ML20096F559
| ML20096F559 | |
| Person / Time | |
|---|---|
| Site: | FitzPatrick  |
| Issue date: | 05/14/1992 |
| From: | Capra R Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML20096F560 | List: |
| References | |
| NUDOCS 9205210225 | |
| Download: ML20096F559 (30) | |
Text
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UNITED STATES
+
i LNUCLEAR REGULATORY COMMISSION
- L WASH.INoToN D C. 20666
. fo POWER AUTHORITY OF THE STATE OF NEW YORK DOCKET NO. 50-333-JAMES A. FIIZPATRICK NUCLEAR POWER PLANT g -
AMENDMENT TO FAClllTY OPERATING LICENSE I
Amendment No.181 License No. OPR-59
- 1. -The Nuclear-Regulatory Comission (the Comission) has found that:
A.
The application for amendment by Power Authority of the State of New York -(the licensee)^ dated May 30, 1990,- as supplemented April-18,'1991, complies:with the standards and requirements of the Atomic Energy' Act of 1954, as amended (the Act) and the Comission's rules and regulations _ set - forth in-10 CFR Chapter ~I;
-B.
The facility will operate.in conformity with the_ application, the provisions of the. Act, and the rules and regulations of the -
Commission;.
C.
There is reasonable assurance (i) that.the activities authorized by this amendment can be conducted without endangering the health and safety of-the public, and (ii) that such activities will be conducted '
- in compliance-with the Commission's regulations;.
D.1The_ issuance of this amendment will not be inimical to the common riefense and security or to the health and safety-of the: public; and -
lE.
The issuance of this amendment is in accordance with 10 CFR Part
- 51 of the' Commission's regulations and:all' applicable requirements
-have-been-satisfied.
_2.
Accordingly, the license is-amended by changes to the Technini
-Specifications as indicated-in the. attachment.to this. license amendment, and: paragraph 2.C,(2) of Facility Operating License No.--OPR-59 is hereby amended to read as follows:
4 4
9205230225 920514 P D R -- ADOCK 05000333
[
P.
~
p (2) Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No.181, are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications.
3.
This license amendment is effective is of the date of its issuance to be implemented within 30 days.
FOR THE NUCLEAR REGULATORY COMMISSION N&0.
Robert A. Capra, Director Project Directorate I-l Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation
Attachment:
Changes to the Tachnical Specifications Date'of Issuance: May_14, 1992
ATTACHMENT TO LICENSE AMENDMENT NO.181 FACILITY OPERATING LICENSE NO. OPR-59 DOCKET NO. 50-333 i
Pevise Appendix A as follows:
Remove Paoes Insert Paaes y
v vi vi 54 54 59 59 60 60 61 61 76 76 76a 76b 76c 76d 77a 7
77b 770 77c 77d 78 78 79 79 80 80 81 81 83 83 84 84 85 85 86 86 86a 86a 90 90 165 165 180 180 l
181 181 i
188 188 190
-190 210 210 l
l l
l l-
JAFNPP LIST OF TABLES j
Table Title Py _
3.1 1 Reactor Protection System (Scram) Instrumentation Requirement 41 4.1 1 Reactor Protection System (Scra a) Instrument Functional Tests 44 4.1 2 Reactor Protection System (Scram) Instrument Ca!ibration 46 02-1 Instrumentation that initiates Primary Containment Isolation G4 32 2 Instrumentation that Initiates of Controis the Core and Containment 66 Cooling Systems l
32-3 Instrumentation that initiates Control Rod Blocks 72 32-4 (DELETED) 74 3.2 5 instrumentation that Monitors Leakage Detection inside tho Drywell 75 l
32-6 (DELETED) 76 32 7 Instrumentation that initiates Recirculation Pump Trip 77 3.2-8 Accideni Monitoring instrumentation 77a 4.2-1 Minimum Test and Calibration Frequency for PCIS 78 42-2 Minimum Test and Cahbration Frequency for Core and Containment 79 Ccoling System 42-3 Minimum Test and Calibration Frequency for Control Rod Blocks 81 Actuation 4.2-4 (DELETED)
_82 j
4.2-5 Minimum Test and Calibration Frequency for Drywell Leak Detection 83 4.2 6 (DELETED) 427 Minimum Test and Calibration Frequency for Recirculation Pump Trip 85 l
l l
l Amendment No. 26,23,#30 181 v
-JAFNPP LIST OF TABLES { Cont'd)
Table '
Title Pace 42-8 Minimum Test and Calibration Frequency for Accident Monitoring 86 l
Instrumentation 4.6 1 Snubber VisualInspectioninterval 161 4.6-2 Minimum Test end Calibration Frequency for Drywell Continuous 162a Atmosphere Radioactivity Monitoring System 4.7 1 (DELETED) 210 4.7 2 Exception to Type C Tests 211 3.12-1 Water Spray / Sprinkler Protected Areas 244j t
3.12 2 Carbon Dioxide Protected Areas 244k 3.12-3 Ma.1ual Fire Hose Stations 2441 i
- 4.12-1 Water Spray /Sprink;c: System Tests 244q 4.12-2 Carbon Dioxide System Tests 244r i
4.12 3-Manual 83 Hose Station Tests 244s 621 Minimum Shift Manning Requirements 260a 6.10-1 Component Cyclic or Transient Umits 261 l
Amendment No. Sd,22,92,1/1,1)d,194,1#0,1J8, W 181 vi
a JAFNPP 32 (cont'd) 4.2 (cont'd)
E.
Drywell Leak Detection E.
Dr*/weil Leak Detection The limiting conditions of operation for the instrumentation that instrumentation shall be calibrated and checked as indicated in mcitors drywell leak detection are given in Table 32-5.
Table 42-5 F.
(Deleted)
F.
(Deleted)
G.
Recirculation Pump Trig G.
Recirculatici. 4; "9 Trip The limiting conditions fr operatio(.,or the instrumentation that instrumenta; ion shdl be functionairy testad and cailtrated as trip (s) tre recirculaSon pumps as a means of limiting the indicated in Table 42-7.
consequences of a f arfurrato scram during an anticipated transient are given in Tabte 3.2-7.
System logic shafi be functiorn'ly tested as indicated in Table 42-7.
H.
Accident Monitoring instrumentation H.
Accident Monitoring lastrumentation The limiting conditions for operation of the instrumentation that provides accident monitoring are given in Table 3.2-8.
Instrumentation sha!! be demonstrated operable by peiicamani,s of a del d-d and hel Mikation as indicated in TWe 1.
4kv Emergency Bus Undervoltage Trip 4.2-8.
The limiting conditions for operation for the instrumentation that prevents damage to electrical equipment or circuits as a resutt of either a degraded or loss-of-voltage condition on the emergancy electrical buses are given in Table 32-2.
- Amendment No 1jM$,90 181 54
JAFNPP 32 BASES (cont'd) the specification are adequate to assure the above criteria are met. The specification preserves the effectiveness of the system during periods of maintenance, testing, or calibr? tion, and also minimizes the risk of inadvertent operation; i.e., only one instrument channel out of service.
Flow integrators are used to record the integrated flow of liquid from the drywell sumps. The leak rate is calculated by dividing the integrated volume pumped out of the sumps by the time between sump pump operations. The resultant leak rate value, which is expressed in gallons per minute, is compared to the acceptance criterion specified in Specification 3.6.D.
For each parameter monitored, as listed in Table 32-8, by I
comparing the reading of each channel to the reading on redundant or related instrument channel a near continuous surveillance of instruinent performance is available.
I
, Amendment No. M,(Mf,1% 181 i
59
JAFNPP 3.2 BASES (cont'd)
The recirculation pump trip has been added at the suggestion The Emergency Bus Undervoltage Trip System transfers the 4 of ACRS as a means of limiting the consequences of the kv emergency electrical buses to the Emergency ' Diesel unlikely occurrence of a failure to scram during an anticipated Generators in the event an undervoltago condition is detected.
transient. The response of the plant to this postulated event The system has two levels of protection: (1) degraded voltage falls within the envelopo of study events given in General protection, ~ and - (2) loss-of-voltago protection. Degraded Electric Company Topical. Report, NEDO-10349, dated voltage protection prevents a sustained low voltage condition March,1971.
from damaging safety-related equipment. The degraded Accident monitoring instrumentation provides additional
- 1tage protection has two time do!ays. A short timo delay information which is helpful to the operator in assessing plant coincident with a loss-of-coolant accident (LOCA) and a longer.
timo delay to allow normal plant evolutions without conditions following an accider; by (1) providing information needed to permit the operators to take preplanned manual unnecessa% stadng h hgency Desel Generatas. N actions to accomplish safe plant shutdown; (2) determining i sse!-voltago protection prevents a more severo voltage drop whether systems are performing their intended functions; from causing a long term interruption of power. Time delays (3) providing information to the operators that will enable them are included in the system to provent inadvertent transfers due to determine the potential for a breach of the barrier to to Wous Wmgo hases. hefwe, W h dwadon radioactivity release and if a barrier has been breached; and severity of the voltage drop are sensed by the Emergency (4) fumishing data for deciding on the need to take unplanned Bus Undervoltage Trip System.
action if an automatic or manually initiated safety system is not functioning properly or the plant is not responding properly to the safety systems in operation; and. (5) allowing for early indication of the need to initiato action necessary to protect the public and for an estimato of the magnitude of any problem.
This instrumentation conforms with the acceptance criteria of NUREG-0737, NUREG4578, and NRC Generic Letter 83-36 and includes Regulatory Guide 1.97, Revision 2 Type A variables.
~ Amendment No. lad,120, l'irJ, PJd 181 60
JAFNPP 42 BASES l
Tne incirumentation listed in Tables 42-1 through 42-8 will be To test the trip relays requires that the channel be bypassed..
functionally tested and calibrated at. regularly scheduled the tost made, and the system returned to its initial state. It is.-
intervals. The same design re!! ability goal as the Reactor assumed inis task requires an estimated 30 min. to complete in Protection System is generally applied. Sensors, trip devices a thorough and workmanlike manner End that the relays have a 4
and power supplies are tested, calibrated and incked at the failure rate of 10 failures per hr. Using this data and the above '
same frequency as comparable devices in "he Reactor operation, the optimum test intervat is:
Protection System.
Those instruments' which, when tripped, result in a rod block i.
M =1x10 hr.
3 4
have their contacts arranged in a 1 out of n logic, and all are 10 capable of being bypassed. For such a tripping arrangement
= 40 days with bypass capability provided, there is an optimum test For additional margin a test interval of once/ month will be interval that should be maintained in order to maximize the used initially.
reliability of a given channel (7). This takes account of the fact that testing degrades reliability and the optimum interva!
The sesors and doctrMc apparatus be not bwn incW between tests is approximately g!ven by:
here as these are analog devices with readouts in the control room and the sensors and electrordc apparatus can be-checkod by comparison with otner like instruments. The checks which are made on a daily basis are adequate to assure i=
operabili;y f the sensors and electronic apparatus, and the __
h e'.
test interval given above provides for optimum testing of the i=
the optimum interval between tests.
relay circuits.
t=
the time the trip contacts are disabled from performing their function while the test is in progress.
r=
tho expected failure rate of the relays.
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- Amendment No. 91,124, 181 61-l
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JAFNPP TABLE 3.24 ACCIDENT MONITORING INSTRUMENTATION No.of Channels Minimum No of Mode in Which Provided by Operable Channets Instrument Must instrument Design Required be Operable Action 1.
Stack High Range Effluent Monitor 2
1-Note H Note B (17RM-53A) -
(17RM-538) 2.
Turbine Building Vent High Range Effluent Monitor 2
1 Noto H Nota B (17RM-434A)
(17RM-434B) 3.
Radwaste Building Vent High Range Effluent Monitor 2
1 Note H Note B (17RM-463A)
(17RM4638) 4.
Containment High Range Radiation Monitor 2
1 Note H Note A (27RM-104A)
(27RM-1048) 5.
Drywell Pressure (narrow range) 2 1
Note J Note A (27PI-115A1 or 27PR-115A1)
(27PI-11581 or 27PR-11581) 6.
Drywell Pressure (wide rarge) 2 1
Note J Note A (27PI-115A2 or 27PR-115A2)
(27PI-11582 or 27PR-11582) 7.
Drywell Temperature 2
1 Note J Note A (16-1TR-107)
- At less than or equal to 450 R/hr, closes vent and purge valves Amendment No, J26, 181 77a 8
_q b
f JAFNPP' l
l.
TABLE 3.2-8 (cont'd) l I
ACCIDENT MONITORING INSTRUMENTATION No.of Channels PAnimum No. of Modo in Which Provided by Operable Channels instrurr:ent Must l
Instniment Design Required be Operable Action j
l l
8.
Torus Water Leve!(wide range) 2 1
Note J Note A (23U-202A or 238-202A/203A)
(23U-2028 or 23LR-202B/2038) 9.
Torus Bulk Water Temperature 2
-1 Note J Note A
)
(16-1T1-131 A or 16-1TR-131 A)
(16-1TI-131B or 16-1TR-1318)
I 10.
Torus Pressure 2
1 Note J Note A (27FR-101A)
(27PR-10181) l 11.
Dryweli Hydrogen / Oxygen Concentration 2
1 Note J Note F i
l (27PCR-101A)
(27PCR-1018) 12.
Reactor Vessel Pressure 2
1 Note J Note A (06PI-61 A or 06PR41 A)
(06PI-618 or 06PR41B) 13.
Reactor Water Level (fue! zone) 2 1
Note J Note A (02-3U-091) l (02-3LRW86) 14.
Reactor Water Level (wide range) 2 1
Note J Note A (02-3U-85A)
(02-3LR-858) l l
l Amendment No.M, 101 l
77b I
u
JAFNPP TABLE 3.2-8 (cont'd)
ACCIDENT MONITORING INSTRUMENTATION No. of Channels Minimum No. of Modoin Which Provided by Operable Channels Instrument Must
!nstrument Design Required be Operable Action 15.
Core Spray Flow 1 per loop 1 perloop Note J Note A loop A (14FI-50A) loop B (14F1-508) 16.
Core Spray discharge pressure 1 per loop 1 porloop Note J Note A loop A (14PI-48A) loop B (14Pi-4SB) 17.
LPCI (RHR) Flow 2 per loop 1 per loop Note J Note A loop A (10F1-133A)
(10FR-143 - red pen) loop B (10F1133G)-
(10FR-143-blue pen) 18.
RHR Service Water Flow 1 perloop 1 per loop Note J Note A loop A (10F1-132A) loop B (10F1-1328) 19.
Safety /Re!ie! Valve Position Indicator 2
1 Note J Notes D, E (See Note.C) 20.
Torus Water Level (narrow range) 2 Note J Note B (23LI-201 A or 27R-101 - red pen or EPIC A-1258)
(EPIC A-1260)
(See Note G) 21.
Dnjwe!!-Torus Ditterential Pressure 2
1 Ncto J Note B (16-1DPR 200 or EPIC A-3554)
(EPIC A-3551)
(See Noto G)
Amendment No.181 77c d
JAFNPP-TABE 32-8 (Cont'd)
ACCIDENT MONITORING INSTRUMENTATION NOTES FOR TABE 3.2-8 A.
With the number of operable channe:S tess than the required minimum, either restore the inoperable channels to operable status within 30 days,
{
or be in a cold condition within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
B.
With the number of OPERABW channels less than required by the minimum channels OPERABW requirements, initiate an a!!cmate method of monitoring the appropriate parameter (s) within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> and: (1) cither testore the inoperable channe8(s) to OPERABW status within 7 days of the event, or (2) prepare and submit a Special Report to the Commission within 14 days following the event outlining the cause of the inoperability, the action taken, and the plans and schedule for restoring the system to OPERABE status.
C.
Each Safety / Relief Valve is equipped with two acoustical detectors, one of which is in service. Each SRV also has a backup thermocouple detector. In the event that a thermocoupie is.aoperable, SRV performance shan be monitored dei!y with the associated in service acoustical detector.
D.
From and after the date that both of the acoustica! detectors are irw ble, continued opcration is permissible until the next outage in which a primary containment entry is made prcvided that the thermocouple is operable. Both acoustical detectors shaf! be rnade operable prior to restart.
E.
In the event that both primary (acoustical detectors) and secondary (thermocouple) indicatic.
- parameter for any one valve are disabled and neither indication can be restored in forty-eight (48) hours, an ordctly shutdown sha'l be inruued and the reactor sha!! be in a Hot SNatdown condition in twelve (12; hours and in a Cold Shutdown within the next twanty-four (24) hours.
F.
Refer to Specification 3.7.A.S.
G.
This parameter and associated instrumentation are not part of posta:cident monitoring.
H.
This instrument shall be operable in the Run, Startup/ Hot Standby, and Hot Shutdown modes.
J.
This instrument shall be operable in the Run and Startup/ Hot Standby modes.
- Amendment No.181 77d
JAFNPP TABLE 42-1 MINIMUM TEST AND CALIBRATION FREQUENCY FOR PCIS Instrument Channe!(8)
' instrument Functional Test Calibration Frequency Instrument Check (4)
I
- 1) Reactor High Pressure
'(1)
Once/3 months None (Shutdown Cooling Permir,sive)
- 2) heacter Low-Low-Lon Water Level (1)(5)
(15)
Once/ day
- 3) Main Steam High Temp.
(1)(5)
(15)
Once/ day
- 4) Main Steam High Flow (1)(5)
(15)
Once/ day
- 5) Main Steam low Pressure (1)(5)
(15)
Once/ day
- 6) Reactor Water Cieanup High Temp.
(1)
Once/3 months None
- 7) Condenser Low Vacuum (1)(5)
(15)
Once/ day Logic System FunctionalTest (7) (9)
Fr w /
1)
Main Steam UneIsolation valves Once/6 months Main Steam Une Drain Valves Reactor Water Sample Valves 2)
RHR -Isolation Valve Control Once/6 months Shutdown Coc4ing Valves Head Soray 3)
Reactor Water Cleanup Isolation Once/6 months 4)
Drywellisolation Valves Once/6 months TIP Withdrawal Atmospheric Controf Valves 5)
Standby Gas Treatment System Once/6 months Reactor Building Isolation l
NOTE:
See notes following Table 42-5
' Amendment No.p/,JFf lad,181 78
-~
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l
JAFNFP TABLE 42-2 MINIMUM TEST AND CAUBRATION FREQUENCY FOR CORE AND CONTAINMENT COOUNG SYSTEMS Instrument Channel (8) instrument Functional Test Calibration Frequency Instrument Check (4) 1)
Reactor Water Level (1)(5)
(15)
Once/ day 2a)
Drywell Pressure (non-ATTS)
(1)
Once/3 months None-2b)
Drywell Pressure (ATTS)
(1)(5)
(15)
Once/ day 3a)
Reactor Pressure (non-ATTS)
(1)
Once/3 months None 3b)
Reactor Pressure (ATTS)
(1)(5)
(15)
Once/ day, 4)
Auto Sequencing Timers None Once/ operating cycle None 5)
(1)
Once/3 months None 6)
Trip System Bus Power Monitors (t)
None None 8)
Core Spray Sparger d/p (1)
Once/3 months Once/ day.
9)
Steam Une High Flow (HPCI & RCIC)
(1)(5)
(15)
Once/ day 10)
Steam Une/ Area High Temp. (HPCI & RCIC)
(1)(5)
(15)
Once/ day 12)
HPCI & RC7 3 team Une Low Pressure (t)(5)
(15)
Once/ day 13)
HPCI & RCIC Suction Source Levels (1)
Once/3 months None 14) 4kV Emergency Bus Under-Voltage Once/ operating cycle Once/ operating cycle None (Loss-of-Voltage, Degraded Voltage LOCA and t.sn-LOCA) Relays and Timers.
15)
HPCI & RCIC Exhaust Diaphragm (1)
Once/3 months None Pressure High 17)
LPCl/ Cross Connect Valve Position Once/ operating cycle None None l NOTE:
See notes fo!!owing Table 42-5.
Amendment No. 14,45,56, p6,106, }2d, I d, 181 f
79
JAFNPP TABLE 4.2-2 (Cont'dl MINIMUM TEST AND CAUBRATION FREQUENCY FOR CORE AND CONTAINMENT COOUNG SYSTEMS Logic System Functional Test Frequency 1)
Core Sprev Subsystem (7) (9)
Once/6 months 2)
Low Pressure Coolant injection Subsystem (7) (9)
Once/6 months 3)
Containment Cooling Subsystem (9)
Once/6 months 4)
HPCI Subsystem (7) (9)
Once/6 months 5)
HPCI Subsystem Auto Isolation (7).
Once/6 months 6)
ADS Subsystem (7) (9)
Once/6 months 7)
RCIC Subsystem Auto isolation (7)
Once/6 months 8)
ADS Relief Valvo Bellow Pressure Switch (7) (9)
Once/ operating cycle NOTE:
See notes following Table 42-5.
\\
Amendment No. g, SG, 109, 181 80 21 2
e----__e e.e:e:=a'-e--
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-JAFNPP-4.
TABLE 4.2 : MINIMUM TEST AND CAUBRATION FREQUENCY FOR CONTROL ROD BLOCKS ACTUATION instrument Functional instrument Instrument Channel Test (5) _
Cali'Jation i Check (4)(
~l 1)
APRM - Downscale (1)
Once/3 rrwdts Once/ day ;
2)
APRM-Upscale (1).
Once/3 irvdts Once/ day -
3)
(RM-Upscale (2)
(3)
.(6)
Once/dap 4) lRM - Downscale (2)
'(3)
.(6)
Once/ day -
5)
RBM - Upscale.
(1)
Once/3 months Once/ day.
6)
RBM - Downscale (1)
Once/3 rnonths Once/ day 7)
SRM-Upscale (2)
(3).
(6)
Once/ day.
8)
SRM - Detector Not in Startup P'sition (2)
(3)
(6)
None
- t 9) lRM - Detector Not in Starco RNion.
(2)
(3)
(S)
None-10)
Scram Discharge Instrumer : hr.a-Once/ month Once/3 rr&dio Once/ day -
High Water Level (Group B h wments)
.(1)
'. i Logic System Function Test (7) (9)
Frequency I
1)
System Logic Check Once/6. months.
j l
NOTE:
See notes following Table 4.2-5.
ii l
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Amendment No. g rf, p!I,.. i81 '
81.
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JAFNPP TABLE 42-5 l
MINIMUM TEST AND CAUBRATION FREQUENCY FOR DRYWELL LEAK DETECTION Instrument Functional Wibration inst;M Check Wrurnent Channel Test Frequency (4) i i
_,xneni Drain Fumf How l
1)
Ldegrator (1)
Once/3 months Once/czy 2)
Floor Drain Str.sp Flow integrator (1)
Once/3 morfJis Once/def f
l l
l NOTE-See notes following Table 42-5
~ Amendment No. Stf,ps,181 83
JAFNPP l NOTES FOR TABLES 42-1 THROUGH 42-5 7.
S once e 1.
Initia!!y once every month until acceptance failure rate data are available; thereaftee a request may be made to the NRC to paabng c'A. he W, aH @ systan W chance the test frt pency. The compilation of instrument tests mH M pafW using h testW failure rato data may include ciata obtained from other boiling 8.
Reactor low water level, h;gh drywc!! pressure and high water reactors for v.tiich the same design instruments operate radiation main steam fine tunnel are not included on Table 42-1 in a environment similar to that of JAFNPP.
since they are tested on Tab;a 4.1-2.
2.
Functional tests are not required when these instruments are 9.
The logic system functional tests shall include a ca!ibration of not required to be operable or are tripped. Functional tests time delay relays and timers necessary for proper functioring shall be performed within seven (7) days prior to each startup.
of the trip systems.
3.
Caibrations are not required when these instruments are not 10.
At least one (1) Main Stack Dilution Fan is required to be in required to be operable or are inpped. Calibration tests shan operation in order to isokinetica'ly sample the Main Stack.
be performed within seven (7) days prior to each startup or 11.
Uses same instrumentation as Main Steam Line High prior to a pm-planned hh Radiation. See Table 4.1-2.
4.
Instrument checks are not required when these instruments are 12.
(Deleted) not required 10 be operable or are inpped.
13.
Calibratica and instrument check surveillance for SRM and IRM 5.
This instrume.. tat. ion ss exempt from th3 functional test definition. The funcu,onal test will consist of injecting a Instruments are as specifed in TatSes 4.1-1,4.1-2,42-3.
simulated ciectrica! signal into the measurement channel.
t4 Functional test is performed once each operating cycle.
6.
These instrument channels will be calibrated using simulated 15.
Sensor calibration once per operating cycle. Master / slave trip electrical signals once every three mont.%.
unit calibration once per6 months.
. Amendment No. 34, A6,FT,ps,181 84
- TABLE 42J MINIMUM TEST AND CAUSRATION FREQUENCY -
FOR ATWS RECIRCULAliOM FUiwP TRIP ACTUATION INSTRUMENTATION FUNCTION -
CHANNEL =
CHANNEL TRIP UNIT CHANNEL SIMULATED AUTO ACTUATION CHECK-FUNCTIONAL
. CAUBRATION CAUBRATION
& LOGIC FUNCTIONALTEST TEST
~-
1 - Reactor Presnre-High Once/ day Once/31 days' Once/6 rreitis Once/ Operating. Once/Operatog cycle cycle 2-Reactor Water Level-Low Low Once/ day Once/31 days Once/6 months Once/ Operating Once/Cwssg cycie cycle s
t i '
Amendment No. p6,36,pf,Jisf,181 as 4
---... ~ -
----d
i JAFNPP TABLE 4.2-8 MINIMUM TEST AND CAllBRATION FREQUENCY FOR ACCIDENT MONITORING INSTRUMENTATION Instrument twLument Instrument FunctionalTest Calihration Frequency Check 1.
Stack High Range Effluent Monitor Once/ Operating Cyde Once/ Operating Cycle Once/ day 2.
Turbine Building Vent High Range Effluent Monitor Once/ Operating Cyde Once/ Operating Cycle Once/ day 3.
Radwaste Building Vent High Range Effluent Monitor Once/ Operating Cyde Once/ Operating Cycle Once/ day J
4.
Containment High Range Radiation Monitor Once/ Operating Cycle Once/ Operating Cyde Once/ day 5.
Drywell Pressure (narrow range)
N/A Once/ Operating Cycle Once/ day 6.
Dryweil Pressure (wide range)
N/A Once/ Operating Cycle Once/ day
't.
Dryr/cIl Temperature N/A Once/ Operating Cycie Once/ day B.
Torus Water Level (wide range)
N/A Onco / Operating Cycle Once/ day 9.
Torus Bulk Water Temperature N/A Once/ Operating Cycle Once/ day l
l 10.
Torus Pressure N/A Goce/ Operating Cycle Once/ day i
11.
Drywe!! Hydrogen / Oxygen ConcenLdion Analyzer N/A Once/3 months Once/ day 12.
Reactor VeM Pressure N/A Once/ Operating Cycle Once/ day l
13.
Reactor Water Level (fuel zone)
N/A Oncc/ Operating Cyde Once/ day 14.
Reactor Water Level (wido range)
N/A Once/ Operating Cycle Once/ day l
Arnendment No. g, pf, 181 86
JAFNPP TABLE 4.2-8 (cont *d)
MINIMUM TEST AND CAU8 RATION FREQUENCY FOR t
ACCIDENT MONITORING INSTRUMENTATION i
instrument Instrument instrument FunctionalTest C&Wucn Frary>ancy Check _
15.
Core Spray Row N/A Once/ Operating Cycle Once/dey 16.
Core Spray Discharge Pressure N/A Once/Operahng Cycle Once/ day 17.
LPCI(RHR) Flow N/A Once/Operahng Cycle Once/ day j
18.
RHR Service Water Flow N/A Once/ Operating Cycle Once/d.y 19.
Safety / Relief Valve Position Indicator -
Once/ Operating Cycle N/A Once/rnonth t
4 (Primary and Secondary) i:
20.
Torus Water Level (narrow range)
N/A Once/ Operating Cycle Once/ day 21 Drywell-Torus Differential Pressure N/A Once/Opsatug Cycle Once/ cay l
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. Amendment No. Ja6,181 k
l' 86a
_. ~.
r's" JAFNPP 3.3.A.2 (cont'd) 4.3A2 (cont'd) b.
The control rod directional control valves for e.
The scram discharge volume drain and vent de inoperablo conirol rods shall be disarrned shall be full-travel cycled at least once per quart-
- f electrically.
verify that the valves close in less than 30 secork c.
Control rods with scram times greater than those W to asswe m wh Me W pahon.
a permitted by Specification 3.3.C.3 are 'noperable, f.
.An instrument check of control rod position 1
but if they can be inserted with contrc* tx1 drive indication shall be pedcxtreed once/ day.
y pressure they need not be disarmed electrically.
d.
Control rods with incterable accumulators or those whose position cannot be positrvely determined shall be considered inoperable.
e.
Inoperable control rods shall be positioned such that -
Specification 3.3A1 is ' met. In addition, during reacior pcwer operation, no more than one contrc4 rod in any 5 X 5 array may be inoperabie (at least 4 operable control rods must separate any 2 inoperable ones). 'If this specification cannot be met the reactor shall not be strted, or if at power, the reactor shall be brought to a cold corx1.1 tion vnthin 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
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. Amendment No.16,1,1!4, }d,Ja$, 181 90
JAFNPP 3.7 UMITING CONDITIONS FOR OPERATION 4.7 SURVEILLANCE REQUIREMENTS 3.7 CONTAINMENT SYSTEMS 4.7 CONTAINMENT SYSTEMS Applicability:
Applicability-Applies to the operating status of the primary and secondary Applies to the pnmary and secondary contamment integnty.
containrnent systems.
Objective:
Objective:
To assure the integrity of the primary and secondary containment To verify Eeintegi*y d the prir.ary, and secondary containment e
systems.
systems.
Specification:
Specificatiort A.
l 1.
The volume and temperature of the water in the torus sha!!
1.
The torus water level and temoerature sha!! be monitoed
{
be maintained within the following limits whenever the as sWfied in Table 42-8. The accessible interior reactor is critical or whenever the reactor coolant surfaces of the drywell and above the water line of the temperature is gresier than 212 F and irradiated fuel is in torus shall be inspected at each refueling ou'ays for the reactor vessel:
evidence of deterioration. Whenever there is indication of relief valve operation or testing which adds heat to the a.
Maximum vent submergence ;cvel of 53 inches.
supgier.Jon pool, the pool temperature sha!! be b.
Minimum vent submergence level oi51.5 inches.
y a
also hM M W W 5 rnnutes until the heat addition is terranated. Vamnever l
The torus water level may be outside the above there is indicata of relief valve operation with the limits for a maximum of four (4) hours during temperature of the suppression pool reaching 160"F or required operability testing of HPCI, RCIC, RHR, CS, more and the primary coolant system pressure greater l
and the Drywell-Torus Vacuum System.
than 200 psig, an extemal vtsual examination of the torus l
c.
Maximum water temperature M be Mucted befmo rMng poww opeada (1)
Dunng normal power operation maximum water temperature shall be 95*F.
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. Amendment No. eg,%,181 165
.q
- 4 $
JAFNPP 3.7 (cont'd) 4.7 (cont'd) 6.
Oxygen Concentration 6.
Oxygen Conco7tration a.
The primary containment atmosphere sha!! be c.
The pomary contarnment oxygen concentration shall I
reduced to less than four percent oxygen with be monitored as specified in Table 42-8.
l nitrogen gas during reactor power operation with reactor coolant pressure atxwe 100 psig, except as specified in 3.7.A.6.b.
b.
Within the 24 hr. period subsequent to placing the reactor in the run mode followW a shutdown, the containment atmosphere oxygen concentra" A shall be reduced to less than 4 percent by weight and maintained in this corxfition. De-inerting may commence 24 hr. prior to a shutdown.
7.
Drywel!-Torus Differential Pressure l
7.
Drywell-Torus Differential Pressure a.
The pressure differer'tial between the drywell and a.
Differential pressure between the drywo!! and torus torus shall be monitored as specified in Tablo 42-8.
l shall be maintained at equal to or greater than 1.7 psi <1 except as speciflad in (1) and (2) below-s
..4,-
. Amendment rJo. /,131 180
JAFNPP 3.7 (cont'd) 4.7 (cont'd) 9.
Primary containment atmosphere shall be continuously 9.
Primary Containment Atmosphere Monitoring Instruments monitored for hydrogen and oxygen when containment integrity is required. The exception to this is when the a.
Instrumentation shall be functionally tested and Post-Accident Sampling System is to be operated. In this ca!ibrated as specified in Table 42-8.
l instance, the containment atmosphere monitoring systems may be isolated for a period not to exceed 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> in a 24-hour period.
The monitoring system shall be considered operable if at least one monitor is operable.
a)
From and after the time the primary containment atmosphere monitoring instruments are found or B.
Standby Gas Treatment System made to be inoperable for any reason, continued reactor operation is permissible for the succeeding 1.
Star.dby Gas Treatment System surveillanco sha!! be f
thirty (30) days unless one instrument monitoring performed as indicated below-
)
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cach parameter is sooner made operable, provided l
an appropriate grab sample is obtained and a.
At least once per operating cycle, it sha!! be 1
l analyzed at least once each twenty-four (24) hour demonstrated that
[
period.
0) sum dop acoss h MW @
b)
If specification 3.7.A.S.a cannot be met, the reactor y ency W NW Mas b less M 5.7 l
shall be placed in the cold condition within twenty-waW at 6,M dm, W four (24) hours.
(2)
Each 39kW heater sha!! dissipate greater than B.
Standby Gas Treatment System 29kW of electnc power as calculated by the following expressort 1.
Except as specified
.7.82 below both circuits of the P =6EI Standby Gas Treatmu System shall be operable at all g.~
times when secondary containment integrity is required.
P= Dissipated Electricd Power; E= Measured line-to-line voltage in volts (RMS);
l=
Average measured phase curren; in amperes (RMS).
, Amendment No. )6,28, Z, G6,69, &f,56, 181 181
i JAFNPP i
3.7 BASES (cont'd)
Using the minimum or maximum downcomer submergence Using a 40V rise (Section 5.2 FSAR) in the suppression levels given in the specification, containment pressure during chamber water temperature and a maximum initial temperature the design basis a:ctdent is appro).imately 45 psig which is of 957, a temperature of 1457 is achieved, which is weil below below the design of 56 psig.- The minirnum downcomer the 170*F teraperature which is used for comp!cte submergence of 51.5 in. results in a minimum suppression condensatior:.
3 chamber water volume of 105.600 ft. The majority of the Bodega tests (9) were run with a submerged length of 4 ft. and For an initial maximum suppression chamber water z
with comp!ete condensation. Thus, with respect to downcomer tmature of 957 and assuming the normal complement of containment cooling pumps (two LPCI pumps and two RHR submergence, this specification js adequate. Addit:onal JAFNPP specific analyses done in connecticn with the Ma!k I service water pumps) containment p' essure is not required to Containment-Suppression Chamber Integnty Program indicate marntain adequate net pcs.tive suction head (HPSH) for tne the adequacy of the specified range of submergence to ensure corc sprav LPCS snd IFCI pumps.
l that dynamic forces associated with pool swell do not resu!t in Umiting suppression pool temperature to 1307 during RCIC, overstress of the suppression chambo-or associated HPCia re!!cf vane operatW1. when decay heat and stored structures. Levet instrumentation is provided for ooorstor use energy are removed form the primary system by discharging to maintain downcomer submergence within ihe specified reardor steam directly to the supo'ession chamber assures
[
range.
cdequate margin for a pctential blowdown any time during 0
" U"'
The maximum temperature at the end of biowdovm tested during the Humboldt Bay (10) and Bodega Bay tests was Experimental data indicates thst excessive steam condensing 1707, and this is conservatively taken to be the timit for loads can be avoiced if the pcait temperature of the complete condensation of the lirnit for comp?cte condensation supp:ession pool is maintained befow 1607 during any penou of the reactor coolant, although condensation would occur for of relief va!ve operation with sonic conditions at the discharge j
temperatures above 1707.
exit. Specifcations have been placed on the envelope of reactor operating conditions so that the reactor can be depressurizett in a timely manner to avoid the regime of
(
potentia:!y high suppression chamber !oadig.
=
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, Amendment No. yI,71,1lil6, 181 t88
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JAFNPP i
THIS PAGE ISINTENTIONALLY BLANK 1
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Amendment No. K181 210 4
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