ML20072P446
| ML20072P446 | |
| Person / Time | |
|---|---|
| Site: | FitzPatrick  |
| Issue date: | 08/31/1994 |
| From: | Michael Case Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML20072P450 | List: |
| References | |
| NUDOCS 9409070286 | |
| Download: ML20072P446 (19) | |
Text
.
~_
~
+
goa"%q f,
UNITED STATES f ' ' W (,j NUCLEAR REGULATORY COMMISSION
]
's WASHINGTON, D.C. 20556-0001 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. 216 License No. DPR-59 1.
The Nuclear Regulatory Commission (the Commission) has found that:
J l
A.
The application for amendment by Power Authority of the State of New York (the licensee) dated June 17, 1993, as supplemented February 24, 1994, and June 13, 1994, 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 (1) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D.
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 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 S 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:
9409070286 940831 PDR ADOCK 05000333 P
(2) Technical Soecifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No.216, are hereby incorporated in the license.
The licensee shall operate the facility in accordance with 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 e e i
5,V{plo 4 [l.'
-,3-
/.
Michael J. Ca/se, Acting Director Project Directorate I-1 Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation j
Attachment:
Changes to the Technical Specifications i
Date of Issuance: August 31, 1994 l
ATTACHMENT TO LICENSE AMENDMENT NO. 216 FACILITY OPERATING LICENSE NO. DPR-52 D0LKET NO. 50-333 Revise Appendix A as fdllows:"
Remove Paaes Insert Paaes i
i y
v 51 51 53 54 54 59 59 60 60 60a 77f 779 77h 771 77j 77k 771 77m
JAFNPP TECHNICAL SPECIFICATIONS TABLE OF CONTENTS P_aga 1.0 Definitions 1
LlMITING SAFETY SAFETY LIMITS SYSTEM SETTINGS 1.1 Fuel Cladding Integrity 2.1 7
1.2 Reactor Coolant System 2.2 27 SURVEILLANCE LIMITING CONDITIONS FOR OPERATION REQUIREMENTS 3.0 General 4.0 30
^
3.1 Reactor Protection System 4.1 30f 3.2 instrumentation 4.2 49 A.
Primary Containment isolation Functions A.
49 B.
Core and Containment Cooling Systems -
B.
50 Initiation and Control C.
Control Rod Block Actuation C.
50 D.
Radiation Monitoring Systems - Isolation D.
50 and Initiation Functions E.
Drywell Leak Detection E.
53 F.
DELETED F.
53 G.
Recirculation Pump Trip G.
53 H.
Accident Monitoring Instrumentation H.
53 1.
4kV Emergency Bus Undervoltage Trip l.
53 J.
Remote Shutdown Capability J.
54 3.3 Reactivity Control 4.3 88 A.
Reactivity Limitations A.
88 B.
Control Rods B.
91 C.
Scram Insertion Times C.
95 D.
Reactivity Anomalies D.
96 3.4 Standby Liquid Control System 4.4 105 A.
Normal Operation A.
105 B.
Operation With Inoperable Components B.
106 C.
Sodium Pentaborate Solution C.
107 3.5 Core and Containment Cooling Systems 4.5 112 A.
Core Spray and LPCI Systems A.
112 B.
Containment Cooling Mode of the RHR B.
115 System C.
HPCI System C.
117 D.
Automatic Depressurization System (ADS)
D.
119 E.
Reactor Core Isolation Cooling (RCIC)
E.
121 System Amendment No. JRJ36, J34', F M 216 i
-e--
~
l LIST OF TABJJS Table Iille Eage 3.1-1 Reactor Protection System (Scram) Instrumentation Requirement 41 3.1-2 Reactor Protection System Instrumentation Response Times 43a 4.1-1 Reactor Protection System (Scram) Instrument Functional Tests 44 4.1-2 Reactor Protection System (Scram) Instrument Calibration 46 J
3.2-1 Instrumentation that initiates Primary Containment Isolation 64 3.2-2 Instrumentation that initiates or Controls the Core and Containment 66 Cooling Systems 3.2-3 Instrumentation that initiates Control Rod Blocks 72 3.2-4 (DELETED) 74 3.2-5 Instrumentation that Monitors Leakage Detection Inside the Drywell 75 3.2-6 (DELETED) 76 3.2-7 Instrumentation that Initiates Recirculation Pump Trip 77 3.2-8 Accident Monitoring Instrumentation 77a 3.2-9 Primary Containment isolation System Actuation Instrumentation 77e Response Times 3.2 10 Remote Shutdown Capability Instrumentation and Controls 77f l
4.2-1 Minimum Test and Calibration Frequency for PCIS 78 4.2-2 Minimum Test and Calibration Frequency for Core and Containment 79 Cooling Systems 1
4.2-3 Minimum Test and Calibration Frequency for Control Rod Blocks 81 Actuation 4.2-4 (DELETED) 82 4.2-5 Minimum Test and Calibration Frequency for Drywell Leak Detection 83 4.2-6 (DELETED) l 4.2-7 Minimum Test and Calibration Frequency for Recirculation Pump Trip 85 l
Amendment No.,36, A 136;yiW,,1pa', j,96', 216 v
45 m
JAFNPP PAGES 51-52 INTENTIONALLY DELETED l
o Amendment 216 51
JAFNPP 3.2 (cont'd) 4.2 (cont'd) l E.
Drvwell Leak Detection E.
Drvwe!! Leak Detection The limiting conditions of operation for the instrumentation that Instrumentation shall be calibrated and checked as indicated in monitors drywell leak detection are given in Table 3.2-5.
Table 4.2-5.
F.
(Deleted)
F.
(Deleted)
G.
Recirculation Pumo Tric G.
Recirculation Pomo Trio The limiting conditions for operation for the instrumentation that Instrumentation shall be functionally tested and calibrated as trip (s) the recirculation pumps as a means of limiting the indicated in Table 4.2-7.
consequences of a failure to scram during an anticipated transient are given in Table 3.2-7.
System logic shall be functionally tested as indicated in Table 4.2-7.
4, H.
Accident Monitorina Instrumentation H.
Accident Monitorino Instrumentation The limiting conditions for operation of the instrumentation that Instrumentation shall be demonstrated operable by performance provides accident monitoring are given in Table 3.2-8.
of a channel check and channel calibration as indicated in Table 4.2-8.
l.
4kv Emergency Bus Undervoltaae Trio I.
Not Used The limiting conditions for operation for the instrumentation that prevents damage to electrical equipment or circuits as a result of either a degraded or loss-of-voltage condition on the emergency electrical buses are given in Table 3.2-2.
Amendment No. jMC 216 53
~
JAFNPP 3.2 (cont'd) 4.2 (cont'd)
J.
Remote Shutdown Caoability J.
Remote Shutdown Caoability 1.
The remote shutdown instrument and control circuits in instruments and controls shall be tested and calibrated as Table 3.2-10 shall be operable in the Run and Startup! Hot indicated in Table 3.2-10.
Standby modes.
2.
With one or more required instrument circuits inoperable:
f
- a. restore the required instrument circuit to operable status within 30 days, or
- b. establish an afternate method of monitoring the parameter within 30 days and restore the required instrument circuit to operable status within 90 days, or
- c. be in hot shutdown within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
3.
With one or more required control circuits inoperable:
- a. p' lace the component actuated by that control circuit in the safe shaidown configuration, or
- b. restore the required control circuit to operable
, status within 30 days, or
- c. be in hot shutdown within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
4.
Specification 3.2.J does not apply if the component actuated by a required control circuit is inoperable.
5.
The provisions of Specification 3.0.D are not applicable.
Amendment No. 406,.137,38f,.496, 216 54
JAFNPP 3.2 BASES (cont'd) the specification are adequate to assure the above criteria are (3) providing information to the operators that will enable them to met. The specification preserves the effectiveness of the system determine the potential for a breach of the barrier to radioactivity during periods of maintenance, testing, or calibration, and also release and if a barrier has been breached; (4) furnishing data minimizes the risk of inadvertent operation; i.e., only one for deciding on the need to take unplanned action if an automatic instrument channel out of service.
or manually initiated safety system is not functioning properly or the plant is not responding properly to the safety systems in Flow integrators are used to record the integrated flow of liquid operation; and (5) allowing for early indication of the need to from the drywell sumps. The leak rate is calculated by dividing initiate action necessary to protect the public and for an estimate the integrated volume pumped out of the sumps by the time of the magnitude of any problem. This instrumentation conforms between sump pump operations. The resultant leak rate value, with the acceptance criteria of NUREG-0737, NUREG-0578, and which is expressed in gallons per minute, is compared to the NRC Generic Letter 83-36 and includes Regulatory Guide 1.97, acceptance criterion specified in Specification 3.6.D.
Revision 2 Type A variables.
For each parameter monitored, as listed in Table 3.2-8, by The Emtsgency Bus Undervoltage Trip System transfers the 4 kv comparing the reading of each channel to the reading on emergency electrical buses to the Emergency Diesel Generators redundant or related instrument channel a near continuous in the event an undervoltage condition is detected. The system surveillance of instrument performance is available.
has two levels of protection: (1) degraded voltage protection, and (2) loss-of-voltage protection. Degraded voltage protection s
The recirculation pump trip has been added at the suggestion of prevents a sustained low voltage condition from damaging ACRS as a means of limiting the consequences of the unlikely safety-related equipment. The degraded voltage protection has occurrence of a. failure to scram during an anticipated transient.
two time delays. A shoit time delay coincident with a The response of the plant to this postulated event falls within the loss-of-coolant accident (LOCA) and a longer time delay to allow envelope c' 2dv events given in General Electric Company normal plant evolutions without unnecessarily starting the Topical; A MDO-10349, dated March,1971.
Emergency Diesel Generators. The loss-of-voltage protection prevents a more severe voltage drop from causing a long term Accident monitoring instrumentation provides additional interruption of power. Time delays are included in the system to information which is helpful to the operator in assessing plant prevent inadvertent transfers due to spurious voltage decreases.
conditions following an accident by (1) providing information Therefore, both the duration and severity of the voltage drop are needed to permit the operators to take preplanned manual sensed by the Emergency Bus Undervoltage Trip System.
actions to accomplish safe plant shutdown; (2) determining whether systems are performing their intended functions; Amendment No. 38',ps, p(,Jaf, 216 59
JPP 3.2 BASES (cont'd)
The remote / alternate shutdown capability at FitzPatrick is and transfer switches will have to be operated locally at the provided by a remote shutdown panel (25RSP) and five alternate switchgear, motor control centers, or other local stations.
safe shutdown panels (25 ASP-1,25 ASP-2,25 ASP-3,25 ASP-4, and 25 ASP-5). These panels are used in conjunction with the Operability of the remote shutdown instrumentation and control Automatic Depressurization System (ADS) relief valve control functions ensure that there is sufficient information available on panel (02 ADS-71) adjacent to 25RSP, the emergency diesel selected plant parameters to place and maintain the plant in a generator (B & D) control panels (93EGP-B and 93EGP-D) shutdown condition should the control room become opposite 25 ASP-3, the reactor building vent and cooling panel inaccessible. The instrumentation and controls installed on the (66HV-38) near 25 ASP-1, instrument rack 25-51, and instrument remote / alternate shutdown panels are listed in Table 3.2-10.
rack 25-6 opposite 25RSP. All of these locations are linked by This table does not include the isolation / transfer switches for the communications and are provided with emergency lighting.
control functions on the remote / alternate shutdown panels. As specified in Surveillance Requirement 4.2.J, the operability of the This Remote Shutdown capability provides the necessary transfer switches will be demonstrated when the remote / alternate instrumentation and controls to place and maintain the plant in a shutdown control functions are tested.
safe shutdown condition from a location other than the control room in the event the control room becomes inaccessible due to The remote shutdown instruments and control circuits covared by a fire or other reason.
this LCO do not need to be energized to be considered operable.
This LCO is intended to ensure that the instruments and control This specification ensures the operability of the remote shutdown circuits will be operable if plant conditions require the use of the instrumentation and control circuits. Operability of components remote shutdown capability. Performance of the instrument such as pumps and valves, which are controlled from these check once every 31 days ensures that a gross failure of panels,is covered by other specifications. This specification instrumentation has not occurred and is intended to ensure that does not impose conditions on plant operation which are more the instrumentation continues to operate properly between each restrictive than those already imposed by other specifications.
instrument channel calibration.
For example, Specification 3.7.D includes provisions for continued operation with one or more containment isolation As specified in the surveillance requirements, an instrument valves inoperable. The 30 day time limitation imposed by 3.2.J check is only required for those instruments that are normally would not apply in this situation, provided that the actions taken energized. Performance of this surveillance provides assurance for the inoperable valve (s) to satisfy 3.7.D are also consistent that undetected outright instrument failure is limited to 31 days.
with the safety function (s) required for fire protection.
The surveillance frequency is based upon plant operating i
experience which indicates that channel failure is rare.
Not all instruments, controls, and necessary transfer switches are located at the remote / alternate shutdown panels. Some controls Amendment No. 306,120, M O,JEM,.1&r, 216 60
4 JAFNPP 3.2 BASES (cont'd) l Surveillance Requirement 4.2.J requires that each remote l
shutdown transfer / isolation switch and control circu t be i
l 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 panels listed in Table 3.2-10 and on panels 25 ASP-4, 25 ASP-5, and 66HV-38. This demonstration is performed from the remote shutdown panel and locally, as appropriate. This will 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.
5 r
I i
i i
Amendment No.- 216 60a
. ~
JAFNPP TABLE 3.2-10 REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS
[ Refer to Notes on Page 77m]
INSTRUMENT PANEL OR OR CONTROL LOCATION 1.
RHR Service Water Flow (Loop B) 25RSP (10F1-134) 2.
RHR Service Water Pump Control 25RSP (10P-18) 3.
RHR Service Water Heat Exchanger Outlet Valve 25RSP Control (10MOV-898) 4.
RHR Service Water to RHR Cross-Tie Valve 25 ASP-1 Control (10MOV-148B) 5.
RHR Service Water to RHR Cross-Tie Valve 25 ASP-1 Control (10MOV-149B) d 6.
RHR Flow (Loop B) 25RSP (10F1-133) 7.
RHR Discharge Pressure (Pump D) 25RSP (10PI-279) 8.
RHR Pump Control 25RSP (10P-3D) 9.-
RHR Heat Exchanger Bypass Valve Control 25RSP (10MOV-66B)
Amendment No. 216 77f
4 l
JAFNPP TABLE 3.2-10 (cont'd) l REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS
[ Refer to Notes on Page 77m]
INSTRUMENT PANEL OR OR CONTROL LOCATION 10.
RHR Inboard injection Valve Control 25RSP (10MOV-25B) 11.
RHR Heat Exchanger Steam inlet Valve Control 25 ASP 1 (10MOV-70B) 12.
RHR Heat Exchanger Vent Valve Control 25 ASP-1 (10MOV-1668) 13.
RHR Heat Exchanger Outlet Valve Control 25 ASP-1 (10MOV-128) 14.
RHR Pump D Torus Suction Valve Control 25 ASP-2
^
(10MOV-13D) 15.
RHR Pump D Shutdown Cooling Suction Valve 25 ASP-2 Control (10MOV-15D) i 16.
RHR Pump P-3B Minimum Flow Valve Control 25 ASP-2 (10MOV-16B) 17.
RHR Heat Exchanger inlet Valve Control 25 ASP-2 (10MOV-658) 18.
RHR Outboard injection Valve Control 25 ASP-2 (10MOV-27B)
Amendment No. 216 779
f JAFNPP t
TABLE 3.2-10 (cont'd)
REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS
[ Refer to Notes on Page 77m]
INSTRUMENT PANEL OR OR CONTROL LOCATION 19.
RHR Heat Exchanger Discharge to Torus Valve 25 ASP-2 Control (10MOV-218) 20.
Torus Cooling isolation Valve Control 25 ASP-2 (10MOV-39B) 21.
DW Spray Outboard Valve Control 25 ASP-3 (10MOV-268) 22.
ADS & Safety Relief Valve A Control 02 ADS-71 (02RV-71 A) 5 23.
ADS & Safety Relief Valve B Control 02 ADS-71 (02RV-71B) 24.
ADS & Safety Relief Valve C Control 02 ADS-71 (02RV-71C) 25.
ADS & Safety Relief Va'.ve D Control 02 ADS-71 (02RV-71D) 26.
ADS & Safety Relief Valve E Control 02 ADS-71 (02RV-71E) 27.
ADS & Safety Relief Valve G Control 02 ADS-71 (02RV-71G)
Amendment No. 216 77h
i JAFNPP L
TABLE 3.2-10 (cont'd)
REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS
[ Refer to Notes on Page 77m]
INSTRUMENT PANEL OR OR CONTROL LOCATION 28.
ADS & Safety Relief Valve H Control 02 ADS-71 (02RV-71H) 29.
Safety Relief Valve F Control 02 ADS-71 (02RV-71F) 30.
Safety Relief Valve J Control 02 ADS-71 (02RV-71J) 31.
Safety Relief Valve K Control 02 ADS-71 (02RV-71K) 32.
Safety Relief Valve L Control 02 ADS-71 (02RV-71L) t 33.
Main Steam Line Drain Outboard Isolation Valve 25 ASP-2
[
Control (29MOV-77) 34.
Drywell Temperature 25RSP (68TI-115) 35.
Torus Water Temperature 25RSP (27TI-101) l l
36.
Torus Water Level 25RSP (23Ll-204) l Amendment No. 216 I
77i
~
l JAFNPP TABLE 3.2-10 (cont'd)
REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS
[ Refer to Notes on Page 77m]
INSTRUMENT PANEL OR OR CONTROL LOCATION 37.
Reactor Vessel Pressure Rack 25-6 (02-3PI-608) 38.
Reactor Vessel Water Level Rack 25-6 (02-3Li-58A) 39.
Reactor Vessel Water Level Rack 25-51 (02-3LI-93) 40.
HPCI Steam Supply Outboard Isolation Valve 25RSP Control (23MOV-16) 41.
HPCI Outboard Isolation Bypass Valve Control 25 ASP-2 (23MOV 60) 42.
HPCI Minimum Flow Valve Control 25 ASP-2 (23MOV-25) 43.
CAD B Train inlet Valve Control 25RSP (27AOV-1268) 44.
Nitrogen Instrument Header Isolation Valve 25RSP Control (27AOV-1298) 45.
Reactor Water Cleanup Outboard Isolation Valve 25 ASP-2 Control (12MOV-18)
Amendment No. 216 77j
~~
JAFNPP TABLE 3.2-10 (cont'd)
REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS
[ Refer to Notes on Page 77m]
INSTRUMENT PANEL OR OR CONTROL LOCATION 46.
Emergency Service Water Pump B Control 25 ASP-3 (46P-28) 47.
ESW Loop B Supply Header Isolation Valve 25 ASP-3 Control (46MOV-1018) 48.
ESW Pump B Test Valve Control 25 ASP-3 (46MOV-1028) 49.
Bus 11600 Supply Breaker Control 25RSP (71-11602) s 50.
EDG B & EDG D Tie Breaker Control 25 ASP-3 (71-10604) 51.
Bus 10400-10600 Tie Breaker Control 25 ASP-3 (71-10614) 52.
Unit Substation L16 & L26 Feeder Breaker 25 ASP-3 Control (71-10660) 53.
Bus 12600 Supply Breaker Control 25 ASP-3 (71-12602) 54.
Breaker 71-10614 Synchronizing Check Control 25 ASP-3 55.
EDG B Control Room Metering Check Control 25 ASP-3 Amendment No. 216 77k
T' l
JAFNPP TABLE 3.2-10 (cont'd) i REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS l
[ Refer to Notes on Page 77m]
INSTRUMENT PANEL OR OR CONTROL LOCATION 56.
EDG B Engine Start /Stop Control 25 ASP-3 57.
EDG D Control Room Metering Check Control 25 ASP-3 58.
EDG D Engine Start /Stop Control 25 ASP-3 59.
EDG B Governor Switch 93EGP-B 60.
EDG B Synchronizing Switch 93EGP-B 61.
EDG B Load Breaker Control (71-10602) 93EGP-B
+
62.
EDG B Motor Control 93EGP-B 63.
EDG B Frequency Meter (93FM-1B) 93EGP-B 64.
EDG B Voltage Control 93EGP-B 65.
EDG B Emergency Bus Meter (93VM-600-18) 93EGP-B
^
66.
EDG B Incoming Bus Meter (93VM-128) 93EGP-B 67.
EDG B Running Bus Meter (93VM-11B) 93EGP-B 68.
EDG D Governor Switch 93EGP-D 69.
EDG D Synchronizing Switch 93EGP-D Amendment No. 216 7 71
's JAFNPP TABLE 3.2-10 (cont'd)
REMOTE SHUTDOWN CAPABILITY INSTRUMENTATION AND CONTROLS INSTRUMENT PANEL OR OR CONTROL LOCATION 70.
EDG D Load Breaker Control (71-10612) 93EGP-D 71.
EDG D Motor Control 93EGP-D 72.
EDG D Frequency Meter (93FM-1D) 93EGP-D 73.
EDG D Voltage Control 93EGP-D 74.
EDG D Emergency Bus Meter (93VM-600-1D) 93EGP-D 75.
EDG D incoming Bus Meter (93VM-12D) 93EGP-D 76.
EDG D Running Bus Meter (93VM-11D) 93EGP-D
^
NOTES FOR TABLE 3.2-10 A.
Minimum required number of divisions for all instruments and controls listed is 1.
B.
Perform instrument check for each required instrument that is normally energized once per 31 days.
The normally energized instruments are identified in line items 1, 6, 7, 34, 35, 36, 37, 38, and 39.
C.
Perform instrument calibration for each required instrumention channel once per operating cycle.
D.
Demonstrate each required control circuit and transfer / isolation switch is capable of performing the intended function once per operating cycle.
Amendment No. 216 77m-
.-