ML20207P561

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Proposed Tech Specs,Reflecting Mods Re Connecting Standby Gas Treatment Sys to Refueling Fuel Vol as Required by License Condition 2(C)(14)
ML20207P561
Person / Time
Site: Limerick Constellation icon.png
Issue date: 01/13/1987
From:
PECO ENERGY CO., (FORMERLY PHILADELPHIA ELECTRIC
To:
Shared Package
ML20207P540 List:
References
NUDOCS 8701160244
Download: ML20207P561 (26)
v • d • e


Text

,

T'BLE 3.3.2-1 (Continued) ..

ISOLATION ACTUATION I N S TUNE NT

  • T I ON D1D!) MINIMUM APPLICABLE , .

tasa . ISOLATION OPERABLE CHANNELS OPERATIONAL

  • LUC) TRIP FUNCTION }!GNAL (a) PER TRIP SYSTEM (b) CONDITION ACTION
  • 3> 06
6. PRIMARY CON #AINMENT ISOLATION t3 C)

(14 1) Low. Low-Levol 2 8 2 20 1 2. 3 7 ten 2) Low. Low. Low-Level 1 C 2 1, 2. 3 20

((0} b. D.ywell Pressure - High H 2 1. 2 3 20 h)h! c. North Stock Effluent qg on. Radiation - High (g) W 1 2 3 C3 L1f.J 1 23 30 05 d. Deleted.

fu

.p ..,

e. Reactor Enclosure Ventilation
Enhaust Duct-Radiation - High 5 2 1, 2 3 23 *
f. Outside Atmoshpere to Reactor Enclosure A Pressure - Low U 1 1, 2. 3 23
g. Deleted.
h. Drywell Pressure - Hight .

Reactor Pressure - Low G 2/2 1 2 3 26

5. Primary Containment Instrument Gas Line to Drywell &

Pressure - Low M l 1, 2. 3 26

j. Manual Init$ation MA 1 1 2 3 24 LIMERICM - UNIT 1 3/4 3-14 I

i j p 3,.%.. . a *. p .

_w eanedy * * * " * * * * * * * * * ' ' * " ~ ~ *' ~-

TABLE 3.3.2-1 (Continued)

  • e ISOLATION ACTU*> TION INST'UMENTATION MINIMUM APPLICABLE ISOLATION OPERABLE CHANNELS OPERATIONAL TRIP FUNCTION SIGNAL (a)(c) PER TRIP $YSTEM (b) CONDITIO*. ACTION l,.

7 SECONDARY CONTAINMENT !$0LATION

a. Reactor vessel Water Level Low. Low-Level 2 8 2 1 2. 3 25
b. Drywell Pressure - High H 2. 1 2. 3 25
c. Refueling Area Venttistion Exhaust Duct Radiation - High R 2
  • 25
d. Reactor Enclosure Ventilation Exhaust Duct Radiation - High 5 2 1 2. 3 25
e. Outside Atmosphere To Reactor Enclosure A Pressure - Low U 1 1 2 3 25 .
f. Outside Atmosphere To Refueling Area A Pr.ssure - Low T i . 25
g. Reactor Enclosure l Manual Initiation NA 1 1 2 3 24 l
h. Refueling Area Manual Initation NA 1
  • 25 LIMERICK - UNIT I 3/4 3-15 l

I i

l 1

1 e

  • ' ' ' ' * * ' i M-

TABLE 3.3.2-1 ISOLATiun acTuariuN(Continu d)

INSTRUMENTATION ACTION STATEMENTS ,

ACTION 20 - Be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. i ACTION 21 - Be in at least STARTUP with the associated isolation valves closed within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

ACTION 22 - Be in at least STARTUP within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

ACTION 23 - In OPERATIONAL CONDITION 1 or 2, verify the affected system

' isolation valves are closed within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and declare the affected system inoperable. In OPERATIONAL CONDITION 3, be in at least COLD SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

ACTION 24 - Restore the manual initiation function to OPERABLE status within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or close the affected system isolation valves within the next hour and declare the affected system inoperable ,

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

ACTION 25 - Establish SECONDARY CONTAINMENT INTEGRITY with the standby gas treatment system operating within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

ACTION 26 - Close the affected system isolation valves within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

TABLE NOTATIONS  ?

I o

When handling irradiated fuel in the secondary containment and during  !

CORE ALTERATIONS and operations with a potential for draining the reactor vessel.

May be bypassed under administrative control, with all turbine stop valves closed.

(a) See Specification 3.6.3, Table 3.6.3-1 for primary containment l isolation valves which are actuated by these isolation signals. l (b) A channel may be placed in an inoperable status for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for required surveillance without placing the channel or trip system in the tripped condition provided at least the other OPERABLE channel in the same trip system is monitoring that parameter. In addition, for  ;

the HPCI system and RCIC system isolation, provided that the redundant g isolation valve, inboard or outboard, as applicable, in each line is ,

OPERABLE and all required actuation instrumentation for that valve is

  • l OPERABLE, one channel may be placed in an inoperable status for up to l 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for required surveillance without placing the channel or trip system in the tripped condition.
(c) Actuates secondary containment isolation valves shown in Table l 3.6.5.2.1-1 and/or 3.6.5.2.2-1 and signals B, H, S, U, R and T also l

start the standby gas treatment system.

(d) RWCU system inlet outboard isolation valve closes on SLCS "B" initiation. RWCU system inlet inboard isolation valve closes on SLCS "A" or SLCS "C" initiation.

i l

LIMERICK - UNIT 1 3/4 3-16 4 1

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_ . _ _ _ _ _ _ b

TA8LE 3.3.2-2 (Continued)

ISOLATION ACTUATION INSTRUMENTATION SETPOINTS .

ALLOWABLE TRIP FUNCTION TRIP SETPOINT VALUE

6. PRIMARY CONTAINMENT ISOLATION *
a. Reactor vessel Water Level
1. Low. Low-Level 2 1 -38 inches
  • 1 -45 inches
2. Low. Low. Low. Level 1 1 -129 inches
  • 1 -136 inches
b. Drywell Pressure - High 1 1.68 pate i 1.88 rste
c. North Stack Effluent Radiation - High 1 2.1 pC1/cc 1 4.0 pct /cc
d. Deleted.
e. Reactor Enclosure Ventilation Enhaust Duct - Radiation - High 1 1.35 mR/h 1 1.5 m4/h
f. Outside Atmosphere To Reactor Enclosure

[L Pressure - Low 1 0.1 inch 1 0.0 inch

g. Deleted.
h. DrywsII Pressure - High/ 1 1.68 psig/ 1 1.88 psig/

Reactor Pressure - Low 1 455 pste (decreasing). 1 435 pato (decreasing)

1. Primary Containment Instrument 1 2.0 psto 1 1.9 pste Gas to Drywell [L Pressure-Low
j. Manual Initiation N.A. N.A.

LIMERICK - UNIT 1 3/4 3-21 i

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l u____________ _

l

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'I, TABLE 3.3.2-2 (Continued) . ., j s

I SO'. ATION ACTUATION INSTRUMENTATION SETPoiNTS '

ALLOWABLE TRIP FUNCTION TRIP SETPOINT VALUE -

7. SECONDARY CONTAINMENT ISOLATION l l
a. Reactor vessel Water Level -

Low. Low-Level 2 1 -38 inches

  • 1 -45 inches j l
b. Drywell Pressure - High i 1.68 psig i 1.88 psig l
c. Refueling Area Ventilation Enhaust Duct Radiation - High 1 2.0 mR/h 3 2.2 mR/h
d. Reactor Enclosure Ventilation Exhaust ,

Duct Radiation - High 1 1.35 mR/h i 1.5 mR/h

e. Outside Atmosphere To Reactor Enclosure A Pressure - Lo= 101 inch 1 0.0 inch
f. Outside Atmosphere to Refueling Area o Pressure - Low 1 0.1 inch 1 0.0 inch
g. Reactor Enclosure
  • Manual initiation N.A. N.A. j
h. Refueling Area I Manual initiation N.A. N.A. j i

f t

k

  • See Bases Figure B 3/4 3-1.

i

    • The low setpoints are for the RWCU Heat Exchanger Rooms: the high setpoints are for the pump g rcoms.

I LIMERICK - UNIT 1 3/4 3-22 '

t t

, TABLE 3.3.2-3 (Continued)

ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME TRIP FUNCTION RESPONSE TIME (Seconds)#

6. PRIMARY CONTAINMENT ISOLATION '
a. Reactor Vessel Water Level
1) Low, Low - Level 2 1 13(a)
2) Low, Low, Low - Level 1 1 13(a)
b. Drywell Pressure - High $ 13(a)
c. North Stack Effluent Radiation - High N.A.
d. Deleted
e. Reactor Enclosure Ventilation Exhaust Duct - Radiation - High N.A.
f. Outside Atmosphere to Reactor Enclosure Delta Pressure - Low N.A.
g. Deleted
h. Drywell Pressure - High/ N.A.

Reactor Pressure - Low

1. Primary Containment Instrument Gas to Drywell Delta Pressure - Low N.A.
j. Manual Initiation N.A.
7. SECONDARY CONTAINMENT ISOLATION
a. Reactor Vessel Water Level Low, Low - Level 2 N.A.
b. Drywell Pressure - High N.A.
c. Refuel Area Ventilation Exhaust Duct Radiation - High N.A.
d. Reactor Enclosure Ventilation Exhaust Duct Radiation - High N.A.
e. Outside Atmosphere to Reactor N.A.

Enclosure Delta Pressure - Low LIMERICK - UNIT 1 3/4 3-25 r

TABLE 3.3.2-3 (Continued) ,i ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME

~

TRIP FUNCTION RESPONSE TIME (Seconds)# f

f. Outside Atmosphere to Refueling N.A.

Area Delta Pressure - Low

g. Reactor Enclosure N.A.

Manual Initiation 1 h. Refueling Area N.A.

Manual Initiation i

TABLE NOTATIONS (c) Isolation system instrumentation response time specified includes 10 seconds diesel generator starting and 3 seconds for sequence loading delays.

(b) Radiation detectors-are exempt from response time testing.

Response time shall be measured from detector output or the input of the first electronic component in the channel.

  • Isolation system instrumentation response time for MSIV only. No diesel generator delays assumed for MSIVs.
    • Isolation system instrumentation response time for associated valves except MSIVs.
  1. Isolation system instrumentation response time specified for the Trip Function actuating each valve group chall be added to isolation time shown in Tables 3.6.3-1, 3.6.5.2.1-1 and 3.6.5.2.2-1 for valves in each valve group to obtain ISOLATION SYSTEM RESPONSE TIME for each valve.
    1. With 45-second time delay.

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LIMERICK - UNIT 1 3/4 3-26 l

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TABLE 4.3.2.1-1 (CIntinued) . .

ISOLATION ACTUATION INSTTUME~TATION SURVETLLANCE rEQUTTEMENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONOITIONS FOR MHICH ' * .

TRIP FUNCTION CHECK TEST CALieRATION SURVEILLANCE REQUIRED .

6. PRIMARV CONTAINMENT ISOLATION
a. Reactor Vessel Water Level
1) Low. Low - Level 2 5 M R 1 2. 3
2) Low. Low. Low - Level 1 5 M R 1 2 3
b. Drywell Pressure - High 5 M R 1, 2 3
c. North Stack Effluent Radiation - Higr. S O R 1, 2. 3
d. Deleted
e. Reactor Enclosure Ventilation Enhaust Duct - Radiation - High 5 M R 1 2 3 .
f. Outside Atmosphere To Reactor .

Enclosure d Pressure - Low N.A. M Q 1 2 3

g. Deleted
h. Drywell Pressure - High/

Reactor Pressure - Low S M R. 1, 2 3

1. Primary Containment Instrument Gas to Drywell [g Pressure - Low N.A. M Q 1 2 3
j. Manual Initiation N.A. R N.A. 1. 2 3 LIMERICK - UNIT 1 3/4 3-30 w

3 .mm , ..o- - . _ . . _ .

TABLE A.3.2.1-1 (Continued)

ISOLATION ACTUATION INST *UMENTATION SURVEILLANCE TEQUIREMENTS CHANNEL OPERATIONAL - '

CHANNEL FUNCTIONAL CHANNEL CONOITIONS FOR WHICH = .

  • Trip FUNCTION CHECM TEST CALIBRATION 'SURVE!LLANCE REQUIRED ,
7. SECONDARY CONTAINMENT ISOLATION ,
s. Reactor Vessel Water Level. .

Low. Low - Level 2 S M R 1 2. 3

b. Drywell Pressure - High 5 M R 1 2. 3
c. Refueling Area Ventilation l

Entaust Duct Radiation - High 5 M R *-

d. Reactor Enclosure Ventilation Enhaust Duct Radiation - High S M R 1 2. 3 l e. Outside Atmosphere To Reactor j Enclosure 8 Pressure - Low N.A. M Q 1 2 3 .
f. Outside Atmosphere To Refueling Area 6 Pressure - Low N.A. M Q
  • q

, g. Reactor Enclosure l Manual Initiation N.A. R N.A. l. 2. 3

h. Refueling Area l Manual Initistion N.A. R N.A.
  • l
  • When handling irradiated fue' in the secondary containment and during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
    • When not administratively bypassed and/or when any turbine stop valve is open.

LIMERICK - UNIT 1 3/4 3-31 4

i

TABLE 3.6.3-1 (Continued)

PA*T A - P71 MARY CONTAINMENT ISOLATION VALVES IN80ARD OUTBOARD ISOL.

PENETRATION FUNCTION ISOLATION ISOLATION- MAX. ISOL. '

  • NUMBER $1GNAL(S). NOTES P&ID -

BARRIER BARRIER TIME. IF APP. IF APP. .

(SEC)(26) -(20)

O25 DRYWELL PURGE SUPPLY HV57-121(X-201A)

~

5** 8.H.S.U W.R.T 3.11.14 57 HV57-123 5** 8.H.S.U.W.R.T 3.11.14 HV57-163 9 8.H.R.S 3.11.14 HV57-109 6** 8.H.S.U.w.R.T 11 l

- (X-201 A ) g HV57-131 5** 8.H.S.U.W.R.T 11 1 (X-201A)

HV57-135 6** 8.H.S.U.W.R.T 11 l 026 DRYWELL PURGE EXHAUST Hv57-114 l 5** 9 H.S.U W.R.T 3.11.14.33 57 HV57-111 15** 8.H.S.U.R.T 5.11 HV57-161 9 l

8.H.R.S 3.11.14 SV57-139 5 10 HV57-115 6** 8.H.S.U.W.R.T 11.33 l HV57-117 5** 8.H.S.U.R.T 11 I SV57-145 5 8.H.R.S 11 027A CONTAINMENT INSTRUMENT 59-1128(CK) NA 59 GAS SUPPLY TO ADS VALVES HV59-151A 45 M H.M.&S O28A-1 RECIRC LOOP SAMPLE HV43-1F019 10 8.D 43 HV43-1F020 10 8.D 028A-2 DRYWELL H2/02 SAMPLE SV57-132 5 8.H.R.S 11 57 SV57-142 5 8.H.R.S 11 028A-3 DRYWELL H2/02 SAMPLE SV57-134 5 8.H.R.S 11 57 SV57-144 5 8 H.F . S 11 i

LIMERICK - UNIT 1 i 3/4.6-22 1

84 t+ O @ dP 1 --

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TfBLE 3.6.3-1 (Continued) ..

PA9T A - PRIMA",Y CONTAINMENT ISOLATION VALVES INB6mRD OUTBOARD ISOL. * .

  • PENETRATION FUNCTION ISOLATION ISOLATION MAX. ISOL. SIGNAL ($). NOTES P&ID-NUMBER BARRIER SARRIER TIME. IF APP. IF APP.

(SEC)(26) (20)

SV57-191 5 8.H.R.S 11 (X-220A) 116 STANDBY LIQUID CONTROL 48-1FOO7(CK) NA 48 (X-42) HV48-1FOO68 60 29 1178-1 DRYWELL RADIATION SV26-190A 5 8.H.R.S 11 26 ,

MONITORING SUPPLY SV26-1908 5 8.H.R.S 11 i 1178-2 DRYWELL RADIATION SV26-190C 5 8.H.R.S 11 26 MONITORING RETURN SV26-1900 5 8 H.R.S 11 k 1

201A SUPPRESSION POOL PURGE HV57-124 5** 8.H.S.U.W.R.T 3.11.14 1 SUPPLY HV57-131(X-25) 58* 8.H.S.U.w.R.T 3.11.14

( HV57-164 9 8.H.R.S 3.11.14 HV57-109(X-25) 6** 8.H.S.U.w.R.T 11 i HV57-147 6** 8.H.S.U.w.R.T 11 1 HV57-121(X-25) 5** 8.H.S.U w.R.T 11 202 SUPPRESSION POOL PURGE HV57-104 5** 8.H.S.U w R.T 3.11.14.33 57 EXHAUST HV57-105 15** 8 H.S.U.R.T 5.11 '

HV57-162 9 8.H.R.S 3.11.14  !

HV57-112 6** 8.H.S.U w R.T 11.33  !

HV57-118 5** 8 H.S.U.R.T 11  ;

SV57-185 5 8.H.R.S 11 >

203A(8.C.D) RHR PUMP SUCTION HV51-1FOO4A(8 240 4.22 51 '

C.D) 19.29

(

PSV51-1F030A(8 NA 22 j C.D) j 1

LIMERICK - UNIT 1 3/4 6-26 i l  ;

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-b

. TABLE 3.6.3-1

>+

.- PRIMARY CONTAINMENT 15ULATION VALVES

. NOTATION NOTES (Continued)

21. Automatic isolation signal causes TIP to retract; ball valve closes when probe is fully retracted.
22. Isolation barrier remains water filled or a water seal remains in the line post-LOCA. Isolation valve may be tested with water. Isolation valve leakage is not included in 0.60 La total Type B & C tests.
23. Valve does not receive an isolation signal. Valves will be open during Type A test. Type C' test not required.
24. Both isolation signals required for valve closure.
25. Deleted.
26. Valve stroke times listed are maximum times verified by testing per Specification 4.0.5 acceptance criteria. The closure times for isolation valves in lines in which-high-energy line breakc could occur are identified with a single asterisk. The closure times for isolation valves in lines which provide an open path from the containment to the environs are identified with a double asterisk.
27. The reactor vessel head seal leak detection line (penetration 29A) excess flow. check valve is not subject to OPERABILITY testing. This valve will not be exposed to primary system pressure except under the unlikely conditions of a seal failure where it could be partially pressurized to reactor pressure. Any leakage path is restricted at the source; therefore, this valve need not be OPERABILITY tested.
28. Automatic isolation logic to be added by the end of the first refueling outage.
29. Valve may be open during normal operation; capable of manual isolation from control room. Position will be controlled procedurally.
30. Valve normally open, closes on scram signal.
31. Valve 41-1016 is an outboard isolation barrier for penetrations X-9A, B and X-44. Leakage through valve 41-1016 is included in the total for penetration X-44 only.
32. Feedwater long path recirculation Jalves are sealed closed whenever the reactor is critical and reactor pressure is greater than 600 psig.

The valves are expected to be opened only.in the following instances:

a. Flushing of the condensate and feedwater systems during plant startup.
b. Reactor pressure vessel hydrostatic testing, which is conducted following each refueling outage prior to comme'. ring plant startup.

Therefore, valve stroke timing in accordance with Specification 4.0.5 l 1s not required.

l l 33. Valve also constitutes a Refueling Area Secondary Containment Automatic Isolation Valve as shown in Table 3.6.5.2.2-1.

LIMERICK - UNIT 1 3/4 6-43

-- _ _. . ~

CONTAINMENT SYSTEMS

~ LIMITING CONDITION FOR OPERATION 3.6.5.1.1 REACTOR ENCLOSURE SECONDARY CONTAINMENT INTEGRITY shall be maintained.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3.

. ACTION:

Without REACTOR ENCLOSURE SECONDARY CONTAINMENT INTEGRITY, restore REACTOR ENCLOSURE SECONDARY CONTAINMENT INTEGRITY vithin 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

SURVEILLANCE REQUIREMENTS 4.6.5.1.1 REACTOR ENCLOSURE SECONDARY CONTAINMENT INTEGRITY shall be d:monstrated by:

a. Verifying at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> that the pressure within the reactor enclosure secondary containment is greater than or equal to 0.25 inch of vacuum water gauge.
b. Verifying at least once per 31 days that:
1. All reactor enclosure secondary containment equipment hatches and blowout panels are closed and sealed.
2. At least one door in each access to the reactor enclosure secondary-containment is closed.
3. All reactor enclosure secondary containment penetrations-not capable of being closed by OPERABLE secondary containment automatic isolation dampecs/ valves and required to be closed during accident conditions are

, closed by valves, blind flanges, slide gate dampers or }

deactivated automatic dampers / valves secured in position.'

c. At least once per 18 months:
1. Verifying that one standby gas treatment subsystem will draw down the reactor enclosure secondary containment to greater than or equal to 0.25 inch of vacuum water gauge in less than or equal to 121 seconds with the reactor enclosure recirc system in operation, and
2. Operating one standby gas treatment subsystem for one hour and maintaining greater than or equal to 0.25 inch of vacuum water gauge in the reactor enclosure secondary containment at a flow rate not exceeding 1250 cfm.

LIMERICK . UNIT 1 3/4 6-46

  • CQNTAIdMENT SYSTEMS

.3.6.5.1.2 REFUELING AREA SECONDARY CONTAINMENT INTEGRITY shall be mai APPLICABILITY: OPERATIONAL CONDITION *.

ACTION: '

Without REFUELING AREA SECONDARY CONTAINMENT INTEGRITY, suspend handling of irradiated fuel in the secondary containment, CORE ALTERATIONS vessel.

and operations with a potential for draining the reactor The provisions of Specification 3.0.3 are not applicable.

I

' SURVEILLANCE REQUIREMENTS 4.6.5.1.2 REFUELING AREA demonstrated by: SECONDARY CONTAINMENT INTEGRITY shall be a.

Verifying at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> that the pressure within the refueling area secondary containment is greater than or I

equal to 0.25 inch of vacuum water gauge.

b. Verifying at least once per 31 days that:

1.

All refueling area secondary containment equipment hatches and blowout panels are closed and sealed.

2.

At least one door in each access to the refueling area secondary containment is closed.

3. All refueling area secondary containment penetrations '

not capable of being closed by OPERABLE secondary containment automatic isolation dampers / valves and required to be closed during accident conditions are l

closed by valves, blind flanges, slide gate dampers, or deactivated automatic dampers / valves secured in j position.

$ c. At .least once per 18 mont hs:

Operating one standby gas eatment subsystem for one hour and maintaining greater t or equal to 0.25 inch of vacuum water gauge in the refuel area secondary containment at a flow rate not exceeding 7e Ofm.

t *When irradiated fuel is being handled in the refueling i area secondary containment and during CORE' ALTERATIONS and operations with a potential for draining the reactor vessel.

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i l LIMERICK - UNIT 1 3/4 6-47

=~---,o

TABLE 3.6.5.2.1-1 REACTOR ENCLOSURE SECONDARY CONTAINMENT VENTILATION SYSTEM AUTOMATIC ISOLATION VALVES REACTOR-ENCLOSURE (ZONE I) MAXIMUM ISOLATION TIME ISOLATION (a)

VALVE FUNCTION (Seconds) SIGNALS

1. Reactor Enclosure Ventilation Supply Valve HV-76-107 5 B,H,S,U
2. Reactor Enclosure Ventilation Supply Valve HV-76-108 5 B,H,S,U
3. Reactor Enclosure Ventilation Exhaust Valve HV-76-157 5 B,H,S,U
4. Reactor Enclosure Ventilation Exhaust Valve HV-76-158 5 B,H,S,U
5. Reactor Enclosure Equipment Compartment Exhaust Valve HV-76-141 5 B,H,S,U
6. Reactor Enclosure Equipment Compartment Exhaust Valve HV-76-142 5 B,H,S,U
7. Drywell Purge Exhaust Valve HV-76-030 5 B,H,S,U,R,T
8. Drywell Purge Exhaust Valve HV-76-031 5 B,H,S,U,R,T (a)

See Specification 3.3.2, Table 3.3.2-1, for isolation signals that operate each automatic valve.

LIMERICK - UNIT 1 3/4 6-49

_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - w

_= _ _ _ _ _ _ _ _ _ . _ _ = - _ _ - _ - . ---.=- c =- =_..._ .- - - - - . . ~ - - .

l I

LIMITING CONDITION FOR OPERATION '

3.6.5.2.2 The refueling' area secondary containment ventilation system '

automatic isolation valves shown in Table 3.6.5.2.2-1 shall be OPERABLE with isolation times less than or equal to the times shown in Table 3.6.5.2.2-1.

APPLICABILITY: OPERATIONAL CONDITION *.

ACTION:

With one or more of the refueling area secondary containment ventilation system autcmatic isolation valves shown in Table 3.6.5.2.2-1 inoperable, maintain at least one isolation valve OPERABLE in each affected penetration that is open and within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> either:

a. Restore the inoperable valves to OPERABLE status, or
b. Isolate each affected penetration by use of at least one deactivated valve secured in the isolation position, or
c. Isolate each affected penetration by use of at least one closed manual valve, blind flange, or slide gate damper. l Otherwise, in Operational Condition *, suspend handling of l irradiated fuel in the refueling area secondary containment, CORE ALTERATIONS and operations with a potential for draining the reactor vessel. Tte provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.6.5.2.2 Each refueling area secondary containment ventilation system automatic isolation valve shown in Table 3.6.5.2.2-1 shall be demonstrated OPERABLE:

a. Prior to returning the valve to service after maintenance, repair of replacement work is performed on the valve or its I I

associated actuator, control or power circuit by cycling

  • the valve through at least one complete cycle of full travel and verifying the specified isolation time.
b. At least once per 18 months by verifying that on a containment isolation test signal each isolation valve actuates to its isolation position,
c. By verifying the isolation time to be within its limit at least once per 92 days.
  • When irradiated fuel is being handled in the refueling area secondary containment and during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.

LIMERICK - UNIT 1 3/4 6-50

TABLE 3.6.5.2.2-1 REFUELING AREA SECONDARY CONTAINMENT VENTILATION SYSTEM AUTOMATIC ISOLATION VALVES REFUELING APEA (ZONE III) MAXIMUM f ISOLATION TIME ISOLATION (a)

VALVE FUNCTION (Seconds) SIGNALS

1. Refueling Area Ventilation Supply Valve HV-76-ll7 (Unit 1) 5 R,T
2. Refueling Area Ventilation Supply Valve HV-76-118 (Unit 1) 5 .R,T ,

t

3. Refueling Area Ventilation Exhaust '

,1 Valve HV-76-167 (Unit 1) 5 R,T 1

4. Refueling Area Ventilation Exhaust Valve HV-76-168 (Unit 1) 5 R,T
5. Refueling Area Ventilation Supply Valve HV-76-217 (Unit 2)** 5 R,T
6. Refueling Area Ventilation Supply Valve HV-76-218 (Unit 2)** 5 R,T
7. Refueling Area Ventilation Exhaust Valve HV-76-267 (Unit 2)** 5 R,T
8. Refueling Area Ventilation Exhaust Valve HV-76-268 (Unit 2)** 5 R,T
9. Drywell Purge Exhaust Valve HV-76-030 5 B,H,S,U,R,T
10. Drywell Purge Exhaust Valve HV-76-031 5 B,H,S,U,R,T
11. Drywell Purge Exhaust Inboard 5 B,H,S,U,W,R,T Valve HV-57-ll4 (Unit 1) i
12. Drywell Purge Exhaust Outboard i

B,H,S,U,W,R,T 6

Valve HV-57-ll5 (Unit 1)

13. Suppression Pool Purge Exhaust Inboard 5 B,H,S,U,W,R,T Valve HV-57-104 (Unit 1) p i

( 14. Suppression Pool Purge Exhaust Outboard 6 B,H,S,U,W,R,T Valve HV-57-ll2 (Unit 1)

LIMERICK - UNIT 1 3/4 6-51 k

N

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

(

TABLE 3.6.5.2.2-1 (Continued)

REFUELING AREA SECONDARY CONTAINMENT VENTILATION SYSTEM AUTOMATIC ISOLATION VALVES REFUELING AREA (ZONE III) MAXIMUM ISOLATION TIME ISOLATION VALVE FUNCTION (a)

(Seconds) SIGNALS

15. Drywell Purge Exhaust Inboard 5 B,H,S,U,W,R,T Valve HV-57-214 (Unit 2)**
16. Drywell Purge Exhaust Outboard 6 B,H,S,U,W,R,T

. Valve HV-57-215 (Unit 2)**

17. Suppression Pool Purge Exhaust Inboard 5 B,H,S,U,W,R,T Valve HV-57-204 (Unit 2)**
18. Suppression Pool Purge Exhaust Outboard 6 B,H,S,U,W,R,T Valve HV-57-212 (Unit 2)**

I

?

i

  • The provisions of Specification 3.0.4 are not applicable.
    • These lines are blanked off during Unit 1 operation / Unit 2 construction.

(a)

.__ _See Specification 3.3.2, Table 3.3.2-1, for isolation signals that operate each automatic-isolation valve.

LIMERICK - UNIT 1 3/4 6-51a l P

CONTAINMEMT SYSTEMS
  • SURVEILLANCE REQUIREMENTS (Continued)
b. At Itast one per 18 months or (1) after any structural maintenance on the HEPA fil.ter or charcoal adsorber housings, or (2) following #

painting,. fire, or chemical release in any ventilation zone communicating with the subsystem by:

1. Verifying that the subsystem 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.S.a, C.S.c and C.S.d of Regulatory Guide 1.52, Revision 2, March 1978,'and the system flow rate is 3000 cfm + 10%.

2.. Verifying within 31 days after removal that a laborahory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide .

1.52, Revision 2, March 1978, for a methyl iodide penetration

of less than 0.175%; and J
3. Verify that when the fan is running the subsystem flowrate is 2800 cfm minimum from each reactor enclosure (Zones I and II) l and 2200 cfm minimum from the refueling area (Zone III) when tested in accordance with ANSI N510-1980.*
4. Verify that the pressure drop across the refueling area to SGTS prefilter is less than 0.25 inches water gage while operating at a flow rate of 2400 cfm + 10%.
c. After every 720 hours0.00833 days <br />0.2 hours <br />0.00119 weeks <br />2.7396e-4 months <br /> of charcoal adsorber operation by verifying within 31 days af ter removal .iat a laboratory analysis of a representative carborr sample obtained in accordance with i Regulatory Position C.6.b of Regulatory Guide 1.'52, Revision 2, l March 1978, meets the laboratory testing criteria of Regulatory l Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978,

! for a methyl iodide penetration of less than 0.175%.

d. At least once per 18 months by:

l 1. Verifying that the pressure drop across the combined HEPA l

filters and charcoal adsorber banks is less than 9.1 inches l l_ _ water gauge while operating the filter train at a flow rate e ol 8400 cfm + 10%. l I

2. Verifying that the fan starts and isolation valves necessary to draw a suction from the refueling area or the reactor "

l enclosure recirculation discharge open on each of the following test signals:

a) Manual initiation from the control room, and b) Simulated automatic initiation signal.

l I

3. Verifying that the standby gas treatment system can be placed in the cooldown mode of operation from the control room.

l-i

  • Specified subsystem flow rate is for a two unit operation.

During the Unit 2 construction phase, the Unit 1 subsystem flow rate will be 2800 cfm minimum from the reactor enclosure and 2200 cfm minimum from the refueling area (Zone III).

LIMERICK - UNIT 1 3/4 6-53

_ . . _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ -~ .

I

J 4

e ' *

'dONTAINMENT SYSTEMS I

SURVEILLANCE REQUIREMENTS (Continued)

4. Verifying that the temperature differential across each heater is > 15 degrees F when tested in accordance with ANSI N510-1980.
e. After each complete or partial replacement of a HEPA filter bank by verifying.that the HEPA filter bank satisfies the inplace penetration and leakage testing-acceptance criteria of less than 0.05% in accordance with ANSI N510-1980 while operating the system at a flow rate of 3000 cfm i 10%. s
f. After each complete or partial replacement of a charcoal j adsorber bank by verifying that the charcral adsorber bank satisfies the inplace penetration and leakage testing acceptance criteria of less than 0.05% in accordance with ANSI N510-1980 for a halogenated hydrocarbon refrigerant test gas while operating the system at a flow rate of 3000 cfm i 10%.
g. Prior to initial criticality of Unit 2 or after any major system alteration:.
1. Verify that when the SGTS fan is running the subsystem flowrate is 2800 cfm minimum from each reactor enclosure (Zones I and II) and 2200 cfm minimum from the refueling area (Zone III).
2. Verify that one standby gas treatment subsystem will drawdown reactor enclosure Zone I secondary containment to greater than or equal to 0.25 inch of vacuum water gage in
less than or equal to 121 seconds with the reactor l enclosure recirculation system in operation and the adjacent reactor enclosure and refueling area zones are in their isolation modes. <

9 I

I

LIMERICK - UNIT 1 3/4 6-54 _

i r

i

, a.CHNTAIMMENT SYSTEMS

  • BASES .

3/4.6.5 SECONDARY CONTAINMENT Secondary containment is designed to minimize any ground 0 level release of radioactive material which may result from an [

accident. The Reactor Enclosure and associated structures provide secondary containment during normal operation when the drywell is sealed and in service. At other times the drywell may be open and, when required, secondary containment integrity is specified.

Establishing and maintaining a vacuum in the reactor enclosure secondary containment with the standby gas treatment system once per 18 months, along with the surveillance of the doors, hatches, dampers and valves, is adequate to ensure that there are no violations of the integrity of the secondary containment.

The OPERABILITY of the reactor enclosure recirculation system i and the standby gas treatment systems ensuras that sufficient iodine {

removal capability will be available in the event of a LOCA or  ;

refueling accident (SGTS only). The reduction in containment iodine  ;

inventory reduces the resulting SITE BOUNDARY radiation doses associated with containment leakage. The operation of this system and i resultant iodine removal capacity are consistent with the assumptions used in the LOCA and refueling accident analyses. Provisions have been made to continuously purge the filter plenums with instrument air .

l when the filters are not in use to prevent buildup of moisture on the l l adsorbers and the HEPA filters. .

Although the safety analyses assumes that the reactor enclosure secondary containment drawdown time will take 135 seconds, these surveillance requirements specify a drawdown time of 121 seconds. This 14 second difference is due to the diesel generator starting and sequence loading delays which is not part of this surveillance requirement.

The reactor enclosure secondary containment drawdown time analyses assumes a starting point of 0.25 inch of vacuum water gauge and worst case SGTS dirty filter flow rate of 2800 cfm. The surveillance requirements satisfy this assumption by starting the drawdown from ambient conditions and connecting the adjacent reactor ,

enclosure and refueling area to the SGTS to split the exhaust flow -

4 between the 4ree zones and verifying a minimum flow rate of 2800 cfm  !

from the test zone. This simulates the worst case flow alignment and '

verifies adequate flow is available to drawdown the test zone within the required time.

LIMERICK - UNIT 1 B 3/4 6-5 -

_ _ ______P

-t 8 i

'ldONTAINMENTSYSTEMS (Continued) t BASES I

The SGTS fans are sized for three zones and therefore, when aligned to a single zone or two zones, will have excess capacity to more quickly drawdown the affected zones. There is no maximum flow

.llmit to individual zones or pairs of zones and the air balance and drawdown time are verified when all three zones are connected to the SGTS.

The field tests for bypass leakage across the SGTS charcoal adsorber and HEPA filter banks are performed at a flow rate of 3000 +

10% cfm. This flow rate corresponds to the maximum overall three zone inleakage rate of 3264 cfm.

The SGTS filter train pressure drop is a function of air flow rate and filter conditions. Surveillance testing is performed using either the SGTS or drywell purge fans to provide operating convenience.

Each reactor enclosure secondary containment zone and refueling area secondary containment zone is tested independently to verify the design leak tightness. A design leak tightness of 1250 cfm or less for each reactor enclosure and 764 cfm or less for the refueling area at a 0.25 inch of vacuum water gage will ensure that containment integrity is maintained at an acceptable level if all zones are connected to the SGTS at the same time.

3/4.6.6 PRIMARY CONTAINMENT ATMOSPHERE CONTROL The OPERABILITY of the systems required for the detection and control of hydrogen combustible mixtures of hydrogen and oxygen ensures that these systems will be available to maintain the hydrogen concentration within the primary containment below the lower flammability limit during post-LOCA conditions. The primary

, containment hydrogen recombiner is provided to maintain the oxygen concentration below the lower flammability limit. The combustible gas analyzer is.provided to continuously monitor, both during normal s

operations and post-LOCA, the hydrogen and oxygen concentrations in f che primary containment. The primary containment atmospheric mixing '

system is provided to ensure adequate mixing of the containment atmosphere to prevent localized accumulations of hydrogen and oxygen from exceeding the lower flammability limit. The hydrogen control system is consistent with the recommendations of Regulatory Guide 1.7,

" Control of Combustible Gas Concentrations in Containment Following a LOCA," March 1971.

4 LIMERICK -l UNIT l- B3/4 6-Sa~ _ %

P

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AFTER HDDIFICATTON j g - - - - _ - ~,m ,

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.o... ,

UNITED STATES OF AMERICA NUCLEAR REGULKIDRY C04 FISSION Before the Atomic Safety and Licensing Board In the Matter of  : Docket No. 50-352 PHILADELPHIA ELECTRIC COMPANY  :

(Limerick Generating Station,  :

Unit No.1)  :

CERTIFICATE OF SERVICE I hereby certify that copies of Philadelphia Electric Company's Application for Amendment of Facility Operating License NPF-39 in'the above-captioned matter were' served on the following by deposit in the United States mail, first-class postage prepaid on this 13th day of January, 1987.

Kathryn S. Lewis, Esquire Atomic Safety 4 Licensing Municipal Services Building Appeal Board Panel 15th 4 JFK Blvd. U. S. Nuclear Regulatory Commission Philadelphia, PA 19107 Washington, D.C. 20555 Benjamin H. Vogler, Esquire Robert J. Sugarman, Esquire Counsel for NRC Staff Sugarman 6 Hellegers Office of the Executive Legal Director 16th Floor, City Place U. S. Nuclear Regulatory Commission 101 North Broad Street Washington, D.C. 20555 Philadelphia, PA 19107 Angus R. Love, Esquire Troy B. Conner, Jr., Esquire Montgomery County Legal Aid Conner 6 Wetterhahn, P.C.

107 E. Main Street 1747 Pennsylvania Avenue, NW Norristown, PA 19401 Washington, D.C. 20006 Docket 6 Service Section Mr. Robert L. Anthony U. S. Nuclear Regulatory Consission 103 Vernon Lane, Box 186 Washington, D.C. 20555 - (3 copies) Moylan, PA 19065 Atomic Safety 6 Licensing Board Panel Mr. Frank R. Romano U. S. Nuclear Regulatory Commission 61 Forest Avenue Washington, D.C. 20555 Ambler, PA 19002 Barry M. Hartman, Esquire Timothy R. S. Campbell, Director Office of General Counsel Department of Emergency Services P.O. Box 11775 14 East Biddle Street Harrisburg, PA 17108 West Chester, PA 19380

e is . ,

David Wersan, Esquire Ms. Maureen Mulligan-Assistant Constner Advocate Limerick Ecology Action Office of Consumer Advocate P.O. Box 761 1425 Strawberry Square 762 Queen Street Harrisburg, PA 17120 Pottstown, PA 19464

-Mr. Thomas Gerusky, Director Charles W. Elliott, Esquire Bureau of Radiation Protection Counsel for Limerick Ecology Action Department of Environmental Resources 325 N. 10th Street Fulton Bank Building,-5th Floor. Easton, PA 18042

'lhird 6 Locust Streets Harrisburg,.A 17120 E. M. Kelly Senior Resident Inspector Spence W. Perry, Esquire U. S. Nuclear Regulatory Commission General Counsel P.O. Box 47 FEMA, Room 840 Sanatoga, PA .19464 500 C Street, SW Washington, D.C. 20472 Regional Administrator U. S. Nuclear Regulatory Commission Director Region I Pennsylvania Emergency 631 Park Avenue Management Agency King of Prussia, PA 19406 '

Basement, Transportation 4 Safety Building s m-Harrisburg, PA 17120 Jay M. Gutierrez, Esquire U. S. Nuclear Regulatory Commission Region 1 631 Park Avenue King of Prussia, PA 19406 ti / hdl z Euggne J. Bradley /

n Attorney for- / '

Philadelphia Electr c Company s, 2301 Market Street-Philadelphia, PA 19101 l

- _ _

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