Text

Amends 179 & 182 to Licenses DPR-44 & DPR-56,respectively, Extending Interval for Certain TS Surveillance Requirements to 24 Months W/Addl 25-percent Grace Period
	ML20056E599
Person / Time
Site:	Peach Bottom
Issue date:	08/02/1993
From:	Boyle M; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML20056E600	List: ML20056E599; ML20056E605;
References
	NUDOCS 9308240315
	Download: ML20056E599 (54)
	v • d • e

- _-

3

[gm *ta jo UNITED STATES v

g NUCLEAR REGULATORY COMMISSION y

E W ASHWGT ON. D. C. 20555 s.,

/

PHILADELPHIA ELECTRIC COMPANY PUBLIC SERVICE ELECTRIC AND GAS COMPANY l

DELMARVA POWER AND LIGHT COMPANY I

ATLANTIC CITY ELECTRIC COMPANY DOCKET NO. 50-277 l

PEACH BOTTOM ATOMIC POWER STATION. UNIT NO. 2 AMENDMENT TO FACILITY OPERATING LICENSE j

Amendment No.179 License No. DP.R-44 i

1.

The Nuclear Regulatory Comission (the Comission) has found that:

A.

The application for amendment by Philadelphia Electric Company, et.

al. (the licensee) dated September 28, 1992 and October 19, 1992, as supplemented by letters dated March 16, 1993, April 13, 1993, May 28, 1993, June 7, 1993, June 23, 1993, July 1, 1993 and July 7, 1993, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Comission's rules and 1

regulations set forth in 10 CFR Chapter I.

B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the J

Comission; C.

There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Comission's regulations; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health or safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Comission's regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C(2) of Facility Operating License No. DPR-44 is hereby j

amended to read as follows:

9308240315 930B02 PDR ADDCK 05000277 P

PDR

t

, l (2) Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No.179, are hereby incorporated in the license.

PECO shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of August 2,1993.

-1 FOR THE NUCLEAR REGULATORY COMMISSION r.1 Michael L. Bo

, Acting Director Project Directorate I-2 Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation i

Attachment-i Changes to the Technical Specifications Date of Issuance: Aui;ust 2,1993 h

i I

l i

l l

L l

a ATTACHMENT TO LICENSE AMENDMENT NO.179 FACILITY OPERATING LICENSE NO. DPR-44 DOCKET NO. 50-277 Replace the following pages of the Appendix A Technical Specifications with the enclosed pages.

The revised areas are indicated by marginal lines.

Remove Insert 5

5 6

6 8

8 l

44 44 i

Bla Bla 86a 86a 157 157 169 169 170 170 l

178 178 l

188 188 i

193 193 211 211 217 217 218d 218d 218e 218e 218f 218f 218h 218h 2181 2181 218j 218j 234b 234b 240j(1) 240j(1) 240j(2) 240j(2) 240v 240v

a PBAPS 1.0 ETTINITIONS (Cont'd) of f site Dos e Calculation Manual - Contains the current methodology and parameters used in the calculation of of fsite doses due to radioactive gaseous and lieuid ef fluents and describes the environmental radiological acnitoring program.

l CPEPABLE - OPERABEITY - A system, subsystem, train, component, l

or device is OPERABLE or has OPERABEITY when it is capable of performing its specified function and all instrumentation, controls, normal and emergency electrical power sources, cooling or seal water supplies, lubrication systems, and other auxiliary couipment that are reonired for the system, subeystem, train, component, or device to perform its function are also capable of performinig their related support functicut.

Oeeratine - Operating means that a system or component is performing its intended functicas in its recuired manner.

oeeratine Cvele - Interval between the end of one refueling outage for a particular unit and the and of the next subs ecuent refueling outage for the same unit.

Pr:, mary C=ntain=ent Intecrity - Primary containment integrity

=sans snat cne crywell anc pressura suppressics chamber are

)

l intact and all of the ic11owing conditions are satisfied:

1.

All primary centainment penetrations raggired to be closed i

during ac=ident ecnditicas are either:

a)

Capable of being closed by an OPE 3ABLE c ntainment autsmatic isolation valve system, or b)

C1csed by at least one manual valve, blind flange, or l

deactivated automatic valve secured in its closed position, except as may be provided in Specificaticas

3. 7.D. 2 and 4. 7.D. 2.

Manual vs.1ves =ay be opened to perfers necessary operational activities.

2.

At least ene door in each airl=ck is closed and sealed.

3.

All blind flanges and manways are closed.

See the term "Once Per Cycle" under the Definition of " Surveillance Frequency" for specific time limits on surveillances with a frequency that includes the tem " Operating Cycle."

l l

Amendment No.1W,179 l

~,

I g

i PBAPS 1.0 DEFINITIONS (Cont'd)

Protective Action - An action initiated by the protection system when a limit is reached.

A protective action can be at a channel or system level.

Protective Function - A system protective action which results from the protective action of the channels monitoring a particular plant conditicri.

Purse - Purgrine - Purge or Purging is the controlled process of discharging air or gas from a eccfinement to maintain temperature, pressure, humidity, concentration or other operating condi ti cri, in such a manner that replacement air or gas is recuired to purify the confinement.

Rated Power - Rated power ref ers to operation at a reactor power of 3,293 MWt; this is also termed 100 percent power and is the maxistan power level authorized by the operating license.

Rat ed steam flow, rated coolant flow, rated neutron flux, and rated nuclear system pressure ref er to the values of these parameters when the reactor is at rated power.

Rosetor Power Operation - Reactor power operation is any l

operation with the sede switch in the "Startup" or "Run" positicri with the reactor critical and above 14 rated power.

l Reactor Vessel Pressure - Unless otherwise indicated, reactor vessel pressures listed in the Technical Specifications are those measured by the reactor vessel steam space detecters.

l Refuel Mode - With the made switcts in the refuel position, the reactor is shutdown and interlocks are established so that only one control rod may be withdrawn.

Refueline Outsee - Refueling outage is the period of time between the shutdown of the unit prior to a refueling and the startup of the unit af ter that refueling.

For the purpose of designatine frecuency of testing and surveillance, a refueling outage shall sean a regularly scheduled outage: however, where such outages occur within 8 months of the completion of the previous refueling

See the term " Refuel" under the Definition of " Surveillance Frequency" for specific time limits on surveillances with a frequency that includes the term

" Refueling Outage."

AmendmentNo.Idd,179 __

n -

Unit 2 i

PBAPS li 1.0 DEFINITIONS (Cont'd)

)

Simulated Automatic Actuation - Simulated automatic actuation means applying a simulated j

signal to the sensor to actuate the circuit in' question.

s i

l Site Boundary - That line beyond which the land is not owned, leased or otherwise j

controlled by licensee.

l Source Check - A source check shall be the qualitative assessment of channel response when the channel sensor is exposed to a radioactive source.

l

~

Startup/ Hot Standby Mode - In this mode the reactor protection scram trips, initiated by condenser low vacuum and main steam line isolation valve closure are bypassed, the reactor protection system is energized with IRN neutron monitoring system trip, the APRM

)

15% high flux trip, and control rod withdrawal interlocks in service. This is often referred to as just Startup Mode. This is intended to imply the Startup/ Hot Standby position of the mode switch.

{

Surveillance Frecuency - Periodic surveillance tests, checks, calibrations, and i

i examinations shall be performed within the specified surveillance intervals. Specified j

periodic surveillance intervals are defined as:

I (N) Hours At least once per (N) hours j

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

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

(M) Days Atleastonceper(N) days i

Twice Per Week At least once per 4 days l

l Weekly At least once per 7 days j

(N) Weeks At least once per (7xN) days j

Semi monthly At least once per 15 days i

Monthly At least once per 31 days j

2 Month At least once per 61 days Quarterly or 3 month At least once per 92 days i

Semi-annually or 6 month At least once per 184 days j

Annually or 12 month At least once per 366 days i

Once Per Cycle At least once per 732 days 18 month At least once per 550 days i

Refuel At least once per 732 days 1

(N) Years Atleastonceper(366xN) days (N) Refuel Cycle At least once per (732xN) days j

24 Months At least once per 732 days t

i These specified time intervals may be exceeded by 255. Surveillance tests are not required on systems or parts of the systems that are not required to be operable or are tripped.

If tests are missed on parts not required to be operable or are tripped, then j

they shall be performed prior to returning the system to an operable status.

j A surveillance test of the diesel generators, that requires a plant outage, may be j

deferred beyond the calculated due date until the next refueling outage, provided the equipment has been similarly tested and meets the surveillance requirement for the other 4

unit.

i l

Transition Boiling - Transition boiling means the boiling regime between nucleate and j

film boiling. Transition boiling is the regime in which both nucleate and film boiling j

occur intermittently with neither type being completely stable.

i Trio System - A trip system means an arrangement of instrument channel trip signals and

-auxiliary equipment required to initiate Amendment No. J02. Il7, I23 I66.179 1

Unit 2 i

TABLE 4.1.2 REACTOR PROTECTION SYSTEM (SCRAM) INSTRUMENT CALIBRATION MINIMUM CAllBRATION FREQUENCIES FOR REACTOR PROTECTION INSTRUMENT CHANNELS Instrument Channel Group (1)

Calibration (4)

Minimus Frequency (2) i IRM High Flux C

Comparison to APRM on Maximum frequency once t

Controlled Shutdown per week, t

I APRM High Flux i

Output Signal 81 Heat Balance Twice per week.

l Flow Blas Signal B1 With Standard Pressure Every eighteen months.

Source LPRM Signal B1 TIP System Traverse Every 6 weeks.

f h

High Reactor Pressure B2 Standard Pressure Source Once per operating cycle.

High Drywell Pressure B2 Standard Pressure Source Once per operating cycle.

i Reactor Low Water Level B2 Pressure Standard Once per operating j

cycle.

High Water Level in Scram A

Water Column Every refueling outage.

Discharge Instrument Volume 3

Turbine Condenser Low Vacuum B2 Standard Vacuum source Once per operating

cycle, h

Main Steam Line Isolation valve A

Note (5)

Closure Main Steam Line High Radiation B1 Standard Current Source (3)

Every 3 months.

l.

U Turbine First State Pressure A

Standard Pressure Source Every 6 months.

Permissive i

w E

g Unit 2 2:s" TABLE 4.2.B (CONTINUED) f MINIMUM TEST AND CAllBRATION FREQUENCY FOR CSCS-Instrument Channel Instrument Functional Test Calibration Frequency instrument Check m

E

13) HPCI and RCIC (1)

Once/3 months None g

Steam Line Low Pressure b

14) HPCI Suction Source (1)

Once/3 month:

None Levels g

15) 4KV Emergency Power Once/ operating cycle Once/5 years None System voltage Relays (HGA.5V) h

16) ADS Relief Valves Once/ operating cycle Once/ operating cycle None n

Bellows Pressure Switches

17) LPCI/ Cross Connect Once/ refueling cycle N/A N/A Valve Position

18) Condensate Storage Once/3 months Once/ operating cycle Once/ day Tank Level (RCIC) (7) l 19) 4KV Emergency Power Once/ month Once/elghteen months None Source Degraded Voltage Relays (IAV,CV-6 ITE)

l Unit 2

- ajl TABLE 4.2.F 3

MINIMUM TEST AND CALIBRATION FREQUENCY FOR SURVEILLANCE INSTRUMENTATION i

E h

Instrument Channel Calibration Frequency Instrument Check

~

{

18) Drywell High Range Radiation Monitors Once/ operating cycle **

Once/ month l 19, Main Stack High Range Once/elghteen months Once/ month Radiation Monitor l 20) Reactor 81dg. Roof Vent Once/elghteen months Once/ month High Range Radiation Monitor

21) Drywell Hydrogen Concentration Quarterly ***

Once/ month Analyzer and Monitor

+

Perform instrument functional check once per operating cycle.

Channel calibration shall consist of an electronic calibration of the channel, not including the detector, for range decades above 10R/hr and a one point calibration check of the detector below 10R/hr with an installed or portable gaama source.

At least a two-point calibration using sample gas.

4 Y

4 5

+

b m.

_________---,_,.--m-_r e-m._s-e-_ee, -

e ss e m

+----se--+

2

- m-..me

-m

_-,_m_m__.

s e

Unit 2 PBAPS

)

3.6.D & 4.6.D BASES Safety and Relief Valves The safety / relief' and safety valves are required to be operable above the pressure (122 psig) at which the core spray system is not designed to deliver full flow. The pressure relief system for each unit at the Peach Bottom APS has been sized to meet two design bases.

First, the total capacity of the safety / relief and the safety valves has been established to meet the overpressure protection criteria of the ASME code.

Second, the distribution of this required capacity between safety / relief valves and safety valves has been set to meet design basis 4.4.4.1 of subsection 4.4 of the FSAR which states that the nuclear system safety / relief valves shall prevent opening of the safety valves during normal i

plant isolations and load rejections.

i The details of the analysis which show compliance with the ASME code requirements is presented in subsection 4.4 of the FSAR and the Reactor Vessel Overpressure Protection Summary Technical Report j

presented in Appendix K of the FSAR.

l Eleven safety / relief valves and two safety valves have been installed on Peach Bottom Unit 3 with a total capacity of 79.51% of rated steam flow. The analysis of the worst overpressure transient demonstrates margin to the code allowable overpressure limit of 1375 psig.

To meet the power generation design basis, the total pressure relief system capacity of 79.51% has been divided into 65.96%

safety / relief (11 valves) and 13.55% safety (2 valves).

The analysis of the plant isolation transient shows that the 11 safety / relief valves limit pressure at the safety valves below the setting of the safety valves.

Therefore, the safety valves will not open.

Experience in safety / relief and safety valve operation shows that l a testing of 50 per cent of the valves per cycle is adequate to detect failure or deteriorations.

The safety / relief and safety valves are benchtested every second Amendment No. 22. 25, 26, (g, 70,179

- 157 -

S O

Unit 2 PBAPS l

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE RE00lREMENTS i

3.7.A Primary Containment (Cont'c.)

4.7.A Primary Containment (Cont'd.)

f.

Local leak rate tests (LLRT's) shall be performed on the primary containment testable penetrations and l

isolation valves in l

accordance with Tables 3.7.2, 3.7.3, & 3.7.4 at a pressure

)

of 49.1 psig (except for the main steam isolation valves, see below) per 10CFR50 l

Appendix J requirements.

l Bolted double-gasketed seals shall be tested whenever the l

seal is closed after being opened and at least once per operating cycle, not to t

l exceed the requirements of 10CFR50 Appendix J.

The Main Steamline isolation valves shall be tested at a l

pressure of 25 psig for leakage during each refueling outage, but in no case exceeding the requirements of 10CFR50 Appendix J.

If a total leakage rate of 11.5 scf/hr for any one main steamline isolation valve is exceeded, repairs and retest shall be performed to correct

,the condition.

i g.

C$ntinuous Leak Rate Monitor When the primary containment i

is inerted, the containment shall be continuously monitored for gross leakage by review of the inerting system makeup requirements.

This monitoring system may be taken out of service for maintenance but shall be returned to service as soon as practicable.

Amendment No.16(,179

-169-

Unit 2 PBAPS LIMITING CONDITIONS FOR OPERATION SURVEILUWICE REQUIREMENTS 3.7.A Primary Containment (Cont'd.)

4.7.A Primary Contairment (Cont'd.)

3.

Pressure Suppression Chamber-

h. Drywell Surfaces Reactor Buildino Vacuum Breakers The interior surfaces of the drywell and torus shall be visually a.

Except as specified in 3.7.A.3.b inspected each operating cycle below, two pressure suppression for evidence of deterioration.

In chamber-reactor building vacuum addition, the external surfaces of breakers shall be operable at the torus below the water level all times when primary contain-shall be inspected on a routine ment integrity is required.

basis for evidence of torus The setpoint of the differential corrosion or leakage.

pressure instrumentation which actuates the pressure suppression

3. Pressure Suopression Chamber-chamber-reactor building vacuum Reactor Building Vacuum Breakers breakers shall be 0.5 + 0.25 psid.

I a.

The pressure suppression chamber-b.

From and after the date that one reactor building vacuum breakers of the pressure suppression chamber-shall be checked for proper operation l

reactor building vacuum breakers every refueling outage. Associated is made or found to be inoperable instrumentation including setpoint for any reason, reactor operation shall be checked for proper is permissible only during the operation'every eighteen months.

succeeding seven days unless such vacuum breaker is sooner made opera--

4. Drywell-Pressure Suppression-l ble provided that the repair proce-Chenber Vacuus Breakers dure does not violate primary

a. Each drywell-suppression chamber containment integrity.

vaccuum breaker shall be exercised through an opening-4.

Drywell-Pressure Suppression closing cycle once a month.

Chamber vacuum Breakers

b. When it is determined that a.

When primary contairment is a vacuum breaker is inoperable required, all drywell-suppression for opening at a time chamber vacuum breakers shall when operability is required, be operable anc positioned all other operable vacuum breakers in the fully c~osed position shall be exercised immediately i

(except during testing) except and every 15 days thereafter l

as specified in 3.7.A.4.b and until the inoperable c below.

Vacuum breaker has been returned to normal service, b.

Drywell-suppression chamber vacuum breaker (s) ray be

c. Once per operating cycle "not fully seated" as each vacuum breaker shall shown by position indication be visually inspected if testing confirms that the bypass area is less than or equivalent to a one-inch diameter hole. Testing shall be initiated withing 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months of initial detection of a i

J "not fully seated" position Amendment No. 24.127, Igd.179

-170-

l a e

PBAPS Unit 2 LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.

If any reactor instrumentation 3.

At least once per operating line excess flow check cycle the operability of valve is inoperable, within the reactor coolent system 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months either:

instrument line flow check valves shall be strified.

a. Restore the inoperable excess flow check valve to operable status or,

b. Isolate the instrument line and declare the associated instrument inoperable.

c. Otherwise be in at least Hot Shutdown.ithin the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in Cold l

Shutdown within the following 24 nours.

3.7.E Large Primary Containment 4.7.E Large Primary Containment Purge / Vent Isolation Valves Purge / Vent Isolation Valves 1.

The large primary containment 1.

The inflatable seals for purge / vent isolation valves the large containment venti-(6 and 18 inches) shall be lation isolation valves operated in accoroance with shall be replaced at specification 3.7.0 and with least once every second I

specifications 3.7.E.2 and refueling outage.

3.7.E.3 below.

2.

When the reactor pressure is 2.

The LLRT leak rate for greater than 100 psig, and the large containment the reactor critical, ventilation isolation and the reactor mode valves shall be compared to switch in the "Startup" or the previously measured leak "Run" mode. primary contain-rate to detect excessive ment purging or venting shall valve degradation.

be subject to the following restrictions:

l

a. The large primary containment purge / vent isolation valves may De opened Only for inerting, de-inerting, and pressure control.

b. The accumulated time a purge or vent flow patn exists shall be limited to 90 hours0.00104 days 0.025 hours 1.488095e-4 weeks 3.4245e-5 months per calendar year.

Amendment No. Idd, 179

~

~ _..

Unit 2 I

PBAPS r

l NOTES FOR TABLES 3.7.2 THROUGH 3.7.4 (1)

Minimum test duration for all valves and penetrations listed is one hour.

(2)

Test pressures of at least 49.1 psig for all valves and penetrations except MSIV's which are tested at 25 psig.

(3)

MSIV's acceptable leakage is 11.5 scfh/ valve of air.

(4)

The total acceptable leakage for all valves and penetrations other than the MSIV's is 0.60 La.

i (5)

Local leak tests on all testable isolation valves shall be performed per 10CFR50, Appendix J requirements.

l (6)

Local leak tests on all testable penetrations shall be l

performed per 10CFR50, Appendix J requirements.

(7)

Personnel Air Locks shall be tested at 6-month intervals.

1 (8)

The personnel air locks are tested at 49.1 psig.

(9)

Identifies isolation valves that may be tested by applying pressure between the inboard and outboard valves.

(10) Gate valves are tested in reverse direction.

Test acceptable since the normal force between the seat and the disc generated by stem action alone is greater than ten (10) times the normal force induced by test differential pressure except for valves MO-10-31A,B which is 7.97.

This applies to the following valves:

i l

l l

l MO-2-74 MO-10-31A, B MO-13-15 MO-10-18 MO-23-15 MO-12-15 (Unit #2)

MO-10-32 (Unit #2) 1

-188-Amendment No. 30, If4,179 l

l 4

Unit 2 PBAPS 3.7.A & 4.7.A BASES (Cont'd.)

The design basis loss-of-coolant accident was evaluated at the primary containment maximum allowable accident leak rate of 0.5t/ day at 56 psig.

Calculations made by the AEC staff with leak rate and a standby gas treatment system filter efficiency of 90%

for halogens and assuming the fission product release fractions stated in TID 14844, show that the maximum total whole body passing cloud dose is about 1.0 REM and the maximum total thyroid dose is about 14 REM at. 4500 meters from the stack over an exposure duration of two hours.

The resultant doses that would occur for the duration of the accident at the low population zone distance of 7300 meters are about 2.5 REM total whole body and 105 REM total thyroid.

Thus, the doses reported are the maximum that would be expected in the unlikely event of a design basis loss-of-coolant accident.-

These doses are also based on the assumption of no holdup in the secondary containment resulting in a direct release of fission products from the primary containment through the filters and stack to the environs.

Therefore, the specified primary containment leak rate and filter efficiency are conservative and provide margin between expected off-site doses and 10 CFR 100 guidelines.

The water in the suppression chamber is used only for cooling in the event of an accident; i.e.,

it is not used for normal operation; therefore, a daily check of the temperature and volume is adequate to assure that adequate heat removal capability is present.

Drywell Interior The interiors of the drywell and suppression chamber are painted to prevent - rusting.

The inspection of the paint during each major refueling ontage, assures the paint is intact.

Experience with this type of paint at fossil fueled generating stations indicates that the inspection interval is adequate.

Post LOCA Atmosphere Dilution In order to ensure that the containment atmosphere remains inerted, i.e. the oxygen-hydrogen mixture below the flammable limit, the capability to inject nitrogen into the containment af ter a LOCA is provided.

During the first year of operation the normal inerting nitrogen makeup system will be available for this purpose.

After that time the specifically designed CAD system will serve as the post-LOCA Containment Atmosphere Dilution System.

By maintaining a minimum of 2000 gallons of liquid N, in the storage tank it is assured that a seven-day supply of N, for post-LOCA containment inerting is available.

Since the inerting makeup system is continually functioning, no Amendment No. !!2.179

- 193 -

=_

Unit 2 PEAPS LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREENTS and one main sta a shall also demonstrate that noble gas monitor control room alars an-shall be operable and set nunciation occurs if any of to alarm in accordance the following conditions exist:

with the methodology 1.

Instrument indicates and parameters in the measured levels ODCM. From and after the above the alars date that both reactor setpoint.

building exhaust vent 2.

Instrument indicates monitors or both main a downscale failure.

stack not,le gas monitor.s Additionally, an instrument are made or found to be check shall be performed inoperable for any reason, every day.

effluent releases via 4b.

The reactor building

]

their respective pathway exhaust vent and the may continue provided at main stack flow rate least two independent monitors shall be grab samples are taken calibrated every 12 at least once per 8 hrs.

months. Additionally, an and these samples are instrument check shall analyzed for gross be performed every day.

activity within 24 4c.

The reactor building hours, and at least two exhaust vent and the main technically qualified stack iodine and particulate members of the facility sample flow rate monitors staff independently shall be calibrated every verify the release 12 months. Additionally, rate calculations.

an instrument check shall c.

One reactor building be performed every day exhaust vent iocine for the reactor building filter and one main exhaust vent sample flow stack iodine filter rate monitors, and every and one reactor build-week for the main stack l

ing exhaust vent sample flow rate monitor.

particulate filter 4d.

The main stack sample and one main stack flow line M1/Lo pressure i

particulate filter with switches shall be their respective flow functionally tested every rate monitors shall be 6 months and calibrated operable. From and after every 24 months.

the date that all lodine filters or all particulate filters for either the reactor building exhaust vent monitor or the main stack monitor are made or found to be inoperable for any reason, effluent releases via their respective pathway may Amendment No. 102. IZ5,179

-211-i nn,,

,.-.a,,

-ne, w-

-~

u-...

~

t Unit 2 PBAPS LIMITING CONDITION 5 FOR OPERATION SURVEILLANCE REQUIREMENTS I

3.9 AUXILIARY ELECTklCAL SYSTEM 4.9 AUXILIARY ELECTRICAL SYSTEM l

Applicability:

Applicability Applies to the auxiliary Applies to the periodic electrical power system.

testing requirements of the auxiliary electrical Objective:

systems.

To assure an adequate Objective:

supply of electrical power for operation of those Verify the op ' ability systems required for safety.

of the auxiliary electrical system.

Specification:

A.

Auxiliary Electrical A.

Auxiliary Electrical 1

Equipment Equipment The reactor <4 hall not be made 1.

Diesel Generators and critical unless all of the following Offsite Circuits conditions are satisfied:

1.

Two physically independent 1.

Each of the required circuits between the offsite independent circuits j

transmission network and between the offsite the onsite Class IE transmission network and I

distribution system are operable.

the onsite Class 1E distribution system 2.

The four diesel generators shall be shall be:

operable and there shall be a siminum of 108,000 gallons of diesel fuel a.

Verified OPERABLE on site.

Each operable diesel at least once per I

generator shall have:

7 days by verifying correct breaker a.

A separate day tank alignments and containing a minimum indicated power of 200 gallons of fuel, availability.

b.

A separate fuel storage taan with a minimum of 28,000 gallons of fuel, b.

Demonstrated OPERABLE and at least once per 24 months l

c.

A separate fuel transfer by transferring, pomp.

manually and automatically, the 3.

The unit 4kV emergency buses start-up source and the 480V emergency from the normal loao aenters are energized.

circuit to the alternate circuit.

4 The four unit 125V batteries and tneir chargers shall be operable.

Amendment No. IH, 173,179

-217-

e l

Unit 2 PBAPS i

LIMITING CONDITION FOR OPERATION SURVEILLANCE REQUIREMENTS 1

4.9.A.I.2 (Continued) e.

At least once every 31 days by obtaining a sample of fuel oil from the storage tank in accordance with ASTM D2276-78, and verifying that total particulate contamination is less than 10mg/ liter when checked in accordance with ASTM D2276-78, Method A, except that the filters i

specified in ASTM D2276-78, Sections 5.1.6 and 5.1.7, may have a nominal pore size of up to three (3) microns.

f.

At least once per 18 months by:

1 1.

Subjecting the diesel to an inspection in accordance with procedures prepared in l

conjunction with its manufacturer's recommendations for this class of standby service.

g.

At least once per 24 months by:

1.

Verifying the diesel generator l

capability to reject a load of l

greater than or equal to that of the RHR Pump Motor for each diesel generator while maintaining voltage within 4160 410 volts and frequency at 60 t 1.2hz.

2.

Verifying the diesel generator l

capability to reject an indicated load of 2400 kW-2600 Kw without tripping. The generator voltage shall not exceed the initial value (4160 410 volts) by more than 660 volts l

during and following the load rejection.

Amendment No. 173.179

-218d-

e Unit 2 PBAPS LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 4.9.A.I.2.g (Continued)

3. Verifying that all automatic diesel generator trips except engine overspeed, generator differential over-current, generator ground overcurrent and manual cardox initiation are automatically bypassed upon an ECCS actuation signal.

4.Verifyingthedieselgenerator operates for at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . During the first 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of this test, the diesel generatorshallbeloagedtoan indicated 2800-3000 kW and during the remaining 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months of this test, the diesel generator j

shallbeloagedtoanindicated 2400-2600 kW.

1 1

5. Verifying diesel generator capability at full load temperature within 5 minutes after completing the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months e

test by starting and loading the diesel as described

{

in Surveillance Requirement 4.9.A.1.2.bandoperatjngfor greater than 5 minutes.

aThis test shall ot: conducted in accordance with the manufacturer's recommendatio regarding engine prelube and warm-up and, as applicable, loading and shutdown.

bThis band is meant as guidance to avoid routine overloading of the engine.

Loads in excess of this band for special testing, under direct monitoring by the manufacturer or system engineer, or momentary variations due to changing bus loads shaii not invalidate the test.

C If Surveillance keoutrement 4.9.A.I.2.g.5 is not satisfactorily completed, it is not I

necessary to repeat the preceding 24-hour test.

Instead, the diesel generator may be operated at 2400-2600 kW for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or until operating temperature has stabilized prior to performing Surveillance Requirement 4.9.A.1.2.g.5.

dPerformance of Surveillance Requirement 4.9.A.1.2.g.5 will not be used to satisfy the I requirements of Surveillance Requirement 4.9.A.1.2.b.

Amendment No. 173,179

-218e-

= - -

.-o

...a m

~w.

w

-u.

.+. -

.s t

l*

Unit

l PBAPS l

LIMITING CONDITIONS FOR OPERATIV SURVEILLANCE REQUIREMENTS

{

l 4.9.A.1.2 (Continued)

{

6. Verifying that the fuel. transfer i

pump transfers fuel from each fuel storage tank to the day tank of each diesel via the installed l

cross connection lines.

h.

At least once each operating-

[

cycle by:

1. Simulating a loss-of-offsite power by itself, and.

a) Verifying deenergization of I

the emergency busses and load shedding from the emergency busses.

i b) Verifyingthedigsel generator starts on the auto-start signal, energizes l

the emergency busses within 10 seconds, energizes the permanent and auto-connected i

loads through the individual load timers and operates for greater than or equal to 5 minutes.

i After energization, the steady-state voltage and I

frequency of the emergency l

busses shal1~be maintained at 4160 + 410 volts and 60 + 1.2

~

Hz during this test.

l aThis test shall be conducted in accordance with the manuf&ct'urer's recommendatio regarding engine prelube and warm-up and, as applicable, loading and shutdown.

l i

i Amendment No. Z73,179 218f-

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

~

PBAPS LIMITING CONDITIONS FOR OPERATI0N SURVEILLANCE REQUIRENENTS 4.9.A.1.2 (Continued) 4.

Verifying the diesel generator's capability to:

a)

Synchronize with the offsite power source while the generator is loaded with its emergency loads upon a simulated restoration of offsite power.

b)

Transfer its loads to the offsite power source, and c)

Be restored to its standby status.

~

1.

At least once per 10 years or l

after any modifications which could affect diesel generator interdependence by starting

all four diesel generators simultaneously and verifying that all four diesel generators accelerate to.at least 855 rpm in less than or equal to 10 seconds.

J.

At least once per 10 years by l

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

k.

The fuel oil. storage tank cathodic prottetion system shall be checked as follows:

1.

At least once every twelve months perform a test to determine whether the cathodic protection is adequate, and

'This test shall be conducted in accordance with the manufacturer's recommendations regarding engine prelube and warsup and, as applicable, loading and shutdown.

' Amendment No. 173, 179

-218h-

O

-4 Unit 2 PBAPS LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 4.9.A.I.2 (Continued) 2.

At least once every two months inspect the cathodic protection rectifiers.

1.

If the number of failures during l

the last 20 valid demandsd is less than or equal to 1, the test i

frequency shall be at least once per 31 days.

If the number of failures during the last 20 valid demands is greater than or equal to 2, the test frequency shall be at least once per 7 days'.

m.

All diesel generator failures, valid or non-valid, shall be reported to the Comission in a Special Report within 30 days.

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

8 Criteria for determining the number of failures and number of valid demands shall be in accordance with Regulatory Position C.2.e of Regulatory Guide 1.108, but determined on a per diesel generator basis.

'The associated test frequency shall be maintained until seven consecutive failure free demands have been performed add the number of failures in the last 20 demands have been reduced to one.

For the purposes of determining the required frequency, the previous test failure count may be reduced to zero if a complete diesel overhaul to like-new condition is completed. This diesel overhaul, including appropriate post-maintenance operation and testing, shall be specifically approved by the manufacturer and acceptable diesel reliability must be demonstrated. The reliability criterion shall be the successful completion of 14 consecutive tests. Ten of these tests may be slow starts in accordance with Surveillance Requirements 4.9.A.I.2.a.3 and 4.9 A.1.2.a.4 and four tests shall be fast starts in accordance with the Surveillance Requirement 4.9.A.I.2.b.

If this j

criterion is not satisfied during the first series of tests, any alternate criterion to be used to reset the valid failure count to zero requires NRC approval.

Amendment No. Z73,179

-218i-

o o

Unit 2 l

PBAPS LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS I

i r

4.9.A.2 Unit Batteries a.

Every week the specific gravity, the voltage and temperature of the pilot cell and overall battery voltage shall be measured and logged.

b.

Every three months the measurements shall be made of i

l voltage of each cell to nearest 0.1 Volt, specific gravity of each cell, and temperature of every fifth cell.

These measurements shall be logged.

c.

The station batteries shall be subjected to a perfomance test every second refueling outage and a service test during the l

other refueling outage.

In lieu of the perfomance test every second refueling outage, any l

battery that shows " signs of l

degradation or has reached 85%

of its service life" shall be subjected to an annual perfomance test. The service test need not be performed on j

the refueling outage during j

which the perfomance test was conducted. The specific gravity

)

and voltage of each cell shall be determined after the discharge and logged.

4.9.A.3 Swing Buses a.

Every two months the swing buses supplying power to the Low Pressure Coolant Injection System (LPCIS) valves shall be tested to assure that the transfer circuits operate as designed.

-218j-Amendment No. ///,179 i

ne.

j Unit 2 is LIMITING CONDIT!0ws FOR OPERATION SURVEILLANCE REQUIREMENTS 5

4.11.0.3 1

i Visual inspection of snubbers required to j

be operable under the provisions of 3.11.D.1 shall verify that 1) there are i

i no indications of damage or impaired l

operability, 2) attachments to the i

foundations or supporting structure are j

functional, and 3) fasteners for the attachment of the snubber to the l'

cogonent and to the snubber anchorage are functional.

Snubbers which appear to be inoperable as a result of visual inspections shall be l

classified as unacceptable and may be j

reclassified acceptable for the purpose of establishing the next visual i

inspection interval, providing that 1)

}

the cause of the re,jection is clearly established and remedied for that I

particular snubber and for other generically susceptible snubbers; and 2) the affected snubber is functionally i

tested in the as found condition and 1

determined operable per Specification 4.11.D.7 or 4.11.0.6, as applicable. All j

snubbers found connected to an inoperable a

{

common hydraulic fluid reservoir shall be j

counted as unacceptable for detersining the next inspection interval. A review 1

i and evaluation shall be performed and documented to justify continued operation with an unacceptable snubber. If l

continued operation cannot be justified.

the snubber shall be declared inoperable and the Limiting Conditions for Operation i

shall be met.

I 1

3 4.11.0.4 Functional Test

a) Once each operating cycle, during j

shutdown, a representative sample of 101

)

of each type of (sechanical or hydraulic) l snubber required to be operable under the i

provisions of 3.11.0.1 shall be j

functionally tested either in place or in 1

a bench test.

For every unit found to be inoperable an additional 105 of that type of starbber shall be functionally l

Performance of 4.11.D.4(a) with an tested until no eDre failures are found j

operating cycl 2 of 732 days is or all snubbers of that type have been approved for the operating cycle tested. The functional test regstrements j

following refueling outage 2R010 for mechanical l

only.

2346 hierdmera..No. Yet, te7.uit,179-

Unit 2 PBAPS LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS l

l 3.14.D Fire Barriers 4.14.D Fire Barriers

1. Fire barriers (including

1. Fire barriers required walls, floor, ceilings, electrical to meet the provisions cable enclosures, cable, piping and of 3.14.D.1 (fire doors ventilation duct penetration excluded - see speci-seals, fire doors, and fire fication 4.14.D.2) shall dampers) which protect be verified operable safety related systems following maintenance required to ensure safe or modifications, and by per-shutdown capability in the forming the following visual event of a fire, shall be inspection:

functional.

a. The exposed surface of each fire barrier wall, floor, and ceiling, shall be inspected

2. If the requirements of at least once per 24 months.

l 3.14.D.1 cannot be met, Exposed surfaces are within one hour establish a those surfaces that can continuous fire watch on at be viewpd by the inspector least one side of the from the floor.

affected fire barrier, or verify the operability of

b. Each fire damper and electrical fire detectors on at least cable enclosure shall be inspected one side of the inoperable at least once per fire barrier and establish 18 months.

an hourly fire watch patrol.

Reactor startup and continued

c. Once per 24 months at least reactor operation is 12.5 percent of each type of permissible.

fire barrier penetration seal (including electrical cable, piping, ventilation duct l

penetration seals, and excluding internal conduit seals) such that each penetration seal will be inspected at least once per 16 years.

l Difficult-to-view fire barrier (unexposed) walls, and ceilings that are rendered accessible by the penetration seal inspection program shall also be inspected during each 12.5 l

percent inspection.

l l

240j(1)

Amendment No. 39, SJ, 93, II9,179

PBAP5 LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 4.14.D Fire Barriers (Cont'd)

1. (Continued)

If any penetration seal selected for inspection is found by surveillance requirements 4.14.D.l(c) in a condition which may compromise the operability of the penetration seal, the cause shall be evaluated.

If the cause is a failure to adhere to penetration seal procedures, or i

an identified phenomenon (e.g.,

l physical interference), the cause shall be corrected and potentially affected seals inspected. Otherwise, a visual inspection of an additional

'12.5 percent, selection based l

on the nature of the degradation, shall be made.

This inspection process shall continue until a 12.5 percent l

sample with no degradation is found.

2. Fire doors required to meet tne provisions of 3.14.0.1 i

shall be verified operable by inspecting the closing mechanism and latches every 6 months *, and by verifying:

l l

a.

The operability of the fire door supervision system for each electrically supervised fire door by performing a functional test every month, b.

That each locked-closed fire door is in the closed position every week.

c.

That each unlocked fire door without electrical l

supervision is in the

'4 closed position every day.

Fire door inspections requiring access to radiation areas may be deferred until the next refueling outage or shutdown initially expected to be of at least a 7-day duration.

l Amendment No. 29. 85. 98.

240j(2) l IIf.179

t s

e i

Unit 2 Table 4.15*

SEISMIC MONITORING INSTRUMENTATION SURVEIT TA_NCE REOUIREidnis Ipatrument*

Instrument

Functional Instrument Check Test Calibration Instruments and Sensor Locations #

1.

Triaxal Time-History Accelerographs a.

Containment Foundation (torus compartment)

M SA R

b.

Refueling Floor M

SA R

c.

RCIC Pump (Rm #7)

M SA R

d.

"C" Diesel Generator M

SA R

i 2.

Triaxal Peak Accelerographs l

a.

Reactor Piping (Drywell)

NA NA R

b.

Refueling Floor MA NA R

c.

"C" Diesel Generator NA NA R

j 3.

Triaxal Response-Spectrum Recorders a.

Cable Spreading Rm M

SA R

Surveillance Frecuencias M:

every month SA:

every 6 months l

l R:

every 24 months Effective upon completion of installation.

Seismic instrumentation located in Unit 2.

l Amendment No. 75. 85, 179

-240v-

/pa ata

'o UNITED STATES

~g

[

w g

NUCLEAR REGULATORY COMMISSION e

W ASWNGTON. D. C. 20555 a

/

%,.....f PHILADELPHIA ELECTRIC COMPANY PUBLIC SERVICE ELECTRIC AND GAS COMPANY DELMARVA POWER AND LIGHT COMPANY ATLANTIC CITY ELECTRIC COMPANY DOCKET NO. 50-278 PEACH BOTTOM ATOMIC F0WER STATION. UNIT NO. 3 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.182 i

License No. DPR-56 j

1.

The Nuclear Regulatory Comission (the Comission) has found that:

A.

The application for amendment by Philadelphia Electric Company, et.

i al. (the licensee) dated September 28, 1992 and October 19, 1992, as supplemented by letters dated March 16, 1993, April 13, 1993, May 28, 1993, June 7, 1993, June 23, 1993, July 1, 1993 and July 7, 1993, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Comission's rules and regulations set forth in 10 CFR Chapter I.

i B.

The facility will operate in conformity with the application, the i

provisions of the Act, and the rules and regulations of the Comission; C.

There is reasonable assurance (1) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Comission's regulations; D.

The issuance of this amendment will not be inimical to the comon defense and security or to the health or safety of the public; and l

E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of i

the Comission's regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C(2) of Facility Operating License No. DPR-56 is hereby amended to read as follows:

1

l i

l (2) Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No.182, are hereby incorporated in the license.

PECO shall operate the facility in accordance with the l

Technical Specifications.

3.

This license amendment is effective as of August 2,1993.

FOR THE NUCLEAR REGULATORY COMMISSION Michael L. Boyl, Acting Director Project Directorate I-2 i

Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation l

Attachment-i l

Changes to the Technical Specifications Date of Issuance: August 2, 1993 l

l

ATTACHMENT TO LICENSE AMENDMENT NO.182 i

FACILITY OPERATING LICENSE NO. DPR-56 DOCKET NO. 50-278 Replace the following pages of the Appendix A Technical Specifications with the enclosed pages.

The revised areas are indicated by marginal lines.

l Remove Insert 5

5 6

6 8

8 44 44 Bla 81a 86a 86a l

l 157 157 i

169 169 170 170 l

178 178 l

188 188 193 193 211 211 217 217 218d 218d 218e 218e l

218f 218f 218h 218h 2181 2181 l

218j 218j f

234b 234b 240j(1) 240j(1) 240j(2) 240j(2) 240v 240v

)

PBAPS 1.0 ETTINITICNS (Cont'd) l of f site Dos e Calculation Manual - Contains the current l

methodology and parameters used in the calculation of of fsite doses due to radioactive gaseous and liauid effluents and describes the environmental radiological monitoring program.

OPERABLE - OPERABILITY - A system, subsystem, train, component, or device is CPERABLE or has OPERABILITY when it is capable of performing its specified function and all instrumentation, controls, normal and emergency electrical power sources, cooling or seal water supplies, lubrication systems, and other auxiliary equipment that are reauired for the system, subsystem, train, component, or device to perform its function are also capable of 1

performini; their related support function.

Oeeratine - Operating means that a system or component,is perf orming its intended functierts in its recuired manner.

0eeratine Cvele - Interval between the and of one refueling outage for a particular unit and the end of the next subsecuent efueling outage for the same unit.

Primary Containment Inteerity - Primary containment integrity means :na: :ne crywell ano pressure suppressica chamber are intact and all of the f ollowing c=nditions are satisfied:

1.

All primary containment penetrations reepired to be closed during accident conditions are sicher:

a)

Capable of being closed by an OPE 3ABLE centainment automatic isolation valve system, or

~

b)

Closed by at least one manual valve, blind flange, or deactivated automatic valve secured in its closed i

position, except as may be provided in Specifications

3. 7.D. 2 and 4. 7.D. 2.

Manual valves may be opened to i

perterm necessary cperaticnal activities.

2.

At least one door in each airicek is closed and sealed.

3.

All blind f1anges and manways are closed.

See the term "Once Per Cycle" under the Definition of " Surveillance Frequency" for specific time liriits on surveillances with a frequency that includes the

' term " Operating Cycle."

Amendment No. W, 182.

G

,,m.,

7

_-r-

,w-

.swa

-w---------

e e

PBAPS 1.0 DEFINITIONS (Cent'd)

Protective Action - An action initiated by the protection system when a limit is reached.

A protective action can be at a channel or system level.

Protective Function - A system protective action which results from the protective actics of the channels acnitoring a particular plant condition.

Purae - Pureine - Purge or Purging is the controlled process of discharging air or gas from a confinement to maintain temperature, pressure, humidity, concentration or other operating conditica, in such a manner that replacement air or gas is recuired to purify the confinement.

Rated Power - Rated power refers to operation at a reactor power of 3,293 MWtr this is also termed 100 percent power and is the maximum power level authorized by the operati ng license.

Rated i

steam flow, rated coolant flow, rated neutron flux, and rated nuclear system pressure ref er to the values of these parameters when the reactor is at rated power.

Reactor Power Oeeration - Reactor power operation is any operation with the mode switch in the "Startup" or "Run" position with the reactor critical and above 14 rated power.

i Reactor Vessel Pressure - Unless otherwise indicated, reactor vessel pressuree listed in the Technical specifications are those measured by the reactor vessel steam space detectors.

Refuel Mode - With the mode switch in the refuel position, the reactor is shutdown and interlocks are established so that on.ly one control rod may be withdrawn.

s

Refueline Outace - Refueling outage is the period of time between the shutdown of the unit prior to a refueling and the startup of the unit af ter that refueling.

For the purpose 'of desiernatine frecuency of testing and surveillance, a refueling outage shall mean a regularly scheduled outage however, where such outages occur within 8 months of the completion of the previous refueline

See the term " Refuel" under the Definition of " Surveillance Frequency" for specific time limits on surveillances with a frequency that includes the term

" Refueling..OutaRe. "

h wndment No. Idl. 182 _...

2 Unit 3 1.0 DEFINITIONS (Cont'd) i Simulated Automatic Actuation - Simulated automatic actuation means applying a simulated j

signal to the sensor to actuate the circuit in question.

l

}

Site Boundary - That line beyond which the land is not owned, leased or otherwise controlled by licensee.

Source Check - A source check shall be the qualitative assessment of channel response when the channel sensor is exposed to a radioactive source.

i

{

Startup/ Hot Standby Mode - In this mode the reactor protection scram trips, initiated by I

condenser low vacuum and main steam line isolation valve closure are bypassed, the reactor protection system is energized with IRM neutron monitoring system trip, the APRM 15% high flux trip, and control rod withdrawal interlocks in service. This is often referred to as just Startup Mode. This is intended to imply the Startup/ Hot Standby i

position of the mode switch.

Surveillance Frequency - Periodic surveillance tests, checks. calibrations, and i

examinations shall be performed within the specified surveillance intervals. Specified j

periodic surveillance intervals are defined as:

1 j

(N) Hours Atleastonceper(N) hours i

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

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

(N) Days Atleastonceper(N) days

]

Twice Per Week At least once per 4 days Weekly At least once per 7 days j

(N) Weeks At least once per (7sN) days Semi monthly At least once per 15 days i

Monthly At least once per 31 days i

2 Month At least once per 61 days Quarterly or 3 month At least once per 92 days i

Semi-annually or 6 month At least once per 184 days

}

Annually or 12 month At least once per 366 days i

I Once Per Cycle At least once oer 732 days 18 month At least once per 550 days j

l Refuel At least once per 732 days j

(N) Years At least once per 366xN) days l

(N) Refuel Cycle At least once per 732xN) days l

24 Months At least once per 732 days These specified time intervals may be exceeded by 255. Surveillance tests are not required on systems or parts of the systems that are not required to be operable or are

{

tripped.

If tests are missed on parts not required to be operable or are tripped, then j

they shall be performed prior to returning the system to an operable status.

]

A surveillance test of the diesel generators, that requires a plant outage, may be deferred beyond the calculated due date until the next refueling outage, provided the i

equipment has been similarly tested and meets the surveillance requirement for the other unit.

Transition Boiling - Transition boiling means the boiling regime between nucleste and 4

i film boiling. Transition boiling is the regime in which both nucleate and film boiling

}

occur intermittently with neither type being completely stable.

Trip System - A trip system means an arrangement of instrument channel trip signals and

]

auxiliary equipment required to initiate Amendment No. IN, 121, 136, 170,

--S--

~

Unit 3 TABLE 4.1.2 REACTOR PROTECTION SYSTEM (SCRAM) INSTRUMENT CALIBRATION MINIMUM CALIBRATION FREQUENCIES FOR REACTOR PROTECTION INSTRUMENT CHANNELS 1

i Instrument Channel Group (1)

Calibration (4)

Minimum Frequency (2)

I IRM High Flux C

Comparison to APRM on Maximum frequency once Controlled Shutdown per week.

APRM High Flux Output Signal B1 Heat Balance Twice per week.

~;

l Flow Bias Signal B1 With Standard Pressure Every eighteen months.

Source LPRM Signal B1 TIP System Traverse Every 6 weeks.

k High Reactor Pressure B2 Standard Pressure Source Once per operating cycle.

i t

High Drywell Pressure B2 Standard Pressure Source Once per operating cycle.

Reactor low Water Level B2 Pressure Standard Once per operating cycle.

High Water Level in Scram A

Water Column Every refueling outage.

}

E Discharge Instrument Volume f

Turbine Condenser Low Vacuum B2 Standard Vacuus Source Once per operating g

cycle.

l&

Main Steam Line Isolation Valve A

Note (5)

Closure f.-

Main Steam Line High Radiation B1 Standard Current Source (3)

Every 3 months.

3 Turbine First State Pressure A

Standard Pressure Source Every 6 months.

l 'g Pemissive w

1 r

m-,

i e

Unit 3 TABLE 4.2.B (CONTINUED)

MINIMUM TEST AND CAllBRATION FREQUENCY FOR CSCS Instrument Channel Instrument Functional lest Calibration frequency Instrument Check i

13) HPCI and RCIC (1)

Once/3 months None Steam Line Low Pressure

14) HPCI Suction Source (1)

Once/3 months None Levels

15) 4KV Emergency Power Once/ operating cycle Once/5 years None System Voltage Relays (HGA,SV)

)

4,

16) ADS Relief Valves Once/ operating cycle Once/ operating cycle None y

Bellows Pressure Switches

17) LPCI/ Cross Connect Once/ refueling cycle N/A N/A Valve Position

18) Condensate Storage Once/3 months Once/ operating cycle Once/ day Tank Level k

(RCIC) (7) o(

l

19) 4KV Emergency Power Once/ month Once/elghteen months None o

Source Degraded Voltage Relays (IAV CV-6,ITE)

Od y-up N

t'

- _. ~., - _. -

Unit 3 TABLE 4.2.F MINIMIM TEST AND CALIBRATION FREQUENCY FOR SURVEILLANCE INSTRUMENTATION Instrument Channel Calibration Frequency Instrument Check l18)

Drywell High Range Radiation Monitors Once/ operating cycle **

Once/ month l19) Main Stack High Range Once/ eighteen months once/ month Radiation Monitor

.l 20)

Reactor Bldg. Roof Vent Once/ eighteen months Once/ month High Range Radiation Monitor

21) Drywell Hydrogen Concentration Quarterly ***

Once/ month Analyzer and Monitor is iE i'

Perform instrument functional check once per operating cycle.

Channel calibration shall consist of an electronic calibration of the l

channel, not including the detector, for range decades above 10R/hr and a one point calibration check of the detector below 10R/hr with j

an-installed or portable gamma source.

At least a two-point calibration using sample gas.

i.iF r

y

~ CD 4

4 4

m.-

m

t i

l

}

l Unit 3 i

PBAPS j

3.6.D & 4.6.D BASES 1

i Safety and Relief _ Valves I

The safety / relief and safety valves are required to be operable i

above the pressure (122 psig) at which the. core spray system is not designed to deliver full flow. The pressure relief system for each unit at the Peach Bottom APS has been sized to meet two design bases.

First, the total capacity of the safety / relief and the i

safety valves has been established to meet the overpressure protection criteria of the ASME code.

Second, the distribution of this required capacity between safety / relief valves and safety valves has been set to meet design basis 4.4.4.1 of subsection 4.4 of the FSAR which states that the nuclear system safety / relief i

valves shall prevent opening of the safety valves during normal l

plant isolations and load rejections.

1 l

The details of the analysis which show compliance with the ASME j

code requirements is presented in subsection 4.4 of the FSAR and q

the Reactor Vessel Overpressure Protection Sununary Technical Report presented in Appendix K of the FSAR.

i j

Eleven safety / relief valves and two safety valves have been i

installed on Peach Bottom Unit 3 with a total capacity of 79.51% of rated steam flow. The analysis of the worst overpressure transient demonstrates margin to the code allowable. overpressure limit of i

1375 psig.

2 To meet the power generation design basis, the total pressure relief system capacity of 79.51% has been divided into 65.96%

safety / relief (11 valves) and 13.55% safety (2 valves).

The

/

analysis of the plant isolation transient shows that the 11 safety / relief valves limit pressure at the safety valves below the setting of the safety valves.

Therefore, the safety valves will not opan.

Experience in safety / relief and safety valve opatration shows that l a testing of 50 per cent of the valves per cycle is adequate to detect failure or deteriorations.

The safety / relief and safety valves are benchtested every second

- 157 -

Amendment No. 77, 77, !/)',

42, 62, 79, 182

i Unit 3 PBAPS l

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.7.A Primary Containment (Cont'd.)

4.7.A Primary Containment (Cont'd.)

f.

Local leak rate tests (LLRT's) shall be performed on the primary containment i

testable penetrations and isolation valves in accordance with Tables 3.7.2, 3.7.3, & 3.7.4 at a pressure of 49.1 psig (except for the

[

main steam isolation valves, see below) per 10CFR50 Appendix J requirements.

t Bolted double-gasketed seals shall be tested whenever the j

seal is closed after being opened and at least once per operating cyt.le, not to exceed the nequirements of 10CFR50 Apperdix J.

The Main Steamline isolation valves shall be tested at a pressure of 25 psig for leakage during each refueling outage, but in no case exceeding the requirerInts of 10CFR50 Appendix J.

If a total leakage rate of 11.5 scf/hr for any one main steamline isolation valve is exceeded, repairs and retest shall be performed to correct the condition.

g.

Continuous Leak Rate Monitor When the primary containment l

is inerted, the containment shall be continuously monitored for gross leakage by review of the inerting l

system makeup requirements.

t This monitoring system may be taken out of service for maintenance but shall be returned to service as soon as practicable.

-169-Amendment No.167,182 r

l l

Unit 3

~"

PBAPS LIMITING CONDITIONS FOR OPERATION SURVEftLANCE REQUIREMENTS 3.7.A Primary Containment (Cont'd.)

4.7.A Primary Contairunent (Cont'd.)

3.

Pressure Suppression Chamber-

h. Drywell Surfaces Reactor Building Vacuum Breakers The interior surfaces of the a.

Except as specified in 2.7.A.3.b drywell and torus shall be visually ir.spected each operating cycle below, two pressure suppression for evidence of deterioration.

In chamber-reactor building vacuun addition, the external surfaces of breakers shall be operable at the torus below the water level all times when primary contain-shall be inspected on a routine ment integrity is required.

basis for evidence of torus The setpoint of the differential corrosion or leakage, pressure instrumentation which actuates the pressure suppression

3. Pressure Suppression Chamber-chamber-reactor building vacuum Reactor Building Vacuum Breakers breakers shall be 0.5 + 0.25 psid.

a.

The pressure suppression chamber-b.

From and after tne date that one reactor building vacuum breakers of the pressure suppression chamber-shall be checked for proper operation reactor building vacuum breakers every refueling outage. Associated is made or found to be inoperable instrumentation including setpoint for any reason, reactor operation shall be checked for proper is permissible only during the operation every eighteen months.

succeeding seven days unless such vacuum breaker is sooner made opera-

4. Drywell-Pressure Suppression ble provided that the repair proce-Chamber Vacuus Breakers dure does not violate primary

a. Each drywell-suppression chamber containment integrity, vaccuum breaker shall be exercised through an opening-4.

Drywell-Pressure Suppression closing cycle once a month.

, Chamber Vacuum Breakers

b. When it is determined that a.

When primary containment is a vacuum breaker is inoperable required, all drywell-suppression for opening at a time chamber vacuum breakers shall when operability is required, be operable and positioned all other operable vacuus breakers in the fully closed position shall be exercised immediately (except during testing) except and every 15 days thereafter as specified in 3.7.A.4.b and until the inoperable c below.

vacuum breaker has been returned to normal service.

b.

Drywell-suppression chamber vacuum breaker (s) may be

c. Once per operating cycle "not fully seated" as each vacuum breaker shall shown by position indication be visually inspected if testing confirms that the bypass area is less than or equivalent to a one-inch diameter hole.

Testing shall be initiated witt.ing 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months of initial detection of a "not fully seated" position

-170-

i PBAPS Unit 3 LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREHENTS l

I 3.

If any reactor instrumentation 3.

At least once per operating line excess flow check cycle the operability of valve is inoperable, within the reactor coolant system i

I 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months either:

instrument line flow check

{

valves shall be verified.

a. Restore the inoperable excess flow check valve to operable status or,

b. Isolate the instrument line and declare the associated instrument inoperable.

c. Otherwise 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 .

3.7.E Large Primary Containment 4.7.E Large Primary Containment Purge / Vent Isolation Valves Purge / Vent Isolation Valves 1.

The large primary containment 1.

The inflatable seals for

{

1 purge / vent isolation valves the large containment venti-(6 and 18 inches) shall be lation isolation valves operated in accordance with shall be replaced at specification 3.7.0 and with least once every second specifications 3.7.E.2 and refueling outage.

l 3.7.E.3 below.

l I

2.

When the reactor pressure is 2.

The LLRT leak rate for greater than 100 psig, and the large containment the reactor critical, ventilation isolation and the reactor mode valves shall be compared to switch in the "Startup" or the previously measured leak "Run" mode, primary contain-rate to detect excessive ment purging or venting shall valve degradation.

be subject to the following restrictions:

a. The large pr h rj containment purge / vent isolation valves may be opened only for inerting, de-inerting, and pressure control.

l

b. The accumulated time a purge or vent flow path exists shall be limitad to 90 hours0.00104 days 0.025 hours 1.488095e-4 weeks 3.4245e-5 months per calendar year.

-178_

Amendment No. IM,182 l

l l

l Unit 3 PBAPS NOTES FOR TABLES 3.7.2 THROUGH 3.7.4 (1)

Minimum test duration for all valves and penetrations listed is one hour.

(2)

Test pressures of at least 49.1 psig for all valves and penetrations except MSIV's which are tested at 25 psig.

(3)

MSIV's acceptable leakage is 11.5 scfh/ valve of air.

(4)

The total acceptable leakage for all valves and penetrations other than the MSIV's is 0.60 La.

(5)

Local leak tests on all testable isolation valves shall be performed per 10CFR50, Appendix J requirements.

i (6)

Local leak tests on all testable penetrations shall be performed per 10CFR50, Appendix J requirements.

(7)

Personnel Air Locks shall be tested at 6-month intervals.

(8)

The personnel air locks are tested at 49.1 psig.

l (9)

Identifies isolation valves that may be tested by applying pressure between the inboard and outboard valves.

(10) Gate valves are tested in reverse direction.

Test acceptable since the normal force between the seat and the disc generated by stem action alone is greater than ten (10) times the normal force induced by test differential pressure except for valves MO-10-31A,B which is 7.97.

This applies to the following valves:

MO-2-74 MO-10-31A, B MO-13-15 MO-10-18 MO-23-15 MO-12-15 (Unit-#2)

MO-10-32 (Unit #2)

-188-Amendment No. 29, 167, 182

i Unit 3 PBAPS l

3.7.A & 4.7.A BASES (Cont'd.)

The design basis loss-of-coolant accident was evaluated at the primary containment maximum allowable accident leak rate of 0.54/ day at 56 psig.

Calculations made by the AEC staff with leak rate and a standby gas treatment system filter efficiency of 904 i

for halogens and assuming the fission product release fractions j

stated in TID 14844, show that the maximum total whole body passing 1

cloud dose is about 1.0 REM and the maximum total thyroid dose is i

about 14 REM at' 4500 meters from the stack over an exposure duration of two hours.

The resultant doses that would occur for the duration of the accident at the low population zone distance of 7300 meters are about 2.5 REN total whole body and 105 REM total l

thyroid.

Thus, the doses reported are the maximum that would be expected in the unlikely event of a design basis loss-of-coolant accident.

These doses are also based on the assumption of no j

holdup in the secondary containment resulting in a direct release i

of fission products from the primary containment through the filters and stack to the environs.

Therefore, the specified l

primary containment leak rate and filter efficiency are conservative and provide margin between expected off-site doses and l

10 CFR 100 guidelines.

1 l

The water in the suppression chamber is used only for cooling in

'i the event of an accident; i.e.,

it is not used for normal operation; therefore, a daily check of the temperature and volume is adequate to assure that adequate heat removal capability is

[

present.

Drywell Interior l

4 The interiors of the drywell and suppression chamber are painted to prevent rusting.

The inspection of the paint during each major refueling outage, assures the paint is intact.

Experience with this type of paint at fossil fueled generating stations indicates 3

that the inspection interval is adequate.

i j

Post LOCA Atmosphere Dilution 1

In order to ensure that the containment atmosphere remains inerted, i.e.

the oxygen-hydrogen mixture below the flammahle limit, the j

capability to inject nitrogen into the containment after a 14CA is

{

provided.

During the first year of operation the normal inerting i

nitrogen makeup system will be available for this purpose.

After that time the specifically designed CAD system will serve as the post-LOCA Containment Atmosphere Dilution System.

By maintaining

}

a minimum of 2000 gallons of liquid N, in the storage tank it is j

assured that a seven-day supply of N for post-LOCA containment j

inerting is available.

Since the inerting makeup system is

~

continually functioning, no

- 193 -

Amendment No.182 i

I i

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

r Mt3 pggp3 LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIRDENTS and one main stack shall also demonstrate that noble gas monitor control room alam an-shall be operable and set nunciation occurs if any of to alam in accordance the following conditions exist:

with the methodology.

1.

Instrument indicates and parameters in the measured levels ODCM. From and after the above the alam j

i date that both reactor setpoint.

building exhaust vent 2.

Instrument indicates monitors or both main a downscale failure.

stack noble gas monitors Additionally, an instrument are made or found to be check shall be perfomed inoperable for any reason, every day.

effluent releases via 4b.

The reactor building l

their respective pathway exhaust vent and the may continue provided at main stack flow rate least two independent monitors shall be grab samples are taken calibrated every 12 i

l at least once per 8 hrs, months. Additionally, an and these samples are instrument check shall analyzed for gross be performed every day.

activity within 24 4c.

The reactor building l

hours, and at least two exhaust vent and the main i

technically qualified stack todine and particulate members of the facility sample flow rate monitors staff independently shall be calibrated every verify the release 12 months. Additionally, rate calculations.

an instrument check shall c.

One reactor building be performed every day exhaust vent iodine for the reactor building filter and one main exhaust vent sample flow stack iodine filter rate monitors, and every and one reactor build-week for the main stack ing exhaust vent sample flow rate monitor.

particulate filter 44.

The main stack sample and one main stack flow line M1/Lc pressure particulate filter with switches shall be their respective flow functionally tested every i

rate monitors shall be 6 months and calibrated operable. From and after I

svery 24 months.

the date that all iodine filters or all particulate filters for either the i

reactor building exhaust i

vent monitor or the main stack monitor are made or found to be inoperable for any reason, effluent releases via their respective pathway may

-211-Amendment No. IN, II9,182

)

Unit 3 PBAPS LIMITItG CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.9 AUXILIARY ELECTRICAL SYSTEM 4.9 AUXILIARY ELECTRICAL SYSTEM Applicabitity:

Applicability i

Applies to the auxiliary Applies to the periodic electrical power system.

testing requirements of the auxiliary electrical Objective:

systems.

l To assure an adequate Objective:

supply of electrical power j

for operation of those Verify the operability j

systems required for safety, of the auxiliary electrical system.

Specification:

Specification-A.

Auxiliary Electrical A.

Auxiliary Electrical Ecuipment Equipment The reactor shall not be made 1.

Diesel Generators and

{

critical unless all of the following Offsite Circuits conditions are satisfied:

1.

Two physically independent 1.

Each of the required circuits between the offsite-independent circuits transmission network and between the offsite the onsite Class 1E transmission network and distrioution system are operable.

the onsite Class IE distribution system l

2.

The four diesel generators shall be shall be:

l operable and there shall be a mimimum l

of 108.000 gallons of diesel fuel a.

Verified OPERABLE on site. Each operele diesel at least once per generator shall have:

7 days by verifying correct ta eaker j

a.

A separate day tank alignments and containing a minimum indicated power of 200 gallons of fuel, availaoility.

b.

A separate fuei storage tank with a minimum of 28,000 gallons of fuel, b.

Demonstrated OPERABLE t

and at least once per 24 months l!

c.

A separate fuel transfer by transferring, pump.

manually and automatically, the 3.

The unit 4kV etrergency buses start-up source and tne 480V emergency from the normal load centers are energized.

circuit to the alternate circuit.

4.

The four unit 125V batteries and their chargers shall be operable.

-217 Amendment No. IJ2,176,182

-~ _

q Unit 3 PBAPS LIMITING CONDITION FOR OPERATION SURVEILLANCE REQUIREMENTS 4.9.A.I.2 (Continued) e.

At least once every 51 days by

{

obtaining.a sample of fuel oil i

from the storage tank in accordance with ASTM D2276-78, and verifying that total particulate contamination is less than 10mg/ liter when checked in accordance with ASTM D2276-78, Method A, except that the filters specified in ASTM D2276-78, Sections 5.1.6 and 5.1.7, may have a nominal pore size of up to three (3) microns.

f.

At least once per 18 months by:

i 1.

Subjecting the diecel to an inspection in accordance with procedures prepared in conjunction with its y

manufacturer's recommendations for this class of standby service.

g.

At least once per 24 months by:

1.

Verifying the diesel generator capability to reject a load of i

greater than or equal to that of the R' R Pump Motor for each A

diesel generator while maintaining voltage within 4160 i-410 volts and frequency at 60 1.2hz.

5 2.

Verifying the diesel generator l

capability to reject an indicated lead of 2400 kW-2600 Kw without tripping. The generator voltage shall not exceed the initial value (4160 2 410 volts) by more than 660 volts during and following the load rejection.

-218d-Amendment No. 176,182 i

i i

Unit 3 i

PBAPS LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 4.9.A.1.2.g (Continued)

3. Verifying that all automatic diesel generator trips except i

engine overspeed, generator differential over-current, generator ground overcurrent and i

manual cardox initiation are automatically bypassed upon an ECCS actuation signal.

4.Verifyingthedieselgenerator operates for at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . During the first 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of this test, the diesel generatorshallbeloagedtoan indicated 2800-3000 kW and during the remaining 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months of this test, the diesel generator i

shallbeloagedtoanindicated i

2400-2600 kW.

l l

5. Verifying diesel generator l

capability at full load temperature within 5 minutes after completing the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months e

test by starting and loading the diesel as described l

in Surveillance Requirement i

i 4.9.A.1.2.bandoperatjngfor greater than 5 minutes aThis test shall be conducted in accordance with the manufacturer's recommendations regarding engine prelube and warm-up and, as applicable, loading and shutdown.

bThis band is meant as guidance to avoid routine overloading of the engine.

Loads in excess of this band for special testing, under direct monitoring by the manufacturer or system engineer, or momentary variations due to changing bus loads shall not invalidate the test.

CIf Surveillance Requirement 4.9.A.1.2.g.5 is not satisfactorily completed, it is not necessary to repeat the preceding 24-hour test.

Instead, the diesel generator may be operated at 2400-2600 kW for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or until operating temperature has stabilized prior to performing Surveillance Requirement 4.9.A.I.2.g.5.

dPerformance of Surveillance Requirement 4.9.A.1.2.g.5 will not be used to satisfy the requirements of Surveillance Requirement 4.9.A.1.2.b.-

4 i

i i

30A Aii'endirent No. 776a 182 i

i Unit 3 i PBAPS LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 4.9.A.l.2 (Continued)

6. Verifying that the fuel transfer l

pump transfers fuel from each' fuel storage tank to the day tank of each diesel via the installed cross connection lines.

h.

At least once each operating l

cycle by:

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

a) Verifying deenergization of the emergency busses and load shedding itre the emergency

busses, b) Verifyingthedigsel i

generator starts on the i

auto-start signal, energizes the emergency busses within 10 seconds, energizes the permanent and auto-connected loads through the individual load timers and operates for

~

greater than or equal to 5 minutes.

After energization, the steady-state voltage and frequency of the emergency busses shall be maintained at 4160 + 410 volts and 60 + 1.2 Hz during this test.

aThis test shall be conducted in accordance with the manufacturer's recommendations regarding engine prelube and warm-up and, as applicable, loading and shutdown.

1 b

Amendment No. 776,182

-218f. -

3<

Unit 3 PBAPS LIMITING CONDITIONS FOR OPERATI0N SURVEILLANCE REQUIREMENTS 4.9.A.I.2 (Continued) 4.

Verifying the diesel generator's capability to:

a)

Synchronize with the offsite power source while the generator is loaded with its emergency loads upon a simulated restoration of offsite power.

b)

Transfer its loads to the offsite power source, and c)

Be restored to its standby status.

i.

At least once per 10 years or I

after any modifications which could affect diesel generator interdependence by starting

all four diesel generators simultaneously and verifying that all four diesel generators accelerate j

to at least 855 rpm in less than or equal to 10 seconds.

t j.

At least once per 10 years by l

l draining each fuel oil tank, removing the accumulated sediment and cleaning the tank using a sodium hypochlorite or equivalent solution.

k.

The fuel oil storage tank l

cathodic protection system l

shall be checked as follows:

1.

At least once every twelve months perform a test to determine whether the cathodic protection is adequate, and

This test shall be conducted in accordance with the manufacturer's recommendations regarding engine prelube and warmup and, as applicable, loading and shutdown.

l

-218h-Amerximent No. 176,182

i

.i 1i j

Unit 3-PBAPS 1.IMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIRENENTS j

i 4.9.A.I.2 (Continued) 2.

At least once every two months inspect the cathodic protection rectifiers.

i t

1.

If the number of failures during l

the last 20 valid demandsd is less than or; equal to 1, the test j

frequency shall be at least once per 31 days.

l If the number of failures during l

the last 20 valid demands is i

greater than or equal to 2, the test frequency shall be at least-once per 7 days'.

m.

All diesel generator failures,.

t valid or non-valid, shall be 3

i reported to the Consission in a Special Report within 30 days.

Reports of the diesel generator failures shall include the information recommended in l

Regulatory Position C.3.b of f

Regulatory Guide 1.108, Revision

{

1, August 1977.

j

" Criteria for determining the number of failures and number of valid demands shall be in accordance with Regulatory Position C.2.e of Regulatory Guide 1.108, but determined on a per diesel generator basis.

1

The associated test frequency shall be maintained until seven consecutive failure free demands have been performed and the number of failures in the last 20 demands have been reduced to one.

For the purposes of determining the required frequency, the previous test failure count may be reduced to zero if a complete diesel overhaul to like-new condition is completed. This diesel overhaul, including appropriate post-maintenance operation and testing, shall be specifically approved by the manufacturer and acceptable diesel reliability must be demonstrated. The reliability criterion shall be the successful completion of 14 consecutive tests. Ten of these tests may be slow starts in accordance with Surveillance Requirements 4.9.A.I.2.a.3 and 4.9.A.1.2.a.4 and four tests shall be fast starts in accordance with the Surveillance Requirement 4.g.A.I.2.b.

If this criterion is not satisfied during the first series of tests, any alternate criterion to be used to reset the valid failure count to zero requires NRC approval.

-2181-Amendment No. 176, 182 a.

Unit 3 PBAPS LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 4.9.A.2 Unit Batteries a.

Every week the specific gravity, the voltage and temperature of the pilot cell and overall battery voltage shall be measured and logged.

b.

Every three months the measurement: shall be made of voltage of each cell to nearest 0.1 Volt, specific gravity of each cell, and temperature of every fifth cell.

These measurements shall be logged.

I c.

The station batteries shall be l

subjected to a performance test every second refueling outage l

and a service test during the other refueling outage.

In lieu l

of the perfomance test every i

second refueling outage, any l

battery that shows " signs of degradation or has reached 85%

of its service life" shall be l

subjected to an annual performance test. The service test need not be performed on the refueling outage during which the performance test was l

conducted. The specific gravity and voltage of each cell shall be determined after the discharge and logged.

l 4.9.A.3 Swing Buses a.

Every two months the swing buses supplying power to the Low Pressure Coolant Injection System (LPCIS) valves shall be tested to assure that the transfer circuits operate as designed.

5~

~

Amendment No. 176,182

Unit 3 i

LIMIT!NG CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 4.11.0.3 Visual inspection of snubbers required to be operable under the provisions of 3.11.0.1 shall verify that 1) there are no indications of damage or impaired operability, 2) attachments to the foundations or supporting structure are functional, and 3) fasteners for the attachment of the snubber to the component and to the snubber anchorage are functional.

Snubbers which appear to be inoperable as a result of visual inspections shall be classified as unacceptable and may be reclassified acceptable for the purpose of establishing the next visual inspectioninterval,providingthat1) the cause of the rejection is clearly established and remedied for that particular snubber and for other generically susceptible snubbers; and 2) the affected snubber is functionally tested in the as found condition and determined operable per Specification 4.11.D.7 or 4.11.D.8, as applicable. All snubbers found connected to an inoperable common hydraulic fluid reservoir shall be counted as unacceptable for determining the next inspection interval. A review and evaluation shall be performed and documented to justify continued operation with an unacceptable snubber. If continued operation cannot be. justified, the snubber shall be declared inoperable and the Limiting Conditions for Operation shall be met.

4.11.D.4 Functional Test

a) Once each operating cycle, during shutdown, a representative sample of 105 ofeachtypeof(sechanicalorhydraulic) snubber required to be operable under the provisions of 3.11.D.1 shall be functionally tested either in place or in a bench test.

For every unit found to be inoperable an additional 105 of that type of snubber shall be functionally

Performance of 4.ll.D.4(a) with an tested until no more failures are found operating cycle of 732 days is or all snubbers of that type have been approved for the operating cycle tested. The functional test requirements following refueling outage for mechanical 3R09 only.

s Amendment'No f93MfpfQ82 g

]

I Unit 3 l

i l

PBAPS i

/

l LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.14.D Fire Barriers 4.14.D Fire Barriers l

1. Fire barriers (including

1. Fire barriers required walls, floor, ceilings, electrical to meet the provisions cable enclosures, cable, piping and of 3.14.0.1 (fire doors ventilation duct penetration excluded - see speci-j seals, fire doors, and fire fication4.14.D.2)shall dampers) which protect be verified operable safety related systems following maintenance required to ensure safe or modifications, and by per-shutdown capability in the forming the following visual event of a fire, shall be inspection:

functional.

a. The exposed surface of each fire barrier wall, floor, j

and ceiling, shall be inspected

2. If the requirements of at least once per 24 months.

I 3.14.D.1 cannot be met, Exposed surfaces are-within one hour establish a those surfaces that can continuous fire watch on at be viewed by the inspector least one side of the from the floor.

I affected fire barrier, or verify the operability of

b. Each fire damper and electrical fire detectors on at least cable enclosure shall be inspected one side of the inoperable at least once per

(

fire barrier and establish 18 months.

an hourly fire watch patrol.

Reactor startup and continued

c. Once per 24 months at least l

reactor operation is 12.5 percent of each type of permissible.

fire barrier penetration seal (including electrical cable, piping, ventilation duct penetration seals, and excluding internal conduit l

seals) such that each penetration i

seal will be inspected at least once per 16 years.

l Difficult-to-view fire l

barrier (unexposed) walls, l

and ceilings that are rendered accessible by the penetration seal inspection program shall also be I

inspected during each 12.5 g

percent inspection.

240j(1)

Amendment No. 39, S4, 100, 123,182

.-,-~,--,,--,+r-----

~

e.

w-w-,

,-e

--w-w.+,m-

,,-w,-,,,-

A Unit 3 PokPS i

LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMCNTS 4.14.0 Fire Barriers (Cont'd)

1. (Continued)

If any penetration seal selected for inspection is found by surveillance i

requirements 4.14.0.1(c) in a condition which may compromise.

the operability of the penetration seal, the cause shall be evaluated.

If the cause is a failure to adhere to penetration seal procedures, or an identified phenomenon (e.g.,

physical interference), the cause shall be corrected and potentially affected seals inspected. Otherwise, a visual inspection of an additional 12.5 percent, selection based on the nature of the degradation, shall be made.

This inspection process shall continue until a 12.5 percent l

sample with no degradation is found.

l

2. Fire doors required to meet the provisions of 3.14.D.1 shall be verified operable by inspecting the closing mechanism and latches every 6 months *, and by verifying:

a.

The operability of the fire door supervision system for each electrically supervised fire door by performing a l

functional test every month, b.

That each locked-closed fire door is in the closed s

position every week.

c.

That each unlocked fire door without electrical supervision is in the closed position every day.

Fire door inspections requiring access to radiation areas may be deferred until the next refueling outage or shutdown initially expected i

to be of at least a 7-day duration.

l 240j(2)

Amendment No. 39, H,100,123,182 l

Unit 3 Table 4.15" SEISMIC MONITORING INSTRUMENTATION SURVEffl1NCE REQUIPNrrfs Instrument

Instrument

Functional Instrument Check Test Calibration

^

Instruments and Sensor Locations #

1.

Triaxal Time-History Accelerographs a.

Containment Foundation (torus compartment)

M SA R

b.

Refueling Floor M

SA R

c.

RCIC Pump (Rm #7)

M SA R

d.

"C" Diesel Generator M

SA R

2.

Triaxal Peak Accelerographs a.

Reactor Piping (Drywell)

NA NA R

b.

Refueling Floor MA NA R

c.

"C" Diesel Generator NA NA R

3.

Triaxal Response-Spectrum Recorders a.

Cable Spreading Rm M

SA R

Surveillance Frecuencies M:

every month SA:

every 6 months l

R:

every 24 months Ef fective upon completion of installation.

Seismic instrumentation located in Unit 2.

-240v-Ahnt No. 74, f4,182

.

ML20056E599

Text

Navigation menu

Search