Text

Marked-up Proposed Tech Specs Re Reactor Trip Sys Instrumentation Trip Setpoints,Esfas Instrumentation Trip Setpoints & Seismic Monitoring Instrumentation Surveillance Requirements
	ML20207N401
Person / Time
Site:	Seabrook
Issue date:	10/14/1988
From:	; PUBLIC SERVICE CO. OF NEW HAMPSHIRE
To:	;
Shared Package
ML20207N396	List: ML20207N394; ML20207N401;
References
	NUDOCS 8810190128
	Download: ML20207N401 (25)
	v • d • e

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TABLE 2.2-1 (Continued) .'

h REACTOR TRIP SYSTEM INSTRUENTATION TRIP SETPOINTS .

E o

SENSOR S TOTAL ERROR e

FUNCTIONAL UNIT ALLOWANCE (TA) Z (R TRIP SETPOINT &lAmmalF VALUE __

E 11. Pressurizer Water Level - High 8.0 M- 4r84-G ~<92% of instrument 494- 5 of instrument

~

A-20 o-&9 span L f 937s%"

- 12. Reactor Coolant Flow - Low 2.5

/Af.0

.o7 gm,,p e.j >90% of loo 12 63 C W > H-o se

>89.4% o & w Py ng y 12.Cs

13. Steam Generator Water U.4- 15. M 4rM- 321. 2 of narrow r20. 5 of narrow Level Low - Low range instrument range instrument

_ span span x -

14. Undervoltage - Reactor 15.0 1.39 0 >10,200 volts >9,822 volts Coolant Pumps

15. Underfrequency - Reactor 2.9 0 0 >55.5 Hz >55.3 Hz y Coolant Pumps w

16. Turbine Trip

a. Low fluid Oil Pressure M.A. N.A. N.A. >500 psig 1450 psig

, b. Turbine Stop Valve M.A. N.A. N.A. >1% open >1% open t,m Closure "8

3

~

17. Safety Injection Input N.A. N.A. N.A. N.A. N.A.

oo from ESF o-on KG O$

85 mgg

Loop design flow = 95,700 gpm fix.

m

TABLE 4.3-1 (Continued)

TABLE NOTATIONS (Continued)

(12) Verify the RTO bypass loops flow rate.

l (13) The TRIP ACTUATING OFVICE OPERATIONAL TEST shall independently verify the OPERABILITY of the undervoltage end shunt trip circuits for the Manual Reactor Trip Function. The test shall also verify the OPERABILITY of the Bypass Breaker trip circuit (s).

(14) calmanuaLshunt trip _ prior to placing breaker in servicey 0 r 'u pi;nt; th;t d; n:t ::te:1Y th_: thEMI EP!; etteck ent c' t* by; ::

breaker: Or : : nuel-reacter trip): 8.0 ete ne:1 undervoltage-telp-

er be::h:r ;1:::d ' ::rv'::. _'

l (15) Automatic undervoltage trip.

(16) Each channel shall be tested at least every 92 days on a STAGGERED TEST BASIS.

i (17) These channels also provide inputs to ESFAS. Comoly with the applicable MODES and surveillance frequencies of Specificatt:n 4.3.2.1 for any por-tion of the channel required to be OPERABLE by Specification 3.3.2.

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SEABROOK - UNIT 1 3/4 3-13 i

= ~_

TA8LE 3.3-4 .'

ENG!NEEWED SAFETY FEATURES ACTUATION SYSTEM INSTRLMENTATION TRIP SETPOINTS

8 o

7 SENSOR TOTAL ERROR E FUNCTIONAL UNIT ALLO W E (TA) (5) TRIP SETPOINT ALLOWABLE VALUE Z_

w

- 1. Safety Injection (Reactor Trip, Feedwater Isolation, Start Diesel Generators, Phase "A Isolation, Containment Ventilation Isolation, and Emergency Fee: heater, Service Water to Secandary Component Cooling Water Isolation, CBA Emergency fan / Filter Actuation, and Latching Relay).

{ a. Manual Initiation N.A. N.A. N.A. N.A. N.A.

b. Automatic Actuation Logic N.A. N.A. N.A. N.A. N.A.

. c. Coctainment Pressure--Hi-1 42 nn 1 E7 < 4.3 psig < 5.3 sig

d. Pressurizer Pressure--Low As.o < 2- S/ o.99 scw serz.

H 29.?! l.49- 1 48 4 psig 1 M psig ,

J

e. Steam Line Pressure--Low 1.1.1 10.71 1.63 1 585 psig 1 568 psig*

2. Containment Spray 4

) a. Manual Initiation M.A. M.A. M.A. N.A. N.A.

b. Automatic Actuation Logic N.A. N.A. N.A. N.A. N.A.

j and Actuation Relays

c. Containment Pressure--Hi-3 3.0 0.71 1.67 5 18.0 psig $ 18.7 psig i

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TABLE 3.3-4 (Continued) -

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3 m

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM IPSTNWENTATION TRIP SETPOINTS 8

" SENsoo TOTAL ERROR

[ FUNCTIONAL UNIT ALLOWANCE (TA) Z (S) TRIP SE'.*0'ET ALLOWABLE VALUE x

7. Emergency Feeshster

a. Manual Initiation (1) Motor drivon pump N.A. N.A. N.A. M.A. N.A.

(2) Turbine driven pump N.A. N.A. N.A. N.A. N.A.

b. Automatic Actuation Logic M. . MA N.A. N.A. N.A.

"** ** "Y'

) /2 63 04f" jfO JZ. 4,

c. Steam Generator Water +7 Wa6- 4-M- > MrE of

> 45 of narrow w Level--Low-Low narrow range range instrument 2 Start Motor-Driven Pump instrument span. j w and Start Turbine-Driven span.

3 Pump

d. Safety Injection See Item 1. above for all Safety Injection Trip Setpoints and Start Motor-Drf wen Pump A11omable Values, and Turbine-Driven Pump

e. Loss of-Offsite Power See item 9. for Loss-of-Of fsite Power Setpoints and Allowable Values.

Start Motor-Driven Pump and Turbine-Driven Pump

8. Automatic Switchover to containment. Sump

a. Automatic Actuation Logic N.A. N.A. N.A. N.A. M.A.

and Actuatloc Relays

b. RWST Level--Low-Low 2.75 1.0 1.8 >122,525 gals. >121,609 gals.

Coincident With Safety Injection See Ites 1. above for all Safe *.y Injection Trip Setpoints and Allowable Values. ,

,_,,,,.,_-mp..,,-- -s -m- + ----,-w eM+W W'

TABLE 3.3-7 SEISMIC MCNITORING INSTRUMENTATION .

MINIMUM MEASUREMENT INSTRUMENTS INSTRUMENTS AND SENSOR LOCATIONS RANGE OPERABLE

1. Triaxial Time-History Accelerographs*

a. 1-SM-XT-6700 Free Field Control i lg 1**

Room East Air Intake, elevation 11' 6"

b. 1-SM-XT-6701 Containment Foundation, t lg 1**

elevation -26' 0"

c. 1-SM-XT-6710 Containment Operating 2 Ig 1**

Floor, elevation 25' 0"

2. Triaxial Peak Accelerographs

a. 1-SM-XR-6702 Accumulator Tank SI-TK-9C, 0-20 Hz 1 elevation -6' 0"

b. 1 SM-XP.-6703 Safety Injection 0-20 Hz 1

! Piping, elevation -24' 0"

c. 1-SM-XR-6704 PCCW Piping, Primary 0-20 Hz 1 Auxiliary Building, elevation 47' 0"

3. Triaxial Seismic Swi 1-SM-XS-67 Tantainment to ati [ 0.025g to 0.25g 1**

elevatio(p2f'0" -N'o

4. Triaxial Response-Spectrum Recorders

a. 1-SM-XR-6705 Containment Foundation, 1-30 Hz 1**

elevation -26' 0" b.1-SM-XR-6706 Containment Foundation 1-30 Hz 1 next to SI-TV.-9C, elevation -26' 0" ,

c. 1-SM-XR-S107 Primary Auxiliary 1-30 Hz 1 Build.ing, elevation 25' 0"

d. 1-SM-XR-6708 Service Water Pump House, 1-30 Hz 1 elevation 4' 0" "Trigger mechanism in accelerograph unit activates recorders in control room when it senses 2 ground motion of 0.01g.

- dith reactor control room indication

Switch setpoint is 0.13g for horizontal and vertical axis.

SEABROOK - UNIT 1 3/4 3-42

TABLE 4.3-4 SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS ,

ANALOG CHANNEL CHANNEL CHANNEL OPERATIONAL INSTRUMENTS AND SENSOR LOCATIONS CHECK CALIBRATION TEST

1. Triaxial Time-History Accelerograp *

a. 1'SM-XT-6700 Free Field Control " It R SA Room East Air Intake, elevation 11' 6" i

b. 1-SM-XT-6701 Containment Foundatio # M R N.A.

elevation -26' 0"

c. 1-SM-XT-6710 containment Operati M R N.A.

Floor, elevation 25' 0" ,

2. Triaxial Peak Accelerographs

a. 1-SM-XR-6702 Accumulator Tank N.A. R N.A.

i SI-TK-9C elevation -6' 0"

b. 1-SM-XR-6703 Safety Injection N.A. R N.A.

Piping, elevation -24' 0"

c. 1-SM-XR-6704 PCCW Piping, Primary N.A. R N.A.

Auxiliary Building, elevation 47' 0"

3. Triaxial Seismic Switch 1-SM-XS-6709 Containment Foundation,** M R N.A.

elevation -26' 0"

4. Triaxial Response-Spectrum Recorders

a. 1-SM-XR-6705 Containment Foundation,** M# R N.A.

elevation -26' 0"

! b. 1-SH-XR-6706 Containment Foundation N.A. R N.A.

next to SI-TK'9C, elevation -26' 0"

c. 1-SM-XR-6707 Primary Auxiliary N. A. R N.A.

) Building, elevation 25' 0"

d. 1-SM-XR-6708 Service Water Pump House, elevation 4' 0" N.A. R N. A.

i l *Each accelerograph has a triaxial trigger to activate the recorder.

- With reactor control room indications.

CHANNEL CHECK to consist of turning the test / reset switch and verify all lamps illuminate on 1-SM-XR-6705.

SEABROOK - UNIT 1 3/4 3-43

IABLE 3.3-10 .

A '

g ACCIDEN! TNITORING lt(SlRtMENIAIION 8

p 10TAL MINIMUH

, NO. OF CHANhELS c INSIRt!Mi til CilANNELS OPERI.BLE 5

" 1. Containment Pres,ure

a. Normal Rar.ge 2 1

b. Extended Range 2 1

2. ' . ter Outlet lemperature - 11101 (Wide Range) 4 2

3. Reactor Coolant inlet Temperature - ICOLD (Wide Range) 4 2

4. Reactor Coolant Pressure - Wide Range 2 1 R

5. Pressurizer Water Level 2 1

6. Steam Generator Pressure 2/ steam generator 1/ steam generator I. Steam Generator Vater Level - Harrow Range 1/ steam generator 1/ steam generator

8. Steam Generator Water Level - Wide Range 1/ steam generator 1/ steam generator

9. Refueling Water Storage Iank Water Level 2 1

10. Heactor Coulant System Subcooling Margin Monitor 2 1

11. Contaisunent Building Water Level 2 1

12. Cere Exit Thermocouples 4/ core quadrant 2/ core quadrant

13. Contaiorr.ent Post-LOCA Ar ea Monitor 2 1 l

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TABLE 3.3-13 (Continuedl TABLE NOTATIONS .

t

At all times. -

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- During CASE 0VS RADWASTE TREATMENT SYSTEM operation. ;

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C** When the gland seal exhauster is in operat on. i ndenser air .

l Noble Gas Monitor for this release point is based on the ma n c -

evacuation monitor. . !

ACTION STATEMENTS i

thway l

ACTION 32 - With the number of channelsleast OPERABLE once f may continue provided the flow rate is estimated at :

per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . ii m i l h y .

With the number of channels QPERA8LE t

i ACTION 33- t least once per ;

j may continue provided grab samples are taken aanalyzed for ra ]

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and these sample -65 may be used as an alternate. ,

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . For RIP 6504 i

IVE GAS l

With the number of channel.s OPERA llected at 8LE l i

ACTION 34 -

WASTE SY3 TEM may continue .

tlowing 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . provid i lear'. once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and analyzed within tha i i ffected i

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ACTION 35 - With the number of channelsl OPERABL ollected l

pathway may continue provided dsamples in the 00CM.are continuo l u with auxiliary samplino equipment as rea ir&

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3/4 3-63 SEABRC0K - UNIT 1 wu

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REACTOR COOLANT SYSTEM

, REACTOR COOLANT LOOPS AND COOLANT CIRCULATION HOT STAN08Y SURVEILLANCE REQUIREMENTS 4.4.1.2.1 At least the abovi required reactor coolant pumps, if not in operation, shall be determined OPERA 8LE once per 7 days by verifying correct breaker alignments ard indicated power availability.

4.4.1.2.2 The required steam generators shal' ba determined E by verify-ing secondary side water level to be greater then or equal t t least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . -

%o 4.4.1.2.3 The required reactor coolant loops shall be verified in operation

, and circulating reactor coolant at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

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SEABROOK - UNIT 1 3/4 4-3

REACTOR COOLANT SYSTEM REACTOR COOLANT LOOPS AND COOLANT CIRCULATION HOT SHUTDOWN SURVEILLANCE REQUIREMENTS 4.4.1.3.1 The required reactor coolant pump (s), i e in operation, shall be determined OPERABLE once per 7 days by verifying . ect breaker alignments and indicated power availability.

i.4.1.3.2 The required steam generator (s) shall be determined OPER by verifying secondary-side water level to be greater than or equal t . at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . /+', o *<

4.4.1.3.3 At least one reactor coolant or RHR loop shall be verified in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

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I SEABROOK - UNIT 1 3/4 4-5

- - - . - . - - - - . - - - . _-- _--__ _ - . . - - - - ._-----..y - - , - - ' =

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REACTOR COOLANT SYSTEM REACTOR COOLANT LOOPS AND COOLANT CIRCULATION COLD SHUTDOWN - LOOPS FILLED LINITING CONDITION FOR OPERATION 3.4.1.4.1 At least one residual heat removal (RHR) loop shall be OPERABLE and in operatior*, and either:

a. One additional RHR loop shall be OPERABLE **, or

b. The secondary-side wat 1 of at least two steam generators shall be greater tha (

'd.o? )

APPLICABILITY: MODE 5 with reactor coolant loops filled ***.

ACTION:

a. With one of the RHR loops inoperable and with less than the requirti steam generator water level, immediately initiate corrective action to return the inoperable RHR loop to OPERABLE status or restore the requirad steam generator water level as soon as possible.

b. With no RHR loop in operation, suspend all operations involving a reduction in boron concentration of the Reactor Coolant System and immediately initiate corrective action to return the required RHR loop to operation.

SURVEILLANCE REQUIREMENTS 1

4.4.1.4.1.1 The secondary side water level of at least two steam generators when required shall be deter >ined to be within Ifmits at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.4.1.4.1.2 At least one RHR loop shall be determined to be in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The RHR pump may be deenergized for up to I hour provided: (1) nr operations are permitted that would cause dilution of the Reactor Coolant e em boron concentration and (2) core outlet temperature is maintained at 10*F below saturation temperature.

- 0ne RHR loop may be inoparable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing provided the other RHR loop is OPERABLE and in operation.

- - A reactor coolant pump shall not be started unless the secondary water temperature of each steam generator is less than 50*F above each of the Reactor Coolant System cold-leg temperatures.

l SEABROOK - UNIT 1 3/4 4-6

CONTAINMENT SYSTEMS PRIMARY CONfAINMENT CONTAINMENT AIR LOCKS LIMITING CONDITION FOR OPERATION 3.6.1.3 Each containment air lock shall be OPERABLE with:

a. Both doors closed except when the air lock is being used for normal transit entry and exit through the containment, then at least one air lock door shall be closed, and

b. An overall air lock leakage rate of less thar or equal to 0.05 L a at P,, 49.6 psig.

APPLICABILITY: MOCES 1, 2, 3, and 4.

ACTION:

a. With one containment air lock door inoperable:

1. Maintain at least the OPERABLE air lock door closed

and either restore the inoperable air lock door to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or lock the OPERABLE air lock door closed,

2. Operation may then continue until performance of the next re-quired overall air lock leakage test provided that the OPERABLE air lock door is verified to be locked closed at least once per 31 days,

3. Otherwise, be in at least HOT STANOBY vithin the nex hours and in COLD SHUTDOWN within the following 30 hour3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months , conc

b. With the containment air lock inoperable, except as the result of an inoperable air lock door, maintain at least one air lock door closed; restore the inoperable air lock to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD i

SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . *

\

4. The provisions of Specification 3.0.4 are not applicable.

i Except during entry to repair an inoperable inner door, for a cumulative tima not to exceed 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per year.

l SEABROOK - UNIT 1 3/4 6-7

. , , -- , ------n

l CONTAINMENT SYSTEMS 9 PRIMARY CONTAINMENT _

CONTAINMENT VENTILATION SYSTEM LIMITING CONDITION FOR OPERATION 3.6.1.7 Each containment purge supply and exhaust isolation valve shall be OPERABLE and:

a. Each 36-inch containmant shutdown purge supply and exhaust isolation valve shall be closed and locked closed, and

b. The 8-inch containment purge supply and exhaust isolation valve (s) shall be sealed closed except when open for purge system operation for pressure control; for ALARA, respitable, and air quality consider-ations to facilitate personnel entry; and for surveill:nce tests that require t W 1ve(s) to be open.

APPLICABILITY: MODES , and 4.

ACTION:

a. With a 36-Inch containment purge supply or exhaust isolation valve open or not locked closed, close and lock closed that valve

)r isolate the penetration (s) within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , otherwise be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTOOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

o. With one or more of the 8-inch containment purge supply or exhaust isolation valves open for reasons other than given in Specifica-tion 3.6.1.7.b above, close the open 8-inch valve (s) or isolate the penetration (s) within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , otherwise be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in COLD SHUTOOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

c. With one or more containment purge supply or exh?ust isolation valves having a nearured leakage rate in excess of tne limits of Specifications 4.6.1.7.2 or 4.6.1.7.3, restore the inoperable valve (s) to OPERABLE status or isolate the affected penetration (s) so that the measured leakage rate does not exceed the limits of Specifications 4.6.1.7.2 or 4.6.1.7.3 within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and close the purge supply if the affected penetration is the exhaust penetration, otherwise be in at least HOT STAN0BY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in COLD SHUTOOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

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SEAHROOK - UNIT 1 3/4 6-12

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT CONTAINMENT VENTILATION SYSTEM SURVEILLANCE REOUIREMENTS 4.6.1.7.1 Each 36-inch containment purge supply and exhaust isol n valve shall be verified to t>e locked closed at least once per 31 days.*

4.6.1.7.2 At least once per 6 months on a STAGGERED TEST BASIO, the inboard d

' and outboard isolation valves with resilient material seals in each sealed closed 36-inch containment purge supply and exhaust penetration shall be demonstrated OPERABLE by verifying that the measured leakage rate is less than or equal to 0.05 L, when pressurized to P,.

4.6.1.7.3 At least once per 92 days each 8-inch containment purge supply and exhaust isolation valve with resilient material seals shall be demonstre.ted OPERABLE by verifying that the measured leakage rate is less than or equal to 0.01 L, when pressurized to P,.

4.6.1.7.4 Each 8-inch containment purge supply and exhaust isolation valve shall be verified to be sealed closed or open in accordanct with Specifi-cation 3.6.1.7.b at least once per 31 days.

1

Containment entry and verification that the inside 36-inch containment purge and exhaust isolation valves are locked closed is not required until a

containment entry is made if no containment entry has been made since the last time the inside 36-inch containment purge and exhaust isolation valves were verified closed.

SEABROOK - UNIT 1 3/4 6-13

- -- " ~* - - '- '-- '- - - - - -----

PLANT SYSTEMS TURBINE CYCLE AUXILIARY FEE 0 WATER SYSTEM SURVEILLANCE REQUIREMENTS 4.7.1.2.la. (Continued)

2) Verifying that the steam turbine-driven pump develops a discharge pressure of greater than or equal to 1460 psig at a flow of greater than or equal to 270 gpm when the secondary steam supply pressure is greater than 500 psig. The provisions of Specification 4.0.4 are not applicable for entry into MODE 3;

3) Verifying that the startup feedwater pump develops a discharge ,

pressure of greater than or equal to 1375 psig at a flow of greater than or equal to 425 gpm; f 4) Verifying that each non-automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in its correct position;

5) Verifying that each automatic valve in the flow path '.s in the fully open position n enever the Auxiliary Feedwater System is placed in automatic control or when above 10% RATER THERMAL POWER; and

6) Verifying that valves FW-156 and FW-163 are OPERAi.t.E for alignment of the startup feedwater pump to the ese 'gency feedwater header.

b. At least cnce per 18 months during shutdown by:

}) Verifying that each automatic valve in the flow path actuates to its correct position upon receipt of an Emergency Feedwater System Actuation test signal;

2) Verifying that each emergency feedwater pump start s designed automatically upon receipt of an Emergency Feedwater Actuation System test signal;

3) Verifying ' hat with all nianuel actions, including power source and valve alignment, the startup feedwater pump starts within the required elapsed time; and

4) '/erifying that each emergency feedwater control valve closes on receipt of a high flow test signal.

14e-the-stea turbine-dt4ven-psp, when-4.he-seeendary-stem :wply presse

) 4s-yhter th:r 500 pir49,-

SEABROOK - UNIT 1 3/4 7-4

EL,ECTRICAL POWER SYSTEMS E_LECTRICAL EQUIPMENT PROTEC7Ib OEVICES CONTAINNENT PENETRATION CONDICTOR OVERCURRENT PROTECTIVE DEVICES AND PROTECTIVE DEVICES FOR CLASS 1E POWER S)URCES CONNECTED TO NON-CLASS lE CIRCulTS LIMITING CONDITION FOR OPERJ 10N, '

3.8.4.2 Each containment pin $trition conductor overcurrent protective device and each protective devica foi Class 1E power sources connected to non-Class 1E circuits shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, 4, 5,* and 6.*

ACTION:

a. With one or t. rare of the containment penetration conductor overcurrent pro-t=ccive device (s) inoperable:

1) Restore the protective device (s) to OPERABLE status or deenergize the circuit (s) by tripping the associated circuit breaker or racking out or removing the inoperable protective device within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , declare the affee.ted system or component inoperable, and verify the circuit breaker to be tripped or the inoperable protectivt device to be racked out or removed at least once per 7 days thereafter; or

2) Be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTOOWN within the following 33 hours3.819444e-4 days 0.00917 hours 5.456349e-5 weeks 1.25565e-5 months .

b. With one or more of the Class IE power source protective device (s) inocer-able, restore the protective device (s) to OPERABLE status or deenergize the circuit (s) by tripping the circuit breaker or racking out or removing the inoperable protective device within 72 Murs, declare the affected com-ponent inoperable, and verify the circuit breakea to be tripped or the inoperable protective device to be racked out or removed at least once per 7 days thereafter.

SURVEILLANCE REQUIREMENTS , 4.8.4.2 Each containment penetration conductor'overcurrent and Class 1E power source protective device shall be demonstrated OPERABLE:

a. At least once per 18 months:

1) By verifying that the medium soltage 13.8-kV and 4.16-kV circuit breakers are OPERABLE by selecting, on a rotating basis, at least one of the circuit breakers, and perfo ming the following:

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0nly fer4 ass-1C pewr source preteethe-4wicos, l"' j g Mont Car (re.tecCre cle rlcx for (? lusi 12 pmer so <w's GoM*'&'I

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i SEADROOK - UNIT 1 3/4 8-21 i

' REFUELJNG OPERATIONS FUEL STORAGE BUILDING EMERGENCY AIO CLEANING SYSTEM SURVEILLANCE REQUIREMENTS 4.9.12b (Continued)

1) Verifying that the cleanup system satisfies the in place penetration and bypass leakage testing acceptance criteria of less than 0.05% and uses the test procedure guidance in Regulatory Positions C.5.a, C.S.c. and C.5.d of Regulatory Guide 1.52, Revision 2, March 1978,* and the system flow rate is 16,450 cfm i 10%;

2) Verifying, within 31 days af ter removal, that a laboratory analysis of a representative carbon sample obtained in accor-dance with Regula6 ry Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978,* meets the laboratory testing criteria of Regula Position C.6.a of Regulatory Guide 1.52, Revision 2, March 19 showing a mett/l iodide penetration of less than 1.0% when tested at a temperature of 30 C and at a relative tu-

' midity of 95% in accordance with ASTH-0-3803; and

3) Verifying a system flow rate of 16,450 cfm 10% during system operation when tested in accoraance witn ANSI N510-1980.

c. Af ter every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of charcoal adsorber operation by verifying, within 31 days after removal, that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulaury Guide 1.52, Revision 2, March 1978,*

meets the laboretory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978,* by showing a methyl iodide peraet.ation of less than 1.0% when tested at a tem-perature of 30*C and at a relative humidity of 95% in accordance with ASTH-0-3803.

d, At least once per 18 months by:

1) Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 6 inches Water Gauge while operating the system at a flow rate of

16,450 cfm i 10%,

2) Verifying that the system maintains the spent fuel storage pool area at a negative pressure of greater than or equal to 1/4 inch Water Gauge relative to the outside atmosphere during system operation.

ANSI NS10-1980 shall be used in place of ANSI N510-1975 as referenced in Regulatory Guide 1.52 Rev. 2, March 1978.

F SEABROOK - UNIT 1 3/4 9-14

( - _ _

- _ __ - ~ _ - - _ -- -

RADIOACTIVE EFFLUENTS GASEOUS EFFLUENTS DOSE - 10 DINE-131, IODINE-133, TRITIUM, AND RADIOACTIVE MATERIAL IN PARTICULATE FORM LIMITING C0kDITION FOR OPERATION 3.11.2.3 The dose to a NdM8ER 0F THE PUBLIC from Iodine-131, Iodine-133, trit-ium, and all radionuclides in particulate form with half-lives greater than

' 8 days in gaseous effluents released, from each unit, to areas at and beyond the SITE BOUNDARY (see Figure 5.1-1) shall be limited to the following:

a. During any calendar quarter: Less than or equal to 7.5 mrems to any organ, and

b. During any calendar year: Less than or equal to 15 mrems to any organ.

APPLICABILITY: At all times.

ACTION:

a. With the calculated dose from the relea'se of Iodine-131. Iodine-133, tritium, and radionuclides in particulate form with half-lives greater than 8 days, in gaseous effluents exceeding any of the above 9 _ 1mits, prepare and submit JAe.the Commission within 30 days, pur-suanc to spectfication o.8.2, a Special Report that identifies the cause(s) for exceeding the limit (s) and defines the corrective ac-tions that have been taken to reduce the releasts and the proposed corrective actions to be taken to assure that subsequent releases will be in compliance with the above limits.

b. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS , 4.11.2.3 Cumulative dose contributions for the current calendar quarter and ,

current calendar year for Iodine-131, Iodine-133, tritium and radionuclides in particulate form with half-lives greater than 8 days shall be determined in accordance with the methodology and parameters in the ODCM at least once per 31 days.

SEABROOK - UNIT 1 3/4 11-7

6.0 ADN'NISTRATIVE CONTROLS ,-

^

6.1 RESPONSI6ILIT]

._ N. i tion and shall delegate in writing the succession to this-l 6.1.1 ' ,

during his absence.

6.1.2 The Shift Superintendent (or during his absence from the control room, ' ' '

a designated individual) shall be responsible for the control room comm i Nuclear function. Production shall be reissued to all station p -

,f.

basis. .

6.2 ORGANIZATION 6.2.1. OFFSITE AND ONSITE ORGANIZATIONS j

Onsite and offsite crganizations shall be established for unit operat f the nuclear power corporate da management, respectively.the Dositions for activities affecting the safet l

pin a.

Lines oi authority, responsibility, and communication shall be

established and defined for the highest management levels throug !

intennediate levels to and including all operating orga positions.

appropriate, in the form of organization charts, functional descriptions for departmental responsibilities and relationships, job descriptions for key personnel positions, or in equiv of docueentation.

.l and updated in accordance with the requirements of 10 CFR 50.71 ,

l b.

The Station Menager shall be responsible for overall unit safe* -

l operation and shall have control over those onsite activities l necessary for safe operation and maintenance of the plant. "

c.

The Vice President - Nuclear Production shall have corporate

^

responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable perf to ensure nuclear safety, f l

d.

The individuals who train the operating staff and those who cari health physics and quality assurance functions may report to the i

appropriate onsite manager; however, they sh ;

pressures.

6-1 SEABROOK - UNIT 1 .

ADMINISTRATIVE CONTROLS RESPONSIBILITIES 6.4.1.7 (Continued) and the Station Manager however, the Station Manager shall have responsibility for resolution of such disagreements pursuant to Specification 6.1.1.

RECORDS 6.4.1.8 The 50RC shall maintain written minutes of each SORC meeting that, at a minimum, document the results of all SORC activities performed under the responsibility provisions of these Technical Specifications. Copies shall be provided to the Vice President-Nuclear Prcduction and the NSARC.

6.4.2 NUCLEARSAFETYAUDITREVIEWCOMMITTEE(NSARCJ FUNCTION 6.4.2.1 The NSARC shall function to provide independent review and audit of designated activitics in the areas of:

a. Nuclear power plant operations,

b. Nuclear engineering,

c. Chemistry and radiochemistry,

d. Metallurgy,

e. Instrumentation and control,

f. Radiological safety,

g. Mechanical and electrical engineering, and

h. Quality assurance practices, ef Ex:ce e,NSABC n thoseshall report areas to and advise of responsibility the NHY specified in Presiden (Specifications 6.4.2.7 an . 2. 8.

COMPOSITION 6.4.2.2 The NSARC shall be composed of at least five (5) individuals. T:.e Chairman,ViceChairmaninndmembers,includipndesignated-alternates be appointed in writing by the NHY President and ._. shall

' :--Executiv: Officce. D Collectively, the individuals appointed to th h @-;;~snoula De competent to conduct reviews identified by Specification 6.4...1. Each member shall meet the qualifications of ANSI 3.1-1978, Section 4.7.

ALTERNATES 6.4.2.3 ILaiternite membeiT'shaLL e appointed in writing by the NHY Presiden :nd Cht:f Ex:cutiv: Of*fc:e to serve on a temporary basis; however, no more t n-e-minnrity shall partic pate at voting members in NSARC activities at any one time.

CONSULTANTS 6.4.2.4 Consultants shall be utilized as determined by the NSARC to provide export advice to the NSARC.

SEABROOK - UNIT 1 6-8

ADMINISTRATIVE CONTROLS AUDITS 6.4.2.8 (Continued) provided the combined time interval for any three consecutive intervals shall not exceed 3.25 times the spec 1ried inte.' val. These audits shall encompass:

a. The conformance of station operation to provisions contained within the Technical Specifications and applicable license conditions at '

least once per 12 months;

b. The performance, training, and qualifications of the entire station staff at least once per 12 months;

c. The results of actions taken to correct deficiencies occurring in station equipment, structures, systems, or method of operation that affect nuclear safety, at least once per 6 months;

d. The performance of activities required by the Operational Quality Assurance Program to meet the criteria of Appendix B,10 CFR Part 50, at least once per 24 months;

e. The fire protection programmatic controls including the implementing procedures at least once per 24 months by qualified licensee QA personnel;

f. The fire protection equipment and program implementation at least once per 12 months utilizing either a qualified offsite licensee fire protaction engineer or an outside independent fire protection consultant. An outside independent fire protection consultant shall be used at least every third year;

g. The Radiological Environmental Monitoring Program and the results thereof at least once per 12 months;

h. The OFFSITE 00SE CALCULATION MANUAL and implementing procedures at least or.ce per 24 months;

i. The PROCESS CONTROL PROGRAN and implementing procedures for processing and packaging of radioactive wastes at least once per 24 months;

j. The performance of activities required by the r.311ty Assurance Program for effluent and environmental monitoring at least once per 12 months;

k. The Emergency Plan and implementing procedures at least once per 12 months;

1. The Security Plan and implementing procedures at least once per 12 months; and

m. Am' other area of station perat.f on-considered-approprjyte by the NdARC or the NHY Presiden d CH:f E :::th: Off':g)

[

SEABROOK - UNIT 1 6-10

ADMINISTRATIVE CONTROLS RE_COROS 6.4.2.0 Records of NSARC activities shall be prepared and distributed as indicated below:

a. liinutes of e4c+rNSARC ineeting repared and forwarded to tne NHY Presiden9 =d Cht:f E=:utive Of'f cer ithin 14 days following ear.n meeting;' -- y

b. Reports of reviews encompassed by Specification 6.4.2.7 shall be included in the minutes where applicabtTTr forwar~dWA sepa-rate cover to the NHY Presiden and CH e' E=cutiv: Offi;;r vithin t 14 days following completion of t eview; and j

c. Audit reports encompp sed _by @ cificetie 4.2.8 shall be forwarded to the NHY Presidented CMef E==tiac Officw nd to the management positions respr.nsibleToT-th reas auditedMtfiTn 30 days after completion of the audit by the auditing organization.

6.5 REPORTABLE EVENT ACTION The following actions shall be taken for REPORTABLE EVENTS:

a. The Commission shall be notified and a report submitted pursuant to the requirements of Section 50.73 to 10 CFR Part 50, and

b. Each kEPORTABLE EVENT shall be reviewed by the 50RC and i.he results of this review shall be submitted to the NSARC and the Vice President-Nuclear Production.

6.6 SAFETY LIMIT VIOLATION The following actions shall be taken in the event a Safety L'11t is violated:

a. The NRC Operations Center shall be notified by telephone as soon as possible and in all cases within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . The Vice President-Nuclear Production and the NSARC shall be notified within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; l

b. A Safety Limit Violation Report shall be prepared. The report shall be reviewed by the 50RC. This report shall describe: (1) applicable circumstances preceding the violation, (2) effects of the violation upon facility components, systems, or structures, and (3) corrective action taken to prevent recurrence;

c. The Safety Limit Violation Report shall be submitted to the Commission, the NSARC, and the Vice President-Nuclear Oroduction within 14 days of the violation; and

d. Operation of the station shall not be resumed until authorized by the Commission.

4 SEABROOK - UNIT 1 6-11

t , . .

ADMINISTRATIVE CONTR0ls PROCEDURES AND PROGRAMS 6.7.4d. (Continued)

1) Training of personnel, and

2) Procedures for monitoring.

e. Post-Accident Sampling A program that will ensure the capability to obtain and analyze reactor coolant, radicactive iodines and particulates in plant gaseous effluents, and containment atmosphere samples under accident conditions. The program shall include the following:

1) Training of personnel,

2) Procedures for sampling and analysis, and

3) Provisions for maintenance of sampling and analysis equipment.

f. Accident Monitoring Instrumentation

A program which will ensure the capabil;ty to monitor plant variables and systems operating status during and following an accident. This program shall include those instruments provided to indicate system operating status and furnish information regaiding the release of radioactive materials (Category 2 a instrumentation as defined in Regulatory Guide 1.97, Revision )d provide the following:

n

1) Preventive maintenance and periodic surveillance o'f instrumentation,

2) Pre planned' operating prccedures and backup instrumentation to be used if one or more monitoring instruments become inoperable, and

3) Administrative procedures for returning inoperable instruments to OPERABLE status as soon as practicable.

6.8 REPORTING REQUIRENENTS ROUTINE REPORTS l 6.8.1 In addition to the applicable reporting requirements of Title 10, Code of Federal Regulations, the following reports shall be submitted to the Regional Administrator of the Regional Office of the NRC ualess othe mise noted.

S_TARTUP REPORT l 6.8.1.1 A summary report of station startup and power escalation testing shall be submitted following: (1) receipt of an Operating License, (2) amendment t2 l

the license involving a planned increase in power level, (3) installation of fuel that has a different design or has been manufactured by a different fuel supplier, and (4) modifications that may have significantly altered the nuclear, l thermal, or hydraulic performance of the station.

l *!mplementatio') of this specification shall take effect when plant goes above 5% power for the first time. ' '

- S o no m ha s is h an en t et u< t- da u hyeris.ns hsfrem t*'* *s swelJa Tif* At.> p G. 4 M7 Rna J . 71e Saw&~.. A e Wr;.% w*/*~<:J- 4 M M he'r 7' s'-r,.M c4 k n ba.ar,- revieArret Ap yfa tisy Sd/fMfL' Qi,* pp 4(, s',

SEABROOK - UNIT 1 6-14

ADMINISTRATIVE CONTROLS

'cMIAN;lAL RADI0 ACTIVE EFFLUENT RELEASE REPORT 6.8.1.4 (Continued) to show conformance with 40 CFR Part 190 Standards for Nuclear Power Operation." , Acceptable methods for calcul the dose Guide 1.109,contribution Rev.1, Octoberfrom 1977. liquid and gaseous effluents are given in Regulatory The Semiannual Radioactive Effluent Release Reports shall include a list and description of unplanned releases from the site to UNRESTRICTED AREAS of radioactive period. materials in gaseous and liquid effluents made during the reporting inade during the reporting period to the PROCESS CON pursuant to Specifications 6.12 and 6.13, respectively, as well as any major change Specification to Liquid, 6.14. Gaseous, or Solid Radweste Treatment Systems pursuant to calculations pursuant ard/or to Specification environmentF 3.12.2. monitoring identified by the land U The Semiannual Radioactive Effluent Release Reports shall also include the following; an explanation as to why the inoperability of liquid or gaseous effluent monitoring instrumentation was not corrected within the time specified in Specification 3.3.3.10 or 3.3.3.11, respectively; and description of the events leading to liquid holdup tanks or gas storage tanks exceeding the limits of Specification 3.11.1.4 or 3.11.2.6, respectively.

MONTHLY OPERATING REPORTS 6.8.1.5 be submitted on a monthly basis to the Dir^cter, Offic: Routine reports of Of 3:0 ur:0 "recenct.

Regional Administrator of the Regional Office of the NRC, no 1 15th of each month following the calendar month covered by the report.

_ RADIAL PEAKING FACTOR LIMIT REPORT A tra: bn mrd,e rm b.s:

G. 8.1. 6 The'F x the limits for RATED THERMAL POWER x (FRTP provided to RegeRC hti:n,Regien U.c y! Wi-itte:t:r with a copy to,vpc ter O!r::y of ";; )ag,n shallg,wa,m,a f.00r .::: tee-

"uch:r 9:guhtery C:=h:ica, '! 3ingt:n, O. C. 20 0 , for all core planes containing Bank "0" control rods and all unrodded core planes and the plot of prc.licted (F Pp ,)) vs Axial Core Height with the limit en-wise approved by the Commission by letter.velope at least 60 days prior to In addition Radial Peaking Factor Limit Report, it will be submitted 60 da date sion by theletter.

limit would become effective unless otherwise approved by the Commis-Any information needed to support F P will be by request from the NRC and need not be included in this report.

SEABROOK - UNIT 1 6-13

@ Nve anh*,,um'y %i>>.. g %,ur +>M ur, z p y/Am Q,,, %

ADMINISTRATIVE CONTROLS SPECIAL REPORTS 4s nua hasrasd.em,4 t&~ b.C..

6.8.2 Special reports shall be submitted to the ":;f:n:1 ".dniif;tr:t:r Of-the 2c6% arr D

$ jgg3} gd#fg7 g# gkg unC within the time period specified for each report. J Arr.U; Le m r Co.orm becr.

6.9 RECORD RETENTION 6.9.1 In addition to the applicable record retention requirements of Title 10, code of Federal Regulations, the following records shall be retained for at least the minimum period indicated.

6.9.2 The following records shall be retained for at least 5 years:

a. Records and logs of statio.: operation covering time interval at each power level;

b. Records and logs of principal maintenance activities, inspections, repair, and replacement of principal items of equipment related to nuclear safety;

c. All REPORTABLE EVENTS;

d. Records of surveillance activities, inspections, and calibrations required by these Technical Specifications;

e. Records of changes made to the procedures required by Specifi-cation 6.7.1;

f. Records cf radioactive shipments;

g. Records of sealed source and fission detector leak tests and results; and I

h. Records of annual physical inventory of all sealed source material of record.

6.9.3 The following records shall be retained for the duration of the station Operating License:

4

a. Records and drawing changes reflecting station design modifications made to systems and equipment described in the Final Safety Analysis Report;

b. Records of new and irradiated fuel inventory, fuel transfers, and assembly burnup histories;

c. Records of radiation exposure for all individuals entering radiation control areas;

d. Records of gaseous and liquid radioactive material released to the environs;

e. Records Of transient or operational cycles for those station compcnents identified in Table 5.7-1; SEABROOK - UNIT 1 6-19

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ML20207N401

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