0CAN019012, Forwards Response to Generic Ltr 89-13, Svc Water Sys Problems Affecting Safety-Related Equipment. Svc Water Integrity Program Will Ensure That Required Design Performance of Svc Water Sys Maintained

Forwards Response to Generic Ltr 89-13, Svc Water Sys Problems Affecting Safety-Related Equipment. Svc Water Integrity Program Will Ensure That Required Design Performance of Svc Water Sys Maintained

ML20006B723
Person / Time
Site:	Arkansas Nuclear
Issue date:	01/26/1990
From:	James Fisicaro ARKANSAS POWER & LIGHT CO.
To:	NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
0CAN019012, CAN19012, GL-89-13, OCAN19012, NUDOCS 9002050293
Download: ML20006B723 (27)

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ARKANSAS POWER & tJGHT COMPANY January 26, 1990 BCAN019012 U. S, Nuclear Regulatory Commission Document Control Desk Mail Station P1-137 Washington, DC 20555

Subject:

Arkansas Nuclear One - Units 1 & 2 Docket Nos. 50-313 and 50-368 License Nos. DPR-51 and NPF-6 Response to Generic Letter 89-13. " Service Water System Problems Affecting Safety-Related Equipment" Gentlemen:

Generic Letter 89-13, " Service Water System Problems Affecting Safety-Related Equipment," requires licensees to supply information.about their service water systems to ensure the NRC of compliance with the General Design Criteria and requirements for quality assurance in 10 CFR, Part 50, Appendix B (in particular Section XI,." Test Control"), and to confirm that the safety functions of their service water systems are being met.

The-Generic Letter was transmitted to AP&L in the NRC's letter of July 18, 1989 (BCNA078922).

Arkansas Power and Light (AP&L) 'as an extensive Service Water Integrity Program already in effect.

This-program was established in 1986 to combine our programs for macroscopic biologicts fouling and corrosion of the Service Water System and has been expanded to account'for other problems (i.e., silt, etc.).

In response to Generic Letter 89-13, AP&L plans to expand our existing Service Water Integrity Program (SWIP) to encompass the objectives of this Generic letter.

There are two categories of actions required by the Generic Letter:

1) specific one-time actions, and 2) ongoing activities to ensure the continued operability of the Service Water System.

AP&L's response specific one-time actions are provided in Attachment 1, our response;to the to tha ongoing activities is provided in Attachment 2.

The current SWIP Program Document which includes those programatic actions' related to GL 89-13 is included as Attachment 3.

The.SWIP had already

' implemented most of the routine actions required by GL 89-13.

Additional actions were those' activities necessary to address thermal performance monitoring. Attachment 4 to this letter provides tables listing the applicable service water coolers and. delineates the test method planned for both initial testing and retesting efforts.

The schedules for implementing the SWIP actions are provided in the Attachments 1 and 2 to p

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this letter.

O 9002050293 900126 P

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-January 26, 1990

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The SWIP will ensure the required design performance of the Service Water a

System is maintained.

Should you or your staff have questions regarding i

this response, please do not hesitate to call.

Very truly yours, 4-

..r.) d i.c -

1 Jame

. Fisicaro Manag r, Licensing JJF/ CWT /1g Attachments

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cc:

Mr. Robert Martin 4

U. S. Nuclear Regulatory Commission i

Region IV i

611 Ryan Plaza Drive, Suite 1000 Arlington, TX 76011 NRC Senior Resident Inspector i

Arkansas Nuclear One - ANO-1 & 2

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Number 1 Nuclear Plant Road Russellville,AR72801 t

)

Mr. Thomas W. Alexi -

'NRRProjectManager,

>gion IV/ANO-1 U. S. Nuclear Regulat-iy Commission i

NRR Mail Stop 13-D-18

.i One White Flint North i

11555 Rockville Pike Rockville, Meryland 20852 i

Mr. Chester Poslusny

' i NRR Project Maniger, Region IV/ANO-2 1

U. S.' Nuclear Regulatory Commission NRR Mail Stop 13-D-18 One White Flint North i

11555 Rockville Pike i

Rockville, Marylan'd 20852:

a Mr. C. Vernon Hodge NRR/0GCB

'U. S. Nuclear Regulatory Commission j

NRR Mail Stop'11-A-1 (Room 11F9)

One White Flint North 11555 Rockville Pike Rockville, Maryland 20852 1

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STATE OF ARKANSAS

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SS COUNTY OF POPE

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I, James J. Fisicaro, being duly sworn, subscribe to and say that I am Manager, Licensing for Arkansas Power & Light Company; that I have full authority to execute this oath; that I have read the document numbered PCAN019012 and know the contents thereof; and that to the best of my knowledge, information and belief the statements in it are true, f# d5 5 Jame J. Fisicaro SUBSCRIBED AND SWORN TO before me, a Notary Public-in and for the County and State above named, thisd day of b f)711 A AlJm, l

1989.

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My Commission Expires:

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s ATTACHMENT 1 SPECIFIC,ONE-TIME ACTIONS I.

4 Recommendation I - Biofouling Control "For open-cycle service water systems, implement and maintain an ongoing program of surveillance and control techniques to significantly-reduce the incidence of flow blockage problems as a result of biofouling.

A program acceptable. to the NRC is described in " Recommended Program to Resolve Generic Issue 51" (Enclosure 1).

It should be noted that Enclosure 1 is provided as guidance for an acceptable program.

An equally effective program to preclude biofouling would also be acceptable.

Initial activities should be completed before plant startup following the first refueling outage beginning 9 months or more after the date of this letter.

All activities should be documented and all relevant documentation should be retained in appropriate plant records."

Response

AP&L took comprehensive corrective action to establish biofouling control in response to biofouling problems at Arkansas Nuclear One in 1980.

These actions meet the intent of Generic Issue 51 and are discussed in more detail-in Attachment 2.

They include chlorination, inspection and cleaning and-periodic flow tests.

Recommendation II - Thermal Performance

" Conduct a test progtam to verify the heat transfer capability of all' safety-related heat exchangers cooled by service water. -The. total test program should consist of an initial test program and a periodic retest program.

Both the initial test program and the periodic retest program a

should include heat exchangers connected to or cooled by one or more open-cycle systems as defined above.

Operating experience'and studies indicate that closed-cycle service water systems, such as component cooling water systems, have the potential for significant fouling as a consequence of aging, related in-leakage, and erosion'or corrosion.

The need for testing of closed-cycle system heat exchangers has not been considered.

necessary because of the assumed high quality of existing chemistry control programs.

If the adequacy of these chemistry control-programs cannot be confirmed over the total operating history of'the plant or. if during the conduct of the total testing program any unexplained downward trend in heat exchanger performance is identified that cannot be remedied by maintenance of an open-cycle system, it may be necessary to-selectively extend the test.

program and the routine inspection and maintenance program addressed in Action III, below, to.the attached closed-cycle systems."

Response

This specific one-time action recommended by GL 89-13 (related to' thermal performance) is an " initial test program" which will verify the heat transfer capability of all safety-related heat exchangers cooled by service water., Table 1 indicates the method to be used to verify the heat' transfer capability for each safety related heat exchanger.

The " Heat Transfer" method will be a determination-of the actual overall heat transfer coefficient or fouling factor for the heat exchanger..- Thi s

.. will be obtained by calculation based on measuring the hot fluid 1-l'

temperatures into and out of the exchanger, and the fluid flow rate.

The test results will be adjusted to account for any parameters which differ from the design base accident conditions (i.e. service water or air cooler

. temperature) and will account for instrument inaccuracies.

Acceptable tests will indicate an actual fouling factor less than that allowed by the DBA assumptions or a overall heat transfer coefficient greater than the DBA assumptions.

The " Thermal Effectiveness" method referenced in Table 1 will be a determination of the actual heat transfer effectiveness of either the hot or the cold fluid.

This will be obtained by calculation based on measuring the hot fluid temperatures into and out of the exchanger and the cold fluid temperatures into and out of the exchanger.

The test results will be adjusted as discussed above.

The as-measured thermal effectiveness will be acceptable if it exceeds the thermal effectiveness required to satisfy DBA heat removal-requirements.

' Thermal performance data will not be taken for pump seal / lube oil coolers or chiller condensers as listed in Attachment 4.

The alternative of " periodic maintenance" will be performed.

This " periodic maintenance" will consist of disassembly, if required, and inspection of the exchanger at intervals as deterinined by inspection results.

In addition, appropriate data (i.e. bearing temperature or condensing temperature) from each functional surveillance will be trended to determine if the heat exchanger's performance is degrading.

Heat exchangers which are a part of the SW system boundary, but are not credited for heat transfer capability'no test required" in Table 1.

for a safe reactor shutdown or accident response, are indicated as Addition 61 permanent and test instrumentation will be required to obtain the performance data required to perform either the " heat transfer" or " thermal effectiveness" analysis.

In addition, due to the normally low differential temperatures across many coolers with ambient or normal _ operating conditions, temporary heat loads may be required to simulate DBA conditions and/or obtain data with an acceptable level of instrument error, The additional instrumentation will be purchased and installed and thermal t

l performance measurements completed for Unit 2 prior'to restart after.the eighth refueling outage, 2R8, currently scheduled for Spring of 1991.

The additional instrumentation will be purchased and' installed and thermal performance measurements completed for Unit 1 prior to restart after the tenth refueling outage, 1R10, currently scheduled for Spring of 1992.

This schedule is consistent with that recommended by the Generic Letter.

AP&L had previously planned to chemically clean appropriate portions of.the ANO-1 SW system during the ninth refueling outage,1R9, currently scheduled for Fall of 1990.

Verification that the chemical cleaning has. removed SW heat exchanger fouling and returned the system to a clean condition will be performed.-

Inspection of the air. side of-room coolers will be performed to verify thet the air side is clean.

Thermal performance measurements during 1R9 will be taken only for the heat exchangers not chemically cleaned l

or which cannot'be inspected on the hot fluid' side.

This combination of l

cleaning, inspection, and testing will ass'ure that the SW system is performing l

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as designed and that design heat removal capacity exists in the system.

This is considered an acceptable alternative to collecting performance data for this cycle of operation.

This alternative was discussed during the NRR sponsored meeting to clarify GL 89-13 implementation requirements held in Denver, Colorado on December 7, 1989 and is considered acceptable.

Retest is discussed in Attachment 2.

The remainder of the initial thermal performance measurements will be completed prior to restart after the tenth refueling outage for Unit 1, 1R10.

Recom'nendation III - Dearadation Control

" Ensure by establishing a routine inspection and maintenance program for open-cycle service water system piping and components that corrosion, erosion, protective coating failure, silting, and biofouling cannot. degrade the performance of the safety-related systems supplied by service water.

The maintenance program should have at least the following purposes:-

A.

To remove excessive accumulations of biofouling agents, corrosion products, and silt; 8.

To repair defective protective coatings and corroded service water system piping and components that could adversely affect performance of their intended safety functions.

This program should be established before plant startup following the first refueling outage beginning 9 months after the date of this letter.

A description of the program and.the results of these maintenance inspections should be documented.

All relevant documentation should-be' retained in appropriate plant records."

Response

As there are no specific one-time actions for. this recommendation, AP&L's response to these recommendations is provided in Attachment 2.-

Recommendation-IV - As-Built Verification

" Confirm that the service water system will perform its intended function in accordance with the licensing basis for the plant, Reconstitution of the; design basis of the system is not intended.

This confirmation should include a review of the ability to perform required safety functions'in the s

event of failure of single active component.

To~ ensure that the as-built ~

system is in accordance with the appropriate licensing basis. documentation,'

this confirmation should include recent (within the past 2 years) system-walkdown inspections. -This confirmation should be completed before= plant startup following the first refueling outage.beginning 9 months or morel after the date of this letter.

Results should be documented ~and retained in appropriate plant records."

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Response

The as-built configuration of the system will be verified to match the design basis of the system as defined by the Safety Analysis Report, Safety Evaluation Report' Technical Specification, and other relevant licensing documentation.

Aphys}calwalkdownwillbeperformedtoverifythisconfiguration.'Recently completed electrical verifications of power supplies and control logics and surveillance tests intended to verify Engineered Safeguards actuations will'be referenced, as well as the physical walkdown in the confirmation of the design basis.

An analysis of single failure mechanisms will be completed to assure the as-built configuration is consistent with-the single failure licensing basis.

This will be completed prior to restart after the ninth refueling outage for Unit 1, IR9, and the eighth refueling outage for Unit 2, 2R8.

Recommendation V - Procedares and Training

" Confirm that maintenance practices, operating and emergency procedures, and training that involves the service water system are adequate to ensure that i

safety-related equipment cooled by the service water system will function as -

-intended and that operators of this equipment williperform effectively.

l This confirmation should include recent (within the past 2 years) reviews of practices, procedures, and training modules.

The intent of this action is to reduce human errors in the operation, repair, and maintenance of the service water system.

This confirmation should be completed before plant startup following the first refueling outage beginning 9 months or more after the date of this letter.

Results should be documented and retained in appropriate plant records."

Response

Maintenance, operating and emergency procedures directly related to the SW system will be reviewed to ensure the SW system will function as intended j

and that the operation of this equipment can be performed effectively.

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will include a review of the following procedures:

system operating, alarm -

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response, emergency operating, corrective maintenance, preventive maintenance, in-service inspection testing and serveillance.

The SWIP will be updated

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upon completion of this review to incorporate a listing,of procedures which maintain and verify the safety-related capability of the systemi This review will be completed and a report' issued prior to restart following the eighth refueling outage for Unit 2, 2R8, and the ninth refueling outage for Unit 1, IR9.

Any. additional surveillance or preventive maintenance actions identified as required by this review, or any revisions to existing actions identified by this review, will' be completed prior to restart following the tenth refueling outage'for Unit 1, 1R10,.and the ninth refueling outage for Unit 2,- 2R9.

After completion of the as-built verification and procedure reviews, appropriate training modules will be reviewed to assure'they are consistent with the aforementioned procedures and practices, accurately reflect-the licensing basis, and provide adequate instruction.

Any required modifications to the training, modules identified as a result of this review will be' t

implemented prior to restart.following the tenth refueling outage for Unit 1, 1R10, and the ninth: refueling outage for Unit 2, 2R9.

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e ATTACHMENT 2 ONGOING PROGRAMS l-A E=-

o Recommendation I - Biofouling Control i

The recommendation numbers and text are the same as for Specific One-Time Actions and are not repeated in this Attachment.

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Response

4 The~ recommended actions in Enclosure 2 of NRC GL 89-13 for surveillance and control of biofouling are existing elements of the AN0 SWIP.

Included in

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the program are the following:

i A.

Visual inspection and cleaning, as necessary, of the SW intake structure each refuelin outage.

Item 1 of Non-Destructive Examination in SWIP (Attachment 3.

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B.

Chlorination of the SW system to prevent biofouling.

Item 1 of Corrosion Monitoring and Water Treatment in SWIP (Attachment 3).

C.

Periodic flow tests of safety-related heat exchangers cooled by SW and routine flush of normally stagnant SW pipe sections.

Items 1, 5 &

8 of Testing in SWIP (Attachment 3).

It should be noted that studies are currently' underway to determine if a treatment other than chlorine would be as effective as a biocide,-yet less corrosive to SW materials.

The recommendations of GL 89-13 will be included in this consideration.

If an alternative biocide is chosen, the NRC will be made aware of this decision.

Recommendation II - Thermal Performance

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Response

l Thermal performance monitoring as required by Recommendation II has been added to the SWIP as Item 2 of " Testing" and Items 1 and 4 of " Maintenance" (Attachment 3).

Retest periodicity will-be determined from as-found test i

L data, as appropriate.

The routine retest program will commence immediately after the initial test of a component.

Retest procedures will be-developed from the initial test program documents., Table 2 indicates the retest methodology to be used and the "like" heat exchangers where-sampling or selective retest of the most limiting component will be-utilized.

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As discussed in Attachment 1, the initial test action, pump seal / lube oil.

f coolers-and chiller condensers will not be measured for thermal performance.

These coolers will be inspected periodically as determined by inspection-data.

In addition, appropriate aump parameters (i.e. bearing temperatures or condensing temperature) will ae trended.

Heat exchangers which are a part of the SW system boundary, but are not credited for heat transfer capability for a safe reactor shutdown or t

accident response are indicted as "no test required."

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Recommendation III - Degradation Control

Response

The recommanded actions in NRC GL 89-13 for surveillance and control of SW I

component degradation are existing elements of the SWIP.'

Included in the i

program are the following:-

i A.

- Periodic ultrasonic thickness mapping of SW p.iping.

Item 2 of NDE.in l

SWIP:(Attachment 3).

B.

Routine inspection of heat exchangers and valves.

Item'3 of NDE in SWIP (Attachment-3).

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.C.

Periodic inspection of the epoxy coated ANO-1 Emergency Cooling Pond--

return line.

Item 4 of NDE in SWIP (Attachment 3).

a D.

Periodic. flow test of all safety-related' components cooled by SW'and routine flushes of normally stagnant pipe sections.

Items 1, 5 and 8 of Testing in SWIP.

A Recommendation IV - As-Built Verification

Response

There are no ongoing programs' recommended for as-built verifications.

Recommendation V - Procedures and Training

Response

l There are no ongoing programs recommended for review of procedures and-training modules.

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1 ATTACHMENT 3 PROGRAM DOCUMENT-FOR SWIP;LONG-TERM PROGRAM PLANSn

' NOTE THE FOLLOWING: INTERNAL PROGRAM DOCUMENT IS PR';VIDED.

FOR INFORMATION ONLY.

THIS PROGRAM REPRESENiS fHE?

OVERALL SERVICE WATER PLAN, PORTIONS OF WHICH ARE,

COMMITTED.TO'IN THE PROCEDING SECTIONS TO SATISFY REGULATORY REQUIREMENTS,

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PROGRAM DESCRIPTION' j

AND SERVICE WATER SYSTEM INTEGRITY PROGRAM 1

PROGRAM OBJECTIVES 1.

To ensure the ANO Service Water (SW) systems continue to operate and perform their safety-related functions for.the remaining life of the plants.

2.

Tc improve the availability, reliability, and safety margin of the ANO l

SW systems.

3.

To provide for the' advance planning, scheduling, and_ budgeting of AND I

SW system maintenance, modifications, testing and inspection.

4.

To maintain involvement in industry-wide programs and issues.

ORGANIZATION i

Administration of the SWIP will be carried out by Plant Engineering.

This will include providing the SWIP chairman, conducting meetings, issuing periodic status reports and interfacing with other utilities, EPRI and other appropriate outside organizations.

The SWIP committee will consist of a t

representative from the following AP&L organization:

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Mech / Civil / Structural Design Engineering 2.

Units 1 &'2 Maintenance 3.

Units 1 & 2 Operations l

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Units-1 & 2 Outage Management 5.

Modifications i

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Chemistry and Radiation Chemistry The SWIP committee will provide input for development and status of the i

SWIP.

Long-term program plans and short-termLspecific action-plans will be first reviewed and approved by the committee, then presented to the managers

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L of the represented organizations for approval-Final approval will be by the Director, Nuclear Operations.

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The'SWIP committee will' meet, as a minimum, after each refueling outage to:

review the.long-term program plans,' document work ' accomplished during the.

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preceding outage and develop an action plan for the next: refueling outage, j

Action plans will be maintained for each refueling outage-. for each unit and for

_i each calendar' yea.r for non-outage actions.

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TESTING Tests are performed to verify that the SW system is capable of functioning as designed.

The tests are as-follows:

1..

Flow tests of safety-related heat exchangers cooled by SW are performed each refueling outage.

The most restrictive hydraulic lineup is tested and acceptance criteria includes margin above minimum flow requirements to account'for instrument error and potential degradations, including' pump degradation, strainer clogging, and hydraulic degradations.

2.

Heat transfer performance tests of safety-related heat exchangers cooled by SW will be performed after the initial tests recommended by NRC Generic Letter 89-13 are completed.

These tests will provide for trending of heat exchanger therma 1' effectiveness or fouling factors to identify when corrective action to restore heat transfer capability is required.

Procedures for the retest program will be generated after the initial testing is completed and will be based upon the initial test program.

3.

Measurement of pressure drops across coolers and pipe sections are routinely taken when performing flow tests. This data is used as input into the SW hydraulic computer model (currently under development) to assist with evaluation of system performance.

Data points are included as part of testing procedures.

4.

Pump performance is measured in accordance with ASME Section XI in-service testing requirements for SW pumps P4A,B,C.and 2P4A,B,C.

Tests are performed in accordance with procedures on a quarterly basis and on a monthly basis, as appropriate.

5.

Flushing, chlorination, and verification-of minimum flow requirements for the Reactor Building Coolers VCC2A,B,C,0 for Unit 1 and the Containment Coolers 2VCC2A,B,C,D for Unit 2 is completed on a bi-weekly basis, in accordance with operations procedures.

6.

Procedures provide for verification that maxi'num allowable leakage requirements are not exceeded by This is performed each refueling,the sluice gates in the SW intake structures.

outage.

7.

Response time to reach minimum flow for containment cooling upon receipt of a Containment Cooling Actuation signal is verified each refueling outage for Unit 2 by appropriate procedure.

8.

Normal operating stagnant portions of the SW system are flushed periodically.

Specific procedures are provided for-flushing.

9.

SW response to Engineered Safety Features actuation is verified each refueling outage by plant procedures.

This includes Safety Injection Actuation Signal, Containment Cooling Actuation Signal, Containment Isolation Actuation Signal, and Containment Spray Actuation Signal.

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10.

System parameters indicative of SW heat exchanger or other SW component performance, including pump surveillance data (bearing temperatures),

i SW header differential pressures, and cooler differential pressure-l versus flow, will be trended and analyzed.

l NON-DESTRUCTIVE EXAMINATION Periodic inspections of the SW systems are conducted to identify and l

quantify the. effects and mechanisms of corrosion, erosion, and fouling..

These inspections consist of the following:

1.

The SW intake structure and sluice gates are inspected and' cleaned as I

required.

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'2.

Mapping of pipe thickness at selected locations with computerized i

ultrasonic equipment is periodically performed and trended.

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Visual inspection of a sample of the safety-related heat exchangers and valves is performed each refueling outage.

The cample includes a majority of the components that have a "high likelihood" of corrosion i

fouling or degradation, as well as a sample of other components.

"High likelihood" valves are determined using Engineering Report 86E-0014.as a guideline.

4.

The epoxy coating internal to the Emergency Cooling Pond; return line is-i inspected once each operating cycle.using a remote video camera.

5.

The-level of water in the ECP is verified on a daily basis and recorded in operations log.

The ECP is sounded and.the riprap visually inspected on an annual basis to verify that sufficient water inventory is available as required for depth verification.

CORROSION MONITORING AND WATER TREATMENT l

Corrosion monitoring is performed to assist'in the evaluation of' actions required to appropriately maintain the SW systems. ' Water treatment is i

utilized to control biofouling and to help mitigate microbiological induced corrosion.

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.The SW system is chlorinated to prevent macrobiological fouling.1.This is primarily oriented to prevent the growth of Asiatic clams wi. thin the i

i SW system.. Chlorination also prevents algae growth.and helps reduce.

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the effects of microbiologically induced corrosion. LThis is in 1

accordance with procedures and Safety Analysis Reports for_ Unit 1 and' l

Unit'2.

Note:

Other methods of macrobiological-fouling control are

- currently under investigation.

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i 2.

A side-stream corrosion rack is being installed and will be utilized for the,following:

a.

Determination of corrosion rates for various in-service and-proposed materials, b.

Evaluation of different layup procedures for piping and heat exchangers.

c.

Evaluation of different chemical t'reatments for SW to better control biological fouling and reduce corrosion and deposition.-

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Determination of fouling rates for heat exchangers and possible j

preventive and corrective actions.

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Random samples.taken from in-service components and failed components 4

will be analyzed to determine active degradation mechanisms.

h MAINTENANCE t

' Routine preventive maintenance is performed to reduce or eliminate system-degradation and assure the operation of active components.

i 1.

Pump seal and lube oil coolers will be flushed at a frequency commensurate with the data taken.

This will prevent a buildup of silt' or corrosion products in the coolers.

i 2.

Low point drains,' pressure points and vents will be flushed out at-1 least once per operating cycle using normal system pressure.

3.

The SW pumps (P4A,B,C and 2P4A,B,C) will be maintained in accordance with preventive maintenance tasks.

t 4.

SW supplied pump seal / lube oil coolers, chiller condensers, and post-accident sampling coolers will be disassembled if necessary and inspected each refueling outage.

5.

Small bore piping clam strainers are flushed periodically during l

operations, thus eliminating macrobiological~ fouling..

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3 RESTORATION ACTIVITIES j

Restoration activities-to correct deficiencies will be initieted when their.

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need is identified by. testing, non-destructive examination or.other.

trending.

System mechanical or chemical cleaning will be directed by Plant Engineering.

Replacements and improvements will be completed. utilizing.the normal methods for controlling such work.

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ATTACHMENT 4 TABLES DELINEATING' INITIAL TEST METHODS AND; RETEST METHODS FOR SERVICE WATER. COOLERS"'

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' NOTE AS CONDITIONS ~AND-TESTS DICTATE; TEST

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METHODS MAY-BE. MODIFIED-

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4 TABLE 1-UNIT 1 SW THERMAL PERFORMANCE MONITORING INITIAL TESTS COOLER #

COOLER DESCRIPTION TEST METHOD VUCIA Decay Heat Room Cooler Thermal Effectiveness VUC1B Decay Heat Room Cooler Thermal Effectiveness VUCIC Decay Heat Room Cooler Thermal Effectiveness VUC1D Decay Heat Room Cooler-Tiermal Effectiveness VUC7A Makeup Pump Room Cooler Ttermal Effectiveness VUC7B Makeup Pump Room Cooler Tt ermal' Effectiveness VUC7C Makeup Pump Room Cooler Tiermal Effect'iveness E47A RB Spray-Pump Jacket Cooler Feriodic Maintensnce E47B RB Spray Pump Jacket-Cooler Periodic Maintenance E50A Decay Heat Pump Jacket Cooler

. Periodic Maintenance E50B Decay Heat Pump Jacket Cooler Periodic Maintenance E39A Makeup Pump Lube Oil Cooler Periodic. Maintenance E39B Makeup Pump' Lube 011 Cooler Periodic Maintenance' E39C Makeup Pump Lube Oil Cooler Periodic Maintenance E35A Decay Heat Removal Heat Exchanger Heat Transfer-E35B Decay Heat Removal Heat Exchanger Heat Transfdr E20A1,A2 Emergency Diesel Generator Coolers Heat Transfer E20B1,82 Emergency Diesel Generator Coolers Heat-Transfer-

.VCH4A Emergency Switchgear Chiller Condenser Periodic Maintenance..

VCH4B Emergency Switchgear Chiller Condenser Periodic Maintenance VCC2A RB Coolers Heat Transfer VCC2B RB Coolers Heat Transfer VCC2C RB Coolers Heat Transfer VCC2D RB Coolers Heat Transfer l

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1 TABLE 1 UNIT 2 SW THERMAL PERFORMANCE MONITORING INITIAL-TESTS f

COOLER #

COOLER DESCRIPTION' TEST METHOD 2VUCIA Shutdown Cooling Room Cooler Thermal Effectiveness 2VUC1B Shutdown Cooling Room Cooler Thermal Effectiveness'

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2VUCIC Shutdown Cooling Room Cooler Thermal Effectiveness 2VUC1D Shutdown Cooling Room Cooler Thermal Effectiveness 2VUC1E Shutdown Cooling Room Cooler

- Thermal Effectiveness 2VUCIF Shutdown Cooling Room Cooler Thermal Effectiveness 2VUC2A Emergency Switchgear Room Cooler.

No Test Required 2VUC2B Emergency Switchgear Room Cooler No' Test Required

[

2VUC2C Emergency Switchgear Room Cooler No Test Required l

2VUC2D Emergency Switchgear Room Cooler No Test Required 2VUC6A Emergency Feedwater Pump Room Cooler Thermal Effectiveness-2VUC6B Emergency Feedwater Pump Room Cooler Thermal Effectiveness 2VUC7A Charging Pump Room Cooler No Test Required 2VUC7B Charging Pump Room Cooler' No-Test Required l

2VUC7C Charging Pump Room Cooler No Test Required 2VUC11A HPInjectionPumpRoomCooler Thermal Effectiveness 2VUC11B HPInjectionPumpRoomCooler Thermal Effectiveness 2VUC19A Emergency Switchgear Room Cooler No Test Required-l 2VUC19B Emergency Switchgear Room Cooler No Test Required l-2VUC20A Emergency Switchgear' Room Cooler Thermal Effectiveness 1

L 2VUC20B Emergency Switchgear Room Cooler' Thermal Effectiveness t

2E47A Containment Spray Pump-Seal Cooler Periodic Maintenance.

f 2E478 Containment Spray Pump Seal Cooler Periodic Maintenance j

2E52A LP Injection Pump Seal Cooler Periodic Maintenance L

2E52B LP Injection. Pump Seal Cooler

- Periodic Maintenance.

l IE53A HP Injection Pump Seal /011 Coolers No Test Required i

2E53B HP Injection Pump Seal /011 Coolers No Test Required

[

2E53C HP Injection Pump Seal /011 Coolers No Test Required i

.4-2 i

w +,

t

TABLE I (Cont'd)

UNIT _2 - INITIAL TESTS i

5 COOLER #

COOLER DESCRIPTION TEST METHOD 2E35A Shutdown Cooling Heat Exchanger Heat Transfer-2E358 Shutdown Cooling Heat Exchanger

. Heat Transfer 2E20A Emergency DG Jacket Coolant Cooler.

Heat fransfer 2E208

-Emergency DG Jacket Coolant Cooler Heat Transfer i

2E63A Emergency DG Lube Oil Cooler Heat Tran,fer 2E63B Emergency DG Lube' Oil-Cooler Heat Transfer' 2E64A Emergency'DG Air Coolant Cooler Heat Transf'er.

2E64B Emergency DG Air Coolant Cooler Heat Transfer 2E86 Post-Accident Sampling Cooler Periodic Maintenance 2E87 Post-Accident Sampling Cooler Periodic Maintenance 2VCC2A Containment Cooler Heat Transfer ~

2VCC2B Containment Cooler Heat Transfer =

i 2VCC2C Containment Cooler Heat Transfer I

2VCC2D Containment Cooler.

Heat Transfer 2VEIA Emergency Control Rm Chiller Condenser.

Periodic Maintsnance 2VElB Emergency Control Rm Chiller Condenser Periodic Maintenance.

[

2E530 HP Injection Pump Seal /0il: Cooler No Test Required 2E53E HP Injection Pump Seal /011 Cooler No Test Required i

2E53F HP Injection Pump Seal /011 Cooler-No Test Required o

i i

s f

p i

4-3.

Ij a

3

^

~

~

4 s

TABLE 2 UNIT 1 SW THERMAL 9ERFORMANCE MONITORING RETEST METHOD COOLER #

COOLER DESCRIPTION TEST METHOD:

VUCIA Decay Heat Room Cooler Thermal Effectiveness -

Sample One of Four VUCIA,B,C or D VUCIB Decay Heat Room Cooler Thermal Effectiveness'-

Sample One of Four-VUCIA,B,C or D VUCIC Decay Heat Room Cooler Thermal Effectiveness -

Sample One of-Four.

VUC1A,B,C or D VUCID Decay Heat Room Cooler

-Thermal Effectiveness Sample One of Four VUCIA,B,0 or D VUC7A Mak ap Pump Room Cooler Thermal Effectiveness -

Sample One-of Three VUC7A,B or C VUC78 Makeup Pump Room Cooler Thermal Effectiveness -

~ Sample One ofoThree

'VUC7A,8 or C VUC70 Makeup Pump Room Cooler Thermal Effectiveness -

Sample One of Three

=VUC7A,B or C' E47A RB Spray Pump Jacket Cooler Periodic Maintenance E478 RB Spray Pump Jacket CoolerL Periodic Maintenance-L'~

E50A Decay Heat Pump Jacket. Cooler Periodic Maintenance-l E50B Decay. Heat Pump-Jacket Cooler Periodic-Maintenance:

E39A Makeup Pump Lube 011 Cooler Periodic. Maintenance l-

_ E39B Makeup Pump Lube.011 Cooler!

Periodic Maintenance E39C Makeup Pump Lube Oil Cooler Periodic. Maintenance E35A Decay Heat Removal Heat Exchanger

- Heat Transfer E35B Decay Heat Removal Heat ExchangerL Heat-Transfer 4-4

F g

r a

g-4 TABLE 2 (Cont'd)

UNIT 1 - RETEST METHOD COOLERf COOLER DESCRIPTION TEST METHOD.

E20A1,A2 Emergency Diesel Generator Coolers Heat. Transfer.

E2081,82 Emergency Diesel' Generator Coolers Heat Transfer-

~

VCH4A Emergency Switchgear Chiller Condenser Periodic Maintenance VCH4B Emergency,Switchgear Chiller Condenser Periodic Maintenance VCC2A Reactor Building Coolors:

Heat = Transfer -

Sample One of Four.

VCC2A,B,C or D-VCC2B Reactor Bui! ding Coolers.

. Hiat Transfer -

Sample One of Four VCC2A,B Ctor Dl-VCC2C Reactor Building Coolers

' Heat Transfer -

~

Sample'One of Four

' VCC2A,B,C or Da VCC2D Reactor Building Coolers Heat'-Transfer Sample One of Four VCC2A,B,C or.0.

1.w 1

f b

4-5 l

3 3

. s.

TABLE 2 UNIT 2 SW THERMAL PERFORMANCE MONITORING RETEST METHOD COOLER #

COOLER DESCRIPTION TEST METHOD-2VUCIA Shutdown Cooling Room Cooler Thermal Effectiveness --

Sample One of Eight.

2VUC1A,B,C,D,E,F or 2VUC11A or B 2VUC1B Shutdown Cooling Room Cooler-

_ Thermal Effectiveness -

Sample One.of Eight:

2VUCIA,B,C,D,E,F or' 2VUC11A or B 2VUCIC Shutdown Cooling Room Cooler Thermal Effectiveness -

Sample One of Eight 2VUCIA,B,C,D,E,F or 2VUC11A or B' 2VUCID Shutdown Cooling Room Cooler Thermal Effectiveness

~

Sample One of.Eight

'2VUCIA,B,C,0,E,F or.-

2VUC11A or B:-

l 2VUC1E Shutdown Cooling Room Cooler

- Thermal: Effectiveness -

L Sample One of Eight J2VUCIA,B;C,0,E,For-

'2VUC11A or 8

-- i t 2VUC1F

_ Shutdown Cooling Room Cooler Thermal Effectiveness -

Sample One of Eight:

2VUC1A,B,C,D,E,F orL l-2VUC11A or B 4-6 L.-

i t

l TABLE 2 (Cont'd) a

- UNIT 2 - RETEST METHOD -

4 COOLER #

COOLER DESCRIPTION

. TEST METHOD.

2VUC2A.

Emergency switchgear Room Cooler No Test Required 2VUC2B Emergency Switchgear Room Cooler No_ Test Required-2VUC2C Emergency Switchgear Room Cooler No Test Required.

2VUC2D Emergency Switchgear Room Cooler No-Test Required 2VUC6A Emergency Feedwater Pump Room Cooler Thermal. Effectiveness -

Sample'One~of.Two 2VUC6A or B.

2VUC6B Emergency Feedwater Pump Room Cooler.

Thermal Effectiveness -

Sample One of.Two-2VUC6A'or'B, 2VUC7A Charging Pump Room Cooler No Test Required 2VUC7B Charging' Pump Room Cooler No. Test Required' 2VUC70-Cherging-Pump Room Cooler

No Test RequiredL i

B 2VUC11A HP injection. Pump Room Cooler See 2VUC1A l

2VUC11B HP injection Pump Room Cooler See'2VUCIA.

'.2VUC19A Emergency Switchgear Room Cooler No Test'Requi' red 2VUC198

. Emergency Switchgear Room Cooler No. Test Required 4-7' u

o 6-j e,

O TABLE 2 (Cont'd)

UNIT 2 - RETEST METHOD COOLER #

COOLER DESCRIPTION TEST METHOD 2VUC20A Emergency Switchgear Room Cooler

' Thermal' Effectiveness -

Sample One of:Two 2VUC20A.or B-2VUC20B Emergency ~Switchgear Room Cooler Thermal. Effectiveness.-

Sample One of Two 2VUC20A or B-2E47A Containment Spray Pump Seal Cooler Periodic Maintenance 2E478 Containment Spray Pump Seal Cooler--

Periodic Maintenance 2E52A LP Injection Pump Seal Cooler

' Periodic Maintenance.

2E528 LP Injection Pump Seal Cooler Periodic Maintenance 2E53A

'HP Injection Pump Seal /011 Coolers-

< No Test Required-2E53B HP Injection Pump Seal /011 Coolers

_No Test' Requiredi 2ES3C HP Injection Pump Seal /011 Coolers No; Test Required 2E35A Shutdown Cooling Heat Exchanger Heat Transfer ~

2E35B Shutdown Cooling Heat Exchanger Heat Transfer 2E20A Emergency DG Jacket Coolant Cooler Heat Transfer-2E20B Emergency DG Jacket; Coolant Cooler Heat Transfer--

l 4-8 t

6 L..

.$ ~ t i

TABLE 2 (Cont'd)

UNIT 2 - RETEST METHOD t

- l

' COOLER #

COOLER DESCRIPTION TEST METHOD 2E63A Emergency DG Lube Oil Cooler Heat Transfer I

I 2E63B Emergency DG Lube Oil Cooler

. Heat Transfer.

f 2E64A Emergency DG Lube Air Coolant Cooler Heat Transfer 2E64B.

Emergency DG Lube Air Coolant Cooler Heat Transfer 2E86 Post-Accident Sampling Cooleri

-Periodic Maintenance

i 2E87 Post-Accident Sampling Cooler Periodic Maintenance l

2VCC2A Containment Cooler

' Heat Transfer -

lI Sample One of FourL

' i

-2VCC2A,B,0 or D-a 2VCC2B Containment Cooler Heat: Transfer 1 '

j Sample One of-Four.

22VCC2A,B,C'or 0

]

2VCCiC Cont ament Cooler Heat Transfer -

Sample One'of;Four.

2VCC2A,B,C or D-

-j 2VCC2D Containment Cooler-Heat Transfer -

L Sample One of Fouri 2VCC2A,B,C or D-i 1

l<

I 4-9

I t

1

fl:

N.>

g....

r

. 7 0.-

TABLE 2 (Cont'd)

ONIT 2 - RETEST METHOD COOLER #

COOLER DESCRIPTION.

TEST METHOD.

o 2VEIA.

Emergency Control Rm Chiller Condenser Periodic Maintenance ~

2VElB-Emergency Control Rm Chiller Condenser Periodic Maintenance 2E53D HPInjectionPump. Seal /0il' Cooler

~ No. Test Required 2E53E HP Injection-Pump-Seal /011 Cooler No Test = Required 2E53F HP_InjectionPump. Seal /0ilCooler No Test Require'd S

t a

I f

l-5,

n 4

4 10.

m, r

l',,

EE--

I

'I

.