Text

Amend 6 to License NPF-14,changing Surveillance Requirements for Vacuum Breakers,Establishing Min Discharge Pressure for LPCI Pump,Changing ECCS Actuation Instrument Setpoint Values & Applicability of Safety Relief Valves
	ML17139B247
Person / Time
Site:	Susquehanna
Issue date:	12/16/1982
From:	Schwencer A; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML17139B248	List: ML17139B247; ML17139B249; ML17139B250;
References
	NUDOCS 8212220554
	Download: ML17139B247 (32)
	v • d • e

PENHSYLYANIA POllER 5 LIGHT COMPANY SUSOUEHAHHA S EAm EC R

C ATION, uNIT 1 License No. NPF-14 Amendment No.

6 1.

The Nuclear Pegulatory Commission (the Commission or the NRC) having found that:

A.

The application for.amendment filed by the Pennsylvania Power 8 Light

Company, dated August 18, 1982, as amended by Pennsylvania Power 5

Light Company letter dated August 23, 1982, 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 >iith the Commission's regulations; 0.

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 is amended by changes to the Technical Specifications 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 Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment Ho. 6, and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the license.

PPSL shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

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This amendment is effective as of the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION

Attachment:

Changes to the Technical Specifications Date of Issuance:

Dpg ] 6 1982 A. Schwa>encer, Chief Licensing Branch No.

2 Division of Licensing OFFICEI SURNAME/

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r ATTACHMENT TO LICENSE AMENOMENT NO.

6 0

E NO.

Replace the following pages of the Appendix "A" Technical Specifications with enclosed pages.

The reviewed pages are identified by Amendment number and contain vertical lines indicating the area of change.

REMOVE 3/4 1-9 3/4 1-10 3/4 3-11 3/4 3-12 3/4 3-15 3/4-3-16 3/4 3-31 3/4 3-32 3/4 3-71 3/4 3-72.

3/4 3-79 3/4 3.-80 3/4 3-87 3/4 3-88 3/4 3>>89 3/4 3-90 3'/4 5-3 3/4-5-4 3/4 6-29 3/4 6-30 3/4 8-33 3/4 10-1 3/4 10-2 83/4 3-7 83/4 3-8 INSERT.

3/4 1-9 3/4 1-10 3/4 3-11 3/4 3-12 3/4 3-15 3/4 3-16 3/4 3-31 3/4 3-32 3/4 3-71 3/4 3-'72 3/4 3-79 3/4 3-80 3/4 3-87 3/4 3-88 3/4 3-89 3'/4 3-90 3/4 5-3 3/4 5-'4 3/4 6 3/4 6-30 3/4 8-33 3/4 10-1 3/4 10-2 B3/4 3-7 B3/4 3-8

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REACTIVITY CONTROL SYSTEMS CONTROL ROD SCRAM ACCUMULATORS LIMITING CONDITION FOR OPERATION 3.1.3.5 All control rod scram accumulators shall be OPERABLE.

APPLICABILITY:

OPERATIONAL CONDITIONS 1, 2 and 5~.

ACTION:

a.

In OPERATIONAL CONDITIONS 1 or 2:

1.

With one control rod scram accumulator inoperable within 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months s:

a)

Restore the inoperable accumulator to OPERABLE status, or b)

Declare the control rod associated with the inoperable accumulator inoperable.

Otherwise, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

2.

With more than one control rod scram accumulator inoperable, declare the associated control rod inoperable and:

a)

If any control rod associated with any inoperable scram accumulator is withdrawn, immediately verify that at least one control rod drive pump is operating by inserting at least one withdrawn control rod at least one notch or place the reactor mode switch in the Shutdown position.

b)

Insert the inoperable control rods and disarm the associated directional control valves either:

b.

j.)

Electrically, or 2)

Hydraulically by closing the drive water and exhaust water isolation valves.

Otherwise, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

I'n OPERATIONAL CONDITION 5":

1.

With one withdrawn control rod with its associated scram accumulator inoperable, insert the affected control rod and disarm the associated directional control valves within one hour, either:

a)

Electrically, or b)

Hydraulically by closing the drive water and exhaust water isolation valves.

2.

With more than one withdrawn control rod with the associated scram accumulator inoperable or with no control rod drive pump operating, immediately place the reactor mode switch in the Shutdown position.

At least the accumulator associated with each withdrawn control rod.

Not applicable to control rods removed per Specification

3. 9. 10. 1 or 3.9. 10. 2.

SUSQUEHANNA " UNIT 1 3/4 1-9 Amendment No.

6

REACTIVITY CONTROL SYSTEMS SURVEILLANCE RE UIREMENTS

4. 1.3.5 Each control rod scram accumulator shall be determined OPERABLE:

At least once per 7 days by verifying that the indicated pressure is greater than or equal to 940 psig unless the control rod is inserted and disarmed or'crammed.'.

At least. once per 18 months by:

1.

Performance of a:

a)

CHANNEL FUNCTIONAL TEST'f the leak detectors, and 2..

b)

CHANNEL CALIBRATION of the pressure detectors, and veri'fying an alarm setpoint of 940 + 30, - 0 psig on decreasing pressure.

Verifying that each individual accumulator check valve maintains the;= associated accumulator pressure above the alarm set point for greater than or equal to 10 minutes with no control rod drive pump, operating.

SUSQUEHANNA - UNIT 1 3/4 1-10

TABLE 3.3.2-1 ISOLATION ACTUATION INSTRUMENTATION M

TRIP FUNCTION 1.

PRIMARY CONTAINMENT ISOLATION a.

Reactor Vessel Mater Level

.l)

Low, Level 3 MINIMUM ISOLATIO(

OPERABLE CHANNELS SIGNAL s PER TRIP SYSTEM b

APPLICABLE OPERATIONAL CONDITION 1,2,3 ACTION 20 2)

Low Low, Level 2 3)

Low Low Low, Level I b.

Drywell Pressure - High c.

Manual Initiation B

X Y,Z NA 2

2 2

1,2,3 I, 2, 3

1 $ 2 $

3 20 20 20 2.

SECONDARY CONTAINMENT ISOLATION b.

C.

Reactor Vessel Mater Level-Low Low, Level 2

'rywall'ressure - High Refuel Floor High Exhaust Duct Radiation -- High Y (c)

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

1, 2, 3

1, 2, 3 and "

25 25 25 B

<II CL TD C+

O d.

Railroad Access Shaft Exhaust Duct Radiation - High

III e.

Refuel Floor Mall Exhaust Duct Radiation High

A'.

Manual Initiation 2

1 1, 2, 3 and

1, 2, 3 and "

1,2,3and" 25 25 24

fll t

I Z

M TRIP FUNCTION 3.

HAIN STEAM LINE ISOLATION TABLE 3.3.2-1 (Continued)

ISOL'ATION ACTUATION INSTRUMENTATION I

HI(IHUH ISOLATION OPEPABLE CHA((ELS SIGNAL s

=

PER TRIP SYSTEM b

APPLICABLE OPERATIONAL CONDITION ACTION v

I b.

a@

C.

g.

h.

Reactor Vessel Mater Level-Low, Low, Level 2 Hain Steam Line Radiation-High Main Steam Line Pressure - Low Hain Steam Line Flow - High Condenser Vacuum " Low Main Steam Line Tunnel Temperature - High Main Steam Line Tunnel z Temperature - High Hanual Initiation UA E

2 2/line 2

2/line 1, 2, 3

1 $ 2 j 3 1 $ 2 $ 3 1

2 3

1 2

3 1

2 3

1/2/3 21 21 22 20 21 21 21 4.

REACTOR WATER CLEANUP SYSTEM ISOLATION O

'a 4 b.

C.

d.

e.

g.

RWCS h Flow - High RWCS Area Temperature - High RWCS Area Ventilation h Temp.-

High SLCS Initiation Reactor Vessel Water Level - Low Low, Level 2 RWCS z Pressure - High Manual Initiation J

W W

(d)

J NA 1,2,3 1,2,3 1 $ 2/3 1,2,3 1, 2, 3

1.2 3

1 2

3 23 23 23 23 23 23 24

TABLE 3.3.2-1 (Continued)

ISOLATION ACTUATION INSTRUMENTATION TRIP FUNCTION MINIMUM ISOLATION( )

OPERABLE CHANNELS SIGNAL s PER TRIP SYSTEM b

APPLICABLE OPERATIONAL CONDITION ACTION 7.

RHR SYSTEM SHUTDOWN COOLING MODE ISOLATION a.

Reactor Vessel Water Level - Low, Level 3

1 2

3 26 b.

C.

Reactor Vessel (RHR Cut-in Permissive)

Pressure - High RHR Equipment Area ATemperature - High UB 1,2,3 1, 2, 3

26 26 d.

RHR Area Cooler Temperature - High e.

RHR Flow - High f.

Hanual Initiation NA 1 j 2 $

3 2y 3

1 2

3 26 26

TABLE 3.3. 2-1 (Continued)

ISOLATION ACTUATION INSTRUMENTATION ACTION ACTION 20 Be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in.COLD SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 21

- 'e in at. least STARTUP with the= associated isolation valves closed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or be in at least HOT SHUTDOWN within 12" hours and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 22 Be in at least'TARTUP within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 23 Close the affected system isolation valves within one hour and declare the affected system inoperable.

ACTION 24 -

Restore the manual initiation function to OPERABLE status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 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 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 25 Establish SECONDARY CONTAINMENT INTEGRITY with the standby gas treatment system operating within one hour.

ACTION 26 Lock the affected system isolation valves closed within one hour 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 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 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 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, I'n 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 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 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 RWCU system inlet outboard valve.

SUSQUEHANNA " UNIT 1 3/4 3"16

TRIP FUNCTION TABLE 3:3.3-2 EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SETPOINTS TRIP SETPOINT ALLOMABLE VALUE CORE SPRAY SYSTEM a.

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

Drywell Pressure

- High c.

Reactor Vessel Steam Dome Pressure Low d.

Manual Initiation 2.

LOW PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM a.'eactor Vessel Mater Leve] - Low Low Low, Level 1 b.

Drywell Pressure

- High c.

Reactor Vessel Steam Dome Pressure - Low d.

Hanual Initiation 3.

HIGH PRESSURE COOLANT INJECTION 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 NA a 0 b.

C.

d.

e.

Reactor Vessel Mater Level - Low Low, Level 2

Drywell Pressure - High Condensate Storage Tank Level - Low Reactor Vessel Ma'ter Level - High, Level 8-Suppression Pool Mater Level - High Manual Initiation

> -38 inches*

< 1.72 psig

> 36.0 inches above tank bottom

< 54 inches

< 23 feet 9 inches NA

> -45 inches

< 1.88 psig

> 36.0 inches above tank bottom

< 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 b.

C.

d.

e.

Reactor Mater Leve.l 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 Mater Level-Low, Level 3

Manual Initiation

> -129 inches"

< l. I2 psig e

< 102 seconds 145 2 10 psig 125 I4 psig

> 13 inches

>-136 inches

< 1.88 psig

< 114 seconds 145 t 20 psjg 125 k 10 psig

> 11.5 inches 5.

LOSS, OF POMER a.

4.16 kv ESS Bus Undervoltage (Loss of

Voltage,

<20K) a.

4.16 ky Basis -.840 k 16.8 volts b.

120 v Basis - 24 2 0.48 volts c.

0.5 a O.l second time delay 840 t 59.6 volts 24 + 1.7 volts 0.5 + 0.1 second time delay b.

4.16 kv ESS Bus Undervoltage (Degraded

Voltage,

<65K)

C.

4.16 kv ESS Bus Undervoltage (Degraded

Voltage,

<84K)

See Bases Figure B 3/4 3-1.

a@

b.

C.

4.16 ky Basis - 3483 + 69.7 volts 120 v Basis - 99.5 t 1.99 volts 5 minute a 30 second time delay without LOCA 10 2 1.0 second time delay with LOCA a.

4.16 ky Basis - 2695 a 53.9 volts b.

120 v Basis 77 + 1.54 volts c.

3.0 + 0.3 second time delay 2695 + 191.3 volts 77 t 5.5 volts 3 + 0.3 second time delay I

3483 + 247.3, - 69.7 volts 99.5 + 7.1 volts 5 minutes 2 30 second time delay without LOCA 10 2 1.0 second time delay with LOCA

TABLE 3.3.7.5-1 ACCIDENT MONITORING. INSTRUMENTATION INSTRUMENT Reactor Vessel Steam Dome Pressure REQUIRED NUMBER OF CHANNELS MINIMUM CHANNELS OPERABLE ACTION 80 2.

Reactor Vessel Water Level 80 3.

Suppress'ion Chamber Water Level 2

80 4.

5.

6.

7.

Suppression Chamber Water Temperature Suppression Chamber Air Temperature Primary Containment Pressure Drywell Temperature 8,

6 locations 2/range 1/range 80 80 6, 1/location 80 80 8.

Drywell Oxygen/Hydrogen Analyzer 80 9.

10.

Safety/Relief Valve Position Indicators Containment High Radiation 1/valve" 1/valve" 80 81 ll.

Noble gas monitors a.

Reactor Bldg. Vent b.

SGTS Vent c.

Turbine Bldg. Vent 81 81 81 Acoustic monitor.

ACTION 80-TABLE 3.3.7.5-1 (Continued)

ACCIDENT MONITORING INSTRUMENTATION ACTION STATEMENT ao With the number of OPERABLE. accident monitoring instrumentation channels less than the Required Number of Channels shown in Table 3.3.7.5-.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 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

b.

With the number of OPERABLE accident monitoring instrumentation channels less than the Minimum Channels OPERABLE requirements of Table 3.3.7.'-1, restore the inoperable channel(s) to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 81 -

With the number of OPERABLE Channels less than required by the Minimum Channels OPERABLE requirement, either restore the inoperable channel(s) to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , or:

a.

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

and b.

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 pl'ans and schedule for restoring the system to OPERABLE-" status.

SUSQUEHANNA " UNIT 1 3/4 3-72

INSTRUMENT LOCATION TABLE 3.3.7. 9-1 (Continued)

FIRE DETECTION INSTRUMENTATION INSTRUMENTS OPERABLE FIRE ZONE ROOM OR AREA ROOM NO.

HEAT ELEV.

TOTAL MIN.

PHOTO" IONIZATION ELECTRIC TOTAL MIN.

TOTAL MIN.

1-2A 1-,3A Access Area Access Area 1".3B 1-,.3C 1-4B 1-4G 1-,5B 1-5D 1-5E Access Area Pipe Penetration Room Main Steam Piping Valve Access Area RMCU Pumps 8 Heat Exchangers Penetration Room Access Area

~RiiCh 1-1B Core Spray Pump Room 1-1A Core Spray Pump Room 1-1E RHR Pump Room 1-1F RHR Pump Room 1-1D RCIC Pump Room 1-1C HPCI Pump Room 1-1G Sump Room 1-2D Remote Shutdown Panel Rm.,

1-4C" Switchgear Room 1-4D Switchgear Room 1-. 4A Containment Access Area 1'-5F Load Center Room 1-5G Load Center Room Access Area I-10 I-17 I"13 I-14 I-12 I-11 I"15 I'-109 I"406 I-407 I-401 I-507 I-510 I-105 I-203 I".200 I'.-202 I-403 I.-411 I"515 I;501 I"506 I"606 645'-0" 645'-0" 645'-0" 645'-0" 645~-0" 645'-0" 645'-0" NA NA NA NA NA NA NA NA 2

1 2

1 NA NA NA NA NA NA NA NA HA NA NA NA NA NA NA 749'"1" 749'-1" 779~-1" NA

.NA NA NA NA NA 670'-0" NA

'719'-0" NA 719 I -0" NA 719'-0" NA 749'-1" NA 749'-1" NA 670'-0" NA 683'0" NA'83'-0" NA 683'-0" NA 719'-1" NA 719'-1" HA 761'lO" NA 5

2 7

3 NA HA NA NA NA NA NA NA 2

1 1

1 2

1 17 8

"2 1

2 1

4 2

9 5

HA NA 2

1 NA NA NA NA NA NA NA NA 9

4 NA NA NA NA 13 7

15 8

5 2

7 3

NA NA NA NA NA NA NA NA NA NA NA NA NA NA HA HA'A NA NA NA

!S 6

NA NA 4

2 2

1 2

1 HA HA

~.'USQUEHANNA - UNIT 1 3/4 3-79 Amendment No.

6

INSTRUMENT LOCATION TABLE 3. 3.7. 9-1 (Continued)

FIRE DETECTION INSTRUMENTATION INSTRUMENTS OPERABLE FIRE.

ZONE.'OOM OR AREA Reactor Buildin Continued ROOM NO.

PHOTO-HEAT IONIZATION ELECTRIC.

ELEV.

TOTAL MIN.

1-.6D 1-6E 0-6G 1-.7A 1-7B 0-8A H8V Equipment Room Recirculation Fans Area Surge Tank Vault H8V Fan and Filter Rooms I"612 I-615 I"601 I'"703 Recirculation Fan Room I-701 Refueling Floor

~EWP h

779'-1" 779'-1" 779'"4" 799'-1" 799'-1" 818'"1" NA NA NA NA NA NA 4

2 NA NA NA NA 10 5

2 1

9 5

2 1

NA NA NA NA NA NA NA NA 2

1 NA NA 30 15 0-51.

0-52.

Pump Room Pump Room 685'"6" 685I-6" NA NA 6

3 NA NA NA NA 6

3 NA NA INFRA-RED (FLAME)

TOTAL MIN.

0"41C 0-41B 0-41D Diesel Generator Rooms and Diesel Generator Rooms and Diesel Generator

Rooms, and d.

Dieeei Generato~r Buildin 0-41A Diesel Generator Rooms and.

DG.-2 OG-17 DG"3 DG"18 OG"4 DG-19 660'-0" 677'"0" 22 660'-0" 677'"0" 22 660'-0" 677'"0" 22 OG-1 660'"0" OG-16 677'"0" 22.

2 N 1

11 1

2 1

15 7

15' 15 7

Not accessible.

SUS(UEHANNA - UNIT 1 3/4 3"80

TABLE 3.3.7.11-1.

RADIOACTIVE GASEOUS EFFLUENT HONITORING INSTRUMENTATION INSTRUMENT l.

HAIN CONDENSER OFFGAS TREATMENT SYSTEM EXPLOSIVE GAS MONITORING SYSTEM a.

Hydrogen Monitor 2.

REACTOR BUILDING VENTILATION MONITORING SYSTEH a..

Noble Gas Activity Monitor b.

Iodine Monitor MINIHUM CHANNELS OPERABLE APPLICABILITY ACTION 110 111 112 Co d.

e.

Parti cul ate Monitor Effluent System F]ow Rate Monitor Sampler Flow Rate Monitor 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 Monitor MINIMUM CHANNELS OPERABLE APPLICABILITY ACTION 114 112 112 113 e.

Sampler Flow Rate Monitor 113 4.

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

Noble Gas Activity Monitor 5.

STANDBY GAS TREATMENT SYSTEM MONITOR 115 O

b.

C.

d.

e.

Noble Gas Activity Monitor Iodine Monitor Particulate Monitor fl Effluent System Flow Rate Monitor Sampler Flow Rate Monitor

.1¹¹ 116 112 112 113

TABLE 3.3.7.11-1 Continued)

TABLE NOTATION

¹During operation of the standby gas treatment system.

¹¹Low-range and mid-range channels of monitor only At all times.

During main condenser offgas treatment system operation.

During operation of the main condenser air ejector.

ACTION 110-ACTION 111 "

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, operation of main condenser offgas treatment system may continue for up to 30 days provided grab samples are collected at least once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and analyzed within the following 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, effluent releases via this pathway may continue for up to 30 days provided grab samples are taken at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months and these samples are analyzed'for gross activity within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

'CTION 112 -

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, effluent releases via thi,s pathway may continue for up to 30 days'rovided samples are continuously collected with auxiliary sampling equipment as required in Table 4.11.2.1..2-1.

ACTION 113-ACTION 114 "

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE. requirement, effluent releases via this pathway may continue for up to 30 days provided the flow rate. is estimated at least once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

With the number of channels OPERABLE less than required by the. Minimum Channels OPERABLE requirement, effluent re'leases via thi's pathway may conti'nue for up to 30 days provided grab samples are taken at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months and these samples are anal'yzed for gross activity within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and provided the. mechanical vacuum pumps are not operated.

ACTION 115 -

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, releases to the environment may continue for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months provided:

a.

The offgas system is not bypassed, and b.

The Turbine Building vent noble gas activity monitor is OPERABLE; Otherwise, be in at least HOT STANDBY within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 116 -

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, suspend release of radioactive effluent via this pathway.

SUSQUEHANNA"UNIT 1 3/4 3-89 Amendment No.

6

C/l AD m

TABLE 4.3.7.11 "1 RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION SURVEILLANCE RE UIREHENTS INSTRUMENT MAIN CONDENSER OFFGAS TREATMENT SYSTEM EXPLOSIVE GAS MONITORING SYSTEM CHANNEL SOURCE CHANNEL CHECK CHECK CALIBRATION CHANNEL MODES IN WHICH FUNCTIONAL SURVEILLANCE T

Rll RR 2.

a.

Hydrogen Monitor REACTOR BUILDING VENTILATION MONITORING SYSTEM N/A Q(3)

CAl I

LCl CD a.

Noble Gas Activity Monitor D

b. Iodine Monitor

c. Particulate Monitor

d. Effluent System Flow Rate Monitor D

e.

Sampler Flow Rate Monitor D.

H R(2)

N.A.

R N.A.

a(1) 9(l) c(i)

EMERGENCY CORE COOLING SYSTEMS LIMTING CONDITION FOR OPERATION Continued ACTION:

(Continued) d; For the ADS:

With one of the above required ADS valves inoperable, provided the HPCI system, the CSS and the LPCI system are

OPERABLE, restore the inoperable ADS valve to OPERABLE status within 14'ays or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and reduce reactor steam dome pressure to

< 100 psig within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

2.

With two or more of the above required ADS valves inoperable, be, in at least HOT'SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and reduce reactor steam dome pressure to < 100 psig within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

With a CSS header delta P instrumentation channel inoperable, restore the inoperable channel to OPERABLE status with 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or determine the ECCS header delta P locally at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; otherwise, declare the CSS inoperable..

f;.

I'n the event, an ECCS'ystem is actuated and injects water into the Reactor Coolant System,

a. Special Report shall be prepared and sub-mi'tted to the. Commission pursuant to Specification.6.9.2 within

'0'ays describing the circumstances of the actuation and the total accumulated actuation cycles to date.

The current, value of the usage, factor for each affected injection nozzle shall be provided in this S'pecial Report whenever its value exceeds 0.70.

SUS(UEHANNA - UNIT 1 3/4 5-3

EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE RE UIREMENTS 4.5. 1 The emergency core cooling systems shall be demonstrated OPERABLE by:

a.

At least once per 3l days:

1.

For the. CSS, the LPCI system, and the HPCI system:

a)

Verifying that'he system piping from the pump discharge valve to the system isolation valve is filled with water, by:

l.

Venting at the high point vents 2.

Performing a CHANNEL FUNCTIONAL TEST of the condensate transfer pump discharge low pressure alarm instrumentation.

b)

Verifing that each valve, manual, power operated or automatic, in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.

2.

For the

CSS, performance of a CHANNEL. FUNCTIONAL TEST of the core spray header delta P instrumentation.

3.

For the LPCI system, verifying that at least one LPCI system subsystem cross-tie valve is closed with power removed from the valve: operator.

4.

For the HPCI'ystem, verifying that the pump flow controller is in the. correct position.

b.

Verifing that, when tested pursuant to Specification 4.0.5:

, 1.

The two CSS pumps in each subsystem together develop a total flow of at least'350 gpm against a test line pressure of greater than or equal to 269 psig, corresponding to a reactor vessel steam dome pressure of > 105 psig.

2.

Each LPCI. pump in each subsystem develops a flow of at least-12:,200 gpm against a test, line pressure of > 204 psig, correspond-.

i'ng, to

a. reactor vessel to primary containment differential pressure

> 20 psid.

3.

The HPCI pump develops a flow of at least 5000 gpm against a test 1;ine pressure of > 1266 psig when steam is being supplied to the turbine at 920, +140, - 20 psig."

c.

At', least once per 18 months:

1.

For the CSS, the LPCI system, and the HPCI system, performing a system functional test which includes simulated automatic actuation of the system throughout its emergency operating sequence and verifying that each automatic valve in the flow path actuates to its correct position.

Actual injection of coolant into the reactor vesse1 may be excluded from this test.

The provisions of Specification 4.0.4 are not applicable. provided the surveillance is performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure is adequate to perform the test.

SUSQUEHANNA - UNIT 1 3/4 5-4 Amendment No.

6

CONTAINMENT SYSTEMS 3/4.6.4 VACUUM RELIEF LIMITING CONDITION FOR OPERATION 3.6.4 Each pair of suppression chamber drywell vacuum breakers shall be OPERABLE and closed.

APPLICABILITY:

OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

a.

With one or more vacuum breakers in one pair of suppression chamber - drywell vacuum breakers inoperable for opening but known to be closed, restore the inoperable pair of vacuum breakers to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b.

With one suppression chamber

" drywell vacuum breaker open, verify the other vacuum breaker in the pair to be closed within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

Restore the-open vacuum breaker to the closed position within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least.

HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

c.

With one position indicator of any suppression chamber - drywell vacuum breaker inoperable:

1.

Verify the other vacuum breaker in the pair to be closed within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and at least once per 15 days thereafter, or 2.

Verify the vacuum breaker(s). with the inoperable position indicator to be closed by conducting' test which demonstrates that the. ZP is maintained at. greater than or equal to 0.7 psi for one hour without makeup within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and at least once per 15 days thereafter.

Otherwise, be in at, least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

SUSQUEHANNA " UNIT 1 3/4 6"29

CONTAINMENT SYSTEMS'URVEILLANCE RE UIREMENTS 4.6.4 Each suppression chamber drywell vacuum breaker shall be:

a.

Verified closed at least once per 7 days.

b.

Demonstrated OPERABLE:

At least once per 31 days and within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after any discharge of steam to the suppression chamber from the safety-relief

valves, by cycling each vacuum breaker through at least one complete cycle of full travel.

2.

At'east once. per 31 days by verifying both position indicators OPERABLE'y observing expected valve movement during the cyc:1'ing, test:.

3.

At least. once per 18 months by; a)

Verifying the opening setpoint, from the closed position, to be 0;,5'sid;+

5%, and b)

Verifyi'ng both position indicators OPERABLE by performance of a

CHANNEL. CALIBRATION.

~ 4 ~

SUSQUEHANNA - UNIT 1 3/4 6-30 Amendment No.

6

ELECTRICAL POWER SYSTEMS REACTOR PROTECTION SYSTEM ELECTRIC POWER MONITORING LIMITING CONDITION FOR OPERATION 3.8.4.3 Two RPS electric power monitoring assemblies for each inservice RPS MG set or alternate power supply shall be OPERABLE.

APPLICABILITY: At all times.

ACTION:

b.

With one RPS electric power monitoring assembly for an inservice RPS MG set or alternate power supply inoperable, restore the inoperable power monitoring assembly to OPERABLE. status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or remove the associated RPS MG set or alternate power supply from service.

With both RPS electric power monitoring assemblies for an inservice RPS MG set or alternate power supply inoperable.,

restore at least one electric power monitoring assembly to OPERABLE-status within 30 minutes or remove the associated RPS MG set or'lternate power supply from service.

SURVEILLANCE. RE UIREMENTS 4.8.4.3 The above specified RPS electric: power monitoring assemblies shall be determined OPERABLE::-

"a.

'By performance of a CHANNEL FUNCTIONAL TEST when in COLD SHUTDOWN if'ot performed within the previous 6 months.

b.

At least once per 18 months by demonstrating the OPERABILITY of over-'voltage, under-voltage and, under-frequency protective instrumentation by performance of a CHANNEL CALIBRATION including simulated. automatic actuation of the protective relays, tripping logic and outp'ut circuit. breakers and verifying the following setpoints:

RPS Division A RPS Division B 1.

Over-voltage 2.

Under-voltage 3.

Under-frequency

< 128.3 VAC

> 110.7 VAC

> 57 Hz

< 129.5 VAC

> 111.9 VAC

> 57 Hz P

i i i i ii i

ii g i i

, ii i iii R i i ment is deleted and'eplaced as follows:

a.

At least once per 6 months by performance of a CHANNEL FUNCTIONAL TEST.

SUSQUEHANNA - UNIT 1 3/4 8-33 Amendment No.

6

~Ae'

3/4.10 SPECIAL TEST EXCEPTIONS 3/4. 10. 1 PRIMARY CONTAINMENT INTEGRITY LIMITING CONDITION FOR OPERATION 3.10.1 The provisions of Specifications 3-4.2, 3.6.1.1.. 3.6;1.3 and 3.9,1 and Table 1.2 may be suspended to permit the. safety valve function of the safety/relief valve to be inoperable, the reactor 'pressure vessel closure head and the--drywell 'head to be. removed.and.,the",primary.:cont'ainment" air'lock'doors. to'be open'when the reactor.

mode 8witch. is in'the'Startup position during,low'power PHYSECS-.TESTS with THERMAL POWER less than'lX"of RATED THERMAL POWER'and-reactor coolant temperatuie less than 2000 F APPLICABILITY:

OPERATIONAL CONDITION 2, during low power PHYSICS TESTS.

ACTION:

With THERMAL POWER greater than or equal to lX of RATED THERMAL POWER or with.

the reactor coolant temperature 'greater than or equal to 200'F, immediately place the reactor mode switch in the Shutdown position.

SURVEILLANCE RE UIREMENTS

4. 10. 1 The THERMAL POWER and reactor coolant temperature shall be verified to be within the limits at least once per hour during low power PHYSICS TESTS.

SUSQUEHANNA - UNIT 1 3/4 10-1 Amendment No.

6

SPECIAL TEST EXCEPTIONS 3/4. 10.2 ROD SE UENCE CONTROL SYSTEM LIMITING CONDITION FOR OPERATION

3. 10.2 The sequence constraints imposed on control rod groups by the rod sequence control system (RSCS) per Specification

3. 1.4.2 may be suspended by means of bypass switches for the following tests provided that the rod worth minimizer is OPERABLE per Specification 3. l. 4. 1:

'a 0 Shutdown margin demonstrations, Specification 4. 1. l.

b.

Control rod scram, Specification 4. 1.3. 2.

c'.

Control rod friction measurements.

Startup Test Program with the THERMAL POWER less than 20K of RATED THERMAL POWER.

. APPLICABILITY:

OPERATIONAL CONDITIONS 1 and 2.

ACTION:

With the requirements of the above specification not satisfied, verify that the RSCS is OPERABLE'er Specification 3. 1.4. 2.

SURVEILLANCE. RE UIREMENTS 4; 10. 2, When the sequence constraints i'mposed by the RSCS are bypassed, verify;

'a 0 b.

C.

d.

That; the RWM is OPERABLE'er S'pecification 3. 1.4. l.

That movement of control rods from 75K ROD DENSITY to the RSCS low.

power setpoint i's blocked or limited to the approved control rod withdrawal sequence during scram and friction tests.

That movement of control rods during shutdown margin demonstrations is limited to the prescribed sequence per Specification

3. 10.3.

C'onformance with this specification and test'procedures by a second licensed operator or other technically qualified member of the unit technical staff.

SUSQUEHANNA - UNIT 1 3/4 10-2

INSTRUMENTATION BASES 3/4.3.8 TURBINE OVERSPEED 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.

SUS(UEHANNA " UNIT 1 B 3/4 3"7

NOTB SCAlE IN INCHES A80VE VESSEL ZERO WATER lEVELNOMENQATDRE HEIGHT A80VE VESSEL 2ERD YERK RAKE 8

ITI IO DI IO m

68 5815 5685 55Th 54IL5 4IL5

~

31KS 3IK3

+54

+39

+30

+13

-38

-148

-3185 80TTOM'OF STEAM ORTER SIGHT FEED WATER s'il 488S 0

0

'll IO HPCL TT0P REQQ PIMPS, QDSE'SIA 48 REACIDR SCRAM 0

4103 4IO' 148 m

250'HL3.

REQRC

SUCTION1615

~

k02ZLE 150.

2IL3 REQRC:

OSQIARGE N022LE.

Bases Figure B 3/4 3-1 REACTOR VESSEL WATER LEVEL SUS(UEHANNA " UNIT 1 B 3/4 3"8 Amendment No.

6

ML17139B247

Text

Attachment:

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