ML17157C443
| ML17157C443 | |
| Person / Time | |
|---|---|
| Site: | Susquehanna  |
| Issue date: | 08/04/1993 |
| From: | Boyle M Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML17157C444 | List: |
| References | |
| NUDOCS 9308250405 | |
| Download: ML17157C443 (25) | |
Text
~ gP,R RK00 (4
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~c 0O UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 2055&0001 PENNSYLVANIA POWER
& LIGHT COMPANY ALLEGHENY ELECTRIC COOPERATIVE INC.
DOCKET NO. 50-387 SUS UEHANNA STEAM ELECTRIC STATION UNIT 1 MENDMENT TO FACILITY OPERATING LICENSE Amendment No. 127 License No.
NPF-14 1.
The Nuclear Regulatory Commission (the Commission or the NRC) having found that:
A.
The application for the amendment filed by the Pennsylvania Power Light Company, dated January 14,
- 1991, as supplemented by letter dated March 3,
- 1992, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's 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 regulations of the Commission; C.
There is reasonable assurance:
(i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I; 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.
9308250405 930804 PDR ADOCK 05000387
'~P, PDR
<<1/ I
2.
Accordingly, the license is amended by changes to the Technical Specifica-tions as indicated in the attachment to this license amendment and paragraph 2.C.(2) of the Facility Operating License No.
NPF-14 is hereby amended to read as follows:
(2)
Technical S ecifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No.
127 and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the license.
PPKL shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
3.
This license amendment is effective as of its date of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION
Attachment:
Changes to the Technical Specifications Date of Issuance:
.August 4, 1993 ichael L. Boyl Acting Director Project Directorate I-2 Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation
ATTACHMENT TO LICENSE AMENDMENT NO.
FACILITY OPERATING LICENSE NO.
NPF-14 DOCKET NO. 50-387 Replace the following pages of the Appendix A Technical Specifications with enclosed pages.
The revised pages are identified by Amendment number and contain vertical lines indicating the area of change.
The overleaf pages are provided to maintain document completeness.*
REMOVE 3/4 3-15 3/4 3-16 3/4 3-19 3/4 3-20 3/4 3-21 3/4 3-22 3/4 3-25 3/4 3-26 INSERT 3/4 3-15 3/4 3-16*
3/4 3-19*
3/4 3-20 3/4 3-21*
3/4 3-22 3/4 3-25*
3/4 3-26
U)C (hDCmx ZZ I
CZ TABLE 3.3.2-1 (Continued)
ISOLATION ACTUATION INSTRUMENTATION Trip Function Isolation Signal(s)'"
Minimum Operable Channels Per Trip System'bI Applicable Operational Condition ActIon 7.
RHR SYSTEM SHUTDOWN COOLING/HEAD SPRAY MODE ISOLATION a.
Reactor Vessel Water Level - Low, Level 3 b.
Reactor Vessel (RHR Cut-in Permissive)
Pressure
- High c.
RHR Flow - High d.
ManuaI In'tiation e.
Drywell Pressure
- High UB NA 1,2,3 1, 2. 3 1,2,3 1,2,3 1,2,3 26 26 26 24 26 3
Z0
~0
ACTION 20 ACTION 21 ACTION 22 ACTION 23 ACTION 24-ACTION 25 ACTION 26 TABLE 3.3.2-1 (Continued)
ISOLATION ACTUATION INSTRUMENTATION ACTION STATEMENTS Be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLO SHUTDOWN within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Be in at least STARTUP with the associated isolation valves closed within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Be in at least STARTUP within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
Close the affected system isolation valves within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and declare the affected system inoperable.
Restore the manual initiation function to OPERABLE status within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or close the affected system isolation valves within the next hour and declare the affected system inoperable or be in at least 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 /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Establish SECONDARY CONTAINMENT INTEGRITY with the standby gas treatment system operating within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
Lock the affected system isolation valves closed within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and declare the affected system inoperable.
NOTES When handling irradiated fuel in the secondary containment and during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
Actuates dampers shown in Table 3.6.5.2-1.
When VENTING or PURGING the drywell per. Specification 3.11.2.8.
(a)
See Specification 3.6.3, Table 3.6.3-1 for valves which are actuated by these isolation signals.
(b)
A channel may be placed in an inoperable status for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for required surveillance without placing the channel or trip system in the tripped condition provided at least one other OPERABLE channel in the same trip system is monitoring that parameter.
In addition, for the HPCI system and RCIC system isolation, provided that the redundant isolation valve, inboard or outboard, as applicable, in each line is OPERABLE and all required actuation instrumentation for that va1ve is OPERABLE, one channel may be placed in an inoperable status for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for required surveillance without placing the channel or trip system in
'the tripped condition.
SUSQUEHANNA - UNIT 1 3/4 3-16 Amendment No. 36
TABLE 3. 3. 2-2 (Continued)
ISOLA I lON ACTIJATION INS IRUHENTATION SETPOINTS m
1 RIP FUNCTION REAClOR CORE ISOLATION COOLING SYSTEH TRIP SElPOINl ISOLATION Contirrued)
ALLOWABLE VALUE g
h.
RCIC Equipment Room Temperature - High RCIC Equipment Room b, Temperature
- High RCIC Pipe Routing Area Temperature - High RCIC Pipe Routing Area 6 Temperature - High RCIC Emergency Area Cooler Temperature
- High Hanual Initiation Orywell Pressure
- High
( 1670FP<
< 89 F
167 F
89QFAP
< 147'F NA
<1.22 psig
(
1740 FQ*
<98 F*
174~FNlhr 980FH"
< 154 F
NA
<1.88 psig 6.
HIGH PRESSURE COOLANT INJECTION SYSTEH ISOLATION
~o rn
+0 +
~o o
~cr n
~re o
~O 0
py e
Q w g+
~ID fD
~gQ
~ ~
EO n
a.
b..
e.
HPCI Steam Line Flow - High HPCI Steam Supply Pressure Low ll,"-'"I Turbine Exhaust Diaplrragm Pressure
- High HPCI Equipment Room Temperature
- High HPCI Equipment Room d, Temperature High llPCI Emergency Area Cooler Temperat.ure
- High HPCI Pipe Rout.ing Area Temperature
- Higlr
< 350 inches HzO 104 psig 10 psig 167 F
(89F 14?
F 16?"F
< 367 inches H~O 90 psig
< 20 psig
< 174'F
<98F
<154 F
1?4oFM "llrese tr ip J'rrrrcliorrs rreed rrot be Ol'LRABLl. lrom October 19, 1989 to January 19, 199tJ.
0)C (00CmZ Zz I
Cz TABLE3.3.2-2 (Continued)
ISOLATION ACTUATIONINSTRUMENTATIONSETPOINTS 4l 6) hJO TRIP FUNCTION h.
HPCI Pipe Routing Area h Temperature
- High i.
Manual Initiation j.
Drywell Pressure
- High 7.
RHR SYSTEM SHUTDOWN COOLING EAD SPRAY MODE ISOLATION a.
Reactor Vessel Water Level - Low, Level 3 b.
Reactor Vessel (RHR Cut-in Permissive)
Pressure
- High c.
RHR Flow - High d.
Manual Initiation e.
Drywell Pressure
- High TRIP SETPOINT 89oF¹¹ NA 6 1.72 psig h 13.0 inches' 98 psig 6 25,000 gpm NA 6 1.72 psig ALLOWABLEVALUE 6 98~F¹¹ NA 6 1.88 psig h 11.5 inches 6 108 psig c 26,000 gpm NA
~ 1.88 psig See Bases Figure B 3/4 3-1.
¹ Lower setpoints for TSH-G33-1N600 E, F and TDSH-G33-1N602 E, F.
¹¹ 15 minute time delay.
This trip function need not be OPERABLE from October 19, 1989 to January 19, 1990.
z0
TRIP
<aP(')
<1 pag<gp(a)aa
< i (
<10~
~
<,0( )
<10(a) b.
C d.
e.
TABLE 3.3.2-3 i
ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME e
FUNCTION
RESPONSE
TIME Seconds 0
PRIMARY CONTAINMENT ISOLATION a.
Reacto~ Vessel Water Level 1)
Low, Level 3
2)
Low Low, Level 2 3)
Low Low Low, Level 1 Drywell Pressure - High Manual Initiation SGTS Exhaust Radiation - High Main Steam Line Radiation - High( )
2.
3.
SECONDARY CONTAINMENT ISOLATION a.
Reacto~ Vessel Water Level-Low Low, Level 2
b.
Drywell Pressure - High c.
Refuel Floor High Exhaust Duct Radiation - High( }
d.
Railroad Accass Shag Exhaust Duct Radiation -
High'.
Refuel Floor Mall Exhaust Duct Radiation -High f.
Manual Initiation MAIN STEAM LINE ISOLATION a.
Reactor Vessel Water Level-Low ~ Low, Level 1 b.
Main Steam Line Radiation -
High'"'.
Main Steal Line Pressure
- Low d.
. Main Steam Line Flow-High e.
Condenser Vacuum - Low f.
Reacto~ Building Main Steam Line. Tunnel Temperature - High g.
Rea~ Building Hain Steam Line Tunnel h Temperature - High h.
Manual Initiation Turbine Building Hain Steam Line Tunnel Temperature - High
<1p(a) gp(a3
<10
<10(a)
-1p(a)
Ra
<10(a)
<1 pa/<yp(
)alt:
QA/<M(a)*A
<P. S</<ZO(a)*
Ha 4.
REACTOR MATER CLEANUP SYSTEM ISOLATION, 5.
a.
RWCU h Flow - High b.
RWCU Area Temperature - High c.
RWCU Area Ventilation Temperature hT - High d.
SLCS Initiation e.
Reactor Vessel Water Level - Low Low, Level 2
f.
RWCU Flow - High g.
Hanual Initiation REACTOR CORE ISOLATION COOLING SYSTEM ISOLATION a.
RCIC Steam Line h Pressure - High b.
RCIC Steam Supply Pressure - Low c.
RCIC Turbine Exhaust-Diaphragm Pressure - High d.
RCIC Equipment Room Temperature - High 10(a)AF Ra NA
<1p(a)
RA NA
<~p(a}tire M(a}
Q, NA SUSQUEHANNA - UNIT 1 3/4 3-21
~
Amendment No. 38
~~~g ~~~M
TABLE 3.3.2-3 (Continued)
ISOLATION SYSTEM INSTRUMENTATIONRESPONSE TIME TRIP FUNCTION RESPONSE'. TIME (seconds)¹'"
e.
f.
g.
h.
L I ~
RCIC Equipment Room b, Temperature - High RCIC Pipe Routing Area Temperature
- High RCIC Pipe Routing Area 6 Temperature
- High RCIC Emergency Area Cooler Temperature
- High Manual Initiation Drywell Pressure
- High NA NA NA NA NA
<10'>>
6.
HIGH PRESSURE COOLANT INJECTION SYSTEM ISOLATION a.
b.
C.
d.
e.
f.
9 h.
I.
I HPCI Steam Flow - High HPCI Steam Supply Pressure
- Low HPCI Turbine Exhaust Diaphragm Pressure
- High HPCI Equipment Room Temperature
- High HPCI Equipment Room b, Temperature
- High HPCI Emergency Area Cooler Temperature
- High HPCI Pipe Routing Area Temperature
- High HPCI Pipe Routing Area 6 Temperature
- High Manual Initiation Drywell Pressure
- High
~ 1 0(>>¹¹¹¹ C10I>>
NA NA NA NA NA NA NA s10'>>
7.
RHR SYSTEM SHUTDOWN COOLING/HEAD SPRAY MODE ISOLATION a0 b.
C.
d.
e.
Reactor Vessel Water Level - Low, Level 3 Reactor Vessel (RHR Cut-In Permissive) Pressure
- High RHR Flow - High Manual Initiation Drywell Press'ure
- High s10'>>
NA NA NA
~ 10I'I (a)
(b)
¹¹
¹¹¹
¹¹¹¹ The isolation system instrumentation response time shall be measured and recorded as a part of the ISOLATION SYSTEM RESPONSE TIME. Isolation system instrumentation response time specified includes the delay for diesel generator starting assumed in the accident analysis.
Radiation detectors are exempt from response time testing.
Response time shall be measured from detector output or the input of the first electronic component in the channel.
Isolation system instrumentation response time for MSIVs only.
No diesel generator delays assumed for MSIV Valves.
Isolation system instrumentation response time for associated valves except MSIVs.
Isolation system instrumentation response time specified for the Trip Function actuating each valve group shall be added to isolation time shown in Table 3.6.3-1 and 3.6.5.2-1 for valves in each valve group to obtain ISOLATION SYSTEM RESPONSE TIME for each valve.
With time delay of 45 seconds.
With time delay of 3 seconds.
With time delay of 3 seconds.
SUSQUEHANNA - UNIT 1 3/4 3-22 Amendment No. N,>27
AD m
TABLE 4.3.2.1-1 (Continued)
ISOLATION ACTUATION INSTRUHENTATION SURVEILLANCE RE UIREHENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICH TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE RE UIRED 5.
REACTOR CORE ISOLATION COOLING SYSTEH ISOLATION a.
g.
-RCIC Pipe Routing Area h Temperature
- High RCIC Steam Line h Pressure
- High RCIC Steam Supply Pressure-Low RCIC Turbine Exhaust Diaphragm Pressure
- High RCIC Equipment Room Temperature
- High RCIC Equipment Room h Temperature High RCIC Pipe Routing Area Temperat.ure - High NA NA NA NA NA NA 1,2,3 1, 2, 3
1,2,3 1,2,3 1, 2, 3" 1,2,3 1, 2, 3*
~OPl R >+M D O iD o.cr n 3 ID c+
A) "S ~
C et MAI ED
~v Q lQ v
WC+
4O fO gQ ~ ~
ED Pln 6.
h.
RCIC Emergency Area Cooler Temperature - High NA i.
Hanual Initiation NA j.
Drywell Pressure
- High NA HIGH PRESSURE COOLANT INJECTION SYSTEH ISOLA110N Q
NA R
a.
b.
HPCI St.earn Line h Pressure
- High HPCI Steam Supply Pressure Low HPCI Turbine Exhaust.
Diaphragm Pressure
- High "lhese trip t*ui>ctions need not. be Ol'ERABLE from October 19, 1989 to January 19, 1990.
1,2,3 1,2,3 I, 2, 3
I, 2, 3
1,2,3 I, 2, 3
TABLE4.3.2.1-1 (Contjnued j ISOLATION ACTUATIONINSTRUMENTATIONSURVEILLANCEREQUIREMENTS x
Z TRIP FUNCTION CHANNEL CHECK CHANNEL FUNCTIONAL TEST CHANNEL CALIBRATION OPERATIONAL CONDITIONS FOR WHICH SURVEILLANCE REQUIRED Cz HIGH PRESSURE COOLANT INJECTION SYSTEM ISOLATION IContinued) d.
HPCI Equipment Room Temperature - High e.
HPCI Equipment Room b Temperature
- High f.
HPCI Emergency Area Cooler Temperature - High g.
HPCI Pipe Routing Area Temperature - High h.
HPCI Pipe Routing Area h Temperature - High i.
Manual Initiation j.
Drywell Pressure
- High RHR SYSTEM SHUTDOWN COOLING/HEAD SPRAY MODE ISOLATION NA NA NA NA NA NA Q
0 0
0 Q
1, 2, 3
- 1. 2. 3 1,2,3 1, 2, 3 1,2,3
- 1. 2, 3 1,2,3 a.
Reactor Vessel Water Level - Low, Level 3 b.
Reactor Vessel (RHR Cut-in Permissive)
Pressure - High c.
RHR Flow - High d.
Manual Initiation e.
Drywell Pressure
- High NA NA 0
1,2,3 1,2,3
- 1. 2, 3 1,2,3 1,2,3 z0 ECL
%a When handling irradiated fuel in the secondary containment and during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
When reactor steam dome pressure > 1043 psig and/or any turbine stop valve is open.
When VENTING or PURGING the drywell per Specification 3.11.2.8.
This trip function need not be OPERABLE from October 19, 1989 to January 19, 1990.
~ <PS Rf00 0
P Cy 0
C O
I C
IA0
~
gO
++*<<+
P V
t UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-000I PENNSYLVANIA POWER
& LIGHT COMPANY ALLEGHENY ELECTRIC COOPERATIVE INC.
DOCKET NO. 50-388 SUS UEHANNA STEAM ELECTRIC STATION UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 96 License No.
NPF-22 1.
The Nuclear Regulatory Commission (the Commission or the NRC) having found that:
A.
The application for the amendment filed by the Pennsylvania Power 8
Light Company, dated January 14,
- 1991, as supplemented by letter dated March 3, 1992.,
complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's 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 regulations of the Commission; C.
There is reasonable assurance:
(i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I; 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 th'e Technical Specifica-tions as indicated in the attachment to this license amendment and paragraph 2.C.(2) of the Facility Operating License No.
NPF-22 is hereby amended to read as follows:
(2) Technical S ecifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No.
96 and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the license.
PP&L shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
3.
This license amendment is effective as of its date of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION
Attachment:
Changes to the Technical Specifications Date of Issuance:
August 4, 1993 Michael L. Boy
, Ac ing Director Project Directorate I-2 Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation
ATTACHMENT TO LICENSE AMENDMENT N0.96 FACILITY OPERATING LICENSE NO.
NPF-22 DOCKET NO. 50-388 Replace the following pages of the Appendix A Technical Specifications with enclosed pages.
The revised pages are identified by Amendment number and contain vertical lines indicating the area of change.
The overleaf pages are provided to maintain document completeness.*
REMOVE 3/4 3-15 3/4 3-16 3/4 3-19 3/4 3-20 3/4 3-21 3/4 3-22 3/4 3-25 3/4 3-26 INSERT 3/4 3-15 3/4 3-16*
3/4 3-19*
3/4 3-20 3/4 3-21*
3/4 3-22 3/4 3-25*
3/4 3-26
V)C V)0C zz I
Cz TABLE 3.3.2-1 (Continued)
ISOLATION ACTUATION INSTRUMENTATION Trip Function Isolation Signal(s)'"
Minimum Operable Channels Per Trip System'b'pplicable Operational Condition Action 7.
RHR SYSTEM SHUTDOWN COOLING/HEAD SPRAY MODE ISOLATION 4) 4 Ca)
CJl a.
Reactor Vessel Water Level - Low, Level 3 b.
Reactor Vessel IRHR Cut-in Permissive)
Pressure
- High c.
RHR Flow - High d.
Manual Initiation e.
Drywell Pressure
- High UB NA 1,2,3 1,2,3
- 1. 2. 3 1,2,3 1,2,3 26 26 26 24 26 r+Z0
ACTION 20 ACTION 21 ACTION 22 ACTION 23 ACTION 24-
. ACTION 25 ACTION 26 TABLE 3. 3. 2-1 (Continued)
ISOLATION ACTUATION INSTRUMENTATION ACTION STATEMENTS Be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Be in at least STARTUP with the associated isolation valves closed within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Be in at least STARTUP within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
Close the affected system isolation valves within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and declare the affected system inoperable.
Restore the manual initiation function to OPERABLE status within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or close the affected system isolation valves within the next hour and declare the affected system inoperable or be in at least 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 /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Establish SECONDARY CONTAINMENT INTEGRITY with the standby gas treatment system operating within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
Lock the affected system isolation valves closed within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and declare the affected system inoperable.
TABLES NOTATIONS When handling irradiated fuel in the secondary containment and during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
Actuates dampers shown in Table 3.6.5.2"1.
When VENTING or PURGING the drywell per Specification 3.11.2.8.
(a)
See Specification 3.6.3, Table 3.6.3-1 for valves which are actuated by.
these isolation signals.
(b)
A channel may be placed in an inoperable status for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />'or required surveillance without placing the channel or trip system in the tripped condition provided at least one other OPERABLE channel in the same trip system is monitoring that parameter.
In addition, for the HPCI system and RCIC system isolation, provided that the redundant isolation valve, inboard or outboard, as applicable, in each line is OPERABLE and all required actuation instrumentation for that valve is OPERABLE, one channel may be placed in an inoperable status for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for required surveillance without placing the channel or trip system in the tripped condition.
SUS(UEHANNA - UNIT 2 3/4 3-16
fABLE 3.3.2-2 (Continued)
ISOLATION ACTUATION INSTRUHENTATION SETPOINTS RCIC Equipment Room Temperature - High RCIC Equipment Room h Temperature - High RCIC Pipe Routing Area Temperature - High RCIC Pipe Routing Area h Temperature
- High RCIC Emergency Area Cooler Temperature
- High Harrual Initiation Drywell Pressure
- High g.
TRIP FUNCTION REACTOR CORE ISOLATION COOLING SYSTEM d.
e.
TRIP SETPOINT ISOLATION (Continued)
< 167F
<89F
< 167'F¹¹
< 89 F¹¹
< 147 F
NA
< 1.72 psig ALLOWABLE VALUE
< 174F
< 98 FA
< 174'F¹¹
< 98'F¹¹"
< 154 F
NA
< 1.88 psig 6.
HIGII PRESSURE COOLANT INJECTION SYSTEM ISOLATION O Pl gn
)
tu e 0
)
gy v
Q I
c+
4D fD Q) ~ ~
4O C7 Pln a.
b..
C.
h.
)IPCI Steam Line Flow - High
.HPCI Steam Supply Pressure
- Low
-HPCI Turbine Exhaust Diaphragm Pressure
- High
'IIPCI Equipment Room Temperature High HPCI Equipment Room h Temperature
- High HPCI Emergency Ar'ea Coolev Temperature
- Higlr HPCI Pipe Routing Area Temperature
- High HPCI Pipe Routing Area 6 Temperature
- Higlr Manual Irrit.iatiorr Dvywell Pressuve
- Higlr
< 275 inches H>0
> 104 psig
< 10 psig
< 167F
< 89 F
< 147F
< 167'F¹¹
< 89 F¹¹ NA
< l.. /2 psig
< 292 inches H20 90 psig
< 20 psig
< 174'F
<98F 154'F
< 174'F¹¹
< 98'F¹¹*
NA 1.88 psig "Ihese Lr ip frrrrctiorrs rreerl >>oL he OPLRABLL from October l9, l989 Lo Ja>>uavy l9, 1990.
TABLE3.3.2-2 (Continued)
ISOLATION ACTUATIONINSTRUMENTATIONSETPOINTS TRIP FUNCTION TRIP SETPOINT ALLOWABLEVALUE 7.
RHR SYSTEM SHUTDOWN COOLING/HEAD SPRAY MODE ISOLATION a.
Reacto. Vessel Water Level - Low, Level 3 Z 13.0 inches h 11.5 inches b.
Reactor Vessel IRHR Cut-in Permissive) Pressure
- High c.
RHR Flow - High d.
Manual Initiation e.
Drywell Pressure
- High See Bases Figure B 3/4 3-1.
Lower setpoints for TSH-G33-2N600 E, F and TDSH-G33-2N602 E, F.
¹¹ 15 minute time delay.
6 98 psig 6 25,000 gpm 6 1.72 psig S 108 psig 6 26,000 gpm NA S 1.88 psig
TASLE 3D4Q NOLATNN SySTEM WSTRUMENTATION ItESPONSE Tag'ESPONSE TlME (Seconds) N 2.
3.
4.
5.
a.
b.
C.
d.
e.
a.
b.
C, d.
e.
f.
a.
b.
C.
d.
e, f.
g h.
I.
aO b.
C.
d.
e.
f1.
f2.
g a.
b.
C.
d.
e, f.
g h.
lo Io Reactor Vessel Water Level
- 1) Low, Level 3
- 2) Low Low, Level 2
- 3) Low Low Low. Level 1
Drywel) Pressure
- High Manual Initition SGTS Exhaust Radiation - Highg'>>
Main Steam Line Radiation - High+I Reactor Vessel Water Level - Low Low, Level 2 Drywell Pressure
- High Refuel Floor High Exhaust Duct Radiation - High"'I Railroad Access Shaft Exhaust Duct Radiation - High (b)
Refuel Floor Wall Exhaust Duct Radiation - High+I Manual Initiation Reactor Vessel Water Level - Low Low Low, Level 1
Main Steam Line Radiation - Highc'I Main Steam Line Pressure
- Low Main Steam Line Flow - High Condenser Vacuum - Low Reactor Building Main Steam Une Tunnel Temperature
~ High Reactor Building Main Steam Line Tunnel h Temperature
- High Manual Initiation Turbine Building Main Steam Line Tunnel Temperature - High RWCU h Flow - High RWCU Area Temperature
- High RWCU Area Ventilation Temperature hT - High SLCS Initiation Reactor Vessel Water Level - Low Low. Level 2 RWCU Flow - High Manual Initiation RCC Steam Lire h Pressure
- High RQC Steam Supply Pressure
- Low RCIC Turbine Exhai et Diaphragm Pressure
- High RCIC Equipment Room Temperature
~ High RCIC Equipment Room 4 Temperature
- High RQC Pipe Routing Area Temperature - High RCC Pipe Routing Area h Temperature
- High RCC Emergency Area Cooler Temperature
- High Manual Initiation Dryweg Preaare
- High s10<<
s1.0'I s10<<
s10<<
s10<<
NA s10<<
s10<<
s10<<
s 10lal s10<<I slola) s10I'I NA ~
s10<<
s1.0 Is10<<
s1.0'Is 10<<
sO.S'I s10<<
NA NA NA NA NA s10<<<<
NA NA NA s10<<
NA NA NA s10>>"
NA NA NA NA NA NA NA s10<<
SUSQUEHANNA - UNIT 2 3/4 3-21 Amendmwn No. +
NR2 Hgg
TABLE 3.3.2-3 (Continued)
ISOLATION SYSTEIVI INSTRUIVIENTA'fION RESPONSE TIIVIE TRIP FUNCTiON 6.
HIGH PRESSURE COOLANT INJECTION SYSTEM ISOLATION a.
HPCI Steam Flow - High b.
HPCI Steam Supply Pressure
- Low c.
HPCI Turbine Exhaust Diaphragm Pressure
- High d.
HPCI Equipment Room Temperature - High e.
HPCI Equipment Room b, Temperature
- High f.
HPCI Emergency Area Cooler Temperature
- High g.
HPCI Pipe Routing Area Temperature
- High h.
HPCI Pipe Routing Area 6 Temperature
- High i.
Manual Initiation j.
Drywell Pressure
- High 7.
RHR SYSTEM SHUTDOWN COOLING/HEAD SPRAY MODE ISOLATION a.
Reactor Vessel Water Level - Low, Level 3 b.
Reactor Vessel (RHR Cut-In Permissive) Pressure
- High c.
RHR Flow - High d.
Manual Initiation e.
Drywell Pressure
- High RESPONSE TIME (seconds)¹'
1 0(al¹¹¹¹
~10(a>>
NA NA NA NA NA NA NA
~10(>>
~10(a)
NA NA NA
~10(a)
(a) The isolation system instrumentation response time shall be measured and recorded as a part of the ISOLATION SYSTEM RESPONSE TIME. Isolation system instrumentation response time specified includes the delay for diesel generator starting assumed in the accident analysis.
(b) Radiation detectors are exempt from response time testing.
Response time shall be measured from detector output or the input of the first electronic component in the channel.
Isolation system instrumentation response time for MSIVs only. No diesel generator delays assumed for MSIV Valves.
Isolation system instrumentation response time for associated valves except MSIVs.
Isolation system instrumentation response time specified for the Trip Function actuating each valve group shall be added to isolation time shown in Table 3.6.3-1 and 3.6.5.2-1 for valves in each valve group to obtain ISOLATION SYSTEM RESPONSE TIME for each valve.
¹¹ With time delay of 45 seconds.
¹¹¹ With time delay of 3 seconds.
¹¹¹¹ With time delay of 3 seconds.
SUSQUEHANNA - UNIT 2 3/4 3-22 Amendment No.9
TABLE 4. 3. 2. 1-1 (Continued)
ISOLATION ACIUATION INSTRUHENTATION SURVEILLANCE RE UIREHENTS CHANNEL CHANNEL FUNCTIONAL TRIP FUNCTION CHECK TEST" 5.
REACTOR CORE ISOLATION COOLING SYSTEH ISOLATION CHANNEL CALIBRATION OPERATIONAL CONDITIONS FOR WHICH SURVEILLANCE RE UIRED a.
b.
C.
RCIC Steam Line 6 Pressure
- High RCIC Steam Supply Pressure-Low RCIC Turbine Exhaust Diaphragm Pressure
- High RCIC Equipment Room Temperature - High RCIC Equipment Room h Temperature
- High
'ANA',2,3 1, 2, 3
1, 2, 3
1, 2, 3
O Pl a onI c+
ID rt MO C) v Q
0 Q)
~ ~
r C
RCIC Pipe Routing Area Temperature - High RCIC Pipe Routing Area h Temperature
- High RCIC Emergency Area Cooler Temperature - High Hanual Initiation NA NA NA j.
Drywe 1 l Pressure High NA 6.
HIGH PRESSURE COOLANT INJECTION SYSIEH ISOLATION NA R
a.
HPCI Steam Line h Pressure
- High HPCI Steam Supply Pressure
- Low HPCI Turbine Exhaust Diaphragm Pressure
- High NA "lhese tr ip functions need not be OPERABLE from October 19, 1989 to January 19, 1990.
1, 2, 3
1, 2, 3" 1, 2, 3
1, 2, 3:
1, 2, 3
1, 2, 3
1, 2, 3
1, 2, 3
0 TABLE4.3.2.1-1 (Continued)
ISOLATIONACTUATIONINSTRUMENTATIONSURVEILLANCEREQUIREMENTS C
zz Cz 4
4) bJ CD TRIP FUNCTION HIGH PRESSURE COOLANT INJECTION SYSTEM ISOLATION (Continued]
d.
HPCI Equipment Room Temperature - High HPCI Equipment Room b Temperature-High
- f. HPCI Emergency Area Cooler Temperature - High HPCI Pipe Routing Area Temperature-High HPCI Pipe Routing Area h Temperature-High
- i. Manual Initiation
- j. Drywell Pressure
- High RHR SYSTEM SHUTDOWN COOLING/HEAD SPRAY MODE ISOLATION CHANNEL CHECK NA NA NA CHANNEL FUNCTIONAL TEST CHANNEL CALIBRATION Q
0 0
0 0
NA OPERATIONAL CONDITIONS FOR WHICH SURVEILLANCEREQUIRED
- 1. 2. 3 1, 2, 3
- 1. 2. 3
- 1. 2. 3 1,2,3 1,2,3
- 1. 2. 3 Reactor Vessel Water Level - Low, Level 3
b.
Reactor Vessel IRHR Cut-in Permissive)
Pressure - High C.
RHR Flow - High d.
Manual Initiation Drywell Pressure
- High NA R
0 1,2,3 1,2,3
- 1. 2. 3
- 1. 2. 3 1,2,3 ca rtz0 When handling irradiated fuel in the secondary containment and during CORE ALTERATIONSand operations with a potential for draining the reactor vessel.
When reactor steam dome pressure > 1043 psig and/or any turbine stop valve is open.
When VENTING or PURGING the drywell per Specification 3.11.2.8.
This trip function need not be OPERABLE from October 19, 1989 to January 19, 1990.