Text

Amends 57 & 38 to Licenses NPF-9 & NPF-17,respectively, Changing Tech Specs to Permit Full Power Operation W/Upper Head Injection Accumulator Sys Removed or Disabled
	ML20210S194
Person / Time
Site:	McGuire, Mcguire
Issue date:	05/13/1986
From:	Youngblood B; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML20210S199	List: ML20210S194; ML20210S213; ML20210S236;
References
	NUDOCS 8605200459
	Download: ML20210S194 (22)
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..

ATTACHMENT TO LICENSE AMENDMENT NO. 57 FACILITY OPERATING LICENSE NO. NPF-9 DOCKET NO. 50-369 AND TO LICENSE AMENDMENT NO. 38 FACILITY OPERATING LICENSE NO. NPF-17

. DOCKET NO. 50-370 Replace the following pages of the Appendix "A" Technical Specifications with the enclosed pages. The revised pages are identified by Amendment number and contain vertical lines indicating the areas of change. The corresponding over-leaf pages are also provided to maintain document completeness.

s Amended Overleaf Page Page 3/4 4-21 3/4 4-22 3/4 5-1 3/4 5-2a 3/4 5-2b 3/4 5-3 3/4 5-3a 3/4 5-3b 3/4 5-4 3/4 6-3 3/4 6-5 3/4 6-6 3/4 6-26 3/4 6-25 3/4 8-21 3/4 8-22

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3/4 8-60 3/4 8-61 3/4 8-62 8 3/4 5-1 B 3/4 5-la B 3/4 5-2 8605200459 860515 PDR ADOCK 05000369 P

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TABLE 3.4-1 REACTOR COOLANT SYSTEM PRES 3URE ISOLATION VALVES VALVE NUMBER FUNCTION MC-1562-2.0 NI60 Accumulator Discharge NI71 Accumulator Discharge NI59 Accumulator Discharge NI70 Accumulator Discharge MC-1562-2.1 NI82 Accumulator Discharge NI94 Accumulator Discharge NI81 Accumulator Discharge NI93 Accumulator Discharge MC-1562-3.0 nil 34 Safety Injection (Hot Leg)

NI159 Safety Injection (Hot Leg)

NI156

~ Safety Injection (Hot Leg)

NI128 Safety Injection (Hot Leg)

NI124 Safety Injection (Hot Leg)

NI160 Safety Injection (Hot Leg)

NI157 Safety Injection (Hot Leg)

NI126 Safety Injection (Hot Leg)

NI129 Safety Injection (Hot Leg)

NI125 Safety Injection (Hot Leg)

MC-1562-3.1 NI165 Safety Injection / Residual Heat Removal (Cold Leg)

NI167 Safety Injection / Residual Heat Removal (Cold Leg)-

NI169 Safety Injection / Residual Heat Removal (Cold Leg)

NI171 Safety Injection / Residual Heat Removal (Cold Leg)

NI175 Safety Injection / Residual Heat Removal (Cold Leg)

NI176 Safety Injecf. ion / Residual Heat Removal (Cold Leg)

NI180 Safety Injection / Residual Heat Removal (Cold Leg)

NI181 Safety Injection / Residual Heat Removal (Cold Leg)

MC-1562-4.0 NI250 Upper Head Injection NI251 Upper Head Injection NI252 Note 1 Upper Head Injection NI253 Upper Head Injection NI249 Upper Head Injection NI248 Upper Head Injection MC-1561-1.0 NDIB" Residual Heat Removal ND2A*

Residual Heat Removal

" Testing per Specification 4.4.6.2.2d not applicable due to positive indication of valve position in Control Room.

Note 1: Upon the deactivation of the UHI System by removal of related compo-nents and piping and modifications to the Cold Leg Accumulators, this specification is no longer applicable.

McGUIRE - UNITS 1 and 2 3/4 4-21 Amendment No. 57 (Unit 1)

Amendment No. 38 (Unit 2) r

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4 REACTOR COOLANT SYSTEM 3/4.4.7 CHEMISTRY LIMITING CONDITION FOR OPERATION 3.4.7 The Reactor Coolant System chemistry shall be maintained within the limits specified in Table 3.4-2.

APPLICABILITY:

At all times.

ACTION:

MODES 1, 2, 3, and 4:

With any one or m're chemistry parameter in excess of its Steady o

a.

Stats Limit but within its Transient Limit, restore the parameter to within its Steady-State Limit 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 SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; and e

b.

With any one or more chemistry parameter in excess of its Transient Limit, be in at least 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 .

At All Other Times:

With the concentration of either chloride or fluoride in the Reactor Coolant System in excess of its Steady-State Limit for more than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or in excess of its Transient Limit, reduce the pressurizer pressure to less than or equal to 500 psig, if applicable, and perform an engineering evaluation to determine the effects of the out-of-limit condition on the structural integrity of the Reactor Coolant System; determine that the Reactor Coolant System remains acceptable for continued operation prior to increasing the pressurizer pressure above 500 psig or prior to proceeding to MODE 4.

SURVEILLANCE REQUIREMENTS 4.4.7 The Reactor Coolant System chemistry shall be determined to be within the limits by analysis of those parameters at the frequencies specified in Table 4.4-3.

1

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McGUIRE - UNITS 1 and 2 3/4 4-22

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3/4.5 EMERGENCY CORE COOLING SYSTEMS 3/4.5.1 ACCUMULATORS COLD LEG INJECTION LIMITING CONDITION FOR OPERATION 2

3.5.1.1 Each cold leg injection accumulator shall be OPERABLE with:

a.

The isolation valve open, b.

A contained borated water volume of between 6870 and 7342 gallons, l

c.

A boron concentration of between 1900 and 2100 ppm, d.

A nitrogen cover pressure of between 585 and 639 psig, and l

p water level and pressure channel OPERABLE.

e.

APPLICABILITY: MODES 1, 2, and 3*.

(UHI physically disconnected or isolation valves closed. Cold Leg Accumulators and discharge paths suit-ably modified.)

ACTION:

a.

With one accumulator inoperable, except as a result of a closed isolation valve, restore the inoperable accumulator to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 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 reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

With 'on'el accumulator inoperable due to the isolation valve being closed, either immediately open the isolation valve or be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

i SURVEILLANCE REQUIREMENTS 4.5.1.1.1 Each cold leg injection accumulator shall be demonstrated OPERABLE:

a.

At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by:

1)

Verifying the contained borated water volume and nitrogen cover pressure in the tanks, and 2)

Verifying that each cold leg injection accumulator isolation valve is open.

Pressurizer pressure above 1000 psig.

McGUIRE - UNITS 1 and 2 3/4 5-1 Amendment No. 57 Amendment No. 38 (Unit 1)

(Unit 2)

3/4.5 EMERGENCY CORE COOLING SYSTEMS 3/4.5.1 ACCUMULATORS COLD LEG INJECTION LIMITING CONDITION FOR OPERATION 3.5.1.2 Each cold leg injection accumulator shall be OPERABLE with:

a.

The isolation valve open, b.

A contained borated water volume of between 8022 and 8256 gallons, c.

A boron concentration of between 1900 and 2100 ppe, d.

A nitrogen cover pressure of between 430 and 484 psig, and e.

A water level and pressure channel OPERABLE.

APPLICABILITY: MODES 1, 2, and 3*.

(UHI operability required).

ACTION:

a.

With one accumulator inoperable, except as a result of a closed isolation valve, restore the inoperable accumulator to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 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 reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

]

b.

With one accumulator inoperable due to the isolation valve being closed, either immediately open the isolation valve or be in at least

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HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REQUIREMENTS 4.5.1.2.1 Each cold leg injection accumulator shall be demonstrated OPERABLE:

a.

At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by:

1)

Verifying the contained borated water volume and nitrogen cover pressure in the tanks, and 2)

Verifying that each cold leg injection accumulator isolation valve is open.

Pressurizer pressure above 1000 psig.

McGUIRE - UNITS 1 and 2 3/4 5-2a Amendment No. 57 (Unit 1)

Amendment No. 38 (Unit 2)

4 6

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EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b.

At least once per 31 days and 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 by verifying the boron concentration of the accumulator solution; c.

At least once per 31 days when the RCS pressure is above 2000 psig by verifying that power to the isolation valve operator is disconnected by removal of the breaker from the circuit.

4.5.1.2.2 Each cold leg injection accumulator water level and pressure channel shall be demonstrated OPERABLE:

a.

At least once per 31 days by the performance of an ANALOG CHANNEL OPERATIONAL TEST, and b.

At least once per 18 months by the performance of a CHANNEL EALIBRATION.

T h

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i McGUIRE - UNITS I and 2 3/4 5-2b Amendment No.57 (Unit 1)

. Amendment No.38 (Unit 2)

EMERGENCY CORE COOLING SYSTEMS 3/4.5.1.3,4 UPPER HEAD INJECTION

[ Deleted upon physical removal of the system]

4 s

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McGUIRE - UNITS 1 and 2 3/4 5-3 Amendment No. 38 (Unit 2)

Amendment No. 57 (Unit 1)

_ -, = _. -. _ _ _ -.

EMERGENCY CORE COOLING SYSTEMS UPPER HEAD INJECTION LIMITING CONDITION FOR OPERATION 3.5.1.3 Each Upper Head Injection Accumulator shall be OPERABLE with:

a.

The isolation valves open, b.

The water-filled accumulator containing a minimum of 1850 cubic feet of borated water having a concentration of between 1900 and i

2100 ppe of boron, and c.

The nitrogen bearing accumulator pressurized to between 1206 and 1264 psig.

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

(UHI cperability required. Cold leg accumulators and discharge paths not suitably modified.)

i I

ACTION:

1 a.

With the Upper Head Injection Accumulator System inoperable, except as a result of a closed isolation valve (s), restore the Upper Head Injection Accumulator System to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 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 reduce pressur-izer pressure to less than 1900 psig within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

With the Upper Head Injection Accumulator System inoperable due to the isolation valve (s) being closed, either immediately open the isolation valve (s) or be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and reduce pressurizer pressure to less than 1900 psig within the follow-ing 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REQUIREMENTS 4.5.1.3 Each Upper Head Injection Accumulator System shall be demonstrated OPERABLE:

a.

At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by:

1)

Verifying the contained borated water volume and nit'rogen pressure in the accumulators, and 2)

Verifying that each accumulator isolation valve is open.

I

Pressurizer pressure above 1900 psig.

McGUIRE - UNITS 1 and 2 3/4 S-3a Amendment No. 57 (Unit 1)

Amendment No. 38 (Unit 2) 1

EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b.

At least once per 31 days and 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 by verifying the boron concentration of the solution in the water-filled accumulator; c.

At least once per 18 months by:

1)

Verifying that each accumulator isolation valve closes automatically when an actual or simulated water level signal of 76.25 1 3.3 inches above the bottom inside edge of the water-filled accumulator exists.

If actual water level is used, then the accumulator shall be at atmospheric pressure.

2)

Verifying that the total dissolved nitrogen and air in the water-filled accumulator is less than 80 scf per 1800 cubic feet of water (equivalent to 5 x 10 5 pounds nitrogen per pounds water).

d.

At least once per 5 years by replacing the membrane installed between the water-filled and nitrogen bearing accumulators and verifying that the removed membrane burst at a differential pressure of 40 1 10 psi.

i i

McGUIRE - UNITS 1 and 2 3/4 5-3b Amendment No.57 (Unit 1)

Amendment No.38 (Unit 2)

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EMERGENCY CORE COOLING SYSTEMS

~

UPPER HEAD INJECTION LIMITING CONDITION FOR OPERATION 3.5.1.4 Each Upper Head Injection Accumulator System shall be isolated with the isolation valves closed.

APPLICABILITY:

MODES 1, 2, and 3.

(With Cold Leg Accumulators and discharge paths suitably modified.)

ACTION:

a.

With the Upper Head Injection Accumulator System isolation valve (s) open, either immediately close the isolation valve (s) or be in HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and reduce pressurizer pressure to less than 1900 psig within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

1 SURVEILLANCE REQUIREMENTS 4.5.1.4 Each Upper Head Injection Accumulator System shall be demonstrated isolated at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by:

1)

Verifying that each accumulator isolation valve is closed.

McGUIRE - UNITS 1 and 2 3/45-4 Amendment No. 38(Unit 2)

Amendment No. 57(Unit 1)

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1 TABLE 3.6-1 g

SECONDARY CONTAINMENT BYPASS LEAKAGE PATHS 8

5 FENETRATION TEST e

NUMBER SERVICE RELEASE LOCATION TYPE C

3 M216 Pressurizer Relief Tank Makeup Auxiliary Building Type C w

w M212 Nitrogen to Pressurizer Relief Tank Auxiliary Building Type C M259 Reactor Makeup Water Tank to NV System Auxiliary Building Type C ro M373 Ice Condenser Glycol In Auxiliary Buildioq Type C M372 Ice Condenser Glycol Out Auxiliary Building Type C M330 Nitrogen to Accumulators Auxiliary Building Type C M321 Safety Injection Test Line Auxiliary Building Type C (M348 Upper Head Injection Test Line Auxiliary Building TypehNote4 l

M374 Containment Floor Sump Incore Instrument Sump Discharge Auxiliary Building Type C M360 Reactor Coolant Drain Tank Gas Space to Waste Gas System Auxiliary Building Type C kk ss M375 Reactor Coolant Drain Tank Heat Exchanger Discharge Auxiliary Building Type C M356 Equipment Decontamination Auxiliary Building Type C Q@

M235 Pressurizer Sample Auxiliary Building Type C M309 Reactor Coolant Hot Leg Sample Auxiliary Building Type C ro s M322 Component Cooling to Component Cooling Drain' Tank Auxiliary Building Type C Note 1: Upon the deactivation of the UHI System by removal of related components and piping and modifications to the Cold Leg Accumulators, this specification is no longer applicable.

1-t i

TA8LE 3.6-1 (Continued)

M g

SECONDARY CONTAINMENT BYPASS LEAKAGE PATHS

)

E PENETRATION TEST e

NUMBER SERVICE RELEASE LOCATION TYPE J

c 5

M307 Nuclear Service Water to Reactor 1

d Coolant Pump Auxiliary Building Type C w

=

M315 Nuclear Service Water From Reactor E

Coolant Pump Auxiliary Building Type C M213 Incore Instrumentation Room Purge In Auxiliary Building Type C M138 Incore Instrumentation Room Purge

~

Out Auxiliary Building Type C M367 Upper Compartment Purge Inlet Auxiliary Building Type C y

i -

i e

M454 Upper Compartment Purge Inlet Auxiliary Building Type C m

M357 Lower Compartment Purge Inlet Auxiliary Building Type C M456 Lower Compartment Purge Inlet Auxiliary Building Type C M368 Containment Purge Exhaust Auxiliary Building Type C l

M455 Containment Purge Exhaust Auxiliary Building Type C l

M119 Containment Purge Exhaust Auxiliary Bulleing Type C l

M337 Demineralized Water Auxiliary Building Type C M240 Containment Ventilation Cooling j

Water In Turbine Buildits Type C i

I M385 Containment Ventilation Cooling l

Water In Turbing Building Type C i

?

p.

i TABLE 3.6-2 (Continued) g CONTAINMENT ISOLATION VALVES i

M MAXIMUM d

ISOLATION 5

VALVE NUMBER FUNCTION TIME (SEC)

U 1.

Phase "A" Isolation (continued) g k

CF-153A Auxiliary Nozzle Temper SG B 110 CF-155B Auxiliary Nozzle Temper SG C

$10 m

CF-157B Auxiliary Nozzle Temper SG D

$10 i

KC-3058#

Excess Letdown Hx Supply Pent. Isolation Outside 130

)

KC-320A NCDT Hx Supply Hdr. Pent. Isolation Outside

-<30 KC-3158#

Excess Letdown Hx Ret. Hdr. Pent. Isolation Outside 115 KC-3328 NCDT Hx Supply Hdr. Pent. Isolation Inside

$15 l

KC-333A NCDT Hx Return Hdr. Pent. Isolation Outside

$15 w'g KC-4298 RB' Drain Header Inside Containment Isolation

$15 KC-430A RB Drain Header Outside Containment Isolation 115 NB-2608 Reactor Makeup Water Tank to NV System 115 l

NC-538 Nitrogen to Pressurizer Relief Tank Containment

$10

[

Isolation Outside t

NC-54A Nitrogen to Pressurizer Relief Tank Containment 110 Isolation Inside NC-56B PRT Makeup

$10 i

NC-1958 NC Pump Motor Oil Containment Isolation Outside 115 NC-196A NC Pump Motor Oil Containment Isolation Inside

$15 l

NF-228A Air Handling Units Glycol Supply Containment

$15 Isolation Outside NF-233A Air Handling Units Glycol Supply Containment

$15 Isolation Inside NF-234A Air Handling Units Glycol Supply Containment

$15

{

Isolation Outside NI-47A Accumulator Nitrogen Supply Outside Containment

$15 Isolation j

N'-95A Test HDR Inside Containment Isolation 110

TABLE 3.6-2 (Continued) 8 CONTAINMENT ISOLATION VALVES E

m MAXIMUM ISOLATION VALVE NUMBER FUNCTION g

TIME (SEC) d 1.

Phase "A" Isolation (continued) s a

NI-96B Test HDR Outside Containment Isolation

<10 E

NI-120B Safety Injection Pump to Accumulator Fill Line Isolation 710 NI-1224 Hot Leg Injection Check NI124, NI128 Test Isolation 710 to NI-255B Note 1 UHI Check Valve Test Line Isolation 710 NI-258A[

UHI Check Valve Test Line Isolation 710 NI-264B y UHI Check Valve Test Line Isolation 710 NI-266A i UHI Check Valve Test Line Isolation 710 NI-267A J UHI Check Valve Test Line Isolation 710 R

NH-3A Pressurizer Liquid Sample Line Inside Containment Isolation

<15 NM-6A

~ Pressurizer Steam Sample Line Inside Containment Isolation 715 i

NM-78 Pressurizer Sample Header Outside Containment Isolation 715 4

S NM-22A NC Hot Leg #1 Sample Line Inside Containment-Isolation 715 NM-25A NC Hot Leg #4 Sample Line Inside Containment Isolation 715 NM-26B NC Hot Legs Sample Hdr. Outside Containment Isolation 715 NM-72B NI Accumulator A Sample Line Inside Containment Isolation 715 Nn-758-NI Accumulator B Sample Line Inside Containment Isolation 715 NM-788 NI Accumulator C Sample Line Inside Containment Isolation 715 NM-81B NI Accumulator D Sample Line Inside Containment Isolation 715

((

NH-82A NI Accumulator Sample Hdr. Outside Containment Isolation 715 s=

NM-187A#

SG A Upper Shell Sample Containment Isolation Inside 715

($

NM-190A#

SG A Blowdown Line Sample Containment Isolation Inside 715 ss NM-1918#

SG A Sample Hdr. Containment Isolation Outside 715 NM-197B#

SG B Upper Shell Sample Containment Isolation Inside 715 f,E NM-200B#

SG B Blowdown Line Sample Containnent Isolation Inside 7_15 g$

NM-201A#

SG B Sample Hdr. Containment Isolation Inside

<15 NM-207A#

SG C Upper Shell Sample Containment Isolation Inside 715

^^

EE NM-210A#

SG C Blowdown Line Sample Containment Isolation Inside 715 3E NM-211B#

SG C Sample Hdr. Containment Isolation Outside 715 i

ru s NM-217B#

SG D Upper Shell Sample Containment Isolation Inside 715

~

NM-220B#

SG D' Blowdown Line Sample Containment Isolation Inside

_715 Note 1: Upon the deactivation of the UHI System by removal of related components and piping.

and modifications to the Cold Leg Accumulators, this specification is no longer applicable.

i

jq:

TABLE 3.8-la (Continued)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES e

TRIP SETPOINT OR

RESPONSE

5 CONT. RATING TIME d

DEVICE NUMBER & LOCATION (AMPERES)

(SECONOS)

SYSTEM POWERED 2.

600 VAC-MCC (Continued) n.

m 1EMXA-2 28 4

Primary Bkr 20 45 9 60A N2 to Prt Cont Isol Inside Backup Fuse 20 N.A.

Viv INC54A IEMXA-2 2C I

Primary Bkr 20 45 8 60A RCP Mtg Brg Oil Fill Isol Backup Fuse 20 N.A.

V1v INC196A s*

l 1EMXA-2 3A

}

T Primary Bkr 30 45 0 90A Accumulator 1A Disch Isol j

U Backup Fuse 30 N.A.

Viv INI54A IEMXA-2 3B Primary Bkr 30 45 9 90A Accumulator IC Disch Isol Backup Fuse 30 N.A.

V1v 1NI76A IEMXA-2 3C

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Primary Bkr 20 45 9 60A Test Hdr Inside Cont Isol Backup Fuse 20 N.A.

V1v INI95A n :2 i

PrimaryBk]r IEMXA-2 4A i

yy BackupFuse)4 Note 1 20 45 9 60A UHI Check Vlv Test Line Isol 20 N.A.

Viv INI266A vw i

11 Note 1:

Upon the deactivation of the UHI System by removal of related components and piping and

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modifications to the Cold Leg Accumulators, this specification is no longer applicable.

ee 7

vv

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s:

TABLE 3.8-la (Continued)

' IE UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES C5 TRIP SETPOINT OR RESPbHSE d

CONT. RATING TIME s

DEVICE NUMBER & LOCATION (AMPERES)

(SECON05)

SYSTEM POWERED 2.

600 VAC-MCC (Centinued)

IEMXA-2 48 7 Primary Bkrl Note 1 20 45 9 60A UHI Check V1v Test Line Isol Backup Fusej 20 N.A.

V1v 1NI267A I'

1EMXA-2 4C 43 6 60A

. Accus IA Vent' t.o INC34 for Primary Bkr 20 1

{

Backup Fuse 20 N. A.'

Bikaut Viv INI430A T

1EMXA-5 IB

'M Primary Bkr 20 45 9 60A Pzr Steas Sample Line Inside Cont 'Is' 1 ?!)v.1NM3A

Backup Fuse 20 N,A.

o 1EMXA s 73

'~

Primary Bkr 20 45 9 60A Pzr St'eas Sample Line Inside j

Backup Fuse 20, N.A.

gontIs,ol,V1v1NM6A

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1EMXA-5 3B s

Primary Bkr

<20 45 9 60A NC Hot. leg 1A Sample Line Cont sagg Backup Fuse 20 N.A.

IsoP VIE INM22A ;

oo 1EMXA-5 2D EE Primary Bkr 20 s

45 9 60A

'yC Hat. leg 10 Sample Line Cont

'd Backup Fuse 20 N.A.

Isol Viv 1NM25A mm EE 1EMXA-2 7A

3 Primary Bkr 20 45 9 60A SG 1A Upper Shell Sample Cont 3s Backup Fuse 20 N.A.

Isol Viv 1NM187A Note 1: Upon the deactivation of the UHI System'by removal of related components and piping and i

modifications to the Cold Leg Accumulators, this specification is no longer applicable.

r.

l TABLE 3.8-1b (Continued) y UNIT 2 CONTAINMENT PENETRATION CON 00CTOR OVERCURRENT PROTECTIVE DEVICES e

c TRIP SETPOINT OR

RESPONSE

3 CONT. RATING TIME d

DEVICE NUMBER & LOCATION (AMPERES)

(SECONOS)

SYSTEM POWERED w

g 2.

600 VAC-MCC (Continued) n.

ro 2EMXA-2 2B Primary Bkr 20 45 9 60A N2 to Prt Cont Isol Inside Backup Fuse 20 N.A.

Viv 2NC54A i

2EMXA-2 2C 1

Primary Bkr 20 45 9 60A RCP Mtg Brg 011 Fill Isol Backup Fuse 20 N.A.

V1v 2NC196A

,s l

2EMXA-2 3A T

Primary Bkr 30 45 9 90A Accumulator 2A Disch Isol i

E Backup Fuse 30 N.A.

Vlv 2NI54A 2EMXA-2 3B Primary Bkr 30 45 9 90A Accumulator 2C Disch Isol Backup Fuse 30 N.A.

Viv 2NI76A 2EMXA-2 3C

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Primary Bkr 20 45 9 60A Test Hdr Inside Cont Isol Backup Fuse 20 N.A.

Viv 2NI95A i

s kk' 2EMXA-2 4A,j s

i Primary Bkr b Note 1 20 45 9 60A UHI Check Viv Test Line Isol IE BackupFusej 20 N.A.

Viv 2NI266A i

4 t,. ta 2E Note 1: Upon the deactivation of the UHI System by removal of related components and piping and j

((

modifications to the Cold Leg Accumulators, this specification is no longer applicable.

i er UU a

i I

l 4

.o

q

TABLE 3.8-1b (Continued) my UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES c-TRIP SETPOINT OR

RESPONSE

5 CONT. RATING TIME d

DEVICE NUMBER & LOCATION (AMPERES)

(SECONDS)

SYSTEM POWERED w

g 2.

600 VAC-MCC (Continued) o.

ro 2EMXA-2 4B l Primary Bkr 4 Note 1 20 45 @ 60A UHI Check V1v Test Line Isol Backup Fuse 20 N.A.

Viv 2NI267A s

2EMXA-2 4C Primary Bkr 20 45 @ 60A Accum 2A Vent to 2NC34 for Backup Fuse 20 N.A.

Bikout Viv 2NI430A

,s*

2EMXA-5 IB T

Primary Bkr 20 45 9 60A Pzr Steam Sample Line Inside Backup Fuse 20 N.A.

Cont Isol V1v 2NM3A 2EMXA-5 2C Primary Bkr 20 45 9 60A Pzr Steam Sample Line Inside Backup Fuse 20 N.A.

Cont Isol Vlv 2NM6A 2EMXA-5 3B

((

Primary Bkr 20 45 9 60A NC Hotleg 2A Sample Line Cont ss-Backup Fuse 20 N.A.

Isol Vlv 2NM22A kk

==

2EMXA-5 20 Primary Bkr 20 45 0 60A NC Hotleg 20 Sample Line Cont fy Backup Fuse 20 N.A.

Isol Viv 2NM25A w u.

RX 2EMXA-2 7A EE Primary Bkr 20 45 9 60A SG 2A Upper Shell Sample Cont 33 Backup Fuse 20 N.A.

Isol Valve 2NM187A Note 1: Upon the deactivation of the UHI System by removal of. related components and piping and modifications to the Cold Leg Accumulators, this specification is no longer applicable.

g' 1.

[

TABLE 3.8-1b (Continued) e g

UNIT 2 CONTAINMENT PENETRATION CON 00CTOR OVERCURRENT PROTECTIVE DEVICES E

TRIP SETPOINT OR

RESPONSE

Q

CONT. RATING TIME

'^

DEVICE NUMBER & LOCATION (AMPERES)

(SECONDS)

SYSTEMS POWERED a.

2.

600 VAC-MCC (Continued) o" 2EMXA-2 78 Primary Bkr 20 45 9 60A SG 2A Blowdown Line Sample Backup Fuse 20 N.A.

Cont Isol Viv 2NM190A 2EMXA-2 7C Primary Bkr 20 45 9 60A SG 2C Upper Shell Sample

~1 Backup Fuse 20 N.A.

Cont Isof Viv 2NM207A sa1 2EMXA-2 8A e.

Primary Bkr 20 45 9 60A SG 2C Blowdown Line Sample g

Backup Fuse 20 N.A.

Cont Isol V1v 2NM210A 2EMXA-4 18 Primary Bkr 20 45 9 60A NC Pump Seal Return Cont Backup Fuse 20 N.A.

Isol Viv 2NV94AC 2EMXA-3 3A Primary Bkr 20 45 9 60A H2 Purge Exhaust Cont Backup Fuse 20 N.A.

Vessel Isol Viv 2VESA 2EMXA-3 3B Primary Bkr 20 45 0 60A Cont H2 Purge Blower 1

Backup Fuse 20 N.A.

Inlet Valve 2VE8A i

2EMXA-3 3C Primary Bkr 20 95 9 60A H2 Purge Inlet Cont

)

Backup Fuse 20 M.A.

Vessel Isol Viv 2VE10A 2EMXA-4 2C Primary Bkr 20 45 9 60A Standby Makeup Pump Inlet Backup Fuse 20 N.A.

Isol Valve 2NV842AC t

_ _. =.

i 3/4.5 EMERGENCY CORE COOLING SYSTEMS e

BASES 3/4.5.1 ACCUMULATORS The OPERABILITY of each Reactor Coolant System (RCS) Cold Leg Accumulator l

ensures that a sufficient volume of borated water will be immediately forced into the reactor core through each of the cold legs in the event the RCS pres-sure falls below the pressure of the accumulators. This initial surge of water into the core provides the initial cooling mechanism during large RCS pipe rup-tures.

The limits on accumulator volume, boron concentration and pressure ensure that the assumptions used for accumulator injection in the safety analysis are met.

The accumulator power operated isolation valves are considered to be

" operating. bypasses" in the context of IEEE Std. 279-1971,.which requires that bypasses of a protective function be removed automatically whenever permissive conditions are not met.

In addition, as these accumulator isolation valves fail to meet single failure criteria, removal of power to the valves is required.

The limits for operation with an accumulator inoperable for any. reason except an isolation valve closed minimizes the time exposure of the plant to a LOCA event occurring concurrent with failure of an additional accumulator which may result. in unacceptable peak cladding temperatures.

If a closed isolation valve cannot be immediately opened, the full capability of one accumulator is not available and prompt action is required to place the reactor in a mode where this capability is not required.

The original licensing bases of McGuire assumes both the UHI system and the Cold Leg Accumulators function to mitigate postulated accidents.

Subse-quent analyses, documented in "McGuire Nuclear Station, Safety Analysis for UHI Elimination" dated September 1985, and docketed by Duke letter dated October 2, 1985, support the determination that UHI is no longer required pro-vided the Cold Leg Accumulator volume is adjusted to be consistent with that assumed in the Safety Analysis.

Accordingly, Specification 3/4.5.1.1 on pages 3/4 5-1, -2 is provided as the planned final condition of the cold leg injection system with water volume and nitrogen cover pressure as assumed in the Safety Analysis.

It is appli-cable for the conditions of UHI being either physically removed or isolated.

It has a prerequisite that the cold leg accumulators and discharge flow paths are consistent with assumptions used in the Safety Analysis. The actions re-quired to align the plant configuration with the safety analyses assumptions are:

1.

Replace flow restricting orifices in the Cold Leg Accumulators dis-charge piping to ensure actual accumulator discharge line resistances are within tolerance bands of ECCS analysis.

McGUIRE - UNITS 1 and 2 B 3/4 5-1 Amendment No. 57 (Unit 1)

Amendment No. 38 (Unit 2)

-. -. +

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EMERGENCY CORE COOLING SYSTEMS I

BASES ACCUMULATORS (Continued) 2.

Reduce the nominal water level in the Cold Leg Accumulators and modify instrumentation, alarm functions, and procedurst accordingly.

3.

Increase the nominal gas cover pressure in the Cold Leg Accumulators and modify instrumentation, alarm functions, and procedures accordingly.

4.

Ensure UHI isolation valves remain closed during operation.

Items 1, 2, 3 constitute modifications required by the phrase " Cold Leg Accumulator and discharge paths suitably modified" contained in the technical specifications.

Item 4 is a requirement that will be implemented by adminis-trative co trols and is reflected in Technical Specification 3/4 5.1.4.

Specification 3/4.5.1.2 on page 3/4 5-2a, -2b is the Technical Specifica-tion requirements for the Cold Leg Injection with UHI system operable. As this is expected to be an interim condition, the pages have been renumbered with suffixes a, b.

With respect to Technical Specifications for the UHI system, page 3/4 5-3 is provided as the planned final condition of the plant, that being with the UHI system deleted.

New page 3/4 5-3c is provided to cover the condition following modification of the cold leg accumulators and discharge paths. This new requirement is that the isolation valves be closed and remain closed. Surveillance once per shift (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) is provided. New page 3/4 5-3a duplicates the present Technical Specification for operability of the UHI sys-tem and is now Specification 3.5.1.3.

As this is expected to be an interim condition the page has been renumbered to 3/4 5-3a.

Page 3/4 5-3b provides the continuation of the surveillance requirements of Specification 4.5.1.2 when UHI system operability is required.

3/4.5.2 and 3/4.5.3 ECCS SUBSYSTEMS

~

A The OPERABILITY of two independent ECCS subsystems ensures that sufficient emergency core cooling capability will be available in the event of a LOCA assuming the loss of one subsystem through any single failure consideration.

Either subsystem operating in conjunction with the accumulators is capable of supplying sufficient core cooling to limit the peak cladding temperatures within acceptable limits for all postulated break sizes ranging from the double ended break of the la. gest RCS cold leg pipe downward.

In addition, each ECCS subsystem provides long-term core cooling capability in the recirculation mode during the accident recovery period.

With the RCS temperature below 350*F, one OPERABLE ECCS subsystem is acceptable without single failure consideration on the basis of the stable reactivity conditinn of the reactor and the limited core cooling requiramm.ts.

McGUIRE - UNITS 1 and 2 B 3/4 5-2 Amendment No.57 (Unit 1)

Amendment No.38 (Unit 2)

.~.

.L

. ~.

~

- ~

EMERGENCY CORE COOLING SYSTEMS BASES ECCS SUBSYSTEMS (Continued)

I The limitation for a maximum of one centrifugal charging pump and one Safety Injection pump to be OPERABLE and the Surveillance Requirement to i

verify all charging pumps and Safety Injection pumps except the required OPERABLE charging pump to be inoperable below 300*F provides assurance that a mass addition pressure transient can be relieved by the operation of a single PORV.

The Surveillance Requirements provided to ensure OPERABILITY of each component ensures that at a minimum, the assumptions used in the safety analyses are met and that subsystem OPERABILITY is maintained.

Surveillance Requirements for throttle valyc position stops and flow balance testing provide assurance that proper ECCS flows will be maintained in the event of a LOCA. Maintenance of proper flow resistance and pressure drop in the piping system to dach injection point is necessary to:

(1) prevent total pump flow j

from exceeding runout conditions when the system is in its minimum resistance configuration, (2) provide the proper flow split between injection points in accordance with the assumptions used in the ECCS-LOCA analyses, and (3) provide an acceptable level of total ECCS flow to all injection points equal to or i

above that assumed in the ECCS-LOCA analyses.

3/4.5.4

[ Deleted]

3/4.5.5 REFUELING WATER STORAGE TANK The OPERABILITY of the refueling water storage tank (RWST) as part of the j

ECCS ensures that a sufficient supply of borated water is available for injection by the ECCS in the event of a LOCA. The limits on RWST minimum volume and boron concentration ensure that:

(1) sufficient water is available 4

~

within containment to permit recirculation cooling flow to the core, and (2) the reactor will remain subcritical in the cold condition folicwing mixing i

of the RWST and the RCS water volumes with all control rods inserted except

(

for the most reactive control assembly. These assumptions are consistent with j

the LOCA analyses.

[

The contained water volume limit includes an allowance for water not f

usable because of tank discharge line location or other physical characteristics.

{

e The limits on contained water volume and boron concentration of the RWST l

also ensure a pH value of between 8.5 and 10.5 for the solution recirculated within containment after a LOCA.

This pH band minimizes the evolution of i

iodine and minimizes the effect of chloride and caustic stress corrosion on mechanical systems and components.

j

!t l

McGUIRE - UNITS 1 and 2 8 3/4 5-3 Amendment No.57 (Unit 1)

Amendment No.38 (Unit 2) i i

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ML20210S194

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ML20210S194

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