensures that adequa}V fire supp'hmsion capability is available to confine and extinguish fip6 occurring in%ny portica of the f acility where safety-related equ,ipmfnt is located.
The fi suppression system consists of the water syyttm, spray, and/cr sprinklers, k and fire hose stations. The collec safety related equipment artd is a major element in t.be',
the fire suppression tyltems is adequate to minimize po ial damage to q
facility fire s
p*ntection progralr.
's
/
s' N In the event that portions of tha firys/
s uppression system are inoperable, s
alternate tackup fire-tighting equipmepb<y required to be made cwailaLle in s-the affected areas until the inoperybfe equbqer.t is rectored to service. When I
the Inoperable fire fighting eqgiptnent is intendqd for use as a backup means of fire supprassion, a longepq1eriod of time is aMaged to provide an alternate means of firu fighting tyvr if the inoperable equipmeht is the primary meatis of
/.<
s's' fire suppression.
In the evp [the fire suppressfoo water system he:u m i %erable,
.immediate c s the maDr fipc'prfective measures must be taken since this systen provt suppression capab-ility of the plant.
The requirement for
')4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> repopVto the Consission provides for prompt evaluation of the acceptabiNQ
/.__The continued protection of the nuclear plant.okthe correctivv SALIM - UNIT 2 B 3/4 7-7
PLANT SYSilNS BASES est
- r 37 (7.11 PENETRATION FIRE 5ARRIERS ThelPERABILITY of the penetration fire, barriors ensures N
{
j will be confined'or adequately retarded f*on spreading to ad.iacent portions t
of the facility. 4his design feiture minimizes the passibility,of'a single i
fire rapidly involvGiNeven1 areas of the racility prior tevetection 4
and extinguishment.
TheD<ttietration fire barriers are a-passive element in the f acility fire protection' program and are subject 4o periodic inspections.
/
Fire barrier penetrations, indibding cabtIpenetration barriers, fire l doors and dampers are contidared OPERAB(Maen the visually observed condition is the same as tha as deilignied condl. titin.
Fcr those # ire barrier penetrations s
th6t are not in the as-designed -efidition, an e kluation shall be performed to ch:N that the modification ht not degraded the firb ting of the fire barrier 4
/
Duricg perjodif',/,
of tim when a barrirr is !aopes able, eith N)bfsthe a
continuous fire w 1s required to be meintaineu in tho vicinity
.;f f ecteo,Mfr s er, a tet:
or '<.) the fire detectors on et le.:st one side of the%ffected DdPrjit1ftust be VL.'ified ')PERABLE and an t.ourly fire watch patrol establislied untf! the ba.rier is mstoried to GPERABLE statur,
'N i
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SALEM - UNIT 2 8 3/a 7-8
. - -. =. - - - ---.
-*h n
e a0HIN STRATIVE C0hTROLS
'6.1
. RESPONSIBILITY 6.1.1' The General Manager - Salem Operations snall ee responstble for overall facility operation and snall ce1994te in writing.the succession to en1s rescon-sietlity during his absence.
6.1.2 The Senior Nuclear Shift Supervisor or, during his absence / rom the Control Room, a designated individual shall be responsible fbr the Control Room l
corwand function. A risanagerier>V direct 1W to this ef fect, signed Dy the Vice Presicant - Nuclear, shall be rei? sued to all station persoricel on an annual bl.si s.
6.2 ORGAN!ZATIO_N OFFS!TE 6.2.1 The offsite organization for facility mnagement armt technical support shall be as snown on Figure 6.2.l.
FACILITY STAFF 6.2.2 The' Facility organization shall be as shown on Figure 6.2-7. and:
a.
Each on duty shtft shall be composed of at least the minimuu shift crew composition sNwn in Taele 6.2-1.
b.-
At least one licensad Operator shall be in the control room when fuel is in ene n actor.
In addition, at least one licensed Senior Reactor i
Operator shall h3 in the Control Room area at all tims.
l
- c.. A health ohysics techniciand shall be on sits when fuel is in the re actor.
1.
ALL CORE al.TERATIOMS shall te observed and directly supervisad oy a lir.ensed Senior Nesctor Operator wrr) has no other concurrent responsi-bilities curing this onarttion.
//
"--= %
A7Trfr1474 Br.lgade of at taast 5 momeers snail be mint _AinaoomrtW'3=
e.
at all timese. MFiewSctgaae shall ntn1 mum shift crew mees 14rs Mii*"ss#4yt._tmehtee-T Einoers of the 4hu.1down of the unit or any personnej._requirerttiF~'dttne essential fun &35ht,$welag._a fire o
x : :. *nV W CY*
f.
The amount of rnertim worked by plant staf f aanbers cerforming 2.u safety-related functions mrt be limited in accordance alta the MC hlicy $tatacent or, wrxing hours (Generic Letter No.32-121.
Who nealtn' onysics acnnIEan Sne-Mee44 ace-composrcion may x lass t*ran tre 9
stt nirue requiremarycs for a period of tim not to exceed 2 nours in orcer to
(
tccomucato unucected aosence of tee meal tri physics tecnnician and/or 5 ice l
Origace meeers provided imedine action is taken to restore the naalta l
Onysics tecnnician and/or Fire Brigaoe to witnin 7.he minm;m requirerents.
SALE.M - UNLT 2 e-1 Amendment No. 33
~
- ADMINISTRAf!VE CONTROLS' 6.7. 3 SHIFT TECHNICAL ADVISOR e
6.2.3.1 fhe Shift Tecantcal Advisor shall serve in an advisory capacity to the Shift Supervisor on matters pertaining to the engineering 4spects assuring safe operation of the unit.
6.2.3.2 The Shift Technical Advisor shall han a Bachelor's Degree er 4
eovivalent-in a scientific or engineering discipline with specific training in plant Jasign and response and analysis of the plant br transfents anc accidents.
'6.3 FACILIJY STAFF GIALIFICATIONS 6.3.1 fach somber of the faciliny 5.caff shall aset or exceed the mininus qualifications of AN51 N18.14971 for comparable positions and the suppleaustal requirements specified in Sections A and C of thclosure 1 of the Merca 28,1980 NRC letter to all licMsees, except for the indiation hotection Engineer was shall meet or ext.eed the qualifications of Regulatory Guide L.3, Septemoor 1975 f.4 TRAINING 6.4.1. ' A retraining 41.d replacenant trainin7 program-mr the facility staff l
shall be coordinaeed by each functional level eenager _(Oeoartment Head) at the facility and.meintained under the-direction of the Manager --Nuclear Training
- and. shall. noet or exceed the requirements and recommendattons of Section 5.5 o f L ANSI M18.14971 and Appendix *A* o f-10 CFR Pa.*t 55 anit the supplenental requirements specified in Sections A and C of_ Enclosure-1 of ene Maren - 28, 1980 MMC letw to all 11consees, and snell: Inelude familiarization with relevhat 1
industry operational experience.-
% ~ ' f~trat % gram A h F E arigm w il s h g r
6 f.2 n
. d rection of tne Manager - stietearm-Training 4Asung or exceeg ne requirements of kction 27afMa^._, Ocat-19 a l D cept- %e e Seigade training sess(QALehn be held' at 1 east quarterly.;,
1 M
ii SALEM - UNIT 2 0-6 Amer.dment No. 33 p
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ADMtNtSTRAityt CONTROLS
=
Type of cratainer (e.g., t,5A, Type A, Tyg J 8. La' 54 Quantity), and e.
f.
Solidification agent or abrortent (9.g., cement, urea formaldahyde).
The Radtoactive Eff1'sent Release Reports shall include a list of descrirtton of unplanned releases from the site to UNRESTR!CTID ARIAS of radio #ctive asterials tn gaseous and itqui4 affluents mede earing the reoccting perios.
The Radioactive Effluyt Release Reports shall includs any changed cada during the reporting period to the PROC 133 CONTROL PR09M (PCP) and to the OFF31TE C43% CALCUt.AT10ll MML% (00CM), as well as a listing of uw locations for dose calculations and/or enviremental sonitoring identified by the IaM use census pursuant to Specification 3.12.2.
' g !AL REPOR_q 8.9.2 Specini' reportJ shall be submitted to the Adelaistrator of the Regional 7INSr.1T 2 ffice within the time period specified for each report.
4.10 atCost0 R(TIMTIQN In addition to the applicaile record retention requirisments of Title 10, Code of Federal Regulations, t>e folloulag records W11 be rstined for at least the minimum period indicated.
6.10.1 The following records shall be retained for at least five years:
4.
Records and logs of unit operatica covering time intarval at acch pcwe level.
4.
Racards ud logs of priticipal maintenansa attivities, inspeettons.
regale ared replaceaant of principal items of slutpment rtisted to
~
nuclear safety.
c.
AL1. REPORTA4L1 CICWIADCIS sabeitted to the Commission.
c.
Racerts cf survetltanca activities, inscoc.tcis and cat tbretions requirtd by thesa Technical Specifications.
t.
Records of esactar tests ar.4 experiments.
f.
Records of changes abda to Operating Procedures required by
$sectftcation 4.8.1.
9 Reards of endtoactive snipements.
4 h.
Recores of sealed scurte and fission detector leak tasts and results.
1.
Records of aanual pnysical toventory of all saaled scuest raatarial of recorn.
SALDi - UMIT 2 6 21 3esn0nent tio.
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ATIACIDDff 3 HOKEED QPHIS TO FIRE HUIDCTICH FBOCRAM REQUIREMDTIS HU.Gt TD RDWAL HM TIIE SAIIM QMBATDG STATICH, UNIT IG.1 N3D 2 T1IINICAL SPECIFICA1TCIG USCRIPI'ICN 01 '1HE _QINK2S A.
QWPAL
)
l StandsIt1 '1binical Specifications (STS) for Westiryhouse Pressurized Water Reactors, nuisicn 5 wan used as a basis for these etnroes. Specific systm para:rstars carrently ocntained in the existing Salm Technical Specifications (TS) were extractal ard intznh4 irio tlw STS wortilry.
The requirents for Salm Generatirg Station cxntaired in this attachmnt reflect consistency with the Fire Protection Prtgram requirements of PSE&G's Hcpe Creek Generatiry Staticn terever possibfe. 'Ihis approach was taken zucrgnizirg that cne emocn organizatien is reapermible for fire prota?. ion system surveillance testirg and ccmpersatory mearAu:es for both staticra. By having a ccanistent set of guidelines for Salm ard Hcpe Creck, the pcssibility for ertura is raduced. Therefore, there significarrt differerres exist between the SIS md the requirmerita previously appreuxi for Hcpe Crtdc (as contaired in NUREG-1186), the Hope (.'. reek zugtir%mentr Wern adcpted.
In addition, other than asaigniry the najor Secticn nLmbara, aa centained in che existiry TS, to the apprtpriate Sections in this submittal, to attecpt was made to corrulate subsecticn rumberirg or Table designaticaw. Subsec. tion rarters were assigned in the order contained in the SIS arrl Tible designaticns reflect the designaticre of the SIS unless otherwise specifically no*axi in the Sumary of Charges belcv. Where entire Secticns or paragrapts have been deleced, misequent paragraphs have been Iwumbered negaantially. Specific ccuments are included in the follcuirq sucamry of Chanya B.
S01 MARY OF QWCES Sction Descrictig) 3.3.3.6 SIS Table 3.3-10 has been rumbered to te consistent with ctLM TS to avoid disrupticn of other tables in the Section.
, This table has been capletely reformatted to maru clearly Jidentify detecticn zcnos and detector nuntions...either as an strly-warning alarm only or as a suppression systs actuation. In contrast to the HCCS format which ir@vh a gemric statment for determinirg minizan ckrtector operability based cn detector functicn, the actual, nininrn in++v of detectors zwquired to be cperable hu been includod cc:nsistent with both existirg 'IS and S15. This format was selected to avoit. ruvising tetnical informaticn ecntainal in tlw existiry TS unless there was a subsequent modificaticn to a zcne or tha rurdoer or type of detectors was clearly in error based on a field walldcun. Since the arrangement of detectors at Salem is primrily 1ccalized or spot coverage ruther than area coverage as provided at HCGS, the generic statment for detA% mininim cperable detectors is not apprtpria*a.
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SidiiGD Descripticn 4.3.3.6.1
' he testing requitumonts for testing rmtorable spot-type therani detectors, as ccotr.ined jn this section, waru adW frun the UCGS nquirments airl npresent a change frun the requiruments of both R3 and existirg TS.
4.3.3.C.2
'Ihe incent of this sectim, as contained in STS Section 4.3.3.3.8.2 and tha HCCS Itgilruments is to ensure that the supervisory function of NFPA 720 supervised ciro. tits is OPERABIE. As presentad in the existing 'IS Sectico 4.3.3.6.?,
the cirulit itsall' is tcsted every 92 days. This, in effect, duplicates Secticn 4.3.3.6.1.
Werefore, SIS and the 6 march frequency arc incorporated in this submittal.
3.7.10.1
'Ihis section has been rqtras+,3 to ruflect SIS and establishes consistency with Hcpe Cnek nquinmits.
It should to notoc' that Section 3.7.10.1.c, as incite led in existing Unit 1 TS as "Autantic initiatico lo,1c for t'n fire panp" ins been significantly rephrased. This~ dou ex suggest, hcwver, that autcmatic logic is no longer requitsd. Surveillance Requirement. 4.7.10.1.1.e, as cantained Jn this subatittal, Itquires functioral tcutirq to dueM.4cate the systan Cpurable which incitike "...sinulated autanatic actuaticn of the system.."
~
4.7.10.1.1 STS Section 4.7.11.1.1.b has boon deleted as not applicable and rd m quent paragraphs re-lettarud. It should be nted that tills paragraph is ccntained in tim er.istiry 'IS.
The pmp run tium reflected in Uls, however, suggests that tha requitamant was not inten.kd to apply to IW1 electric ard diesal driven punps. Salesa does tot use electric driven punps. 'Ibe requirements for running diesel driven punts are car tained in SIS Section <'. 7.11.1.2.
4.7.10.1.1.b Thin Sectica ccrrespads to cristire TS 4.7.10.1.1.c.
Currently, Unit 1 only regairm valve position verification for valves that are not locktd, sea 3ed, or otherwise securai.
Neither Saltan Unit 'IS nor FIS irr.luir3 this relief. Ikkuver, a ruview of Section 4.3.3.6.1 Irdicates that Inlief has boon prtnidad for emWnt not readily accessible during operating conditiores (in this eme, fire detection instru::ents). At the Salan plar.ts, several fire protection valva aru installed in inaccessible ervas, such as in the containment. Thezefore, rulief has been introduced in this Secticn (for those va.1ves) that is consistent with the extent of the relief pruvidad in Secticn 4.3.3.6.1.
4.7.10.1.1.c The frequency of this requirement, as contained in SIS Section 4.7.11.1.1.d, has been Invised frua 6 months to 12 IxntJis for omsistency with both Haps Ctmk requirements ard NFPA requirtments.
4,7.10.1.2 Fxistiry Unit 1 TS includes Se6icn 4.7.10.1.2.c.2.
- However, since it is repetitive of Sectico 4.7.10.1.2.a.2 ard is not con *h in sis, this reglirerent has not been incitzied in this submittal.
Section DgagrJIgigo 4.7.10.1.2.a.2 The pump tui tim contained in existiry Unit 17S Suctico 4.7.10.1.2.a.2 is 20 mirutm. This requinrrat is exterrhi in this sutnittal to 30 mirutes to be otruistant with existirn thit 2 'IS, ikpe CITek Staticn 1S, ard SIS rupitur. ants.
3.7.10.2 The listirq of ILuarti Artes has boon upisted to cicarly reflect all safoty-rulated areas pitta:ted by watsr sqpressicn systas.
4.7.10.2.a This secticn, omtaired in S'IS 4.7.11.2.a, la rot irrlttkd in edstirq Unit 1 Tech Specs. This requirumant is ocosistent with existirq thit 2 78 ard ikpe Creek requirunents and is, tharsfore, hcitdod in this stuittal. Additicrnlly, tM nama relief fc r Jrw=alble valves di-M in 4.7.10.1.1.b above has been incitdai in this Section.
4.7.10.2.c.1.b 1his secticri, rot contafrad 11 e.' Mirn 'IS, ripnosents rulief for cycliig iracomsible valvor ary la mcnths ratkr tMn uvary 12 scnths. 'Ibe 18 mMth _r,quwicy corresponds to the refuelirg cyclo. 'Ihis rtvpiranant reflects both S7S ard the llope Creek requirunents.
4.7.10.2.c.3 This requiranrat is curtuntly rambered 4.7.10.2.b.3 in existhq Unit 11s arri 4.7.10.2.c.3 in Unit 2 TS.
In niilticn to rarambering the requhunent to permit intnducticn of a tww Secticn 4.7.10.2.a for Unit 1 (dia:umed ab:Vo),the tupirment, as stated, reflects s'15.
The fluction of nozzle blockage inspecticn is addrwesed by (W,:ticn 4.7.10.2.d.
3.7.10.3 The listire of lie.zard Areas hau been tpdatal to clearly ruflect all safety related areas protectal by CD 84 F#""8IC" 2
systaw.
4.7.10.3.1 This sectica, etntained in Stardard %cti Specn as 4.7.11.3.1, is rot irritded in existing Unit 1 'IS.
This requirunant is ocawistant with existirn Unit 21S ard IKus nquirunants ard is, thereform, irritxkd in this submittal.
4.7.10.3.2.a Tne existirn TS licitde CD sta tank level and plumure requirsonnts in tM Limiti CX tions for Operation. 'Ihis surveillance secticn ncw contains those specific regairunents.
3/4.7.10.4 1his section is a now sectica ircitxkd to adities requilenants
- f or tha halco systms installed for prutsction of the Relay f
J Bocans. Because syntan cparaticn apacciata$ vith the halcn
' ~ s'jstma provided for the ikpe Cdwk control Docan Cbnsole Pit is significantly different than the halcn systes for the Salcn nalay Rocxas, the requitumaats ocntained in sis were ircitdod in the sulnittal with no chargos for similarity to Pope Crock.
4.7.10.4.a This sectico, ocntained in SIS as 4.711.4.a, is not ircitdod in cxistim Salan TS. This requirer:cnt is consistent with llope creck tuc,airunents ard is, thereforu, included in this sutnittal.
._,m--r
i SmQqo Igrriotico 3.7.10.5 This sect icri cort opwin to existirg Secticn 3.7.10.4 for firu hose static w.
Ir.xotrast to the fire hcue staticn listiry provided in the existing 15, this listirq incitdes all firo hose staticos required to prutect safety-rulated areas regan11ess of the fine hooe staticn tutie desigration. Wiro csw firm hcse staticn is required for prutactics1 of areas contained in both Units, it is included in the sukuittal for each Unit.
3.7.10.5.a This secticn, as ccotained in existirq 75 as 3.7.10.4.a ard MS requires the routing of fire hcees Milch can create recognizable hazards. The couwdirg HCUS requirusnent permits hcmes to be stored in a roll, reMy for use, at the outlet of an OIDAB2 hoes station Wars the routirq of the hoes would result in a recognizable hazard. In acosideration of the safety elemencs involved, this Section was worded to inoo':porata the provisions of the cou.=ipcr11ng Hm3 requirument.
4.7.10.5.a This sectico, as contained in socisting Unit 1 TS 4.7.10.4.a, ckes not include relief frun 31 day inspections of inacoussible fire hose staticos. Because this relief is ocotained in mu, existiry Unit 215, ard HOGS requirmnents, it is included in this sulmittal.
4.7.10.5.c.2 This sectico, in ed* stirq Unit 21S as 4.7.10 4.c.2, requirer hydrostatic tastirn of fire br=as at 50 peig greater than the
=v4== fire main pressure or 300 psig, Wiich ever is greater.
Existirn Unit i TS call for a pt=amim of at least 50 psig greater than the maxima pr=amim available at the home station. STS stipulate 150 psig or 50 poig above =vi=rn fixu main pressure, Wilchever is greater. Bacause the 300 psig contained in existirn Unit 2 75 is both greater than the maxinun operatirg pressure plus 50 pcig ard in conflict with the maxian pressures requiral by NFPA 1962 for service pressure tests, the requircaent has been revised to agree with the MS.
3/4.7.10.6 This section is new ard not included in existirg 15.
Bocau.ce thers are two fire hydrants called out in the Salms Fire Protectica Report as beiry required for coverage of saf,'ty-Islated arsars incitrihg the Service Water Intake Structure ard the I W 1 Handl Balldirgs, this sectico is included. 7hezu l
is no uu.1=ipcr '
HOGS requiranent.
t 3.7.11 The phrasing used to identify the ami!=it governed by this specification reflects both the STS ard the Hcus requirements.
This woniiry results in the inclusicn of fire area bourdaries governed by existing is and any other barriers within those L
boundaries. This would include, as an example, cne hour fire wraps on cable trays.
In addition, u.w sisatory ACTICH a.3, for daily firm watches, er l
Maad on available detection on both sides of the barrier (not l
included in STS) has been incitdod as cmrently approved in the HOGS reqairements. -
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=_. -..
Sectico Ibecriotigo 4.7.11 ilmco surveillance rupirments Mvo been significantly tuvised frun their counterputs in existify 13.
itw.ca dnrgos are consistant with both S1B art! IKCS rupirurents. Those ciargos result in rulief frun sme rupirurents, but aM surveillancos as a result of othar rupirutents.
IDECH Iut 11tB liorumD QWE PSFE Ma been implumantirq the Fire Protectico Imprweent Program for Salem Generatirg Staticn as cumnitted to IEC. As part of tMt program, it was realized that, in scr:e casos, Technical Specificaticos currently in effect for Salm Units 1 ard 2 do not reflect actual plant ocatiltions.
In aMitico, the inconsistencies between both Units' is for similar equipment has the potential for causirg errors in implementiJg rupired surval.11ances arxl acticns.
Dy ugiatirg, with these chargos, the Fire Protecticn Program - with the SIS as a guido, and incorporatirq clarificaricos of specific Fire Protecticn Program rupirutents arprwwl for !! ape creek Generatirg Statico, the organization responsible for inplosnentiry the Fire Protectico Prugrams at Artificial Island can arply uniforn procedurus at all three units.
In additicn, Generic Latters 86-10 and 88-12 prwide guidarce to utilities sockirg licenso amordments to recognize apprwed Fire Protectics. Prograns an1 rumovo Sutve111ance/Limitiry corriiticos for Operaticn frun the Technical Specifications. ikurver, the assunpticn made by imC for that type of anwGwit request is that the cparability raquirunents inposed by existiin is are acx: urate. PSFM has determined tb;.1, due to recent fire prutacticn systan enhanoaments and due to the above iaantrenad is inconsistercios, Salan Unit lbs.1 and 2 prosently do net moet ' chat criteria.
The purpose of thie anerrimant request is to sul.uit a ca.pmhensive ard up-to-date Fire Protecticn Psu are that, upon imC review arri tqproval, will satisfy the critaria of the Carr h Letters and ultimately permit the runoval of the Fire Protectico Program asan the Salan 1bchnical Specificaticos as ruquestod in Attadunent 1.
agmacEtnLIn'nnt mium gg;g; As prwlously indicated, the prtpocod revisicos permit ocnoistency of ruquirements to be WM on Fire Prottcticn systans for both Saloin units.
clarificaticos to rwpirunents previously apptwed for licpe creek Generating Statico have been incorporated as well. Approval of those charges allow uniform sugemu6 tic requirunants to be a; plied to all thrn unita en l
Artificial Islani by a ocmon organizaticn.
There are casos involvirs either relief from existirg surveillance requirutents arrt u wsatory masures or cuiversaly, nore restrictive surveillance requirunants. licwver, no attarpt was unde to tailor this i
subnittal to gain relief frun standard sutveillarce requirutents or cupensatory mcsasures.
PSFE is makirq this charge rupest to imptwo t's overall Fire Partectico l
Program at Artificial Islard.
l SIQi1FICNfr IIAZAIM ANAIMilS 01UTTWJYEL If Um prtriused dargos to tre todnical spacificatitre & rot involve a algnifiant ircrease in the ptdnh{}ity or carEc[prCOs of any DCCi&Y1b ptwicunly waluatal.
'Ihe enhar unuits unde to Todnical Specificaticre thrtugh this Attadunent reflo::t actual plant cxniiticrm. Um iroorporaticn of Star:1ml 'Ibdmical Spocificaticn requirunants and awrwul itpe crock variatims allcv a ccrmistant fire protecticn program to be appliod at Artificial Islard.
By ruxnirn inomsistent requirunents, tM prdability of errors in surveillarco requirements is reduced. Um lac twiew and a@rwal of the propased darges will then satisfy the critaria of Generic letters 86-10 ard 88-12 ard permit the rumaval of the Salun Fire Protecticn Ptugam (as apprwed by 1GC) frun the
'Ibchnical Specificaticra folicwiry the guidelinos prtnidad by tho Generic Intters. Um rtrwal of the Firu Prota: tion Paujuun frun the TS has been twiewed by the IUc staff as part of the issuance of the Cencric letters ard been fcurd acceptable prcuided that tM criteria establishcd in the Generic Intters are met.
Upan lac apptwal of tM requestod durges herein, the FTP ruquirunents curruntly definod in the TS, in canjuncticn with these aliiticml propaced changes to thom 'Is ard t-) tM SCS Updated Pacility safety Arnlysis Report (UEAR) in Attadunant 4, would be cebodied within a pericdic testirg ard surveillance program Aw,-ibed in the SCS UFSAR ard would entail shiftirg of the testirn requirtaints frun TS surveillance ru.uiurus to periodic test s u.uiarus. '1he Attadment 1-prtpocod License Ctrditicn ard additicral Spccial Repart ruquirunents in TS Secticn 6.9.3 would prwide adequate administrative control of FPP alemmts to ensure that statica capabilities co adtieve ard maintain safe shutdown in the event of a fire runain at an equivalent level of fire protectim as currontly prtnidad with the FPP in the
'IS.
Sinm staticn fire protectivi capabilitios will runin at an equivalent level with the FPP ruxwed frun the TS, it can be acrcluded that the prwcoed durgo does rut involve a significant increase in the probability or oansequerres of an accident previously evaluated.
'Ibe swa.m=1 changes to the tednical specifications do nct create th prvmIh11ity of a DOW Or differtnt kird of WMwit fInt any Whvit ptwlously evaluated.
l
'Ibe pred danges represent enhancements to existiry technical specifications. 'Ihe majority of significant charges are to Unit 1 technical specificaticais to provide omsistency with Unit 2.
'Ihe charges to both units' technical specifications are in accettlance with amtwed generic Westirghause Stardsrd 'mdmical Spacificaticra ard variaticns approved for ikpe crock Canaratirn Staticn. No ghysical plant modifications or operatirg j
ocnfigurations result frun these darges. 'Iha prrr-d dunges do not affect the design or cperaticn of any systan or ccmporant important to safety.
Upcn IGC apprtwal of the Fire Protecticn Pawram, as ecdified heruin, the rumaval of the elomonts of that program frun 'IYdnical Specificaticos and lircrporaticn in the UFSAR in accordance with the prtnisicos ard guidelines of Generic Icturs 86-10 ard 88-12 will rot create any new or differunt accident l
frun any pruviously evaluated.
1
4 1he pcupased clunges to tim tattriical apcifications do not irwolve o significant r*+% in a margin of safety.
The prvyred changes affect the cuitrul of periodic testirn ard anveillanaes for fb a Irutection systmas and otspcnants. The chargem do not affect any analysis of design h accidents or any Arperx11x R Hazards Otnsideraticn.
The kw-r3 charges prtuide a otswistant approach to assuring operability ard availability of existirq fire protect.icn systans for safety-rulated armas at Saleen Generatirg Staticn.
The pt _-xM License ccn11 tion ard requirements placed in TS Section 6.9.3 will ensure that the station fire ptotecticn capabilities, followirg runwal of the FPP frun the Technical Specifications, remain at an level equivalent to that level currently in place with the FPP in the Technical Specifications.
Thereform, recval of the fi.ti protection program elements frun the 7 Weal Specificaticos will not iruolve a significent reducticn in a margin of safety.
02K11EICE Based on the informaticn pttwide! abcNo, IEFJG has cucitded that the prop ad charges satisfy the criteria for a no significant hazards ocnsideration, n
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JNSTRUPENTATION 2L(,,1_{i FIRE DITECTION li4STRUMENTATION LIMITillG CONDITION FOR OPERATION 3.3.3.6 As a minimum, the fire detection instrumentation for each fire detection zone shown in Table 3.3-10 shall be operable.
&RPLICABIL::TY t-Whenever e@ipment protected by the fire detection
.nstrumentation is required to be OPERABLE.
ACTION With-the number of OPERABLE firo detection instrument (s) less than the minimum number OPERABLE requirement of Table 3.3-10 a.
Within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> establish a fire watch patrol to inspect the zone (s) with the inoperable instrument (s) at least oncer per hour, unless the instrument s)~ is locatad inside the containment, then inspec(t the containment at least once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or monitor the containment air temperature at least once por hour at the locations listed in Specifcation 4.6.1.5.
b.
Restore the inoperable instrument (s) to OPERABLE
..atus within 14 days or,ication 6.9.1in lieu of any other report required by Specif prepare and submit a Special Report to the Commisskon pursuant to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability, and the plans and schedule for restoring the instrument (s) to OPERABLE status.
c.
The provisions of 3pecifications.3.0.3 and 3.0.4 are not applicable.-
s Unit 1 L
=.... -.. -
l EQRVEILLANCE REQEIPJJifl!IS 4.3.3.6.1 Each of the above remaired fire detection instruments which are accessibfe during plant operation shall be demonstrated OPERABLE at least once par 6 months by performance of a TRIP ACTUATING DEVICE OPERATIONAL TEST except for restorable spot type thermal heat detectors, which shall be tested such that at least one detector on each signal-initiating circuit will be tested at least once per 6 months, such that all detectors are tested in 5 years.
Fire detectors which are'not accessible during plant operation shall be demonstrated OPERABLE by performance of a TRIP ACTUATING DEVICE OPERATIONAL TEST during each COLD SHUTDOWN exceeding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> unless performed in the previous 6 months.
4.3.3.6.2 The NFPA Standard 72D supervised circuits supervision associated with the detector alarms of each of the above required fire detection instruments shall be demonstrated OPERABLE at least once per 6 months.
Unit 1 l
l
L TABLE 3.3-10 FIRE DETECTION INSTRUMENTS-1 I
Minimum Total Type "A" Type "B' Detectors Description No. of Detectors Detectors Operable Zone Area Breakdown Detectors (Note 1)
(Note 2)
(Note 3)
- 61. Service Building Cable Vaults (Note 3) 12 j
la & IB Cable Vaults, El. 113' 3
2 IC & 1D Cable Vaults, El. 113' 3
2 s
2A & 2B Cable vaults, El. 113*
3 2
i 2C & 2D Cable Vaults, El. 113' 3
2 62 Battery Rooms El. 100*
7 I'
1A 125VDC El. 100*
2 1
[
1-1 250VDC El. 100*
3 2
r 1B 125VDC El. 100' 2
1 63 Radiation Monitor Enclosure El. 120' 1
1 1
64 No. 1 Control Console-2 2
1 L
66 Computer Room.
2 2
1
[
- 67 Control Room & Peripheral Areas Ceiling Void 12 12 8
l 1
Control'Rm & Cosputer Rn, Det's 67-1, 67-2,
& 67-9.to 67-1 6
4 Corridor, Det's 67-3 to 67-5 3
2
[
Shitt Supv Offices, Det's 67-6 to 67-8 3
- 68 Control Room Peripheral Areas 14 Aux Equip Area, Det's 68-1 to 68-8, & 68-14 9
6 Corridor & Shift Supv Office, Det's 63-9 to 68-13 5
4 69 Fuel Handling Building 13 Vent Equip Room 3
2
[
Elect Control Area 2
1 New/ Spent Fuel Storage Area 5
4
[
3 Storage and Service Area 3
2 70 1A,1B,1C Diesel Gen Control Ras 3
1A Control Room 1
1 IB Control Room 1
1
[
IC Control Room 1
1
- 71 Equip Rm, Ladies Rm, Spare Office El. 122' 2
2 2
a f
SALEM - UNIT 1 3/4 3-51 i
n
I TABLE 3.3-10 FIRE DETECTION INSTRUMENTS
)
Minimum Total Type "A" Type "B" Detectors Description No. of Detectors Detectors Operable Zone Area Breakdown Detectors (Note 1)
(Note 2)
(Note 3) 72 Panel 335 El. 100' 3
3 2
75 Switchgear Rooms & Penet Area Ventitation 3
l Electrical Penet Area Vent System 2
2 l
Switchgear Room Vent System 1
1 76 Relay Room & Control Room Air Conditioning 3
3 3
77 Aux B Idg East Aisle 1 El. 84*
4 4
4 78' Aux Bldg West Aisle 1 El. 84' 6
6 6
79 Aux Bldg #1 LTDN/ Seal Vtr Ex Entry El. 84' 2
2 2
81 Switchgear & Battery Rooms El. 64' 20 Switchgear Room El. 64' 18 16 l
IC 125VDC Battery Room El. 64*
2 1
1 82 Switchgear Room El. 84*
18 18 10 j
83 Electrical Petetration Area El. 78*
13 13 7
SS Diesel F.O. Transfer Pumps El 84 2
i No 11 Diesel F.O. Transfer Pump Room 1
1 No 12 Diesel F.O. Transfer Pump Room 1
1 86 No. 11 Diesel F.O. Storage Tank El 84 2
2 1
87 No. 12 Diesel F.O. Storage Tank El 84 2
2 1
l 88 1A Diesel Gen Area El. 100*
7 1A Diesel Gen Room El. 100' 4
3 1A Control Room El. 100' 1
1 l
1A Day Tank Room El. 120' 2
2 89 1B Diesel Gen Area El. 109' 7
i IB Diesel Gen Roor El, 100' 4
3 1B Control Room El. 100*
1 1
IB Day Tank Rcom El. 120' 2
2 90 1C Diesel Gen Area El. 100*
7 1C Diesel Gen Room El. 100*
4 3
IC Contrcl Room El. 100' 1
1 1C Day Tank Room El. 120' 2
2 SALEM - UNIT 1 3/4 3-52a l
f TABLE 3.3-10 FIRE DETECTION INSTRUMENTS Minimus f
Total Type "A" Type B" Detectors Description No. of Decectors Detectors Operable i
Zone Area Breakdown Detectors (Note _1)
(Note 2)
(Note 3) 91 Relay Room 9
9 17 i
(ZIU 91, odd numbered detectors)
(Note 5) l 91 Relay Room 9
9 (ZIU 96, even numbered detectors) 92 Aux Feed Pumps El. 84* Detection Only No Discharge 5
5 4
97 Switchgear Room El. 84' 14 14 13 98 Electrical Penetration Area El. 78' 6
5 5
101 No. 12 Fuel Edig Ares Exhaust El 100 1
1 1
102 Containment Pressure Relief El 100 1
1 1
103 No. 11 Iodine Removal El 78 1
1 1
[
104 No. 12 Iodine Removal El 78 1
1 1
l 105 Control Room Air Ccod*g El 100 1
1 1
l 106 Aux Bldg Air Cond*g El 100 1
1 1
l' 121 South Penetration El. 92'-6" & 100*
6 6
5 i
122 Elect Penetration E1. 100*
6 6
4 123 Mech Penet. East El. 100*
6 6
4 j
124 Mech Penet. Vest El. 100' 5
5 4
125 Aux Bldg Elev 100 Col 11.8-14 FF-NN 21 21 4
r Corridor Det's 125-1 to 125-5, & 125-15 6
5
[
j Boric Acid Evap Ra, Det's 125-6 to 125-8 3
2 Misc Areas, Det's 125-9 to 125-14 6
6 d
1,ab El 100* & 110', Det's 125-16 to 125-21 6
6 l
126 Aux Bldg Boric Acid Trans Pumps E1. 100*
3 3
2 127 Containment Fan Coil Unit 11 & 12 El. 130' 12 12 Ring Duct by 11 FCU 2
2 Ring Duct by 12 FCU 2
2 t
Above 11 FCU 4
3 Above 12 FCU 4
3
[
128 Containment Fan Coil Unit 13 & 14 El. 130*
12
[
12 Ring Duct by 13 FCU 2
2 Ring Duct by 14 FCU 2
2 Above 13 FCU 4
3 Above 14 FCU 4
3 l
}
SALEM - UNIT 1 3/4 3-52b I
\\
4.
P TABLE i.3-10 FIRE DETECTION INSTRUMENTS Minimum Total Type "A" Type "B" Detectors Description No. of Detectors Detectors Operable Zone Area Breakdown Detectors. (Note 1)
(Note 2)
(Note 3) 129 Containment Fan Coil l' nit 15 El.130' 6
Ring Duct by 15 TCU 2
2 Above 15 FCU 4
3 120 Containment RCP 11 Bel El. 130' 4
4 3
131 Containment RCP 12 Bel El. 130*
4 4
3 132 Containment RCP 13 3el El. 130*
4 4
3 133 Containment RCP 14 Bel El. 130' 4
4 3
134 Aux Bldg #1 A/C Equip Rm El. 122' 5
5 4
135 Aux Bldg #1 A/C Room El. 122' 9
9 7
136 Aux Bldg Resin Storage Area El. 122' 4
4 3
137 Aux B Idg E Aisle 1 El. 64' 4
4 4
138 Aux B Idg V Aisle 1 El. 64' 3
V Aisle El. 64' 7
7 l
In Duct - CVCS Hold Up Tanks Ver.t Systen 1
1 141 Aux Bldg 11 & 12 Vaste Gas Compt Area El. 64*
7 7
6 142 Aux Bldg 11 & 12 RHR Pumps Elev 45 7
11 RHR Pump El. 45' 4
3 12 RNR Pump 21. 45*
4 3
[
i 143 Aux Bldg El. 55*
7 7
7 144 SIP-CCP El. 84*
6 i
Component Cocling 3
2 Safety Injection 3
2 145 CO2 Equip Rm Chg Pump & SIP CS Pcp Elev 84 8
2 CHG - SIP 3
3 CO2 Equip Room 2
2 146 Paping Penetration El. 78*
8 83 6
147 No 11,12,13 Service Vtr Pump Bay 7
7 5
146 No 21,22,23 Service Utr Pump Bay (Note 6) 7 7
5 149 No I4,15,16 Service Etr Pump Bay 7
7 5
150 No 24,25,26 Service Wtr Pump Bay (Note 6) 7 7
5 151 fic 11,12,13 Service Vtr Pump Control Room 1
1 1
SALEM - UNIT 1 3/4 3-52c
TABLE 3.3-1_0 FIRE DETECTION INSTRUMENTS 3
Minimum Total Type "A" Type "B" Detectors Description No. of Detectors Detectors Operable Zone Area Breakdown Detectors (Note 1)
(Note 2}
(Note 3) 152 No 21,22,23 Service Vtr Pump Control Room (Note 6) 1 1
1 153 No 14,15,,16 Service Vtr Pump Centrol Room 1
1 1
154 No 24,25,26 Service Vtr Pump Control Room (Note 6) 1 1
1 157 Aux Bldg #11 & 12 Monitor Tank El. 64*
4 4
4 158 Aux BlCg til Vaste Hold-up Tank El. 64*
2 2
2 159 Aux Bldg #12 Vaste Hold-up Tank El. 64*
2 2
2 160 Aux Bldg #1 V&ste Monitor El. 64*
2 2
2
- - Indicates detection rones containing both Unit I and Unit 2 equipment or cables or detection zones covering a portion of a Fire Area.containing both Unit I and Unit 2 equipment which may directly expose both Units.
In th? event that the zone is ret.dered INOPERABLE, ensure that the equipment required to be OPERABLE for both Units, not just the Unit to which the zone alarms.
Additionally, in the event that a fire alarm is received from any of these :enes, ensure that both Control Rooms are alerted to the condition to ensure that any necessary operational actions are taken.
Note 1 - Type "A" detectors are for early warning indication only.
Note 2 - Type "B" detectors are for suppression systes actuation.
Note 3 - Where the minimum detectors OPERABLE indicated is less than ene less than the total nunber ci detectors for the zone, no two INOPERABLE detectors shall be adjacent to each other.
l 1
SALEM - UNIT 1 3/4 3-52d I
L
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t f
TABLE 3.3-10
}
f FIRE DETECTION INSTRUMENTS i
e Note 4 - Zone 61, monitored by the Unit 1 Control Room, contains Unit 2 Cable Vaults. Upon i
confirmation.that the alarm received is from a Unit 2 Cable vault detector, Unit 1 Control l
t Room personnel shall notify Unit 2 Control Room personnel to ensure any necessary l
operational actions are taken, In the event that this zone is rendered.INOFERABLE, Unit 1 Control Room personnel shall ne..'fy Unit 2 Control Room personnel and the appropriate action f
statement.shall be logged again>c both Units'l & 2.
Note 5 - Icne 91 is a cross zoned detection system used for the actuation of the halon suppression system for the Relay Room. Therefore, the minimum detectors OPERABLE is based on 18, the combined number of detectors for both zones of the cross runed systen.
{
Note 6 - Zones 148, 150, 152, & 154, monitored by the Unit 1 Control Room, crotect Unit 2 Service Vater Pump Bays and Control Rooms. Upon receipt of an alarm from any of these zones, Unit 1 I
Control Room personnel shall notify Unit 2 Control Roos personnel to ensure any necessary
{
4 operational' actions are taken.
In the event thdt any of these zones are rendered
[
INOFERABLE, Unit 1 Control Roca' personnel shall notify Unit 2 Control Room personnel and the appropriate action statement shall be logged, as a minimum, against Unit 2.
i 1
i i
i I
i r
I 1.
l SALEM - UNIT 1 3/4 3-52e v
t
PlMI liYSTD'A 3/4.7.10 EIRE SUPPRESSIQH SYSTEMS ELEE SUPPREUl_QH HAIIB SYSTEM LIM 1IlEG_SDRDITLQ1LI9E_QEEMT10F 3.7.10.1 the fire suppreasion water system shall be OFERABLE withs a.
Two OPERABLE fire suppression pumps, each with a capacity of 2500 gpm with their discharge aligned to the fire suppress 1on header, b.
Separate water supplies, each with a minimum contained volume of 300,000 gallons, and c.
An OPERABLE flow path ca pable of tahing suction from either or both of t1e fire water storage tanks and transferring the water through the distribution
\\.sipingwithOPERABLEsectionalizingcontrolor solation valves to the yard hydrant curb valves the last valve ahead of the water flow alarm device on each sprinkler or hose standpipe and the last valvo ahead of the deluge valve on e,ach deluge or spray system required to be OPERABLE per Speelfications 3.7.10.2, 3.7.10.$, and 3.7.10.6.
AEELLCABILITY: At all times ACTION:
a.
With one pump and/or one water supply inoperable, restore t.ie inoperable equipment to OPERABLE statum within 7 days or in lieu of any other report required by specification 6.9.1 prepare and submit a special Report to the Commiss1on pursuant to Specification 6.9.2 within the next 30 days outlining the plans and procedures to be used to restore the inoperable equipment to OPERABLE status or to provide an alternate backup pump or supply.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicablo.
b.
With the fire suppression water system otherwise inoperable:
1.
Establish a backup fire suppression water system within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, and Unit 1
2.
In lieu of any other report required by Specification 6.9.1,ification 6.9.2 submit a Special Report in accordance with Spec a)
By telephone within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, 1
b)
Confirming by tulograph, mailgram or facsimile trant..aiss in no later than the first working d*v following the event, and
- s. )
- n vriting within 14 days following the l
event, nutlining the cause of the inoperability and the plans and schedulo for restoring the system to OPERABLE status.
EWlYll1141MLliklQVlBIMUi _ -
4.7.10.1.1 The fire supprossion water nyntem shall be dononstrated OPERABLEt At least onco por 7 days by verifying the contained a.
water supply volune.
b.
At least once por 31 days by verifying that each i
valve (manual, power operated or automatic) in the flow path which is accesnible during-operation is in.its corroet position. plant Valves which are locked, scaled, or otherwasu secured and not accousiblo during plant operation shall be verified to be in the correct position during each COLD SHUTDOWII exceeding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> unless performed in the previous 31 days.
c, At least once per 12 monthu by performance of a syston flush, d.
At least once por 12 months by cycling each testable valve in the flow path through at-least one complete cycle of full travel.
l:
I Unit 'l l
-~
e.
At least onco por 18 monthe by performing s system functional test which ircludes simulated automatic actuation of the systea,throughout its operating sequence, andt 1.
Verifying that each automatic valvo in the flow path actuateu to its correct position, 2.
Verifying that each pump develops at least 2500 gpm at a systum head of 256 f-7t, 3.
Cycling each valve in the flow path that is not testablo during plant operation through at least one complete cycle of full travel, and 4.
Verifying that each fire suppression pump starta (sequentially) to maintain the fire t,
suppression water systen presaure greater than or equal to 115 paig.
f.
At least once per 3 years by performing a flow test Section of the syntum in accordance with Chapter 5,ition, l
11 of the Fire Protection Handbook, 14th ed o
L published by'the National Fire Protection Association.
4.7.10.1.2 The fira pump diesel engines shall be demonstrated OPERABLE:
a.
At least once per 31 days by vecifying:
1.
Each fuel storage tank contains at leant 300 gallons of fuel, and 2.
Each diosci starts from ambient conditions and operates *or at least 30 minutes on racirculation flow, b.
At least once per 92 days-by verifying that a obtained in accordance with ASTH-D270-65, $e tanka within fuul.from the fuel stora sample of diesel, tha-acceptable limits specified in Table 1 of ASTM D975-74 when checked for viscosity, water and sediment.
during shutdown, by At least once per 18 nonths, inspection in c.
subjecting the diesol to an accordance with procopures prepared in ceujunction with its manufacturers recommendations for the class of service.
Unit 1
,-- ~,..-.~. -. ~ _ _.. = -.... - -. -. - -. -.. -. - _. - - -. - -. _. -...... -
i t
i A.7.10.1.3 The fire pump diesel starting 24-volt battery bank and charger shall be demonstrated CPERABLE1 a.
At least once per 7 days by varifying that:
1.
The electrolyte level of each battery in above the plates, and 2.
The overall battery voltage is grecter than equal to 24 volts.
b.
A': least once per 42 days by verifying that the specific gravity la appropelate f.or continued service of the battery.
c.
At 1 cast once por 18 menths by thatt 1.
The batteries cell plates and battery racka show no visual in'51 cation of physical damage or abnormal deterioration, and 2.
The battery-to-battery and terminal cennactions are clean, tight tree of corrosion and coated with anti-corrosion material, r
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i 1
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1 u
L EIAULMiiIDiS EBM_ MID/DH_ME1HIMiLSXETDiS IJMn11G_DDUDlTlDILERB_DEINCIDF -
3.7.10.2 The following spray and/or sp.-inkler systems shall be OPERABLE 11MMD MEb Cantninment
- No. 11 Reactor Coolant Pump Lube oil System
- No. 12 R<mctor Coolant Pump Lube Oil System
- No. 13 Reactor Coolant Putnp Lube Oil System
- No. 14 Ruactor Coolant Pump Lube Oil System
- No. 11 Containment Iodine Removal Charcoal Filter
- No. 12 Containment Iodine Removal Charcoal Filter
- Panel 335 AuriUArx aullding
- Auxi.11ary Building Ventilation Rom
- 1 Charcoal Filter
- Control Room Energency Ventilation C.arcoal Filter
- Containmont pressure Relief Charcoal Filter
- 11 0. 11 Diesel Fuel Oil Storage Tank Room No. 12 Diesel Fuel Oil Storage Tank Room
- No. 11, 12, & 13 Charging pumps
- No. 11, 12, & 13 Auxiliary Feedvater Pumps (nlectrically actuated preaction sprinkler system)
- No. 11, 12, G 13 Auxlliary Feedwater Pumps (pntumatically actuated preaction sprinkler system)
MELICMILIT.Yi whenever equipment protected by the spray / sprinkler system is required to be OPERABLE.
ACIlQlil a.
With one or more of the above required spray and/
or sprinkler systems inoperable, within one 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 areau, establish an hourly fire watch i
patrol.
Restore the system to OPERABLE status within 14 days or, in lieu of any other report required by specification 6.9.1, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability and the plans and schedule for i
restoring the system to OPERABLE status.
(
i b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
l Unit 1
SilRYELLMECX_PJWlEI%D1IS 4.7.10.2 Each of the above required spray and/or sprinkler systems shall be demonstrated OpERABIA:
a.
At least once per 31 days by verifying that each valve (inanual, power operated or automatic) in the flow path which is accessible during operation is in its correct position. plant Valvon which are locked, sealnd, or other secured and not accessible during plant operation shall be verified to bo in the correct position during each COLD SHUTDOWN exceeding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> unless performed in the previous 31 days, b.
At least onco per 12 months by cyclirg each testable valve in the flow path chrough at least one complete cycle of full travel, c.
At least once per 18 months 1.
By performing a system functional test which includes simulated automatic actuation of the syster, ands a) verifying that the automatic valves in the flow path actuate to their correct positions on a test nignal, and b)
Cycling each valve in the flow path that is not testable during plant operation through at least onta couplete cycle of full travol.
2.
By a visual inspection of the dry pipe spray and sprinkler headers to verify their integrity, and 3.
Br a visual inspection of encn sprinkler or deluge nozale's spray area to verify spray pattern is not obstructed, d.
At least once per 3 years by performing an air flow test through each open head spray / sprinkler header and verifying each open head spray /uprinkler nozzle la unobstructed.
i Unit 1
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,e
. -.. ~.. -
-.. - - ~
CO2 UIEINIE LUi1T_mG._C9ND.1T101LMR 9EUt&T10N 3.7.10.3 The following low pressure CO2 systems ahall be OPERABLE:
AMXillAC D.911d1119
- 1A Diesel Generator Area
- 1B Diesel Generator Area
- IC Diosol Generator Area
- No. 11 Diesel Fuel Oil Storage Tank Room
- No. 12 Diesel Fuel Oil Storage Tank Room
- tio 11 & 12 Diesel Fuel Oil Transfer pump Rooms
- 460 VAC Switchgear Room
- 4160 VAC Switchgear Room ElR91I.is.31 ff.QSirALIDD hLCA
- Iow.er Electrical Ponetration Area APf_LLCAEJdT11. Whenever equipment protected by the CO2 systems
.a required to be OPERABLE.
hCTlDD.t.
a.
With one or more of the above required CO2 systems inoperable, within one hour establish a continuous fire watch with backup fire suppression equipment for those areas in which redundant systems or c apor.ents could be damaged; for other areas, l
ostablish an hoarly fire watch patrol.
Restore the sfstemtoOPERABLEstatuswithin14daysor in l eu of any other report required by Specif1 cation 6.9.1, prepare and submit a Special Report to the commission purs.uant to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status.
b.
The provisions of Specifications 3.0.3 and-3.0.4 are not applicable Unit 1
- -... _. _ _ _ _.. _ _ ~ _ _. _.. _. --
i l
1 fdlRYZIllAtlCX REQUIREliEUlf 4.7.10.3.1 Each of the above required co2 systema shall be dononutrated OPEP.ABLE at least once per 31 days by verifying that each valve Lmanual, power operated or automatic) in tho i
flow path is in ',ts correct position.
4.7.10.3.2 Each of the above required low pressure co2 systems shall be demonstrated OPERABLE:
i I
At least once pir 7 days by vurifying the CO a.
storagetankleveltobegreaterthan50%and pressure to be greater than 285 psig, and b.
At least once per la months by verifyingt l
- 1. The system valves and associated ventilation 4
dampers and fire door release mechaniums actuato manually and automatically, upon receipt of a nimulated actuation signal, and 2.
Flow frota nach nozzle during a " Puff To.at."
I I
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.,.-..,.e..ve,i
,. w.er y-es. m
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g c, m m., et *wir-r-cre---w+r,+,e--r-e*,,e-m e-n e y-v,wy---
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i 11M&J1 fd1TMA LIlitTlRG. sD11DITID1LJDR_DMPATID1L.
- ). 7.10. 4 The following Halon system shall be OPERABLE.
Al1KilifAU. 18111111 09 Relay Room 4.
t AEl%ICADildTYJ.
Whenever equipment protected by tno Halon system is required to be OP2RADt2.
)
6.C110111.
a.
With the above required halon system inoporable, within one hour establish a continuous flre watch with backup fire supprossion equipaient for thoro arons in walch redundant nystems or componentu could be damagods for other arean, establish ar, hourly fire katch patrol.
Rostore the nyaton to 4
OPERADIE statun within 14 days or, in lieu of any other report. required by Spacification 6.9.1, prepara and submit a Special Report to the commission pursuant to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability e.nel the plans and schedule for resto:cing the system to OPERABLE status.
b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
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fi1MJdLLil10.2.MOMEliMCIS 4.7.10.4 The above required llalon system ahall be demonstrated OPERADLE:
a.
At least onca por 31 days by verifying that each valva (rnanual[n ita correct position. power operatwd or automat.ic) in the flow path in b.
At least once per 6 months by verifying the lialon storage tank weight to be at least 95% of full 5
charge weight (or level) and presture to be at least 90% of the full charge pressure.
c.
At least onco por la months by:
2.
Venifying the system, incitding associated ventilatAon dampors and fire door release mechaninms, actuates manually and automatically, upon receipt of a simulated actuation signal, and i
2, Perfor1 hance of a flow test through headers and noxzlos to assure no blockage.
1 1
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J URE LLOM STATlME
!df1JTllio CONJ)J.Tlo.)).JCLRlRMIION 341.10.5 Thu tiro hope stationa shown in TABLE 3.1-5 ahall be OPERABLE.
AIM S)RSB,.Ltd L i Whenever tquipment in the arco protocted by the ifro houe statiorn is required to bo OPERA 3LE.
ACT10,N1 a.
With one or more of the firo hone ntations shown in Table 3.7-5 inoperable, provido garod Wyo(s) on the nearest OPERAB!,8 hoco station (s).
One outlet rf the w/o chall be connected to the standard iangth of haue provided ut the hons station.
The sucond outlet of the wyn chall be connected to a length of hoso sufficient to provido coverago for the area lett unprotected by the inoperable huon statior.,
Whero it can iao demonstrated that the phyalcal routing of the fire hoce vould result in a rcergnizabiu hazard to operating technicirna, plant equipmont, or the hone itoolf, the fire hose shal'1 be stored in a rcil at the aut]ct of the OPERABLE hooe station.
Signs shall bo mounteci above the wyo(s) to identify the proper hone to uso.
The above ACTION requirencnt shall be accomp11ohod within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> if thu inoperable tiro hope in the primary means at firo uupproosion; otherwise ot<tsblish the additional I?ose capability within 5.4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
b.
The provisions of specificationu 3.0.3 and 3.0.4 are not applicable.
4 Unit 1
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fdJIf,LEILLANCE REQUIREMENTS-4.7.10.5 Each of the fire hose stations shown in Table 3.7-5 shall be demonstrated OPERABLE:
a.
At least once por 31 days by a visual inspection of the fire hose stations accessible during 71 ant operations to assure all required equipma nt is at he station.
b.
At least once per 10 months by:
- 3..
Visual inspection of the stations not acecosible during plant operations to aasure all required equipment is a the station, 2.
Removing the hose for inspection and re-rocking, and 3.
Inspecting all gaskets and replacing any degraded gaskets in the couplings.
c.
At leant once per 3 years by:
1.
Partially opening eacn hose station valve to verify valve OPEAABILITY and no flev blockage.
2.
Conducting a hose hydrostatic test at a pressure of 150 psig oc at least 50 psig above maximum fire main operating pressure, whichever is greater.
4 Unit 1 I
1 1
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I TAD 1% 3.7_-5 ElRE 110SI S. TAT 10HE LOCATION
- NOSE VALVE ELEVATIQ1{
CQJ&Mll IDEllTIFICATJ.ON Auxiliary Building 122' BB-13.8 1FP277 122' GG-14 1FP138 122' NN-14 1FP76 100' AA-14.2 2FP231 100' E2-14 2FP283 100' GG-14 1FP137 100' NN- ?.4 1FP75 84' AA-14.2 2FP230 R4' GG-14 1FP136 848 NN-14 1FP74 64' AA-14.2 2FP229 64' GG-14 1FP135 64' NN-14 1FP73 55' GG-14 1FP134 tiesharlic.11 nenetration Am 100' KK-10.4 1FP279 9911tA1DRO.Dt 130' A6 17P89 130 A17 1FP96 78' A6 1FP88 78' A17 1FP97
- List all Fire 11ose Stations required to ensure the OPERABILITY of safety-related equipment.
Unit 1
YARD FIEE HYDRANTS MD llYDRAliT ll0E 110MES L1112TitM_ C.QRDITION FOR OPERATION -
3.7.10.6 The yard fire hydrants and associr..ad hose houcos shown in Table 3.7-6 shall be OPERABLE.
APPLICABIL;IY.i Whenever equipment in the areas protected by the yard f,.re hydrants is required to be OPERABLE.
ACTIONt a.
With one or more of the yard tire hydrants shown in Table 3.7-6 inoperable, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> have sufficient additional lengths of 2 1/2 inch diameter hose located in an adjacent OPERABLE hydrant hose houso to provide service to the unprotected area (s) if the inoperable fire hose is the primary means of fire suppression; otherwise, provide the additional hose within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Restore the hydrant or hose house to OPERABLE status within 14 days or,ication 6.9.1, prepare and in lieu of any other report required by Specif submit a Special Report to the commission pursuant to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the snd the plans and schedule for inoperability, hydrant or hose house to OPERABl2 restoring the status.
b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable, SEVIILIANCE _REOU1REMEETE 4.'.10.6 Each of the yard fire hydrants and associated hydrant hose houses shown in Table 3.7-6 shall be demonstrated OPERABLE:
a.
At least once per 31 days by visual inspection of the hydrant house to assure all required equipment is at the hose house.
b.
At least once per 6 months (once during March.
3 April, or May and once during September, October, or Novenber) by visually inspecting each yard fire hydrant and verifying the hydrant barrel la dry and that the hydrant ls not damaged.
Unit 1
~. _ _
c.
At lear.t once per 12 me.iths by:
1.
Conducting a hose hydrostatic test at a pressure of 150 psig or at least 50 psig above maximum fire main operating pressure, whichever is greater.
2.
Inspecting all gaskets and replacing any degraded gaskets in the couplings.
3.
Perforring a flow check of each hydrant to verify its OPERABILITY.
l Unit 1
TABLE ; 7-6 XARD f_IEE aaRARrS AED AsfaOCIATED liYDRANT liq 1E }iQMSIS LOCATION
- HYDRANT [{pHREB Fuel Handling Duilding, Southwest yard 16FP50 Service Water Intake Structure 1FP50
- List all Yard Hydrants and Hydrant Hose Houses required to ensure the OPERABILITY of safety-related equipment.
Unit 7.
l l
l
I E1AUI SYSTEMS 3/4.7.11 EIRE RATED ASSEMBLIES LIMITING CONDITION FOR OPERATION 3.7.11 All fire rated assemblies floor / ceilings.
cable tray enclosures and other fire (walls, barriers) separating safety related fire areas or separating portions of redundant systems important to safe shutdown within a fire area and all sealing devices in fire rated assembly penetrations (fire doors, fire windows, fire dampers, cable and piping penes,ation seals and ventilation seals) shall be OPERABLE.
APPLICABILITY: At all times A.CTlDEi a.
With one or more of the above required fire rated assemblies and/or sealing devices inoperable, within one hour:
1.
Verify the OPERABILT.TY of tne fire detectors on both sides of the affected penetration and establish a daily fire watch patrol, or 2.
Verify the OPERABILITY of fire detectors on at least one sid'e of the affected penetration and establish an hourly fire waten patrol, or 3.
Establish a continuous fire watch on at least one side of the affected penetration.
b.
Restore the inoperable fire rated assembly and sealing device to OPERABLE status within 7 days or, in lieu of any other report required by Specification 6.9.1, prepare and submit a Speciti Report to the Commission pursuant to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the ino</arability, and the plans ard schedule for restir.fing the fire rated assembly and sealing device to OPERABLE status, c.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
Unit 1 I
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I INSTRUMENTATIQ11 3/4.3. 6 UEE DETICTIDH INSTRUMENTATIOl{
LIMITING CQHDlII9E FOR.OPEBATION 3.3.3.6 As a minimum, the fire detection instrumentation for each fire detection zone shown in Table 3.3-10 shall be operable.
APPLICABILLILL Whenever equipment procected by the fire detection instrumentation is required to be OPERABLE.
hCT.191LL With the number of OPERABLE fire detection instrument (s) less than the minimum number OPERABLE requirement of Table 3.3-10:
a.
Within i hour establish a fire watch patrol to inspect the zone (s) with the inoperable instrument (s) at least once por hour, unless the instrument (s) is located inside the containment, then inspect the containment at least once per 8 haurs or monitor the containment air torperature at least once per hour at the locations listed in Specifcation 4.6.1.5.
b.
Restore the inoperable instrument (s) to OPERABLE status within 14 days or, in lieu of any other report required by specification 6.9.1, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability, and the plans and schedule for restoring the instrument (s) to OPERABLE status.
c.
The provisions of Specifications.3.0.3 and 3.0.4 are not applicable.
Unit 2
SURVEILL&l[QL.RE.QlllBfdiENTS 4.3.3.6.1 E:.
if the above required fire detection instruments t
- h are accessible during plant operation shall be demonstrated OPERABLE at least once per 6 months by performance of a TRIP ACTUATING DEVICE OPERATIONAL TEST except for restorable spot type thermal heat detectors, which shall be tested such that at least one detector on each signal-initiating circuit will be tested at least once por G months, such that all detectors are tested in 5 years.
Fire detectors which are'not necessible during plant operation shall be demonstrated OPERABLE by performance of a TRIP ACTUATING DEVICE OPERATIONAL TEST during each COLD SHUTDOWN exceeding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> unicas performed in the previous 6 months.
- 4. 3. 3. 6. 2 The NFPA Standard 72D supervised circuits supervision associated with tne detector alarms of each of the above required fire detection instruments shall be demonstrated OPERABLE at least once per 6 months.
Unit 2
i TABLE 3.3-10_
FIRE DETECTION INSTRUMENTS Minimum Total Type "A" Type "B" Detectors Description No. of Detectors Detectors Operable Zone Area Breakdown Detectors (Note 1)
(Note 2)
(Note 3) a61
. Aux Sidg Cooridor Area El 200.
6 6
4 61 Service Bldq Cable Vaults (Note 4) 6 2A & 2B Cable Vaults, El. 113' 3
2 20 & 2D Cable Vaults El. 113' 3
2 62 Battery Rooms El. 100*
7 2A 125VDC El, 100*
2 1
2 250VDC El. 10C' 3
2 i
2B 125VDC El. 100*
2 1
2 63 Radiation Monitor Enclosure El.120' 1
1 1
65
- m. 2 control Censole 2
2 1
66 Competer Room 2
2 1
67 C+ trd Irea Ceiling Void Space 6
6 4
68 Conttd Aux-Equip Room 9
9 6
69 Fuel Handling Building 13 i
Vent Equip Room 3
2 l
-Elect Control Area 2
1 New/ Spent-Fuel Storage Area 5
4 i-Storage aci Service Area 3
2 70 2A, 2B, 2C Diesel Gen Control R=s 3
2A Control Room 1
1 2B Control Room 1
1 2C Control Room 1
1 71
.Maint & Test Equip Room El. 122' BB-15.7 1
1 1
75 Swgr Rooms & Penet Area Ventitations 3
Electrical'Penet Area Vent System 2
2 Switchgear Room Vent System 1
1 76 Relay Roos & Control Roon Air Cond*g 3
3 3
77 Aux Bldg East Aisle 2 El. 84 4
4 4
78 Aux Bldg Vest Aisle 2 El. 84 6
6 6
79 Aux Bldg 12 LTDN/ Seal Hx Entry El. 84 2
2 2
SALEM - UNIT 2 3/4 3-48
TABLE 3.3-10 FIRE DETECTION, INSTRUMENTS Minimum Total Type "A" Type "5" Detectors No. ot Detectors Detectors Operable Description Detectors (Note 1)
(Note 2)
(Note 3)
Zone Area Breaklown 20 81 Switchgear & Battery Rooms El. 64*
18 16 Switchgear Roca El. 64' 2
1 2C 125VDC Battery Room El. 64' 18 18 15 32 Switchgear Room El. 84 13 13 11 83 Electrical Penetration Area El. 78*
2 85 Diesel F.O. Transfer Pumps El. 84 1
1 No 22 Diesel T.O. Transfer Pump 1
1 No 21 Diesel F.O. Transfer Pump 2
2 1
86 No. 21 Diesel F.O. Storage Tank El. 84*
2 2
1 87 No. 22 Diesel P.O. Storage Tank El. 84*
7 88 2A Diesel Gen Area El. 100*
4 3
2A Diesel Gen Roo= El. 100*
1 1
2A Control Room El. 100*
2 2
2A Day Tank Room El 120*
7 89 28 Diesel Gen Area El. 100*
4 3
2B Diesel Gen Roon El. 100*
1 1
2B Control Room El. 100*
2 2
2B P y Tank Room El. 120' 7
90 2C Dier een Area El. 100*
4 3
2L Jiesel Gen Roon El 100*
1 1
2C Control Room E1. 100' 2
2 2C Day Tank Rcom El. 120' 9
9 17 91 Relay Roc =
(Note 5)
(ZIU 91, cdd numbered detectors) 9 9
91 Relay Room (ZIU 96, even numbered detectors) 14 14 13 97 Switchgear Room El. 84 6
6 5
98 Electrical Penetration Area El. 78*
101 No. 22 Fuel Edlg Area Exhaust El 100 1
1 1
1 1
1 102 containment Pressure Relief El 100 1
1 1
j No. 21 Iodine Removal El 78 103 3/4 3-49a SALEM - UNIT 2 4.
TABLE 3.3-10 FIRE DETECTION INSTRUMENTS Minimum
- 1otal Type "A" Type "B" Detectors Description No. of Detectors Detectors Operable Zone Area Breakdown Detectors (Note 4)
(Note 2)
(Note 3) 104 No. 22 Iodine Removal El 78 1
1 1
105-Control Room Air Cond'g El 100 1
1 1
106 Aux Bldg Air Cond'g El 100 1
1 1
121 North Penetration El.. 92*-6" & 100*
6 6
5 122 Elect Penetration El. 100' 6
6 4
123 Mech Penet. East El. 100' 6
6 4
124 Mech Penet. West El. 100*
5 5
4 125 Aux Bldg Elev. 100 Col 14-16.2~FF-LL 22 Corridor, det's 125-1 to 125-5, & 125-17 6
5 Boric Acid Evap Rm, Dat's 125-11 to 125-13 3
2 Radio chemistry Lab, Det's 125-18, 125-19, 4
3 125-21, & 125-22 Misc Areas, Det's 125-6 to 125-10, 125-14 9
9 to 125-16, & 125-20 126 Aux Bldg Boric Acid Trans Pumps El. 100' 3
3 2
127 Containment Fan Coil Unit 21 & 22 E1. 130' 12 Ring Duct by 21 FCU 2
2 Ring Duct by 22 FCU 2
2 Above 21.FCU 4
3 Above 22 FCU 4
3 128 Containment fan Coil Unit 23 & 24 El. 130' 12 Ring Duct by 23 FCU 2
2 Pia 7 Duct hy 24 FCU 2
2
,.sove'23 FCU 4
3 Above 24 FCU 4
3 129
. Containment Fan Coil Unit 25 El. 130' 6
. Ring Duct by 25 FCU 2
2 Above 25 FCU 4
3 130 Containment RCP 21 Bel El. 130' 4
4 3
131 Containment RCP 22 Bel El. 130' 4
4 3
132 Containment RCP 23 Bel El. 130' 4
4 3
SALEM - UNIT 2 3/4 3-49b
TABLE 3.3-10 FIRE DETECTION INSTRUMENTS _
Minimum Tots]
Type "A" Type "B" Detectors No. of Detectors Detectors Operable Description Detectors (Note 1)
(Note 2)
(Note 3)
Zone Area Breakdown 4
4 3
133 Containment RCP 24 Bel El. 130' 5
5 4
134 Aux Bldg $2 A.C. Equip Room El. 122' 10 10 P
135 Aux Bldg 82 A.C. Room El. 122' 136 Aux Bldg Resin Storage Area El. 122' 4
4 3
4 4
4 137 Aux Bldg East Aisle El. 64' 8
138 Aux Bldg West Aisle El. 64' 7
7 V Aisle El. 64' 1
1 In Duct - CVCS Hold Up Tanks Vent Syst 7
7 6
141
. Aux Bldg 21 & 22 Waste Gas Compr Area El. 64' 7
142 Aux Bldg 21 & 22 RHR Pumps Elev 45 4
3 21 RER Pump El.45' 4
4 3
22 RHR Pump El.45' 7
7 7
143 Aux Bldg El. 55' 6
144 SIF-CCP El. 84' 3
2 Component Cooling 3
2 Safety Injection 8
145 CO2 Equip Rm Chg PMP & SIP CS Pump Elev 84 3
2 i
3 CHG - SIP 2
2 CO2 Equip Room 8
8 6
146 Piping Penetetration El. 78' 5
5 4
147 Aux Feed Pumps El.84' 7
- 148 Control Area East Corridor 1
1 Janitor Closet 6
4 I
Work Control Center & Corridor 148 No. 21,22,23 Service Utr Pump Bay (Note 6) 7 7
5 7
- 149 Control Area East Corridor - Ceiling Void 1
1 Jartitor Closet 6
4 Work Control Center & Corridor 16 16 14
- 150 Service Vtr Pipe Tunnel Area El. 88 150 No 24,25,26 Service Vtr Pump Bay (Note 6) 7 7
5 3/4 3-49c SALEM - UNIT 2
TABLE 3.3-10 FIRE DETECTION _INSTREMENTS Minimum Total Type "A" Type "B" Detectors Description No. of Detectors Detectors' Operable Zone Area Breakdown Detectors (Note 1)
(Note 2)
(Note 3) 152 No 21,22,23 Service Vtr Pump Control Room (Note 6) 1 1
1 154 No 24,25,26 Service Vtr Pump Control Room (Note 6) 1 1
1 157 Aux Bldg 121 & 22 Monitor Tank El. 64' 4
4 4
158 Aux Bldg #21'Vaste Hold-up Tank El. 64' 2
2 2
159 Aux Bldg #22 Vaste Hold-up Tank El. 64*
2 2
2 160 Aux Bldg #2 Waste Monitor El. 64' 2
2 2
- - Indicates d tection zones containing both Unit 1 and Unit 2 equipment or cables or detection zones covering a pcrtion of a Fire Area containing both Unit 1 and Unit 2 equipment which may directly expose both Units. In the event that the zone is rendered INOPERABLE, ensure that the action statement is logged and compensatory measures are established based on the equipment required OPERABLE for both Units, not just the Unit to which the zone alarms. Additionally, in the event that a fire alarm is received from any of these zones, ensure that both Control Rooms are alerted to the condition to ensure that any necessary operational actions are taken.
Note 1 - Type "A" detectors are for early warning indication only.
Note 2 - Type "B" detectors are for suppression system actuation.
Note 3 - Where the minimum detectors OPERABLE indicated is less than one less than the total number of detectors for the zone, no two detectors sha71 be adjacent to each other.
SALEM - UNIT 2 3/4 3-49d j
TABLE 3.3-10 FIRE DETECTION INSTRUMENTS Note 4 - This zone.i:s provided for Cable Vaults'for.both Units 1 and 2.
Alarm indication, however, is received in the Unit 1 Control Room only. Upon confirmation that the alarm received is from a Unit 2 Cable Vault, detector, Unit 1 Control Room personnel shall notify Unit 2 Control Room personnel to ensure any necessary operational actions are taken.
In the event that this' zone is rendered INOPERABLE, Unit 1 Control Room personnel shall notify Unit 2 Control Room personnel and the appropriate action statement shall be logged'against both Units 1 & 2.
Note 5 - Zone 91 is a cross zoned detection system used for actuation of the halon suppression system for the Relay Room. Therefore, the minimum detectors OPERABLE is based on 18, the combined number of detectors for both zones of the cross zoned system.
Note 6 - Zones 148, 150, 152, & 154, monitored by the Unit 1 Control Room, protect Unit 2 Service Vater Pump Bays and Control Rooms. Upon receipt of an alarm from any of these zones, Unit 1 Control Room personnel shall notify Unit 2 Control Room to ensure any necessary operational actions are taken. In the event that any of these zones are rendered INOPERABLE, Unit 1 Control Room personnel ; hall notify Unit 2 Control Room personnel and the appropriate action statement shall be logged, as a minimum, against. Unit 2.
StLEM - UNIT 2 3/4 3-49e
PLANT SYSTEMS 3/4.7.10 ElRE SUPPRESSION SYSTEMS IIEE SUPPRESSION HATf2 EJEIEM LIMITING CONDITION FOR OfEJtATION 3.7.10.1 The fire suppression water system shall be OPERABLE with:
a.
Two OPERABLE fire suppression pumps, each with a capacity of 2500 gpm, with their discharge aligned to the fire suppression header, b.
Separate water supplies, each with a minimum contained volume of 300,000 gallons, and c.
An OPERABLE-flow path capable of taking suction from either or both of the fire water storage tanks and transferring the water through the distribution piping with OPERABLE sectionalizing control or isolation valves to the yard hydrant curb valves the last valve ahead of the water flow alarm device on each sprinkler or hose standpipe, and the last valve ahead of the deluge valve on each deluge or spray system required to be OPERABLE per Specifications 3.7.10.2, 3.7.10.5, and 3.7.10.6.
APPLICABILITY.i At all times ACTION:
a.
With one pump and/or one water supply inoperable, restore-the inoperable equipment to OPERABLE status within 7 days or, in lieu of any other report-required by specification 6.9.1 prepare and submit a special Report to the Commisskon pursuant to Specification 6.9.2 within the next 30 days outlining the plans and procedures to be used to restore the inoperable equipment to OPERABLE status or to provide an alternate backup pump or supply.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable, b.
With the fire suppression water system otherwise inoperable:
1.
Establish a backup fire suppression water system within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, and Unit 2
l 2.
In lieu of any other report required by Specification 6.9.1,ification 6.9.21 submit a Special Report in accordance with Spec a)
By telephone within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, b)
Confirming by telegraph, mailgram or facsimile transmission no later than the first working day following the event, and c)
In writing within 14 days following the event, outlining the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status.
SURVEI LIANCLREOUIREMEt1S 4.7.10.1.1 The fire suppression water sy. tem shall be s
demonstrated OPERABLE:
a.
At least once per 7 days by verifying the contained water supply volume.
b.
At least once per 31 days by verifying that each valve (manual, power operated or automatic) in the flow pata which is accessible during plant operation is in its correct position.
Valves which are locked, sealed, or otherwise secured and not accessible during plant operation shall be verified to be in the correct position during each COLD SHUTDOWN exceeding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> unless performed in the previous 31 days.
c.
At least once per 12 months by performance of a system flush.
d.
At least once per 12 months by cycling each testable valve in the flow path through at least one complete cycle of full travel.
Unit 2
E e.
At least once per 18 months by performing a system functional test which includes simulated automatic i
actuation of the system throughout its operating sequence, undt 1.
Verifying that each automatic valve in the flow path actuates to its correct position, 2.
Verifying that each pump develops at least 2500 gpm at a system head of 250 feet, 3.
Cycling each valve in the flow path that is not 1
testable curing plant operation through at least one complete cycle of full travel, and 4.
Verifying that each fire suppression pump starts - (sequentially) to maintain the fire suppression water system pressure greater than or equal to 135 psig.
f.
At least once per 3 years by performing a flow test Section of.the system in accordance with Chapter 5,ition, 11 of the Fire Protection Handbook, 14th ed published by'the National Fire Protection Association.-
4.7.10.1.2 The fire pump diesel engines shall be demonstrated OPERABIA:
a.
At least once per 31 days by verifying:
1.
Each fuel storagc tank contains at least 300 gallons of fuel,-and-
- 2. -Each diesel starts from ambient conditions and operates for at least 30 minutes on-recirculation flow.
b.
At least once per 92 days by verifying that a i
sample of diesel, fuel from the fuel storacfe tanks within obtained in accordance with ASTH-D270-65, the acceptable limits specified in Table 1 of ASTM D975-74:when checked for viscosity, water and
- sediment, c.
At least once per 18 months, during shutdown, by subjecting the diesel to an inspection in accordance with procepures prepared in conjunction with its manufacturers recommendations for the class of service.
I i
t l
Unit 2 l
l l
4.7.10.1.3 The fire pump djesel starting 24-volt battery bank and charger shall be demonstrated OPERABLE:
a.
At least once per 7 dayu by verifying that:
1.
The electrolyto level of each battery is above the plates, and 2.
The overall battery voltage is greater than equal to 24 volts, b.
At least once per 92 days by verifying that the specific gravity is appropriate for continued service of the battery.
c.
At least once por la months by that:
1.
The batterica, coll plates and battery racks show no visual indication of physical damage or abnormal deterioration, and 2.
The battery-to-battery and terminal connections are clean, tight free of corrosion and coated with anti-corronion material.
Unit 2
l P16RT_D ETEMS S. PRAY AMD/_QlLMRIllELER_EYETEKS LIREUM3911DlII0lLEQR.93'ERATIQH 3.7.10.2 The following spray and/or sprinkler systems shall bo OPERABLE:
lih%ARD ABEA C931tailllMat
- No. 21 Reactor Coolant Pump Lube Oil System
- No. 22 Reactor Coolant Pump Lube Oil System
- No. 23 Reactor Coolant Pump Lube Oil System
- No. 24 Reactor Coolant Pump Lube Oil System
- No. 21 Containment Iodine Removal Charcoal Filter
- No. 22 Containment Iodine Removal Charcoal Filter ARKiliary iblilding
- Auxiliary Building Ventilatien Removal Charcoal Filter
- Control Room Emergency Ventilation Charcoal Filter
- Containment pressure Relief Charcoal Filter
- No. 21 Diccol Fuel Oil Storage. Tank Roou
- No. 22 Diesel Fuel Oil Storage Tank Room
- No. 21, 22, L 2 3 Charging Pun.ps
- No. II, 22, & 23 Auxiliary Feedwater Puups (electrically l
actusted preaction sprinkler system)
- No. 21, 32, & 23 Auxiliary Feedwater Pumps (pneumatically ectuated preaction st"inkler system)
ARPRCARGITY1 hhnever equipment protouted by the spray /aprinkler system is required to be OPERABLE.
hSIl4131 a.
With cr.m or more of the above required spray and/
or sprinkler systems inoperable, within one hour establish a continuous fire watch with backuo fire suppression equipment for those areas in whihh l
redundant systers or components cou.ld be damaged; i
for other areas, establish an hourly fire watch i
patrol.
Restore the system to OPERABLE status within 14 dhys or, in lieu of any uther report required by Specification 6.9.1, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within the next 30 days D
outlining the action taken, the cause of the l
inoperability and the plana and schedule for l
rentoring the system to OPERABLE status.
I b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
l l
Unit 2
~__ _
l MEYmwmK.mularmnfi 4.7.10.2 Each of tha above required upray and/or sprinkler systems shall be demonntrated OPTRABTE:
a.
At least once per 31 days by verifying that each valve (manual, power operated or automatic) in the flow path which is accessible during operation is in its correct position. plant Valves which are locked, sealed, or other secured and not accessible during plent. operation shall be verified to be in the correct' position during each COLD SHUTDOWN exceeding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> unless performed in the 4
previous 31 days.
b.
At least once per 12 months by c-l cling each testable valve in the flow path chrough at least 4
one complete cycle of full travel.
c.
At least once por 18 months:
1.
By performing 4. system functional test which includes simulated automatic actuation of the system, and:
a)
Verifying that the autcmatic valves in the flow path actuate to their correct positions on a test signal, and b)
Cycling each valve in the flow path that-is not testable during plant operation through at least one completo cycle of full travel.
2.
By a visual inspection of the dry pipo spray and sprinkler-hcaders to verify their
-integrity, and 3.
By a visual inspection of each sprinkler or deluge nozzle's spray area to verify spray r
pattern is not obstructed.
i L
d.
At leant once per 3 yearn by perforning an air flow test through each open head spray / sprinkler header and verifying each open head spray / sprinkler nozzle is unobstructed.
l i
i Unit 2
~
i l
CQ2 EIMIEIE i
\\
l LIMITING.CQHDITIQM_EQR_QffRATION 3.7.10.3 The following low pressure CO2 systems shall be OPERABLE:
Auxiliary flg11 ding
- 2A Diesel Generator Area
- 2B Diesel Generator Area
- 2C Diesel Generator Area
- No. 21 Diesel Fuel Oil Storage Tank Room
- No. 22 Diesel Fuel Oil Storage Tank Room
- No 21 & 't2 Diesel Fuel Oil Transfer Pump Rooms
- 460 VAC Switchgear Room 4160 VAC Switchgear Room ElEC3riCA1 E2nittIAkiAD ATf2
- Lower Electrical Penetration Area AREM.CADXMTh Whenever equipment protected by the CO2 systems is required to be OPERABLE.
ACTlQKl.
a.
With one or more of the above required CO2 systems inoperable, within one hour estr.b]ish a cont 3auous fira watch with backup fire suppression equipment for those areas in which redundant systems or components could be damaged; for other areas, establish an hourly fire watch patrol.
Restore the e stem to OPERABLE status within 14 days or in 3 au of any other report required by Specif1 cation 6.9.1, prepare and submit a Specit. ' Report to the Commission pursuant to Specificatic.
6.9.2 within the nex.t 30 days cutlining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to CPERABLE
- statue, b.
The provisions of Specifications 3.0.3 and LO.4 are not applicable.
i i
Unit 2
SRBYEILLANCE REOUIRE}iEJ{TS 4.7.10.3.1 Each of the above required CO2 systems shall be demonstrated OPERABLE at least once per 31 days by verifying that each valve (manual, power operated or automatic) in the flow path is in its correct position.
4.7.10.3.2 Each of the above required low pressure CO2 systems shall be demonstrated OPEkABLE:
a.
At least once per 7 days by verifying the C07 storage tank level to be greater than 501 and pressure to be greater than 285 psig, and b.
At least once per 18 months by verifying:
- 1. The system valves and associated ventilation dampers and fire door release mechanisms actuate manually and automatically, upon receipt of a simulated actuation signal, and 2.
Flow from each nozzle during a " Puff Test."
I r
f Unit 2
-a..
a
lib.LQL{ SXS.TDiS LI}ilTING __ CQFDITIOjilQR OPERATION 3.7.10.4 The following Halon system shall be OPERABLE.
Aux 11iary Egilding
- Relay Room AEELI.C.ADILI.TXi Uhenever equipment protected by the Halon system is required to be OPERABLE.
hC11.QEli a.
With the above required halon system inoperable, within one 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 hourly tire watch patrol.
Restore the system to OPERABLE status within 14 days or, in lieu of any other report required by Specification 6.9.1, prepare and submit a Special Report to the Commissien pursuant to Specification 6.9.2 within the next 30 days outlining the action taken, the cauce of the inoperability and tha plans and schedule for restoring the system to OPERABLE status.
b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicsble.
i Unit 2
24 SURVEILM_ REQ 111RQiETIA 4.7.10.4 The above required Halon system shall be demonstrated OPERABLE:
a.
At least once per 31 days by verifying that each valve (manual power operated or automatic) in the flow path is [n its correct position.
b.
At least once per 6 months by verifying the Halon storage tank Veight to be at least 95% of full charge weight (or level) and pressure to be at least 90% of the full charge pressure.
c.
At least once per 18 months by:
1.
Verifying the system, including associated ventilation dampers and fire door release mechanisms, actuates manually and automatically, upon receipt of a simulated actuation signal, and 2.
Performance of a flow test through headers and nozzles to assure no blockage.
s tinit 2 1
g
-_m...
a 1
2 Y
ElRii JLO_Sfi ET.&TI_ONS IdMTING CONDITION fQR OPERATION 3.7.10.G Tite-firo hose stations shown in TABLE 3,7* 5 shall
- c be OPERABLE.
i Af PI,1C Af}JAITY; Whenever equiprent in the aron protected by the fire hone aLatiana 10 r quired to bo OPERABLE.
bgT)ON1,-
i a.
With one or more'of the fire' hone stationo chosn I
in Table 3.7-5 Inoperable, provide gared wyu{a) on the nearcot OPERABLE hose station (n).
One oatlet of the wye shall be connected to the atandard length of hose provided at the hono statich.
The cocond outlet of the.wyo shall be connected to 4 lengt24 of hose aufficient to provide coverage Ior the area left unprotected by the inoperable _hoso atation.- Where it can he' demonstrated'that the physical routing of the fire hode would result lu a recognizable hazard to operating technicians, plant. equipment, or the houe itoolf, the fire t.000 chall be stored in a roll at the outlet of the OPERADLE hole Station.
Signs shall be-mounted d
.above the wye (s) to identify the proper hone to use..
The above ACTION requirement shall be
'accompliabod within I hour if the inoperable. fire houe is the primary moana of. fire supprension;
.othorwise catablish the additional-hone cat. ability within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, b,
-The provisions'of.~ Specifications 3.0.3 and 3.0.4 L.
are not applicable.
~ l l
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W!tVLUJ NLCLREWIREMEtIIS_ _.
4. '/,10. 5 E'ach of the fire hostt stations Shown in Tablo 3.7-S ahall be denonatrated OPERANE.1 a.
At lout,t once por 31 days by a viaual inspection of the fire hose stations accessible during plant operaticns to assure all required (quipment is at chs station, b.
At least once per le months by:
1.
Vinual inspect.lon of the stations not accessible during plant operationu to sasure a11 requ.1 red equlpr.ont in a the statjon, 2,
Removing the home for inspection an1 rc~
racking, and 3.
l'nspacting all gatskota nnd replacing any
(,'agraded gaakota in the coup.11ngs, c.
At least once por
') years ',ay:
1.
Partially opaninq each hose station valve to verify valvo OPERAMLITY and no flov blockago, 2.
C:Jnducting a hose hydrostatic toat at a pwssure of 150 psig or at least 50 poi J above maximum fire main operat,ing prosaure, wh,8chover is greater, I
f l
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Unit 2 Io a
TAMS 2.d.-1 l
EIEE liO2F. ETAIlQHS LOCATION *.
HOSE VALVE ELUIATl9R
_C91'RiN IDIt'IIILCAT10H Auxi1iuv finiMing 122' 68-13,8 1FP277 1223 GG-14 2FP138
- 3. 2 '2
- NN-1/.
2FP76 1008 AA-14.2 2FP231 100' EC-14 2FP283 100' GG-14 2FP137 100' NN-14 2FP75 84' AA-14.2 2FP230 848 GG-14 2FP136 34' IIN-14 2FP74 64' AA-14.2 2FP229.
64' GG-14 2FP135 64' UN-14 2FF73.
55' GG-14 2FP134 E%hDni!2Al EAnatIB.tl.QB hTRA 100' KK-13 2FP279
. Cont 3inatat
.130' B6 2FP09 120 B16 2FP96 78' B6 2FP88 78' B16 2FP97 p
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- List all Fire I!one Stations required to ensure the
+
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i-l laan LEI HYDRANTS AED HYDRANl ILQSI lipy1ES 7_
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LIMITING CQHDLIl0H.10R_QPIRAT10N 3.7.10.6 The yard fire hydrants and associated hose houses shown in Table 3.7-6 shall be OPERABLE.
APPLICARILII11 Whenever equipmer.c in the areas protected by
~
the yard fire hydrants is required to be OPLPADLE.
E ACT10H1 1
l a.
With one or more of the yard fire hydrants shown in Table 3.7-6 inoperable, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> have sufficient additional lengths of 2 1/2 inch diameter houe located in an adjacent OPERABLS hydrant hose house to provide service to the unprotected area (s) if the inoperable fire hose is a
the primary tocans of
- ire suppression; othe rw ise,
provido the additional hose within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Rectore the hydrant or hose house to OPERABLE status within 14 days or, in lieu of any other report required b'; Specification 6.9.1, preparo und submit a Special Report to the Commission pursuant to Specification 6.9.2 within.he next 30 days outlining the action taken, th( cause of the inoperability, and the plans ont schedule for restoring the hydrant or hose houe; to 09EHAB12
- status, b.
The provisions of specifications 3.0.3 and 3.0.4 are not applicable.
EURYELIJR9E REOUIREMENTS 4.7.10.6 Each of the yard fire hydrants and associated hydre. t hose houses chown in Table 3.7-6 cha)1 be demonstrated OPERABLE:
a.
At least once per 31 days by visual inspection of the hydrant house to assure all required equipment is at the hose house.
b.
At least once per 6 months (once during !iarch.,
April, or May and once during September, October, or November) by visoally inspecting each yard fire hydrant and verifying the hydrant barrel 1s dry and that the hydrant is not damaged.
Unit 2
4 1
4 J
c.
At least once'per 12 months by 1.
Coriducting a hose hydrostatic test at a pressure of 150 psig or at least 50 poig above maximum fire main operating prosaure, whichever is greater.
Inspecting all gaakets nnd replacin 2.
degraded gaskets in the coup 11nga. g any 3.
Performing a flow chock of each hydrant to verify its OPERABILITY.
a e
2 Unit 2
t TA %E 3.7-6 XARD IIBA IIXDEMIS AHD MfiOCIATED RYpBART RQEE HauEEs W ATIOE liYDRANT NUMBgg Fuel Handling Building, Northwest yard 18FP50 Service Water Intake Structure 1FP50 List all Yard Hydrants and Hydrant Hose Houses required to A
ensure the OPERABILITY of safety-related equipment.
Unit 2 x
l
PLANT SYSTEMS 3/4.7.11 flBE RATED ASSEMB_ LIES LIMITING CONDITION FOR OPERATION 3.7.11 All_ fire rated assemblies (walls, floor / ceilings.
cable tray enclosures and other fire barriers) separating safety related fire areas or separating portions of redundant systems important to safe shutdown within a fire area and all sealing devices in fire rated assembly penetrations (fire doors, fire windows, fire dampers,-cable and piping penetration seals and ventilation seals) shall be OPERABLE.
APPLICABILITY: At all times ACTION:
a.
With one or more of the above required fire rated assemblies and/or sealing devices inoperable, within one hour:
1.
Verify the OPERABILITY of the fire detectors on both sides of the affected penetration and establish a daily fire watch patrol,-or 2.
Verify the OPERABILITY of fire detectors on at least one sid'e of the affected penetration and establish an hourly fire watch patrol, or 3.
Establish a continuous fire watch on at least one side of the affected penetration.
b.
Restore the inoperable fire rated assembly and sealing device-to OPERABLE status within 7 days or, in lieu of any other report required by Specification-6.9.1, prepare and submit a Special Report to the commission pursuant to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability, ire rated and the plans and schedule for restoring the f assembly and sealing device to OPERABLE status, c.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
Unit 2
-l SURVEILLANCE REOUIREMENTS 4.7.11.1 At least once per 18 months the above required fire rated assemblies and penetration sealing devices shall be
{
verified OPERABLE by:
a.
Performing a visual inspection of the exposed surfaces of each fire rated assemblies.
b.
Performing a visual inspection of each fire window, fire damper and associated hardware.
c.
Performing a visual inspection of at least 10 percent of each type of sealed penetration.
If apparent changes in appearance or abnormal degradations are found, a visual inspection of an additional 10 percent of each type of sealed penetration shall be made.
This inspection process shall continue until a 10 percent sample with no apparent change in appearance or abnormal degradation is found.
Samples shall be selected such that each penetration seal will be inspected at least once per 15 years.
4.7.11.2 Each of the above required fire doors shall be verified OPERABLE by inspecting the automatic hold-open, release and closing mechanisms and latches at least once per 6 months, and by verifying:
a.
The position of each closed fire door at least once per 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
b.
That doors with automatic hold-open and release mechanisms are - free of obstructions at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
c.
The position of each locked closed fire door at
-least once per 7 days, d.
The OPERABILITY of the fire door supervision system by performing a TRIP ACTUATING DEVICE OPERATIONAL TEST at least once per 31 days.
Unit 2
&m
ATT ACliMENT 4 PROPOSED CHANGES TO FIRE PROTECTION PROGRAM DESCRIPTION IN Tile SALEM Gi:NERATING STATION, UNIT NOS, 1 AND 2 UPDATED FINAL SAFETY ANAL,YSIS REPORT The attached UFSAk pages, in conjunction with the proposed revised Technical Specification in Attachment 3, would, upon review and approval by the USNRC, form the basis for removal and relocation of t he f i re prot ect ion program f rotu the Technical Specifications in accordance with the provisions of Genetic Letters 86-10 and 88-12.
9.5.1 Fire Protection 9.5.1.1 Eire Protection _Etogam The Salem Generating Station Fire Protection Program has been established to prevent significant fires, to ensure the capability to shutdown the reactors and maintain them in a i
safe shutdown condition, and to minimize radioactive releases to the emironment in the event of a significant fire. De Fire Protection Program implements the philosophy of defense in depth protection against the hazards of fire and its associated affect:. on equipment important to safety by:
1.
Preventing fires from starting.
2.
Rapidly detecting, controlling, and promptly extinguishing those fires that do occur.
3.
Providing protection for structures, systems, and components important to safety so that a fire that is not promptly extinguished by the fire suppression activities will not prevent the safe shutdown of the plant.
The Salem Generating Station Fire Protection Program censists of design features, equipment, personnel, and proce'dures : hat provide defense in depth protection of the public health and safety. The Salem Fire Protection Program is described in several documents:
A program description which establishes the basis for the fire protection program at the Salem Generating Station. The Report identifies and documents principal fire protection commitments made between the Nuclear Regulatory Commission and Public Service Electric & Gas Co. through a narrative _ description of the Fire Protection Program. The report also provides a comparison to Appendix A of BTP APCSB 9.51.
A report which establishes the basis for demonstrating a capability to achieve and maintain post-fire safe shutdown in accordance with Appendix R to 10 CFR 50. This report, also establishes the information and format of the information to be utilized for long term compliance to Appendix R to 10 CFR 50.
A report which identifies the cables and the routing of the cables that were utilized in the assessment of post fire safe shutdown.
A report which outlines the Fire Hazards Analysis performed for Salem Generating Station in accordance with USNRC Branch Technical Position B'. J-APCSB 9.51 Appendix A " Guidelines for Fire Protection for Nuclear Power Plants".
l 9.51 l
l L
A report which defines and assesses the adequacy of the fire area boundaries in the Salem Generating Station as recommended by Generic letter 8610.
The information contained in these reports is summarized in the following sections, 9.5.1.1.1 Organization for Fire Protection The Yjee President and Chief Nuclear Officer is the upper level offsite management position who has management responsibility for the formulation, implementation, and assessment of the effectiveness of the Fire Protection Program for Artificial Island.
The hinnager - Nuclear Enginming Design is the offsite management position who is responsible for formulating and implementing a program or programs to control and maintain the design aspects of the Fire Protection program.
The Muhar Engineering Sciences Managn reporting to the Manager - Nuclear Engineering Design is responsible for establishing program requirements for implementing and maintaining the design related aspects of the Fire Protection Program.
The yige President - Nuclen_Q2nalinns is the offsite management position who is responsible for formulating and irnplementing a program or programs to control and maintain fire prevention aspects of the Fire Protection Program and the readiness to detect and suppress fires and safely shut down the plant.
The General Managers - Salem and Hope Creek Ooerations reporting to the Vice President
- Nuclear Operations are responsible for maintaining procedures for safely shutting down the plant in the event of a fire and providing trained operators in support of safe shutdown and fire brigade activities.
The General Manager - Nuclear Services reporting to the Vice President - Nuclear Operations is responsible for establishing a method of tracking and correcting Fire Protection Program deficiencies.
The hiapager - Site Protection reporting to the General Manager - Nuclear Sersices is responsible for establishing program requirements for implementing the aspects of the Fire Protection Program relative to fire prevention and housekeeping and readiness to detect and suppress fires.
The hianager - Nuclear Training reporting to the General Manager Nuclear Services is responsible for ensuring that personnel designated to operate the plant are trained such that they can safely shut down the plant and maintain it in a safe shutdown condition in the event of a fire.
9.52 l
l
The bhm;ger - Site Services reporting to the General Manager - Nuclear Senices is responsible for ensuring any required maintenance of fire protection systems is completed in a prompt and effective fashion.
The General Maqager - Ouality Assurance / Nuclear Safety Reyits is the offsite management position responsible for defining a QA program for fire protection and for conductingindependent verification and review for compliance with Fire Protection Program requirements.
9.5.1.1.2 Use of Combustible Materials The use of combustible materials at the Salem Generating Station is controlled by station procedures.
Administrative controls are established to minimize the quantity of combustibles that a safety related trea may be exposed to.
Procedures outline the methods to be used to ensure safe handling and limitations on the use of combustibles, i
i The use of ordinary combustibles such as paper, wood and plastic is minimized in the station. When wood is used for scaffolding, it is of the flame retardant type.
The bulk storage of hydrogen is in a separate area, outside plant structures. Additional hydrogen storage is in the Turbine Building and on the Auxiliary Building Roof. Signs are posted in the storage areas prohibiting smoking, open flames, and spark producing equipment.
Bulk Class A materials, such as charcoal filter medium, are not stored in safety related areas of the station.
Chemicals are stored in the primary and secondary water chemistry l boratories. The a
quantities of chemicals stored in the labs are minimal, and are stored in metal cabinets.
9.5.1.13 Control of Ignition Sources Procedures are established to ensure safe operating practices whenever hot-work operations are performed. Hot work permits and fire watches are required to protect safety related equipment from fire damage or loss resulting from work involving ignitien sources, welding, cutting, grinding, and open flame type work. Procedures also prohibit the use of combustion by-products for ventilation leak testing.
Smoking is prohibited in vital plant areas.
9.53 l
l
I 9.5.1.1.4 Testing and Mrdntenance of Fire Protection Systems The Salem Generating Station suppression and detection systems are periodically tested in accordance with station procedures to verify their operability. Systems that do not satisfy acceptance criteria are restored to operable condition in a timely fashion. As specified in Generic Letters 86-10 and 8812, fire protection system requirements were removed from the Salem Technical Specifications after the FSAR was updated to incorporatn 9e Fire Protection Program. The limiting Conditions for Operations and Surveillance Requirements formally contained within Technical Specifications have been adapted into Administrative and Surveillance Procedures respectively, 9.5.1.1.5 Quality Assurance Program for Fire Protection The Quality Assurance Program at Salem Generating Station assures that the requirements for design, procurement, installation, testing, and administrative controls for the fire protection program for safety related areas are satisfied.
The QA program for fire protection is part of the overall station QA program and contains the following elements:
DESIGN CONTROL AND PROCUREhiENT DOCUMENT CONTROL Design control and procurement document control measures are established to assure that applicable NRC guidelines are included in design and procurement, and that design changes and deviations are adequately reviewed and approved.
INSTRUCTIONS, PROCEDURES, AND DRAWINGS Instructions, procedures, and drawings govern the fire protection program of inspection, tests, administrative controls, fire drills, and training.
CONTROL OF PURCHASED MATERIAI, EQUIPMENT AND SERVICES Control of purchased material, equipment, and services are established to assure that these items conform to procurement documents.
INSPECTIONS A program for the inspection of activities affecting fire protection is established to verify conformance to documented installation drawings and test procedures.
9.5-4
.~ -
TEST AND CONTROL A test program is established to ensure that testing is performed and verified by inspection and audit to demonstrate conformance with fire protection requirements.
INSPECTION, TEST AND OPERKflNG STATUS Inspection, test, and operating status measures are established to provide for the identification of items that have satisfactorily passed required tests and inspections.
NONCONFORMING FrEMS Measures are established to control items that do not conform to specified requirements to prevent inadvertent use in fire protection installations.
CORRECTIVE ACTION Corrective action measures are estabFshed at the station to ensure that conditions adverse to fire protection such as failures, malfunctions, deficiencies, deviations, defective components, uncontrolled cornbustible materials,and non conformances are i
prornptly identified, reported, and corrected.
RECORDS Records are prepared and maintained to furnish evidence that the OA program
- criteria are being met for those activities affecting the fire protection program.
AUDITS Audits of activities affecting quality are performed by the PSE&G Quality Assurance -
Department and by the Station QA Engineer.
9.5.1.1.6 Fire Brigade The Salem Fire Brigade consists of full time dedicated fire fighting personnel with a minimum of five trained fire fighting personnel onsite at all times with provisions for a 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> call out to cover emergency absences. At icast three of the on shift fire brigade members are knowledgeable in Salem's safety systems to understand the effects of fire and fire suppressants on safe shutdown capability.
9.5-5
9.S.1.1.7 Fire Brigade Training and Drills The fire brigade training program ensures that the capability to fight potential fires is established and maintained. The program comists of classroom training, fire fighting practice, and fire drills.
The fire brigade training is provided by individut who are knowledgeable and quaiified by previous training, and experienced in the use of,b allable equipment and in fighting the fires which could occur a' the Salem Station.
9.5.1.1.8 Fire Drills Fire brigade drills are conducted quarterly for each fire brigade shift, The drills are conducted in areas where simulated fires of the type, size, and arrangement that could reasonably occur and develop during the response and organization time of the fire brigade.
Drills are conducted so that each fire brigade member can participate in each drill, but must participate in at least two drills per year. At least one drill per year is held on the back, shift. At least one drill per year is unannounced.
A randomly scheduled unannounced drill is critiqued by an engineer who is qualified for Member Grade in the Society of Fire Protection Engineers and who is not an employee of PSE&G. This drillis conducted at 3 year intervals as part of the Triennial Fire Protection Program audit and inspection.
9.5.1.1.9 Fire Brigade Equipment The fire brigade is provided with complete personal protective gear, emergency communication equipment, portable lights, portable ventilation equipment, and self.
contained breathing units.
9.5.1.1.10 _Off-Site Fire Department Training of the plant fire brigade is coordinated with the local fire department to ensure that the responsibilities and duties of the brigade and the offsite fire departments are delineated in advance of any fire.
9.5.1.2 ElanLComintclion Features 9.5.1.2.1 Fire Areas and Barriers Fire areas are established to separate redundant trains of safe shutdown equipment from each other, to isolate safety.related systems from fire hazards in non. safety related areas, 9.56
to separate Salem Unit 1 from Salem Unit 2 and to limit the spread of fire through the station by compartmentalization.
Fire area boundaries have been defined and evaluated as part of the Salem Fire Protection Program. Construction which does not meet specific rating criteria is either evaluated by an engineering evaluation in accordance with Generic Letter S610 or is included in an approved exemption request.
9.5.1.2.2 Penetration Scals At Salem Generating Station, openings through fire barriers for pipe, conduit, and cable trays which separate fire areas are sealed or closed to provide a fire resistance rating equal to that required of the barrier or have been evaluated and determined adequate to withstand the fire hazard in the area in accordance with Generic Ixtter 8610. In some areas, exemption requests rather than engineering evaluations form the basis for approval of specific seals.
G a
p 9.5 7
-i 9.5.1.2.3 Fire Doors Doors which are installed in fire area boundaries carry the UL label, with the exception of i
oversize doors, which cannot be tested. Fire area boundary doors, enclosing fire areas which are not normally locked, are either provided with a time delay alarm to indicate when the door has been left open, or are routinely inspected. Reliability of the fire doors are enhanced by inspections and administrative controls, which ensure the operability of the fire doors.
i i
PSE&G has been granted a generic exemption from the requirements of 10 CFR 50 Appendix R Section Ill G.2(a) which allows the use of 1 1/2 hour fire rated doors in 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> barriers based on maintaining a limited combustible loading in the affected areas.
9.5.1.2.4 Fire Dampers j
At Salem Generating Station,11/2 hour and 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> rated fire dampers are installed in locations where llVAC ducts pass through fire area boundaries. Most of the fire dampers installed at Salem Generating Station are located within the llVAC duct and are not within the plane of the penetrated fire barrier.
PSE&G has been granted a generic exemption from the requirements of 10 CFR 50 Appendix R Section III.G.2(a) which allows this installation as well as the use of 1 1/2 hour fire rated dampers, I hour rated ventilation ducts and ventilation duct penetration seals in 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> barriers based on maintaining a limited combustible loading in the affected areas.
9.5.1.2.5 Cable Wrap Cable wraps are used at Salem Generating Station to enclose redundant cabling in a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> fire rated barrier In the 4160V Switchgear Room, cable wraps are also used to cover open cable trays so that the cabling would not be considered as an " intervening. combustible" The cable wraps used at Salem has been approved by the NRC as a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> rated material.
9.5.1.2.6 Panial IIcight, Partial length Marinite Walls At Salem Generating Station, partial height, partial length marinite walls are used to separate equipment needed for safe shutdown in the following areas:
4160V Switchgear Room (Fire Areas 1&2FA AB-64A) 460V Switchgear Room (Fire Areas 1&2FA-AB-84A) e 9.5-8 l
l l
Lower electrical penetration area (Fire Areas 1&2FA.EP 78C)
De technical justification for these partial walls separating safe shutdown equipment is provided in approved exemption requests.
9.5.1.2.7 Reactor Coolant Pump Oil Collection System The reactor coolant pump bearing tube oil lift pumps are protected with fixed water fire suppression systems. The discharge from these systems is directed to four reactor coolant pump oil drain tanks which are designed to act as oil skimming tanks. These tanks retain the oil and allow the water to drain to the Containment sumps.
In addition. a reactor coolant pump lube oil collection system is provided. The oil collection system is engineered, designed and installed so that there is reasonable assurance that its failure will not lead to fire during normal or design basis accident conditions. The oil collection system consists of a series of collection pans and drainage piping that is capable of collecting tube oil from potential pressurized and unpressurized leakage points in the reactor coolant pump lube oil system. Oil leakage is drained and collected to vented closed containers. A f!ame arrester is provided in the vent systems of the oil collection tanks.
9.5.1.2.8 - Radiant Energy Shields Inside Containment, concentrations of electrical cables converge at the electrical penetration areas. Radiant energy shields are placed between the divisions so that radiant energy from a fire involving the cabling of one division would not damage cables of the other divisions.
9.5.13 Control of ComNstibles 9.5.13.1 Storage of Flammable Uquids Bulk quantities of flammable liquids are not stored at Salent Combustible liquids stored in buildings containing safety related equipment are limited to the Diesel Generator Fuel Oil Storage Tanks and Day Tanks.
Each Diesel Generator Day Tank is located in a concrete enclosure and is protected by an automatic CO flooding system. The tanks are vented to the outside and tlie vents are 2
equipped with flame arresters.
Each Diesel Generator Fuel Oil Storage Tank is located in a separate room enclosed by fire barriers. The tanks are vented to the outside with provisions to prevent overpressurization.
Each tank is located in an enclosure that is designed to hold the entire volume of the tank.
9.5-9
9.5.13.2 Electrical Cable Constniction Tests have been performed to demonstrate the flame retardant properties of the cables used at Salem Generating Station in accordance with IEEE 383, or the UL single conductor test.
Short sections of non-qualified cable may be used for lighting or communications circuits, or may be contained within vendor supplied panels or conduits.
9.5.1.4 Safc Shutdown capahility 9.5.1.4.1 Systems Required for Safe Shutdown For the Salem unks, the term " post fire safe shutdowrf refers both to the capability to achieve and maintain hot standby, as well as the capability to achieve and maintain cold shutdown. To demonstrate a post. fire safe shutdown capability, a number of discrete tasks were performed. For the first task, a safe shutdown methodology was established. The safe shutdown methodology essentially provides a scenario for shutting down the plant, i.e., the process by which reactiv ty is controlled and decay heat is removed. Utilizing the shutdown methodology the systems (auxiliary feedwater) and components (pumps, valves) within the systems, necessary for safe shutdown, were identified for the second task.
Concurrent with this task, the plant was subdivided into " fire areas." The fire rated boundaries provide reasonable assurance that a fire would be confined to the specific plant sections and would not spread beyond the boundaries. Because fire areas restrict the spread of fire, the overall task is reduced to demonstrating a post fire shutdown capability for any one particular area at a time.
Utilizing both the fire areas and the identified shutdown components, the circuits / cables necessary to operate these components were identified along with the conduit and raceway routing of the cables. The conduits and raceways were then identified as to which fire area they were located. With the shutdown methodology and fire area boundaries defined, and the location of components and cables identified, the final task, the process of fire area assessments was initiated.
A fire area assessment evaluates the components and cables within a particular fire area to determine if the capability to achieve post-fire safe shutdown exists.
If it was determined that safe shutdown could not be achieved due to loss of equipment and cabling, fire protection measures were evaluated.Section III.G.2 of Appendix R, specifies fire protection measures which include separation, cable wrap (tray and conduit),
suppression systems, detection systems, fire barriers, and combinations of these features.
In addition, alternate fire protection measures were considered through the licensing I
9.5-10 l
1
exemption process, In lieu of protecting the cables in the Control Room Complex, the Relay Room, and the ceiling of the 460V Switchgear Room, an alternative means of shutting down has been provided. For each fire area of the two units, the ability to achieve and maintain safe shutdown has been assured. Generally, the same level of protection was applied to the capability to achieve and maintain hot standby as the capability to achieve and maintain cold shutdown.
The shutdown model provides the overall methodology, scenario for shutting down the plant in the event of a fire. In developing a shutdown scenario several assumptions and initial conditions were utilized as follows:
a.
At any given time, only one fire would occur, b.
A fire would nat occur concurrent with other plant accidents or severe natural occurrences (seismic events).
c.
During the course of the post fire shutdown, the plant would not experience an additional, random single active failure.
These assumptions are consistent with the requirements of Appendix R.
Further, the shutdown scenario considered that the units were operating at full power conditions and that offsite power may be available or unavailable for 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. The shutdown model scenario addresses the Appendix R criteria for achieving and maintaining hot standby and cold shutdown conditions through the five basic performance goals delineated in Section Ill L of Appendix R. The performance goals for post fire shutdown are reactivity control, reactor coolant inventory control, decay heat remeval, process monitoring and support functions.
A sixth performance goal of reactor coolant system pressure control can also be inferred from the basic five performance goals.
In the event of a fire, the shutdown process begins with a plant trip. It is more than likely, that if a fire causes damage to the reactor protection system it would initiate a plant trip.
Further, if a loss of offsite power was to occur, an automatic tr!p would also be initiated.
However, in any case, a manual trip could be performed and a shutdown initiated. The process would continue with establishment of charging flow from at least one pump.
Reactor coolant pump seal cooling would be established to prevent seal degradatica.
On the secondary side, decay heat removal would be accomplished by use of the auxiliary feedwater system. At first, the rate of secondary side heat removal would be controlled by the main steam relief valves. As the shutdown process progressed, control would be provided by auxiliary feedwater flow and the main steam atmospheric dump valves. Long-term decay heat removal would be provided by one train of residual heat remov:J.
9.5-11
The above systems would be supported by essential room coolers (liVAC), component cooling and service water, Vital power would be provided by the vital power buses (125V DC,120V AC,230V AC,460V AC and 4160V AC) supplied from the diesel generators o-offsite sources. The entire shutdown process would be controlled and monitored with reactor coolant system instrumentation including pressurizer instrumentation and secondary side instrumentation. Specific details of the shutdown process are contained in the Salem Appendix.R safe shutdown engineering document.
For modeling purposes, the five basic performance goals were subdivided into 22 shutdown functions.
Shutdown functions are processes necessary during post fire shutdown to accomplish the listed performance goals. For example, the shutdown function " Service Water" is utilized, in part, as a support tunction, one of the five performance goals.
To address the performance goal of reactivity control, the shutdown functions of Charging, Boric Acid Supply and Letdown are utilized.
To address the performance goal of reactor coolant inventory control as well as the inferred goal of reactor coolant system pressure control, the shutdown functions of Charging, Letdown, RCP Seal Cooling and Reactor Depressurization are used.
For the performance goal of decay heat removal, the shutdown functions of Auxiliary t
Feedwater, Main Feedwater Isolation, Main Steam isolation, Residual lieat Removal and Secondary Depressurization are utilized.
The performance goal of process monitoring is provided by the shutdown functions of Auxiliary Feedwater, Pressurizer, and Steam Generator Instrumentation.
The performance goal for a support function is addressed by several shutdown functions.
Motive power is addressed by the Air Supply, the DG Fuel Oil Transfer and the Power Distribution functions. These functions ensure the availability of vital electrical power and control air. Cooling water support is ensured by the shutdown functions of Chilled Water, Component Cooling and Service Water. Post fire ventilation is ensured through the shutdown functions of HVAC-AFW, IIVAC Charging HVAC RilR, Containment Ventilation, and Service Water Ventilation.
9.5.1.4.2 Identification of Cables As part of the Appendix R safe shutdown analysis process, a cable identification methodology was established to identify any cable that would be required for operation of a safe shutdown component or whose fire induced damage may resu(t in spurious actuation i
of a' safe shutdown component. These cables are referred to as " safe shutdown cables."
l 9.5-12
~.
The cable identification process for each device (component) identified the cables that:
1.
Formed part of the control, power or required indication circuit for the component; 2.
Provided a contact, interlock, etc., that can affect the operation of the component; 3.
Provided power to the above circuits; 4.
Shared a common power supply; and 3.
In any way could affect the operation of the component.
The cable routings are traced to their termination or to an isolation device that would prevent the feedback of faults or spurious signals. Power cables are traced back to the switchgear, MCC, or distribution panel. The switchgear, MCC, and distribution panels are considered as separate components and devices.
The above process was utilized for all devices and fire areas, except for the diesel generator rooms and for the Safeguards and % lid State Protection Signals. Numerous cables exist between the diesel generators ani..icir control panels. Each diesel generator and control panel are located in separate fire areas. For the most part, the wiring between the engine and generator and the control panels are contained within the respective fire areas.
Therefore, only those cables which were routed outside the respective diesel generator and control panel areas were recorded on input forms and subsequently their routes traced throughout the plant. For devices associated with the Safeguards and Solid State Protection Signals, cabling was traced ba:k to the cabinet or panel which provides the protective function.
9.5.1.4.3 Associated Circuits The post-fire safe shutdown equipment is powered from the various levels of the vital power distrioution system. Associated circuits with a common power source would, then, be limited to non-shu:down loads (loads which are not utilized for shutdown, such as containment spray pumps) from the vital buses. The non vital buses are electrically separated from the vital buses, in general, electrical protection has been applied to all loads of the vital buses. Thus, the vital buses are electrically protected from the non shutdown loads by coordinated breakers and fuses. In those instances where complete coordination has not been applied, the non shutdown loads were considered equivalent to shutdown circuits and subjected to the separation / protection requirements of Section Ill.G of Appendix R.
95 13
+c-v--.
.-y v
+ -
wr
I For the spurious operation case of associated circuits, it was necessary to demonstrate that fire induced spurious actuation of equipment would not adversely impact the ability to achieve and maintain safe shutdown. He shutdown model identified for each shutdown function and Gow path, those components whose spurious operation would adversely impact the particular function and/or flow path. These components were then treated as safe shutdown components. For example,if the spurious closure of a valve would block a service water now path, then that valve was considered necessary for operation of that now path.
For each fire area, the unprotected spurious operation components were evaluated to Generic Letter 3610 and 8112 criteria. The cabling for these components was also evaluated with respect to the ability of fire induced failures which could result in spurious 1
actuations of the component. The cr.ble failure modes considered included hot shorts, open i
circuits and shorts to ground. Power cables for motor-open ted valves which do not have to be repositioned were not protected since loss of those cabbs annot cause the valve to change position.
Special consideration was given to the suction valves of the charging pumps from the VCT, if the charging pump suction valves were to spuriously close, the normal operating charging pump could potentially be damaged due to loss of suction flow. For the alternate shutdown areas, the ability to utilize any of the three charging pumps is provided. For the remaining areas, separation and protection ensures post fire availability of at least one charging pump.
In addition, special consideration was given to the valves comprising high-low pressure interfaces.
For the high-low pressure interfaces, five sets of interfaces were identified and evaluated, as follows: the pressurizer PORV and block valve lines, the reactor head vent lines, the residual heat removal suction lines, the letdown lines and the excess letdown lines. For the alternate shutdown capability areas, the procedures require the block valves to be verified closed or closed if they were observed to be open. For the remaining areas, either the cabling is protected or power could be de-energized to fail close the valves.
The reactor head vent lines are 3/4" lines and thus, do not pose an immediate concern. The charging system is more than capable of making-up the reactor coolant inventory losses through the reactor head vents. For protection of the residual heat removal suction valves, motive power to at least one of the valves has been de-energized at the motor control c nter in the electrical penetration area during normal power operation. Thus, failures of the control circuits would not result in spurious actuation.
In evaluating the normal letdown and excess letdown,it is important to note that numerous (five to seven) spurious valve operations would be necessary to result in uncontrolled loss of Inventory. In addition, most of these valves are fail closed solenoid valves. Post-fire controllable letdown is desirable, thus only long term loss of inventory is of concern. For 9.5-14
- a -
- ~
the alternate shutdown capability areas, the ability to control normal letdown has been ensured. For the remaining areas, at least one valve in the interface line has been protected. Similarly for the excess letdown, the alternate shutdown capability provides the ability to control two of the excess letdown valves as part of the RCP seal cooling function.
For the remaining areas, fire damage would not result in spurious opening of all of the i
valves for excess letdown.
For the common enclosure case of associated circuits, it was necessary to demonstrate that fire induced failure in non shutdown cables would not electrically or physically propagate a fire to the shutdown cables. Design criteria provides for field routed cabling to meet IEEE 383 requirements. Essentially the cabling utilized will not re: ult in propagation of a
)
fire. As part of the safe shutdown cable identification process, cabling directly connected to the circuit of a safe shutdown component was considered part of the circuit unless it was separated by an isolation device. Thus, sny non-electrically isolated circuit is considered part of the safe shutdown cables.
In addition, the cable separation requirements for Salem eliminates a common enclosure concern related to cable installation. He vital channels, "A," *B," "C" and "D" are required to be routed in separate trays and conduits. The electrical divisions 460V,230V, and 4kV power are also tequired to be routed in a separate tray or conduit. In addition, channels of non-vital cabling "H,""E,""F," and "G" are designated such that they are routed with only one particular vital channel. Further, the rating of the cables utilized in the Salem units are such that fire-induced shorting or grounding would result in a blown fuse or a tripped breaker before significant degradation of the cabling itself.
9.5.1.4.4 Alternate Shutdown Capability For the Salem units, alternate shutdown capability is utilized for the Control Room Complex, the Relay Rooms, and the upper portions of the 460V Switchgear Rooms. The alternate shutdown capability is primarily procedural control of the same post fire shutdown equipment utilized for the other plant areas.
The alternate shutdown procedure directs use of the charging system and letdown lines for reactivity control and reactor coolant inventory control. Any two of the three charging pumps could be utilized, even though the procedure specifically states to start one l
l centrifugal pump. Reactor coolant pressure control is provided by either the pressurizer heaters, if available, or the charging pumps. De pressurizer heaters are not considered required equipment. For depressurization, either letdown or auxiliary spray could be utilized. For initial decay heat removal, the procedure directs use of the turbine-driven auxiliary feedwater pump. If desired, the motor driven auxiliary feedwater pumps could also be utilized. For long-term decay heat removal, a residual heat removal pump is utilized.
l 9.5 15
For support, the procedure directs start of the diesel generators, component cooling water system pumps and the senice water system pumps. Any two of the three diesel generators could be utilized and any of the component cooling water pumps and senice water pumps could be utilized. The procedure also addresses the start of room coolers, an air compressor j
and containment ventilation fans. The procedure addresses both the availability and unavailability of offsite power sources through the verification of the vital buses. Process monitoring is available at the Hot Shutdown Panel. The available instrumentation includes steam generator level and pressure, pressurizer pressure and level, reactor coolant hot and cold leg temperature and source range flux level.
Equipment operating instructions were developed to accomplish individual functions (pump start /stop operation, valve open/close operation, dicsci operation, etc.) for use by the operator as necessary. Each function has its own specific instruction. The preferred method of operation of the various motor-operated valves is from the motor-control center, even though the necessary valves may be manually aligned. The procedures require that personnel be stationed at various locations to effect hot standby and to address contingent activities. The procedures can be accomplished utilizing onsite shift personnel, exclusive of the fire department personnel. Communication and emergency lighting has been provided to implement the shutdown process.
9.5.1.4.5 Exemption Requests PSE&G has received NRC approval of exemptions from the applicable requirements of Appendix R. The exemptions which have been granted by the NRC are described in a Safety Evaluation Report (SER) and summarized below:
a.
Generic Exemption. Station Wide his exemption is from Section III.G.2.a to the extent that 1-1/2 hour fire rated doors and dampers,1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> fire rated ventilation ducts and their penetration seals, and non rated equipment hatches do not provide 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> fire rated barriers between areas containing redundant shutdown systems, equipment, cables and associated circuits.
b.
Control Room Complex (Area 12 FA AB-122A)
This exemption is from Section III.G.3 of Appendix R to 10 CFR Part 50 to the extent it requires a fixed fire suppression system for an area where alternate shutdown capability is provided. Specifically, the Salem Units 1 and 2 Control Room Complex does not have a fixed fire suppression system.
9.5 16
= -.
c.
Reactor Plant Auxiliary Equipment Area Elcration_100lt._and 110 ft.
IJpper Electrical Penetration Area (Areas 1 and 2 FA EP-100Q)*
Inner Piping PenCEation Area (Areas __1 and 2 FA PP 1001])
Reactor Plant Auxiliary Building Elgyation 64 ft. (Arens_1_and 2 FA AB 64B)
These exemptions are from the requirements of Section Ill.G.2 of Appendix R to 10 CFR Part 50 in the above referenced areas to the extent that it requires the separation of redundant safe shutdown cables and equipment by 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> fire rated barriers plus automatic fire suppression and detection systems. Specifically, these locations are not protected by automatic fire suppression systems or arca wide fire detection systems.
' Approval pending, d.
Mechanisal Penetration Areas (Fire Areas 1 and 2 FA MP-781)
This exemption is from Section Ill.G.2 of Appendix R to 10 CFR 50 to the exteat it requires the separation of redundant cables and equipment by 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> rated fire barriers plus arca wide suppression and detection. Specifically, Fire Areas 1 and 2 FA MP-781 are not protected by automatic suppression systems and area wide detection capability, e.
460V Switchgear R_oom (Arcus 1 and 2 FA-AB-84A)
Lower Electrical Penetration Area (Areas 1 and 2 FA-EP-78C) 4160V Switchgear Room (Areas 1 and 2 FA-AB-64A)
These exemptions are from the requirements of Section III.G.1 of Appendix R to 10 CFR Part 50 in the above referenced areas to the extent that it requires the separation _of redundant safe shutdown equipment by I hour fire rated barriers plus automatic suppression and detection systems. Specifically, redundant safe shutdown systems are not protected by complete,1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> fire barriers. In addition, the fire suppression system in the 4160V Switchgear Room is manually actuated.
f.
Reactor Plant Auxiliary Eauipment Area - Elevation 84 fim-(Attas 1 and 2 FA AB_-
8_4B.)
This exemption is from the requirements of Section III.G.2 of Appendix R to 10 CFR Part 50 to the extent that it requires the separation of redundant safe shutdown cables and equipment by 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> fire rated barriers plus automatic fire detection and suppression systems. Specifically, area wide detection and suppression systems are not provided. Additionally, auxiliary feedwater (AFW) system and chemical and 9.5-17
volume cor. trol system (CVCS) equipment are not separated by complete fire rated
- barriers, g.
Rendual Heat Removal Pumo and IIcat Exchangcr Areas (Algas 1 and 2 FA AB-45A and B)
This exemption is from the technical requirements of Section Ill.G.2 of Appendix R to 10 CFR Part 50 to the extent that it requires the separation of redundant safe shutdown systems Sy complete 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> fire rated barriers. Specifically, redundant cables in these areas are separated by 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> fire rated walls with open penetrations.
h.
Containment (Arsac 1 and 2 FA RC-78)
This exemption is from the requirements of Section Ill.G.2 of Appendix R to 10 CFR Part 50 to the extent that it requires that redundant cables and equipment within containment be separated by at least 20 feet of horizontal distance free of intervening combustibles or be separated by a radiant energy shield.
i.
Pipe Tunnel Elevation 84 feet (Are.aj2 FA PTL4)
This exemption is from the technical requirements of Section Ill.G.2 of Appendix R to 10 CFR Part 50 to the extent that it requires that redundant shutdown systems be separated by at least 20 feet free of intervening combustibles and be protected by automatic fire detection and suppression systems. Specifically, redundant systems are separated by less than 20 feet and the tunnel is not protected by an automatic fire suppression system.
j.
CQAtui2mtDLRenm_diltnttion.Bilte.thm.1.2012.EA.DG-84F) -
This exemption is from the technical requirements of Section Ill.G.2 of Appendix R
- to 10 CFR Part 50 to the extent that it requires separation of redundant shutdown systems by 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> fin barriers and protection by automatic fire detection and suppression systems, Specifically, redundant shutdown cables are not protected by an automatic fire suppression system.
9.5.1.5 Support Eauipment 9.5.1.5.1 Emergency Lighting The lighting system at Salem Generating Station consists of normal lighting, emergency lighting, self-contained emergency battery lighting, and portable hand held lights. A description of the complete system is contained in Section 9.5J.1 of the Salem UFSAR.
9.5-18 l
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De emergency lighting provided for Appendix R safe shutdown is a fixed self-contained lighting system. Each unit consists of a battery, charger, lights. had electronics all contained within a box. The units are energized automatically upon loss of power, and are rated to r
supply 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> of lighting.
The emergency lighting units are located in access routes to and within areas where shutdown functions must be performed.
9.5.1.5.2 Portable Radios A portable radio communication system as described in Section 9.5.2 of the Salem UFSAR is provided for use of the fire brigade as well as operations personnel involved in emergency activities. His system does not interfere with the communication equipment of the security force. For post fire safe shutdown, the operators will use portable hand held radios. The radio system including repeaters and power supplies has been designed to be available for a fire in any of the alternate shutdown areas.
9.5.L5.3 Ver.tilation and Smoke Removal Ventilation systems for the station were not specifically designed to provide automatic smoke and heat venting. Natural convection type ventilation is not used at this station. The station ventilation systems provide forced-convection flows for specific areas. Srnoke and corrosive gases from a fire may be discharged directly to the outdoors by nature of the once-through ventilation design applied throughout the station (with the exception of the Reactor Containment).
Ventilation systems serving the safety related areas are controlled from the Control Room.
Charcoal filters are provided in the exhaust ducts to absorb smoke and corrosive gases for oublic protection, except for the systems serving the service water intake, diesel-generator and fuel oil storage rooms, battery rooms, switchgear rooms and penetration areas. A special part of the Control Area Air Conditioning System, designated Emergency Air Conditioning System (EACS) contains special equipment to ensure habitability of the Control Room under a!! operating conditions.
9.5.1.6 Fire Delecting l
9.5.1.6.1 Fire Detection and Alarm System I
The Salem Generating Station fire detection and alarm systems are designed and installed L
as a " Class B" supervised signaling system. The system is not a safety related system and is not designed to record system signals.
9.5-19 l
The primary purpose of the proprietary protective signaling system is to detect fire during its early stages of development and htitiate an alarm to minimite the adverse impact of fire on buildinp, systems, and components, in addition, these signal systems provide release of selected extinguishing systems.
Annunciation functions are displayed on the Fire Protection System Panel in each Control Roont The overhead annunciator in each Control Roam indicates alarm and trouble signals, as well as loss of DC power.
Several different types of fire detectors are used at Salem Generating Station. The majority of detectors are ionization chamber smoke detectors. The detection system also utilizes other types of fire detectors such as rate of rise, fixed temperature heat detectors, and rate compensated detectors.
The number and placement of fire detectors was determined by considering the configuration of the space protected. NFPA 72E, Automatic Fire Detectors, was used as a guideline for the placement of fire detectors except where altemative spacing was judged acceptable by a Member grade fire protection engineer.
All of the fire detection systems are of the Class B supervised circuit type.
9.5.1.7 Eiic_ Suppression Sysictm 9.5.1.7.1 Water Supply Fresh water for fire protection is stored in two independent fresh water storage tanks. Each tank has a capacity of 350,000 gallons; 300,000 gallons of which are reserved for fire protec-tion use and 50,000 gallons available for domestic service. De largest system demand is 1450 gpm at 70 psig for a main power transformer. Each tank is therefore capable of supplying the greatest system demand plus an additional 1000 gpm for hose streams for a minimum of 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, representing 100% redundant capacity.
Two redundant diesel driven fire pumps are provided at Salem Generating Station, each rated for 2500 gpm at 135 psig. Each pump has its own driver with independent power supplies and controls mounted on a structural steel base and controlled by a combined manual and automatic panel. In addition, a pressure maintenance (jockey) pump provides system pressuriration.
The fire pump suction piping and valve arrangement allows either pump to take water from either or both fresh water storage tanks. Isolation valves have been provided in the supply headers.
9.5-20
i A separate discharge header from each fire pump connects to the underground yard fire main loop which encircles the station.
The two fire pumps and their associated fuel oil day tanks are located in one room. The room is provided with a wet pipe sprinkler system. Floor drains are provided which would i
limit the spread of oilIn the event of a leaking oil tank. The fire pumps are mounted on a 12 inch high concrete pedepals. These alternative fire protection provisions were found acceptable by the NRC in lieu of locating the fire pumps in separate fire areas.
1 The pressure malatensnee pump is used to supply water to makeup for minor system leaks, and to avoid frequent starting of tl.e Gre pumps from minor system fluctuations. Should the jockey pump be unable to maintain pressure, and the system preszure falls the first fire pump automaticahy starts. Once this pump starts, it wil: continue to run until it is manually shut off at its controt cabinet located in the Fire Pump IIouse. Should the first Grc pump fail to start or if there is a large demand for fire water, and the system pressure continues to fall, the second fire pump automatically starts to maintain system pressure. The second fire pump, will also cont.inue to pump until it is manually shut off at its control cabinet in the Fire Pump House. The fire pumps can only be stopped at the fire pump controller with the manual switch.
Each of the fire pumps is equipped with operating alarms which appear on the fire pump Control Cabinet, and any one of these alarnu will also sound the trouble alarm on the Unit 1 Control Room overhead annunciator.
The fire pumps discharge into an underground main surrounding the plant. Fire hydrants, installed in the station yard areas, tie into the fire main loop. Each hydrant is equipped with two 21/2 inch hose connectors. Hydrants in strategic locations within the protected I_
area are also equipped with. hose houses. A looped header located inside the plant buildings is also supplied from the underground loop. Connections from the underground dBtribution main enter the Turbine and Auxiliary Buildings to supply a header at the perimeter of the Turbine Generator area, and another header through the center of tne i
Auxiliary Building. The pipe is sectionalized by valves which permit the use of selected l
lengths in the event any section of piping is damaged. The indoor header supplies fire water l
to the various deluge water spray systems, sprinkler systenu and standpipes located L
throughout the Auxiliary Building, Containment, Turbine Generator area, Service Building, l.
Administrative Building and main transformer nrea.
Approved post indicator type valves or curb salves are provided in the yard main and in supply beaders to the buildings to allow for isolating hydrants and portions of the piping system during maintenance and repair periods without shutting off the entire system. Each sprinkler, deluge and standpipe supply line is equipped with an approved gate valve. Valves l
in supply lines to fire water sprinkler systems, deluge system, and standpipe valves, located 9.5-21
m---,._
inside buildings, are locked in the correct position and periodically checked by surveillance or periodic test procedures, llose standpipe isolation valves and yard main post indientori
)
are provided with locking devices. Supervision of key operated hydrant isolation valves (curb valves) which are not locked is maintained by strict control of the key wrenches which have been aufgned to responsible station personnel. In addition, vist:al checks of all valves are performed periodically, 9.5.1.7.2 Sprinkler and Water Spray Systems Three types of water based suppression systems are utilized at Salem Generating Station:
W et Pipe Spnnklers Dry Pipe Sprinklers Water Spray Systems All systems are pmvided with alarms in the Control Room which indicate system operation.
The locations for each type of system are as follows:
Wet Pipe Sprinklers Closed head wet pipe sprinkler systems are installed in the following areas:
1.
Senice Building - Elevations 88,100,113, and 127 2.
Fire Pump House - Elevation 100 3.
Heating Boiler House Elevation 100 4.
Turbine Perimeter - Elevations 88,100, and 120 5.
Auxiliary Building Drumming & Baling Storage Area, and Truck Bay 6.
Auxiliary Building Resin Storage Area 7.
Cable Vaults carning cable between the Auxiliary Building and Turbine Building 8.
Clean facilities building 0 Elevations 100,119, and 132.
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9.
Auxillary lluilding Charging and Safety injection Pumps. Elevation 84 10.
Auxillary Feedwater pumps Elevation 84 11.
Administration Building. Elevation 100 Dry Pipe Sprinklers Tw(, closed head dry pipe pre. action type sprinkler systems are provided for the protection of the Auxiliary Feedwater pumps on Elevation 84'.
One system is electrically actuated and the other is pneumatically actuated in order to provide redttodant protect'on.
Water Spray Systems Water spray systems consisting of open head deluge systems automatically released by either water (hydraulic), air (pneumatic), or electrical mechanisms are provided la the following locatioru:
il'ater Release ll'ater Spmy Systenu Water spray systems actuated by water filled pilet sprinklers are provided for the following equipment.
1.
Turbine lubricating oil makeup tank.
2.
Turbine lubricating oil storage tanks.
3.
Turbine lubricating oil reservoir, coolers, and conditioner.
4.
Seal oil unit.
5.
Feedwater pump turbine lubricating oil c olers and tank.
6.
Station air compressors.
Pnewnatic Release Water Spray Systenu Water spray systems actuated by pneumatic air pilot line sprinklers are provided for the following equipment:
9.5 23
1.
Generator main transformer banks.
2.
Auxiliuy power transformers.
3.
Station power transformers.
4.
Ileating boiler fuel oil pump and heater.
5.
Reactor coolant pump lubricating oil lift pump and discharge lines.
6.
Turbine and inboard generator bearing housings, i stn' cal Release IVater Spray Systems Water spray systems actuated by continuous strip thermal dettetors are prosided for the following charcoal filter banks:
1.
Control Room emergency air conditioning system.
2.
Auxiliary Building exhaust emergency filter bank.
3.
Containment pressure vacuum relief system.
4.
Iodir.e removal system.
5.
Fuel llandling Building Ventilation Unit Charcoal filters.
Water spray systems activated by thermal detectors are provided for the:
1.
Diesel Fuel Oil Storage Tank Rooms 9.5.1.7.3 IIose and Standpipe Systenu l-lose stations at the Salem Station are provided for the Reactor Containments, Auxiliary Building, Service Building, Turbine Building and Administration Building. Each hose station is equipped with 1-1/2 inch fire hose and an adjustable fog nozzle. Electrically safe nozzles
. are provided at specified locations. Additionallengths of hose are stored on hose racks at specific locations.
Ilose stations are provided for all Doors of these buildings, except on Elevation 45 ft. of the Auxiliary Building, and the Fuel llandling Building. These areas can be reached from existing hose stations in other areas.
9.5 24
llose stations are not provided in the Service Water Pump flouse. Since access to each of the pump roonu is from outside, a fire hydrant is provided in the yard near the building.
All standpipes are bl/2 inch diameter. The individual branch supply to the hose reel is 1 1/2 inch diameter.
9 5.1.7.4 Other Supprer.clon Systems Eontitlystem At Salem Generating Station, a manually operated foam fire suppression system protects the Bulk Fuel Oil Storage Tank. This tank is a non safety related facility, located above ground, outdoors, and approximately 400 feet south of the Tui -ne-Generator Building.
COJitsluppicisloa.Systsms law pressure carbon dioxide fire protection systems are provided for the Diesel-Generator Rooms and associated control rooms, day tanks, fuel oil storage tanks and pumps, and the Switchgear Rooms and the lower Electrical Penetration Area. Each CO tank contains a sufficient supply of carbon dioxide for two full discharges into 2
the largest protected area. The largest area protected is the 4160 Volt Switchgear Room. Dere are three diesel generator sets per unit at the Salem Generating Station. Each set is flooded by independent CO actuation. Each Diesel-Generator 2
Room and its associated control room and day tank area are actuated together The two diesel fuel oil pump rooms for each uni' e also actuated together, Carbon dioxide fire protection for the Generator Exciter Enclosure for each unit is supplied from a separate refrigerated storage tank located in the Turbine Area.
[htlDILl39LEitsluppression syitems IIalon 1301 fire extinguishing systems are provided for the Relay Rooms. Each Relay Room has an independent extinguishing system capable of total discharge of either main or reserve charges of fire extinguishing agent within approximately ten seconds of activation. The IIalon systems are designed to be activated either automatically or manually, Automatic actuation occurs upon receipt of signals from both zones of a cioss zone Fire Detection System. Manual actuation is accomplished by using remote pull stations.
9.5 25
A llalon 1301 system is also provided for the protection of the Dimension 2000 Telephone building.
EnttahltEitehtinguishen Portable fire extinguishers are provided at specific locations throughout the station.
The selection and spacing of extinguishers at Salem is based upon NFPA 10 guidance for the type of hazard present.
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