ML19208A987
| ML19208A987 | |
| Person / Time | |
|---|---|
| Site: | FitzPatrick  |
| Issue date: | 09/13/1979 |
| From: | Early P POWER AUTHORITY OF THE STATE OF NEW YORK (NEW YORK |
| To: | |
| Shared Package | |
| ML19208A985 | List: |
| References | |
| NUDOCS 7909180390 | |
| Download: ML19208A987 (40) | |
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ATTACHMENT I PROPOSED TEC!iNICAL SPECIFICATION CHANGES RELATED TO INSTRUMENTATION POWER AUTHORITY OF THE STATE OF NEW YORK JAMES A. FITZPATPICK NUCLEAR POWER PLANT DOCKET NO. 50-333 S61200 7909180 3 9 O
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JAFNPP surveillance tests, checks, calibrations, and exam- V. Electrically Disarmed Control Rod inations shall be performed within the specified ,
surveillance intervals. These intervals may be ad- To disarm a rod drive electrically, the four juste d + 25 percent. The interval as pertaining to amphenol type plug connectors are removed instrument and electric surveillance shall never from the drive insert and withdrawal solenoids exceed one operating cycle. In cases where the rendering the rod incapable of withdrawal.
elasped interval has exceeded 100 percent of the ,y This procedure is equivalent to valving out the specified interval, the next surveillance interval drive and is preferred. Electrical disarming shall commence at the end of the original specified does not eliminate position indication.
interval.
W. High Pressure Water Fire Protection System U. Thermal Paramet?rs The High Pressure Water Fire Protection System
- 1. Minimum critical power Latio (MCPR)-Ratio of consists of: a water source and pumps; and that power in a fuel assembly which is calcu- distribution system piping with associated post lated to cause some point in that fuel assembly indicator vavles (isolation valves). Such to experience boiling transition to the actual valves include the yard hydrant curb val es and assembly operating power as calculated by ap- the first valve ahead of the water flow alarm plication of the GEXL correlation (Reference device on each sprinkler or water spray subsystem.
X. Staggered Test Basis
- 2. Fraction of Limiting Power Density - The ratio of the linear heat generation rate (LHGR) ex- A Staggered Test Basis shall consist of:
isting at a given location to the design LHGR for that bundle type. Design LHGR's are 18.5 a. A test schedule for a systems, subsystems, KW/ft for 7x7 bundles and 13.4 KW/ft for 8x8 trains or other designeated components ob-and 8x8R bundles. tained by dividing the specified test in-terval into n equal subintervals.
- 3. Maximum Fraction of Limiting Power Density -
The Maximum Fraction of Limiting Power Density b. The testing of one system, subsystem, train (MFLPD) is the highest value existing in the or other designated component at the be-core of the Fraction of Limiting Power Density ginning of each subinterval.
(FLPD).
- 4. Transition Boiling - Transition boiling means the boiling region between nucleate and film boiling. Transition boiling is the region in os which both nucleate and film boiling occur in-
)g termittently with neither type being completely
- - stable.
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h1 Amendment No. IA, 34, 3A, 43, 6
steam line isolation valves, main steam closure group. The water level drain valves, recirc. sample valves instrumentation initiates protection for (Group 1), initiates the HPCI and RCIC the full spectrum of loss-of-coolant and trips the recirculation pumps. The accidents.
low-low-low reactor water level instru-mentation is set to trip when the water Venturis are provided in the main steam level is 18 in above the top of the lines as a means of measuring steam flow active fuel. This trip activates the and also limiting the loss of mass remainder of the ECCS subsystems, and inventory from the vessel during a steam starts the emergency diesel generators. line break accident. The primary These trip level settings were chosen to function of the instrumentation is to be high enough to prevent spuricos actu- detect a break in the main steam line, ation but low enough to initiate ECCS For the worst case accident, main steam operation and primary system isolation line break outside the drywell, a trip so that post-accident cooling can be ac- setting of 140 percent of rated steam complished and the guidelines of flow in conjunction with the flow 10CFR100 will not be exceeded. For limiters and main steam line valve large breaks up to the complete closure, limits the mass inventory loss circumferential break of a 24 in. such that fuel is not uncovered, fuel recirculation line and with the trip temperature peak at approximately setting given above, ECCS initiation and 1,0000 F and release of radioactivity to primary system isolation are initiated the envircns is below 10CFR100 guide-in time to meet the above criteria. lines. Reference Section 14.6.5 FSAR.
Reference paragraph 6.5.3.1 FSAR.
The high drywell pressure instru-mentation is a diverse signal for mal-functions to the water level instru-mentation and in addition to initiating ECCS, it causes isolation of Groups B and 3 isolation valves. For the breaks discussed above, this instrumentation will generally initiate CSCS operation before the low-low-low water level instrumentation; thus the results given
,% above are applicable here also. See
- Specification 3.7 for isolation valve DJ C
?O Amendment No. 33 56
3.2 BASES (cont'd) JAFNPP High radiation monitors in the main steam The trip settings of <300 percent of design line tunnel have been provided to detect flow for this high flow of 400 F above maximum gross fuel failure as in the control rod ambient for high temperature are such that drop accident. With the established sett- uncovering the core is prevented and fission ing of 3 times normal background, and main product release is within limits.
steam line isolation valve closure, fission product release is limited so that 10CFR100 The RCIC high flow and temperature instrumentation guidelines are not exceeded for this acci- are arranged the same as that for the HPCI. The dent. Reference Section 14.6.2 FSAR. trip setting of <300 percent for high flow and 400 F above maximum ambient for temperature are Pressure instrumentation is provided to based on the same criteria as the HPCI.
close the main steam isolation valves in the run mode ~ hen the main steam line pressure The reactor water cleanup system high flow tem-drops below 825 psig. The reactor pressure perature instrumentation are arranged similar vessel thermal transient due to an inadver- to that for the HPCI. The trip settings are tent opening of the turbine bypass valves such that uncovering the core is prevented and when not in the run mode is less severe fission product release is within limits, than the loss of feedwater analyzed in Section 14.5 of the FSAR, therefore, The instrumentation which initiates ECCS action closure of the main steam isolation valves is arranged in a dual bus system. As for other for thermal transient protection when not vital instrumentation arranged in this fashion, in the run mode is not required. the specification preserves the effectiveness of the systen even during periods when maintenance The HPCI high flow and temperature instru- or testing is being performed. An exception to mentation are provided to detect a break this is when logic functional testing is being in the HPCI steam piping. Tripping of performed.
this instrumentation results in actuation of HPCI isolation valves. Tripping logic The control rod block functions are provided to
.or the high flow is a 1 out of 2 logic. prevent excessive control rod withdrawal so that MCPR does not de-CO C
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(; Amendment No. 14, 37, 3$ 57 CJ
3.2 BASES (cont'd) the specification are adequate to assure duct. Each pair is considered a the above criteria are met. The separate system. The trip logic specification preserves the ef- consists of any upscale trip on a single fectiveness of the system during periods monitor or a downscale trip on both of maintenance, testing, or calibration, monitors in a pair to cause the desired and alsc inimizes the risk of action.
inadvertent operation; i.e, only one 5
instrument channel out of service. Trip settings of 2.7 x 10 cpm for the monito: s in the refueling area Two air ejector offgas monitors are ventilation exhaust ducts are based upon provided and when their trip point is initiating normal ventilation isolation reached, cause an isolation of the air and Standby Gas Treatment System opera-ejector offgas line. Isolation is tion so that most of the activity initiated when both instruments reach released during the refueling accident their high trip point or one has an up- is processed by the Standby Gas Treatment scale trip and the other a downscale system.
trip. There is a 15 min. delay efore the air ejector offgas isolation 'alve Flow integrators are used to record the is closed. This delay is accounted for integrated flow of liquid from the dry-by the 30 min. holdup time of the offgaa well sumps. The alarm unit in each before it is released to the stack, integrator is set to annunciate before Both instruments are required for trip the values specified in Speci-but the instruments are so designed that fication 3.6.D are exceeded.
any instrument failure gives a downscale trip. The trip settings of the For each parameter monitored, as listed in instruments are set so that the instant- Table 3.2-6, by comparing the reading of aneous stack release rate limit given in each channel to the reading on redundant or Environmental Technical Speci- related instrument channel a near continuous fication 2.3.B is not exceeded. surveillance of instrument performance is available. Any deviation in readings will Four radiation monitors are provided initiate any early recalibration thereby which initiate isolation of the reactor maintaining the quality of the instrument E
X building and operating of the Standby readings.
fj Gas Treatment System. The monitors are located as follows: two in the reactor
'E s. building ventilation exhaust duct and g;
g2 two in refuel floor ventilation exhaust Amendment No. 28 59
TABLE 3.2-1 INSTRUMENTATION THAT INITI ATES PRIMARY CONTAINMENT ISOLATION Minimum Number of Total Number of Instrument Operable Instrument Channels Channels Provided by Design Action per Trip System (1) Instrument Trip Level Setting for Both Trip Systems (2) 2 (6) Reac or Iow Water 2 12.5 Indicated 4 Inst. Channels A Le .1 Level (3) 1 Reactor liigh Pressure d 75 psig 2 Inst. Channels D (Shutdown Cooling Isolation) 2 Reactor Low-Low }
._. -38 in. 4 Inst. Channels A Water Level indicated level (4) 2 (6) liigh Drywell Pressure d 2.7 psig 4 Inst. Channels A 2 liigh Radiation Main S 3 x Normal Rated 4 Inst. Channels B Steam Line Tunnel Full Power Background 2 Low Pressure Main 1 825 psig (7) 4 Inst. Channels B Steam Line 2 Iligh Flow Main Steam 4 140% of Rated Steam 4 Inst. Channels B Line Flow 2 Main Stea Line Leak 400 F above max 4 Inst. Channels B Detection High ambient (O Temperature C.)
ha 3 Reactor Cleanup Sys- I 400 F above max 6 Inst. Channels C U tem Equipment Area ambient Q
V1 liigh Temperature 2 Low Condenser Vacuum D 8" lig. Vac (8) 4 Inst. Channels B closes MSIV's Amendment No. f, f 64
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TABLE 3.2-1 (Cont'd)
INSTRUMENTATION TilAT INITIATES PRIMARY CONTAINMENT ISOLATION NOTES FOR TABLE 3.2-1
- 1. Whenever Primary Containment integrity is required by Section 3.7, there shall be two co trable or tripped trip systems for each function.
- 2. From and after the time it is found that the first column cannot be met for one of the trip systems, that trip system shall be tripped or the appropriate action listed below shall be taken.
A. Initiate an orderly shutdown and have the reactor in cold shutdown condition in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
B. Initiate an orderly load reduction and have main steam lines isolated within eight hours.
C. Isolate Reactor Water Cleanup System.
D. Isolate shutdown cooling.
- 3. Instrument set point corresponds to 177 in. above top of active fuel.
- 4. Instrument set point corresponds to 126.5 in. above top of active fuel.
- 5. Two required for each steam line.
- 6. These signals also start SBGTS and initiate secondary containment isolation.
- 7. Only required in run mode (interlocked with Mode Switch).
- 8. Bypassed when reactor pressure is less than 1005 psig and turbine stop valves are closed.
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Amendment No.J 65 301M00
JAFNPP TABLE 3.2-2 INSTRUMENTATION THAT INITIATES OR CONTROLS THE CORE AND CONTAINMENT COOLING SYSTEMS Minimum No. Total of Operable Number of Instru-Instrument ment Channels Pro-Item Channels Per vided by Design for No. Trip System (1) Trip Function Trip Level Setting Both Trip Systems Remarks 1 2 Reactor Low-Low 2 -38 in. indicated 4 HPCI & RCIC Initiates IIPCI, RCIC &
Water Level level Inst. Channels SGTS.
2 2 Reactor Low-Low- 2 -146.5 in. indicated 4 Core Spray & RHR Initiates Core Spray, Low Water level level Instrument Channels LPCI, and Emergency Diesel Generators.
4 ADS Instrument Initiates ADS in conjunction Channels with confirmatory low level, High Drywell Pressure, 120 second time delay and LPCI or Core Spray pump discharge pressure interlock.
3 2 Reactor High Water d +58 in, indicated 2 Inst. Channels Trips HPCI and RCIC Level level CO Turbines.
4 C1 1 Reactor Low Level E +352 in. above j (inside shroud) vessel zero 2 Inst. Channels Prevents inadvertent operation of containment spray during accident
,j condition.
66 Amendment No. 19
JAFNPP TABLE 3.2-2 (Cont'd)
INSTRILMENTATION THAT INITIATES OR CONTROLS THE CORE AND CONTAINMENT COOLING SYSTEMS Minimum No. Total of Operable Number of Instru-Instrument ment Channels P'.o-Item Channels Per vided by Desig., for No. Trip System (1) Trip Function Trip Level Setting Both Trip Systems Remarks 5 2 Containment High l< P< 2.7 psig 4 Inst. Channels Prevents indavertent Pressure operation of contain-ment spray during accident condition.
6 1 Confirmatory Low 2 12.5 in. indicat- 2 Inst. Channels ADS Permissive.
Level ed level 7 2 High Drywell 6. 2.7 psig 4 HPCI Inst. Chan- Initiates Core Pressure nels Spray LPCI , HPCI
& SGTS.
4 RHR & Core Spray Initiates starting Inst. Channels of Diesel Generators 8 2 Reactor Low Pressure 2 450 psig 4 Inst. Channels Permissive for opening Core Spray and LPCI Adnission valves.
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g) Amendment No. 19 67 H
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JAFNPP TABLE 3.2-2 (Cont'd)
INSTRUMENTATION TIIAT INITIATES OR CONTROLS TifE CORE AND CONTAINMENT COOLING SYSTEMS Minimum No. Total of Operable Number of Instru-Instrument ment Channels Pro-Item Channels Per vided by Design for No. Trip System (1) Trip Function Trip Level Setting Both Trip Systems Remarks 1 Reactor Low Pressure 50f*Pf$75 psig 2 Inst. Channels In conjunction with 9 PCIS signal permits closure of R!!R (LPCI) injection valves.
10 11 2 liigh Drywell Pressure 26 2.7 psig 4 Inst. Channels Initiates ADS in conjunction with Low-Low-Low Reactor Water Level, 120 second time delay -l LPCI sr Core Spray pump ai_._..arge pressure interlock.
12 Core Spray Pump Initates starting of 1 1 Inst. Channel Start Timer 11 + 0.6 sec core spray pumps. (each (See Note 3) loop)
(each loop)
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(J Amendment No. 19 C3 68 (O
JAFNPP TABLE 3.2-2 (Cont'd)
INSTRUMENTATION TIIAT INITIATES OR CONTROLS THE CORE AND CONTAINMENT COOLING SYSTEMS Minimum No. Total of Operable Number of Instru-Instrument ment Channels Pro-Item Channels Per vided by Design for No. Trip System (1) Trip Function Trip Level Setting Both Trip Systems Remarks 13 1 RiiR Pump Start Timer (See Note 3) lst Pump (A Loop) 1.0 + 0.5 (-) O sec. 1 Inst. Channel Starts 1st Pump (A Loop) 1st Pump (B Loop) 1. 0 + 0. 5 (-) O sec. 1 Inst. Channel Starts 1st Pump (B Loop) 2nd Pump (A Loop) 6.0 + 0.5 sec. 1 Inst. Channel Starts 2nd Pump (A Incp) 2nd Pump (B Loop) 6.0 + 0.5 sec. 1 Inst. Channel Starts 2nd Pump (B Loop) 14 1 Auto Blowdown Timer 120 sec + 5 sec 2 Inst. Channels Initiates ADS, in conjunction with Low-Iow-Iow Reactor Water Level, High Drywell Pressure,
' and LPCI or Core Spray Pump discharge pressure interlock.
15 2 RilR (LPCI) Pump 125 psig + 20 psig 4 Inst. Channels Defers ADS actuation Discharge Pressure pending confirmation Interlock of low pressure core cooling system opera-tion.
g Amendment No, f, y/ 69 C
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JAFNPP TABLE 3.2-2 (Cont'd)
INSTRUMENTATION THAT INITIATES OR CONTROLS THE CORE AND CONTAINMENT COOLING SYSTEMS Minimum No. Total of Operable Number of Instru-Instrument ment Channels Pro-Item Channels Per vided by Design for No. Trip System (1) Trip Function Trip Level Setting Both Trip Systems Remarks 16 2 Core Spray Pump 100 psig + 10 psi 9 4 Inst. Channels Discharge Pressure Defers ADS actuation pending Interlock confirmation of low pressure core cooling system operation 17 1 RHR (LPCI) Trip 2 Inst. Channels Monitors availability Loss of Voltace' System bus power of power to logic monitor systems.
18 1 Core Spray Trip Loss of Voltage 2 Inst. Channels Monitors availability System bus power of power to logic monitor systems.
19 1 ADS Trip System Loss of Voltage *- 2 Inst. Channels Monitors availability bus power monitor of power to logic systems.
20 1 HPCI Trip System Loss of Voltage 2 Inst. Channels Monitors availability bus power monitor of power to logic systems. 6 21 1 RCIC Trip System Loss of Voltage 2 Inst. Channels Monitors availability bus power monitor of power to logic '
systems.
CO Ch Fa pg Amendment No. 7 70 ps FA
JAFNPP TABLE 3.2-2 (Cont'd)
INSTRUMENTATION TilAT INITIATES OR COh?ROLS TIIE CORE AND CONTAINMENT COOLING SYSTEMS Minimum No. Total of Operable Number of Instru-Instrument ment Channels Pro-Item Channels Per vided by Design for Trip System (1) Trip Function Trip Level Setting Both Trip Systems Remarks No.
22 23 24 1 Core Spray Sparger f 0.5 psid 2 Inst. Channels Alarm to detect core 25 to Reactor Pressure spray sparger pipe vessel d/p break.
26 2 Condensate storage 2 59.5 in, above tank 2 Inst. Channels Provides interlock to Tank Low Level bottom IIPCI suction valves.
(=15,600 gal avail)
Transfers llPCI pump 27 2 Suppression Chamber [ 6 in. above normal level 2 Inst. Channels suction to suppression Itigh Level chamber.
28 1 RCIC Turbine Steam f 282 in.11 20 psid 2 Inst. Channels Close Isolation Valves Line liigh Flow in RCIC Subsystem CC C)
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JAFNPP TABLE 3.2-2 (Cont'd)
INSTRUMENTATION THAT INITIATIONS OR CONTROLS THE CORE AND CONTAINMENT COOLING SYSTEMS Minimum No. Total of Operable Number of Instru-Instrument ment Channels Pro-Item Channels Per vided by Design for No. Trip System (1) Trip Function Trip Level Setting Both Trip Systems Remarks 29 1 RCIC Steam Line/ 6 40 F Above 2 Inst. Channels Close Isolation valves Area Temperature max, ambient in RCIC Subsystem 30 1 RCIC Steam Line 1007 P > 50 psig 2 Inst. Channels Close Isolation valves Low Pressure in RCIC Subsystem 31 1 IIPCI Turbine Steam f 230 in. H O psid 2 Inst. Channels Close Isolation Valves 2
Line High Flow in HPCI Subsystem 32 1 PCIC Turbine High d 10 psig 2 Inst. Channels Close Isolation Valves Exhaust Diaphragm Pressure in RCIC Subsystem 33 1 IIPCI Turbine Ifigh S 10 psig 2 Inst. Channels close Isolation valves Exhaust Diaphragm pressure in IIPCI Subsystem 34 1 LPCI Cross-Connect NA 1 Inst. Channels Initiates annunciation Position when valve is not closed 35 1 IIPCI steam Line 100> P> 50 psig 2 Inst. Channel Close Isolation Valve Low Pressure in llPCI Subsystem 36 1 IIPCI Steam Line/ I 40 F. 2 Inst. Channels Close Isolation Valve Area Temperature above max. ambient in HPCI Subsystem (O
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Amendment No. 14 ~;Ob
JAFNPP TABLE 3.2-2 (Cont'd)
INSTRUMENTATION THAT INITIATES OR CONTROLS THE CORE AND CONATINMENT COOLING SYSTEMS Minimum No. Total of Operable Nunber of Instru-Instrument
.3ent Channels Pro-Item Channels Per vided by Design for No. Trip System (1) Trip Function Trip Level Setting Both Trip Systents Remarks 37 38 39 Q per 4kV bus) 4kV Emergency Bus 85 + 4.25 secondary volts 2 Inst. Channels Initiates 4 KV Emergency Undervoltage Relay Bus Undervoltage Timer 40 (1 per 4kV bus ) 4kV Dmergency Bus 2.50 + 0.05 sec. 2 Inst. Channels Trip open all closed pump Undervoltage Timer motor breakers.
Initiates start of emergency diesel generators In conjunction with 90% EDG Voltage initiates Diesel breaker close permissive and trip normal reserve tie qm breaker fE Initiates sequential start-Li '
ing of vital load in con-hy junction with Low-Low-Low F+ reactor water level or high Jb drywell pressure.
2 Reactor Low Pressure 285 to 335 psig 4 Inst. Channels Permissive for c&osing re-circulation pump discharge valve.
Amendment No. 14 70c
Intentionally Left Blank (O
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s' 70d
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TABLE 3.2-2 (Cont'd)
INSTRUMENTATION THAT INITIATES OR CONTROLS THE CORE AND CONTAIN'1ENT COOLING SYSTEMS NOTES FOR TABLE 3.2-2
- 1. Whenever any ECCS subsystem is required by specification 3.5 to be operable, there shall be two operable trip sytems. From and after the time it is found that the first column cannot be met for one of the trip systems, that trip system shall be placed in the tripped condition or the reactor shall be placed in the cold condition within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
- 2. Instrument set point corresponds to 18 in, above the top of active fuel.
- 3. Refer to Technical Specification 3.5.A for limiting conditions for operation, failure of one (1) instrument channel disables one (1) pump.
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71
TABLE 3.2-6 SURVEILLANCE INSTRUMENTATION Minimum No.
of Operable No. of Channels Instrument Type Indication Provided Channels Instrument and Range by Design Action (Reactor Level Indicator)
( (Note 3) 0 - +60 )
2 ( ) 5 (1) (2)
(Reactor Level Recorder )
( (Note 4) 0 - +60 )
1 Reactor Level Indicator
-150 - +60 2 (2)
(Reactor Pressure Indicator )
( (Note 5) 0-1200 psig) 2 ( ) 5 (1) (2)
(Reactor Pressure Recorder )
( (Note 6) 0-1200 psig)
(Drywell Pressure (Narrow Range)
( (Narrow Range) Indicator )
( Recorder )
( 10 - 19 psia )
1 ( ) 2 (2)
(Drywell Pressure (Wide Range) )
( (Wide Range) Indicator )
( Recorder )
( 0 - 100 psia )
(Drywell Temperature Indicator )
( 50 - 2500 F )
2 ( ) 4 (1) (2)
(Drywell Temperature Recorder )
50 - 350 F )
- A M (Suppression Chamber Indicator )
h (Temperature 50 - 250 F )
) 4 (1) (2) d) 2 (
Recorder
}- a (Suppression Chamber )
- }. (Temperature 50 - 350 F )
Amendment No. 35 76
TABLE 3.2-6 SURVEILLANCE INSTRUMENTATION Minimum No.
of Operable No. of Channels Instrument Type Indication Provided Channels Instrument and 'lange by Design Action (Suppression Chamber Indicator )
(Water Level Recorder )
( (Wide Range) -72 to +72 inches) 1 ( ) 2 (2)
(Suppression Chamber Indicator )
(Water Level Recorder )
( (Narrow Range) -6 to +6 inches )
N/A Control Rod Indicator 1 (7)
Position Indication Postion 00 to 48 2 Source Range Indicator 4 (0)
Monitors Recorder 1 to 100 cps 3 Intermediate Indicator 8 (8) (9)
Range Monitor Recorder 10 ~4 to 40% Rated Power 2 Average Power Indicator 6 (8) (9)
Rnage Monitors Recorder 0-125% Rated Power 1 Drywell-Suppr- tion Recorder 2 (2)
Chamber Diffe atial O to 5 psi Pressure Computer 0 to 5 psi U NOTES FOR TABLE 3.2-6 O
- 1. From and after the date that the minimum number of operable instrument channels is one less than the 7
9, minimum number specified for each parameter, continued operation is permissible during the succeeding g 30 days unless the minimum number specified is made operable sooner.
- 2. In the event that all indications of this parameter is disabled and such indication cannot be restored in six (6) hours, an orderly shutdown shall be initiated and the reactor shall be in a Hot Shutdown condition in six (6) hours and a Cold Shutdown condition in the following eighteen (18) hours, n-ana nne un ,,_
NOTES FOR TABLE 3.2-6 (CONTINUED)
- 3. Three (3) indicators from level instrument channel A, B, & C. Channel A or B are utilized for feedwater control, reactor water high and low level alarms, recirculation pump runback. High level trip of main turbine and feedwater pump turbine utilizes channels A, B, & C.
- 4. One (1) recorder utilized the same level instrument channel as selected for feedwater control.
- 5. Three (3) indicators from reactor pressure instrument channel A, B, & C. Channel A or B are utilized for feedwater control and reactor pressure high alarm.
- 6. One (1) recorder. Utilizes the same reactor pressure instrument channel as selected for feedwater control.
- 7. The position of each of the 137 control rods is monitored by the Rod Position Information System. For control rods in which the position is unknown, refer to Paragraph 3.3.A.
- 8. Neutron monitoring operability requirements are specified by Table 3.1-1 and Paragraph 3.3.B.4.
- 9. A minimum of 3 IRM or 2 APRM channels respectively must be operable (or tripped) in each safety system.
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76b
JAFNPP TABLE 4.2-2 MINIMUM TEST AND CALIBRATION FREQUENCY FOR CORE AND CONTAINMENT COOLING SYSTEMS Instrument Channel Instrument Functional Test Calibration Frequency Instrument Check
- 1) Reactor Water Level (1) Once/3 months once/ day
- 2) Drywell Pressure (1) Once/3 months None
- 3) Reactor Pressure (1) Once/3 months None
- 4) Auto Sequencing Timers NA Once/ operating cycle None
- 6) Trip System Bus Power Monitors (1) N/A None
- 8) Core Spray Sparger d/p (1) Once/6 months Once/ day
- 10) Steam Line/ Area liigh Temp. (!!PCI & RCIC) (1) Once/ operating cycle Once/ day
- 13) HPCI Suction Source Levels (1) Once/3 months None
- 14) 4KV Emergency Power Under-Voltage Relays Once/ operating cycle Once/ operating cycle None and timers
C p 17) LPCI/ Cross Connect Valve Position Once/ operating cycle NA NA hk Note: See listing'of notes following Table 4.2-6 for the notes referred to herein.
fv O
Amendment No. p 79
JAFNPP TABLE 4.2-6 MINIMUM TEST AND CALIBRATION FREQUENCY FOR SURVEILLANCE INSTRUMENTATION INSTRUMENT CHANNEL CALIBRATION FREQUENCY INSTRUMENT CHECK 1.) Reactor Water Level Once/6 months Once Each Shift 2.) Reactor Pressure Once/6 months Once Each Shift 3.) Drywell Pressure Once/6 months Once Each Shift 4.) Drywall Temperature Once/6 months Once Each Shift 5.) Suppression Chamber Temperature once/6 months Once Each Shift 6.) Suppression Chamber Water Level Once/6 months Once Each Shift 7.) Control Rod Position Indication N/A Once Each Shift 8.) Neutron Monitoring (APRM) Five/ week Once Each Shift 9.) Neutron Monitoring (IRM and SRM) Note 10 Note 10 10.) Drywell-Suppression Chamber Differential Pressure Once/6 months Once Each Shift Amendment No. 3$ 84 (O
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NOTES FOR TABLES 4.2-1 THROUGH 4.2-6 JAFNPP
- 1. Initially once every month until acceptable failure rate 8. Uses same instrumentation as Main Steam data are available; thereafter, a request may be made to the Line High Radiation. See Table 4.1-2.
AEC to change the test frequency. The compliation of instrument failure rate data may include data obtained from 9. See Technical Specification 1.0.F.4, other boiling water reactors for which the same design Definitions, for meaning of term, instrument operate in an environment similar te that of " Instrument Check".
- 10. Calibration and instrument check surveillance
- 2. Functional tests, calibrations and instrument checxs are not for SRM and IRM Instruments are as spccified required when these instruments are not required to be in Table 4.1-1, 4.1-2, 4.2-3.
operable or the tripped. Functional tests shall be performed before each startup with a required frequency not to exceed once per week. Calibrations shall be performed prior to each startup or prior to preplanned shutdowns with a required frequency not to exceed once per week.
Instrument checks shall be performed at least once per day during these periods when the instruments are required to be operable.
- 3. This instrumentation is excepted from the functional test definition. The functional test will consist of injecting a simulated electrical signal into the measurement channel.
These instrument channels will be calibrated using sinulated electrical signals once every three months.
- 4. Simulated automatic actuation shall be performed once each operating cycle. Where possible, all logic system functional tests will be performed using tne test jacks.
- 5. Reactor low watr e level, high drywell pressure and high radiation main steam line tunnel are not included on Table 4.2-1 since they are tested on Table 4.1-2.
- 6. The logic system functional tests shall include a calibration or time delay relays and timers necessary for bk proper functioning of the trip systems.
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%3 7. At least one (1) Main Stack Dilution Fan is required to be
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pg in operation in order to isokineticaly samply the Main Stack.
Amendment No. 3$ 85
3.6 (cont'd) JAFNPP 4.6 (cont'd)
- 3. The pump in an idle reactor 3. Prior to starting the pump in recirculating loop shall not an idle recirculation loop, the be started unless the coolant temperature of the coolant in in that loop is within 500 F of that loop chall be compared to the reactor coolant temperature the temperature of the reactor in the reactor vessel. coolant in the reactor vessel.
- 4. Recirculation loop Temperature millivolt transmitter / recorder shall be checked daily and calibrated once/ operating cycle.
B. Pressurization Temperature B. Pressurization Temperature
- 1. The reactor vessel head bolting 1. when the reactor vessel head bolting studs shall not be under studs are tightened or loosened the tension unless the temperatures reactor vessel flange and head flange of the vessel flange and the temperature shall be recorded.
head flange are 900F.
- 2. Neutron flux monitors and samples
- 2. Pressurization temperature shall be installed in the reactor during hydrostatic testing vessel adjacent to the vessel wall shall be in accordance with at the core midplane level. The Figure 3.6-1. monitor and sample program shall, in the main, conform to 1972 Draft revision, ASTM E185. The monitor shall be installed during the 1978 refueling outage and shall be removed and tested d. iring the next subsequent refueling outage to experimentally verify the calculated values of integrated neutron flux that are used to determine RTNDT.
The capsule withdrawal schedule shall be in accordance with the following:
O Cs H
PO ki 44 137 Amendment No. Jd
JAFNPP 3.7 LIMITING CONDITIONS FOR OPERA- 4.7 SURVEILLANCE REQUIREMNTS TION 4.7 CONTAINMENT SYSTEMS 3.7 CONTAINMENT SYSTEMS Applicability:
Applicability:
Applies to the primary and secondary Applies to the operating status of the containment integrity.
primary and secondary containment systems. Objective:
Objective: To verify the integrity of the primary, and secondary containment systems.
To assure the integrity of the primary and secondary containment systems. Specification:
Specification: A. Primary Containment A. Primary Containment 1. The pressure suppression chamber water level and temperature
- 1. The volume and temperature of shall be checked once per day.
the water in the pressure The accessible interior surfaces suppression chamber shall at all of the drywell and above the times, except ac specified in water line of the pressure Specification 3.5.F.2 be suppression chamber shall be maintained within the following inspected at each refueling limits: outage for evidence of deterioration. Whenever there is
- a. Maximum vent submergence level indication of relief valve operation or .
of 53 inches. testing which adds heat to the suppression l pool, the pool temperature shall be
- b. Minimum vent submergence level continually monitored and also observed of 51.5 inches. and logged every 5 minutes until the The suppression chamber water level heat addition is terminated. Whenever may be ou; side the above limits for there is indication of relief valve
,, a maximum of four (4) hours during operation with the temperature of the
>T required operability testing of HPCI, suppression pool reaching 1600 F or more
[j, RCIC, RHR, CS, and the Suppression and the primary coolant system pressure pj Chamber - Drywell Vaccum System. greater than 200 psig, an external visual p; examination of the suppression chamber shall da c. Maximum water temperature be conducted before resuming power operation.
(1) During normal power operation maximum water temperature shall be 95F. 165 Amendaent No. 16,36
JAFNPP TARII 3.7-1 PROCESS PIPELINE PFNETRATING PRIMARY COVfA1WINT (Numbers in parentheses are keyed to numbers on following pages; signdl coces are Itated on following pages) row r Location Power Closing Drywell Valve Type to Open Ref. to to Open Isolation Time Normal Remarks and Line Teolated Penetration (6) (O (6) Croup DrYw ll ($)(6) $1tnel (7) Status Exceptions Main Steam Line X-7A,8,C,D 40 Clobe Air & ac,dc A Inside Air & Spring 5,C,D P E Note (1) Open Main Steam Lins X-7A,B,C,D AD Clobe Air & ac,dc A Outside Air & Spring B,C,D,P,E Note (1) Open Main Steam Llae Crain X-8 HD Cate Ac A Inside Ac B,C,0,P,E 15 see cloaed Main Steam Line Drain X-8 MD Cate De A Outside Dc B,C,D.P.E 15 see Closed
- Prom Reactor Peedwater X-9A,B Check - A Outside Process Rey, flow Not applicable Jpen From Reactor Peedwater X-9A,B Check - A Inside Process Rev. flow Not applicable Open Reactor Water Sample X-41 AO Clobe Air & ac A Inside Spring B,C,D,P,E Not applicable Open Reactor Water Saaple X-41 AO Clobe Air & ac A Outside Spring B,C,D,P,E Not applicable Open Control Rod Hydraulic X-36 Check - A Inside Process Rev. flow Not applicable)
Retu r- ) (
)
Control Rod Hydraulic X-36 Check - A Outside Process Rev. flow Not applica ble) Opena on Rod Return ) movement and
) closed at all Control Rod Drive X-38 SO Valves Air & ac A Outside Spring Note (4) Not applicable) other times Note (4)
Exhaust )
)
Control Rod Drive X-38 SO Valves Air & ac A Outside Spring Note (4) Not applicable)
Enhaust )
)
Control Rod Drive Inlet X-37 SO Valves Air & ac A Outside Spring Note (4) Not applicable)
)
Control mod Drive Inlet X-37 "O Valves Air & ac A Outside Spring Note (4) Not applicable) 198 i
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JAPNPP TAPLE 3,7-1 (Cont'd)
PROCESS PIPELINE PENTTRATING PRIMARY CONTAfittEVT (Numbers in parentheses are keyed to numbers on following pages t signal codes are listed on following pages)
Power location Power Closing Drywell Valve Type to Open Re f. to to Close Isola tion Time Norsun t Remarks and Line Isolated Penetration (6) (5)(6) Crou p Drywell (5)(6) Slanal (7) Status Excertions Mini-purge to I-31AC Check Process C Outside Process Rev. flow Not applicable Open '
rectre pump X-31BC Mint-purge to I-31AC Check Process C Inside Process Rev. flow Not applicable Open rectre pump X-318C RHR Reactor shut- X-12 MO Cate Dc A Outside Dc A,U,F RM 38 Sec closed down Cooling supply RRR Reactor Shut- X-12 MO Cate Ac A Insion Ac A,U,F,RM 38 Sec Ciraed down Cooling supply RHR to Suppression I-211A,B M) Globe Ac B Outside Ac C,S,RM 10 Se Closed Thrc.tling Tyya Valse Spray Header Note (2)
RHR - Containment 1-39A,B, MO Cate Ac 3 Outside Ac C,S,RM 10 Sec Closed Note (2)
Spray RHR - Containment X-39A,B, M0 Cate Ac B Outside Ac C,S,RM 10 Sec C l<,,e d Note (2, '
Spray i
RHR - Reactor Head X-17 MO Cate Ac A Inside Ac A,U,F,RM 20 Sec Closed Spray l RHR - Reactor Head I-17 M) Cata Dc A Outside Dc A,U.F.RM 20 Sec Closed Spray RHR to suppression K-210A B. M0 Globe Ac 5 Outside Ac C,RM 70 Sec Closed Throttling Type valve Pool Note (2)
RHR - LPCI to X-13A,B, MO Cate Ac A Outside Ac RM, 120 See closed Note (10)
Reactor RHR - LPCI to X-13A,8 M) Clobe Ac A Outside Ac RM, 90 Sec Open Throttling Type Valve Reactor Note (10) '
RHR - LPCI to X-13A,B, A0 Check - A Inside Process Ref. flow Not applicable Closed Testable check velve Reactor (3,16)
RHR pump suction X-225A,B, M) Ca t e Ac B Outside Ac RM Not applicable Ope n from suppreeston pool Amendment No. 4g 199 (O
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JA FNPP TABil 3.71 (Cont'd)
PR0rTSS PIPELINE PENTTFATIlt PRIMARY COPrrAIWTPrr (Numbers in parentheses are keyed to numbers on following pages: signal codes are listed on following pages)
Power 1ccatton Power Closing Drywell valve Type to Open Ref. to to Close Isolation Time Normal Remarks and Line teclared Pecerration (6) (5)(6) Croup Drywell (5)(6) Stanal (7) Status Exceptione Standby Liquid X-42 Check - A Outside Process Rev. flod Not applicable Closed Control Standby Liquid I-42 Check - A Inside Process Rev. flow Not opp 11 cable Closed Contas!
Reactor Water Clean-up from Reactor I-14 MO Cate Ac A Inside Ac A , J.RM 30 Sec Open Reactor Water Clean up from Reactor X-14 MO Cate Dc A Outside Dc A ,V , J, RM 30 Sec Open Reactor Water from X-14 MO Cate Dc A Outside Dc A ,V ,Y , J, RM 10 Sec Closed Reactor Warm-up Reactor Water X-9A Check - A Outside Process Rev. flow Not applicable Open Cleanup Return RCIC - Turbine I-10 Mo Cate Ac A Inside Ac K,RM 15 Sec Open) Opene on Sig B:
Steam Supply ) Line breat sig K
) overrides to RCIC - Turbine X-10 M0 Cate Dc A Outside Dc K,RM 15 Sec Open) close valves Steam Supply RCIC - Turbine I-212 Check Pwd flow B Outside Process Rev. flow - Closed l Exhaust RCIC - Minimum I-210A M) Clobe De B Outside De K,RM 5 Sec Closed Pump Flow RCIC - Pump I-9A M0 Cate De B Outside De RM Not applicahle Closed Discharge RER to Radweste K-225A M0 Cate Ac B Outside Ac A F.RM 24 Sec Closed RHR to Radweste I-225A M0 Cate Dc B Outside De A,R.kM 24 Sec Closed RCIC - Vacuum I-226 Check hrd Flow B Outside Process L e. flow - Closed Pump Discharge RCIC - Fug Suction X-224 M0 Cate Dc B Outside Dc RM Not applicable Closed RCIC - Pump Suction X-224 M0 Cate Dc 5 Outside Dc RM Not applicable Closed Amendment No. 4g 200 C
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JAFhTP TAflLE 3,7-1 (Cont 'd)
PROCESS PIPELINE PENETRATIE PRDMRY CONTAIP90.hi (Numbers in parentheses are keyed to numbers on following pagest signal codes are listed on followf ag pages)
Power location Power Closing Drywell Valve Type to Open Re f. to ta Close Isolation Time Normal Remarks and Line Isolated Penetration (6) (5)(6) Crou p Drvwell (5)(h) Stanal (7) Status Erceptione Core Spray Minimum X-210A,8 m Cate Ac B Outside Ac RM Not applicable Closed l Pump Flow Core Spray to I-16A,B, W Cate Ac A Outside Ac RM Reactor Not applicable Open Note (10)
Core Spray to X-16A,9 M Cate Ac A Outside Ac RM Reactor Not applicable Closed Note (10)
Core Spray to I-16A,9 AO Check (3) A Reactor Inside Note (3) Rev. flow Not applicable Closed Testable Check Velve Note (3,16)
Core Spray Test to X-210A,8 M0 Clobe Ac B Outside Ac G,RM 45 Sec Closed Suppreeston Pool Core Spray Pump K-227A,8 W Cate Ac Outside Suction B Ac RM Not applicable Open Drywell Equipment I-19 MO Plug Ac B Ac A,F,RM Inside 30 Sec Ope n Drain Sump Discharge Drywell Equipment I-19 A0 Plug Air /Ac B Outside Sprird Drain Sump Discharge A.F RM Not applicable Closed (17)
Drywell Floor Drain K-18 M0 Plug Ac B Inside Ac A,F,RM 30 Sec Open Sung Discharge Drywell Floor Drain X-18 A0 Plus Air /Ac B Outside Spring A,F,RM Not appilc able Open l
Sump Discharge Traveling Incore X-35A,B,C,D Explosive Dc A Probe Outside Dc RM Not applicable Open One valve on each line 9 Shear Traveling Incore K-35A,B,C,D SO Ball Ac A Outside Ac Not appitcable Open Probe A F.RM One valve on each line Note (14)
Traveling Incore X-35B Check Fwd Flow A Outside i Probe Purge Process Rev. flow Not applicable Closed HPCI - Turbine I-11 M0 Cate Ac A Inside Ac L,RM Steam Supply 20 Sec Open ) Signal "C" opene valve.
) Signal "L" overrides and HPCI - Turbine X-11 M0 Cate
) closes valve, Dc A Outside De L.RM 20 Sec Closed)
Steam Supply i
Amendment No. 49 201 I
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JAFNPP TAB 12 3.7-1 (Cont'd)
PROCESS PIPR1hT PFNTTRATINC PRIMARY COhTAlfMENT (Numbers in parentheses are keyed to numbers on following pages: eignal codes are listed on following pages)
Power kcation Power Closing Drywell Valve Type to Open Ref. to to Close Isolation Time Normal Remarks and Line Isolated Penetration (6) (M (6) Croup Drywell (5)(6) Stanal (7) Statue Exceptione N*CI - Turbine I-214 Check Fvd Flow B Outside Process Rev. flow Not applicable Open Closes on Rev. flow or Exhaust low exhaust pressure NFCI - Turbine I-214 Check rwd Flow B Outside Process Rev. flow Not applicable Open Exhaust HPCI Pump Suction I-226 MO Cate Dc 5 Outside Dc L.RM 60 Sec Closed HPCI - Puey X-93 70 Cate De B Outside Dc RM Not applicable Closed Discharge HFCI - Turbine 1-222 Stop Check fwd Ficw B Outside Process Rev. flow Not applicable Closed Exhaust Drain HPCI - Minimum I-2103 Check Pwd Flow B Outside Process Rev, flow Not appliceble Closed Pump Flow RPCI - Minimum I-2108 to Globe Dc B Outside Dc L , RPt 10 Sec Closed Pump Flow DRWE1.L AIMOSPHERIC COffrROL AND SERVICFS Service Air to I-21 Check Process C Inside Process Rev. flow Not applicable Cicsed Drywell Service Air to I-21 Eand Gate Hand C Outside Hand - Not applicable Closed Drywell Instrument Air to I-22 Check Process C Inside Process Rev. flow Not applicable Open Drywell Instrument Air to I-22 Hand Cate Hand C Outside Hand - Not applicable Open Drywell Breathing Air to I-61 Check Process C Inside Process Rev. flow Not applicable Closed Drywell Breathing Air to I-61 Hand Cate Hand C Outside Hand - Not applicable Closed Drywell Drywell Purge Inlet I-25,I-71 AO Butterfly Air /Ac B Outside Spring F,A,Z,RM 5 Sec Closed Drywell PurRe Inlet I-25.I-71 AO Butterfly Air /Ac B Outside Spring F .A ,2 , RM 5 Sec Closed Drywell Main 1-26A,8 AO Butterfly Air /Ac B Outside Spring F A,Z,RM 5 Sec Closed Exhavet Amendment No. 43 202 O
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ABIE 3,7-1 (Cont'd)
PROCFSS PIPEIINE PENETRATING PRIMARY COfffAI?t4F?tt (Numbers in parentheses are keyed to numbers on f ollowing pages eignal codes are listed on following pages)
Power loca t ion Power Closing Drywell Valva Type to Open Re f, to to Close Isolation Time Normal Remarks and Line Isolated Penetration (6) (5)(6) Croup Drywell (5)(6) Stanal (7) Status Exceptions Drywell Maan X-26A,5 AO Butterfly Air /Ac B Outside Spring F,A,Z,RM 5 Sec closed Exhaust Drywell Exhaust X-26A,B W Butterfly Ac B Outsida Ac F A,2,RM 5 Sec Closed Valve Bypass Suppression Chamber X-205 MO Butterfly Ac B Outside Ac F.A,2,RM 5 See Closed Exhaust Valve Bypass S=ppreselon Chamber X-220 MO Butterfly Air /Ac 5 Outside Spring F,A ,2 ,RM 5 See Closed Furge Inlet Suppression Chamber X-220 AO Butterfly Air /Ac 3 Outside Spring F,A ,Z , RM S See Closed Furge Inlet Suppreeston Chamber X-205 AO Butterfly Air /Ac B Outside Spring F A,Z,RM 5 Sec Closed Main Exhaust Suppression Chamber X-205 AO Butterfly Air /Ac B Outside Spring F,A,2,RM 5 Sec closed Main Exhaust Containment Atmo- X-26A,X-59 SO valve Dc B Outside Spring F,A,Z,RM Not applicable Open sphere Sampling Lines l
Containment Atmo- X-26A,X-59 SO valve Ac 3 Outside Spring F,A,Z,RM Not applicable Open i sphere Sas911ng Lines Suppression Chamber X-203A SO Valve Ac B Outside Spring F, A ,Z ,RM Not applicable Open Atmosphere Sampling Lines Suppression Chamber X-203A SO valve Dc B Outside Spring F,A ,Z ,RM Not applicable Open Atmosphere Sampling Lines Containment /Sup- I 203B SO Valve Ac B Outside Ac F,A,Z,RM Not applicable Ope n preeeton Chamber Atmosphere Sampling Return Containment /Sup- X-203B SO valve Dc B Outside Ac F,A,2,RM Not applicable Open preselon Chamber Atmosphere Sampling Return Amendment No. 43 203 e
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JAFhTP TABIE 3.7-1 (Cont'd)
Process PIPFLINE ITETRATIE PRINARY CONTAINNr (Numbers in parentheses are keyed to numbers on following pages eignal codes are listed on followir.g pages)
I Power locatton Power C1oeing l Remarks and Drywell Valve Type to Open Ref. to to Close leolation Time Normal Line Isolated Penetration (6) (5)(6) Croup Drywell (5)(6) stan 1 (7) Status Exceptions Vacuum Breaker Ra= I-202A A0 Butterfly Air /Dc B Outside Spring PM Not applicable Closed) Valve opena when actor Building to ) suppreeston chamber Suppreselon Chamber ) pressure is 0.5 poi
) below reactor building vacuum Breaker Re= X-2023 Vacuum Vacuum B Outside Sup- Suppression Rev. flow Not applicable Closed) pressure.
actor Building to Breaker preselon chamber )
Suppression Chamber Chamber Pres sure )
Reactor Building 1-23,I-24, check Fwd Flow C Outside Process Rev. flow Not applicable Open Closed Cooling X-63,X-67 Water In
- Reactor Building X-6 8,1-66, Hand Globe Hand C Outsids Hand - Not applicable Open closed Cooling X-64,1-6 2 Water Out m.
Emerrency Service I-24,K-23 Check Fwd Flow C Outside Process Rev. flow Not applicable Closed Water to Drywell I-63,K-67 Instrument Sensing I-30A Hand Globe Hand A Outside Hand - Not applicable Open Typical all Class A Steam Flow Instrument Lines
! Instrument Sensing 1 30A Flow Check Spring A Outside Process Excess Flow Not applicable Open Typical all Class A Steam Flow Instrument Lines Instrument Sensing X-50C Hand Globe Hand B Outelde Hand - Not applicable Open Typical all Class B Drywell Pressure Instrument Lines Torus Pressure X-218 AO Valve Air /Dc B Outside Sprin9 F,A,Z,RM Not appli- Open Sensing cable Torus Pressure X-218 AO Valve Air /DC B Outside Spring F,A,3,RM Not appli- Open Sensing cable Drywell X-45 A0 Valve Air /Dc B Outside Sprin9 F,A,2,RM Not appli- Open Pressure cable Sensing Drywell X-45 AO Valve Air /Dc B Outside Sprin9 F,A,Z,RM Not appli- Open Pressure cable Sensing Amendment No. 45 204 I eA
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INTENTIONALLY LEFT BLANK Amenc.nent No. 4g 205 36[202
JAFNPP NOTES FOR TABLE 3.7-1 ISOLATION SIGNAL CODES Signal Description A* Reactor vessel low water level - (A scram occurs at this level also. This is the higher of the two isolation low water level signals)
B* Reactor vessel low water level - (This is the lower of the two low water level signals. Main steam line isolation occurs at this level).
C* High radiation - main steam line D* Line break - main steam line (steam line high steam flow)
E* Line break - main steam line (steam line high temperature)
F* High drywell pressure G Reactor vessel low water level or high drywell pressure (Emergency Core Cooling Systems are started)
H J* Line break in Reactor Water Cleanup System - high space temperature K* Line break in RCIC System steam line to turbine (high $
steam line space temperature, high steam flow, low steam line pressure, or high turbine exhaust pressure)
L* Line break in HPCI System steam line to turbine (high steam line space temperature, high steam flow, low steam line pressure, or high turbine exhaust pressure)
M P* Low main steam line pressure at inlet to main turbine (RUN mode only)
S Low drywell pressure T Low reactor pressure permissive to open core spray and RHR-LPCI valves These are the isolation functions of the Primary Containment and Reactor Vessel Isolation Control System 3 other functions are given for information only.
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JAFNPP NOTES FOR TABLE 3.7.1 (CONT'D) 9.
- 10. Coincident signals "G" and "T" open valves. Special interlocks permit testing these valves by manual switch except when automatic signals are present.
- 11. Normal status position of valve (open or closed) is the position during normal power operation of the reactor (see " Normal Status" column).
- 12. The specified closure rates are as required for containment isolation only.
- 13. Minimum closing time is based on valve and line size.
- 14. Signal "A" or "F" causes automatic withdrawals of TIP probe. When probe is withdrawn, the valve automatically closes by mechanical action
- 15. Reactor building ventilati: , exhaust high radiation m signal "Z" is generated by two trip untis. This @
required one unit at high trip or both units at down scale (instrument failure) trip, in order to initiate isolation.
- 16. Leak testing shall be accomplished in accordance with section 4.7.A.2.d.
- 17. The valve opens during pump out of the drywell equipment sump.
Automatic isolation signals A and F override an open signal that might be present for sump pump out.
Amendment No. 40 4 of 4 q) > 3 -s MJ 14.Oe 4
JAFNPP 3.11 (cont'd) 4,11 (cont'd)
B. Crescent Area Ventilation B. C r e s c e ra t Area Ventilation Crescent area ventilation and Unit coolers serving ECCS cooling equipment shall be components will be checked operable on a continuous basis for operability during whenever specification 3.5.A, surveillance testing of the 3.5.B, and 3.S.C are required associated pumps as per to be satisfied. specification 4.5.A, 4.5.B, and 4.5.C.
- 1. From and after the date that more than one unit cooler 1. When it is determined that serving ECCS components in the two unit coolers serving same compartment are made or ECCS components in the same found to be inoperable, all compartment are made or found ECCS components in that com- inoperable, reactor operation partment shali be considered may continue for 7 days unless to be inoperable for purposes one is made operable earlier.
of specification 3.5.A, 3.5.C, and 3.5.D. 2. Temperature indicator controllers shall be C. Battery Room Ventilaticn calibrated once/ operating cycle.
Battery room ventilation shall be operable on a continuous basis 3. If 3.ll.B.1 cannot be met, whenever specification 3.9.E is the reactor shall be placed required to be satisfied, in a cold condition within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
- 1. From and after the date that one of the battery room ventil- C. Battery Room Ventilation ation systems is made or found to be inoperable, its associated Battery room ventilation equip-battery shall be considered to :.e n t shall be checked for be inoperable for purposes of operability once/ week.
specification 3.9.E.
- 1. When it is determined that one battery room ventilation (3 system is inoperable, the
(; remaining ventilation system FA shall be checked for operability D) and daily thereafter.
C.'
UI 2. Tempet-ture transmitters and differenwial pressure switches shall be calibrated once/
239 operating cycle.
9 ATTACHMENT II SUPPORTING INFORMATION FOR PROPOSED TECHNICAL SPECIFICATION CHANGES RELATED TO INSTRUMENTATION POWER AUTHORITY OF THE S'I ATE OF NEW YORK JAMES A. FITZPATRICK NUCLEAR POWER PLANT DOCKET NO. 50-333 31s1.h300
- 1. Page 6 Section 1.0.T Definitions This change is made in order to correct the interval for instrument and electrical surveillances. An operating cycle can extend beyond the 15-month as defined in Technical Specifications. An 18 month cycle is a very real possibility or operation at reduced power could extend this interval to longer periods of time.
- 2. Pages 56, 57 and 64 Table 3.2.1 Mainsteam Line Tunnel Exhaust Duct Temperature Main Steam Line Tunnel Exhaust Duct Temperature is not provided by plant design. High temperature in the vicinity of the main steam lines outside the primary containment is detected by 16 bimetallic temperature switches located along the main steam lines between the drywell and main turbine stop valves. These 16 switches are grouped into 4 isolation logic channels and are included in Table 3.2-1 under Main Steam Line Leak.
- 3. Page 64 Table 3.2-1 Reactor Cleanup System Hihh Temperature This change deletes the listing of the temperature switch (12TlS99) on the non-regenerative heat exchanger. Switca 12 tc isolate Reactor Water Clean-up (RWCU) from the primary containnant on high temperature. The intented purpose of this isolation is for filter deminerlizer resin protection, not primary containment isolation. This is also supported by the Standard Technical Specifications.
RWCU Equipment Area High Temperture isolation is provided by design as listed Table 3.2-1.
- 4. Page 65 Note 8 A MSIV NOT FULLY OPEN SCRAM cannot now be reset until reactor pressure is less than 600 PSIG, with mode switch not in run, since the reactor pressure switches and its associated relays also supply the bypass for the low condensor vacuum isolations. The proposed Technical Specifications Amendment would allow the scram to be bypassed up to 1005 PSIG. The setpoint for this bypass is required to be < 600 PSIG by the existing Technical Specifications.
Although the bypass circuitry involved is in different system (PCIS and RPS) the result of changing the PCIS setpoint allows the same isolation mode of operation with the required protection as RPS bypass setpoint. Changing the PCIS setpoint would allow resetting a scram after an isolation. This will prevent runout of the CRD pumps and cooling of the lower region of the reactor vessel below the limits allowed for a recirculation pump restart (ie upper - lower region differential temperature < 145 F) .
In addition, the proposed Technical Specifications amendment will allow an isolation to be reset quicker and thus allow return to normal at an earlier time and may reduce dependence on operator initiated safety relief valve open/close cycles to control reactor pressure.
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New pages 66 through 71 (old pages 66 through 70) Table 3.2-2 Items 2&B Remarks are consolidated and clarified.
Item 10. Reactor Low Pressure (> 900 PSIG) Vermont Yankee modification to the LPCI System, eliminates this instrumentation.
Item 12. Core Spray Pump Start Timer (11 + 0.6 sec)
Change updated, to be consistent with table format.
Item 13. RHR Pump Discharge Pressure interlock (1.0 + 0.5, -0 sec. &
6.0 + 0.5 sec.) Reorganized, to depict the Vermont Yankee modificaiton and update to be consistent with table format.
Item 14. Remarks are consolidated and clarified.
Items RHR (LPCI), Core Spray, ADS, HPCI and RCIC Trip System Bus 17-21. Power Monitor (loss of voltage). The intent of the monitors are to annunciate the loss of voltage (or power failure) to the lcgic power buses. The once/ operating cycle calibration frequency requirements of Table 4.2-2, would only be a duplication of the once/ month functional test requirement.
Items Recirculation Pump A d/p, Recirculation B d/p and Recirculation 22-24. Riser d/p A > B. Same as Item 10 above.
Item 31. HPCI Turbine Steam Line High Flow, HPCI has two trip channels and not one as inferred in previous note (3) of Table 3.2-2.
Items RCIC/HPCI Turbine High Exhaust Diaphragm Pressure replacing RCIC/HPCI 32-33. Turbine High Exhaust Pressure, which only trips che turbine.
Isolation initiation is from the c ;.aphram pressure switches.
Item 35. HPCI Steam Line Low Pressure Same as Item 31.
Item 36. HPCI Steam Line/ Area Temperature changed to update as designed trip channels and deletion of previous note (3) of Table 3.2-2 Same as Item 31.
Items 37-38. HPCI and RCIC Low Pump Suction Pressure only trips the turbine.
Vermont Yankee modification to the HPCI and RCIC systems eliminate these instrumentations.
Item 39. 4KV Emergency E2s Undervoltage Re]ry Changed to reflect installed equipmeat. Undervoltage relay initiates the undervoltage timer, which initiates the sequence of emergency power.
Item 40. Emergency Bus Undervoltage Timer Trip level setting is listed under 4KV Emergency Bus Under-voltage relay. Which should be entered under Time. Technical Specifications Amendment No. 2 revised this setting.
- 6. Page 71, Notes for Table 3.2-2
- < Existing notes (3) and (4) are not applicable to Table. New notes (3) reflect changes made in the Table (see items 35 & 36).
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- 7. Page 59 and Pages 76, 76a, 76b Table 3.2-6 and Pages 84, 85 Table 4.2-6 Surveillance Instrumentation
@ hanged, for clarification and to reflect plant surveillance instrumentation ranges that were incorrectly listed on original. This also ref&ects actual installation ccnditions.
- 8. Page 79 Table 4.2-2 Minimum Test and Calibration Frequency for Core and Containment Cooling Systems Changes made to reflect changes in Table 3.2-3. Also item 11 is included on Table 4.2-1 and is therefore deleted.
- 9. Page 84 Table 4.2-6 Minimum Test and Calibraton Frequency for Surveillance Instruments Units have no provisions for adjustments, only a functional check can be performed.
- 10. Page 137, Section 3.6.B.4 This function being performed by thermocouples not RTD's. Change reflects as built conditions.
- 11. Page 165 Section 3.7.A.1 Allow operability testings of systems while the suppression chamber water level remains outside the limiting condition of operations limits for limited duration.
- 12. Page 198 through 206 and 209 Table 3.7-1 Process Pipeline Penetrating Primary Containments This table is updated to reflect previously approved changes and for legibility purposes have been retyped.
- 13. Page 239 Section 4.ll.B.2 Installed unit cooler are without differential pressure switches therefore, has been removed from Technical Specifications.
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