ML20134C985

Amend 233 to License DPR-59,extending Instrumentation Surveillance Test Intervals to Support 24 Month Operating Cycles & Eliminating mid-cycle Outages to Perform TS Surveillance Requirements

ML20134C985
Person / Time
Site:	FitzPatrick
Issue date:	10/02/1996
From:	Bajwa S NRC (Affiliation Not Assigned)
To:
Shared Package
ML20134C988	List: ML20134C985 ML20134C989
References
NUDOCS 9610110231
Download: ML20134C985 (46)

Text

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4 UNITED STATES g

j NUCLEAR REGULATORY COMMISSION o

f WASHINGTON. D.C. 20666.0001 49.....,o POWER AUTHORITY OF THE STATE OF NEW YORK 1

DOCKET N0. 50-333 JAMES A. FITZPATRICK NUCLEAR POWER PLANT AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.233 License No. DPR-59 1.

The Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment by Power Authority of the State of New York (the licensee) dated January 25, 1996, complies with the 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; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized

)

by this amendment can be conducted without endangering the health and i

safety of the public, and (ii) that such activities will be conducted j

in compliance with the Commission's regulations; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and i

E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. DPR-59 is hereby amended to read as follows:

9 9610110231 961002 PDR ADOCK 05000333 P

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(2) Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No.233, are hereby incorporated in the license.

The licensee shall operate the facility in accordance with 4

the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance to be implemented within 30 days.

FOR THE NUCLEAR REGULATORY COMMISSION (b f f

,s' S. Singh Bajwa, Acting Director Project Directorate I-1 Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of. Issuance: October 2, 1996 n

J ATTACHMENT TO LICENSE AMENDMENT N0.233 i

j FACILITY OPERATING LICENSE N0. DPR-59

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DOCKET NO. 50-333 1

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Revise Appendix A as follows:

l Remove Paaes Insert Paaes 1'

5 5

i 30g 30g 37 37 38 38 46 46 47 47 49 49 60 60 60a 60a 70 70 77f 77f 779 779 77h 77h 771 771 77j 77j 77k 77k 771 771 77m 77m 77n 77n 770 770 80 80 i

82 82 83 83 84 84 84a 84a 86 86 86a 86a 112 112 113 113 115 115 121 121 132 132 133 183

!,95 185

??Xc 222c i20 226 238 238 239 239

l JAFNPP 1.0 (cont d) opened to perform necessary operational activities.

deficiency subject to regulatory review.

2.

At least one door in each airlock is closed and S.

Secondary Containment Inteority - Secondary containment sealed.

integrity means that the reactor building is intact and the following conditions are met:

3.

All automatic containment isolation valves are i

l operable or de-activated in the isdated position.

1.

At least one door in each access opening is closed.

4.

All blird flanges and manways are closed.

2.

The Standby Gas Treatment System is operable.

l l

N.

Rated Power - Rated power refers to operation at a reactor 3.

All automatic ventilation system isolation valves are power of 2,436 MWt. This is also termed 100 percent operable or secured in the isolated position.

power and is the maxinium power level authorized by the l

operating license. Rated steam flow, rated coolant flow, T.

Surveillance Freauency Notations / Intervals rated nuclear system pressure, refer to the values of these parameters when the reactor is at rated power.

The surveillance frequency notations / intervals used in these specifications are defined as follows:

O.

Reactor Power Onoration - Reactor power operation is any operation with the Mode Switch in the Startup/ Hot Notations Intervals Freauency Standby or Run position with the reactor critical and above 1 percent rated thermal power.

D Daily At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> W

Weekly At least once per 7 days P.

Reactor Vessel Pressure - Unless otherwise indicated, M

Monthly At least once per 31 days i

reactor vessel pressures listed in the Technical O

Quarterly or At least once per 92 days i

Specifications are those measured by the reactor vessel every 3 months i

steam space sensor.

SA Semiannually or At least once per 184 days every 6 months l

O.

Refuehne Outage - Refueling outage is the period of time A

Annually or Yearly At least once per 366 days between the shutdown of the unit prior to refueling and 18M 18 Months At least once per 18 months (550 the startup of the Plant subsequent to that refueling.

days) i R

Operating Cycle At least once per 24 months (731 R.

Safety Limits - The safety limits are limits within which days) the reasonable maintenance of the fuel cladding integrity S/U Prior to each reactor startup r

and the reactor coolant system integrity are assured.

NA Not applicable Violation of such a limit is cause for unit shutdown and i

review by the Nuclear Regulatory Commission before i

resumption of unit operation. Operation beyond such a i

limit may not in itself result in serious consequences but it i

indicates an operational Amendment No. *i, 131,188, 227, 233 5

l

JAFNPP 3.1 LIMITING CONDITIONS FOR OPERATION 4.1 SURVEILLANCE REQUIREMENTS 3.1 REACTOR PROTECTION SYSTEM 4.1 REACTOR PROTECTION SYSTEM Anchcabihtv:

Anolicability:

Applies to the instrumentation and associated devices which Applies to the surveillance of the instrumentation and associated

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initiate the reactor scram.

devices which initiate reactor scram.

Obiective:

Obiective:

r To assure the operability of the Reactor Protection System.

To specify the type of frequency of surveillance to be applied to the protection Instrumentation.

j Snecification:

Soecification:

A. The setpoints and minimum number of instrument A.

Instrumentation systems shall be functiona!!y tested and channels per trip system that must be operable for each calibrated as indicated in Tables 4.1-1 and 4.1-2 respectively.

position of the reactor mode switch, shall be as shown in Table 3.1-1.

The response time of the reactor protection system trip functions listed below shall be demonstrated to be within its limit once per 24 months. Neutron detectors are exempt l

from response time testing. Each test shall include at least i

one channel in each trip system. All channels in both trip j

systems shall be tested within two test intervals.

t

1. Reactor High Pressure (02-3PT-55A, B, C, D)

2. Drywell High Pressure (05PT-12A, B, C, D) i

3. Reactor Water Level-Low (L3) (02-3LT-101 A, B, C, D)

4. Main Steam Line isolation Valve Closure (29PNS-80A2, B2, C2, D2) i (29PNS-86A2, B2, C2, D2) l

5. Turbine Stop Valve Closure (94PNS-101,102,103,104)

I

6. Turbine Control Valve Fast Closure (94PS-200A, B, C, D)

7. APRM Fixed High Neutron Flux

8. APRM Flow Referenced Neutron Flux k

Amendment No. 337, 233 309 i

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JAFNPP 4.1 BASES (cont'd)

For the APRM System, drift of electronic apparatus is not The measurement of response time provides assurance the only consideration in determining a cC6 ration that the Reactor Protection System trip functions are frequency. Change in power distribution ar,d loss of completed within the time limits assumed in the transient chamber sensitivity dictates a calibration every 7 days.

and accident analyses.

Calibration on this frequency assures plant operation at or below thermal limits.

In terms of the transient analysis, the Standard Technical Specifications (NUREG-0123, Rev.3) define individual trip The frequency of calibration of the APRM flow biasing function response time as "the time interval from when the network has been established as once per 24 months. The monitored parameter exceeds its trip setpoint at the flow biasing network is functionally tested at least once channel sensor until de-energization of the scram pilot every three months and, in addition, cross calibration valve solenoids." The individual sensor response time checks of the flow input to the flow biasing network can defined as " operating time" in General Electric (GE) design be made during the functional test by direct meter reading.

specification data sheet 22A3083AJ, note (8), is "the There are several instruments which must be calibrated and maximum allowable time from when the variable being it will take several days to perform the calibration of the measured just exceeds the trip setpoint to opening of the entire network. While the calibration is being performed, a trip channel sensor contact during a transient." A transient zero flow signal will be sent to half of the APRM's resulting is defined in note (4) of the same data sheet as "the in a half scram and rod block condition. Thus, if the maximum expected rate of change of the variable for the calibration were performed during operation, flux shaping accident or the abnormal operating condition which is would not be possible. Based on plant specific evaluation postulated in the safety analysis report.

of drift over a 24 month operating cycle, it was determined that drift of instrumentation used in the flow biasing network is not significant. Therefore, to avoid spurious scrams, a calibration frequency of once per 24 months is established.

Amendment No. 337,233 37

i JAFNPP 4.1 BASES (cont'd) i The individual sensor response time may be measured by B. The MFLPD is checked once per day to determine if the

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simulating a step change of the particular parameter. This APRM scram requires adjustment. Only a small number of method provides a conservative value for the sensor control rods arc moved daily and thus the MFLPD is not response time, and confirms that the instrument has retained expected to change significantly and thus a daily check of its specified electromechanical characteristics. When sensor the MFLPD is adequate.

response time is measured independently, it is necessary to also measure the remaining portion of the response time in The sensitivity of LPRM detectors decreases with exposure l

the logic train up to the time at which the scram pilot valve to risutton flux at a slow and approximately constant rate.

solenoids de-energize. The channel response time must This is compensated for in the APRM system by calibrating include all component delays in the response chain to the twice a week using heat balance data and by calibrating ATTS output relay plus the design allowance for RPS logic individual LPRM's every 1000 effective full power hours, system response time. A response time for the RPS logic using TIP traverse data.

relays in excess of the design allowance is acceptable provided the overall response time does not exceed the response time limits specified in the UFSAR. The basis for excluding the neutron detectors from response time testing is provided by NRC Regulatory Guide 1.118, Revision 2, section C.5.

I i

Two instrument channels in Table 4.1-1 have not been included in Table 4.1-2. These are: mode switch in shutdown and manual scram. All of the devices or sensors associated with these scram functions are simple on-off switches and, hence, calibration during operation is not l

applicable.

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i Amendment No. ii, 89, 134,183, 227, 233 l

38 t

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l JAFNPP j

TABLE 4.1-2 REACTOR PROTECTION SYSTEM (SCRAM) INSTRUMENT CAllBRATION MINIMUM CALIBRATION FREQUENCIES FOR REACTOR PROTECTION INSTRUMENT CHANNELS t

Instrument Channel Group (1)

Calibration Freauency (2)

IRM High Flux C

Comparison to APRM on W

Controlled Shutdowns i

APRM High Flux Output Signal B

Heat Balance D

Flow Bias Signal B

Intemal Power and Flow Test R

with Standard Pressure Source LPRM Signal B

TIP System Traverse Every 1000 effective full power hours 1

High Reactor Pressure B

Standard Pressure Source (Note 6)

L High Drywell Pressure B

Standard Pressure Source (Note 6)

Reactor Low Water Level B

Standard Pressure Source (Note 6) f High Water Level in Scram A

Water Column (Note 5)

R (Note 5)

Discharge Instrument Volume a

i 3

High Water Levelin Scram B

Standard Pressure Source Q

Discharge instrument Volume Main Steam Line isolation A

(Note 4)

(Note 4) r y

Valve Closure

~

i il Turbine First Stage Pressure B

Standard Pressure Source (Note 6) l Permissive 5!

i Amendment No. 12,13, S2, 75, 80,136,183, 207, 233 l

46

JAFNPP

+

TABLE 4.1-2 (Cont'd)

REACTOR PROTECTION SYSTEM (SCRAM) INSTRUMENT CAllBRATION MINIMUM CALIBRATION FREQUENCIES FOR REACTOR PROTECTION INSTRUMENT CHANNELS Inshoment Channe:

Group (1)

Calibration Freauency (2)

Turbine Control Valve Fast A

Standard Pressure Source R

Closure Oil Pressure Trip Turbine Stop Valve Closure A

(Note 4)

(Note 4)

NOTES FOR TABLE 4.1-2 1.

A description of three groups is included in the Bases of this Specification.

2.

Calibration test is not required on the part of the system that is not required to be operable, or is tripped, but is required prior to return to service.

3.

Deleted i

4.

Actuation of these switches by normal means will be performed once per 24 months.

l S.

Calibration shall be performed utilizing a water column or similar device to provide assurance that damage to a float or other portions of f

the float assembly will be detected.

6.

Sensor calibration once per 24 months. Master / slave trip unit calibration once per 6 months.

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t i

Amendment No. 13, S2, 39,136,183, 207, 233 l

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J/JNPP i

3.2 LIMITING CONDITIONS FOR OPERATION 4.2 SURVEILLANCE REQUIREMENTS l

3.2 INSTRUMENTATION 4.2 INSTRUMENTATION l

t Anolicability:

Anolicability.

I Applies to the plant instrumentation which either (1) initiates and Applies to the surveillance requirement of the instrumentation controls a protective function, or (2) provides information to aid which either (1) initiates and controls protective function, or (2) i the operator in monitoring and assessing plant status during provides information to aid the operator in monitoring and i

normal and accident conditions.

assessing plant status during normal and accident conditions.

Obiective:

Obiective:

To assure the operability of the aforementioned instrumentation.

To specify the type and frequency of surveillance to be applied to the aforementioned instrumentation.

r Specifications:

Specifications:

A. Pnmary Containment isolation Functions A. Primary Containment isolation Functions When primary containment integrity is required, the limiting Instrumentation shall be functionally tested and calibrated as conditions of operation for the instrumentation that initiates indicated in Table 4.2-1. System logic shall be functionally primary containment isolation are given in Table 3.2-1.

tested as indicated in Table 4.2-1.

The response time of the main steam isolation valve actuation instrumentation isolation trip functions listed below shall be demonstrated to be within their limits once per 24 months.

Each test shall include at least one channel in each trip i

system. All channels in both trip systems shall be tested within two test intervals.

1. MSIV Closure - Reactor Low Water Level (L1)

(02-3LT-57A,B and 02-3LT-58A,B)

2. MSIV Closure - Low Steam Line Pressure (02PT-134A,B,C D) f

3. MSIV Closure - High Steam Line Flow (02DPT-1 1 6 A-D, 1 17A-D, 1 18 A-D, 1 19 A-D)

Amendment No. 130,182,227, 233 49 i

(

JAFNPP 3.2 BASES (cont'd)

The remote /altemate shutdown capability at FitzPatrick is Not all instruments, controls, and necessary transfer switches provided by a remote shutdown panel (25RSP) and five are located at the remote /altemate shutdown panels. Some alternate safe shutdown panels (25 ASP-1, 25 ASP-2, 25 ASP-controls and transfer switches will have to be operated locally 3,25 ASP-4, and 25 ASP-5). These panels are used in at the switchgear, motor control centers, or other local conjunction with the Automatic Depressurization System stations.

(ADS) relief valve control panel (02 ADS-71) adjacent to 25RSP, the emergency diesel generator (B & D) control panels Operability of the remote shutdown instrumentation and (93EGP-B and 93EGP-D) opposite 25 ASP-3, the reactor control functions ensure that there is sufficient information i

building vent and cooling panel (66HV-3B) near 25 ASP-1, available on selected plant parameters to place and maintain instrument rack 25-51, and instrument rack 25-6 opposite the plant in a shutdown condition should the control room l

25RSP. All of these locations are linked by communications become inaccessible. The instrumentation and controls and are provided with emergency lighting.

installed on the remote / alternate shutdown panels are listed in Table 3.2-10. This table only includes those isolation / transfer This Remote Shutdown capability provides the necessary switches that do not have an associated control switch.

instrumentation and controls to place and maintain the plant in Operability of isolation / transfer switches that have an

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a safe shutdown condition from a location other than the associated control switch will be demonstrated when the control room in the event the control room becomes control functions are tested as required by Surveillance i

inaccessible due to a fire or other reason.

Requirement 4.2.J.

This specification ensures the operability of the remote The remote shutdown instruments and control circuits covered i

shutdown instrumentation and control circuits. Operability of by this LCO do not need to be energized to be considered components such as pumps and valves, which are controlled operable. This LCO is intended to ensure that the instruments i

from these panels, is covered by other specifications. This and control circuits will be operable if plant conditions require i

specification does not impose conditions on plant operation the use of the remote shutdown capability. Performance of which are more ' restrictive than those already imposed by the instrument check once every 31 days ensures that a gross l

other specifications. For example, Specification 3.7.D includes failure of instrumentation has not occurred and is intended to provisions for continued operation with one or more ensure that the instrumentation continues to operate properly containment isolation valves inoperable. The 30 day time between each instrument channel calibration.

limitation imposed by 3.2.J would not apply in this situation, l

provided that the actions taken for the inoperable valve (s) to As specified in the surveillance requirements, an instrument satisfy 3.7.D are also consistent with the safety function (s) check is only required for those instruments that are normally l

required for fire protection.

energized. Performance of this surveillance provides i

assurance that undetected outright instrument failure is limited f

to 31 days. The surveillance frequency is based upon plant t

operating experience which indicates that channel failure is rare.

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i Amendment No. 10S,120,130,1 SO,181, 21 S, 233 i

60 l

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JAFNPP I

3.2 BASES (cont'd)

Surveillance Requirement 4.2.J requires that each remote shutdown transfer / isolation switch and control circuit be

[

periodically tested to demonstrate that it is capable of performing its intended function. The requirements of this section apply to each remote shutdown control circuit on the l

panels listed in Table 3.2-10. This demonstration is performed from the remote shutdown panel and locally, as appropriate. This wil' ensure that if the control room becomes inaccessible, the plant can be placed and maintained in a shutdown condition from the remote shutdown panel and the local control stations.

Three channels of the Reactor Vessel Water Level - High instrumentation are provided as input to a two-out-of-three initiation logic that trips the two feedwater pump turbines and the main turbine. An event involving excessive feedwater flow results in a rising reactor vessel water level, which upon reaching the reactor vessel water level trip setpoint, results in a trip of both feedwater pump turbines, and the main turbine. The feedwater pump turbine trip under these conditions limits further increase in the reactor vessel i

water level due to feedwater flow. A trip of the main turbine protects the turbine from damage due to excessive water carryover.

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i Amendment No. 21S,225, 233 60s

JAFNPP TABLE 3.2-2 (cont'd)

CORE AND CONTAINMENT COOLING SYSTEM INITIATION AND CONTROL INSTRUMENTATION OPERAmL!TY REOUIREMENTS Minimum No. of Operable Instrument Total Number of Channels Per instrument Channels item Trip System Provided by Design No.

(Notes 1 and 2)

Trio Function Trio Level Settina for Both Trio Systems Remarks 26 (1 per 4kV bus) 4kV Emergency Bus 110.6 i O.8 2

initiates both 4kV (Note 9)

Undervoltage Relay secondary volts Emergency Bus Undervoltage (Degraded Voltage)

Timers. (Degraded Voltage LOCA and non-LOCA)

(Notes 4 and 6) 27 (1 per 4kV bus) 4kV Emergency Bus 8.9610.55 sec.

2 (Note 5)

(Note 9)

Undervoltage Timer (Degraded Voltage LOCA) 28 (1 per 4kV bus) 4kV Emergency Bus 43.8

• 2.8 sec.

2 (Note 5)

(Note 9)

Undervoltage Timer (Degraded Voltage non-LOCA)

I 29 (1 per 4kV bus) 4kV Emergency Bus 85 i 4.81 2

initiates 4kV EmergencygBus (Note 9)

Undervoltage Relay secondary volts Undervoltage Loss of i

(Loss of Voltage)

Voltage Timer.

1 (Notes 4 and 7) 30 (1 per 4kV bus) 4kV Emergency Bus 2.50

• O.11 sec.

2 (Note 5)

F (Note 9)

Undervoltage Timer (Loss of Voltage)

U 31 2

Reactor Low Pressure 285 to 335 psig 4

Permits closure of recirculation pump discharge valve. l

,t; 1

Amendment No. 3, 'O, 227, 233 70 l

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i JAFNPP

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TABLE 3.2-10 REMOTE SHUTDOWN CAPADILITY INSTRUMENTATION AND CONTROLS (Refer to Notes on Page 770]

INSTRUMENT PANEL OR INSTRUMENT INSTRUMENT FUNCTIONAL OR CONTROL LOCATION CHECK CAllBRATION TEST 1.

RHR Service Water Flow (Loop B) 25RSP M

R NA (10FI-134) 2.

RHR Service Water Pump Control 25RSP NA NA R

(10P-1 B) 3.

RHR Service Water Heat Exchanger Outlet 25RSP NA NA R

Valve Control (10MOV-89B) 4.

RHR Service Water to RHR Cross-Tie Valve 25 ASP-1 NA NA R

Control (10MOV-148B) 5.

RHR Service Water to RHR Cross-Tie Valve 25 ASP-1 NA NA R

Control (10MOV-1498) t 6.

RHR Flow (Loop B) 25RSP M

R NA

[

(10FI-133) l l

7.

RHR Discharge Pressure (Pump D) 25RSP M

R NA (10PI-279) 8.

RHR Pump Control 25RSP NA NA R

(10P-3D) 9.

RHR Heat Exchanger Bypass Valve Control 25RSP NA NA R

(10MOV-66B)

Amendment No. 444, 233 77f

JAFNPP TABLE 3.2-10 (cont'd)

REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS

[ Refer to Notes on Page 770)

INSTRUMENT PANEL OR INSTRUMENT INSTRUMENT FUNCTIONAL OR CONTROL LOCATION CHECK CAllBRATION TEST 10.

RHR Inboard injection Valve Control 25RSP NA NA R

(10MOV-25B) 11.

RHR Heat Exchanger Steam Inlet Valve 25 ASP-1 NA NA R

Control (10MOV-708) 12.

RHR Heat Exchanger Vent Valve Control 25 ASP-1 NA NA R

(10MOV-1668) 13.

RHR Heat Exchanger Outlet Valve Control 25 ASP-1 NA NA R

(10MOV-12B) 14.

RHR Pump D Torus Suction Valve Control 25 ASP-2 NA NA R

(10MOV-13D) 15.

RHR Pump D Shutdown Cooling Suction Valve 25 ASP-2 NA NA R

Control (10MOV-15D) 16.

RHR Pump B Minimum Flow Valve Control 25 ASP-2 NA NA R

(10MOV-168) 17.

RHR Heat Exchanger inlet Valve Control 25 ASP-2 NA NA R

(10MOV-65B) 18.

RHR Outboard injection Valve Control 25 ASP-2 NA NA R

(10MOV-27B)

Amendment No. 246, 233 77g

m___

JAFNPP TABLE 3.2-10 (cont'd)

REMOTE SHUTDOWN CAPABILITY INSTRUMENTATIQN AND CONTROLS

[ Refer to Notes on Page 770]

INSTRUMENT PANEL OR INSTRUMENT INSTRUMENT FUNCTIONAL t

OR CONTROL LOCATION CHECK CAllBRATION TEST 19.

RHR Heat Exchanger Discharge to Torus Valve 25 ASP-2 NA NA R

Control (10MOV-21B) i 20.

Torus Cooling Isolation Valve Control 25 ASP-2 NA NA R

(10MOV-39B) 21.

DW Spray Outboard Valve Control 25 ASP-3 NA NA R

(10MOV-26B) 22.

ADS & Safety Relief Valve A Control 02 ADS-71 NA NA R

(02RV-71 A) 23.

ADS & Safety Relief Valve B Control 02 ADS-71 NA NA R

l (02RV-71 B) i

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24.

ADS & Safety Relief Valve C Control 02 ADS-71 NA NA R

(02RV-71C) 25.

ADS & Safety Relief Valve D Control 02 ADS-71 NA NA R

(02RV-71 D) 26.

ADS & Safety Relief Valve E Control 02 ADS-71 NA NA R

(02RV-71E) 27.

ADS & Safety Relief Valve G Control 02 ADS-71 NA NA R

(02RV-71G) t Amendment No. 444, 233 77h f

JAFNPP TABLE 3.2-10 (cont'd)

REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS

[ Refer to Notes on Page 770)

INSTRUMENT PANEL OR INSTRUMENT INSTRUMENT FUNCTIONAL l

OR CONTROL LOCATION CHECK CAllBRATION TEST 28.

ADS & Safety Relief Valve H Control 02 ADS-71 NA NA R

(02RV-71H) 29.

Safety Relief Valve F Control 02 ADS-71 NA NA R

(02RV-71 F) 30.

Safety Relief Valve J Control 02 ADS-71 NA NA R

(02RV-71J) 31.

Safety Relief Valve K Control 02 ADS-71 NA NA R

(02RV-71 K) 32.

Safety Relief Valve L Control 02 ADS-71 NA NA R

(02RV-71 L) 33.

Main Steam Line Drain Outboard Isolation 25 ASP-2 NA NA R

Valve Contro! (29MOV-77) 34.

Drywell Temperature 25RSP M

R NA (68TI-115) 35.

Torus Water Temperature 25RSP M

R NA (27TI-101) 36.

Torus Water Level 25RSP M

R NA (23LI-204)

Amendment No. 246,233 77i

JAFNPP TABLE 3.2-10 (cont'd)

REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS

[ Refer to Notes on Page 7701 INSTRUMENT PANEL OR INSTRUMENT INSTRUMENT FUNCTIONAL OR CONTROL LOCATION CHECK CAllBRATION TEST 37.

Reactor Vessel Pressure Rack 25-6 M

R NA (02-3PI-60B) 38.

Reactor Vessel Water Level Rack 25-6 M

R NA (02-3Li-58A) 39.

Reactor Vessel Water Level Rack 25-51 M

R NA (02-3LI-93) 40.

HPCI Steam Supply Outboard Isolation Valve 25RSP NA NA R

Control (23MOV-16) 41.

HPCI Outboard Isolation Bypass Valve Control 25 ASP-2 NA NA R;

(23MOV-60) 42.

HPCI Minimum Flow Valve Control 25 ASP-2 NA NA RI (23MOV-25) 43.

CAD B Train inlet Valve Control 25RSP NA NA Ri (27AOV-1268) i 44.

Nitrogen Instrument Header Isolation Valve 25RSP NA NA R

li Control (27AOV-1298) 45.

. Reactor Water Cleanup Outboard Isolation 25 ASP-2 NA NA Rj Valve Control (12MOV-18)

Amendment No. 346, 233 l

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77j 1

s'

-.. -. -.... ~ -- - -.-..

JAFNPP l

TABLE 3.2-10 (cont'd)

REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS

[ Refer to Notes on Page 770) t INSTRUMENT PANEL OR INSTRUMENT INSTRUMENT FUNCTIONAL OR CONTROL LOCATION CHECK CAllBRATION TEST 46.

Emergency Service Water Pump B Control 25 ASP-3 NA NA R

(46P-2B) 47.

ESW Loop B Supply Header Isolation Valve 25 ASP-3 NA -

NA R

Control (46MOV-101B) 48.

ESW Pump B Test Valve Control 25 ASP-3 NA NA R

(46MOV-1028) 49.

Bus 11600 Supply Breaker Control 25RSP NA NA R

i (71-11602) i 50.

EDG B & EDG D Tie Breaker Control 25ASF'-3 NA NA R

(71-10604) 51.

Bus 10400-10600 Tie Breaker Control 25 ASP-3 NA NA R

(71-10614) 52.

Unit Substation L16 & L26 Feeder Breaker 25 ASP-3 NA NA R

Control (71-10660) 53.

Bus 12600 Supply Breaker Control 25 ASP-3 NA NA R

(71-12602) 54.

Breaker 71-10614 Synchronizing Check Control 25 ASP-3 NA NA R

55.

EDG B Control Room Metering Check Control 25 ASP-3 NA NA R

Amendment No. 444, 233 77k

JAFNPP TABLE 3.2-10 (cont'd)

REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS (Refer to Notes on Page 770]

INSTRUMENT PANEL OR INSTRUMENT INSTRUMENT FUNCTIONAL OR CONTROL LOCATION CHECK CAllBRATION TEST 3

56.

EDG B Engine Start /Stop Control 25 ASP-3 NA NA R

57.

EDG D Control Room Metering Check Control 25 ASP-3 NA NA R

58.

EDG D Engine Start /Stop Control 25 ASP-3 NA NA R

59.

EDG B Governor Switch 93EGP-B NA NA R

60.

EDG B Synchronizing Switch 93EGP-B NA NA R

61.

EDG B Load Breaker Control (71-10602) 93EGP-B NA NA R

62.

EDG B Motor Control 93EGP-B NA NA R

63.

EDG B Frequency Meter (93FM-1B) 93EGP-B NA R

NA 64.

EDG B Voltage Control 93EGP-B NA NA R

l f

65.

EDG B Emergency Bus Meter (71VM-600-18) 93EGP-B M

R NA 66.

EDG B locoming Bus Meter (93VM-128) 93EGP-B NA R

NA 67.

EDG B Running Bus Meter (93VM-11B) 93EGP-B NA R

NA 68.

EDG D Govemor Switch 93EGP-D NA NA R

69.

EDG D Synchronizing Switch 93EGP-D NA NA R

Amendment No. 244, 233 7 71

JAFNPP TABLE 3.2-10 (cont'd)

REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS

[ Refer to Notes on Page 770]

INSTRUMENT PANEL OR INSTRUMENT INSTRUMENT FUNCTIONAL OR CONTROL LOCATION CHECK CAllBRATION TEST r

70.

EDG D Load Breaker Control (71-10612) 93EGP-D NA NA R

71.

EDG D Motor Controi 93EGP-D NA NA R

72.

EDG D Frequency Meter (93FM-1D) 93EGP-D NA R

NA 73.

EDG D Voltage Control 93EGP-D NA NA R

74.

EDG D Emergency Bus Meter (71VM-600-1D) 93EGP-D M

R NA 75.

EDG D incoming Bus Meter (93VM-12D) 93EGP-D NA R

NA I

76.

EDG D Running Bus Meter (93VM-11D) 93EGP-D NA R

NA I

77.

Reactor Head Vent isolation Switch 25RSP NA NA R

(02AOV-17) i 78.

Outboard MSlV A isolation Switch 25 ASP-4 NA NA R

l (29AOV-86A) i 79.

Outboard MSIV B isolation Switch 25 ASP-4 NA NA R

[

(29AOV-868) 80.

Outboard MSIV C isolation Switch 25 ASP-4 NA NA R

(29AOV-86C)

[

)

Amendment No. 444,233 l

77m i

JAFNPP TABLE 3.2-10 (cont'd)

REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS (Refer to Notes on Page 770)

INSTRUMENT PANEL OR INSTRUMENT INSTRUMENT FUNCTIONAL OR CONTROL LOCATION CHECK CAllBRATION TEST 81.

Outboard MSIV D isolation Switch 25 ASP-4 NA NA R

(29AOV-86D) 82.

East Crescent Area Unit Cooler B,D,F 66HV-3B NA NA R

(66UC-22B, 22D, 22F) Isolation Switch 83.

East Crescent Area Unit Cooler H,K 66HV-3B NA NA R

(66UC-22H, 22K) Isolation Switch 84.

ADS & Safety Relief Valve A 25 ASP-5 NA NA R

isolation Switch (02RV-71 A) 85.

ADS & Safety Relief Valve B 25 ASP-5 NA NA R

isolation Switch (02RV-71B) 86.

ADS & Safety Relief Valve C 25 ASP-5 NA NA R

isolation Switch (02RV-71C)

I 87.

ADS & Safety Relief Valve D 25 ASP-5 NA NA R

isolation Switch (02RV-71D) 88.

ADS & Safety Relief Valve E 25 ASP-5 NA NA R

lsolation Switch (02RV-71E) 89.

Safety Relief Valve F 25 ASP-5 NA NA R

isolation Switch (02RV-71F)

Amendment No. 233 77n i

JAFNPP TABLE 3.2-10 (cont'd)

REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS INSTRUMENT

~

3ANEL OR INSTRUMENT INSTRUMENT FUNCTIONAL OR CONTROL LOCATION CHECK CAllBRATION TEST 90.

ADS & Safety Relief Valve G 25 ASP-5 NA NA R

lsolation Switch (02RV-71G) 91.

ADS & Safety Relief Valve H 25 ASP-5 NA NA R

isolation Switch (02RV-71H) 92.

Safety Relief Valve J 25 ASP-5 NA NA R

isolation Switch (02RV-71J) 93.

Safety Relief Valve K 25 ASP-5 NA NA R

lsolation Switch (02RV-71K) 94.

Safety Relief Valve L 25 ASP-5 NA NA R{

Isolation Switch (02RV-71L) i i

NOTES FOR TABLE 3.2-10 1.

Minimum required number of divisions for all instruments and controls listed is 1.

l I

Amendment No. 233 l

, [

770

.I

1 I

i, l

i !

T JAFNPP TABLE 4.2-2 CORE AND CONTAINMENT COOLING SYSTEM INSTRUMENTATION TEST AND CAllBRATION REQUIREMENTS Instrument Channel Instrument Functional Test Calibration Frequency Instrument Check (Note 4) 1)

Reactor Water Level O (Nete 5)

SA / R (Note 15)

D 2a)

Drywell Pressure (non-ATTS)

Q O

NA 2b)

Drywell Pressure (ATTS)

Q (Note 5)

SA / R (Note 15)

D 3a)

Reactor Pressure (non-ATTS)

Q O

NA 3b)

Reactor Pressure (ATTS)

Q (Note 5)

SA / R (Note 15)

D 4)

Auto Sequencing Timers NA 18M

?A 5)

ADS - LPCI or CS Pump Disch.

O O

NA 6)

Trip System Bus Power Monitors Q

NA NA 7)

Core Spray Sparger d/p Q

Q D

8)

HPCI & RCIC Suction Source Levels O

O NA 9) 4kV Emergency Bus Under-Voltage R

R NA (Loss-of-Voltage, Degraded Voltage LOCA and non-LOCA) Relays and Timers.

10)

LPCI Cross Connect Valve Position R

NA NA I

NOTE:

See notes following Table 4.2-5.

l l

imendment No. 3,00,160,181,201,217,227, 233 80

JAFNPP TABLE 4.2-3 CONTROL ROD BLOCK INSTRUMENTATION TEST AND CAllBRATION REQUIREMENTS Instrument Functional Instrument Instrument Channel Test (Note 5)

Calibration Check (Note 4) 1)

APRM - Downscale Q

Q D

2)

APRM - Upscale Q

Q D

3) lliM - Upscale S/U (Note 2)

O (Notes 3 & 6)

D 4) 1RM - Downscals S/U (Note 2)

Q (Notes 3 & 6)

D 5)

IRM - Detector Not in Startup Position S!U (Note 2)

NA NA 6)

RBM - Upscale Q

Q D

7)

RBM - Downscale Q

Q D

8)

SRM - Upscale S/U (Note 2)

Q (Notes 3 & 6)

D 9)

SRM - Detector Not in Startup Position S/U (Note 2)

NA NA 10)

Scram Discharge Instrument Volume -

O Q

D High Water Level (Group B Instruments)

NOTE: See nctes following Table 4.2-5.

Amendment No. 3,59,93,227, 233 82 i

JAFNPP TABLE 4.2-5 M!NIMUM TEST AND CALIBRATION FREQUENCY FOR DRYWELL LEAK DETECTION instrument Functional Calibration Instrument Check Instrument Channel Test Frequency (Note 4) 1)

Equipment Drain Sump Row Integrator (Note 1)

Q D

2)

Floor Drain Sump Flow Integrator (Note 1)

Q D

i l

NOTE: See notes following Table 4.2-5.

e Amendment No. 3S, Se,181, 233 83

i JAFNPP l

i i

NOTES FOR TABLES 4.2-1 THROUGH 4.2-5 i

1. Initially ones every month until acceptance failure rate data are 8.

Reactor low water level, and high drywell pressure are not available; thereafter, a request may be made to the NRC to included on Table 4.2-1 since they are listed on Table change the test frequency. The compilation of instrument 4.1-2.

failure rate data may include data obtained from other boiling water reactors for which the same design instruments operate 9.

The logic system functional tests shall include a calibration in a environment similar to that of JAFNPP.

of time delay relays and timers necessary for proper i

functioning of the trip systems.

2. Functional tests are not required when thesa instruments are l

not required to be operable or are tripped. Functional tests

10. (Deleted) shall be performed within seven (7) days prior to each startup.

11. Perform a calibration once per 24 months using a niidiation l

3. Calibrations are not required when these instruments are not source. Perform an instrument channel alignment ance required to be operable or are tripped. Calibration tests shall every 3 months using a current source.

l be performed within seven (7) days prior to each startup or prior to a pre-planned shutdown.

12. (Deleted)

4. Instrument checks are not required when these instruments

13. (Deleted) are not required to be operable or are tripped.

14. (Deleted)

5. This instrumentation is exempt from the functional test definition. The functional test will consist of injecting a

15. Sensor calibration once per 24 months. Master / slave trip

[

simulated electrical signal into the measurement channel.

unit calibration once per 6 months.

i

6. These instrument channels will be calibrated using simulated

16. The quarterly calibration of the temperature sensor consists

[

electrical signals once every three months.

of comparing the active temperature signal with a i

redundant temperature signal.

l

7. Simulated automatic actuation sliall be performed once per 24 months.

l t

L Amendment No. Si, 10, 57,89,181, 207, 227, 233 l

84 1

JAFNPP TABLE 4.2-6 FEEDWATER PUMP TURBINE AND MAIN TURBINE TRIP INSTRUMENTATION TEST AND CAllBRATION REQUIREMENTS Instrument Channel Instrument Functional Logic System Functional Calibration Frequency instrument Check Test Frequency (Note 2)

Test Frequency Frequency Reactor Vessel Water Level - High Note 1 R

R D

NOTES FOR TABLE 4.2-6

1. Perform the instrument functional test:

a. Once per 24 months during each refueling outage, and

b. Each time the plant is in cold shutdown for a period of more than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, unless performed i

in the previous 92 days.

I

2. This instrumentation is exempt from the instrument channel functional test definition. The l

functional test will consist of injecting a simulated electrical signal into the instrument channel as close to the censor as practicable.

i 5

i

~

Amendment No. 3G6, 233 84a l

.I t'

I I

. _ ~. _

1 JAFNPP I

TABLE 4.2-8 i

MINIMUM TEST AND CAllBRATION FREQUENCY FOR ACCIDENT MONITORING INSTRUMENTATION instrument Instrument Instrument Functional Test Calibration Frequency Check 1.

Stack High Range Effluent Monitor 18M 18M D

i 2.

Turbine Building Vent High Range Effluent Monitor 18M 18M D

3.

Redwaste Building Vent High Range Effluent Monitor 18M 18M D

4.

Containment High Rarige Radiation Monitor R

R D

I 5.

Drywell Pressura (narrow range)

N/A R

D t

6.

Drywell Pressure (wide range)

N/A R

D 7.

Drywell Temperature N/A R

D l

8.

Torus Water Level (wide range)

N/A R

D 9.

Torus Bu'k Water Temperature N/A R

D i

10.

Torus Pressure N/A R

D I

11.

Primary Containment Hydrogen / Oxygen Concentration N/A O

D Analyzer 12.

Reactor Vessel Pressure N/A R

D 13.

Reactor Water Level (fuel zone)

N/A R

D 14.

Reactor Water Level (wide range)

N/A R

D Amendment No. 2,'72,181, 221, 233 86

JAFNPP TABLE 4.2-8 (cont'd)

MINIMUM TEST AND CAllBRATION FREQUENCY FOR ACCIDENT MONITORING INSTRUMENTATION Instrument Instrument Instrument Functional Test Calibration Frequency Check 15.

Core Spray Flow N/A R

D 16.

Core Spray Discharge Pressure N/A R

D 17.

LPCI (RHR) Flow N/A R

D 18.

RHR Service Water Flow N/A R

D 19.

Safety / Relief Valve Position Indicator R

N/A M

(Primary and Secondary) 20.

Torus Water Level (narrow range)

N/A R

D 21.

Drywell-Torus Differential Pressure N/A R

D Amendment No. 130,181,229, 233 86a

l JAFNPP 3.5 LIMITING CONDITIONS FOR OPERATION 4.5 SURVEILLANCE REQUIREMENTS i

3.5 CORE AND CONTAINMENT COOLING SYSTEMS 4.5 CORE AND CONTAINMENT COOLING SYSTEMS Anoticatnhtv:

Anolicability:

Applies to the operational status of the Emergency Core Cooling Applies to periodic testing of the Emergency Core Cooling Systems.

Systems, the suppression pool cooling, and containment spray the suppression pool cooling and containment spray mode of the modes of the Residual Heat Removal (RHR) System.

Residual Heat Removal (RHR) System.

Qbjective:

Obiective:

l To assure operability of the Core and Containment Cooling Systems To verify the operability of the Core and Containment Cooling f

under all conditions for which this cooling capability is an essential Systems under all conditions for which operability is essential.

l response to plant abnormalities.

i Specification:

Specification:

}

A.

Core Sorav System and Low Pressure A. Core Sorav System and Low Pressure Coolant Iniection (LPCI)

Coolant Iniection (LPCI) Mode of the RHR System Mode of the (RBR) System 1.

Both Core, Spray Systems shall be operable when ever 1.

Surveillance of the Core Spray System shall be performed f

irradiated fuel is in the reactor vessel and prior to reactor as follows:

startup from a cold condition, except as specified below:

ltem Freauency 1

a.

Simulated Refer to Table 4.2-2 Automatic Actuation Test t

t Amendment No. 233 112

JAFNPP 3.5 (cont'd) 4.5 (cont'd) b.

Flow Rate Test -

Once/3 months Core spray pumps shall deliver at least 4,265 gpm against a system head corresponding to a reactor vessel pressure greater than or equal to 113 psi above primary containment pressure.

c.

Pump Operability Once/ month d.

Motor Operated Valve Once/ month e.

Core Spray Header a p instrumentation t

Check Once/ day Calibrate Once/3 months Test Once/3 months f.

Logic System Refer to Table 4.2-2 Functional Test g.

Testable Check Tested for operability Valves any time the reactor is in the cold condition exceeding 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />, if operability tests have l

not been performed during the preceding 31 days.

Amendment No. 10, 'ia, 204, 233 113

JAFNPP 3.5 (cont'd) 4.5 (cont'd) b.

When the reactor water temperature is greater b.

The power source disconnect and chain lock to than 212*F, the motor operator for the RHR motor operated RHR cross-tie valve (10MOV-20),

l cross-tie valve (10MOV-20) shall be maintained and lock on manually operated gate valve disconnected from its electric power source. It (10RHR-09) shall be inspected once per month to shall be maintained chain-locked in the closed verify that both valves are closed and locked.

position. The manually operated gate valve l_

(10RHR-09) in the cross-tie line, in series with the motor operated valve, shall be maintained locked in the closed position.

4.

a.

The reactor shall not be staited up with the RHR System supplying cooling to the fuel pool.

b.

The RHR System shall not supply cooling to the spent fuel pool when the reactor coolant temperature is above 212*F.

+

l

}

i i

s i

I l

I l

i i

t e

i Amendment No. 55, 95,'18,233 115 f.

l JAFNPP i

l 3.5 (Cont'd) 4.5 (Cont'd)

E.

Reactor Core Isolation Coolina (RCIC) Sys19m E.

Reactor Core Isolation Coolina (RCIC) System 1.

The RCIC System shall be operable whenever there 1.

RCIC System testing shall be performed as follows is irradiated fuel in the reactor vessel and the reactor provided a reactor steam supply is available. If pressure is greater than 150 psig and reactor coolant steam is not available at the time the surveillance temperature is greater than 212*F except from the test is scheduled to be performed, the test shall be time that the RCIC System is made or found to be performed within ten days of continuous operation inoperable for any reason, continued reactor power from the time steam becomes available.

operation is permissible during the succeeding 7 days unless the system is made operable earlier item Freauency provided that during these 7 days the HPCI System is operable.

a.

Simulated Automatic Once per 24 Months Actuation (and Restart")

2.

If the requirements of 3.5.E cannot be met, the Test reactor shall be placed in the cold condition and pressure less than 150 psig within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

b.

Pump Operability Once/ month 3.

Low power physics testing and reactor operator c.

Motor Operated Once/ month training shall be permitted with inoperable Valve Operability components as spec 5fied in 3.5.E.2 above, provided that reactor coolant temperature is :s212*F.

d.

Flow Rate Once/3 months 4.

The RCIC system is not required to be operable e.

Testable Check Tested for operability during hydrostatic pressure and leakage testing with Valves any time the reactor is reactor coolont temperatures between 212'F and in the cold condition 3OO'F and irradiated fuel in the reactor vessel exceeding 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />, if provided all control rods are inserted.

operability tests have not been performed during the preceding 31 days.

f.

Logic System Once per 24 Months Functional Test Automatic restart on a low water level signal which is subsequent to a high water level trip.

Amendment No. 10,107, ? ?O, '??, 233 121

JAFNPP 4.5 BASES The testing interval for the Core and Containment Cooling The RCIC flow rate is described in the UFSAR. The flow rates to Systems is based on a quantitative reliability analysis, industry be delivered to the reactor core for HPCI, the LPCI mode of RHR, practice, judgement, and practicality. The Emergency Core and CS are based on the SAFER /GESTR LOCA analysis. The flow Cooling Systems have not been designed to be fully testable rates for the LPCI mode of RHR and CS are modified by a 10 during operation. For example, the core spray final admission percent reduction from the SAFER /GESTR LOCA analysis. The valves do not open until reactor pressure has fallen to 450 psig:

reductions are based _an a sensitivity analvsin m-n m,+ic thus, during operation even if high drywell pressure were MDE-83-0786) performed for the parameters used in the simulated, the final valves would not open. In the case of the SAFER /GESTR analysis.

HPCl, automatic initiation during power operation would result in pumping cold water into the reactor vessel which is not The CS surveillance requirement includes an allowance for system desirable.

leakage in addition to the flow rate required to be delivered to the reactor core. The leak rate from the core spray piping inside the The systems will be automatically actuated once per 24 months.

reactor but outside the core shroud is assumed in the UFSAR and in the case of the Core Spray System, condensate storage tank includes a known loss of less than 20 gpm from the 1/4 inch water will be pumped to the vessel to verify the operability of diameter vent hole in the core spray T-box connection in each of the core spray header. To increase the availability of the the loops, and in the B loop, a potential additional loss of less than individual components of the Core and Containment Cooling 40 gpm from a clamshell repair whose structural weld covers only Systems the components which make up the ~ system i.e.,

5/6 of the circumference of the pipe. Both of these identified instrumentation, pumps, valve operators, etc. are tested more sources of leakage occur in the space between the reactor vessel frequently. The instrumentation is functionally tested each wall and the core shroud. Therefore flow lost through these leak month. Likewise, the pumps and motor-operated valves are also sources does not contribute to core cooling.

tested each month to assure their operability. The combination automatic actuation test and monthly tests of the pumps and The surveillance requirements to ensure that the discharge piping valve operators is deemed to be adequate testing of these of the core spray, LPCI mode of the RHR, HPCI, and RCIC systems.

Systems are filled provides for a visual observation that water flows from a high point vent. This ensures that With components or subsystems out-of-service, overall core and containment cooling reliability is maintained by verifying the operability of the remaining cooling equipment. Consistent with the definition of operable in Section 4.0.C, demonstrate means conduct a test to show; verify means that the associated surveillance activities have been satisfactorily performed within i

the specified time interval.

t i

Amendment No. ti, tis, 201, 233 f

132

JAFfrP 3.7 (cont'd) 4.7 (cont'd)

I t

e.

On:e per 24 months, marmal operability of the

(

bypass varve for filter cooling shall be demonstrated.

f.

Standby Gas Treatment System Instrumentation Ca5 brat on:

differential Once per 24 Months I

pressure switches 2.

From and after the date that one circuit of the Standby 2.

When one circuit of the Standby Gas Treatment Gas Treatment System is made cr found to be inoperable System becomes inoperable the operable circuit

[

for any reason, the foEowing would apply:

shall be verified to be operable immediately and daily thereafter.

a.

if in Start up/ Hot Standby, Run or Hot Shutdown mode, reactor operation or irradiated fuel handling is permissible only during the succeeding 7 days unless such cwcuit is sooner made operabfe, provided that during such 7 days all active components of the other Standby Gas Treatment Circuit shot be operable.

i b.

If in Refuel or Cold Shutdown mode, reactor operation or irradiated fuel handing is permissib:e I

only during the succeeding 31 days unless such circuit is sooner made operebfe, provided that during such 31 days at active components of the other Standby Gas Treatment Circuit shall be operable.

3.

If Specifications 3.7.B.1 and 3.7.B.2 are not met, the

3. Intentionaly Blank reactor shall be placed in the cold condition and irradiated fuel beneng operations and operations that csuid reduce the shutdown mergii sheE be prohibited.

I Amendment No. ? ^ SS, '48,1S', 232, i

183

JAFM*P 4.7 (cort *d) 3.7 (cont'd) c.

Secondary containment capability to maintain a 1/4 in. of water vacuum under calm wnd conditions with a filter train flow rate of not rnore than 6,000 cfat, shaR be demonstrated once per 24 months prior to refimling.

D.

P6 nary Containment isoletion Valves D.

Prirnary Containment isolation Vafves 1.

Whenever primary contamment integrity is required per 1.

The pririary containment isofation valves surveillence 3.7.A.2. containment isolation valves and all instrument shel be performed as follows:

line exess flow check valves shall be operable, except a.

Orce per 24 mo7ths, the operable isolation valves as specified in 3.7.0.2. The containment vent and aurge valves sheB be limited to opening angles less then or that are power operated End automatically initiated shall be tested for simulated autorraticinitiation and equal to that specified below:

for clo:ure time.

Valve Number _

Maxrmum Openino Anale 27AOV-111 40*

b.

Once per 24 months, the instrument line excess i

flow check valves shap be tested for proper 27AOV-112 40' 27AOV-113 40*

operation.

27AOV-114 50' 27AOV-115 50 c.

Atleast once per quarter:

27AOV-116 50*

27AOV-117 50*

(1.) All normaty open power-operated isolation valves (except for the main stream line and 27AOV-118 50' Reactor Building Cicmd Loop CoalN Water System IRBCLCWS) power-operated isolation valves) shall be fuBy closed and reopened.

Amendenent No. 15 % *73,105, 232, 185

JAFNPP 3.9 (cont'd) 4.9 (cont'd) 3.

From and after the time both power supplies are made or s

found inoperable the reactor shall be brought to cold condition within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

G.

REACTOR PROTECTION SYSTEM ELECTRICAL PROTECTION G.

REACTOR PROTECTION SYSTEM ELECTRICAL PROTECTION ASSEMBLIES ASSEMBLIES Two RPS electrical protection assemblies for each inservice The RPS electrical protection assemblies instrumentation shall RPS MG set and inservice alternate source shall be operable be determined operable by:

t except as specified below:

1.

Performing a channel functional test each time the plant is

)

1.

With one RPS electrical protection assembly for an in cold shutdc,wn for a period of more than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, inservice RPS MG set or an inservice alternate power unless pc armed in the previous 6 months.

l supply inoperable, restore the inoperable channel to operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or remove the associated 2.

Once per 24 months, demonstrating the operability of RPS MG set or alternate power supply from service.

over-voltage, under-voltage and under-frequency protective instrumentation by performance of a channel

~

2.

With two RPS elecuical protection assemblies for an calibration including simulated automatic actuation of the inservice RPS MG set or an inservice alternate power protective relays, tripping logic and output circuit supply inoperable, restore at least one to operable status breakers and verifying the following setpoints: i RPS MG SET SOURCE ;l within 30 minutes or remove the associated RPS MG set or altemate power supply from service.

i OVER-VOLTAGE s132V B

s4 second Time Delay l l

UNDER-VOLTAGE 2112.3V g

h i

s4 second Time Delay I

H UNDER-FREQUENCY 257Hz s4 second Time Delay '

(

,r i

~l Amendment No.11, S,189, 233 (continued on pahe 222d) l 222c j

it

JAFNPP 4.9 BASES (cont'd) followed by a constant discharge current (temperature D.

Not Used

~

correctec) for the performance test.

l E.

Battery System The purpose of the mo:13ed performance testis to Measurements and electrical tests are conducted at specified demonstrate the battery has sufficient capacity to meet the I

intervals to provide indication of cell condition and to system design requirements and to g:rovide trendable determee the discharge capability of the batteries.

performat:e data to compare the available capacity in the j

Performance and service tests are condtscted in accordance battery to previous car.acity test results. The modfied with the recommendations of IEEE 450-1995.

performance test may be performed in lieu of the battery l

service test.

The bettery servce (duty cycle) test demonstrates the capacity of the tattery to meet the system design The station batteries are required for plant opers. tion, and requiremer ':s. When a se.vice testis used on a regular basis, performing the station battery service test and performance (or it will reflect maintenance practices. The FitzPatrick design modified performance) test requires the reactor to be shut duty cycle loads are dete mined by a LOCA concurrent with a down.

[

loss of normal and reserve power.

F.

LPCf MOV Indeoendent Power Supoly The performance (discharge) test is a test of the constant current capacity of a battery and can be conducted with the Measurernent and electrical tests are conducted at specified battery in en as-found condition efter being subjected to an intervals to provide indication of cell condition, to determine equalizing charge tf performance testing is to be used to the discharge capability of the bettery. Perfonnance ard reflect baselined bettery trending capacity, then special service tests are conductedin accordance with the conditions (including equalizing) are required to estab1sh the recommandat ons of IEEE 450-1995.

bettery in an as known condition p%r to the test. If performance testing is to be used to reflect maintenance G.

Reactor Protection Power Suooles practices as weR as trending, the equalizing charge can be Functional tests of the electncal protection assemblies are i

omitted.

conducted at specified intervals utilizing a built-in test device l

The modified performance test is a composite test which and once per 24 months by performing an instrument i

erwelopes both the service test and performance test calibratioq which verifies operation within the limits of Section requirements. The modified performance test discharge 4.9.G.

current envelopes the peak duty cycle loads of the service test Amendment No. 30,70, !?i,157,122,1"1232.

226 i

JAFNPP

?

3.11 (cont'd) 4.11 (cont'd) ventilation air supply fan and/or filter may be out of b.

Di-octylphtalate (DOP) test for particulate filter f

service for 14 days.

efficiency greater than 99% for particulate greater than 0.3 micron size.

c.

Freon-112 test for charcoal filter bypass as a measure of filter efficiency of at least 99.5% for halogen removal.

d.

A sample of charcoal filter shall be analyzed once a year to assure halogen removal efficiency of at least 99.5%.

2.

The main control room air radiation monitor shall be 2.

Operability of the main control room air intake radiation operable whenever the control room emergency monitor shall be tested once/3 months.

ventilation air supply fans and filter trains are required to be operable by 3.11.A.1 or filtration of the control room ventilation intake air must be initiated.

3.

The control room emergency ventilation system shall not 3.

Temperature transmitters and differential pressure be out of service for a period exceeding 3 days during switches shall be calibrated once per 24 months.

normal reactor operation or refueling operations. In the l

event that the system is not returned to service within 3 i

days, the reactor shall be in cold shutdown within 24 i

hours and any handling of irradiated fuel, core alterations, and operations with a potential for draining the reactor vessel shall be suspended as soon as practicable 4.

Not Used 4.

Main control room emergency ventilation eir supply

[

system capacity shall be tested once every 18 months to assure that it is 110% of the design value of 1000 cfm.

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Amendment No. 1 'i,120,192, 233 238

t JAFNPP j

3.11 (cont'd) 4.11 (cont'dl r

B.

DELETfD B.

DELETED C.

Battery Room Ventilation C. Battery Room Ventitaticn Battery room ventitation shallbe operable en a continuous Battery room ventilation equipment shall be demonstrated basis whenever specification 3.9.E is required to be satistW.

operable once! week.

i 1.

From and after the date that one of the battery room

1. When it is determined that one battery roorn ventilat.on ventilation systems is trade or found to be inoperable, system is inoperable, the remaining ventilat on system shall its associeted battery shall be co tsidered to be be verified operable and daily thereafter.

inoperable for purposes of specifcation 3.9.E.

2. Ternperature transmitters and differential pressure switches shall be calbrated once per 24 months.

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L Amendment No. '", S2, ! 25, ? 3', t '", ? 55, 231, f

239

ATTACHMENT TO LICENSE AMENDMENT NO. 233 3

j FACILITY OPERATING LICENSE NO. DPR-59 DOCKET N0. 50-333 i

4 Revise Appendix B as follows:

i Remove Paaes Insert Paaes 32 32 33 33 38 38 j

39 39 A

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4 3

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4

l JAFNPP LIMITING CONDITIONS FOR OPERATION SURVElLLANCE REQUIREMENTS

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3.7 OFFGAS TREATMENT SYSTEM EXPLOSIVE GAS MIXTURE 3.7 OFFGAS TREATMENT SYSTEM EXPLOSIVE GAS MIXTURE INSTRUMENTATION INSTRUMENTATION Acolicability Acolicability Applies to the condenser offgas treatment system recombiner Applies to the offgas treatment system instrumentation, which operation.

monitors the critical operating parameters of the primary I

recombiner.

Obiectiv.a Obiective To ensure proper conditions for the offgas recombiner to To ensure that instrumentation required for automatic isolation i

operate at design efficiency in order to prevent an explosive is maintained and calibrated.

mixture of gases in the charcoal treatment system.

Specifications Soecifications a.

The concentration of wither hydrogen or oxygen in the i

a.

The concentration of either hydrogen or oxygen in the main condenser offgas treatment system shall be main condenser offgas treatment system shall be limited determined to be within the limits of Specification 3.7.a to less than or equal to 4% by volume.

by continuously monitoring the waste gases in the main condenser offgas treatment system whenever the main condenser evacuation system is in operation with the hydrogen or oxygen monitors. Operation of the hydrogen or oxygen monitors shall be verified in accordance with Specification 3.7.b.1 and 3.7.b.4.

l b.

In lieu of continuous hydrogen or oxygen monitoring, the b.

Whenever continuous hydrogen or oxygen monitoring is following instrumentation shall be operational and not available, operation of the explosive gas mixture capable of providing automatic isolation of the offgas instruments listed in Specification 3.7.b shall be verified.

Amendment No. 93, 233 32

m. _ ___ -

JAFNPP LIMITING CONDITIONS FOR OPERATION SURVElLLANCE REQUIREMENTS treatment system under the following conditions:

1.

An instrument check shall be performed daily when the offgas treatment system is in operation.

1.

The offgas dilution steam flow instrumentation shall alarm and automatic' lly isolate the offgas recombiner 2.

An instrument channel functional test of the a

system at a low flow setpoint greater than or equal to instrumentation listed in Specification 3.7.b shall be 6300 pounds per hour and at a high flow setpoint less performed once per 24 months.

than or equal to 7900 pounds per hour.

3.

An instrument channel calibration of the instrumentation 2.

The offgas recombiner inlet temperature sensor shall listed in Specification 3.7.b shall be performed once per alarm and automatically isolate the offgas recombiner 24 months.

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system at a temperature setpoint of greater than or equal to 125'C.

4.

An instrument channel functional test and calibration of the off-gas hydrogen or oxygen monitors shall be 3.

The offgas recombiner outlet temperature sensor shall performed once every 3 months.

alarm and automatically isolate the offgas treatment system at a temperature setpoint of greater than or equal to 150'C.

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c.

In lieu of continuous hydrogen or oxygen monitoring, the c.

With condenser offgas treatment system recombinet n i

condenser offgas treatment system recombiner effluent shall service, in lieu of continuous hydrogen or oxygen monitoring.

be analyzed to verify that it contains less than or equal to 4%

the hydrogen content shall be verified weekly to be less than f

hydrogen by volume.

or equal to 4 % by volume.

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d.

With the requirements of the above specifications not in the event that the hydrogen content cannot be verified, satisfied, restore the recombiner system to within operating operation of this system may continue for up to 14 tiays.

h specifications or suspend use of the charcoal treatment y

l system within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.

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4 Amendment No. 93,127,187, 203, 233 j

33 i!

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JAFNPP TABLE 3.10-2 MINIMUM TEST AND CALIBRATION FREQUENCY FOR RADIATION MONITORING SYSTEMS'd Instrument instrument Channel Instrument Channel Logic System Instrument Channels Check" Functional Test" Calibration Function Test'*

Main Stack Exhaust Monitors and Recorders Daily Quarterly Quarterly Refuel Area Exhaust Monitors and Recorders Daily Quarterly Quarterly Reactor Building Area Exhaust Monitors, Recorders, Daily Quarterly Quarterly Semiannually and Isolation Turbine Building Exhaust Monitors and Recorders Daily Quarterly Quarterly Radweste Building Exhaust Monitors and Recorders Daily Quarterly Quarterly SJAE Radiation Monitors /Offgas Line Isolation Daily Quarterly Quarterly Semiannually Main Control Room Ventilation Monitor Daily Quarterly Quarterly W

Once per Mechanical Vacuum Pump Isolation 24 Months Liquid Radwaste Discharge Monitor /

Daily When Quarterly Quarterly Semiannually f

Isolation'd"'d'8 Discharging Liquid Redwaste Discharge Flow Rate Daily Quarterly Once per Measuring Devices" 18 Months Liquid Radwaste Discharge Radioactivity Daily Quarterly Once per Recorder '8 18 Months Normal Service Water Effluent Daily Quarterly Quarterly I

SBGTS Actuation Semiannually Amendment No. 93, 127, 213, 233 38 m____

m_.__ _ _ __ _ - _ _

m_.--

JAFNPP i

j NOTES FOR TABLE 3.10-2 (a)

Functional tests, calibrations and instrument checks need not be performed when

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these instruments are not required to be operable or are tripped.

(b) instrument checks shall be performed at least once per day during these periods when the instruments are required to be operable.

(c)

A source check shall be performed prior to each release.

(d)

Liquid radwaste effluent line instrumentation surveillance requirements need not be i

performed when the instruments are not required as the result of the discharge path not being utilized.

(e)

An instrument channel calibration shall be performed with known radioactive sources standardized on plant equipment which has been calibrated with NBS traceable j

standards.

(f)

Simulated automatic actuation shal! be performed once per 24 months. Where possible, alllogic system functional tests will be performed using the test jacks.

(g)

Refer to Appendix A for instrument chanr'ol functional test and instrument channel

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calibration requirements (Table 4.2-1). These requirements are performed as part of main steam high radiation monitor surveillances.

(h)

The logic system functional tests shallinclude a calibration of time delay relays and timers necessary for proper functioning of the trip systems.

(i)

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 simulated electrical signals once every three months.

1 d

d Amendment No. 93, 207, 233 39