ML17139A916

Corrected Tech Spec Pages 3/4 3-11,3/4 3-12,3/4 3-15, 3/4 3-32,3/4 3-71,3/4 3-88,3/4 6-6 & B 3/4 3-8 Re Isolation Actuation Instrumentation & ECCS Setpoints

ML17139A916
Person / Time
Site:	Susquehanna
Issue date:	07/26/1982
From:	Office of Nuclear Reactor Regulation
To:
Shared Package
ML17139A917	List: ML17139A916
References
NUDOCS 8208110208
Download: ML17139A916 (14)

Text

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'rne TRIP FUNCTION 1.

PRIMARY CONTAINMENT ISOLATION a.

Reactor Vessel Mater Level 1)

Low, Level 3

TABLE 3.3.2-1 ISOLATION ACTUATION INSTRUMENTATION MINIMUM APPLICABLE ISOLATION OPERABLE CHANNELS OPERATIONAL SIGNAL('s PER TRIP SYSTEM (b)

CONDITION 1, 2, 3

ACTION 20 GJ CA I

2.

2)

Low Low, Level 2

b.-

Drywell Pressure - High c.

Manual Initiation SECONDARY CONTAINMENT ISOLATION Y,Z 1,2,3 1,2,3 1, 2, 3'020 24 a 0 b.

C.

d.

Reactor Vessel Mater Level-Low Low, Level 2

Drywell Pressure

- High Refuel Floor High Exhaust Duct Radiation - High Railroad. Access Shaft Exhaust.

Duct Radiation - High Y (c)

Y Z (c) 1, 2, 3 and "

1 p 2 j 3 1, 2, 3 and

• 1, 2, 3 and ~

25 Z5 25 25 e.

f.

Manual Initiation Refuel Floor Mall Exhaust Duct Radiation - High 1, 2, 3 and "

1,2,3and" 25 24

TABLE 3.3.2-1 (Continued)

ISOLATION ACTUATION INSTRUMENTATION TRIP FUNCTION MINIMUM APPLICABLE ISOLATION OPERABLE CHANNELS OPERATIONAL SIGNAL(s)

PER TRIP SYSTEM (b)

CONDITION ACTION 3.

C.

High Main Steam Line Pressure -

Low d.

Main Steam Line Flow - High e.

Condenser Vacuum - Low f.

. Main Steam Line Tunnel Temperature - High MAIN STEAM LINE ISOLATION a.

Reactor Vessel Mater Level-Low, Low, Level 2

b.

Main -Steam Line Radiation-P 0

UA E

2 2/line 2

2/line 1, 2, 3

1, 2, 3

1,'2, 3

1, 2, 3

1, 2, 3

21 21 22 20 21 21 g.

Main Steam Line Tunnel 6 Temperature - High Manual Initiation 1, 2, 3

1, 2, 3

21 24 REACTOR WTER CLEANUP SYSTEM ISOLATION a.

b.

C.

d.

e.

g.

RMCS h Flow - High RMCS Area Temperature - High RMCS Area Ventilation 6 Temp.-

High SLCS Initiation Reactor Vessel Mater Level -

Low Low, Level 2

RMCS h, Pressure

- High Manual Ini'tiation (d)

J NA

-NA 2

1 1

1,2,3 1,2,3 1, 2, 3

l,2,3 1, 2, 3

-12 3

l,2,3 23 23 23 23 23 23 24

TABLE 3.3.2-1 (Continued)

.ISOLATION ACTUATION INSTRUMENTATION MINIMUM ISOLATION OPERABLE CHANNELS TRIP FUNCTION, 'IGNALs)

PER TRIP SYSTEM (b) 7.

RHR SYSTEM SHUTDOWN COOLING MODE ISOLATION APPLICABLE OPERATIONAL CONDITION ACTION a.

Reactor Vessel Mater Level - Low, Level 3

b.

Reactor Vessel (RHR Cut-in Permissive)

Pressure - High c.

RHR Equipment Area b, Temperature - High-d.

RHR Area Cooler Temperature - High e.

RHR Flow - High f.

Manual Initiation A

UB 1, 2,'3 1,2,3 1

2 3

1, 2, 3

1, 2, 3

1 j 2 )

3 26 26 26 26

ACTION 20 ACTION 21 ACTION 22 ACTION 23 ACTION 24-ACTION 25 ACTION 26 TABLE 3.3.2-1 (Continued)

ISOLATION ACTUATION INSTRUMENTATION ACTION 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 SHUTDOMN 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 with'in 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 one hour and declare the affected system inoperable.

Restore the manual initiation function to OPERABLE status within 8 'hours 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 one hour.

Lock the affected system isolation valves closed within one hour and decIare the affected system inoperable.

I NOTES When handling irradiated fuel in the secondary containment and during CORE. ALTERATIONS and operations with a potential for draining the reactor vessel.

Actuates valves shown in Table 3. 6. 5.2-1.

(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 tr'ip 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.

'c)

Also starts the standby gas treatment system.

(d)

Closes only RMCU system inlet outboard valve.

SUSQUEHANNA " UNIT 1 3/4 3" 16

AD TRIP FUNCTION TABLE 3.3.3-2 EMERGENCY CORE COOL'ING SYSTEM ACTUATION INSTRUMENTATION SETPOINTS TRIP SETPOINT ALLOWABLE VALUE Crk 2.'.

CORE SPRAY SYSTEM a.

.Reactor Vessel Water Level - Low Low Low, Level 1 b.

Drywell Pressure; High c.

Reactor-Vessel Steam Dome Pressure Low d.

Manual Initiation LOW PRESSURE COOLANT=INJECTION MODE OF RHR SYSTEM a.-

Reactor Vessel Water Level - Low Low Low, Level 1

b..;Drywel 1'ressure High c.

Reactor Vessel Steam Dome Pressure

- Low d.

Manual, Initiation HIGH PRESSURE COOLANT'NJECTION SYSTEM

>-129 inches*

< 1 72 psig

> 436 psig, decreasing NA

>-129 inches*

< 1.72 psig

> 436 psig, decreasing NA

>-136 inches

< 1.88 psig

> 416 psig, decreasing NA

>-136 inches

< 1.88 psig

> 416 psig, decreasing'A a.

b.

C.

Reactor Vessel Water. Level Low Low,.Level 2

Drywell Pressure

- High Condensate Storage Tank Level -

Low

> -38 inches*

< 1.72 psig 36.0 inches above

..-tank bottom

> -,45 inches

< 1.88 psig.

> 36.0 inches above tank bottom d.

Reactor Vessel Water Level - High, Level 8

e.

Suppression Pool Water Level. -'High f:

Manual Initiation

< 54 inches

< 23 feet 9 inches NA

< 55.5.inches

< 24 feet NA

TABLE 3.3.3-2 (Continued)

EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SETPOINTS TRIP FUNCTION 4.

AUTOMATIC DEPRESSURIZATION SYSTEM TRIP SETPOINT ALLOWABLE VALUE a 0 b.

C.

d.

e.

Reactor Water Level - Low Low Low, Level 1

Drywell Pressure - High ADS Timer Core Spray Pump Discharge Pressure - High RHR, LPCI Mode Pump Discharge Pressure

- High Reactor Vessel Water Level-Low, Level 3

Manual Initiation

> -129 inches"

< 1.72 psig

< 102 seconds 145 + 10 psig 125 + 4 psig

> 13 inches

>-136 inches

< 1.88 psig

< 114 seconds 145 + 20 psig 125 +.10 psig

> 11.5 inches NA 5.

LOSS OF POWER a.

4.16 kv ESS-Bus Undervoltage (Loss of

Voltage,

<20X) b.

4.16 kv ESS Bus Undervoltage (Degraded

Voltage,

<65K) a.

4.16 kv Basis - 840 a 16.8 volts b.

120 v Basis - 24 + 0.48 volts c.

0.5 + 0.1 second time delay a.

4. 16 kv Basis - 2695 + 53.9 volts b.

120 v Basis --77 + 1.54 volts c.

3.0 + 0.3 second time delay 840 + 59.6 volts 24 + 1.7 volts 0.5 + 0.1 second time delay 2695 + 191.3 volts 77 + 5.5 volts 3 + 0.3 second time delay C.

4.16 kv ESS Bus

'ndervoltage (Degraded

Voltage,

<84K)

See Bases Figure B 3/4 3-1.

a 0 b.

C.

4. 16 kv Basis - 3483

+ 69.7 volts 120 v Basis - 99.5 + 1.99 volts 5 minute + 30 second time delay without LOCA 10 + 1.0 second time delay with LOCA 3483 + 247.3, - 69.7 volts 99.5 + 7.1 volts 5 minutes

+ 30 second time delay without LOCA 10 + 1.0 second time delay with LOCA

INSTRUMENT TABLE 3.3.7.5-1.

ACCIDENT HONITORING INSTRUHENTATION RE(UIRED NUHBER OF CHANNELS

- HINIHUH CHANNELS OPERABLE ACTION 1.

Reactor Vessel Steam Dome Pressure 2.

Reactor Vessel Water Level 3.

Suppression Chamber Mater Level 4.

Suppression Chamber Mater Temperature 5.

Suppression Chamber Air Temperature 6.

. Primar'y Containment Pressure 7.

Drywell Temperature 8.

Drywel 1 Oxygen/Hydrogen Analyzer 9.

Safety/Relief Valve PositiOn Indicators 10.

Containment High Radiation 11.

Noble gas monitors a..

Reactor Bldg. Vent b.

SGTS Vent c.

.Turbine Bldg. Vent

'8, 6 locations 2/range 1/valve" 6, 1/location 1/range 1

1/val ve*

80 80 80 80 80 80 80 80 80 81 81 81 SI "Acoustic monitor.

ACTION 80-TABLE 3.3.7.5-1 (Continued)

ACCIDENT MONITORING INSTRUMENTATION ACTION STATFMENT a.

With the number of OPERABLE accident monitoring instrumentation channels less than the Required Number of Channels shown in Table'.3.7.5-1, restore the inoperable channel(s) to OPERABLE status within 7 days 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 />.

b.

With the number of OPERABLE accident monitoring instrumentation channels.less than the Minimum Channels OPERABLE requirements of Table 3.3.7.5-1, restore the inoperable channel(s) to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> 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 />.

ACTION 81 a.

b.

With the number of OPERABLE Channels less'han required by the Minimum Channels OPERABLE requirement; either restore the inoperable channel(s) 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:

Initiate the preplanned alternate method of monitoring the appropriate parameter(s),

and Prepare and submit a Special Report to the Commission.pursuant to Specification 6.9.2 within 14 days following the event outlining the action taken, the cause of the inoperability, and the plans and schedule for'estoring the system to OPERABLE status.

d SUSQUEHANNA " UNIT 1 3/4 3-72

(

cO TABLE 3.3.7.11-1 RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION

(

INSTRUMENT 1.

MAIN CONDENSER OFFGAS TREATMENT-SYSTEM EXPLOSIVE GAS MONITORING SYSTEM a.

Hydrogen Monitor 2.

REACTOR BUILDING VENTILATION MONITORING SYSTEM a.

, Noble Gas Activity Monitor

b.,

Iodine Monitor Particulate Monitor d.

Effluent System Flow Rate Monitor

e. 'ampler Flow Rate Monitor MINIMUM CHANNELS OPERABLE APPLICABILITY ACTION 110 112 112.

113 113

TABLE 3.3.7.11-1 RADIOACTIVE -GASEOUS EFFLUENT MONITORING INSTRUMENTATION INSTRUMENT 3.

TURBINE BUILDING VENTILATION MONITORING SYSTEM a.

Noble Gas Activity Monitor b.

Iodine Monitor c.

Particulate Monitor d.

- Effluent System Flow Rate Honitor I'. 'ampler. Flow Rate Monitor 4.

HAIN CONDENSER OFFGAS PRE-TREATMENT RADIOACTIVITYMONITOR (Prior to Input to Holdup System) a.

Noble Gas Activity Hon'ftor 5-STANDBY GAS TREATHENT SYSTEM MONITOR a.

Noble Gas Activity Monitor b.

Iodine-Monitor, c.'articulate'Monitor

.d.

. Effluent System Flow Rate Monitor

- e.

Sampler Flow hate Monitor flINIHUH CHANNELS OPERABLE APPLICABILITY.

=

ACTION 114 112 112 113 113 115 116 112 112 113 113

INSTRUMENTATION BASES 3/4. 3. 8 TURBINE OVERSPEEO PROTECTION SYSTEM This specification is provided to ensure that the turbine overspeed protection system instrumentation and the turbine speed control valves are OPERABLE and will protect the turbine from excessive overspeed.

Protection from turbine excessive overspeed is required since excessive overspeed of the turbine could generate potentially damaging missiles which could impact and damage safety related components, equipment or structures.

3/4. 3. 9 FEEDWATER/MAIN TURBINE TRIP SYSTEM ACTUATION INSTRUMENTATION The feedwater/main turbine trip system actuation instrumentation is provided to initiate action of the feedwater system/main turbine trip system in the event of failure of feedwater controller under maximum demand.

SUSQUEHANNA - UNIT 1, B 3/4 3-7

HO% SCALE IH IHCHES, ABOVE VESSEL 2ERO WATER IEVELNONTQA'ii%

HEIGHT ABOVE VmL 2EIm pg YE5SE RAKE 80 OI III OI OI m

581$

5R5 5575 5405 4KS 37IL5

~ 3183

+54

+39

+30

+13

-38 rl48

-31ILS BOTTOM Of STEAM ORTER SIGRT fEEO WATER

=

Em WIOE RANGE 0

0 HARROW RANGE m

54 HPO &

RCIC TRIPS 0

OI REACTOR SCRAM 0

4!

G3 8ImATE RCIQ RPCL TRIP RECIRC PUMPS, CLOSE MSIA 4103 378SII 3775 3%3 140

'O IHWATE RHR, W START OISEL ANO COHTIRIBUTE TO ADS 31IL3 3ML380 R83RC SUCTION 1515 NO22LE 150 2103 RH3RC 18131 DSCHARGE-NO22LE Bases Figure B 3/4.3-1 REACTOR VESSEL MATER LEVEL SUSQUEHANNA - UNIT 1 B 3/4 3"8

,TABLE 6. 2. 2-1

. MINIMUM SHIFT CREW COMPOSITION POSITION NUMBER OF INDIVIDUALS RE UIRED TO FILL POSITION SS SRO RO NLO STA OP ERATIONAL CONDITIONS 1 2

8( 3 OPERATIONAL CONDITIONS 4 & 5 1

None 1

1 None TABLE NOTATION SS Shift Supervisor with a Senior Reactor Operators License 'on Unit l.

SRO -.Individual with a Seni'or.,Reactor Operators License on Unit 1.

RO

'Individual with a Reactor Operators License on Unit.l.

NLO - Non-Licensed Operator STA - Shift Technical Advisor Except for the Shift Supervisor, the Shift Crew Compo'sition may be one less than the minimum 'requirements. of Table 6. 2. 2-1 for a period of time not to exceed 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the Shift Crew Composition to within the minimum requirements of Table 6.2.2-1.

This pr'-

vision does not permit any. shift'rew position to be unmanned'pon shift change due to an oncoming shift crewman being late or absent.

During any absence of the Shift Supervisor from'he Control'oom while the unit is in OPERATIONAL'ONDITION 1, 2 or 3, an individual, other than the Shift Technical Advisor, with a valid SRO license shall be designated to assume the Control Room command function.

During any absence of the Shift Supervisor from the Control Room while the unit is in OPERATIONAL CONDITION 4 or 5; an individual with a. valid SRO or RO'icense shall, be designated to assume the Control Room command function.

SUSQUEHANNA " UNIT 1 6-5

ADMINISTRATIVE CONTROLS 6.2.3 NUCLEAR SAFETY ASSESSMENT GROUP NSAG FUNCTION 6.2.3.1 The NSAG shall function to examine unit operating characteristics, NRC issuances, industry advisories, Licensee Event Reports, and other sources of plant design and operating experience information, including plants of similar design,. which may indicate areas for improving plant safety.

COMPOSITION 6.2.3.2 The NSAG shall be composed of at least five dedicated, full-time engineers with at least three located onsite, each with a bachelor's degree in engineering or related science and at least two years professional level experience in his field, at least one year of which experience shall be in the nuclear field.

RESPONSIBILITIES 6.2.3.3 The NSAG shall be responsible for maintaining surveillance of unit activities to provide. independent verification" that these activities are performed correctly and that human errors are reduced as much as practical.

AUTHORITY I'.2.3.4 The NSAG shall make detailed recommendations for revised procedures, equipment modifications, maintenance activities, operations activities, or other means of improving unit safety to the Senior Vice President-Nuclear.

6.2.4 SHIFT TECHNICAL ADVISOR 6.2.4.1 The Shift Technical Advisor shall provide technical, support to the Shift Supervisor in the areas of thermal hydraulics, reactor engineering, and plant analysis with regard to the safe operation of the unit.

6. 3 UNIT STAFF VALIF ICATIONS 6.3.1 Each member of the unit staff shall meet or exceed-the minimum qualifications 'of 'ANSI N18. 1-,1971 for comparable positions and the supplemental requirements specified in Section A and C of Enclosure 1 of the March 28, 1980 NRC letter to all 'licensees, except for 'the Health Physics Supervisor who shall meet or exceed the qualifications of Regulatory Guide 1.8, September

1975, and the shift Technical'dvisor who shall meet or exceed the qualifications referred to in Section 2.2. l.b of Enclosure I of the October 30, 1979 NRC letter to all operating nuclear power plants.

6. 4 TRAINING

"'.4.1 A retraining and replacement traini'ng program for the unit staff shall be maintained under the direction of the Manager - Nuclear Training, 'shall.meet or exceed the requirements and recommendations of Section 5.5 of ANSI N18:1-1971 and Appendix "A" of 10 CFR'Part 55 and the supplemental requirements specified in Section A and C of Enclosure 1 of the March 28, 1980'NRC le&er to all licensees, and shall include familiarization with relevant industry operational experience.

Not responsible for sign-off function.

SUSQUEHANNA - UNIT 1