ML19275A571
| ML19275A571 | |
| Person / Time | |
|---|---|
| Site: | Peach Bottom  |
| Issue date: | 08/23/1979 |
| From: | Bauer E, Bradley E, Daltroff S PECO ENERGY CO., (FORMERLY PHILADELPHIA ELECTRIC |
| To: | |
| References | |
| NUDOCS 7910040671 | |
| Download: ML19275A571 (22) | |
Text
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s BEFCF2 THE UNIreD STATES NUCLEAR RIGULATORY COMMISSION In the Matter of Docker. No.
50-277 PHILADELPEIA ILECS.IC COMPANY 278 APPLICATION FCR AMENDMINT OF FACILITY OPERATING LICENSES OPE-nu S DPE-56 Edward G.
Bauer, Jr.
Eugene J.
Bradley 2301 Market Street Philadelphia, Pennsylvania 19101 Attorneys for Philadelphia Electric Company 1100 185 17910040 6 7/
,9 EEFORE TEZ UNITED STATES NUCLEAR REGULATOR'l COM_v_ISSION In the Matter of Docket No.
50-277 PEII.ADELPHIA ELEGIC COMPANY 50-279 APPLICATION FOR AMINCMENT CF FACILITY OPERATING LICENSES DPR-44 5 DPR-56 1100 186 Philadelphia Electric Company, Licensee under Facility Operating License DPR-44 for Peach Bottom Atomic Power Station Unit No. 2 and Licensee under Facility Operating License DPR-56 for Peach Bottom Atomic Power Station Unit No. 3, hereby requests that the Technical Specifications contained in Appendix A of the Operating Licenses be amended by revising certain sections, tables, and bases.
The proposed amendments involve the folicwing changes :
- 1) replacement of existing pressure switches that sense drywell and reacter pressures with analog loops and 2) the
modification of two reactor water level indication loops.
The revisions are indicated by vertical lines in the right margin of the attached copies of pages 41, 42, 44, 45, 48, 65, 66, 81, and 86.
A discussion of the requested changes is set forth below.
Analoo Loco Installation The requested revision of the Technical specification Tables 4.1.1, 4.1.2, 3.2.3, and 4.2.B reflects the planned replacement of existing pressura switches that sense reactor and drywell pressures with analog loops.
Each loop will consist of a transmitter, indicator and trip unit.
A detailed description of the proposed replacement is set forth in a document titled " Modification Description, Replacement of Pressure Switches with Analog Transmitters and Electronic Trip Units at Peach Bottom Atomic Power Station Units 2 and 3" which is attached hereto and incorporated herein by reference.
Safety Analysis - The modification involves removing one device and suhstituting other devices to perform the same function.
Changes in design bases, protective function, redundancy, trip point, and logic are not involved.
Therefore, this evaluation can be limited to a discussion of the replacement devices with respect to meeting the reliability, accuracy, and response time requirements of the instrument channels.
The existing instrument channels censist of a switch with a design reliability goal of 0.99 3 (refer
!100 187
to Page 52 of the Technical Specifications).
The replacement instrument channels consist of a transmitter in series with a trip unit.
The transmitter has a failure rate of less than 2.0x10-5 failures / hour.
With a once/ day monitoring interval, this yields a reliability greater than 0. 9995.
The trip unit has a failure rate of less than 9x10-6 failures / hour.
With a once/ month test interval, this yields a reliability greater than 0. 99 35.
Since both the transmitter and the trip unit must operate for proper channel response, the channel reliability is the product of the individual reliabilities.
This product yields a channel reliability greater tnan 0. 993, which satisfies the desAgn reliability goal of the existing instrumenta tion.
In all cases, the response time and accuracy requirements of the instrument channels are met by the replacement devices.
The proposed instrument modifications are designed to:
1.
Reduce undetected primary senscr element drift due to the utilization of a meter in e ach primary sensor signal loop; 2.
Reduce the frequency of setpoint drift occurrences; 3.
Provide indication for each primary sensor which will prove operability of the sensor; 1100 188
~ _ _ _. _..
4.
Reduce the time Reactor Protectior. System logic must be in a half-scram condition to functionally test or calibrate a safety trip; 5..
Reduce the functional test and calibration frequency for the primary sensor and to allow calibration of the primary sensor to be performe - when the reactor is shut down fcr refueling; 6.
Reduce likelihood of instrument valving errors; 7.
Reduce the potential for instrument tes*ing related scrams.
Modification of Reactor Level Indication Loces The amendment to the Technical Specifications fcr Table
- 4. 2.F is being requested to re flect the planned removal of existing reactor water level indication transmitters LITS 2-3-59A and 3.
They provide analog reactor water level signals to II 2-3-85A and 3 and to LI 2-3-85AX and BX through a selector switch.
The level transmitters will be removed and their function will be performed by existing channels of level transmitters LT 2-3-72A and B and the auxiliary analog cutput of trip units LISH 2-3-72A and B.
Existing indicators will be replaced with new indicators that are compatible with the auxiliary analog output of the electronic trip units.
Safety Analvsis - The modification involves removing two level transmitters and substituting existing instruments to perform the same function.
Changes in design basis, function, and redundancy are not 1100 189~
involved.
The reliability, accuracy, and response time of the replacement instrunantation are better than that of the existing instrumentation.
Level transmitters LT 2-3-72A and 3 provide reactor water level signals to trip units LISH 2-3-72A and a which are used in the tripping of the emergency core cooling systems.
Auxiliary analog outputs from the trip units, as a result of the modification, will provide analog level signals to position indicators LI 2-3-85A and 3 and to LI 2-3-35AX and 3X.
The safety-related trip portion of LISH 2-3-72A and B is isolated from the non-safeguard auxiliary analog output and will not be affected by any credible failure in the non-safeguard portion of the circuit.
Credible failures include open circuits and shorts to ground, 125 VDC, and 115 VAC.
It can be concluded that the modification will create no adverse effects on the existing safety-related equipment.
The transmitters, in accordance with the Technical Specification Table 4.2.3 requirements, are calibrated once per operating cycle.
This coupled with the instrument check once each shift provides satisf actory instrument channel reliability.
I, t
1 \\ 00 14 D.
The proposed instrument modifications are designed to:
1.
Provide reliability, accuracy, and response time which are better than that of the existing instrumentation:
2.
Provide the control room operators with reactor water level position indicatica from the same level transmitter that initiates the trip function:
3.
Reduce likelihood of inst.mment valving errors.
Based on the foregoing review, it is concluded that the proposed modifications do not involve unreviewed safety questions.
Since the above modifications will not be installed until after approval of the changes to the Technical Specifications, requested herein, it is requested that these changes be made effective upon completion of the installations.
This amendment request does not involve a significant hazard consideration.
Therefore, pursuant to CFR 170.22, Philadelphia Electric Company, for fee purposes, proposes t. at the Application for Amendment for Unit No. 2 be considered a Class III Amendment.
Since the amendment request for Unit 3 is a duplicate of that for Unit 2, it is proposed that the Application for Amendment for Unit No. 3 be considered a Class ! Amendment.
The Plant Operation Review Committee and the Operation and Safety Review Committee have reviawed these proposed changes 110D i91
to the Technical Specifications and have concluded that they fo not involve an unreviewed safety question or a significant hazard consideration, and will not endanger the health and safety of the public.
Respectfully submitted, PHI' ADELPHIA ELEC"RIC CCMPANY By
/s/ S. L. Daltroff vice Presiden 1100 192 COMMOT4EA.LTH OF PETISYLVA!TIA ss.
COUNTY OF PHII.ADELPEIA S.
L. Daltrof f, being first duly sworn, deposes and says:
That he is Vice President of Philadelphia Electric Company, the Applicant herein; that he has read the foregoing Application f or Amendment of Facility Operating Licenses and knows the contents thereof; and that the statements and matters set forth therein t.:e true and correct to the best of his knowledge, information and belief.
/s/ S. L. Daltroff Subscribed and sworn to be fore me this 23rd day of August, 1979.
(SEAL)
/s / Elizabeth H. 3cver Notary Purlic Elizabeth H.
Boyer Notary Public, Phila., Phila. Co.
My Commission Expires Jan. 30, 1982 1100 193'
4 CERTIFICATE CF SERVICE I certify that service of the foregoing Application was made upon the Board of Supervisors, Peach Bottom Township, York County, Pennsylvania, by mailing a copy thereof, via first-class mail, to Alhert R. Steele, Chairman of the Board of Supervisors, R.
D. No.
1, Delta, Pennsylvania 17314; upon the Board of Supervisors, Fulton Township, Lancaster County, Pennsylvania, by mailing a copy thereof, via first-class mail, to George K.
Brinton, Chairman of the Board of Supervisors, Peach Bottom, Pennsylvania 17563; and upon the Board of Supervisors, Drumore Township, Lancaster County, :8ennsylvania, by nailing a copy thereof, via first-class mail, to Wilmer P.
Bolton, Chairman of the Board of Supervisors, R.
D.
No.
1, Holtwood, Pennsylvania 17532; all this 27th day of
- August, 1s79.
/s/ Eugene J. Bradlev Eugene J.
Bradley Attorney for Philadelphia Electric Company i100'f94
MODIFICATION DESCRIPTION REPLACEMEM OF PRESSURE SWITCHES WITH ANALOG TRANSMI""'ZRS AND ELECTRONIC TRIP UNITS AT PEACH BOTTCM ATOMIC POWEP STATION UNITS 2 and 3 Introduction This nodification affects 24 safety-related switches per unit sense drywell and reactor pressures.
They are to be that The replaced with analog transmitters and electronic trip units.
only change being made by this modification is in the method of generating the trip signals.
All trip functions will remain the same.
There are no changes in design basis, protective function, redundancy, trip point setting, or logic.
Descriotion channel in the existing design consists of a An instrunc-nt Contacts of pressure switch monitoring the process variable.
this switch are used to energize an auxiliary relay in a logic An instrument channel in the modified design consists of panel.
The a pressure transmitter monitoring the process variable.
output of the transmitter is connected to an electric trip unit and indicator.
The indicator displays the actual output of the transmitter and the trip unit produces a trip output signal when input value is reached.
The trip unit output then a preset energizes a relay whose contacts are used in the logic circuit in place of the existing pressure switch contacts.
Each modified instrument channel exactly duplicates the function of each existing instrument channel.
The following is a review of the proposed changes and a functional description of the instruments involved:
1)
Pressure switches PS 5-12A,B,C,D measure primary containment pressure and provide a trip that initiates scram ar.1 primary containment isolation.
These switches will be removed and replaced by a modified instrument channel consisting of pressure transmitters PT 5-12A,B,C,D, electronic trip units PIS 5-12A, B, C, D, and auxiliary relays to provide the contacts for the RPS scram logic.
The power supply to these analog loops is from 115 VAC RPS Bus " A" for the A and C channels and from 115 VAC RPS Bus "B" for channels B and D.
2)
Pressure switches PS 2-3-51 A,B,C,D measure reactor pressure The for the condenser low vacuum and MSIV closure bypass.
1100 195
function of these switches will be performed by an existing channel consisting of pressure transmitters PT 2-3-55A,3,C,D, master and slave. trip units PISH 2-3-55A,3,C, D, and PSL 2 55A,3,C,D, snd contacts from auxiliary relays.
The pcwer supply to these.snalog loops is from 115 VAC RPS Bus "A"
for the A and C channels and from 115 VAC RPS Bus "B"
for channels 3 and D.
3)
Pr;ssure switches PS 2-3-52A,3,C,D measure reactor pressure, have two setpoints each, and will be replaced by the following channels.
Pressure transmitters PT 2-3-5 2A,3,C,D will feed master trip units PISL 2-3-52A,3,C, D f or the 350 psi setting of SW41 the Core Spray and REE injection valves.for the low pressure permissive to ope A signal from these master trip units will feed slave trip units PSLL 2 52A,3,C,0 for the 225 psi setting of SW82 for the low pressure permissive to close the recirculation pump discharge valves.
The power supply to these analog loops is from 125 VCC Bus "A"
for the 3 and D channels.for the A and C channels and from 125 VDC "B"
a)
Fressure switches PS 10-100A,3,C,D, PS 10-101A,3,C,D, and PS 10-119A,3,C,3 measure drywell pressure and provide high drywell pressure (2.0 psig) signals that initiate ADS, EPCI, Core Spray, RER, and the diesel generators and provide a high drywell pressure (1. 5 psig) signal which allows opening the containment spray motcr operated valves 10-26, 10-3 1, 10-38.
These switches vill be replaced by modified instrument channels consisting of pressure transmitters PT 10-100A,3,C,D, master trip units PISH 10-100A,3,C,D, and slave trip units PSHE 10-100A,3,C,D.
analog loops is from 125 VDC Bus "A"The power supply to these for the A and C channels and from 125 VDC Bus "3" for the 3 and D channels.
The new transmitters are to be mounted on the existing instrument racks in the same lccation previously occupied by the old switches.
The instrument racks will be analyzed to assure that they are seismically qualified with the new instruments in place prior to installation.
An alvsis The proposed modification has been analyred to assure that the changes meet following specific areas were addressed: applicable standTrds and requirements.
The a)
Equipment capability and Ef fects on Related Icuicment As indicated in the Safety Analysis, the reliability of the replacement equipment meets the design reliability goal for these instrument channels.
An investigation of the response time and accuracy requirements of the instrument channels was conducted and it was found that the replacement instrumentation met these requirements.
The interfacing logic of the EPs and the ECCS is unchanged.
The rating of the replacement relay contacts is equal to the rating of the original contacts.
No adverse affects on the interf acing equipment is therefore created.
b)
Codes, Standards, and Reculations The modification affects the safety systems and has been designed to meet the standards and guides which were applicable to the original design.
Specifically:
1)
Quality Components - high quality components will be utilized as indicated in the Safety Analysis.
2)
Separatten Criteria - the sepatiti@n criteria of the original plant is unchanged.
Separation is provided by locating equipment on separate racks and panels and by running cable in separated cable tray or conduit.
The power supply used for an instrument channel is dependent on that channel's divisional assignment.
3)
Single Failure Criterion - no new single f ailure avehts have been created, therefore, no single f ailure will result in any action not previously evaluated in the FSAR.
4)
Qualification - all new equipment has been tested or analyzed to assure that the design environmental conditions and the design basis seismic requirementz are met.
5)
Testability - means are provided to test the trip units periodically by injecting a signal and observing the trip output.
Operability of the analog loop is verified by periodic instrument checks.
c)
Ouality Assurance Quality assurance and control will be applied to this modification as detailed in the Peach Bottom Quality Assurance Manual.
1100 197
TA11LE 4.1.1 ItEACTOR PROTECTIOll SYSTEM (SCHAM) Ills *lHUMEtiT FUtk?TIONAL TESTS MINIMUM FiltJCTIONAL TEST FREQllE!JCIES FOR SAFETY ItJSTHUMEf4T AND CollTh0L CIRCUITS Group (2)
Functiona1 Test Minimum Frequency (3)
Mode switch in Shutdowra A
Place Mode Switch in Each refueling outage.
Sh u t.down Manual Scram A
Trip Channel and Alarm Every 3 months.
RPS Channel Test Switch A
Trip Channel and Alarm Every retueling outage or af ter channet maintenance.
IHM M
liigh Flux C
Trip channel aged Alarm (4)
Orte ptfr week during refueling or startup and hetore each startup.
Inoperative C
Trip Channel and Alarm (4)
Once per week during r e f ueling or u t.a t tup and hetore each startup.
A PRM liigh Flux H1 Trip Output Delays (4)
Once/ week.
Inoperative CD 11 1 Trip Output Delays (4)
Once/ week.
Downscale B1 Trip Output helays (4)
Once/ week.
Flow Hias lit Calibrate Flow Bias Signal (4) Once/ month ( 1).
Iligh Flux in Startup or Refuel C
Trip Output helays (4)
Once per week during ref ueling or utart up ased het on e each ut art up.
liigh Heactor Preunute (6) 11 2 Tri p Channel and Alarm (4)
Every 1 anout.h (1).
Iligh Drywell Preunure (6)
H2 Trip Channel and Alar m (4)
Every 1 rnout h (1).
Heactor Low Water lea vel (S) (6)
H2 Trip Channel and Alarm (4)
Every 1 mont h (1).
TAltl.E 4.1.1 (cout 'd)
HEACTOR PROTECTION SYSTEM (SCitAM) INS *IltUMENT FUNCTIONAL TESTS MINIMUM FuriCTIONAL 'EST Fl<EQUEf1CIES Folt LAFETY If1ST14UME14T AND CONTitOL CIl<CUITS Gronip (2)
Fairectiona 1 Test Minimus: Frequency (3) liigh Water IcVel In Scram A
Trip Charnie arid Alarm Every 3 months.
Discharge Tank Turbine Condenser Low Vacuism (6)
B2 Trip Cliannel and Alarm (4)
Every 1 month (1).
Main Steam Line iligh l<adiat ion 111 Trip Cliannel and Alarm (84)
Once/ week.
Main Steam Line Isolation A
Trip Chantiel and Alarm Every 1 month (1).
p Valve Closure Turbine Control Valve A
Trip Channel and Alarm Every 1 month.
EllC Oil Pressure Turbine First Stage Pressure A
Trip Channel and Alarm Every 3 months (1).
Perminuive Turbine Stop Valve closure A
Trip Channel and Alarm Every 1 month (1).
Iteactor Preustare Permissive (6) h2 Trip Channel and Alarm (ii)
Every 3 months.
t
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.G.
TABLE (4.1.2 REACTOR PROTECTIOli SYSTEM (SCRAM) INSTRUMENT CALIBRATION HINIHilM CALIDHATIori FREQUENCIES FOR ItEACTOH PItOTECTION INSTRUMENT CilAtlNELS Instrument Channel Group (1)
Cali t: ration (II)
Minimum Frequency (2)
IRM liigh Flux
~
C Comparison to APitM on Maximum frequency once Controlled Shutdown per week.
APRM liigh Plux output signal B1 Ile at 11alance Flow Ilias Signal Twice per week.
B1 With Standard Pressure Every refueling outage.
Source LPitM Signal til T1P System Traverse Every 6 weeks.
Iligh Heact or Press ur e h'
B2 Standard Pressure Source once per operating
- cycle, liigh Drywell Pressure 11 2 Standard Pressure Source once per operating cycle.
Reactor Low Water Level B2 Preuuure Standard
]
once per operat.ing cycle.
Iligh Water Level in Scram h
A Discharge Volume Water Column Every refueling outage.
N Turbine condenser Low Vacuum o
B2 Standard vacuum Source O
once per operating cycle.
Main Steam Line Isolation A
ilot e (S)
Valve closure Note (5).
Main Steam Line Iligh leadiation B1 Standard Current Source (J)
Eve ry 3 monl iiu.
Turbine First Stage Pressure A
Standard Pressure Source Every de months.
Permissive
Taut,g 4.1.2 (cout W I<EACTOR PitOTECTION SYSTEM (SCI (AM) INS 11<UMEllT CAI.Il3RATIOti MilllMllM CAI.I Bit ATIOli FitEQUEt1CI ES Fult It EAC'l Olt l'I10TECTION ItJSTI<UMENT CilANNEl.S Instrument Channel Group ( 1)
Calitration (ta)
Minimm trequency (2)
Turbine Control Valve Faut.
A Stasidard Pressure Source once per operating Closure Oil Pressure Trip cycle.
Turbine Stop Valve closure A
thte (S) tiot e (S).
Reactor Pressure Preinissive 11 2 St.anda rd laressure Source once per operating Cycle.
M
()
N O
e
?3A?S 3.0 3ASES (Cont'd) the other protectica trip system.
Each protection : rip system has one more APRM :han is necessary to meet the
=ini=un number required per channel.
This allows the
, bypass ng of one APRM per protection trip system for maintenance, testing or calibration.
Addi:ional IRM channels have als o been provided to allow for bypassing of one such channel.
The bases for the scra= setting for :he IRM, A?lM.
high reactor pressure, reactor low vater level, MSIV closure, genera:or load rejec: ion, turbine s:op valve closure and loss of condenser vacuum are discussed in Specification 2.1 and 2.2 Instrumen:a:icn sensing dryvell pressure is provided to detect a loss of coolant acciden: and initiate the core standby cooling equipment.
A high drywell p ressu re scra is provided at the same setting as the core standby cooling systems (CSCS) ini:iation to minimi:e the energy which must be acco:moda:ed during a loss of coolant accident and to prevent return to criticality.
This instrumentation is a backup to the reactor vessel water level instrumen:ation.
High radiation levels in :he main steam line tunnel above
A scram is initiated whenever such radiation level exceeds three times normal background.
The purpose of this scram is to limit fission product release so that 10 CFM Part 100 guidelines are not exceeded.
Discharge of excessive amounts of radioactivity to the site environs is prevented by the air ejector off-gas monitors which cause an isola:icn of the =ain condenser off-gas line.
A reac:or = ode switch is provided which actua:es or bypasses the various scra: fune:icns appropriate to the particular plant operating sta:us.
Ref. paragraph 7.2.3.7 FSAR.
The manual scram fuse:1on is ac:ive in all modes, thus providing for a manual =eans of rapidly inser:in; control rods during all modes of reactor operation.
The A?RM (High flux in S: art-ap or Refuel) system provides protec: ion against excessive pover levels and shor: reactor periods in the star:-up and in:ermediate pover ranges.
The IRM system provides protection against short reactor periods in these ranges.
The control rod drive scram sys:em is desi;ned so that all of the water which is discharged from the reactor by a scra: can be accommodated in the discharge piping.
The scra: discharge volume acco=modates in excess of 50 gallons of water and is the low point in the piping.
No credi: was taken for this volume in :he design of the discharge piping as concerns 1100 20n2
- 3. 2. b. (Cont. 'd)
TABLE INSTI<tiMEt4TATION TilAT ItJITI ATES Olt COtJTi(OLS Tile CORE Ar.D CONTAINME!JT COOLItJG S YS'I EMS Minimum 130.
of Operable 11 umber of Instru-Inutrumeint Trip Function Trip fevel Setting ment Charisiels Pro Hemarks Channels Per Trip System (1) vided Ly Design 2
Reactor liigh Water 5* 45 in. indicat ed 2 Inst. Channels Tripu llPCI and FCIC Level le el turbincu.
1 Heactor Inw Level 1*312 in. above 2 Inst. Channels Prevents inadvertent (inside shroud) vessel zero (2/3 operat. ion of constain-core height) meant spray during accidesit contli t ion.
2 Containment fligli 1 <p<
2 psig 11 Inst. Channels Prevenits isiadverteret v.
Pressure operations of contain-ment spray during accident cos pli t i on.
1 Confirmatory Low 2*6 in. ind ica te<1 2 Isist. Channels ADS Perminuive Level level 2
liigh Drywell 52 psig is Isist. Channels 1.
Initiateu Core Spray:
Pressure LPCI; llPCI 2.
Istitiates starting ot Diesel Generators
.l. Initiates Auto blow-C down (ADS) in conjunction C
with Low-Low Heactor Water level, 120 g
uccond time delay, and g
Li>C I or Cgste Spray u
pump t uninitsig.
l
TABLE 3.2.B (Cont'd) s INSTittlMElJTATION TilAT IN1TI A'IES Olt CO!J'lNOLS Tile CollE AtJD cot 4TAIIIMEllT COOLING SYS'lEMS Minimum Ho.
of Operal)le Ntunt;e r at Iristr:1-I nstrumerit Trip Function Trip Level Setting ment Chasinclu Pre liemarks Channels Per vided by Deuign Tr in System (1) 2 Reactor I.ow 400-500 r 3ig 4 Inst. Channeis Permissive for openisig Pressure
.' Core Spray and LPCI Admission valves.
Coincident with higli dry well pressure, utartu LPCI and Cote Spray rumps.
2 Reactor Low 200-250 psig 4 Inst. Channels Pe rmissive for closing Pressure becirculating Pump I)lucliarge Valve.
h 1
Ileactor I.ow 505P575 psig 2 Inst. Cha.ineln In conjunction with PCI Pressure u tgsia l 1.ermits closure or l<llit (1.PC I) ist ject ion va1feu.
O CD
.r.
. _.. - _.. - - _. ~. - - -.. _ _. _ - _ _
9 TAHl.E ti.2.B 4
1 MINIMUM TEST AND CAI.IllHATION FREOllENCY FOR CSCS Instrument Channel I sist rumen t Funictiona1 Test Calibrations l regineticy Instr urnent Check 1)
Iteactor Water Level (7)
(1) (3)
Once/ operating cycle once/ day 2)
Drywell Pressure (7)
(1) ( 3)
Once/operatisig cycle Once/ day 3)
Heactor Pressure (7)
(1) (3)
Once/ operating cycle once/ day fa )
Auto Sequencing Tirners 13A Once/operatisig cycle None 5)
( 8)
Once/3 mont.hu None Pressure Interlock 6)
Trip System l' a Power Monitors (1)
NA tione 7)
Core Spray Sparger d/p
( 1)
Once/6 months 0
once/ day U)
Steatri Linie liigli Flow (IIPCI & HCIC)
(1)
Once/3 monthu Notic
,9)
Steam Line liigh Teinp. (IIPCI & RCIC)
(1) (3)
Once/orerating cycle once/ day
- 10) Safeguards Area Iligh Temp.
( 1)
Once/3 months None
- 11) IIPCI and HCIC Steam Line (1)
Once/3 monthu None Low Pressure
- 12) IIPCI Snation Source Levels (1)
Once/3 marithu Hone
- 13) 84KV Emergency lower System l
Voltage Relays Once/ operating cycle Once/S year None o
O 1:4) ADS Helief valven lsellows once/ operating cycle Once/ol.erating cycle None Pressure Switches N
O
- 15) I.PCI/ Cross Connect Valve Positidn" Once/refineling cycle N/A N/A
e TAllI.E 'I. 2. F MilllMllM TEST AtJD CAI.lliltATIOff I'ItEQIlEtJCY FOlt Sill <V E I I.AtJC E I tJSTI< TIM E!11'AT 1014 I rist rumen t Clia tiste l Cd I ilsr.st i ori 1 ;egurricy t itut t tiene nt Check 1)
I<c ac t o r Level Once/otierating cycle Once Each Ubif t l
2)
Iteactor Presstare 0 ice /6 monsths Once Each Sliift i
t 3)
Drywell Pressure r ce/6 anonths once Each Shitt i
s i
is)
Drywell Temperature Cnce/6 months once Eacts shif t I.
I, 5)
Stappression Chamber Temperature Once/6 inonths once Each Shift
\\
l 6)
Suppression Chamber Water Level Orice/6 inonths once Euch Shift l
1 7)
Control Itod Posit ion tiA Once Each Shift i
i 8) ficutron Monitoring ( API 1M)
Twice Per Week Once Eacli Shitt l
0 W
e-Q i
IN' s
C C' ~
s