ML19262C382
| ML19262C382 | |
| Person / Time | |
|---|---|
| Site: | FitzPatrick  |
| Issue date: | 01/23/1980 |
| From: | Ippolito T Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML19262C383 | List: |
| References | |
| NUDOCS 8002120094 | |
| Download: ML19262C382 (38) | |
Text
pa a' coq UNITED STATES hg 7g NUCLEAR REGULATORY COMMISSION W ASHlh f' TON, D. C. 20555 g
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POWER AUTHORITY OF THE STATE OF NEW YORK DOCKET NO. 50-333 JAMES A. FITZPATRICK NUCLEAR POWER PLANT AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 48 License No. DPR-59 The Nuclear Regulatory Commission (the Comission) has found that:
1.
The application for amendment by Power Authority of the State of A.
13, 1979, complies with the New York (the licensee) dated September standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; The facility will operate in conformity with the application, the B.
provisions of the Act, and the rules and regulations of the Commission; There is reasonable assurance (i) that the activities authorized C.
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 Comission's regulations; The issuance of this amendment will not be inimical to the common D.
defense and security or to the health and safety of the public; and The issuance of this amendment is in accordance with 10 CFR Part 51 E.
of the Commission's regulations and all applicable requirements have been satisfied.
Accordingly, the license is amended by changes to the Technical Specifi-2.
cations as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. DPR-59 is h.reby amended to read as follows:
(2) Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 48, are hereby incorporated in the license. The licensee shall operate the facility in-accordance with the Technical Specificaticns.
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. 3.
This license amendment is effective as of the date of its issuance.
FOR THE NUCLEAR REGULATORY COMMISSION CM 4t /5 Thomas
. Ippolito, Chief Operating Reactors Branch #3 Division of Operating Reactors
Attachment:
Changes to the Technical Specifications Date of Issuance:
January 23, 1980 1948 105
ATTACHMENT TO LICENSE AMENDMENT NO. 48 FACILITY OPERATING LICENSE NO. DPR-59 DOCKET N0. E0-333 Replace the following pages of the Appendix "A" Technical Specifications with the enclosed pages.
Remove Insert 6
6 56 56 57 57 59 59 64 64 65 65 66 66 67 67 68 68 69 69 70 70 70a 70b 70c 70d 71 71 76 76 76a 76a 76b 79 79 84 84 85 85 137 137 165 165 198 198 199 199 200 200 201 201 202 202 203 203 204 204 205 205 206 206 H
E9 E948 106
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 justed + 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 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 Parameters The High Pressure Water Fire Protection System 1.
Minimu" critical power ratio (MCPR)-Ratio of consists of: a water source and pumpas and that pt r 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 alves and assembly operating power as calculated by ap-
.the first valve ahead of the water fic. 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 A Staggered Test Basis shall consist of of the linear heat generation rate (LHGR) ex-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 ax8 trains or other designeated components ob-tained by dividing the specified test in-and 8x8R bundles.
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 43, boiling. Transition boiling is the region in C%)
which both nucleate and film boiling occur in-termittently with neither type being completely C) stable.
N Amendment No. 14, 3 34, 44, 48 6
steam line isolat.on valves, main steam closure group. The water level drain valves, recirc. sample valves instruzentation initiates protection for (Group 1), initiates the llPCI and RCIC the f c211 spectrum of loss-of-coolant and trips the recirculation pumps. The accidants, 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 spurious 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 isol 4 tion line break outside the drywell, a trip so that post-accident cooling can be ac-setting af 140 percent of rated steam complished and the guidelines of flow in conjunction with the flow 30CFRIGO 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 1,000 F and release of radioactivity to the environs is below 10CFR100 guide-primary system isolation are initiated 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
%4) instrumentation thus the results given WA" above are applicable here also.
See CXD Specification 3.7 for isolation valve CD CD Amendment No. 33, 48 56
3.2 BASES (cont'd)
~
High radiation monitors in the main steam The trip settings of <300 percent of design 0
line tunnel have been provided to detect flow for this high flow of 40 F above maximum gross fuel failure as in the control rod ambient for high temyerature 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 40 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 when the main steam line pressure The reactor water cleanup system high flow ten-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 16 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 wben 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 for the high flow is a 1 out of 2 logic.
prevent excessive control rod withdrawal so that MCPR does not de-
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Amendment No. 14, 37, 35,48 57
3.2 BASES (cont'd) duct.
Each pair is considered a the specification are adequate to assure 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 also minimizes the risk of action.
inadvertent operations i.e, only one 5
instrument channel out of service.
Trip settings of 2.7 x 10 cp, for the monitors in the refueling area ventilation exhaust ducts are based upon Two air ejector offgas monitors are 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 before the air ejector offgas isolation valve 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 offgan 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 r eading of aneous stack reletae 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
%g3 Four radiation monitors are provided initiate any early recalibration thereby
- 42. which initiate isolation of the reactor maintaining the quality of the instrument C)D. building and operating of the Standby readings.
Gas Trea ment System. The monitors are
-~~ located as follows: two in the reactor
-
- building ventilation exhaust duct and C3 two in refuel floor ventilation exhaust AmendmentNo.,28I48 59
T AB LE 3. 2-3 INSTRUMENTATION THAT INITI ATES PRIMAki' CONTAINMET ISOLATION Hinimum 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)
React'ar Low Water 2 12.5 Indicated 4 Inst. Channe?.s A
Level Level (3) 1 Reactor High Pressure d$ 75 psig 2 Inst. Channels D
(Shutdown Cooling Isolation) 2 Reactor Low-Low 21 -38 in.
4 Inst. Channels A
Water Level indicated level (4) 2 (6)
High Drywell Pressure j$ 2.7 psig 4 Inst. Channels A
2 High Radiation Main db 3 x Norwal Rated 4 Inst. Channels B
Steam Line Tunnel Full Power Background 2
Low Pressure Main 21 825 psig (7) 4 Inst. Channels B
Steam Line 4
140% of Rated Steam 4 Inst. Channels B
2 High Flow Main Steam Line Flow
< 40o F above max 4 Inst. Channels B
2 Main Steam Line Leak Detection High ambient Temperature 3
Reactor Cleanup Sys-lbb 400 F above max 6 Inst. Channels C
tem Equipment Area ambient High Temperature g).
4 CC 2
Low Condenser Vacuum 25 8" Hg. Vac (8) 4 Inst. Channels B
(([
closes MSIV's f), ]h, 48 64 Amendment No.
JATNPP TABLE 3.2-1 (Cont'd)
INSTRUMENTATION 'IHAT INITIATES PRIMARY CONTAINMENT ISOLATION HOTES FOR TABLE 3.2-1 1.
Whenever Primary Containment integrity is required by Section 3.7, there shall be two operable or tripped trip systems for each function.
2.
From and af ter 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. 48 65
JAFNPP TABLE 3. 2-2 INSTRUMENTATION THAT INITIATES OR CONTROLS THE CORE AND CONTAINMDrr 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 HPCI, RCIC &
Water Level level Inst. Channels SGTS.
2 2
Reactor Lcw-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.
i i
3 2
Reactor High Water I +58 in, indicated 2 Inst. Channels Trips HPCI and RCIC
]f Level level Turbines.
C3D 4
1 Reactor Low Level E +352 in. above 2 Inst. Channels Prevents inadvertent (inside shroud) vessel zero operation of containment L>4 spray during accident condition.
66 Amendment No.
, 48
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JAFNPP TABLE 3.2-2 (Cont'd)
INSThUMENTATION TilAT INITIATES OR CONTROLS Tile CORE AND CO?TTAINMENT COOLING SYSTEMS Hinimun 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
Rl!R Pump Start Timer (See Note 3)
Ist Pump (A Loop) 1.0 + 0.5 (-) O sec.
1 Inst. Channel Starts 1st Pump (A Loop)
Ist Pump (B Loop) 1.0 + 0.5 (-) O sec.
1 Inst. Channel Starts 1st Pump (B Ioop) 2nd Pump (A Ioop) 6.0 + 0.5 sec.
1 Inst. Channel Starts 2nd Pump (A Imop) 2nd Pun:p (B Loop) 6.0 + 0.5 sec.
1 Inst. Channel Starts 2nd Pump (B Isop) 14 1
Auto Blowdown Timer 120 sec + 5 sec 2 Inst. Channels Initiates ADS, in conjunction with Low-Low-Iow Reactor Water Level, High Drywell Pressure, and LPCI or Core Spray Ptump discharge pressure interlock.
Defers ADS actution 15 2
RHR (LPCI) Pump 125 psig + 20 psig 4 Inst. Channels Discharge Pressure pending ce,firmation Interlock of low pressure core cooling system opera-
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Amendment No. 48 70d
JAFNPP TABLE 3.2-2 (Cont'd)
INSTRUMENTATION THAT INITIATES OR CONTROLS THE CORE AND CONTAIm4ENT COOLING SYSTEMS NOTES FOR TABLE 3.2-2 1.
Whenever any ECCS subsystem is required b, specification 3.5 to be operable, there shall be two operable trip sytems. From and af ter the tiene 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.
Hefer 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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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 Hone
(1)
Once/3 months None Pressure Interlock
- 6) Trip System Bus Power Monitors (1)
N/A Hone
- 8) Core Spray Sparger d/p (1)
Once/6 months Once/ day
(1)
Once/3 months None
(1)
Once/ operating cycle Once/ day
Once/3 months None
- 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 45=
Once/3 months None CX?
High
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- 17) LPCI/ Cross Connect Valva Position Once/ operating cycle NA NA C7%
Note: See listing'of notes following Table 4.2-6 for the notes referred to herein.
Amendment No.
, 48 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.)
Drywell 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 4
CO
(($
Amendment No. 3$, 48 84
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 fata 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 to that of
" Instrument Check".
10.
Calibration and instrument check surveillance 2.
Functional tests, calibrations and instrument checks are not for SRM and IRM Instruments are as specified 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 usi.,g 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 the test jacks.
5.
Reactor low water level, high drywell pressure and high radiation main steam line tunnel are not included on s43' Table 4.2-1 since they are tested on Table 4.1-2.
4 C33 6.
The logic system functional testa shall include a calibration or time delay relays and timers necessary for
~-'
proper functioning of the trip systems.
N 7.
At least one (1) Main Stack Dilution Fan is required to be in operation in order to isokineticaly samply the Main Stack.
Amendment No. 3$, 48 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 0
in that loop is within 50 F of that loop shall 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 j
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 90 F.
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 during 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:
~~
4 CD-N
%O J/(48 137 Amendment No.
JAFNPP 3.7 LIMITING CONDITIONS FOR OPERA-4.7 SURVEILLANCE REQUIREMNTS TION 4.7 CONTAINMENT SYSTEMS 3.7 COtfrAINMENT 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.
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 as 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 in a.
Maximum vent submergence level indication of relief valve operation or of 53 inches.
testing which adds heat to the suppression 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 outside the above limits for there is indication of relief valve a maximum of four (4) hours during operation with the temperature of the sI) required operability testing of HPCI, suppression pool reaching 1600F or more 43' RCIC, RHR, CS, and the Suppression and the primary coolant system pressure C33 Chamber - Drywell Vaccum System.
greater than 200 psig, an external visual examination of the suppression chamber shall c.
Maximum water temperature be conducted before resuming power operation.
{ CD (1) During normal power operation maximum water temperature shall be 95F, 165 Amendment No. 16.36, 48
JAf BIFF T1812 3.7-1 FtnCE55 FIFFillE FTWTRATIIC FEDuaY CoorTAl*NFNT (habers in parentheses are teyed to cus.bers on followleg pagee; eignal codes are !!sted on following pages) Power 14catton Power Clostog Drywell valve Type to open Re f. to to Open Isolation Time normal Rasmarke and Line leolated Fecetretton (6) (1)(e) Croup Drrvell (5)(6) Sinnel (7) statue r ec ept ion e taale steam Line I-7&,B,C,D A0 Clobe Air & ac,de Inside Air & Spring 9,C,D,F,E leote (1) Open Itata Steam Line I-7&,B,C.D A0 Clebe Air & ac de A Outside Air & Spring 3,C,D,F,8 leote (1) Open besta Steam Lima Drata I-W to Cate Ac laatde As B,C,D,F,t 15 esc Closed testa steam Line Drain I-8 MD Cate Dc A Dut elde Dc 3,C,D,F,E 13 see Closed ' From Ramster Feedwater I-9A,3 Dieck A Outside Process Rev. flow teot applicable Open Free Reactor Feehter I-9A,8 Check A Inside Process Ba v. flow isnt applicable Open Reacter Water Seegle I-41 A0 Globe Air & ac Inalde Spring B.C.D,F.E thot applicable Open Asactor Water Sample I-41 A0 Globe Air & ac Outelde Spring 3,C,D,F E Not applicable Open A Inside Process Rev. flow blot applicable) Central Rod Ilydraulic I-36 Check Saturs ) ) Control and p draulic I-% Check A outside Frocese sa y, flow loot applicable) Opens on God y Retura ) movement and ) closed at all Centrol Bad Drive I-35 to Valves Air & as A Outelde Spring Hate (4) Isot applicable) other timme pote (4) Bahavet ) ) Control Rod Drive I-38 80 Valves Air & se Outside Spring peote (4) not applicable) Eshavet ) ) Centrol Rod Drive Inlet I-37 SO valves Air & ac A Outelde Spring Note (4) llot applicable) ) Control Rod prive Inlet I-37 50 Valves Air & ac Outelde Spring Note (4) Not applicable) 1 p 4' a -r> co u ) Amendment No. 48
JAFNFP TA Bt2 3.7 1 (Cont'd) ParrISS FIFTLINE FI$tTRATIMC PITNABT COWTAl*JWT (Embers to parenthesee are keyed to cu=Lere on foltoutng pages eignal codes are Plated ce folloutng pages) Power Locattos Power Cloetas l Drywell Valve Type to open Re f. t o to close Is ola t ion Time inormel neearbe end 1.tne Ieeleted Penetretten (6) 0)(6) Croup Drywell (S)(6) S izna l (7) statue t=<eptioce Niel-perge to I-llAC Checb Process C Outelde Process Rev. flow Mot applicable Opea rectes pump I-31BC Ittet-purge to I-31AC Ome c k Proc ess C Inside Process Rev. flow loot applicable Opes rectre pump I-38tC RM Reactor shut. E-12 to Cato Dc Outside Dc A,U, F.2M 38 Sec Closed doun Coottog supply Ras teacter shut. 1-12 IO Cate Ac Inside Ac A,U, F, Ept 38 Sec Closed down Cooltag supply RN3 to Suppreseloa I-211A,3 10 Clobe &c 3 Outside Ac C,5,RM 10 Sec Closed Throttling type Valve Spray Beeder Ste (2) RMB - Coatstement I-39A,3, MO Gate &c 5 Outside Ac C,8,EM 10 Sec Closed Note (2) Spray EM - Coateinment I-394,3, MO Cete Ac 9 Outelde Ac C.S,tM 10 Sec Closed Ih.te (2) Sprey EMR - Reactor need I-17 M0 Cate Ac laside Ac A,ti, F,tM 20 Sec Closed s Spray BM - Beacter Read I-IP MD Gate De A (ktelde Dc A.U,F 3M 20 Sec Closed sprey BM to Suppreselon I-210A,3, 900 Globe Ac 9 Outside Ac C.RM 70 8ec closed Throttltas Type Velve Pool tiote (2) EME - LPCI to I-13A,B, M0 Cete &c Outetdo Ac RM, 120 sec Closed IIote (10) Reacter E M - LFCI to I-13A,8 PO Clobe &c Outelde &c RM, 90 Sec Open Throttitas Type Velve teactor peote (10) RM - LPCI to I-13A,B, AD Check A Inside Process Ref. flow Not opplicable Closed Testable check velve Reactor (3,16) ERS pump esction I-225A,9, le Cate Ac 3 Outelde Ac EM Mot applicable Open from suppteeston Poel " Amendment No. ~ dp' 48 199 -Cm-00 '0 N ./ V (
JA FN7F <N.' ^ ' ' TABlJ ),71 (Coct'd) PgncfSS PIFELINE PENTTRATlut, FEDMAY COPfTAIMW (mmbers te parenthesee are beyed to nuet. ore on followt:5 pages t signal codee are listed on following pages) , mew 3>* Power Locatton Power Cloetna Drywell Talve Type to Open Ref. to to Close leoletion flee Moraal tamarks and Line feelsted Penetration (6) (5)(6) Gemy Dryvell (S)(6) Staul (7) statue t sc eet t cme Broadby Liquid I-42 Q eck A Outelde Process Bew. flow ht applicable Close d Control Steadby Ligeld I-42 Check A Inside Process Rev. flow Not applicable Cleas4 control l Beector Water Clean-up from Reacter 3 14 MO Gate &c A InstJe Ac A.J, tM 30 Sec Open teactor Water Clean up from Reactor I.14 MO Cate Dc Outetde Oc A,V,J,RM 30 Sec Open Beacter Water frem I.14 MO Cate Oc A tutelde De A V,Y,J,RM 10 Sec Closed teacter Werm-up teacter Water I-9A Check = A Outetde Process Rev. flow we applicable open Cleanup Retura E lc - Turbine I.10 M0 Cate Ac A Inside Ac E.RM 15 sec Open) Opene om Big ts Steam Supply ) Line break sig E ) overrides to K lc - Turbine 1 10 M0 Cate Dc Outelde De E,RM 15 Sec Open) close velvee Steam Supply E IC - Turblee I.212 Check Pwd flow B Outelde Process Rev. flow Cleead Enhavet KIC - Minimum I.210A 30 Globe Dc 3 Outside De E,tM 5 Sec Closed Pump Flow Elc - Pump E-9A 90 Cate Dc 3 Outside De RM Mot applicabl e Closed Discharge In to Radweete I.22%A MD Cate Ac 5 Outelde Ac A.P,pH 24 Sec Closed BMt to Radunste I.225A MD Ce t e Dc 3 Outside Dc A,t,tM 24 Sec Closed K IC - vacuum I.226 Check fwd Flow S Outelde Process Rav. flow Ciceed Pump Discharge EIC - Pump suction I 224 M0 Cete De 3 Outside De RM Mot applicable Closed g E!C - Pump Bectlee I.224 M0 Cate Dc B Outside De RM Not applicable Closed 6 Amendment No, dp, 4h 200 4.s b V oc U
JAFWF? I TASII ).1-1 (Cost'd) reor'133 plFTLIPE FINETRATlag PsDutt CowrAlrefirr (Numbers te paraathesse are keyed to nuet,ere ce followtag pages s signal codes are Itated se following pages) Powe r incation Power Closing Drywell Velve Type to Open ka f. t o to Close feeletten Time Moraal Ramerke and Line leoleted Penettetton (6) ($)(6) Croup Drywell (5)(6) 8tanel (7) sestue Racestione Core sprey Mteia m I-2104,3 to Cete Ac B Outside Ac RM hot applicable Closed P g Flow l Core Spray to I-16&,8, to Cete &c A Outalde Ac RM Not applicable Open Note (10) taector Core Spray to I-16A,9 PC Cate Ac Outside Ac EM Not appItceble Clee d Note (10) Reetter Core Spray to I-16A,9 AOtheck (3) A Ins ide le>te Q) Ray, flow Mot applicable closed Testable Chech Talve teactor Note (3,16) Core sprey Test to I-3104,8 MD clobe Ac a (ktside As c,aN 45 Sec Closed Suppreestem rool Core Spray rway I-227A,3 PC Cete &c 5 Outelde &c 30 Not applicable Open i Suction Drywell Equipment I-19 MO Flug Ac 5 Imaide &c A,F,uM 30 sec Open Drete Suey Discharge Drywell Equipment I-19 A0 Flug Air /Ac 3 Outelde Spring A,F,321 Mot applicable Closed (17) Drate Sump Discharge Drywell Floor Drate I-18 MD Plus Ac 5 Ima tda Ac A.F.RM 30 Sec Open Sump Discharge Drywell Floor Drete I-It A0 Flus Atr/Ac 5 Outelde Spring A,F.3M Not appIlc able Opee Sump Discharge Travelles lacere I-35A,9,C,D toploelve Oc Outelde Dc El Not appItceble Opee One velve os each lies Prete sheer Travoltog locore I-35A,0,C,D 30 Bell Ac Outetde &c A F,tp Not applicable Opee One velve on each line Probe hte (14) Traveling Encore I-335 CNck Pud Flow Outside Process Rav. flow Not applicable Closed Probe Furge EPCI. Turbine I-Il M0 Cete Ac A 1melde Ac L RM 20 Sec Opee ) Signal "C" opees velve. Stoes Supply ) signal "L" overrides eel ) closee velve. KFCI - Turbine I-Il DC Cate Dc Outside De L.EM 20 Sec Closed) Steas Supply N Amendment No. 49, @ 201 g i ao ,t, r ./o iG
JA FMPP TA B12 L 7-1 (Cont'd) Ptm235 P!rftINE FYWTRATINC Pr! MART Corrf AIPEAT (humbero la parentheses are beyed to numbers on folloutog pagee n eigt at codee are listed en follonting pages) Power lacet ton Power M ostr.g Drywell valve Type to Opee Raf to to Close Isolation T ime Normal Semarte and time fooleted Penetretton (e) (5)(6) Croup Drywe l l (S)(6) S t c.e l (7) Status t a c e pt i one RPCI - Turbine I-214 Check Pwd Flow 5 Outelde Process tav. flow Not applicable Open Closes os Rev. fleer er low exhaust pressure Enhavet EPCI Turbine I-214 Check Fwd Flow B Outside Process Rav. flow Not applicable Open tahaust EPCI Po p Section I-126 MO Cate De 3 Outside Dc L,uM 60 Sec Closed RFC1
- Pus, E-9 8 W Cate Dc B
Outelde De RM Hot applicable Closed Discharge RPCI - Turntae I-222 Stop Check rwd Flow B Outelde Process Rev. flow Not applicable Closed Eshavet Drata RFCI bttatamme I-2108 Check Pwd Flow 3 Outside Process tav. flow Not applicable Closed twe Flow EPCI - ptintas I-2105 m Globe De 3 Outside De I IUt 13 See Closed Pum, Plow DETWEti. ATMO6FtttilC Ongrrtal. AJr0 883VIGS service Als to I 21 Qeck Process C Imatde Process Rev. flow Not applicable Closed Duywell Hot applicable Closed Seritee Air to I-21 Esod Cate mand C Outelde Hand a Drywell featrument Air to 1-22 Check Process C Imelde Process Rev. flow Not applicable Opee Drywell lastrumeet Air to I-22 Hand Cate Hand C Outside Hand Not applicable Open Drywell Breathtag Air to I.el Oe ch Process C Inalde Proc es s Rav. flow Not applicable Cicea.d 3J) Drywell m Breathing Air to I-el Nead Onte Hand C Outelde Hand = Not applicable Closed Drywell Drywell Purge Inlet 1-25,I-71 AO Butterfly Air /Ac B Outelde Spring F.A,1,RM 5 Sec Closed ~,,Drywell Purge talet 1-25.I-71 AO tuttently Atr/Ac B Outside Spring F,A,Z, RM 5 Sec Closed Q Drywell Malm 1-26A,B AO butterfly Atr/Ac 3 Outside Spring F.A.Z,RM S sec closed .Enhavet j/ o, 48 202 m mr-a wW
JAF1tvf TA tt1 L 7-l (Cost'd) FtortSS PIPELINE FTNITRATIE ptthARY COff!AIMGWT (Numbers ta pereetheses are keyed to numbers os follwies pageet signal codes are listed oe following pages) Pouer tocattoe Power Closteg Drywell Valve Type to Open Est, to to Cloes Isolation Tlee Norum! Remarke and Line teoleted Penetretton (61 (5)(6) Grous Drywell (5)(6) Sf aul (F) Statue facestfene Drywell Mata I-26A,8 AO Sutterfly Air /Ac Outside Spring F.A.1.3M 5 See closed Bahamet Drywell Bahaust I-26A,9 N) Dutterfly Ac 3 Outside &c F,1,2,tM 5 Ses closed valve Sypase Seppreesten Chamber 1-205 MO Sutterfly Ac 5 (kit eide Ac F,A,1,tM 5 Sec Closed Eshseet Valve Sypese Suppreestem Chae6er 1-220 MO Sutterfly atr/Ac 3 Outside Sprias F A,1,SM S Sec Closed Purge talet Suppreeston Chamber I-220 AO Betterfly Atr/Ac 3 Outside Spring F,4,I tM 5 Sec Closed Purge telet Suppreestas Chamber I-205 AD Sutterfly Air /Ac 3 Outetda Spring F,4,1 RM 5 Bec Closed Mata Enheest Swppraestae Chamber I-205 AO Sutterfly Air /Ac 3 Outside Sprtag f,4,2.tM S Sec closed lenta Ealmust Comestammet Atmea I-2&A E-59 SO Valve De 3 Oist e lde Spring F A Z,IM Hot applicable Open ephere Sampling Liese Contatement Atmo. I 264,I-59 80 valve &c 3 Outelde Syf t.g F,A,1,tM Not applicable Open sphere Seapitag Lines Suppresoton Chamber I-203A SO valve Ac 5 (bteide Spring F, A,Z,RM Not applicable Opes Atmoephere Sampling Lines Suppreselos Chamber I-203A SO valve Dc 8 Outside Spring F A,1,EM Not applicable Opea j atmosphere Seapling Lines Coetstemest/s p-E-2038 SO valve As s Outelde Ac F.A,1,EM Not applicable Opes d prosatos Cheeber Asseephere Sampling Reture Cente trument /Sup-1-2038 SO Valve Dc 3 Outside Ac F,A,Z,IM Not applicable Open preesten c amber Atmosphere Sampling Reture ~. Amendment No. 49, 48 203 9 cf' 4 CC o Ch
JA FFFF TA312 3 J-] (Cont'd) FE0CI58 71Ft114 FTPFTRAfinc PsDentY coorTAlwNT (hmbers is parenthesee are keyed to numbers on fellowt s pagee s signe t codee are listed os followtas pages) t Power Lacetton Power Closing Drywell Velve Type to Open se f. t o to Cleee teoletton Time Normal Remarke and I Llae feelsted renetrettom (6) (s)(6) crovo orywell (s)(6) sinnet (7) statue recentle. I focu m treaker Es. E-202A A0 Butterfly Air /DC 3 Out elde Sprieg EM Nt applicable Cleaed) Velve opese utee ) suppresetoo chsaber actor Sullding to ) presease to 0.5 pet suppreselon Chs.ber ) below reacter butidtag vacu m treekst te. I-2023 Tacous Vacuum 3 Outside Sup. Supp re es t on Rev. flow Hot applicable Closed) pressure. ester Building to Broeker preeston chamber ) Chambe r Pressure ) Seypreeston Cheeber teactor Bulldtag I-23,I-34 Check Pwd riow C Out side Procase Rev. flow h t appitceble Open Closed Coolina 3-63.5-47 Water In Not applicable Opes f Seester Butidtag I-68,I-64, need Globe Head C Outende Hand I Cleoed Cooling I-b4,5-4 2 Water Out A Emergency Service I-24,I-23 Check Pwd Flow C Outside Proc ess Rev flow Not app!! cable Closed Wates to Drywell I-63,I-47 Not spylicable opes Tyytcal all Clase & lastrunnet seestas I-30h sand Glebe mand Cutside pend Instruenot Lines Steen Flame Emetrument seostes I-304 Flame Check Spring OutetJe Prot.e as Iscess Ficw Not applicable Opee Tyytcal all Claes & Instrument Linee Steam Ficer ht appitceble Opes Typical all Close a last ruent Seastas I-50C Reed Clobe Brad 5 Outelde hand Instrument Lloes Drywell Freesere Torus Pressure I-210 Ao Velve Air /Dc B Outside Spring F.A.E.RM Not appl 1-Open 8 Sensin9 cable e Freneure I-210 AO Velve Afr/Dc 8 Outside Sprin9 F,A,I RM Not a 11-Open Drywell I-45 AO Velve Alr/Dc B Outside Spring F A,3,RM Not oppil-Open d F r es sure cable e) ) sensing Drywell I-45 AO Velve Air /Dc 3 Outside Sprin9 F A,3,RM Not appl 1-Open Pressure cable Sensing . Aseendment No. 45, 48 204 4 4 l Q N
O 9 8 e INTENTIONALLY LEFT BLANK {9kb Amendment No. 49, 48 205
p 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 pressu 2 (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 d e only) S Iow drywell pressure T Iow 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. 1948 139 Amendment No. 48 l'of 4
a JAFNPP NOTES FOR TABLE 3.7.1 (CONT'D) 9. 10. Coincident signals "G" and "T" open vals42. 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 ventilation exhaust high radiation en signal "Z" is generated by two trip untis. This 2 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. 44, 48 4 of 4 1948 140
JAFNPP 3.11 (cont'd) 4,11 (cont'd) B. Crescent Area Ventilation B, Crescent _A_r e a 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 3.5.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 detert ied 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 shall 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 Room Ventilation calibrated once/ operating C. Battery __ 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 hours. 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 ment 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 O. system is inoperable, the 4g remaining ventilation system CD shall be checked for operability and daily thereafter. Jb-2. Temperature transmitters and ~~* differential pressure switches Amendment No. 48 shall be calibrated once/ 239 operating cycle.}}