ML18051A415

Proposed Tech Spec Change Request Re Surveillance Testing Frequency

ML18051A415
Person / Time
Site:	Palisades
Issue date:	05/05/1983
From:	CONSUMERS ENERGY CO. (FORMERLY CONSUMERS POWER CO.)
To:
Shared Package
ML18051A413	List: ML18051A412 ML18051A414 ML18051A415
References
NUDOCS 8305100291
Download: ML18051A415 (19)

Text

CONSuMERS POWER COMPANY PALISADES PLANT - DOCKE.T 50-255 - LICENSE DPR-20 PROPOSED TECHNJCAL SPECIFICATIONS CHANGE REQUEST PROPOSED PAGES r 8305 100291 030505 I :~

ll PDR ADOCK 05000255 l *p PDR _

I\.

~- .J. , ..

• J 18 PAGES BP1282-0002A-NL02

4. 0 SURVEILLANCE REQUIREME:NTS 4.0.l .surveillance requirements shall be applicable during the reactor operating cond.i tions associated vi th individual Lim ting Cond.i tions.

for Operation unless othervise stated 1D B.D individual su..-..eillance requirement.

4.0.2 Unless other\l'ise specif~ed, each surveilla..~ce requireme:::lt sl::a.11 be performed vithi.D the specifiec tiQe interval vitb:

a. A max:i:rum a.llo\1'8.ble extension not to exceec 25% of the surveil-la.nce interval, ~d

b. A total me.xii:tU:!l combi:::led interval t:~e fc:- e.."'y three ccnsec'.ltive surveilla.oce intervals not to exce~i 3.25 ti:es the specifie~

surveillB.Dce interval.

4.1 INSTRUMENTATION AND CONTROL ko"Oli ce.bili tv Applies to the reactor prote{'tive syste:i imd othe:- critical inst:r.::e::rta-

. ti on a:;d co~trols.

Objective To specify the m:inii::um frequency B:ld type of S'UZ'VeillaDce to be a?pl ~.I!~

to critical plant i!lstrument~tion a::id controls.

S"Oec i:fications Calibration, testing, e.od checking of inst~e~t che.r..ne:s, reactor pro-tective syste: a..~d erig!neered safe~~rds syste~ logic cha::.~els e.nd miscellB.!leous inst~e::it syste:s and controls she.il be perfo1":1ec as specified in 4.1.1 and in Tables 4.1.1 to 4.1.3.

4.1.1 Overpressure Protection Systems

a. Each PORV shall be demonstrated operable by:

1. Performance of a channel functional test on the PORV actuation channel, but excluding valve operation, within 31 days prior to entering a condition in which the PORV is required operable and at least once per 31 days thereafter when the PORV is required operable.

2. Performance of a channel calibration on the PORV actuation channel at least once per refueling cycle.

3. Verifying the PORV isolation valve is open at least once per 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> t,*hen .the PORV is being used for overpressure protection.

4. Testing in accordance with the inservice inspection requiTe1'1ents for AS:!E Sect:i.c'r. :\I, Section I~,y Category C valves.

4-1 PROPOSED

TABLE 4.1.1 Minimum Frequencies for Checks, Calibrations and Testing of Reactor Protective System(5)

Su rve i 1 I a nee Channel Description Function Frequency Survei I lance Method

.1. Power Range Safety Channels a. Check s a. Comparison of four-power channel readings.

b. Check(3) D b. Channel adjustment to agree with heat balance calculation. Repeat whenever flux- T power comparator alarms.

c. Test M(2) c. Internal test signal.(4)

d. Ca I i bra te RC d. Channel alignment through measurement/

adjustment of internal test points.

2. Wide-Range Logarithmic a. Check s a. Comparison of both wide-range readings.

Neutron Monitors b. Test p b. Internal test signal.

3. Reactor Coolant Flow a. Check s a. Comparison of four separate total flow indications.

b. Ca 1 i bra te ( 6) RC b. Known differential pressure applied to sen so rs.

c. Test M(2) c. Bistable trip tester.(1)(4)

4. Thermal Margin/Low a. Check: s a. Check:

Pressurizer Pressure ( 1) Temperature (1) Comparison of four separate calculated Input trip pressure set point indications.

( 2 ) P re s s u re (2) Comparison of four pressurizer pressure Input indications. (Same as 5(a) below.)

b. Cai i brate RC b. Calibrate:

( 1) Temperature (1) Known resistance substituted for RTD lnpµt coincident with known pressure input.

(2) Pressure (2) Part of 5(b) below.

Input

c. Test M(2) c. Bistable trip te~ter.(1)(4)

5. High-Pressurizer Pressure a. Check s a. Coffiparison of four separate pressure indications.

b. Ca I i bra te ( 6) RC b. Known pressure applied to sensors.

c. Test M(2) c. Bistable trip tester.(1) nu0681-0313b-43-42 4-3 Proposed

TABL~ 4.1.l Minimum Frequencies for Checks, Calibrations and Testing of Reactor Protective System(5) (Contd)

Su rve i I I a nee Channel Description Function Freguenc:t Surve i I I a nee Method

6. Steam Generator Level a. Check s a. Comparison of four level indications per generator.

b. ca Ii b rate RC b. Known different i a I pressure app I i ed to sensors.

c. Test M(2) c. Bistable trip tester.(1)

7. Steam Generator Pressure a. Check s a. Comparisons of four pressure indications per generator.

b. Ca I ibrate(6) RC b. Known pressure applied to sen so rs. I

8. Containment Pressure c.

a.

b.

Test Ca I i bra te Test M(2)

R M(2) c.

a.

b.

Bistable trip tester.(1)

Known pressure applied to sen so rs.

Simulate pressure switch action.

e

9. Loss of Load a. Test p a. Manua I ly trip turbine auto stop oi I re I ays.

10. Manua I Trips a. Test p a. Manually test both circuits.

11. Reactor Protection System a. Test M(2) a. I nte rna I test circuits.

Logic Units NOTES: (l)The bistable trip tester injects a signal into the bistable and provides a precision readout of the trip set point.

(2)AI I monthly tests wi I I be done on only one of four channels at a time to prevent reactor trip.

(3)Adjust the nuclear gain pot on the T cabinet unti I readout agrees with heat balance calculations.

(4)Trip setting for operating pump combination only. Settings for other than operating pump combinations must be tested during routine monthly testing performed when shut down and within four hours after resuming operation with a different pump combination if the setting for that combination has not been tested within the previous month.

(5)1t is not necessary to perform the specified testing during prolonged periods in the refueling shutdown condition. If this occurs, omitted testing wi 11 be performed prior to returning the plant to service.

nu0681-0313d-43-42 4-4 Proposed

TABLE 4.1.1 ( )

Minimum Frequencies for Checks, Calibrations and Testing of Reactor _Protective System 5 (Contd)

FREQUENCY NOTATION Notation

--- Frequency s At least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

D At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

w At least once per 7 days.

M At least once per 31 days.

Q At least once per 92 days.

SA At least once per 6 months.

R At least once per 18 months.

.i::- p Prior to each start-up if not done 1

\J1 previous week.

NJ\ Not applicable.

RC

• At least once per refueling cycle.

• Refueling cycle defined as the period from startup from one refueling outage to startup from the next.

TABLE 4.1.2 Minimum Frequencies for Checks, Calibrations and Testfng of Engineered Safety Feature Instrumentation Controls(4)

Surve i 11 ance Channel Description Function Freguenc~ Survei I lance Method

1. Low-Pressure SIS Initiation a. Check s a. Comparison of four separate ~ressure Channels indications.

b. Test(1)(4) RC b. Signal to meter relay adjust with test device to verify SIS actuation logic.

c. Test M(2) c. Signal to meter relay adjusted with test device.

2. Low-Pressure SIS Signal Block a. Test(1)(4) RC a. Part of 1(b) above. I Permissive and Auto Reset

3. SIS Actuation Relays a. Test Q a. Simulation of SIS 2/4 logic trip, using bui It-in testing system .. Both 'standby power" and "no standby power" circuits wi I I be tested for left and right chan-nels. Test wi I I verify functioning of initiation circuits of al I equipment normally operated by SIS signals.

b. Test RC b. Complete automatic test initiated by same method as Item 1(b) and including al I normal automatic operations.

4. Containment High-Pressure a. Ca I i bra te R a. Known pressure applied to sensors.

Channels b. Test RC b. Simulation of CHP 2/4 logic trip to verify actuation logic for SIS, contain-ment isolation and containment spray.

c. Test M(2) c. Pressure switch operation simulated by opening or shorting terminals or pressure applied to the switch.

5. Containment High Radiation Channels (see Item 4.B of Table 4.1.3. "Minimum Frequencies for Checks, Calibrations, and Testing of Miscellaneous Instrumentation and Controls).

nu1182-0076b142-42 4-6 Proposed

r TABLE 4. l. 2 Minimum Frequencies for Checks, Calibrations and Testing of Engineered Safety Feature Instrumentation Control~(4) (Contd)

Surve i 11 ance Channel Description Function Frequency Survei I lance Method

6. Manual SIS Initiation a. Test R a. Manual push~button test.

7. Manual Containment a. Test RC a. Manual push-button test.

Isolation Initiation b. Check RC b. Observe isolation valves closure.

8. Manual Initiation Contain- a. Test R a. Manual switch operation.

ment Spray Pumps and Valves

9. OBA Sequencers a. Test Q a. Proper operation wi 11 be verified during SIS actuation test of Item 3(a) above.

10. Normal Shutdown Sequencers a. Test R a. Simulate normal actuation with test-

.operate switch and verify equipment

• starting circuits.

11. Diesel Start a. Test M a. Manual initiation fol lowed by synchronizing and loading.

b. Test RC b. Diesel start, load shed, synchronizing and loadi~g wi I I be verified duri~g Item 3(b) above.

c. Test p c. Diesel auto start initiating circuits.

12. SIRW Tank Level Switch a. Test RC a. Level switches removed from fluid to Interlocks verify actuation logic.

nu1182-0076b142-42 4-7 Proposed

TABLE 4.1.2 Minimum Frequencies for Checks, Calibrations and Testing of Engineered Safety Feature Instrumentation Controls(4) (Contd)

Surve i 11 ance Channel Description Function Frequency Survei I lance Method

13. Safety Injection Tank Level a. Check s a. Verify that level and pressure indica-and Pressure Instruments tion is between independent high high/

low alarms for level and pressure.

b* Ca I i bra te RC b. Known pressure and differential pres-sure applied to pressure and level sen so rs.

14. Boric Acid Tank Level Switches a. Test R a. Pump tank below low-level alarm point to verify switch operation.

15. Boric Acid Heat Tracing System a. Check D a. Observe temperature recorders for proper readings.

16. Main Steam Isolation Valve a. Check s a. Compare four independent pressure indi-circuits cations.

b. Test( 3) RC b. Signal to meter relay adjusted with test device to verify MSIV circuit logic.

17. SIRW Tank Temperature a. Check M a. Compare independent temperature readouts.

Indication and Alarms b. Ca I ibrate RC b. Known resistance applied to indicating loop.

18. Low-Pressure Safety Injection a. Check p a. Observe valve is open with air supp~y Flow Control Valve CV-3006 isolated.

19. Safety Injection Bottle a. Check p a. Ensure each valve is open by observing valve Isolation Valves position indication and valve itself.

Then lock open breakers (at MCC-9) and control power (key switch in control room).

20. Safety Injection Miniflow a. Check p a. Verify valves open and HS-3027 and 3056 Valves CV-3027, 3056 positioned to maintain them open.

NOTES: (l)Cal ibration of the sensors is performed during calibration of Item 5(b), Table 4.1.1.

(2)AI I monthly tests wi I I be done on only one channel *at a time to prevent protection system actuation.

(3)Cal ibration of the sensors is performed during calibration of Item 7(b), Table 4.1.1.

(4)1t is not necessary to perform the specified testing during prolonged periods in the refueling shutdown condition. If this occurs, omitted testing wi 11 be performed prior to returning the plant to service.

nu0880-0003d-43-42 4-8 Proposed

TABLE !1.1. 2 ( 4)

Minimwn Frequencies for Checks, Calibrations o.nd Testing of' Reactor Protective System (Contd)

FREQUENCY NO'i'A'I'ION Notation Frequency s At least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

D At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

w At least once per 7 days.

M* At least once per 31 days.

Q At least once per 92 days.

SA At least once per 6 months.

R At least once per 18 months.

.i::--

1

\()

p Prior to each start-up if not done previous week.

NA Not applicable.

RC

• At least once per refueling cycle.

• Refueling cycle is defined as the period from startup from one refueling outage to startup from the next.

TABLE 4. 1. 3 Minimum Frequencies for Checks, Cal I brat ions and Testing of Miscellaneous Instrumentation and Controls(5)

Surve i I I ance Channel Description Function Frequency Survei I lance Method

1. Start-Up Range Neutron a. Check s a. Comparison of both channel count rate Monitors indications when in service.

b. Test p b. Internal test signals.

2. Primary Rod Position a. Check s a. Comparison of output data with secondary Indication System RPIS.

b. Check M b. Check of power dependent insertion I imits monitoring system.

c. Calibrate(l) RC c. Physically measured ~od drive position used to verify system accuracy. Check rod position interlocks.

3. Secondary Rod Position Indication System a.

b.

Check Check s

M a.

b.

Comparison of output data with primary RPIS.

Same as 2.b above.

eI

c. Ca I i bra te ( 1 ) RC c. Same as 2.c above, including out-of-sequence alarm function.

4. Area Monitors

a. Containment High- a. Check s a. Comparison of two independent Ra nge Mon i to rs monitor readings relative to (RIA-2321 and 2322) expected response ratios.

b. Ca I ibrate .RC b. Calibration by electronic signal substitution for ranges above 10 R/hr. One-point exposure to a known radiation source below 10 R/hr.

c. Test M c. Internal Test Signal.

b. Containment Isola- a. Check s a. Normal readings observed and Internal tion Monitors (RIA-1805, Test Signals used to verify 1806, 1807 and 1808) instrument operation.

b. Ca I i bra te RC b. Calibration by electronic signal substitution for ranges above 10 R/hr.

One-point exposure to a known radiation source below 10 R/hr.

c. Test M c. Detector exposed to radiation check source.

d. Test RC d. Simulation of CHR 2/4 Logic trip with test switch to verify actuation relays, including containment isolation.

c. Spent Fuel Pool a. Check s a. Norma1 readings observed and internal test Criticality Monitors(l) signals used to verify instrument operation.

(RIA-2313 and 5709) b. Ca Ii brate R b. Exposure to known external radiation source.

c. Test M c. Exposure to a radioactive source or con-firmation of a significant instrument reiding above natural background by radiation field measurement is used to verify instrument operation.

(')Criticality monitors for fuel hand I ing in the containment bui I ding are calibrated and routine checks of their operability are control led by refueling procedures.

nu1082-0542a-43-42 4-10 Proposed

TABLE 4.1.3 Minimum Frequencies for Checks, Calibrations and Testing of Mi see I laneous Instrumentation and Controls(5) (Contd)

Su rve i I I a nee Channel Description Function Frequency Surve i I lance Method

5. Emergency Plan Radiation a. Ca I i bra te A a. Exposure to known radiation source.

Instruments b. Test M b. Battery check.

6. Environmental Monitors a. Check M a. Operational check.

b. Ca Ii brate A b. Verify airflow indicator.

7. Pressurizer Level a. Check s a. Comparison of six independent level Instruments

b. Ca Ii brate RC b.

readings.

Known differential pressure applied to I

c. Test M c.

sensor.

Signal to meter relay adjusted with test device.

e

8. Control Rod Drive System a. Test RC a. Verify proper operation of al I rod drive

.l Interlocks control system interlocks, using simulated signals where necessary.

b. Test p b. Same as 8.a above, if not done within three months.

~. Flux-T Power Comparator a. Ca I i bra te R a. Use simulated signals.

b. Test

• M b. Internal test signal.

10. Calorimetric Instrumentation a. Cal ibrate(2) RC a. Known differential pressure applied to feedwater flow sensors.

11. Containment Bui I ding Humidity a. Test RC a. Expose sensor to high humidity atmosphere.

Detectors

12. Interlocks - Isolation Valves a. Ca I i bra te RC a. Known pressure applied to sensor.

on. Shutdown Cooling Line

13. Service Water Break Detector a. Test RC a. Known differential pressure applied to in Containment Sensors.

nu0681-0313c-43-42 4-11 Proposed

.[

TABLE 4.1.3 Minimum Frequencies for Checks, Calibrations and Testing of Miscellaneous Instrumentation and Contro~s(5) (Contd)

Surveillance Channel Description Function Freguenc~ Surve i I I ance Method

14. Auxi I iary Feed Pump a. Check M(4) a. Comparison of channels.

Flow Indication b. Ca I i bra te R b. Known differential pressure applied to sen so rs.

15. Auxi I ia ry Feed Pump a. Test* M( 2 ), ( 4) a. I nte rna I Test Signa I.

Auto Initiation b. Ca I i b rate R b. Known differential pressure applied to sensors.

16. Power-Operated Re l.ief Valves and Pressurizer Code Safety Relief Valves Position Indication

a. Temperature a. Calibrate R a. Known resistance substitute for RTD.

b. Check s b. Comparison.of channels.

b. Acoustic Monitor a. Ca I i brate R a. Inject ca I ibrated test signal.

17. Subcoo Ii ng Margin a. Check s a. Comparison of channels.

Monitor b. ca Ii brate RC b. Known resistance substituted for RTD Coincident with known pressure input(3).

18. Containment Pressure a. *Check s a*. Comparison of channels.

Wide Range b. Ca I i brate R b. Known pressure applied to sensors.

19. Containment Sump a. Check s a. Comparison of channels.

Water Level Instrument b. Ca Ii brate R b. Known differential pressure applied to sensors.

20. Containment Floor a. Check s a. Comparison of channels.

Water Level Instrument b. Ca I i brate R b. Known level app I ied to transducer.

(2)Test method to be alternated to include starting au.xi I iary feedwater pump from the control room hand switch, from the breaker and from the automatic start in a three-month period.

(3)1n conjunction-with Item 4(b), Table 4.1.1.

(4)1t is not necessary to perform the specified testing during the cold shutdown condition.

(5)1t is not necessary to perform the specified testing during prolonged periods in the refueling shutdown condition.

If this occurs, omitted testing wi I I be performed prior to returning the plant to service.

nu1081-0228a-46-42 4-lla Proposed

2 TABLE 4.1.3 Minimum Frequencies for Checks, Calibrations and Testing of Mlscel laneous Instrumentation and Controls(5) (Contd)

Surve I I I ance Channel Description Function Frequency Survei I lance Method

21. Process Monitors

a. App I i es to:

Steam Generators Blowdown* a. Check D a. Normal readings observed and Internal Test Monitor (RIA-0707), Waste Signals used to verify instrument operation.

Gas Monitor (RIA-1113), b. Ca I i bra te R b. Exposure to known external radiation source.

Radwaste Discharge Monitor c. Test M c. Exposure to a radioactive source or confirma-(RIA-1049), Turbine Bui Id- tion of a significant instrument reading ing Sump Monitor (RIA-5211), above natural background by radiation field Steam Generators Blowdown measurement is used to verify instrument Tank Vent (RIA-2320) and operation.

Engineered Safeguards Rooms Ventilation Monitor (RIA-1810 and 1811)

b. Applies to:

Particulate Stack Monitor a. Check s a. Normal readings observed and internal test (RIA-2325), Normal Range signals used to verify instrument Noble Gas Stack Monitor operation.

(RIA-2326), High-Range b. Ca I i bra te R b. Exposure to a known radiation source.

Noble Gas Stack Monitor Calibration need not cover entire range (RIA-2327) and Main Steam of monitor due to the personnel exposure Safety and Dump Valve hazard of high-range calibrations.

Discharge Monitor c. Test M c. Exposure to a radioactive source or con-(RIA-2323. and 2324) firmation of a slgnificant instrument reading above natural background by radiation field measurement is used to verify instrument operation.

22. Containment Hydrogen Monitor. a. Check D a. Visual observation of control room panels (C161 and C162) for expected indications. .

b. Ca I i bra te RC b. Calibration to a known hydrogen gas.

Gas sample between O and 10 volume percent.

nu1081-0228a-46-42 4-11b Proposed '

TATII.E 11. 1. 3 ( )

Mi rai.11111111 F'requt:ncies for Checks, Calibrations and 'l'esLlng of Mlscello.neous l11strumento.tion and Controls 5 (Contd) l"HEQUENCY NO'l'Nl'ION Notation Frequenc s At least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

D .At leaot once per 211 hours0.00244 days <br />0.0586 hours <br />3.488757e-4 weeks <br />8.02855e-5 months <br />

• w At least once per 7 days.

M At least ouce per 31. days.

Q At least once per 92 days.

SA At least once 11er 6 months.

1:-

n .At least once per 18 months.

I p Prior to each start-up if not done I\.)

previous week.

NA Not o.pplicnbl.e.

A **At least once per 12 months.

RC ***At . lea.st once per refueling cycle.

HNO'l'li!: Thia lntervul ia included as on interval not included in the standard Technical ,Specifications liul. rcgulreJ liy t11e present conunl t.meuts.

• • • Refueling cycle is defined as the period from startup from one refueling outage to startup from the next.

EMERGENCY POWER SYSTEM PERIODIC TESTS Applicability Applies to periodic testfng and surveillance requirements of the emer-gency power system.

Objective To verify that the emergency power system will respond promptly and properly when required.

Specifications 4.7.1 Diesel Generators

a. Each diesel generator shall be manually started each month and demonstrated to be ready for loading within 10 seconds. The signal initiated to start the diesel shall be varied from one test to another to verify that A and B starting circuits are operable. The generator shall be synchronized from the control room, and loaded to 2400 + 100 kW.

b. A test shall be conducted during each refueling outage to demonstrate the overall automatic operation of the emergency power system. The test shall be initiated by a simulated simultaneous loss of normal and standby power sources and a simulated SIS signal. Proper operations shall be verified by bus load shedding and automatic starting of selected motors and equipment to establish that restoration with emergency power has been accomplished within 30 seconds.

c. Each diesel generator shall be subjected to an inspection, in accordance with procedures prepared in conjunction with the manufacturer's recommendations for this class of standby service, at least once per refueling cycle during plant shutdown. The licensee J shall utilize his best efforts to conduct additional major diesel generator inspections and overhauls during shutdown periods.

d. Diesel generator electric loads shall not be increased beyond the continuous rating of 2500 kW.

e. The fuel transfer pumps shall be verified to be operable each month.

Station Batteries

a. Every month, the voltage of each cell (to the nearest 0.01 volt),

the specific gravity and the temperature of a pilot cell in each battery shall be measured and recorded.

4-42 PROPOSED

. ~

c. Functional Tes'ts At least once per re.fueling cycle during plant shutdown, a representative sample (10% of the total safety-related snubbers in use at the plant) shall be functionally tested either in place or in a bench test. The test shall verify the.snubber has freedom of movement and is not frozen up. For each snubber.which did not meet the functional test acceptance criteria of Specifica-tion 4.16.1.d or 4.16.1.e, an additional 10% of th.e total shall be functionally tested.**

The representative sample selected for functional testing shall include the various configurations, operating environments and the range of size and capacity of snubbers. Snubbers identified in Table 3.20.1 and 3.20.2 as "Especially Difficult To Remove" or in "High Radiation Zones During Shutdown" shall also be included in the representative sample.*

Table 3.20.1 and 3.20.2 may be used jointly or separately as the basis for the sampling plan.

In addition to the regular sample, snubbers which failed the previous functional test shall be retested during the next test period. If a spare snubber has been installed in place of a failed snubber, then both the failed snubber (if it is repaired and installed in another position) and the spare snubber shall be retested. *Test results of these snubbers may not be included for the resampling.

If any snubber selected for functional testing either fails to lock up or fails to move~ ie, frozen in place, an additional 10% of the snubbers shall be tested until no more failures are found or all units have been tested.

For the snubber(s) found inoperable, an engineering evaluation shall be performed on the components which are suppressed by the snubber(s). The purpose of this

• Permanent or other exemptions from .functional testing for individual snubbers may be granted by the Commission only if a justifiable basis for exemption is presented and/or snubber life destructive testing was performed to qualify snubber operability for all design conditions at either the completion of their fabrication or at a subsequent date.

• • Functional tests for snubbers of rated capacity greater than 50,000 pounds will not be performed until such time that suitable onsite testing equipment is available. In the interim, a stroke test will be performed to verify freedom of movement over the full range of stroke in both compression and tension.

nu0881-0373a-43-42 4-72 Proposed

Bases All snubbers ar~ required OPERABLE to ensure that the structural integrity of the reactor coolant system and all other safety-related systems is maintained during and following a seismic or other event initiating dynamic loads.

Snubbers excluded from this inspection program are those installed on nonsafety-related systems and then only if their failure or failure of the system on which they are installed, would have no adverse effect on any safety-related system.

The visual inspection frequency is based upon maintaining a constant level of snubber protection to systems. Therefore, the required inspectfon interval varies inversely with the observed snubber failures and is determined by the number of inoperable snubbers found during an inspection. Inspections performed before that interval has elapsed may be used as a new reference point to determine the next inspection.

However, the results of such early inspections performed before the original required time interval has elapsed (nominal time less 25%) may not be used to lengthen the required inspection interv.al. Any inspection whose results require a shorter inspection interval will override the previous schedule.

When the cause of the rejection of a snubber is clearly established and remedied for that snubber and for any o.ther snubbe~s that may be generically susceptible, and verfied by inservice functional testing, that snubber may be exempted from being counted as inoperable . . -Generically susceptible.

snubbers are those which are of a specific make or model and have the same design features directly related to rejection of the snubber by visual inspection, or are similarly located or exposed to the same environmental conditions such as temperature, radiation and vibration.

When a snubber is found inoperable, an engineering evaluation is performed, in addition to the determination of the snubber mode of failure, in order to determine if any safety-related component or system has been adversely affected by the inoperability of the snubber. The engineering evaluation shall determine whether or not the snubber mode of failure has imparied a significant effect or degradation on the supported component or system.

To provide assurance of snubber functional reliability, a representative sample of the installed snubbers will be functionally tested during plant shutdowns at least once per refueling cycle.

nu0881-0373a-43-42 4-74 Proposed

FIRE PROTECTION SYSTEM 4.17.2 FIRE SUPPRESSION WATER SYSTEM SURVEILLANCE REQUIREMENTS 4 .17. 2. 2 The fire pump diesel engines ( 2) and starting 2.4 volt battery banks ( 2) and charger shall be demonstrated operable:

a. At least once per 7 days by verifying that:

1) The electrolyte level of each battery is above the plates, and

2) The overall battery voltage is ~ 24 volts.

b. At least once per 3 months by verifying that:

1) A sample of diesel fuel from the main storage tank (T-10) obtained in accordance with ASTM-D270-65, is within the acceptable limits specified in Table 1 of ASTM D975-74 with respect to viscosity, water content, and sediment.

2) *The specific gravity* of the starting battery bank is appropriate for continued service of the battery.

c. At least once per 18 months by verifying that:

1) The batteries, cell plates and battery racks show no visual indication of physical damage or abnormal deterioration, and

2) The battery~to-battery and terminal connections are clean, tight, free of corrosion and coated with anticorrosion material.

d. At least once per refueling cycle during plant shutdown, by:

1) Subjecting the diesels to an inspection in accordance with procedures prepared in conjunction with its manufacturer's recommendations for the class of service.

PROPOSED 4-77

,. ~

FIRE PROTECTION SYSTEM-4.17.5 PEHETRATION FIRE BP.RRIERS SlJRVEILLANCE REQUIREMENTS 4.17.5.1 .Each of the penetration fire barriers sr...all be verified to be functional by a visual inspection at least once per refueling cycl~ and prior to f declaring a penetration fire barrier functional following repairs er maintenance.

Basis During periods of time when the barriers are not functional, a continuous fire watch is req_uired to be maintained in the vicinity of the affected barrier u."ltil the barrier is restore::i to functional status.

4-80 PROPOSED