Text

Proposed Tech Specs Re Surveillance Intervals to Accommodate 24-month Fuel Cycle,Per GL 91-04
	ML20217E887
Person / Time
Site:	Seabrook
Issue date:	04/22/1998
From:	; NORTH ATLANTIC ENERGY SERVICE CORP. (NAESCO)
To:	;
Shared Package
ML20217E848	List: ML20217E844; ML20217E861; ML20217E887;
References
	GL-91-04, GL-91-4, NUDOCS 9804270451
	Download: ML20217E887 (30)
	v • d • e

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I Section II l

Markup of Proposed Changes The attached markups reflects the currently issued revision of the Technical Specifications listed below.

Pending Technical Specifications or Technical Specification changes issued subsequent to this submittal are not reflected in the enclosed markup. Please note that the attached markups which contain the words "during shutdown" are shown as deleted as proposed in LAR 98-02.

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The following Technical Specifications are included in the attached markup:

Technical Specification Title Page(s) 4.1.2.2b & c Boration Flow Paths - Operations 3/41-8

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4.3.3.5.2 Remote Shutdown System 3/4 3-46 4.4.3.2 Pressurizer lleaters 3/4 4-10 4.4.4.1 Relief Valves 3/4 4-12 4.4.6.2.2a. & b. Operational Leakage 3/4 4-23 I 4.4.11.2 Reactor Coolant System Vents 3/4 4-38 4.5.1.ld.1 & 2 Accumulators 3/45-2 4.5.2.d., e, g.2) & h ECCS Subsystems - Tavg Greater Than 3/45-6& i Or Equal to 350 F 3/4 5-7 4.6.3.2 Containment Isolation Valves 3/4 6-17 4.7.1.2. l c. Auxiliary Feedwater 3/47-4 l

i 9804270451 900422 PDR ADOCK 05000443 Page 46 P PDR

REACTIVITY CONTROL SYSTEMS r- BORATION SYSTEMS FLOW PATHS - OPERATING LINITING CONDITION FOR OPERATION 3.1.2.2 At least be OPERA 8LE: two of the following three boron injection flow paths shall a.

The flow path from the boric acid tanks via a boric acid transfer pump and a charging pump to the Reactor Coolant System (RCS), and b.

Two flow pumps paths to the RCS.from the refueling water storage tank via charging APPLICABILITY: MODES 1, 2, and 3*

ACTION:

With only one of the above required boron injection flow paths to the RCS OPERABLE, restare at least two boron injection flow paths to the RCS 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 H0T STAND 8Y and to a SHUTOOWN MARGIN equivalent to at least the limit specified in the CORE OPERATING LIMITS REPORT (COLR) for the above MODES at 200*F, withi )

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next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore at least two flow paths to GPERABLE status within v the next 7 days or be in COLD SHUT 00WN within the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.1.2.2 OPERA 8LE:

At least two of the above required flow paths shall be demonstrated i

a. ,

At least once per 31 days by verifying that each valve (manual, power-operated, sealed, or othe oreautomatic) in the flow path that is not locked, secured in b.

q eptettAG osition,)isinitscorrectposition;

L (;ns p At least once per mo%ths (Wring phytdg@i)by verifying that each I automatic valve in the flow path actuates to its correct position on a safety injection test signal; and 3Rd F'LLELMG *LWreR

c. At least once per@)onth8y ver.#L.(k ifying that the flow path required i by Specification 3.1.2.2a. delivers at least 30 gpa to the RCS.

The provisions of Specifications 3.0.4 and 4.0.4 are not applicable for entry into MD0E 3 for the centrifugal charging pump declared inoperable pursuant to Specification 4.1.2.3.2 provided that the centrifugal charging pump is restored to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or prior to the temperature of one or more of the RC5 cold legs exceeding 375'F, whichever comes first.

SEABROOK - UNIT 1 3/41-8 AnandmentNo.[

99%

f INSTRUMENTATION-l MONITORING INSTRUMENTATION

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l REMOTE SHUTDOWN SYSTEM LIMITING CONDITION FOR UPERATION 3.3.3.5 The Remote Shutdown System transfer switches, power, controls and i monitoring instrumentation channels shown in Table 3.3-9 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

a. With the number of OPERABLE remote shutdown monitoring channels less tnan the Minimum Channels OPERABLE as required by Table 3.3-9, restore the inoperable channel (s) to OPERABLE status within 7 days, or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The provisions of Specifica-tion 3.0.4 are not applicable,

b. With the number of OPERABLE remote shutdown monitoring channels less than the Total Number of Channels as required by Table 3.3-9, within 60 days restore the inoperable channel (s) to OPERABLE status or, pursuant'to Specification 6.8.2, submit a Special Report that defines the corrective action to be taken.

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c. With one or more Remote Shutdown System transfer switches, power, I or control circuits inoperable' restore the inoperable switch (s)/

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, circuit (s) to OPERABLE status within 7 days, or be in HOT STANDBY within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The provisions of Specification 3.0.4 are not applicable. . .

SURVEILLANCE REQUIREMENTS 4.3.3.5.1 Each remote shutdown monitoring instrumentation channel in Table 3.3-9 shall be demonstrated OPERABLE:

a. Every 31 days by performance of a CHANNEL CHECK, and l

b. Every 18 months by performance of a CHANNEL CALIBRATION. ;

4.3.3.5.2 Each Remote Shutdown System transfer switch, power and control circuit listed in Table 3.3-9, including the actuated components, shall be l demonstrated OPERABLE at least once perQympfipp -

WeFGuMG mTEMAL r

3/4 3-46 Y M7 SEABROOK - UNIT 1 dg

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j REACTOR COOLANT SYSTEM -

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. .j 3/4.4.3 PRESSURIZER j LIMITING CONDITION FOR OPERATION -

3.4.3 The pressurizer shall be OPERABLE with a water volume of less than or equal to 92% of pressurizer level (1656 cubic feet), and at least two groups of.

pressurizer heaters each having a capacity of at least 150 kW.

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

a. With only one group of pressurizer heaters OPERABLE, restore at least two groups 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 STANDB7 within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the folicsing 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . "

b. With the pressurizer othenvise inoperable, be in at least HOT STANDBY with the Reactor Trip System breakers open within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REOUIREMENTS 4.4.3.1 The pressurizer water volume shs11 be determined to be within its limit at least once per 12-hours.

4.4.3.2 The capacity of each of the above required groups of pressurizer heaters shall be verified by energizing the heaters from the emergency power '

supply and measuring circuit current at least once each refieling phrval l 4tA CAfs (2 6, 5

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SEABROOK - UNIT 1 3/4 4-10 Amendment No. 70

REACTOR COOLANT SYSTEM RELIEF VALVES _

SURVEILLANCE REQUIREMENTS 4.4.4.1 In addition to the requirements of Specification 4 .5, each PORV shallbedemonstratedOPERABLEatleastonceper(lS'966thsby: 1 i a. Performance of a CHANNEL CALIBRATION, and L RgpqeusG LA M % t l b. Operating the valve through one complete cycle of full travel during MODES 3 or 4. ,l 4.4.4.2 Each block valve shall be demonstrated OPERABLE at least once per 92 days by operating the valve through one complete cycle of full travel unless the block valve is closed with pown- remo',ed in order to meet the requirements of ACTION b. or c. in Specificat- 3.4.4.

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i SEA 8 ROOK - UNIT 1 3/4 4-12 Ame:whent No.)[

REACTOR COOLANT SYSTEM REACTOR COOLANT SYSTEM LEAKAGE .

OPERATIONAL LEAKAGE SURVEILLANCE REQUIREMENTS 4.4.6.2.2 Each Reactor Coolant System Pressure Isolation Valve shall be demonstrated OPERABLE by verifying leakage to be within its limit:

a.

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At least-~once perQ8 mon

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b. Prior to entering MODE 2 whenever the )lant has been in COLD.

SHUTDOWN for 7 days or mor< d if leacage testing has not been performed in the previous nths, l

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c. Prior to returning the valve to service following maintenance, repair, or replacement work on the valve, and

d. Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuation due to automatic or manual action or flow through the valve.'

e. As outlined in the ASME Code,Section XI, paragraph IWV-3427(b).

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The provisions of Specification 4.0-4 are not applicable for entry into MODE 3 or 4.

Not applicable to RHR Pumps 8A and 8B suction isolation valves.

i SEABROOK - UNIT 1 3/4 4-23 AmendmentNo.[

REACTOR COOLANT SYSTEM 3/4.4.11 REACTOR COOLANT SYSTEM VENTS LIMITING CONDITION FOR OPERATION 3.4.11 At least one Reactor Coolant System vent path consisting of one vent valve and one block valve powered from emergency busses shall be OPERABLE and closed

at each of the following locations:

1

a. Reactor. vessel, head, and

b. Pressurizer steam space.

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

ACTION: "

a. With one of the above Reactor Coolant System vent paths ,

inoperable, STARTUP and/or POWER OPERATION may continue provided the inoperable vent path is maintained closed with power removed from the valve actuator of all the vent valves and block valves in i the inoperable vent path; restore the inoperable vent path to i OPERABLE status within 30 days, or, be in HOT STANDBY within 6 ;

hours and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . I

b. With both Reactor Coolant System vent. paths inoperable; maintain the inoperable vent path closed with power removed from the valve actuators of all the vent valves and block valves in the inoperable vent paths, and restore at least one of the vent paths to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE RE0VIREMENTS 4.4.11.1 Each Reactor Coolant System vent path block valve not required to be closed. by ACTION a. or b., above, shall be demonstrated OPERABLE at least once per COLD SHUTDOWN, if not performed within the previous 92 days, by operating the valve through one complete cycle of full travel from the control room.

4.4.11.2 . Each Reactor Cool t System vent path shall be demonstrated OPERABLE atleastonceper@ y: s !

c. - REF4 ell 4 G *.T syIEdAL C4

a. Verifying all manual isolation valves in each vent path are locked in the open position,

For an OPERABLE vent path using a power-operated relief valve (PORV) as the vent path, the PORY block valve is not required to be closed.

SEABROOK - UNIT 1 3/4 4-3B Amendment No.

9, EMERGENC'Y CORE COOLING ' SYSTEMS -

ACCUMULATORS HOT STANDBY. STARTUP. AND POWER OPERATIO.8 SURVEILLANCE REOUIREMENTS 4.5.1.1 (Continued)

2) Verifying that each accumuleor' isolation valve is open.

b. By verifying the boron concentrati. n of the accumulator solution under the following conditions:

1) At least once per 31 days, \

2) Within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of greater than or equal to 1% of tank volume. This s i surveillance is not required when the volume increase makeup j source is the RWST and the RWST has not been diluted since ,

verifying that the RWST boron concentration is equal to or greater than the accumulator boron concentration limit.

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c. At least once per 31 days when the RCS pressure is above 1000 psig by verifying that power to the isolation valve operator is disconnected. pmug xWmMAL MV)

d. At least once perdiVmehths$y verifying that each accumulator )

isolation valve opens automatically'under 'each of the following conditions:

1) When an actual or a simulated RCS pressure signal exceeds the P-11 (Pressurizer Pressure Block of Safety Injection)

Setpoint, and

2) Upon receipt of a Safety Injection test signal.

SEABROOK - UNIT 1 3/4 5-2 AmendmentNo.g i

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EMERGENCY CORE COOLING SYSTEMS ECCS SUBSYSTEMS - Ty GREATER THAN OR E0 VAL TO 350*F SURVEILLANCE REQUIREMENTS 4.5.2 (Continued) RupWG nmN C2d -

d. At least once per :

1) Verifying automatic interlock action of the RHR system from the Reactor Coolant System to ensure that with a simulated or. actual Reactor Coolant System pressure signal greater than or equal to 365 psig, the interlocks prevent the valves from being opened. j

2) A visual inspection of the containment sump and verifying that the subsystem suction inlets are not restricted by debris and that the sump components etc.

st gctu4al,d gs,sofabnormalcorros (trash g racks, screens, ion. ) show no evi

e. Atleastoncep7r GMGf,td : 1

1) Verifying that each automatic valve in the flow path actuates to its correct position on (Safety Injection actuation and Automatic Switchover to Containment Sump) test signals, and

2) Verifying that each of the following pumps start automatically upon receipt of a Safety Injection actuation test signal:

a) Centrifugal charging pump, b) Safety Injection pump, and c) RHR pump. l

f. By verifying that each of the following pumps develops the indicated !

differential pressure on recirculation flow when tested pursuant to Specification 4.0.5:

1) Centrifugal charging pump, t 2480 psid;

2) Safety Injection pump, 2 1445 psid; and

3) RHR pump, 2 171 psid.

SEABROOK - UNIT 1 3/4 5-6 AmendmentNo.J3'

EMERGENCY CORE C00l1NG SYSTEMS ECCS SUBSYSTEMS - T m GREATER THAN OR E00AL_TO 350'F SURVEILLANCE RE0VIREMENTS a

4.5.2 (Continued)

g. By verifying the correct position of each electrical and/or mechanical position stop for the following ECCS throttle valves:

1) Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months following completion of each valve stroking operation or maintenance on the valve when the ECCS subsystems are required to be OPERABLE, and

2) At least' once per@)60pthN !

Hioh Head SI System Intermediate Head SI System Valve Number Valve Number SI-V-143 SI-V-80 SI-V-147 SI-V-85 SI-V-151 SI-V-104 SI-V-155 SI-V-109 SI-V-117 i SI-V-121 SI-V-125 h.

SI-V-129 W

By performing a flow balance test 6drfng/ s~h4td4wp following I completion of modifications to the tCCS subsystems that alter the subsystem flow characteristics and verifying that:

1) For centrifugal charging pump lines, with a single pump running:

a) The sum of the injection line flow rates, excluding the y highest flow rate, is greater than or equal to 306 gpm, -

and b) The total pump flow rate is less than or equal to 549 gpm.

2) For Safety Injection pump lines, with a single pump running:

a) The sum of the injection line flow rates, excluding the highest flow rate, is greater than or equal to 419 gpm, and b) The total pump flow rate is less than or equal to 669 gpm.

3) For RHR pump lines, with a single pump running, the sum of'th'e

! injection line flow rates is greater than or equal to 4213 gpm.

SEABROOK - UNIT 1 3 /G 5-7 Ameid mt Ns. J[

CONTAINMENT SYSTEMS

,_ CONTAINMENT ISOLATION VALVES 1 ,

l SURVEILLANCE REQUIREMENTS 1

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y ach containment t least once isolation perm valve shall be demonstrated OPERABLEM RegguoG zMeda('AV) l l a. Verifying that on a Phase "A" Isolation test signal, each Phase "A" i

Isolation valve actuates to its isolation position,

b. Verifying that on a Phase "B" Isolation test signal, each Phase "B" l Isolation valve' actuates to its isolation position, and

c. Verifying that on a Containment Purge and Exhaust Isolation test signal, each purge and exhaust valve actuates to its isolation position.

4.6.3.3 The isolation time of each power-operated or automatic containment "

isolation valve shall be determined to be within its limit when tested pursuant to Specification 4.0.5.

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I SEABROOK - UNIT I 3/4 6-17 Amendment No.

1 PLANT SYSTEMS

' l' TURBINE CYCLE -

3

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AUXILIARY FEEDWATER SYSTEM SURVEILLANCE REOUIREMENTS 4.7.1.2.la. (Continued)

3) Verifying that valves FW-156 and FW-163 are OPERABLE for d alignment of the startup feedwater pump to the emergency faedwater header.

b. At least once per g2 days on a STAGGERED TEST BASIS by:

1) Verifying that the motor-driven emergency feedwater pump develops a discharge pressure of greater than or equal to 1460 psig at a flow of greater than or equal to 270 gps;

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 gpa when the secondary steam supply pressure is greater than 500 psig.

The provisions of Specification 4.0.4 are not applicable f'or entry into MODE 3;

3) Verifying that the startup feedwater pump develops a l discharge pressure of greater than or equal to 1375 psig at a flow of gre pter hg g uag.q o 425 gpm;

c. At least once perQsggtviydy14 shotatgk> y: [

1) 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 starts as designed automatically upon receipt of an Emergency Feedwater Actuation System test signal;

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

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

SEABROOK - UNIT 1 3/4 7-4 AmendmentNo.g

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SECTION III l Retype of Proposed Changes l

The attached retype reflects the currently issued version of the Technical Specifications. Pending Technical Specification changes or Technical Specification changes issued subsequent to this submittal j are not reflected in the enclosed retype. The enclosed retype should be checked for continuity with

! Technical Specifications prior to issuance. Please note that the attached markups which contain the words "during shutdown" are shown as deleted as proposed in LAR 98-02.

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l Page 47 i

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REACTIVITY CONTROL SYSTEMS BORATION CONTROL FLOW PATHS - OPERATING LIMITING CONDITION FOR OPERATION 3.1.2.2 At least two of the following three boron injection flow paths shall be OPERABLE:

a. The flow path from the boric acid tanks via a boric acid transfer pump and a charging pump to the Reactor Coolant System (RCS), and

b. Two flow paths from the refueling water storage tank via charging pumps to the RCS.

APPLICABILITY: MODES 1. 2. and 3*

ACTION:

With only one of the above required baron injection flow paths to the RCS OPERABLE restore at least two boron injection flow paths to the RCS 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 STANDBY and borated to a SHUTDOWN MARGIN equivalent to at least the limit specified in the CORE OPERATING LIMITS REPORT (COLR) for the above MODES at 200 F within the next 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months s: restore at least two flow paths to OPERABLE status within the next 7 days or be in COLD SHUTDOWN within the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . I SURVEILLANCE REQUIREMENTS 4.1.2.2 At least two of the above required flow paths shall be demonstrated OPERABLE:

a. At least once per 31 days by verifying 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:

b. At least once per REFUELING INTERVAL (24) by verifying that each I automatic valve in the flow path actuates to its correct position '

on a safety injection test signal; and j

c. At least once per REFUELING INTERVAL (24) by verifying that the l flow path required by Specification 3.1.2.2a. delivers at least 30 gpm to the RCS.

The provisions of Specifications 3.0.4 and 4.0.4 are not applicable for entry into MODE 3 for the centrifugal charging pump declared inoperable pursuant to Specification 4.1.2.3.2 provided that the centrifugal charging pump is ;

restored to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or prior to the temperature of one '

or more of the RCS cold legs exceeding 375 F. whichever comes first.

SEABROOK - UNIT 1 3/4 1-8 Amendment No. 9

INSTRUMENTATIOy MONITORING INSTRUMENTATION REMOTE SHUTDOWN SYSTEM LIMITING CONDITION FOR OPERATION 3.3.3.5 The Remote Shutdown System transfer switches, power. controls and monitoring instrumentation channels shown in Table 3.3-9 shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3.

ACTION:

a. With the number of OPERABLE remote shutdown monitoring channels less than the Minimum Channels OPERABLE as required by Table '

3.3-9. restore the ino3erable channel (s) to OPERABLE status within 7 days, or be in HOT SiUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The provisions of Specification 3.0.4 are not applicable.

, b. With the number of OPERABLE remote shutdown monitoring channels .

less than the Total Number of Channels as required by Table 3.3-9. I within 60 days restore the inoperable channel (s) to OPERABLE status or, pursuant to Specification 6.8.2. submit a Special Report that defines the corrective action to be taken,

c. With one or more Remote Shutdown System transfer switches power.

or control circuits inoperable, restore the inoperable switch (s)/

circuit (s) to OPERABLE status within 7 days, or be in HOT STANDBY within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The provisions of Specification 3.0.4 are not applicable. ,

SURVEILLANCE REQUIREMENTS 4.3.3.5.1 Each remote shutdown monitoring instrumentation channel in Table 3.3-9 shall be demonstrated OPERABLE: ,

a. Every 31 days by performance of a CHANNEL CHECK. and

b. Every 18 months by performance of a CHANNEL CALIBRATION.

4.3.3.5.2 Each Remote Shutdown System transfer switch, power and control circuit listed in Table 3.3-9. including the actuated components, shall be demonstrated OPERABLE at least once per REFUELING INTERVAL (24).

l SEABROOK - UNIT 1 3/4 3-46

REACTOR COOLANT SYSTEM 3/4.4.3 PRESSURIZER LIMITING CONDITION FOR OPERATION 3.4.3 The pressurizer shall be OPERABLE with a water volume of less than or equal to 92% of pressurizer level (1656 cubic feet), and at least two groups of pressurizer heaters each having a capacity of at least 150 kW.

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

a. With only one group of 3ressurizer heaters OPERABLE restore at least two groups 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 STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

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b. With the pressurizer otherwise inoperable, be in at least HOT ;

STANDBY with the Reactor Tri) System breakers open within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 1 and in HOT SHUTDOWN within t1e following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REOUIREMENTS 4.4.3.1 The pressurizer water volume shall be determined to be within its limit at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . ;

i 4.4.3.2 The capacity of each of the above required groups of pressurizer heaters shall be verified by energizing the heaters from the emergency power ;

supply and measuring circuit current at least once each REFUELING INTERVAL !

(24).

i SFABROOK - UNIT 1 3/4 4-10 Amendment No. 30

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REACTOR COOLANT SYSTEM j RELIEF VALVES SURVElLLANCE REQUIREMENTS 4.4.4.1 In addition to the requirements of Specification 4.0.5. each PORV shall be demonstrated OPERABLE at least once per REFUELING INTERVAL (24) by:

a. Performance of a CHANNEL CALIBRATION. and

b. Operating the valve through one complete cycle of full travel I during MODES 3 or 4. I 4.4.4.2 Each block valve shall be demonstrated OPERABLE at least once per 92 days by operating the valve through one complete cycle of full travel unless the block valve is closed with power removed in order to meet the requirements ;

of ACTION b. or c. in Specification 3.4.4. l i

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l SEABROOK - UNIT 1 3/4 4-12 Amendment No. M

REACTOR COOLANT SYSTEM 1

REACTOR COOLANT SYSTEM LEAKAGE OPERATIONAL LEAKAGE SURVEILLANCE REOUIREMENTS 4.4.6.2.2 Each Reactor Coolant System Pressure Isolation Valve shall be demonstrated OPERABLE by verifying leakage to be within its limit:

a. At least once per REFUELING INTERVAL (24).

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b. Prior to entering MODE 2 whenever the )lant has been in COLD SHUTDOWN for 7 days or more and if leacage testing has not been performed in the previous 12 months. I

c. Prior to returning the valve to service following maintenance, repair, or replacement work on the valve, and

d. Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuatio manual action or flow through the valve.p due to automatic or

e. As outlined in the ASME Code.Section XI. paragraph IWV-3427(b).

The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or 4.

Not applicable to RHR Pumps 8A and 8B suction isolation valves.

l SEABROOK - UNIT 1 3/4 4-23 Amendment No. 30.44

REACTOR COOLANT SYSTEM 3/4.4 11 REACTOR COOLANT SYSTEM VENTS LIMITING CONDITION FOR OPERATION 3.4.11 At least one Reactor Coolant System vent )ath consisting of one vent valve and one block valve powored from emergency Jusses shall be OPERABLE and closed

at each of the following locations:

a. Reactor vessel head, and

b. Pressurizer steam space.

APPLICABILITY: MODES 1. 2. 3. and 4.

ACTION:

a. With one of the above Reactor Coolant System vent paths inoperable. STARTUP and/or POWER OPERATION may continue provided the inoperable vent path is maintained closed with )ower removed from the valve actuator of all the vent valves and alock valves in the ino)erable vent path: restore the' inoperable vent path to OPERABLE status within 30 days, or, be in HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ,

b. With both Reactor Coolant System vent paths inoperable maintain i the inoperable vent path closed with )ower removed from the valve actuators of all the vent valves and alock valves in the inoperable vent paths, and restore at least one of the vent paths to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE RE0UIREMENTS 4.4.11.1 Each Reactor Coolant System vent path block valve not required to be closed by ACTION a. or b., above, shall be demonstrated OPERABLE at least once per COLD SHUTDOWN. if not performed within the previous 92 days, by operating the valve through one complete cycle of full travel from the control room.

4.4.11.2 Each Reactor Coolant System vent path shall be demonstrated OPERABLE at least once per REFUELING INTERVAL (24) by: l

a. Verifying all manual isolation valves in each vent path are locked in the open position.

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For an OPERABLE vent path using a power-operated relief valve (PORV) as the vent path, the PORV block valve is not required to be closed. j SEABROOK - UNIT 1 3/4 4-38 Amendment No. 30 l

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EMERGENCY CORE COOLING SYSTEMS ACCUMULATORS i

l HOT STANDBY. STARTUP. AND POWER OPERATION l SURVEILLANCE REQUIREMENTS 4.5.1.1 (Continued) l 2) Verifying that each accumulator isolation valve is open, i b. By verifying the boron concentration of the accumulator solution

! under the following conditions:

1) At least once per 31 days.

2) Within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of greater than or equal to 1% of-tank volume. This surveillance is not required when the volume increase makeup source is the RWST and the RWST has not been diluted since verifying that the RWST boron concentration is equal to or 4 greater than the accumulator boron concentration limit.

c. At least once 3er 31 days when the RCS pressure is above 1000 psig by verifying tlat power to the isolation valve operator is disconnected.

d. At least once per REFUELING INTERVAL (24) by verifying that each l accumulator isolation valve opens automatically under each of the following conditions:

1) When an actual or a simulated RCS ressure signal exceeds the P-11 (Pressurizer Pressure Blo k of Safety Injection)

Setpoint, and

2) Upon receipt of a Safety Injection test signal.

1 i

) SEABROOK - UNIT 1 3/4 5-2 Amendment No. 30

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EMERGENCY CORE COOLING SYSTEMS ECCS SUBSYSTEMS - T GREATER THAN OR EDUAL TO 350 F SURVEILLANCE REQUIREMENTS I

, 4.5.2 (Continued)

d. At least once per REFUELING INTERVAL (24) by: l

1) Verifying automatic interlock action of the RHR system from '

the Reactor Coolant System to ensure that with a simulated ,

or actual Reactor Coolant System pressure signal greater !

than or equal to 365 psig, the interlocks prevent the valves from being opened.

2) A visual inspection of the containment sump and verifying that the subsystem suction inlets are not restricted by debris and that the sump components (trash racks screens.

etc.) show no evidence of structural distress or abnormal corrosion. 1

e. At least once per REFUELING INTERVAL (24) by:

1) Verifying that each automatic valve in the flow path actuates to its correct position on (Safety Injection actuation and Automatic Switchover to Containment Sump) test signals, and

2) Verifying that each of the following pumps start automatically upon receipt of a Safety Injection actuation test signal:

a) Centrifugal charging pump, b) Safety Injection pump, and c) RHR pump.

f. By verifying that each of the following pumps develops the indicated differential pressure on recirculation flow when tested pursuant to Specification 4.0.5:

1) Centrifugal charging pump, a 2480 psid:

2) Safety Injection pump, a 1445 psid: and

3) RHR pump. 2 171 psid.

SEABROOK - UNIT 1 3/4 5-6 Amendment No. 3. 33

EMERGENCY CORE COOLING SYSTEMS ECCS SUBSYSTEMS - T GREATER THAN OR EDUAL TO 350 F SURVEILLANCE REOUIREMENTS 4.5.2 (Continued) 9 By verifying the correct position of each electrical and/or mechanical position stop for the following ECCS throttle valves:

1) Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months following completion of each valve stroking operation or maintenance on the valve when the ECCS subsystems are required to be OPERABLE. and

2) At least once per REFUELING INTERVAL (24). l Hiah Head SI System Intermediate Head SI System Valve Number Valve Number SI-V-143 SI-V-80 SI-V-147 SI-V-85 SI-V-151 SI-V-104 SI-V-155 SI-V-109 SI-V-117 SI-V-121 SI-V-125 SI-V-129

h. By performing a flow balance test following completion of I modifications to the ECCS subsystems that alter the subsystem flow characteristics and verifying that:

1) For centrifugal charging pump lines, with a single pump running:

a) The sum of the injection line flow rates, excluding the highest flow rate. is greater than or equal to 306 gpm.

and b) The total pump flow rate is less than or equal to 549 gpm.

2) For Safety Injection pump lines, with a single pump running:

a) The sum of the injection line flow rates, excluding the highest flow rate. is greater than or equal to 419 gpm.

and b) The total pump flow rate is less than or equal to 669 gpm.

3) For RHR pump lines, with a single pump running, the sum of the injection line flow rates is greater than or equal to 4213 gpm.

SEABROOK - UNIT 1 3/4 5-7 Amendment No. 24, 33

CONTAINMENT SYSTEMS CONTAINMENT ISOLATION VALVES SURVEILLANCE REQUIREMENTS 4.6.3.2 Each containment isolation valve shall be demonstrated OPERABLE at least once per REFUELING INTERVAL (24) by:

a. Verifying that on a Phase "A" Isolation test signal, each Phase "A" Isolation valve actuates to its isolation position,

b. Verifying that on a Phase "B" Isolation test signal each Phase "B" Isolation valve actuates to its isolation position and

c. Verifying that on a Containment Purge and Exhaust Isolation test signal. each purge and exhaust valve actuates to its isolation position.

4.6.3.3 The isolation time of each power-operated or automatic containment isolation valve shall be determined to be within its limit when tested pursuant to Specification 4.0.5.

SEABROOK - UNIT 1 3/4 6-17 Amendment No. 44. 34

PLANT SYSTEMS TURBlNE CYCLE AUXILIARY FEEDWATER SYSTEM SURVEILLANCE RE0UIREMENTS 4.7.1.2.la. (Continued)

3) Verifying that valves FW-156 and FW-163 are OPERABLE for alignment of the startup feedwater pump to the emergency feedwater header.

b. At least once per 92 days on a STAGGERED TEST BASIS by:

1) Verifying that the motor-driven emergency feedwater pump develops a discharge pressure of greater than or equal to 1460 psig at a flow of greater than or equal to 270 gpm;

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;

c. At least once per REFUELING INTERVAL (24) by: 1

1) 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 starts as designed automatically upon receipt of an Emergency Feedwater Actuation System test signal:

3) Verifying that with all manual actions, including power source and valve alignment, the startup feedwater pump starts within the required elapsed time: and

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

SEABROOK - UNIT 1 3/4 7-4 Amendment No. 30

1 Section IV Determination of Significant Hazards for Proposed Change 1

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i IV. i DETERMINATION OF SIGNIFICANT HAZARDS FOR PROPOSED CHANGES j License Amendment Request (LAR) 98-04 is the third submittal in a planned series of License Amendment Requests which propose changes to the Seabrook Station Technical Specifications to accommodate fuel cycles of up to 24 months. The proposed changes are associated with surveillance requirements that are currently performed at each 18-month or other outage interval. The License '

Amendment Request has been prepared in accordance with the generic guidance contained in NRC Generic Letter (GL) 91-04, " Changes in Technical Specification Surveillance Intervals To Accommodate A 24-Month Fuel Cycle." i l

i The Technical Specifications proposed to be amended are:

l 4.1.2.2b & c Boration Flow Paths - Operations 4.3.3.5.2 Remote Shutdown System 4.4.3.2 Pressurizer Heaters 4.4.4.1 Relief Valves 4.4.6.2.2a. & b. Operational Leakage 4.4.11.2 Reactor Coolant System Vents 4.5.1.1d.1 & 2 Accumulators 4.5.2.d., e, g.2) & h ECCS Subsystems - Tavg Greater Than Or Equal to 350 F 4.6.3.2 Containment Isolation Vaives !

4.7.1.2. l c. Auxiliary Feedwater I Furthermore, the components addressed by the following additional surveillance requirements (which need no wording changes) have been evaluated to support an extension in frequen:y to accommodate fuel cycles of up to 24 months.

4.6.3.1 & 4.6.3.3 Containment Isolation Valves 4.7.1.2.2 Auxiliary Feedwater Flow Paths 4.7.1.5 Main Steam Line Isolation Valves 4.7.1.6 Atmospheric Relief Valves In accordance with 10 CFR 50.92, North Atlantic has reviewed the proposed changes and has concluded that they do not involve a significant hazards consideration (SIIC). The basis for the conclusion that the proposed changes do not involve a SHC is as follows:

1. The proposed changes do not involve a significant increase in the probability or consequences of an accident previously evaluated.

The proposed changes have no adverse affect on accident initiators or precursors nor alter the design assumptions, conditions, configuration of the facility or the manner in which the plant is operated. The proposed changes do not alter or prevent the ability of structures, systems, or components (SSCs) to perform their intended function to mitigate the consequences of an initiating event within the acceptance limits assumed in the Updated Final Safety Analysis Report (UFSAR). The proposed changes are administrative in nature and do not change the level of programmatic controls or the procedural details associated with afercmentioned surveillance requirements.

Page 49

Changing the frequencies of the aforementioned surveillance requirements from at least once per 18 months to at least once per refueling interval does not change the basis for the frequencies.

The frequencies were chosen because of the need to perform these verifications under the conditions that are normally found during a plant refueling outage, and to avoid the potential of an unplanned transient if these surveillances were conducted with the plant at power.

Equipment performance over several operating cycles was evaluated to determine the impact of extending the surveillance intervals. This evaluation included a review of surveillance results, preventative maintenance records, and the frequency and type of corrective maintenance activities., and a failure mode analysis. The evaluations conclude that the subject SSCs are reliable, presently exhibiting no time dependent failure modes of significance, and that b : no indication that the proposed extension could cause deterioration in the condition or pen nnance of the subject SSCs. There are no known mechanisms that would significantly degrade the performance of the evaluated equipment during normal plant operation. Although there have been generic or repetitive failures of some components in the past, which may have affected the ability of the SSCs to consistently and successfully perform their safety function, those items have been resolved through design changes and rework such that they have not recurred. There have been no repetitive failures or time dependent failures that were significant in nature which would have prevented the SSCs from performing their intended safety function.

Deletion of the restriction "during shutdown" where this restriction is stated will permit performance of certain maintenar,ce and testing activities during conditions or modes other than shutdown. North Atlantic will ensuit, through the implementation of administrative controls that proper regard to their effect on safe operation of the plant is given prior to conduct of a particular surveillance in a condition or mode other than shutdown.

Since the proposed changes only affect the surveillance intervals for SSCs that are used to mitigate accidents, the changes do not affect the probability or consequence of a previously analyzed accident. While the proposed changes will lengthen the intervals between surveillances, the increase in intervals has been evaluated. Based on the reviews of the surveillance tests, inspections, and maintenance activities, it is concluded that there is no significant adverse impact on the reliability or availability of these SSCs.

Since there are no changes to previous accident analyses, the radiological consequences associated with these analyses remain unchanged, therefore, the proposed changes do not involve a significant increase in the probability or consequences of an accident previously evaluated.

2. The proposed changes do not create the possibility of a new or different kind of accident from any presiously analyzed.

The proposed changes do not alter the design assumptions, conditiens, configuration of the facility or the manner in which the plant is operated. There are no changes to the source term, containment isolation or radiological release assumptions used in evaluating the radiological consequences in the Seabrook Station UFSAR. Existing system and component redundancy is not being changed by the proposed changes. The proposed changes have no adverse impact on component or system interactions. The proposed changes are administrative in nature and do not change the level of programmatic controls and procedural details associated with the aforementioned surveillance requirements. Therefore, since there are no changes to the design Page 50

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assumptions, conditions, configuration of the facility, or the manner in which the plant is operated and surveilled, the proposed changes do not create the possibility of a new or different kind of accident from any previously analyzed.

3. The proposed changes do not involve a significant reduction in a margin of safety.

There is no adverse impact on equipment design or operation and there are no changes being made to the Technical Specification required safety limits or safety system settings that would adversely affect plant safety. The proposed changes are administrative in nature and do not change the level of programmatic controls and procedural details associated with the aforementioned surveillance requirements.

From the evaluations performed on the subject SSCs there are no indications that potential problems would be cycle-length dependent or that potential degradation would be significant for the time frame of interest and, therefore, increasing the surveillance interval to the bounding limit of 30 months (24 months plus 25%) will have little, if any, impact on safety.

The proposed changes to the surveillance intervals are still consistent with the basis for the intervals and the intent and method of performing the surveillance is unchanged. Deletion of the restriction "during shutdown" where this restriction is stated will permit performance of certain maintenance and testing activities during conditions or modes other than shutdown. North Atlantic will ensure, through the implementation of appropriate administrative controls, that proper regard to their effect on safe operation of the plant is given prior to conduct of a particular surveillance in a condition or mode other than shutdown. In addition, use of the subject SSCs during normal plant operation, combined with their previous history of availability and reliability, provide assurance that the proposed changes will not affect the reliability of the subject SSCs. Thus, it is concluded that the subject SSCs would be available upon demand to 3 mitigate the consequences of an accident and, therefore, there is no significant reduction in a I margin of safety.

Based on the above evaluation, North Atlantic concludes that the proposed changes do not constitute a significant hazard.

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l Sectichs y & y1 Proposed Schedule for License Amendment issuance and L'ffectiveness and EnvironmentalImpact Assessnsent

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V. l PROPOSED SCHEDULE FOR LICENSE AMENDMENT ISSUANCE AND l EFFECTIVENESS North Atlantic requests NRC review of License Amendment Request 98-04 and issuance of a license amendment by October 22,1998, having immediate effectiveness and implementation required within 60 days.

VI. ENVIRONMENTAL IMPACT ASSESSMENT North Atlantic has reviewed the proposed license amendment against the criteria of 10CFR51.22 for environmental considerations. The proposed changes do not involve a significant hazards consideration, nor increase the types and amounts of effluent that may be released offsite, nor significantly increase i individual or cumulative occupational radiation exposures. Based on the foregoing, North Atlantic l concludes that the proposed change meets the criteria delineated in 10CFR51.22(c)(9) and l 10CFR51.22(c)(10) for a categorical exclusion from the requirements for an Environmental Impact Statement.

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ML20217E887

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