Text

Comments on Final Draft Tech Specs Per .Changes Discussed W/Nrc Tech Spec Review Group Reviewer
	ML20198F412
Person / Time
Site:	Perry
Issue date:	11/07/1985
From:	Edelman M; CLEVELAND ELECTRIC ILLUMINATING CO.
To:	Youngblood B; Office of Nuclear Reactor Regulation
References
	PY-CEI-NRR-0389, PY-CEI-NRR-389, NUDOCS 8511140345
	Download: ML20198F412 (34)
	v • d • e

- _ - _ _ _ _ _ _

, T!! C;EUEi.JM!i . C e f h i c ! L L U M I N AT b1 G C a ni P A iH P.O. box 5000 - CLEVELAND. oHlo 44101 - TELEPHONE (216) 622-9800 - ILLUMINATING BLDG. - $5 PUBLICSCUARE Serving The Best Location in the Nation MURRAY R. EDELMAN VICE PRESIDENT NUCLEAR November 7, 1985 PY-CEI/NRR-0389 L Mr. B. J. Youngblood, Chief 4 Licensing Branch No. 1 l Division of Licensing U.S. Nuclear Regulatory Commission Washington, D.C. 20555 Perry Nuclear Power Plant Docket No. 50-440 Comments on Final Draft Perry Technical Specifications

Dear Mr. Youngblood:

This letter is to provide comments on the Final Draft Perry Technical Specifications as requested by your letter dated October 21, 1985.

The attached pages have been marked to transmit our comments to you and your staff. These changes and other editorial changes have been discussed with our Technical Specification Review Group Reviewer and other members of your technical staff. Incorporation of these comments should result in the final Perry Unit 1 Technical Specifications which the Cleveland Electric Illuminating Company can certify to support licensing.

If you have any questions please feel free to call.

Very truly yours, 146 h-4%

Murray Edelman Vice President Nuclear Group MRE:nje Attachments cc: Jay Silberg, Esq.

John Stefano (2)

J. Grobe y

8 I 8511140345 851107 PDR ADOCK C5000440 A PDR

REACTIVITY CONTROL SYSTEMS

j SURVEILLANCE REQUIREMENTS (Continued)

b. At least once per 31 days by; l.

Verifying the continuity of the explosive charge..

s* 2 s 4

' , 2. Determining that the available ght of sodium pentaborate is greater than or equal to 1bs and the sodium pentaborate solution concentration is within the limits of Figure 3.1.5-1

! by chemical analysis.*

3. 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.

c. Demonstrating that, when tested pursuant to Specification 4.0.5, the minimum flow requirement of 41.2 gpm per pump at a pressure of greater than or equal to 1220 psig is met.

d. At least once per 18 months during shutdown by;- - -

i -

1. Initiating both of the standby liquid control system subsystems, including an explosive valve, and verifying that a flow path from the pumps to the reactor pressure vessel is available by pumping domineralized water into the reactor vessel. The replacement charge for the explosive valve shall be from the i

same manufactured batch as the one fired or from another batch which has been certified by having one of that batch success-fully fired.

2. nstrating that all heat traced piping between the storage

' tank and the reactor vessel is unblocked by pumping from the

~ storage tank to the test tank and then draining and flushing thepipingwithdomineralizedwater.f 1

3. Demonstrating that the storage tank operating heater is OPERA 8LE

! h verifying the expected temperature rise of the sodium pentaborate solution in the storage tank after the operating heater is energized.

i T

This test 7, hall also be performed anytime water or baron is added to the i solution or when the solution temperature drops below 70*F.

t

- This test shall also be performed whenever both heat tracing circuits have been

' found to be inoperable and may be performed by any series of sequential, over- ,

lapping or total flow path steps such that the entire flow path is included.

I l

i l PERRY - UNIT 1 3/4 1-19 i g g

i t

1 l 15-

$ LOW HIGH OVERFLOW

? LEVEL ALARM LEVEL ALARM VOLUME

< 14-i cs l j k d

=3 13.4-O

\ MARGIN 1

5 12 .8- REGION OF APPROVED x N

O $ $ 12.7- VOLUME - CONCENTR ATION 'g 85 m a.

n U 12- MINIMUM' REQUIRED CONCENTRATION LINE i

43'00 44C0 4500 46'00 4700 4800 4900 50'C0 4260 4409 4647 5013 i

V - NET TANK VOLUME (GALLONS) l 5)uve 2 /. S'~/ ._- _- -.

TABLE 3.3.1-1 (Continued) i REACTOR PROTECTION SYSTEM INSTRUMENTATION TABLE NOTATIONS (a) A channel may be placed in an inoperable status for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for required surveillance without placing the trip system in the tripped condition provided at least one OPERABLE channel in the same trip system is monitoring that ar,ameter. _

g .- .

g g (b) te shutdown margin has been demonstrated per Specifica- d'" O ' E Unless tion 3.1.1,adeq[the shorting links shall be removed from the RPS circuit prior to and during the time any control rod is withdrawn." 7. f. / ,

(c) An APRM channel is inoperable if there are less than 2 LPRM inputs per level or less than 14 LPRM inputs to an APRM channel.

(d) This function is not required to be OPERABLE when the reactor pressure vessel head is removed per Specification 3.10.1.

~ ~

(e) This function shall be automatically bypassed when the reactor. node switch is not in the Run position.

(f) This function is not required to be OPERABLE when DRYWELL INTEGRITY is

, not required.

(g) With any control rod withdrawn. Not applicable to control rods removed per Specification 3.9.10.1 or 3.9.10.2.

(h) This function is automatically bypassed when turbine first stage pressure is less than the value of turbine first stage pressure corresponding to 40% of RATED THERMAL POWER. -

4.

Not required for control rods removed per Specification 3.9.10.1 or 3.9.10.2. ;

1 PERRY - UNIT 1 3/4 3-5 OCT 16 te.B5

I ATION SURVEILLANCE REQUIREMENTS .

4.3.4.2.1 Each end-of-cycle recirculation pump trip system instrumentation channel shall be demonstrated OPERA 8LE by the performance of the CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3.4.2.1-1.

4.3.4.2.2. LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all channels shall be performed at least once per 18 months.

4.3.4.2.3 The END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM RESPONSE TIME of each trip function shown in Table 3.3.4.2-3 shall be demonstrated to be within its limit at least once per 18 months. Each test shall include at least the logic of one type of channel input, turbine control valve fast closure or turbine stop valve closure, such that both types of channel inputs are tested at 1 east once per 36 months. T snorf eecen + s<<gec, .,a _d* e ma cared (k e sh//k d dk//It

,.,,,, , ,,,,,, ,, y , w ,, , , ,, , ,,,;,

fao or e yc< E ACctxcaiitriey yau,, rg,,a g4 ,gpy,g 7,pg tht! he ven Ynd /> be o,PA,;, ,y, ,,a,.,,,

( 4. 2. A. 2. 4 77e hae a fern / secenary Ac 4, eJe<< a <c 1

ryorea/en fr"m esegha fa,1 s f' /Ae recscala fa, ,swyr cdcaiY beenher /<,k coi/ .cha// 4e aaruece/ n/ /ea.c / oir ee ,s er do snon /Ac.

9 ausp.

j k 0

PERRY - UNIT 1 3/4 3-45 Of.716 m

TABLE 3.3.7.4-1 FIFtfL 1nkouNd' REMOTE SHUTOOWN SYSTEM INSTRUMENTATION MINIMUM CHANNELS OF:RAPLE INSTRUMENT Division 1 Divis'en 2

1. Reactor Vessel Pressure 1 1

2. Reactor Vessel Water Level 1 1

3. Safety / Relief Valve Position *, 3 valves 1/ valve 1/ valve

4. Suppression Pool Water Level 1 1

5. Suppression Pool Water Temperature 1 1

6. Drywell Pressure 1 1

7. Drywell Temperature 1 1

8. RHR System Flow 1 l'

9. Emergency Service Water Flow to RHR 1 1 Heat Exchanger

10. Emergency Service Water Flow to 1 1 Emergency Closed. Cooling Heat Exchanger

11. PCIC System Flow 1 NA

12. RCIC Turbine Speed 1 NA

13. Emergency Closed Cocling 1 1 System Flow li, Lk.a<d MSIV positic i Valves I/V' IVC NA

Indicating lights to indicate %1enoiQ energized /de-energized.

i, n Iwh'atTg b'gM s te ,*w 4 mte. v'<tiv e, p e c/pic,3, k 4-

TA8LE 3.3.7.4-1 (Continued)

REMOTE SHUTOOWN SYSTEM CONTROLS MINIMUM CHANNELS OPERABLE CONTROL Division 1 Division 2 ESW Pump 1 1 ESW Pump Discharge Valve 1 . 1 RHR NX's ESW Inlet / outlet Valves 2(*,)) 2(,)

RHR NX's Inlet / Outlet /8ypass Valves 3I 3(*)

RHR Pump 1 1 RHR to Containment Shutoff Valve 1 1 RHR Pump Suppression Pool Suction Valve 1 1 LPCI Injection Valve: 51 , 1 4 RHR A Shutdown Cooling Suction Valve 1 NA RHR Upper. Pool Suction Valve 1 1 RHR Head spray Isolation Valve 1 NA RHR NX's Dump Valve 1 1 Containment Spray First Shutoff 1 1 Shutdown Cool kc to Feedwater Shutoff 1 f l 1

_ RHR Test Valvs to Suppression Pool 1 1

Shutdown Cooling Outboard Suction Isolation Valve 1 NA RHR A to Radweste Second Isolation Valve 1 NA

, Steam Condensing Shutoff Valve to RCIC 1- - -

T

RHR HX's Steam Shutoff Valve 1 1

RHR Pump Minimus Flow Valve 1 1 ECC Pump 1 1 RCIC Turbine Gland Seal Compressor 1 NA t

RHR & RC7C Steam Supply Outboard Isolation Valve 1 NA I

RCIC Second Test Valve to CST 1 NA RCIC Turbine Trip 1 NA RCIC Steam Shutoff Valve 1 NA RCIC First Test Valve to CST 1 NA RCIC Pump CST Suction Valve 1 NA RCIC Injktion Valve 1 NA RCIC Pump Suppression Pool Suction Isolation Valve 1 NA RCIC Turbine Trip Th'rottle Valve 1 NA RCIC Pump Minimus Flow Valve 1 ,, NA RCIC Turbine Exhaust Shutoff Valve: 1s NA h l RCIC Exhaust Vacuun Breaker Outboard Isolation Valve 1 NA A RCIC Pump Discharge to L.O. Cooler Valve 1 NA RCIC Exhaust Vacuus Breaker Inboard Isolation Valve 1 NA E RHR B Shutdown Cooling Suction Valve NA 1* b Shutdown Cooling Inboard Suction Isolation Valve NA 1*

RHR & RCIC Steam Supply Inboard Isolation Valve NA 18 b RNR & RCIC Steam Supply Wansup Isolation Valve Safety Relief Valves g) 3 1{,)'

3 N,\

Centrol Room to Shutdown Panel Transfer Switches 16,(b) M NA 3,. (b)

APRM Power Supply Breakers 1 (a)1 per valvd *

(b)0ne breaker constitutes one channel for ATWS Division 1 and Division 2.

These Division 2 controls are physically located on the Division 1 panel, b

- These breakers are physically located on ATWS Distribution Panels 1R14-5014 ._

and 1R14-5015. ,,,

I,be=A N'w hI5*ldl** 'M"5 (I(c) 1(c)

PERRY - UNIT 1 3/4 3-75

, _ _ _ _ M 6 1995 _ ,. _ ,

TABLE 4.3.7.4-1 ppae.ga m wi.r uau .d REMOTE SHUTDOWN SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL CHANNEL INSTRUMENT CHECK CALIBRATION

1. Reactor Vessel Pressure M R

2. Reactor Vessel Water Level M R

3. Safety / Relief Valve Position M NA

4. Suppression Pool Water Level M R

5. Suppression Pool Water Temperature M R

6. Drywell Pressure M R

7. Drywell Temperature M R

8. RHR System Flow M -

R -

9. Emergency Service Water Flow to RHR H R Heat Exchanger

10. Emergency Service Water Flow to Emergency M R Closed Cooling Heat Exchanger

11. RCIC System Flow M R

12. RCIC Turbine Speed M R

13. Emergency Closed Cooling System Flow M R

~

d . Ta c<.<A t1 CIV p a sili.n M NR PERRY - UNIT 1 3/4 3-76 fMR1 e mer

REACTOR COOLANT SYSTEM ag OPERATIONAL LEAKAGE . 3 LIMITING CONDITION FOR OPERATION 3.4.3.2 Reactor coolant system leakage.shall be limited to: ,_

a. No PRESSURE BOUNDARY LEAKAGE.

b. 5 gpa UNIDENTIFIED LEAKAGE.

c. 25 gpm IDENTIFIED LEAKAGE averaged over any 24-hour period.

d. 0.5 gpm leakage per nominal inch of valve size up to a maximum of 5 gpm from any reactor coolant system pressure isolation valve speci-fled in Table 3.4.3.2-1, at rated u .,.;. A. 4 pressure.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

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

b. With any reactor coolant system leakage greater than the limits in b and/or c, above, reduce the leakage rate to within the limits within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and i in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

c. With any reactor coolant system pressure isolation valve leakage greater than the above limit, isolate the high pressure portion of the affected system from the low pressure portion within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months by use of at least one other closed manual or deactivated automatic or check

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

A Which have been verified not to exceed the allowable leakage limit at the last refueling outage or after the last time the valve was disturbed, whichever is more recent.

PERRY - UNIT 1 ,

3/4 4-10

EMERGENCY CORE COOLING SYSTEMS

( SURVEILLANCE REQUIREMENTS 4.5.1 ECCS division 1, 2 and 3 shall be demonstrated OPERABLE by:

. a. At least once per 31 days for the LPCS, LPCI and HPCS systems: ^

1. Verifyingbyventingatthehighpointventsthattiiesystem piping from the pump discharge valve to the system isolation valve is filled with water.

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

position.

b. Verifying that, when tested pursuant to Specification 4.0.5, each:

1. LPCS pump develops a flow of at least 6110 gpa at a differentia 1' pressure greater than or equal to 128 psid, (,c ne sys tem .

l

~ ~

2. LPCI pump develops a flow of at least 7100 gpa at a differential pressure greater than or equal to 24 psidx fee %j rystm. _

3. HPCS pump develops a flow of at least 6110 gpa at a differential pressure greater than or equal to 200 psid, 4',e Me epf*=.

c. For the LPCS, LPCI and HPCS systems, at least once per 18 months:

(

1. Performing a system functional test which includes simulated

' automatic actuation of the system throughout its emergency operating sequence and verifying that each automatic valve in

- the flow path actuates to its correct position. Actual injec-tion of coolant into the reactor vessel may be excluded from this test.

- 2. Performing a CHANNEL CALIBRATION of the ECCS discharge line

" keep filled" pressure alarm instrumentation.

d. For the HPCS system, at least once per 18 months, verifying that the suction is automatically transferred from the condensate storage tank to the suppression pool on a condensate storage tank low water level signal and on a suppression pool high water level signal.

~_.

t I (

Except that an automatic valve capable of automatic ret I.

PERRY - UNIT 1 3/4 5-4 00T 161985

EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

e. For the ADS by: -

1. At least once per 31 days, performing a CHANNEL FUNCTIONAL TEST of the safety related instrument air system low pressure alarm system.

2. At least once per 18 months:

a) Performing a system functional test which includes simulated automatic actuation of the system throughout its emergency operating sequence, but excluding actual valve actuation, b) Manually opening each ADS valve when the reactor steam dome pressure is greater than or equal to 100 psig* and observing that either:

1)

The control valve or bypass valve position responds accordingly, or _

2) There is a corresponding change in the measured steam flow, or

3) The safety relief valve discharge pressure switch indicates the valve is open.

c) Performing a CHANNEL CALIBRATION of the safety related instrument air system low pressure alarm sy tem and verifying an alarm setpoint of 2450

50, -t psig on (/

/i decreasing pressure, g yfqg "The provisions of Specification 4.0.4 are not applicable pro adequate to perform the test.

l t

3/4 5-5 PERRY - UNIT 1 W161985

CONTAINMENT SYSTEMS ORYWELL AND CONTAINMENT PURGE SYSTEM

$g h m. .::s -s "

LIMITING CONDITION FOR OPERATION

~

3.6.1.8 The drywell and containment purge 42-inch outboard (IM14-F040, F090) supply and exhaust isolation valves and the 18-inch supply and exhaust isolation valves (1M14-F190, F195, F200, F205) shall be OPERABLE and:

a. Each 42-inch inboard purge valve (IM14-F045, F085) shall be sealed closed.

b. Each 42-inch outboard purge valve (IM14-F040, F090) may be open limited to an opening angle of 50' or less for purge system operation

with such operation limited to 3000 hours0.0347 days 0.833 hours 0.00496 weeks 0.00114 months ** per 365 days for reducing airb.orne activity and pressure control.

c. Each 24-inch (IM14-F055A, B and F060 A, B) and 36-inch (IM14-F065, F070) drywell purge valve shall be sealed closed.

~ d. Each 2-inch (IM51-F090 and F110) backup hydrogen purge system iso-lation valves may be open for controlling drywell pressure th;;E

. ~ . . , , _ _

""'r" V APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

a. With a 42-inch inboard drywell and containment purge supply and/or

, exhaust isolation valve (s) open or not sealed closed, within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months close and/or seal the 42-inch valve (s) or otherwise isolate the penetration or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDCWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. W4th a 18-inch or 42-inch outboard drywell and containment purge supply and/or exhaust isolation valves inoperable or open for nr.e

' than 3000 hours0.0347 days 0.833 hours 0.00496 weeks 0.00114 months per 365 days for purge system operation *, within

~ four hours close the open 18- or 42-inch valve (s) or othemise isolate the penetration (s) or be in at least HOT SHUTDOWN within

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

c. With a 24- or 36-inch drywell purge supply and/or exhaust isolation valve (s) open or not sealed closed, within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months close and/or seal

, close the 24- or 36-inch valve (s) or otherwise isolate the penetra-tion, or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

d. With a drywell and containment purge supply and/or exhaest isolation valve (s) with resilient material seals having a measured leakage rate i exceeding the limit of Surveillance Requirement 4.6.1.8.3 and/or 1

Purge system operation shall be defined as any time or exhaust line.

- Applicable from initial fuel load until 3 months follow 3/4 6-12 PERRY - UNIT 1 OCT161985

f CONTAINMENT SYSTEMS LIMITING CONDITION FOR OPERATION -

DRYWELL AND CONTAINMENT PURGE SYSTEM (Continued) 4.6.1.8.4, restore the inoperable valve (s) to OP in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

e.

With one or more 2-inch backup hydrogen purge system isolation valve (s) not closed except as permitted above, clo 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

- f.

The provisions of specification 3.0.4 are not applicable to ACTIONS a, b, c, and e above.

J SURVEILLANCE REQUIREMENTS 4.6.1.8.1 Each 42-inch inboard drywell and containment purge supply and-exhaust isolation valve shall be verified to be sealed closed at least once p 31 days.

4.6.1.8.2 The cumulative time that the 18-inch and the 42-inch i ou drywell and containment purge supplyleast and onceexha the past 365 days for purge system operation

shall be determined at per 7 days.

At least once per 6 months each sealed closed 42-inch inboard con-i l seals 4.6.1.8.3 is tainment purge supply and exhaust isolation valve w

- less than or equal to 0.05 L, when pressurized to P,.

At least once per 92 days each 18-inch and 42-inch l outboard c

- 4.6.1.8.4 ment purge supply and exhaust isolation valve wi less than or equal to 0.05 L,when pressurized to P,.

Each 24-inch and 36-inch drywell purge valve shall be verified 4.6.1.8.5 t

sealed closed at least once per 31 days.

At least once per 18 months each 42-inch outboard drywell and c i d to be 4.6.1.8.6 tainment purge supply and exhaust isolation valve shall be verif e limited to an opening angle of 50' or less.

' 4.6.1.8.7 Each 2-inch backup hydrogen purge system isolation valve verified to be closed within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months following each str-+"r pu.cc)e.. 1

Purge system operation shall be defined as hanythetime supplythat bo I

the 42-inch outboard purge valves are open concurrently in eit er or exhaust line.

3/4 6-13 PERRY - UNIT 1 00716 25

s CONTAINMENT SYSTEMS p3 p .p .

SURVEILLANCE REQUIREMENTS Nk $Y '. \

4.6.2.3 The drywell air lock shall be demonstrated OPERABLE: _

a. W' thin 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months following each closing, except when the air lock is being used for multiple entries, then at least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , by verifying seal leakage rate less than or equal to 2.5 scf per hour when the gap between the door seals is pressurized to 2.5 psig.

b. By verifying at least once per 7 days that the service and instrument air system pressure in the header to the drywell air lock is > 60 _

psig.

c. By cond'ucting an overall air lock leakage test at 2.5 psig and veri-fying that the overall air lock leakage rate is within its limit:

- - -- 1. Each COLD SHUTDOWN if not performed within the previous 6 month

2. Prior to establishing DRYWELL INTEGRITY when maintenance has been performed on the air lock that could effect-the air-lock sealing capability.

d. By verifying that only one door in the air lock can be opened at a time prior to drywell entry, if not performed in the previous 18 months.

e. By verifying the door inflatable seal system OPERA 8LE at least once per 18 months by conducting a seal pneumatic system leak test and verifying that system pressure does not decay more than 3 psig from 60 psig within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

I -

\

i

~

\

1

At least once per 18 months, the air lock shall be pressurized to 21.8 psid)-

Q ~ prior to conducting the overall air lock test. .

e

/

PERRY - UNIT 1 3/4 6-18 00T161965

I Table 3.6.4-1 Containment and Orywell Isolation Valves

a. CONTAINMENT AUTOMATIC ISOLATION VALVES Test Penetration Valve Maximum hitcab Secondary Containment Pressure-Valve Number Group (c) Isolation Time ', Operational Bypass Path (Psig) e Number (Seconds) p Condition (Yes/No) 5*

Yes 11.31 'g 15* PC 1,2,3 -

IB21-F016 P423 6 6 15* 4 c Oe 1,2,3 Yes 11.31 1821-F019 P423 No 11.31 u 5(g) 1, 2, 3 '

P124 6 No 11.31 1821-F022A 6 5(g) 1, 2, 3 P416 1, 2, 3 No 11.31 1B21-F022B 5(g)

P122 6 1, 2, 3 No 11.31 1821-F022C 5(g)

P415 6 1, 2, 3 No 11.31 1821-F0220 6 5(g) 11.31 P124 1, 2, 3 No 1B21-F028A P416 6 5(g) 11.31 1821-F028B 1, 2, 3 No P122 6 5(g) 11.31 1, 2, 3 No 1821-F028C P415 6 5(g) 11.31 IB21-F0280 22.5* 1,2,3 No P124 6 1,2,3 No 11.31 1821-F067A 6 22.5* 11.31 IB21-F067B P416 1,2,3 No P122 6 22.5* No 11.31 1821-F067C 22.5* 1,2,3

{ 1821-F0670 P415 6 1,2,3 Yes 11.31 1 3 11.31 P201 Yes

$ 1017-F071A P201 1 3 1,2,3 Yes 11.31 1017-F071B 3 1,2,3 1 11.31 1017-F079A P201 1 3 1,2,3 { Yes Yes 11.31 %

1017-F079B 1017-F081A P201 P317 1 3 3

1,2,3 1,2,3 Yes 11.31 %

G P317 1

'1, 2, 3 Yes 11.31 1017-F081B 1017-F089A P317 1 3 3

i I 1,2,3 I

Yes 11.31 fD P317 1 1017-F089B No(h) 11.31 33 1,2,3 11.31 g P421 4 1,2,3 No 1E12-F008 4 33 No (b) + . g ,

1E12-F009 ' P421 60* 1,2,3 o P105 2 1,2,3 (b) p - )I 1E12-F011A 60* N (h) II*31 w

Q 1E12-F011B P407 2 2 90 .1, 2, 3 N 11.31 8

' , .J P408 1, 2, 3 .No(h) m .j ch 1E12-F021 4 90* No (b)

P123 1, 2, 3

g IE12-F023 P105 2 90 1, 2, 3 No (b) 11.31 M 1E12-F024A 2 90 No 1E12-F0248 P407 180* 1,2,3 11.31 P113 4 No

1E12-F037A 4 180*

P412

' 1E12-F037B

v I

l

a. CONTAINMENT AUTOMATIC ISOLATION VALVES (Continued)

Valve Penetration Valve Maximum ' h abl Secondary Test Pressure-Number Group (c) IsolationTimef. Condition Containment Operational -Bypass Path Number (Psig)

(Seconds)

(Yes/No) 27 1,2,3 No 11.31 P113 4 1E12-F042A 27 1,2,3 No 11.31 P412 4 1E12-F0428 4 8 1,2,3 No (b) 1E12-F064A P105 (b) 4 8 1,2,3 No 1E12-F064B P407 (b) 4 8 1,2,3 No 1E12-F064C P408 17 20* 1,2,3 No (b) 1E21-F011 P105 (b)

P105 2 180* 1,2,3 No 1E21-F012 1,2,3 11.31 1E22-F004 P410 16 27 1,2,3 No((h) 11.31 1E22-F012 P409 16 5 1,2,3 No(h)

No h) 11.31 P409 1 180*

1E22-F023 No 11.31 P124 10 .MMi* 2 0 1, 2, 3 11.31 1E32-F001A .MHf* 10 1, 2, 3 No P416 10 11.31 i 1E32-F001E .ae S* A o 1,2,3 No P122 10 11.31 E 1E32-F001J P415 10 M 40 , 1, 2, 3 No IE32-F001N 30 J 1, 2, 3 No (b)

P101 9 11.31 1E51-F031 20*

! 1, 2, 3

) P422 9 No(h) 11.31 1E51-F063 gI No 1E51-F064 P422 9 10 1, 2, 3 11,2,3 No 11.31 Y P422 9 15*

1E51-F076fII 1E51-F07dI) P106, P107 22.5*

i

!l', 2, 3

{

f No 11.31 N P115, P429 9 11.31 N

7 15 1,2,3 Yes ( :c.2 1G33-F001 P131 1, 2, 3 Yes 11.31 P131 7 15 11.31 1G33-F004 1,2,3 Yes ' '~

7 15 11.31' P424 J 1, 2, 3 e

1G33-F028 '

1G33-F034 P424 7 15 1,2,3 Yes No th ) 11.31 3 7 15 { 11.31 ~E3 O 1G33-F039 P132 1,2,3 No 7 15 1 11.31

IG33-F040 P132 i 1, 2, 3 Yes

1G33-F053 P419 7 15

\ , 2, 3 Yes 11.31 ~[-

7 15 P419 g 1G33-F054

\

I

a. CONTAINMENT AUTOMATIC ISOLATION VALVES (Continued) o Maximum Applicable Secondary Test E Valve Penetration Valve Pressure Group (c) Isolation Time Operational Containment l4 Number Number (Seconds) Condition Bypass Path (Psig)

(Yes/No)

E 30 1, 2, 3 I Yes 11.31 1

Z 1G41-F100 P203 1 30 1, 2, 3 Yes 11.31 s 1G41-F140 P301 Yes 11.31 1 30 1, 2, 3 1G41-F145 P301 1,2,3 Yes 11.31 P420 1 20* 11.31 1G50-F272 1,2,3 Yes P420 1 20*

1G50-F277 11.31 22N 1,2,3 Yes P417 1 11.31 1G61-F075 1,2,3 Yes 1G61-F080 P417 1 22M } 11.31 1,2,3 Yes IG61-F165 P418 1 1

2(

27 1,2,3 Yes 11.31 1G61-F170 P418 1, 2, 3,** Yes 11.31 V313 8 4 IM14-F040 1, 2, 3,** Yes 11.31 V313 8 4 IM14-F045 11, 2, 3,** Yes 11.31

, V314 8 4 y 1M14-F085 I 1, 2, 3,** Yes 11.31 V314 8 4 IM14-F090 1, 2, 3,** Yes 11.31

, V313 8 4 1M14-F190 , 1, 2, 3,** Yes 11.31 4

to 1M14-F200 V314 8 4 I 1, 2, 3,* Yes 11.31 V313 8 4 IM14-F195 1, 2, 3,** Yes 11.31 V314 8 4 l 1M14-F205 11.31 5 1,2,3 Yes P114 5 11.31 IM17-F015 5 1,2,3 Yes P208 5 11.31 IM17-F025 1, 2, 3 Yes 5 5 1M17-F035 P428 1, 2, 3 Yes 11.31 P436 5 5 1M17-F045 11.31 P]

2 30* 1,2,3 No 1M51-F090 P302 1,2,3 No 11.31 ,

P302 2 30* "'

1M51-F110 Yes 11.31 1 30 1, 2, 3 0 P108 11.31 1

IP11-F060 1, 2, 3 Yes 1 30 c IP11-F080 i P111 1 30 f 1, 2, 3 Yes 11. 3L -

L Pill M

1P11-F090 1 / Z 2. 1,2,3 Yes 11.31 r

m 1P22-F010 P309 11.31 2 30 i,2,3 Yes S 'j IP43-F055 P310 1, 2, 3 Yes 11.31 P311 2 30 Yes 11.31 J 1P43-F140 2 30 1, 2, 3 ~% ,l P311 1P43-F215 Q ... j i

I I

b. CDNTAINMENT MANUAL ISOLATION VALVES (Continued)

/ PPlicable. Secondary Test Penetration M8ximum Pressure y , Valve Number Number Valve Group (c) Isolation Time l Operational Condition Containment Bypass Path (Psig)

o (Seconds)

(Yes/No) 7 c

1,2,3 11.31 I P123 NA 15 No((h) 77,37 b 1E51-F013(**) P104 NA 5 1,2,3 No(h)

No h) 73,37 1E51-F019 I 60* ,1, 2, 3 IE51-F068 *)N)

P106, P107 NA P115, P429 1,2,3 Yes 11.31 P319 NA NA 11.31 1,2,3 Yes 1E61-F517((d) P319 NA NA 1,2,3 Yes 11.31 1E61-F520(d) P317 NA NA 1,2,3 Yes 11.31 1E61-F523(d) 1E61-F525 d) P317 NA NA

,1, 2, 3 Yes 11.31 NA NA 11.31 1E61-F549 P317 1,2,3 Yes NA NA 11.31 1E61-F550 P317 1,2,3 Yes NA NA 11.31 1E61-F551 P319 1, 2, 3 Yes NA NA 1E61-F552 P319 1,2,3 No (a)

I P102 NA 3 1,2,3 No (a) t l

1G43-F050A I )) P402 NA 3 1,2,3 No (a)

. 1G43-F050g*) P401 NA 3 L3 1G43-F060 w 1,2,3 No (a)

) P434 NA 3 1,2,3 No (a) 1M17-F055(I*)

IM17-F065 P320 NA 3 3

1, 2, 3 l No (a) g cc, P425 NA 1,2,3 No (a)

IM51-F210Af' P318 NA 3 1,2,3 No (a) 7' '

1M51-F210B(,) NA 3 No (a)

P425 1,2,3 ' I IM51-F220A(,) P318 NA 3 No (a)

,1, 2, 3 1M51-F220B g ,) NA 3 No (a) 1M51-F230A P425 1,2,3 NA 3 (a)

IM51-F2308 P318 P425 NA 3 1,2,3 No No (a) P 1,2,3 ,

h 1M51-F240A 3 -

P318 NA a 1,2,3 No (a) y 1M51-F2408 NA 3 No (a) I ,

P425 3 1,2,3 1M51-F250AI *)

m

-g IM51-F250B P318 NA N'

k]

"3

i

c. OTHERCONhAINMENTISOLATIONVALVES ,

Maximum Applicable Secondary Test Valve Penetration Valve Number Group (c) Isolation' Time / Operational Containment Pressure

-< Number (Seconds) Condition Bypass Path (Psig) n t (Yes/No)

E II) NA NA 1,2,3 No (b) 1821-F032A P121

II) NA NA j 1,2,3 No (b) 1821-F032B P414 NA 1,2,3 Yes 11.31 P204 NA IC11-F122(I)

NA NA 1,2,3 Yes 11.31 II) P315 1C41-F520 1,2,3 h) 77,37 1E12-F005 P106, P107, P115, P429 NA NA NA 1, 2, 3 No(Ih) 11.31 P106, P107, P115, P429 NA No(h) 33,33 1E12-F025A NA 1,2,3 P106, P107, P115, P429 NA No(h) 1E12-F025B NA 1, 2, 3 No 11.31 P106, P107, P115, P429 NA ,

1,2,3 11.31 1E12-F025C(f) 1E12-F041C P411 NA NA No(h) 33,33 NA NA 1,2,3 No(h) 4 1E12-F055A P106, P107 P115, P429 1,2,3 No 11.31

P106, P107. P115, P429 NA NA 1E12-F055gI) NA 1,2,3 No 11.31 P421 NA 11.31 i 1E12-F550 NA NA 1,2,3 No 0 1E12-F558A P118 11.31 1E12-F558B ff P431 NA NA 1,2,3 No 1,2,3 No 11.31 II) P112 NA NA g) 11.31 1E21-F006 NA NA 1, 2, 3 No 1E21-F018 P106, P107, P115, P429 NA 1,2,3 11.31 1E22-F005(I) P410 NA 1,2,3 No(h)m9 No g 77,37 NA NA ma 1E22-F035 P409 ,

P123 NA NA 1,2,3 i

No $$

e ,- .

11.31 1E51-F066(I 1G41-F522 II) P203 NA NA - 1,2,3 Yes hN 11.31 NA 1,2,3 j Ye's 11.31

) P114 NA 1,2,3 Yes 11.31 NA NA g

IM17-F010(f#

IM17-F020 1M17-F030 f

gf)

P208 P428 NA NA NA ,

NA 1, 2, 3 1,2,3 '

Yes Yes

_]

j 11.31 11.31 IM17-F040 P436 mj

.:q

I I

Table 3.6.4.1 Containment and Drywell Isolation Valves E NOTES: a. Isolation valve for instrument line which penetrates the. containment, conforms to the requirements E of Regulatory Guide 1.11. The In-service Inspection (IST) program will provide assurance of the testing will not be performed on operability and integrity of the isolation provisions. Type "C" the instrument line isolation valves. The instrument lines will be within the boundaries of the i

g Type "A" test, open to the media (containment atmosphere or suppression pool water) to which they

will be exposed under postulated accident conditions. Three exceptions to the above are penetrations

" P401, P318, and P425. Isolation valves for these three penetrations include the Hz analyzer and Post Accident Sampling System valves. These valves are normally closed post-LOCA, opened only inter-mittently, and will receive Type C tests.

b. Hydrostatic leak test at > 1.10Pa.

c. See Specification 3.3.2, Table 3.3.2-1, for isolation signal (s) associated with each valve groups 1-9. Valve groups 10-13, 16 and 17 are as follows:

Valve Group 10 - MSIV Leakage Control System Valve Group 11 - Reactor Recirculation System Valve Group 12 - Combustible Gas Control System w

Valve Group 13 - Drywell Vacuum Relief System i Valve Group 16 - HPCS Valve Group 17 - LPCS 9

$ d. Test connection valve.

e. Remote manually controlled valve.

q

f. Check valve. [. j

g. See Section 3/4.4.7, " Main Steam Line Isolation Valves." b?

During Type C testing, valve stem and bonnet are checked for leaks as potential secondary r :3 h.

containment bypass leakage paths.

W"l CO M W ITo M * * ,

i, , N,t egdred t, Is c. O f EtlhG t C & O M*T' 9

Standard closure time, based upon nominal pipe diameter, is approximately 12 inches / min for,a gate valves a e approximately 4 inches / min for globe valves.in 1.ne primary cont.ainment and .during-CORE ALTERAUDMS_and y an *eti Q **2. %~ilina ice =di st&~uwi

. pat =atiel fac deminina the reactoraasseh-

=

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i

q n 'l r'~3" r'"

SUREVILLANCE REQUIREMENTS y[ U Nb .!= b .. -

4.6.5.1 Each containment vacuum breaker shall be: ,

a. Verified' closed at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. Demonstrated OPERABLE:

1. At least once per 31 days by:

a) Cycling the vacuum breaker and isolation valve through at least one complete cycle of full travel.

b) Verifying the position indicator OPERABLE by observing expected valve movement during the cycling test.

2. At least once per 18 months by:

a) Verifying the pressure differential required to begin to open the vacuum breaker, from the closed position, to be

< . psid and to be fully open to be < ereefy psid (out-O' I s de containment to containment) and -

\. g b) Verifying the position indicator OPERABLE .by performance of a CHANNEL CALIBRATION .

3. By verifying the OPERA 8ILITY of the vacuum breaker isolation f valve differential pressure actuation instrumentation with the openingsetpointofgreaterthanorequalto.,.^2;;^^'S(psid and less than or equal to psid (containment to outside #* C containment) by performance o a:

O. / / 2, a) CHANNEL CRECK at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

_ b) CHANNEL FUNCTIONAL TEST at least once per 31 days, and

. c) CHANNEL CALIBRATION at least once per 18 months.

PERRY - UNIT 1 3/4 6-43 GCT 16 GB5

CONTAINMENT SYSTEMS fCQ9 t;

" <4 I 5.Q7)[ 7 DRYWELL VACUUM BREAKERS LIMITING CONDITION FOR OPERATION 3.6.5.3 All drywell vacuum breakers shall be OPERABLE and closed. ~

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

a.

With one drywell vacuum breaker inoperable for opening but known to be closed, restore the inoperable vacuum breaker to OP CCLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

b. With one drywell vacuum breaker open, restore the open vacuum breaker to the closed position within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in at least HOT SHUT-DOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

c. With the position indicator of an OPERAULE drywel Otherwise, declare the vacuum breaker inoperable.

local indication.

SURVEILLANCE REQUIREMENTS 4.6.5.3 Each drywell vacuum breaker shall be:

a. Verified closed at least once per 7 days.

b. Demonstrated OPERABLE:

1. At least once per 31 days by a) Cycling the vacuum breaker and associated isolation valve through at least one complete cycle of full travel.

b)

Verifying the position indicators OPERABLE by observing l __,. expected valve movement during the cycling test.

l At least once per 18 months by:

I 2.

a)

Verifying the pressure differential required to open the vacuum breaker, from the closed position, tn be less than or equal to 0.5 psid (containment to drywell), and b)

Verifying the position indicators OPERA 8LE by performance of a CHANNEL CALIBRATION.

3. By verifying the OPERABILITY of the vacuum breaker valve differential inch water gauge d/p by performance of a:

opening setpoint < -

g g -_ CHANNEL FUNCTIONAL TEST at least once per 31 days, and a)

CHANNEL CALIBRATION at least once per 18 months.

b)

L l

ECT 161985 3/4 6-46 PERRY - UNIT 1

-p-

u 51 A ,

CONTAINMENT SYSTEMS FF M,1 a :- -

hlf.

.,. 3iLsypt

.i nJ SURVEILLANCE REQUIREMENTS (Continued)

b. At least once per 18 months or (1) after any structural maintenance on the HEPA filter 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 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 2000 scfm i 10%.

2. Verifying within 31 days after removal that a laboratory analysis V 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 l5 u{

Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978, t

_ by showing a mechyl iodide penetration of less than 0.175% when "d D tested at a temperature of 30*C and at a relative humidity of ;q 70% in accordance with ASTM D3803; and ,

f4

3. Verifying a subsystem flow rate of 2000 scfm i 10% during system ;

operation when tested in accordance with ANSI N510-1980.

4

c. After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of charcoal adsorber operation by verifying \

within 31 days after removal that a laboratory analysis of a repre- - ! *-

sentative carbon sample obtained in accordance with Regulatory 'T 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, by showing a methyl N }[7 ,

iodide penetration of less than 0.175% when tested at a temperature .@

gt-of 30*C and at a relative humidity of 70% in accordance with

ASTM 03803; At least once per 18 months by:

[4Ywg' d.

Performing a system functional test which includes simulated 4(q

1. g automatic actuation of the system throughout its emergency

~

operating sequence for the LOCA.

2. Verifying that the pressure drop across the combineu HEPA filters and charcoal adsorber banks is less than 6.0 inches Water Gauge while operating the filter train at a flow rate of 2000 scfm i 10%.

3. Verifying that the filter train starts and isolation dampers ,

open on each of the following test signals:

a. Manual initiation from the control room, and

b. Simulated automatic initation signal.

4. Verifying that the heaters dissipate 20 kw 1 10% when tested I

in accordance with ANSI N510-1980.

? 3/4 6-49 CCT 161985 PERRY - UNIT 1

~

e

(

U D

PLANT SYSTEMS m S l 'S 1 7' 3 SURVEILLANCE REQUIREMENTS (Continued)

~

5%

r .4

c. At least once per 18 months or (1) after any structural maintenance &\

on the HEPA filter or charcoal adsorber housings, or (2) following g, painting, fire or chemical release in any ventilation zone communi- gg sy cating with the subsystem by: e%

1. Verifying that che subsystem satisfies the in-place penetration g 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 30000 scfm i ICL s3

2. Verifying within 31 days after removal that a laboratory analysis d(

of a representative carbon sample obtained in accordance with ,{s Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory q Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978 g by showing a methyl iodide penetration of less than.1% when '

tested at a temperature of 30*C and at a relative humidity of 4 ),

70% in accordance with ASTM D3803; and I

3. Verifying a subsystem flow rate of 30000 scfm i 10% during sub d h.i system operation when tested in accordance with ANSI M510-1980.

d. After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of charcoal adsorber operation by verifying within 31 days after removal that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory Post-

!. ton C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets r

the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978, by showing a methyl iodida penetration of less than 1% when tested at a temperature of 30*C and at a relative humidity of 70% in accordance with ASTM D3803.

l

e. At least once per 18 months by:

1. Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 4.9 inches Water Gauge while operating the subsystem at a flow rate of 30000 scfm i 10L

2. Verifying that on each of the below emergency recirculation mode i actuation test signals, the subsystem automatically switches to the emergency recirculation mode of operation and the isolation dampers close within 10 seconds: -

a) High Drywell Pressure b) Low Reactor Water Level-Level 1 c) High radiation from control room ventilation duct OCT 161995 PERRY - UNIT 1 3/4 7 4

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

l PLANT SYSTEMS [~ ]' S ))yp

' d .r d = - ;., ,.s j j k -

SURVEILLANCE REQUIREMENTS (Continued)

3. Verifying that the heaters dissipate 100 Kw i 10% when tested in accordance with ANSI N510-1980.

4. Verifying that leakage through the outside air intake dampers (M25-F010A and M25-F0208 for one train and M25-F0108 and M25-F020A for the other train) is limited to less than 20 scfm.

~

5. Verify that leakage through the exhaust dampers M25-F130A and M25-F130By? -ceaf tr:tf er rf th ' :-c "?"-F110? : d F551? :-d C JLE-F110" : d F55L" reeaet % ely, is limited to less than 20 scfm.

f. After each complete or partial replacement of a HEPA filter bank by verifying that the HEPA filter bank satisfies the inplace penetration

' - - testing acceptance criteria of less than 0.05% in accordance with Regulatory Positions C.S.a and C.S.c of Regulatory Guide 1.52 Revi-sion 2, March 1978, while operating the system _at a fjow rate _of 30000 scfm i 10%.

g. After each complete or partial replacement of a charcoal adsorber bark by verifying that the charcoal adsorber bank satisfies the in-I place penetration and testing acceptance criteria of less than 0.05%

in accordance with Regulatory Positions C.S.a and C.S.d of Regulatory Guide 1.52 Revision 2, March 1978, for a halogenated hydrocarbon re-frigerant test gas while operating the system at a flow rate of 30000 scfm i 10%.

t e

a@

3/4 7-5 0071gjggg PERRY - UNIT 1

ELECTRICAL POWER SYSTEMS

@} i W & #h wdd .h t .-

\

- SURVEILLANCE REQUIREMENTS 4.8.1.1.1 Each of the above required independent circuits betweeff the offsite transmission network and the onsite Class 1E distribution system shall be:

a. Determined OPERABLE at least once per 7 days by verifying correct breaker alignments and indicated power availability, and

b. Demonstrated OPERABLE at least once per 18 months during shutdown j by transferring unit power supply from the normal circuit to the alternate circuit. _

4.8.1.1.2 Each of the above required diesel generators shall be demonstrated OPERABLE:

a. In accordance with the frequency specified in Table 4.8.1.1.2-1 on a STAGGERED TEST BASIS by:

1. Verifying the fuel level in the day tank. -

2. Verifying the fuel level in the fuel storage tank.'

3. Verifying the fuel transfer pump starts and transfers fuel from the storage system to the day tank.

lf

4. Verifying the diesel starts from ambient conditions and acceler-i ates to at least 441 rps for Div 1 and Div 2 and 882 rps for Div 3 in less than or equal to 10 seconds *. The generator voltage and frequency shall be 4160

420 volts and 60

1.2 Hz within 10 seconds

after the start signal for Div 1 and Div 2

- - and 13 seconds

after the start signal for Div 3.

- 5. Verifying the diesel generator is synchronized, loaded to queste><,

NW88^ '

er : :;:1 '- 57'^ h for diesel generators Div 1 and Div 2 and 2600 kw for diesel generator Div 3 in less than or equal to rBoo kw seconds *, and operates with this load for at least 60 minutes.

' fisoled h fiesfer}6. Verifying the diesel generator is aligned to provide standby

/444 */ 8ge/ b .I power to the associated emergency busses.

"All diesel generator starts for the purpose of this Surveillance Requirement may be preceded by an engine prelube period. The diesel generator start (10 sec)/ load (60 sec) from ambient conditions shall be performed-at least once per 184 days in these surveillance tests. All other engine starts for the purpose of this surveillance testing may be preceded by other warmup pro-cedures recommended by the manufacturer so that the mechanical stress and wear on the diesel engine is minimized.

M This k<nd i.s nu eanf es $ sistame 4 e sveig rou.tk e eveel,as( Ay of .

l fbe enfi nc. Joads in excerr of /Ais had tha// nof tis w/ss(<fe #4e Yetff /be /*<dt, hoa ever, s hall 3/4 *to 8-4 f tr e sea f% S geo y" G U 16 $85 PERRY - UNIT 1 0

r f rtAter~ }has *10 co k w ,

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

k ELECTRICAL POWER SYSTdMS

- h, d L'd_!= dij?g,Q ig SU SURVEILLANCE REQUIREMENTS (Continued) fordieselgeneratorDiv2,andgreaterthanoreda~1to2200kw (HPCS pump) for diesel generator Div 3 while maintaining speed less than nominal speed plus 75% of the difference between nominal speed and the overspeed trip setpoint or 15% above nominal, whichever is less.

3. Verifying the diesel generator capability to reject a load of A kw for diesel generators Div 1 and Div 2 and 2600 kw for fB00 ' diesel generator Div 3 without tripping. The generator voltage.

shall not exceed 4784 volts for Div 1 and Div 2 and 5000 volts for Div 3 during and following the load rejection.

4. Simulating a loss of offsite power by itself, and:

~~

For divisions 1 and 2:

a)

1) Verifying de-energization of the emergency busses and load shedding from the emergency busses.

- 2) Verifying the diesel generator starts

on the auto-start signal, energizes the emergency busses with per-( manently connected loads within 10 seconds, energizes t

the auto-connected loads through the load sequence (individual load timers) and operates for greater than or equal to 5 minutes while its generator is so Ioaded. e After energization, the stea # state voltage and frequency of the emergency busses shall'be main-tained at 4160

420 volts and 60 i 1.2 Hz during this test.

b) For division 3:

1) Verifying de-energization of the emergency bus.

2) Verifying the diesel generator starts

on the auto-l start signal, energizes the emergency bus with the per-manently connected loads within 13 seconds and operates i

for greater than or equal to 5 minutes while its gen-erator is so loaded. After energization, the steady

All diesel generator starts for the purpose of this Surveillance .equirement R may be preceded by an engine prelube period. The diesel generator start (10 sec)/ load (60 sec) from ashient conditions shall be perfomed at least once per 184 days in these surveillance tests. All other engine starts for the purpose of this surveillance testing may be preceded by other wamup pro-

', cedures recommended by the manufacturer so that the mechanical stress and wear on the diesel engine is minimized. ,_

PERRY - UNIT 1 3/4 8-6 0CT16125

~

l i

l ELECTRICAL POWER SYSTEMS eo

= u dg g .

h. ,

SURVEILLANCE REQUIRENENTS (Continued)

I

~

voltage and frequency of the emergency.bGl'shall be maintained at 4160

420 volts and 60.i 1.2 Hz during this test. '

7. Verifying that all automatic diesel generator trips are auto-matica11y bypassed with an ECCS actuation signal except:

a) For divisions 1 and 2, engine overspeed and generator differential current. ,

yeiam 4800 - 7000 For division 3, engine overspeed and generator differential b) k u 4'.c + k < N et current.

h e hea d M 8. Verifying the diesel generator operates for at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

betuecd f600 During this test, the diesel generator shall be loaded to 4740-inet

-tfor diesel generator Div 1 and Div 2. The Div 3 diesel generator fgog n kw f,7 shall be loaded to greater than or equal to 2860 kw for the first two hours of this test and 2600 kw for the remaining 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months of ,

4

//g yemo".t A 2 2. this test. The generator voltage and frequency shall be 4160 t 0 420 volts and 60 1 1.2 Hz within 10 seconds after the stdrt signal b*M - for Div 1 and Div 2 and within 13 seconds after the start signal

. for Div 3; the steady state generator voltage and frequency shall be maintained within these limits during this test. Within l 5 minutes after completing this 24-hour test, perfom Surveillance l

{ Requirement 4.8.1.1.2.e.4.a.2 and b.2* or perform Surveillance l Requirement 4.8.1.1.2.e.6.a.2 and b.2.* '

1

. 9. Verifying that the auto-connected loads to each diesel generator do not exceeds 9996 kw for diesel generator Div 1 and Div 2 and i

.,_ 7860 " 2860 kw for diesel generator Div 3. 1 1

Verifying the diesel generator's capability to:

10.

i

- a) Synchronize with the offsite power source while the generator I is loaded with its emergency loads upon a simulated i

. . restoration of offsite power, .

l b). Transfer its loads to the offsite power source, and

- c) 8e restored to its standby status. I

\

! 11. Verifying that with the diesel generator operating in a test mode and connected to its bus, a simulated ECCS actuation signal over-rides the test mode by (1) returning the diesel generator to

If Surveillance Requirements 4.8.1.1.2.e.4.a.2 and b.2 or 4.8.1.f 2.e.6.a.2 and b.2 are not satisfactorily completed, it is not necessary to repeat the preceding 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months test. Instead, the diesel generator Div 1 or Div 2 may be operated at 5740 kw or diesel generator Div 3 may be operated at 2600 kw for i one hour er until o

- Tids b..A is me=perating temperatures have stabilized.4 c p,(cu e. +. .v.N

%=As in < u c e u

f +4.'s ba.M r kil n o t a vah d ate ihe fes t'* WUg p(,f /**g',buever, rAost n + 4 3e,4gg Man noo ke noe y reater fhw Occo ku,

I l

rh E -=

.N

[3 rp ELECTRICAL POWER SYSTEMS j,7 SURVEILLANCE REQUIREMENTS (Continued i

to standby operation, and (2) automatically energizes the emer-gency loads with offsite power. ,

12. Verifying that each fuel transfer pump transfers fuel from the fuel storage tank to the day tank of each diesel.

13. Verifying that the automatic load sequence timers are OPERABLE with the interval between each load block within 110% of its design interval for diesel generators Div 1 and Div 2.

14. Verifying that the following diesel generator lockout features prevent diesel generator starting only when required:

a. For diesel. generators Div 1 and Div 2:

1) Control room switch in pull-to-lock (with local / remote switch in remote).

2) Local / remote switch in local _ _

3) Barring device engaged

b. 4)

Fordiesel generator Div 3:%e/nml niks, in ine,o i

1) Emergency run/stop switch in stop

2) Maintenance / auto / test switch in maintenance

f. At least once per 10 years or after any modifications which could af-fact diesel generator interdependence by starting all _three diesel generators simultaneously, during shutdown, and verifying that all three diesel generators accelerate to at least 441 rps for diesel i generators Div 1 and Div 2 and 882 rps for diesel generator.Div 3 in less than or equal to 10 seconds.

~

g. At least once per 10 years by:

1. Draining each fuel oil storage tank . removing the accumulated sediment and cleaning the tank using a sodium hypochlorite or equivalent solution, and

2. Perfoming a pressure test of those portions of the diesel fuel oil system designed to Section III, subsection NO of the ASME Code in accordance with ASME Code Section 11 Article IWD-5000.

4.8.1.1.3 Reports - All diesel generator failures, valid or non-valid, shall be

' reported to the Commission pursuant to Specification 6.9.2 within.30 days.

Reports of diesel generator failures shall include the information recommended in Regulatory Position C.3.b of Regulatory Guide 1.108, Revision 1, August 1977.

If the number of failures in the last 100 valid tests, on a per nuclear unit basis, is greater than or equal to 7, the report shall be supplemented to in-clude the additional information recommended in Regulatory Position C.3.b of --

Regulatory Guide 1.108, Revision 1, August 1977.

3/4 8-9 M 161985

, PERRY - UNIT 1

j(I"fl.* n l n ,__.3 -

l.

) REFUELING OPERATIONS

~5 U ., ] j SURVEILLANCE REQUIREMENTS (Continued)

b. Performance of a CHANNEL FUNCTIONAL TEST:

1. Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior to the start of CORE ALTERATIONS, and

2. At least once per 7 days.

c. Verifying that the channel count rate is at least 0.7 cps *:

1. Prior to control rod withdrawal,

2. Prior to and at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months during CORE ALTERATIONS, and

--- 3. At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

except that: - - -

1. During fuel unloading, the reqJired Count rate may be permitted to be less than 0.7 cps *.

2. Prior to and during fuel loading, until sufficient fuel has been

(

loaded to maintain at least 0.7 cps *, the required count rate may be achieved by:

a) Use of portable external source, or b) Loading up to 2 fuel assemblies # in cells containing

,~

inserted control rods around an SRM.

~

d. Verifying within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months prior to and at lea g once thatper the 12 hours shorting during the time any control rod is withdrawn links have been removed from the RPS circuitry unless adequate shutdown margin has been demonstrated per Specification 3.1.1) ad N " u - c.4- e## (e6u.IposN.s Afu(. k.kn teem Ameuin%(. O PEMArst.C per- fp ecoWer fik f,9 /,

i

Provided signal to noise ratio 12.

"Not required for control rods removed per Specification 3.9.10.1 or 3.9.10.2.

These fuel assemblies may be loaded with the SRM count-rateAof'0.7 cps pro- ._

l .

vided the signal-to-noise ratio is 1 herwise 3~

PERRY - UNIT 1 3/4 9-4 DCT 16190e.

a REACTIVITY CONTROL SYSTErtS " " " " ' '

BASES Id l

I CONTROL ROD PROGRAM CONTROLS (Continued) -

I l

The RPCS provide automatic' supervision to assure that out of:~ sequence rods '

will not be withdrawn or inserted. ---

i The analysis of the rod drop accident is presented in Section 15.4 of the FSAR and the techniques of the analysis are presented in a topical report, Reference 1, and two supplements, References 2 and 3. ,

The RPCS is also designed to automatically prevent fuel damage in the event of erroneous power operation. rod withdrawal from locations of high power density during higher A dual channel system is provided that, above the low power setpoint,

restricts the withdrawal distances of all control rods. This restriction is greatest at highest power levels. ~- -

3/4.1.5 STANDBY LIQUID CONTROL SYSTEM 7 13.4 9. by ucighh

-n_ - -.J

(

The standby liquid control sy em provides a backup capability for bringing

- the reactor from full power to a old, Xenon-free shutdown, assuming that the withdrawn control rods remain fi d in the rated power pattern. - To meet this i

objective it is necessary to in ect a quantity of boron which produces a concen-

~. tration of 660 ppe in the reac r core. To allow for potential leakage and imperfect mixing this concent tion is increased by 25%. The required concen-f tration is achieved by havin a minimum available quantity of 4 g

p sodium pentaborate solution containing a minimum f soc tumof % 1bs. o %

pentaborate. This quantity of solution is the net amount above tne pump suc- , gg ,

tion, thus allowing for the portion that cannot be injected. The pumping rate of 41.2 gpa provides a negative reactivity insertion rate over the permissible sodium pentaborate solution volume range which adequately compensates for the positive reactivity effects due to temperature and xenon during shutdown. The

- temperature requirement for the sodium pentaborate solution is necessary to

. _ ensure that the sodium pen'.aborate remains in solution.

~

' With redundant pumps and explosive injection valves and with a highly

, reliable control rod scram system, operation of the reactor is permitted to continue for short periods of time with the system inoperable or for longer periods of time with one of the redundant components inoperable.

Surveillance requirements are established on a frequency that assures a high reliability of the system. Once the solution is established, boron con-centration will not vary unless more boron or water is added, thus a check on the temperature and volume once each 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months assures that the solution is available for use.

Replacement of the explosive charges in the valves at regular intervals will assure that these valves will not fail because of deterioration of the charges.

1. C. J. Paone, R. C. Stirn and J. A. Woolley, " Rod Drop Accident Analysis for Large BWR's," G. E. Topical Report NEDO-10527, March 1972

2. C. J. Paone, R. C. Stirn and R. M. Young, Supplement 1 to NEDO-10527, July 1972

3. Jc M. Haun, C. J. Paone and R. C. Stirn, Addendum 2, " Exposed Cores,"

Supplement 2 to NEDO-10527, January 1973 j PERRY - UNIT 1 8 3/4 1-4 OM 161995

m W e.

CONTAINMENT SYSTEMS h

~

=..

h O ] .m In f

BASES DEPRESSURIZATION SYSTEMS (Continued)

Experimental data indicates that effective steam condensation without excessive load on the containment pool walls will occur with a quen~cher device and pool temperature below 200 F during relief valve operation. -4pecifications have been placed on the envelope of reactor operating conditions to assure the bulk pool temperature does not rise above 185'F in compliance with the containment structural design criteria.

In addition to the limits on temperature of the suppression pool water, operating procedures define the action to be taken in the event a safety-relief valve inadvertently opens or sticks open. As a minimum this action shall include: (1) use of all available means to close the valve, (2) initiate suppression pool water cooling, and (3) if other safety-relief valves are used to depressurize the reactor, their discharge shall be separated from that of the stuck-open safety relief valve, where possible, to assure mixing and uniformity of energy insertion to the pool.

The containment spray system consists of two 100% capacity loops, each with three spray rings lecated at different elevations about the inside circum-ference of the containmer.t. RHR pump A supplies one loop and RHR pump B'sup-plies the other.

RHR pump C cannot supply the spray system. Dispersion of the flow of water is effected by 345 nozzles in each loop, enhancing the condensa-tion of water vapor in the containment volume and prever. ting overpressurization.

Heat rejection is through the RHR heat exchangers. The turbulence caused by the spray system aids in mixing the containment air volume to maintain a homogeneous mixture for Ha control.

The suppression pool cooling function is a mode of the RHR system and functions as part of the containment heat removal system. The purpose of the system is to ensure containment integrity following a LOCA by preventing exces-sive containment pressures and temperatures. The suppression pool cooling rode

_. is designed to limit the long term bulk temperature of the pool to 185'F con-sidering all of the post-LOCA energy additions. The suppression pool cooling trains, being an integral part of the RHR syscem, are redundant, safety-related component systems that are initiated following the recovery of the reactor vessel water level by ECCS flows from the RHR system. Heat rejection to the emergency service water is accomplished in the RHR heat exchangers.

The suppression pool make-up system provides water from the upper containment pool to the suppression pool by gravity flow through two 100%

capacity dump lines following a LOCA. The quantity of water provided is sufficient to account for all conceivable post-accident entrapment volumes, ensuring the long term energy sink capabilities of the suppression pool and l maintaining the water coverage over the uppermost drywell vents. T;- . . .. Mum '

::t:--d df ttr : :b:x th: : ;;n;;Sn ;::1 M;h act:r 1:n! tr * +T sf

!" mf- "-11 4< -d T t: t: pr ! d: 'h;dkg ef th; dga:ll k 07,; m; t af l

M i . int.nt d7 During refueling, there will be administrative control i to ensure the make-up dump valves will not be opened.

PERRY - UNIT 1 8 3/4 6-5 ECI16 M l i

CONTAINMENT SYSTEMS hF '1 P '. q ry BASES :

J i

3/4.6.6 SECONDARY CONTAINMENT -

Secondary containment is designed to minimize any ground leverielease of radioactive material which may result from an accident. The Shield Building provides secondary containment during normal operation when the containment is sealed and in service. At other times, the containment may be open and, when required, secondary containment integrity is specified.

Establishing and maintaining a vacuum in the annulus with the annulus exhaust gas treatment system, along with the surveillance of the doors, hatches, and valves, is adequate to ensure that there are no violations of the integrity of the secondary containment.

The OPERABILITY of the annulus exhaust gas treatment systems ensures that

' -sufficient iodine removal capability will be available in the event of a LOCA.

The reduction in containment iodine inventory reduces the resulting site ;

~~ boundary radiation doses associated with containment leakage. The operation !

of this-system and resultant iodine removal capacity are consistent with the assumptions used in the LOCA analyses. Continuous operation of the system

~

with the heaters OPERA 8LE for 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months during each 31 day period is sufficient to reduce the buildup of moisture on the absorbers and HEPA filters. -

-- 3/4.6.7 ATMOSPHERE CONTROL The OPERA 8ILITY of the systems required for the detection and control of hydrogen gas ensures that these~ systems will be available to maintain the hydrogen concentration within the containment below its flammable limit during post-LOCA conditions. The containment hydrogen recombiner system is capable of controlling the expected hydrogen generation associated with (1) zirconium-water

-- reactions, (2) radiolytic decomposition of water and (3) corrosion of metals c- within containment. The combustible gas mixing system is provided to ensure ,

adequate mixing of the containment atmosphere following a LOCA. This mixing '

- action will prevent localized accumulations of hydrogen from exceeding the flammable 15it.

Two 1005 combustible gas mixing subsystems are the primary means of H 2

control within the drywell, purging hydrogen produced following a LOCA into the containment volume. Hydrogen generated from the metal-water reaction and radiolysis is assumed to evolve to the drywell atmosphere and form a homogenous mixture through natural forces and mechanical turbulence (ECCS pipe break flow).

The combustible gas mixing system forces drywell atmosphere thr:r;;h 5 bri-

"- +

=*21 d into the containment.ec4 e. e . oui u no un,... r^2 ""'M.

The hydrogen control system is consistent with the recommendations of Regulatory Guide 1.7, " Control of Combustible Gas Concentrations in l Containment Following a LOCA", November, 1978.

The OPERA 8ILITY of the primary containment /drywell hydrogeri igniters ensures that hydrogen combustion can be accomplished in a controlled manner following a degraded core event that produces hydrogen concentrations in excess of LOCA conditions. ._

Inaccessible areas are defined as areas that have high radiation levels i during the entire refueling outage period. These areas are the heat exchanger, -

filter demineralizer, backwash, and holding pump rooms of the RWCU system.

PERRY - UNIT 1 8 3/4 6-7 g .

f i$ l 1 :'- ?

f[ us' uJa L. h ,.j'g ADMINISTRATIVE CONTROLS 6.4 TRAINING 6.4.1 A retraining and replacement training program for the unit staff shall be maintained under the direction of the Perry Training Section General Super-visor, and shall meet or exceed the requirements and recommendations of Sec-tion 5.5 of ANSI N18.1-1971 and Appendix A of 10 CFR Part 55 and the supplemen-tal requirements specified in Sections A ard C of Enclosure 1 of the March 28, 1980 NRC letter to all licensees, and shall include familiarization with relevant industry operational experience.

6.5 REVIEW AND AUDIT 6.5.1 PLANT OPERATIONS REVIEW COMMITTEE (PORC)

FUNCTION 6.5.1.1 The PORC shall function to advise the Managers, Perry Plant Departments, on all matters related to nuclear safety.

COMPOSITION 4

6.5.1.2 The PORC shall be composed of the: - - ~~

~

Chairman: Manager, Perry Plant Operations Department Vice-Chairman / Member: Manager, Perry Plant Technical Department Vice-Chairman / Member: Technical Superintendent, Perry Plant Techtiical Department Member: General Supervisor, Operations Section Member: General Supervising Engineer, Technical Section Member: General Supervisor, Maintenance Section Member: Reactor Engineer

- , Member: General Supervising Engineer, Radiation

__ Protection Section

~~~ Member: Plant Health Physicist Member: General Supervising Engineer, Instrumentation and Control Section ALTERNATES 6.5.1.3 All alternate members shall be appointed in writing by the PORC Chairman to serve on a temporary basis; howevar, no more than two alternates shall participate as voting members in PORC activities at any one time.

MEETING FREQUENCY

6. 5.1. 4 The PORC shall meet at least once per calendar month and as convened by the PORC Chairman or his designated alternate.

QUORUM -

6. 5.1. 5 The quorum of the PORC necessary for the performance of the PORC responsibility and authority provisions of these Technical Specifications shall consist of the Chairman or his designated alternate and at least-frer members including alternates.

o+f PERKY - UNIT 1 6-8 ,,..

._. - . -- _ .. . _ _ _

PY-CEI-NRR-0389, Comments on Final Draft Tech Specs Per .Changes Discussed W/Nrc Tech Spec Review Group Reviewer

Text

Dear Mr. Youngblood:

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PY-CEI-NRR-0389, Comments on Final Draft Tech Specs Per .Changes Discussed W/Nrc Tech Spec Review Group Reviewer

Text

Dear Mr. Youngblood:

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