ML20003E652

Forwards Info in Response to NUREG-0737 Which Provides Updated Schedule Requirements & Implementation Status.Eccs Outage Rept for 1976-80 Encl

ML20003E652
Person / Time
Site:	Point Beach
Issue date:	03/31/1981
From:	Fay C WISCONSIN ELECTRIC POWER CO.
To:	Harold Denton Office of Nuclear Reactor Regulation
References
RTR-NUREG-0737, RTR-NUREG-737, TASK-2.K.3.17, TASK-TM NUDOCS 8104070547
Download: ML20003E652 (97)

Text

{{#Wiki_filter:t o O Wisconsin Electnc m cwn 231 W. MICHIGAN, P.O. 80X 2046. MILWAUKEE, WI 53201 March 31, 1981 !, a3 x ,,' y i / 's /) /[ I Mr. Harold R. Denton, Director [ b '.O Li)L i s b ' if Office of Nuclear Reactor Regulation U. S. NUCLEAR REGULATORY COMMISSION a ,,..,31 7 V, Washington, D. C. 20555

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Dear Mr. Denton:

'e { Q;/s A: DOCKET NOS. 50-266 AND 50-301 Ov[ RESPONSE TO NUREG-0737 UPDATE TO SCHEDULE REQUIREMENTS AND IMPLEMENTATION STATUS POINT BEACH NUCLEAR PLANT, UNITS 1 AND 2 This letter provides additional information related to the requirements of NUREG-0737, " Clarification of TMI Action Plan Requirements", for the Point Beadt Nuclear Plant, Units 1 and 2. This information includeo Revision 1 to our Schedule Table and Notes which provides schedule and implementation status, as of March 31, 1981. Each iten is addressed relative to the requirements and schedules stated in NUREG-0737 with clarifica-tion provided for those items completed, updated, or otherwise modified since our December 23, 1980 response. Your review of this response should be made with reference to prior Wisconsin Electric Power Company submittals. We have not repeated the pertinent Note referenced in the Schedule Table for those items whose status has not changed since our December 23, 1980 submittal. Additional attachments to the Schedule Table and Notes are included with this submittal. Certain engineering, construction, and training services required to complete several of the NUREG-0737 requirements are being performed by consultants and contractors. The completion date of these items and other items requiring plant modification is, of course, dependent on the contractor's and A the supplier's manufacturing schedule. Since all licensees are pOYb attempting to meet the same set of implementation dates, some 3 material and personnel shortages may well be unavoidabla. These j shortages may result-in some delays in implementation schedules //f which are beyond our control. l I 8104070547

+ r Mr. Harold R. Denton March 31, 1981 We would be pleased to respond to any questions you =ay have regarding this response. Very truly yours, a C. W. Fay, Director Nuclear Power Depart =ent Enclosures. Subscribed and sworn to before =e This 31st day of March, 1981. L..<, # -Notary Public, State of hisconsin My cc u issicn expires Copy to: NRC Resident Inspectot 4 ) f d !~

e e t POST-TMI REQUIREMENTS FOR OPERATING REACTORS Clcrifi-Implemen-PBNP

cation,

.tation Applica-PBNP Ittm~ ,Shortered Title Description-Schedule bility . Schedule Remarks I.A.1.1 Shift' Technical Advisor.l. On duty 1/1/80 -Yes complete On duty since 1/1/80 - Reference 1

2. Tech Specs 12/15/80 Yes Complete Reference 15 l

3. Trained per.LL 1/1/81 Yes Complete Note I.A.l.l.3 Cat B gg

.4. Describe'long-1/1/81 Yes Complete Note I.A.I l.4 term program t iI.A.1.2 Shift Supervisor Delegate.non-1/1/80 Yes Complete Reference 1 Responsibilities safety duties ~I. A.l. 3-Shift Manning

1. Limit'o"ertime 11/1/80 Yes Complete pBNP Approved Procedure 4.3, (1/10/81 Operations Division P

Implementa-Personnel Assignments and tion Date) Scheduling, Rev. 0

2. Min Shift Crew 7/1/82 Yes N.A.

Note I.A.l.3.2 I.A.2.1 Immediate Upgrading 1.-SRO Experience 5/1/80 Yes Complet$ of RO and SRO Training-2. SROs be'ROs 12/1/80 Yes

Complete, and Qualifications 1 yr

(

3. Three mo. trng 8/1/80 Yes Complete r Note I.A.2.1.1/4 on shift

4. Modify Training 8/1/80 Yes Complete

5. Facility 5/1/80 Yes Complete Note I.A.2.1.5 s

Certification I.A.2.3 L Administration of Instructors 8/1/80 Yes Complete Note I.A.2.3 , Training Programs Complete SRO Exam I.A.3.1 Revise Scope and '... Increase scope 5/1/80 Yes Complete Criteria'for Licensing 2. Increase passing 5/1/80 Yes Complete , Exams grade

3. Simulator exams 6/1/80 N.A.

Note I.A.3.1.3 N.A..= Schedule not applicable to PDNP TBD = To be determined -at 'a 'later date per the remarks (1) Devision 1 Ja:ed March 31, 1981.

9 a Clcrifi-Implemen-PBNP cation-tation Applica- .PBNP 'Itcm Shortened' Title-Description Schedule bility Schedule Remarks !I.C.1-Short-Term Accident and 1. SB LOCA 6/1/80 . Yes Completed ~ Procedures Review-

2.. Inadequate Core Cooling a.

Reanalyze 1/1/81 Yes Completed Generic procedures already and propose submitted to NRC 1 guidelines

b. Revise First

<es First Procedures refueling refueling outage after outage after 1/1/82 1/1/82

3. Transients and accidents Note I.C.1.3

a. Reanalyze 1/1/81 Yes Completed

,l1 and propose guidelines

b. Revise First Yes First procedures ~

refueling refueling outage after outage after 1/1/82 1/1/82 I.C.2 ' Shift and Relief Implement shift 1/1/80 Yes Completed Turnover Procedures turnover checklist I.C.3 Shift-supervisor" Clearly define 1/1/80 Yes Completed Responsibility superv and oper responsibilities I.C.4- ' Control-Room Access Establish authority 1/1/80 Yes Completed limit access I.C.5 Feedback of Operating Licensee to 1/1/81 Yes Completed PBNP Administrative implement (1/1/81 Procedure 3.15.7, Rev. O, procedures Effective approved '.2/19/8 0, Date) " Procedure for Feedback of Operating Experience to Plant Staff" N (1) Revision 1. dated March.31, 1981

e-i. r -Clcrifi-l fcation 'Implemon-PBNP s ta tion Applica-PDNP It m: ' Shortened Title Description Schedulo bility Schedule Remarks EI.C.6 , Verify. Correct "Roviso 1/1/01 Yes Completed PDNP Administrativo Perform.snce of performanco ' Operating Activities procedures Procedure 4.13, Rov. 9, offectivo 6/20/80, " Equipment Isolation Procedure" .I.D.1 , Control Room Design. Prelimi;,ary TilD Yes TBD Note 1.D.1 Reviews assessment and schedule for correcting deficiencies

1. D'. 2 Plant Safety Para-

1. Descripticn TBD Yes 7/1/01 motor Display Consolo (Projected) 2. Installed TDD Yes 1/1/83 (Projected) > Noto.I.D.2

3.. I'ull y TBD Yes 7/1/83 implemented (Projected)

II.B.1 '. Reactor. Coolant .1.-Design vents 7/1/81 Yes 7/1/81 System Vents 2. Install Vents 7/1/82 Yes 7/1/H2 .(LL Cat B)

3. Proceduros 1/1/82 Yes 1/1/82 II.B.2 Plant Shielding

1. Review designs 1/1/80 Yes Completed

2. Plant modifi-1/1/82 Yes 6/1/82 Note II.B.2.2 cations.(LL

{1 Ca t h) 3. Equipment 6/30/82 Yes 6/30/82 qualification 1 1. 11. 3 Post Accident S,ampling 1. Interim system 1/1/80 Yes Completed

2. Plant modif1-1/1/82 Yes 1/1/82 Note II.D.3 ca t. ion s (LL Ca t 15)

.(1) Revision'l dated March'31,-1981 l

b e Citrifi-Implemen-PBNP cation- . Description Schedule bility Schedule Remarks .tation. Applica-PBNP-It+m Shortened ~ Title-

II.B.4 Training for

1. Develop training 1/1/81 Yes Complet Mitigating Core Damage.

program 1 2. Implement (' Note II.B.4 program a. Initial 4/1/81 Yes-Complete c

b. Complete-10/1/81 Yes 10/1/81,j

~ l, II.D. l' _ Relief and Safety Valve 1. Submit program 1/1/80 Yes Completed Note II.D.1 Test Requirements'

2. RV.and SV Testing (LL Cat B)

a. Complete 7/1/81 Yes 9/1/81 Note II.D.l.2a testing

b. Plant-10/1/81 Yes 1/1/82 Note II.D.l.2b specific report

?

3. Block-Valve 7/1/82 Yes N.A.

Note II.D.l.3 testing II.D.3. Valve Position. 1.fInstall direct 1/1/80 Yes Completed Indication indications of e-valve position

2. Tech Specs 12/15/80 Yes Complete Reference 15 1

- II.E.1.1 Auxiliary Feedwater-

1. Shor t term 7/1/81 Yes TBD 1 Note II*E*1*1 Systen' Evaluation

2. Long term 1/1/82 Yes TLD f

' II.E.1.2 Auxiliary Feedwater 1. Initiation System Initiation

a. Control grade 6/1/80 Yes N.A.

and Flow

b. Safety grade 7/1/81 Yes Original References 1, 2, and 3.

Plant Design l

2. Flow Indication 1

~

a. Control grade 1/1/80 Yes Complete Note II.E.1.2 1

b. LL A Tech 12/15/80 Yes Complete Reference 15 1

Specs

c. Safety grade 7/1/81 Yes 7/1/81 J

(1)" Revision 1 dated March - 31, 1931 j L. m m

II l Clarifi-Implemen-PBNP cation tation Applica-PBNP Iten Shortened Title Description Schedule .bility Schedulo Remarks II.E.3.1 Emergency Power for

1. Upgrade power 1/1/80 Yes Original References 1, 2, and 3.

Pressurizer lleatets Plant Design

2. Tech Specs 12/15/80 Yes Completed Reference 15 1

II.E.4.1 Dedicated !!ydrogen

1. Design 1/1/80 Yee Original References 1, 2, and 3.

Penetrations Plant Design 2. Install 7/1/81 Yes N.A. II.E.4.2 Containment Isolation 1-4. Imp. diverse 1/1/80 Yes TBD Note II.E.4.2.1/4 Dependability isolation

5. Cntat pru;sure setpoint

a. Specify 1/1/81 Yes 1/1/81 6 psig pressure Note II.E.4.2.5

b. Modifi-7/1/81 Yes N.A.

cations

6. Cntmt purge 1/1/31 Yes Complated Administratively closed, valver.

7. Radia tion 7/1/81 Yes Original Plant Reference Point Ecach FFDSAB signal on design Section 4.2 and Fig. 5.2-8 purge valves

8. Tech Specs 12/15/80 Yes Completed Reference 15 3

II.F.1 Accident Monitoring

1. Noble gas 1/1/82 Yes 1/1/82*

Note II.F.1.1/2 'nonitor

2. Iodine /

1/1/82 Yes 1/1/82* Note II.F.1.2 2 particulate sampiing

3. Containment 1/1/82 Yes 1/1/82*

high-range monitor

4. Containment 1/1/82 Yes 1/1/82*

5. Containment 1/1/82 Yes 1/1/82*

water level

6. Containment 1/1/82 Yes TBD Note II.F.1.6 hydrogen

• Schedule is based on delivery of equipment on schedule.

(1) Revision 1 dated March 31, it 81 e 4

y,' m n Citrifi-Implemen. 'cntion tation Applica-PBNP It m - 'Shortenec Title Description Schedule bility Schedule Remarks II.F.2 . Instrumen ta tion. for. ..'l. Subcool meter 1/1/80 Yes Complete Note II.P.2.1 Detection of Inadequate 2.' Tech Spec 12/15/80 Yes Conplete Reference 15 1 ' Core Cooling (LL Cat A) 3. Install level 1/1/82 Yes '6/1/82* Note II.F.2.3 Anstruments (LL Cat B)- II.G.l' ' Power Supplies for

1. Upgrade to 1/1/80 Yes Original Pressurizer Relief.

emerg' sources Plant Design . Valves, Block Valves,

2. Tech Specs 12/15/80 Yes Complete Reference 15

'and Level' Indicators l1 IIlK.l. IE Bulletins 79-05,'-06. -08 ' Bulletin Yes Bulletin specific specific II.K.2 Orders on B&W Plants-

8. Upgrade AFW See N.A.

n system II.E.1.1

9. FEMA'on ICS 8/17/79 N.A.

10. Safety-grade 7/1/81 N.A.

trip

11. Operator Complete N.A.

training, drilling

13. Thermal-mechanical report 1/1/82 Yes 1/1/82 Note II.K 2.13

14. Lift frequency See-N.A.

of PORVs and SVs II.K.3.7

15. Effects of slug Complete N.A.

flow on GTSGS

16. RCP seal damage Complete N.A.

17. Voiding in RCS

a. Complete N.A.

b. 1/1/82 Yes 1/1/82 Note II.K.2.17

19. Bencitaark

a. Complete N.A.

analysis of seq. b. 1/1/82 Vas TBD Note II.K.2.19 AFW flow

20. System response Complete N.A.

to SB LOCA

• 5chedule is' based on delivery of equipment on schedule.

(1).P.wision 1 dated varch il, 1 H11

Clcrifi-Implemen-PBNP cation 'tation Applica-PBNP It m " Shortened Title Description Schedule bility Sc: edule - Remarks II.K.3 Final' recommendations,

1. Auto PORV B60 Task Force isolation

~

a. design 7/1/81 Yes NR

b. Test /

1st refuel Yes NR Note II.K.3.1 and 1 install 6 mos after Reference 4 staff approval

2. Report on PORV 1/1/81 Yes Complete Note II.K.3.2 ll failures 3.~ Reporting SV and 1/1/81 Yes Complete Nota II.K.3.3 l1 RV failures and challenges

5. Auts trip of RCPS-

a. Propose..

7/1/81 Yes TBD modifications Note II.K.3.5 g: . b. Modify-3/1/82 Yes TBD T

7. Eval of PORV 1/1/81-N.A.

opening probability

9. PID controller 1/1/81 Yes Completed Controller change made upon initial notification by vendor prior to TMI-2 (Reference 4)

10. Proposed Plant Yes Original Reference 4 1.f '.

anticipatory specific Plant Design trip modifi-cations ll. Justify use of Plant Yes N.A. As part of the original . certain PORV specific Plant design (different fran TMI-2), Point Beach has Copes-Vulcan PORVs which corresponds to the Westir.ghouse data base and, thus, no justification is needed. N.F. Not Required f (1) Revision 1 dated March 31, 1981

c

12. Anticipatory trip on turbine 1 trip.

a. Confirma,

1/1/81 Yes Original Reactor trip caused by ' tion or pro-- plant turbine trip bypassed below posed modifi-- design 50% power as detected by cations the power range detectors. .b. Modify 1st refuel-N.A. 60 mo. after sta f f approval e T 0

Clarifi-Implemen-PBNP cation. ..-Shortened Title' Description Schedule bility Schedule Remarks ' Item tation .Applica-PBNP -II.K.3 -Final recommendations, -13. HPCI & RCIC '<(Continued) B&O Task-Force init levels

a. Analysis'.

1/1/81 N.A.

b. Modify _

7/1/81 N.A. .14. Iso condenser 1/1/82 N.A. isol modifi-cation

15. ; Isolation of 7/1/81 N.A.

HPCI and RCIC modification

16. Challenges and failures to '

relief valves

a. Study 4/1/81 N.A.

b. Modify 1st refuel N.A.

g' or 1 yr a(tor i approval

17. ECC system 1/1/81 Yes Completed Note II.K.'3.17 l1 outages

=

18. ADS actuation

a. Study 4/1/81 N.A.

b. Propose

'4/1/82 N.A. mods

c. Modification 1st refuel N.A.

6 mo after staf f approval

19. Interlock 7/1/81 N.A.

recirc pump modification 20.. Loss of SVC 7/1/81 N.A.

21. Restart of CCS and LPCI

'a. Design 1/1/81 N.A.

b. Modification 1st. refueling N.A.

60 mo after i s ;af f approval (1) Revision 'l-dated tL1rch 31, 1981 I

hc n I 1 i 1Clarifi-Implemen-PBNP

cation.

tation Applicab-PBNP Item Shortened Title . Description- . Schedule bility ' Schedule Remarks II.K.3' I'inal recommendations, - 22. RCIC suction f '(Continued) B&O Task Force

a. Verify 1/1/81 N.A.

procedures,

b. Modification 1/1/82 N.A.

24. Space cooling 1/1/82 N.A.

for HPCI/RCIC modifications

25. Power on pump seals

a. Propose 7/1/81 N.A.

mods 1/1/82 Yes 1/1/82

b. Modification 1/1/82 N.A.

7/1/82 Yes N.A.

27. Common ref.

7/1/81 N.A. level. 28.. Qual'of ADS 1/1/82 N.A. accumulators

29. Performance of 4/1/81 N.A.

isolation condensers

30. SB LOCA methods

a. Schedule 11/15/80 Yes TBD I

outline

b. Model 1/1/82 Yes TBD Note II.K.3.30

c. New 1/1/83 or Yes TBD analyses 1 yr after staff approval

31. Compliance 1/1/83 or Yes TBD Note II.K.3.31 with CFR 50.46 1 yr after staf f approval

40. RCP seal See N.A.

damage-II.K.2.16

43. Effects of See N.A.

slug flow II.K.2.15

43. Eval transient 1/1/81 N.A.

with single failure

45. Manual depres-1/1/81 N.A.

surization f'

s r i i l 'Clhr.^ fi-Implemen-PBNP b cttien tation Applicab-' PBNP -Itrn . Shortened Title Description Schedule bility Schedule Remarks .II.K.3 Final recommendations

46. Michelson-Complete.

N.A. (C:ntinued) B&O Task Force, . 57. Manual act TBD N.A. concerns of ADS 'III.A.1.1' Emergency Preparedness, Short-term Completo. Yes Complete . Shor t Term. improvements l l1 III.A.l.2 Upgrade. Emergency

1. Interim TSC Complete Yes

' Complete Note III.A.l.2 - Support' Facilities OSC.and EOF 2. Design TBD TBD TBD l 3. Modifications TBD. TBD TBD l1 III.A.2 Emergency Preparedness.

1. Upgrade'emer-4/1/81 Yes Comple'e Note III.A.2.1 gency plans to l

. App. E, - 10 CPR 50 l1 t

2. Meteorological 6/1/03 Yes 7/1/82 Note III.A.2.2 data III.D.l.1 Primary Coolant

1. Leak' reduction Complete Yes Complete Currently changing to a Outside Containment yeatly testing schedule for both units coincident with refueling outages (References 1, 2, and 3) 2.-

Tech specs 12/15/80 Yes Complete Reference 15 1 l III.D.3.3 Inplant Iodine

1. Provide mear.u to Complete Yes Complete Monitoring determine-presence of radioiodine

2. Modifications 1/1/01 Yes Complete Note III.D.3.3 1

l. to accurately measure 12 i-III.D.3.4- ' Control Room

1. Review 1/1/01 Yes Completed Note III.D.3.4 1

liabitability

2. Modification 1/1/83 Yes 1/1/83 Note III.D.3.4 l-(1) Revision 1 dated March 31, 1981.

,r l l

RESPONSE TO NUREG-0737 POST-TMI REQUIREMENTS FOR OPERATING PLANTS 4 Point Beach Nuclear: Plant,-Units 1 and.2 ~ Docket Nos. 50-266 and 50-301 Schedule Table 'and Notes Revision.l~:- March 131, 1981 +' t 4 e e E er ur+v i ,Qh 1 -9 v69-t- e e 4-e-w gd gn _,+-3 --c-.t.- y ittry

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Revision 1 3/31/81 I.A.1.1.3 SHIFT '"i;NICAL ADVISOR TRAINING All Duty Technical Advir'r training was completed by March 1, 1981, per Reference 17, with the exception of training for mitigating core 4- 'ge as addressed in II.B.4. The scheduled completion date Oc this additional training is October 1, 1981. The content of this training is addressed in the attached program description. I.A.l.l.4 SHIFT TECHNICAL ADVISOR LONG-TERM PROGRAM DESCRIPTION The Duty Technical Advisor long-term training program description was submitted to the NRC on February 26, 1981, by Reference 17. I.C.l.3 GUIDANCE FOR THE EVALUATION AND DEVELOPMENT OF PROCEDURES FOR TRANSIENTS AND ACCIDENTS The program to achieve compliance with NUREG-0~37, I.C.1, was described'in Owners Group letter, OG-47, to S. S. Hanauer dated December 15, 1980 (Reference 10). That letter identified generic procedural. guidelines and supporting material already submitted to the NRC and identified three phases of proposed future action. Your letter, S. S. Hanauer to R. A. Newton datad' December 17, 1980 (Reference 11), responded to a ~ November 12 meeting and identified several additional items of concern. Owners Group letter, OG-48, dated January 28, 1981 (Reference'14), responded to the items listed in the NRC's December 17 letter. The three phases outlined in OG-47 were nearing completion during the end of February and a meeting was held on February 20, 1981, between the Westinghouse-Owners Group and members of your Staff, which was intended to update you and your Staff on our activities to date, get feedback from your - Staff with regard tx the program activities, and ~ to identify the items that are r eeded to complete the program. It is our understanding, as a result of the Feb::uary 20 meeting, that completion of the - it. ems 'as described in Owners Group ' letter, OG-54,.to S..S. Hant.uer dated March 18, 1981, Reference 20, will fully address the NRC requirements in the procedures evaluation and -development areas, as set -forth in I.C.l. II.B.2.2 PLANT SHIELDING ~ As described-in Reference 12, shielding modifications are being evaluated 'for the Point Beach Nuclear Plant. Three areas of the auriliary building-are'being studied for installati<n of permanent. -

Revision 1 3/31/01 II.B.2.2 Continued shieldi.sg, relocation of plant equipment, or the use of temporary portable shielding to reduce post-accident exposure of equipment and personnel. Each of these is described below. A consultant has been retained to begin the basic design evalua-tions for relocation of portions of the Unit 1 safety injection lines. This relocation sh.110 eliminate the major radiological contributor to exposure of adjacent electrical equipment and reduce the dose rates for personnel access in the corridor beneath the exiJting piping. Since these modifications require the unit to be at ;old shutdown and the purchase of safety-grade equipment, not yet designed, implementation by the fall refueling outage in 1982 would be the earliest achievable date. A complete access study was performe with the existing piping configuration (Reference 1) and pre 2-accident operations can be performed by minimizing access tirm_s. No equipment should fail due to radiation exposure within thirty days following the postulated accident (Reference 2). Proposals'for design of shielding for electrical equipment near a portion of the Unit 2 safety injection lines is under evaluation. Installation of any required modifications should be possible by the June 30, 1982 NRC implementation date. Proposals for the evaluation and design of portable and permanent shielding in the area of the C-59 control panel (References 1 and 2) are currently being evaluated. Installation should be possible by the January 1, 1982 NRC implementation date. Additionally, wall penetrations for piping and electrical ruris between the auxiliary and control buildings were identified as requiring shielding. This was made necessary by implementation of IE Bulletin 80-11, which requires the removal of concrete block' which fills the unused portions of these wall openings. New shielding for these penetrations is being designed for installation when the existing b1cck is removed. This work is scheduled for completion prior to the June 30, 1982 NRC implemen-tation date. II.B.4 TRAINING FOR MITIGATING CORE DAMAGE ~ The program description and content for this training is provided in the -attached -document, " Point Beach Nuclear Plant, Mitigating Core Damage Training Program", Revision 0, March 16, 1981.. Table 1 of the' attachment provides the specific training requirements. for plant personnel. Completion'of training for.all individuals involved will. follow the ' initial training : session and is ' scheduled 'for completion by October-1, 1981. Part 1 training for this program was integrated into and completed as part of the licensed operator retraining program. All licensed ~ plant personnel-and Duty Technical Advisors completed this j Ltraining prior to. March 31, 1981. w 'Revisi'>n 1 3/31/8.1 II.E.1.2 AUXILIARY FEEDWATER SYSTEM INITIATION AND FLOW-FLOW INDICATION The auxiliary feedwater flow indication of flow to each steam generator has been implemented for Unit 1 prior to Ma ch 31, 1981. The Unit 2 flow indication will be implemented during the refueling outage scheduled to begin on April 17, 1981. During that outage it will be possible to install the orifice plates and pressure taps required for the new Foxboro differential pressure transmitters and complete the implementation. The auxiliary feedwater system and flow indication has been described in References 1, 2, 3, 9, 12, and submittals by Wisconsin Electric in response to IE Bulletin 79-06B. The steam generator flow indication instrumentation channels, when fully implemented, will be environmentally qualified to meet the requirements of IE Bulletin 79-OlB. The model of Foxboro transmitter used in the system is currently undergoing a complete 79-OlB environmental testing program. This program is scheduled for completion by June 30, 1982. Any changes required of the installed transmitters will follow the program completion. Ultimately, power to the flow indication instrumentation channels will originate from highly reliable, battery-backed, Class IE power sources. Implementation of this pcver source will, however, require the completion of an instrument bus upgrade involving new chargars, batteries, inverters, and electrical distribution equipment.. The design of this modification is nearly complete. Conntruction and installation will be completed consistent with other TMI modifications, with operation by early 1982. Until then, the channels will be pcuered by diverse, highly reliable, non-battery-backed power sources. Periodic testability has been designed into the channel circuitry. Channel component purchase, handling, and installation was covered under the quality assurance program implemented at Point i Beach Nuclear Plant. Display of auxiliary feedwater flow to each steam generator is continuous and was installed taking into consideration operator use, control room human engineering, ana available space on existing control boards. II.F.2.3 . INSTRUMENTATION FOR DETECTION OF INADECUATE CORE COOLING - INSTALL LEVEL INSTRUMENTS The reactor vessel level system' design and description has Paan provided in. References 1 and 2. The detailed desien of the system is in progress but has resulted i possible changes to how the system will be implemented due to selection of available considerations for how the sys-tem will be qualified hardware, installed, accuracy.of the signal processing-system and maintain-ability of the system after installation.. The planned system will still use' vessel differential pressure as the sensed Due to parameter for the determination of vessel water level. these difficulties,.the report detailing the design of the planned-instrumentation for the monitoring.of inadequate core 40

Revision 1 3/31/81 II.F.2.3 Continued cooling will be submitted by July 1, 1981, not the April 1, 1981 date indicated in Reference 12. Our aim is to still meet the planned schedule for having the vessel level systems operational for Unit 1 by January 1, 1982, and by June 1, 1982 for Unit 2. i This is based on delivery of equipment on schedule to meet the l Unit 1 fall 1981 and Unit 2 spring 1982 refueling outages. f II.K.3.1 INSTALLATION AND TESTING OF AUTOMATIC POWER-OPERATED RELIEF VALVE ISOLATION SYSTEM Based on the previous operating history at the Point Beach Nuclear Plant during' which no PORV has failed open, we see no need for an automatic isolation system. We believe that such a system would add unnecessary complexity to a well-design, functional system and may, in fact, contribute to a reduction in safety and operator attention to the PORV status. Such a system may also reduce the number. of options available to the operator and, thus, limit the accident rasponse-capability for the plant. .The conclusion in WCAP-9804, as quoted in II.K.3.2, supports the positions stated above. Therefore, a system which automatically closes the PORV -isolation valves will not be implemented at the Point Beach Nuclear Plant. 4 II.K.3'.2 REPORT ON OVERALL SAFETY EFFECT OF POWER-OPERATED RELIEF-VALVE ISOLATION SYSTEM (PWR VENDOR REPORT ON PORV FAILURE REDUCTION The' Owners Group-of_ Utilities with Westinghouse plants ha's submitted ~, L a -report on the overall safety effect of PORVs. This report includes historical valve failure rate Ldata and actions taken since the TMI-2 event to/ decrease'the probability of a stuck-open PO RV. ' 'The report was submitted to. the NRC.as WCAP-9804, "Probabilistic1 Analysis. and Operational -Data in Response to NUREG-0737,; Item II.K.3.2, For WestinghouseLNSSS Plants", and transmitted via Owners 1 Group letter OG-52, R. Jurgensen to

J.. Miller, dated' March 13,E1981 (Reference 19)'.

p As per the Wisconsin Electric submittal of. December 23, 1980, in d response to Items II.K.3.1:and II.K.3.~2 of NUREG-0737, there'is no: operating aistory.at;the Point Beach Nuclear Plant during which a - PORV has ' failed-to open" or close. iAlso, several post-TMI actions' haveJ been taken to reduceo the probability of a~ small break 1LOCA caused by ' a' stuck-openf PORV.- This includos. operator . training,- revisions to - procedures,Tand instrumentaticn. wiring changes. All' of ?theLmodifications cdescribed in Section 3.4.2 of "WCAP-9804i have.been implemented at Point. Beach Nuclea r. Plant. -In addition, the current. plant' operating: pressure of 2,000. psia-

provides additional' operating! margin ~'to the setpoint1for PORV opening.- _

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. -. _ ~ i Revision 1 3/31/01 II.K.3.2 Continued WCAP-9904 describes in Section 3.5 an evaluation of an automatic -PORV block valve closure concept. The conclusion stated in this section is as follows: "The concept of an automatic PORV block valve closure system, which closes the PORV isolation valves when lower pressure is sensed subsequent to a PORV failing to close, .cannot be warranted on the basis of providing. additional protection against a PORV LOCA. Such a system, however, is also nc expected to be detrimental to reactor safety considering the PORV LOCA, steam generator tube rupture recovery, or ICC recovery' procedures." Based on the conclusion that no benefit in safetycis achieved by an automatic PORV. block valve closure system, a system which performs this function will not be implemented at the Point Beach Nuclear Plant. -II.K.3.3 REPORTING SAFETY AND RELIF.F VALVE FAILURES AND CHALLENGES Covering the reporting - period from April 1,1980 through December 31,.1980: No power-operated relief. valves or Code safety valves, connected to the Point Beach Nuclear Plant primary coolant system;off ofFthe' pressurizer steam space, have been challenged by any plant operations or operating conditions. No power-operated relief valves or Code safety valves have' failed. This-information is being reported for dua initial nine-month period specified by the NRC as partL of. the Point Beach Nuclear Plant Annual Report for.1980. It is included in this submittal as an errata item to that. report, which was submitted prior to March 1, 1981.' Future 1 reports of any PORV. challenges or failures .will be for the full one-year period and will be included-as a regular reporting item 1on future annual reports for the plant. 1 II'.'K.3.17 'ECCS OUTAGE REPORT A report covering the itime period; from January 1,'- 1976 - through December =31,11980 is attached to-this submittal.. e l III. A. l~. 2 UPGRADING-EMERGENCY: SUPPORT FACILITIES i ~ All of theninstrumentationidescribed'in Reference 2 was installed =infthefterporary Technical ~ Support: Center prior to March.1, 1981'. Twith the L exception of: wind speedf and direction indicators..The .~ Linstrumentation.issfully operationalxwithithelfollowing exceptions: ( T ~

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Revision 1 3/31/81 III.A.l.4 Continued 1. Auxiliary feedwater flow; 2. One Th and T 1 p in each unit; c 3. Containment sump level; and 5 4. Contalument high-range radiation. Item 1, auxiliery feedwater flow to. the steem generators, has been implemented for Unit 1 and will be implemented for Unit 2 ~ during the Unit 2 refueling outage which is scheduled to begin April 17, 1981 (See II.E.1.2 above). Item 2 is implemented -only for one Th and Tc loop in each unit. The remaining Th and Tc loop and Iten,s 3 and 4 will be operational when the new instrumentation racks and auxiliary safety control panels are installed and operational in early 1982 (Reference 12, Item II.F.2.1). A training session was held on March 11, 1981 for all Duty and Call personnel and all Duty Technical Advisors to cover the parameters displayed. User instructions and an appropriate continuing training' program are being developed. III.A.2.1 EMERGENCY PREPARENDESS - UPGRADED EMERGENCY PLANS TO APPENDIX E, 10 CFR 50 Effective April 1, 1981,_ Wisconsin Electric will be implementing its revised Emergency Plan in accordance with 10 CFR 50.47S2. .III.A.2.2 EMERGENCY PREPAREDNESS - METEOROLOGICAL DATA Wisconsin Electric has provided in Reference 13 a description of its plans for upgrading the meteorological measurements program at Point Beach Nuclear Plant. The implementation schedule for this upgrading is given in Section C of the description. The estimated completion'date is July.1, 1982. III.D.3.4 CONTROL ROOM HABITABILITY Refercnce 12 provides an initial response to the requirements pertaining to the control room habitability evaluation. ' Additiona1 'information was 'provided in : Reference 13 and the final. report on control room habitability.for Point Beach Nuclear Plant was transmitted by our letter of February, 23, 1981 (Reference L 16). Revision 1 3/31/81 I;;I.D.3.4 Continued .\\s -indicated in the final report, a supply of potassium ic dide tablets, eye protection, and. protective clothing has been 4 provided in the control room in conjunction with other preparations for. implementing the revised Emergency Plan. Portable shielding to be placed in front of doorways and windows is being designed and will be installed on or before January 1, 1983. Technical ^ Specifications 15.3.12 and 15.4.11 already adequately address control room emergency filtration, and no further changes are required. j 4 ?:- I ^'. d' e 4 -

Revision 1 March 31, 1981 II.F.1.2 IODINE / PARTICULATE SAMPLING Two aspects of this item, one schedular and one technical, require further clarification of our position as addressed in our submittals of December 23, 1980, and March 4, 1981. In the original September 5, 1980 letter'from Mr. D. G. Eisenhut to All Licensees, no preimplementation review was required, and implementation and documentation dates were identical, i.e., October 1, 1981. In the final November 1980 issuance of NUREG-0737, NRC continues its position that no preimplementation review is required and delays the implementation date to January 1, 1982. However, the text states that "By January 1, 1981 operating reactors should have available for review the final dc" gn details of the implementation of the above position and clarif. cation." Since no preimplementation review is required and since final design details and as-built drawings cannot Le provided before implementation, we have concluded that this da".e is an error and that January 1, 1982 is intended. Accordingly, final design details of the implementation will be submitted by January 1, 1982. As stated in both our December 23, 1980 and March 4, 1981 submittals, we anticipate compliance with the technical intent of the iodine sampling requirements except for the requirement for isokinetic and representative sampling per ANSI N13.1 (1969). These additional requirements in the November 1980' revision of NUREG-0737 regarding iodine sampling and analysis have resulted in a re-examination of our design approach. We have procured Eberline SPING units for our gaseous monitoring system and intended that iodine sampling equipment be added near or on these units. In order to meet che ANSI criteria, the sampler must be located very close to the vent being sampled. _However, personnel radiation dose considerations may require sampling units to be located some distance away from the point of vent sampling, as planned in our ~ original design considerations for_the SPINGs. 1 4 i 1 "

Revision 1 3/31/J1 REFERENCES 1. S. Burstein (WE) to H. R. Dentc a (NRC), December 31, 1979, "Implementa tion of NUREG-0578" 2. C. W. Fay (WE) letter to h. R. Denton (NRC), March 14, 1980, " Implementation of NUREG-0$78" 3. A. Schwencer (NRC) letter tc S. Lorstein (WE), April 9, 1980, " Evaluation of Compliance with Category "A" Lessons Learned Requirements" 4. C. W. Fay (WE) letter to H. R. Denton (NRC), June 11, 1980, " Implementation of Five Additional TMI-2 Related Requirements" 5. C. W. Fay (WE) letter to H. R. Denton (NRC), November 3, 1980, " Status of Duty and Call Technical Advisor Training" 6. C. W. Fay (WE) letter to H. R. Denton (NRC), December 1, 1980, " Revised Dmergency Plan" 7. C. W. Fay (WE) letter to H. R. Denton (NRC), November 3, 1980, " Operating Licenses DPR-24 and DPR-27, Interim Criteria for Shift Staffing" 8. C. W. Fay (ES) letter to H. R. Denton (NRC), September 22, 1980, " Comments on Draf t NUREG-0696, Functional Criteria for Emergency Response Facilities" 9. S. Burstein (WE) letter to H. R. Denton (NRC), October 20,~1979, " Implementation of NUREG-0578" - including TMI Accident Review Task Force Report (Section 3.6.A) 10. R. W.'Jurgensen (WOG) letter to S. S. Hanauer (NRC), OG-47, December 15, 1980, " Westinghouse Owners Group Response to Item I.C.1 of NUREG-0737" 11. -S. S.fHanauer (NRC) letter to R. A. Newton (WE), December 17, 1980, request-for.a basis document for the emergency procedure -guidelines. '12. C.W. Fay (WE) letter to H. R. Denton ' (URC), December 23, 1980, " Response _to NUREG-0737,' Schedule Requirements as Related to Point Beach Nuclear Plant, Units 1 and 2" 13. C. W. Fay (NE) letter to H. R. Denton-(NRC),. January 9,

1901,

" Additional Response-to NUREG-073.7"

14.

-R. W. Jurgensen - (WOG) letter to S. S. Hanauer (NRC), OG-47, January 28, 1981, " Emergency Operating Instruction Background Documents" -9.

Revision 1 3/31/81 j 15. C. W. Fay (WE) letter to H. R. Denton (NRC), February 4, 1981,." Technical Specification Change Request No. 65" 16. C. W. Pay (WE) letter to H. R. Denton (NRC), February 23, 1981, " Additional Response to NUREG-0737" [ 17. C. W. Fajr (WE) - le tter to H. R. Denton (NRC), February 23, 1981, "Laty and Call Technical Advi~sor Training" 18. C. W. Fay.(WE) letter to H. R. Denton (NRC), March 4, 1981, l "NUREG-0737 Schedule Requirements" 19. R. W. Jurgensen (WOG) letter to J. R. Miller (NRC), OG-52, March 13, 1981, WCAP-9604, "Probabilistic Analysis and r Operational Data in Response to Item II.K.3.2 for Westinghouse i NSSS. Plants" 20. R. W..Jurgensen (WOG) letter.to S. S. Hanauer (NRC), OG-54, March-18, 1980, " Westinghouse Owners Group Update on Item I.C.1 of NUREG-0737' Activities" r I O b e 1 1 e.

ATTACHMENT Revision 0 03-16-81 POINT BEACH NUCLEAR PLANT MITIGATING CORE DAMAGE TRAINING Pr.0 GRAM 1.0 PURPOSE The purpose of this document is to establish a mitigating : ore damage training program for Point Beach Nuclear Plant. This program is intended to meet the requirements for mitigating core damage training as addressed -in the March 28, 1980, Denton letter and further defined by NUREG's 0660 and 0737. 2.0~ OBJECTIVE As a result of the accident at Three Mile Island, the NRC concluded that, in general, plant operating staff and management lacked knowledge and expertise in the methods to mitigate core damage. Based on that conclusion, the NRC now requires that plant personnel with responsibilities involving mitigating core damage receive special training. This program f~ will assist the operating staff in decision-making processes involving an y accident resulting in core damage. The operator will develop the knowledge L _. and skille necessary to constantly analyze integrated systems operations and readily recognize conditions during which the plant is more vulnerable .to accident initiations. The course material outlined in this program assumes the trainee to have prior training in reactor principles, heat transfar, fluid flow, and nuclear plant systems involved with reactor heat removal. This' program will also provide personnel holding positions listed in Table 1 the knowledge necessary to recognize conditions that could result. or have resulted in core damage and to mitigate the consequences of such accidents. 3.0 PROGRAM 3.1 Part 1 Part 1 of this' program was integrated into and completed as part of the licensed operator retraining program and consisted of approximately four contact hours of tralning and a quiz. A generic. overview of the problems expected when operating a core that may have experienced damage and, in general. the actions that could be taken to determine the extent of and mitigate the consequences of the damage, were ' cover ad. In specific, the problems anticipated during a small break LOCA were emphasized. Text material developed by General Physics Corporation and information presented in the Westinghouse Duty & Call Technical Advisor accident analysis course provided the-basis for this part of the program.

Page 2 3.2 Part 2 Westinghouse has been contractea to provide the additional plant-specific mitigating core damage training. All training in this part of the program will be completed before October 1, 1981. It is anticipated that the course will entail approximately 40 contact hours of training. A rough outline of the program is listed below. Table 1 designates personnel and tne particular portions of the training program they are to receive. 3.2.1 Course Introduction a. Major plant assumptiens b. Core thermal and linear power density limits 3.2.2 Incore Instrumentation a. System functions, characteris;ics, and operations including moveable incore detection system and incere thermocouples "ko, b. Determinat.on of core damage extent and core gecmetry d changes c. Determination of peak core :emperatures d. Methods of obtaining extended range readings e. Direct readings at terminni junctions f. System outputs and recorders g. Potential causes of instrument failures and probable time to failure under various degraded conditions 3.2.3 Excore Instrumentation a. Factors affecting excere instrumentation response during various operatienal conditions b. Expected' indications for various loss of coolant accidents c. -Determination of void formation in the' core region d. Detector reliability under adverse-envicoraental conditions.

Page 3 3.2.4 Post-Accident Primary Chemistry a. Expected changes in primary plant chemistry b. Consequences of transferring primary water outside of containment c. Long term system problems associated with extended immersion in contaminated primary water and potential failure mechanisms d. Expected isotopic breakdowns for various conditions of fuel and cladding 3.2.5 Radiation Monitorinc Types or detectors utilized in the radiation monitoring a. system b. Response of process and area monitors to radioactivity release I, c. Verification of installed instrumentation through supplemental measurements \\. N d. Detennination of dose rates with nonfunctional or nonavailable instrumentation 3.2.6 Vital Process Instrumentation Specific applications of major types of transmitters a. b. Various failure methods and their reliability c. Pressurizer pressure instrumentation d. Steam generator level instrumentation 'e. Various temperature detectors ~ f. Major flow indicators .g. Alternate methods to determine critical process variables h. Use of plant computer stored information ~ 3.2.7 LGas Generation . Physical and chemical characteristics and potential a. sources-of major gases M __._a__

Page 4 b. Hydrogen flammability and explosion limits c. Venting, disposal, and sampling methods of containment gases 3.2.8 Potentially Damaging Situations and Cooling Methods a. Loss of feedwater i'nduced loss of coolant accident b. Heat removal paths and sinks c. Steam and water cooling d. Injection flovpaths - hot leg versus cold leg injection e. Quenching effects'on clad material f. Gas or steam binding effects g. Natural circulation indications and controls - one-phase and two-phase fluids 3.2.9 Course Summarv 'a. Course' overview b. Unanswered questions e .I 4 l i 'l

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EMERGENCY CORE CdOLING SYSTEM OUTAGE REPORT FOR TIIE PERIOD j-JANUARY 1976 TO DECEMBER 1980 = i: 4-r - Point: Beach Nuclear ' Plant, - Units -1 and 2 Wisconsin ElectriczPower Company e ' 8,~ W f ~ m

INTRODUCTION A tabulation of all Emergency Core Cooling System (ECCS) equipment out of service at Point Beach Nuclear Plant, Units 1 and 2, from January 1976 to December 1980 has been compiled in response to Item II.K.3.17 of NUREG-0737. This tabulation includes the component (s) involved, cause of the outage, corrective action taken, length of time, and dates tae component was out of service. This is in accordance with the "Five Additional TMI Requirements" letter issued in May 1980, and the " Clarification of TMI Action Plan Requirements" letter issued in September 1980. The purpose of this tabulation is to provide a documentation of unavailability time for each of the ECCS essential components over the past five years. SCOPE The majority of the data for this tabulation was taken from the plant Maintenance Request and test records. Based on these records and backup information from Licensee Event Reports, Significant Operating Event Reports, Machinery History Records, Station Logs, and Modification Requests, the tabulation (Tables 1 through 10) -was compiled which describes the component, reference for the outage, cause of the outage, corrective action taken, date, and length of time which the equipment was out of service. Point Beach Nuclear Plant Technical Specification 15.4, " Surveillance Requirements", provides for testing, calibration or inspection of those systems or components whose functioning is required for continued, safe operation of the plant. Beginning in September 1977, in-service testing of pumps and valves was initiated to assess the operational readiness of safety-related components (Table 11). These tests are required by Technical Specifications and are in accordance with ASME Code, Section IX, IWP, Subsection 1100, "In-Service Testing of Pumps and In-Service Testing of Valves in Nuclear Power Plants," Frior to the "In-Service Test", Technical Specification tests were' performed (Table 12). Lengths of outages, where not documented, were based on estimates of hours needed to isolate the system; perform the maintenance, test, Jr corrective action; and restore the system to operational s ta tus.' All of the test and maintenance procedures and results are available.at the Point Beach Nuclear Plant site. Excluded were tests and maintenance done during scheduled outages, H such as annual refueling outages, when the systems are rer.oved from service as part of normal plant operations (cold shutdown). 1

O The following systems and components are considered part of the ECCS and provided tae basis for the tabulations: 1. Accumulators; 1 2. High head safety injection system; 3. Residual heat removal (low head) system; 4. Containment sump; 5. Boric acid storage tanks; 6. Refueling wat?r storage tank; 7. Containment spray system; 8. Auxiliary coolant system; and 9. Service water system. Non-essential components and instrumentation were excluded from the tabulation since their loss of service can in no way adversely aff2ct the capability of the ECCS to perform its intended safety functions. SYSTEM DESCRIPTION The ECQ 'rovides borated water to. cool the core and insert negative reactivity by injection into the cold legs of the reactor coolant loops (Figure.1). The system uses two passive accumulators and two high pressure safety injection pumps._ The high pressure . safety injection may also be directed over the top of the core vir. injection through core deluge nozzles. The two residual heat removal (RHR) pumps also function as low pressure safety injection pumps to provide high volume / low pressure injection into the. reactor coolant system via the core deluge nozzles. The boric acid storage tanks and refueling water-storage tanks prcVide tha-sources of borated water. The auxiliary coolant system provides component cooling water and heat removal from recirculated primary water via the RHR heat exchangers. The service water system is the circulating water system which removes this heat to the environment. These systems can operate in either the injection or recirculation phases. The. containment spray' system provides a spray of cooled, chemically -treated, borated water to the containment atmosphere to provide ~ iodinc removal capacity and to-back up.the containment. air recir-culation cooling system. Each unit at the Point Beach Nuclear Plant is equipped with a ~ separate and independent ECCS.- There is a cross-connection between the two systems at the boric acid storage tanks to allow the two_ units to share a third,ispare horic acid storage tank. ~ The following system description _is applicable to either unit:.

1. Accumulators .Under normal operating conditions, the two accumulators, Figures 2 and 3, are isolated from the Reactor Coolant System (RCS) by way of two check valves in series. The contents of each accumulator (borated water at greater than 2,000 parts per million)-is press".rized to 750 psi by nitrogen gas. Should RCS pressure fall below accumulator pressure, the check valves open and borated water is forced into the RCS. No external power or signal is necessary to cause actuation of the system. Connections for drawing a local sample of the tank contents and remoto draining / filling of the fluid space are provided. Instru-mentation includes level, pressure and the alarms associated with these-parameters. High Head Safety Injection The high head safety njection system, Figures 2 and 4, includes twc horizontal, cen r2 fugal, motor-driven pumps having a shutof f heaJ of approximately 1,500 psi. At the pump suctions is a boric acid storace tank that contains a highly concentrated solution of boric Ecid to provide additional shutdown margin for an accident (especially a steam break in which the RCS cools down rapidly). At the discharga of each pump is a minimum bypass orifice to permit. recirculation back to the refueling water storage tank (RMST) in the event the pumps - are started with the normal flow paths-biccked. The pump seals are cooled by the auxiliary coolant system. Instrumentation for the system includes local and remote pressure and flow indication. Also included in the system is a sample . connection, a. drain connection, and a test line'.- Residual. Heat Removal System-(Low-Head Safety Injection) The two residual ~ heat removal (low head) pumps are horizontal, i centrif agal' type, each driven by an _ electric motor. The . functions of;the system,~ Figures 2 and 5, are to provide decay -heat removal from the RCS via recirculation during normal cooldown and : shutdown, - low head. safety injection to the RCS, suction. head to the high: head safety injection pumps and containment spray pumps:during; recirculation. Borated water'.for injection is-obtained from the RWST.- Borated water for recirculation is obtained.either directly from'the RCS or from the containment

sump (Figures 2:and G).-

LCooling of the fluid'during recircula-Ltion ois. accomplished by way of the residual heat exchangers. These heat exchangers are, in turn, cooled by the auxiliary -

coolant system..

Instrumentation ' for the system includes local and remote pressure,. ~ ~ tempera ture", and' flow indication. 'Also included ~are cross-connection . lines:to the high head safety injection and containment spray systems. a

Boric Acid Storage Tanks Three boric acid storage tanks (Figures 2 and 7) are provided. One of the tanks supplies the initial source cf boric acid solution (11.5-12.5 percent by weight) for injection into the RCS following the generation of a safety injection signal. Using one tank per unit leaves the third tank as a standby. Temperature of each tank is maintained at 165"F by two electric immersion heaters located at the bottom of the tank. Instrumentation for the system includes temperature and level indication and alarms. Also included in the system are the cross-connection piping and isolation valves. Refueling Water Storage Tank One function of the refueling water storage tank (RWST), Figures 2 and 8, is to store and supply borated water to the refueling canal for refueling operations. It also provides borated water to the safety injection pumps, residual heat removal pumps, and the containment' spray pumps for either a loss-of-coolant accident or a steam break accident. (Luring normal plant operations, the tank is aligned to the above pumps. ) The RWST ccntains 275,000 gallons minimum. The water in the tank is borated to a concentration of >2,000 ppm. Heaters are provided to prevent freezing of tank contents during cold weather and the tank is protected from wind chill by insulation and is located within the containment facade. Instrumentation is provided to monitor tank temperature and level. An alarm circuit is provided for low level conditions. Penetrations to the 'ank include a local sample connection, the instrumentation, a drain connection, an overflow, and vent path. Containment Spray System The containment spray system contains two spray pumps (horizontal, centrifugal, motor driven), two liquid eductors, one spray additive tank, and two spray ring headers and nozzles and associated valves (Figures 2 and 9). -The pumps take a suction from the RWST during the initial phase of safety injection. They pump borated water into the spray header to reduce containment pressure. They are also used to spray NaOH into the containment to aid in the removal of air-borne iodine. This is accomplished by use of the spray eductors. NaOH is stored in the Spray Additive Tank and through entrainment the NaOH is introduced into the borated water and eventually into the containment. The RHR pumps supply the flow to the suction of the containment spray pumps during recirculation. The operation is terminated when the level in the Spray Additive Tank reaches the point indicating enough NaOH solution has been added to the containment for required sump chemistry. s The Spray Additive Tank has a drain connection and a sample connection as well as a level detector. The entire system is equipped with pressure and flow detectors and the instrumentation necessary for these detectors. , Cooling Water Systems A. Auxiliary Coolant System During the recirculation mode, the auxiliary coolant system is used to cool the recirculation fluid as it passes through the residual heat exchanger. One of the two component cooling pumps and one of the componen_ heat exchangers is sufficient to provide the core and contain - ment cooling function during recirculation. B. Service Water System (Common to Both Units) The service water system is provided with a ring header and valves such that the auxiliary coolant heat exchangers, which are supplied with service water for cooling, can have flow directed to them from either side of the header. Three of the six service water pumps are required to operate during the recirculation phase to cool the recirculation flow and containment atmosphere in the unit suffering the accident and provide the necessary cooling for the other unit. SYSTEM ACTUATION Safety-Injection System Actuation Safety injection will be initiated in.the event of a loss-of-coolant accident (LOCA) or a steam line break accident from the signals gen 2 rated by the following parameters: 1. Low Pressurizer Pressure 11,715 psig 2. High Containment Pressure (Hi). 6 psig 3. Low Steam Line' Pressure - Loop A 1_ 500 psig 4.. Low Steam Line Pressure - Loop B 1 500 psig The~ accidents listed _above will result in a decrease in pressurizer -pressure _and an increase in containment pressure..The decrease in pressurizer ' pressure is brought about by the. loss-of-coolant from the RCS ' to the containment,. which in turn increases the containment pressure (thereby acting as a backup to the low pressurizer signal). A' steam 'line break will also decrease RCS pressure and temperature due to ' the rapid removal of RCS heat. The steam emitted into the

containment will increase containment. pressurc, and, zus before, this>provides a backup signal for the. system.

Containment Spray Actuation Containment spray will be actuated upon receipt of a containment high pressure signal (Hi-Hi). This actuates at a higher pressure than safety injection (50 percent of design pressure versus 10 percent for salety inj ection). To prevent spurious actuation of spray, it will only be initiated on sensing a "Hi-Hi" containment pressure condition by both channels in two-out-of-three containment pressure signals provided for its actuation. e.

I LIST OF FIGURES I Figure . Number Description 1 PBNP Reactor Coolant System Flow Diagram 2 PBNP Safety Injection System Schematic 3 P5NP Accumulator System Schematic - 4 PBNP High Head Safety Injection System Schematic 5 PBNP Residual Heat Removal System Schematic 6 PBNP Containment Sump Schematic 7 PBNP Doric Acid Storage Tank Schematic- . 8 PBNP Refueling Water Storage Tank Schematic 9 PBNP. Containment Spray System Schematic J . m W 9 t t 1 f T y ( w w- +

TO SAFETY VALVES O PRESSURIZER SPRAY

1. TO POWER OPERATED ib RELIEF VALVES AUXILIARY' SPRAY (CVCS) g 'h EXCESS RESIDUAL CTDOWN T

HEAT A PRESSURIZER I " P ES SA ETY ECTION E ClAtiGERRE LO STEAM GEMERATOR A SYSTEM ( A HEATERS h' REACTOR M( U COOLANT PUMP B Q n _ t. \\ ESIDUAL PRESSURIZER HEAT SURGE LINE REMOVAL SYSTEN ClA GIlG O REACTOR VESSEL LOOP A LINE (CVCS) t STEAM GENERATOR B . SIS REACTOR I I Q VESSEL / y A INJECTION LOOP B LINE REACTOR ^ Il C00LAr4T ~ PUMP A l < -l b 4 aLETOUWN SIS REACTOR LIllE (CVCS) [~k VESSEL g INJECTION LINE i ggg /p EXCESS LETDOWN if PRESSURE CHARGING LIfiE (CVCS) SAFETY LIllE (CVCS) INJECTION SYSTEM Figure 1 - PBriP REACTOR COOLANT SYSTEM FLOW DIAGRAM

l IllSIDE I OUTSIDE 00flTAlliMENT C0liTAlt! MENT SAFETY IilJECTI0li l BORIC ACID ACCur10LATORS STORAGE TAf1K REFUELING WATER O STOP. AGE TAllK A I S+ ~ (j ~ ~ -M g 92 l k Y# ta RCS W lY U ( A,

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S y N PHR PUMPS 9 ~ --c 04 I h c-) C0tlTAlllMEllT 4 W= MOTOR OPERATED VALVE SUMP L 0.= LOCKED OPEN Figure 2 - PBNP SAFETY INJECTION SYSTEM SCHEMATIC t e

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Test Line (ro(ss }onnect,867A RCS l-1-812A M S,sTest Line A

Connection l '(open)Connec tion From RHR,. M -- } I 1-845A 1-8709 To Other Accumulator Injection Line Figure 3 - PBNP Accumulator System Schematic e

_i-rt S2S QFJ ~ ~ ~ - - Es' 1;-p N 923 i-rE 1-c43h, 925 k1-8403 '^ 1-831A TO COLD. l l LO LCG I:lJ - I ll X /i u I INE I # 3^ ^- 1-839A .y,pg 1-51-013,jg, 1-SI.D10 ggg 1-P15A LC )'1-829A II -fy! -F g 924 IfJ C ION T 1-FE L 92 PU:!PS q 7 1-843C 1-8183 1-801B 1-51-D8 J L LO u TO COEE l l l -l 'E I3 lj' 1 c 83 ' ] I~3393 3,3([ 1-51-09 1-P153 1-es1A l$ l{ 1-8910 1-857A sll-8578 1-PI l l '( [' 1-8' GB 1-876A s LO L0 FRO:1 RitR SYSTDt 1-s30 o FRott TEST LC LC II LINC *t--Det--j 474--Q-- lTO RWST g 1 a793 1-cus Test Line ~~ 1-833)[ )(1-832 l I i t-LOCAL St& LE Figure 4 - PBNP High Head Safety Injection System Schematic

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~+ II13 8 Figure 5 - PBNP Residual ifeat Removal System Schematic

= l M M n~ x n \\ M M M M -LC 1-LC 1-LC 1-LC' 42A 9423 943A 943B J _____q H I i lH l l. ~ <c-:4 -l l t>e l l 1-850A 1-8500 SCREENS To RHR l h CONTAI!NENT SLCIP B h To"RHR i l Figure 6 - PPND Containn ent Sump Schematic

I LT 72 LT LT 90 C6 [ \\ BORIC ACID TANX .TI: # '105 (1 of 3) /, . TE g 107 \\ h

LOCAL,

(- n '3TO C!MP,3IMG m SAMFLE' ' PU!iPS From BAT From BAT G. S [1 SI-V4 [ 1-827A 2 ( M v( O, _O 3 C\\/ [ h82ifA 1-0278 \\ g TO UNIT 2 / U SI Pumps 1 -826C TO SAFETY. EE -INJECTION ! c ? ^tlMPS E E Figure 7 --PBNP Born-Acid Storage. Tank Schematic

r --+ V ent I l l INSIDE I FR0:1 FACADE I CVCS S T

4 FUEL REFUELING PIT OVERFLOW WATER e

FILTER 1TI STORA'iE l I-LIA 1-1729 [ 6 920 960 TAfiK - LO (1-T13) gg IQ l-LIA r; h 1-893A 1-8938 920' - LO-Lo A j LO / 8 REACT 0'l V LOCAL __ LOSS OF COOLANT l-SI-Y14 1-893C A >+4 ? SAMPLE LEVEL DRAlil I-890 PUMPS CVCS --_.SR-J ?'7 ~ )_. l -3 5 )1 -SI-01 From Boric li!SIDEFACADE( DRAlfi Acid Tanks ,,0 .C. F r 1897A ~ 1 r 1-82SA } \\I S '.L p SI l REFUELITG F.C. jg-WATER ff vfnps Tel-----% CIRCULATIriG ' b,1 -897 8 1_ 1-820 puttp (ACS) 1-8250 REFUELI?n "0 !-1 Co'}-- N--- ---s VJAT ER RETURN 1-742 (ACS) From Test Line 1-A0V j _ggs j _ ggt rj_ 825C 'i L.0. Containment Spray N --CE Pumps 1-870A r1 L _1 l ^ 1-870B To RHR Pumps Figure 8 - PBNP Refueling Water Storage Tank Schematic l'

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cy ;[r 1-868A 1-862A - lC t 'A DM g p iP'3Y 1$g.013t 1 -DiBA I-07M A' 1-840A 1-8400 t !OZILES l LC][1.cc4A --> 4-- 00:1Tili $ PRAY I I-0600 PuttP 1-P14A 1-871A b r' C0iiliti $ PRAY ,)I I Cross Connection EDUCT 03 and to Test Line 1-PIA 93 0 y --I :- gg 'b %g'7}g I_f Relief valve 1-8643 )(1-873A I'0 IIA 1-063C 1-3998 dit o ot-4 G,*:' i IIEAT EXCil r 1-SSSA Q 5 1-3 j9C d ' AIL 1 -P.4 cA To Test Line f,* L* sy-Lo 1-YIC / ' j.(f '916A~ [ 1-'I SPRAY AD3ITIVE 'c 932 TA;;K 911 ' 1-Fg F0 LO '- 1-T3a a ~ o~ 'o 'o ,,,_c q. I-8493 -6W 1 333A 1.c49E 3r1SI-V13 1.;gy.836A 3 -FIT LO ,L O,, M {930 [$bB III ilA DRA1I ~ 'I I3 ][l 31C 3 LOCAL 1 -lCV -3363 i SAM.PL E (1-831DblC 1-863B TO C0'111ti 926n' SFRAY From RWST EDUCTOR D 1 rain 8 Figure 9 - PBNP Containment Spray Systen Schonatic (showing Train A only)

KEY TO FIGURES --{>4-140RiMLLY OPEN GATE VALVE M NOPJMLLY CLOSED X GLOBE VALVE NEEDLE VALVE [ CHECK VALVE D REDUCER AIR DIAPHRAGM OPERATOR ELECTRICAL MOTOR OPERATOR SAFETY RELIEF VALVE CAPPED PIPE PROPORTI0tlAL CONTROLLED AIR OPERATOR g P1,.._R ll BLIND FLANGE HEAT EXCHANGER FLOW RESTRICTOR lll FLOW RESTRICTION ORIFICE' SAUNDERS PATENT DIAPHRAGM VALVE h TEMPERATURE INDICATOR . h. LEVEL INDICATOR h FLOW INDICATOR., h_ PRESSURE INDICATOR

i LTST OF TAI!LES Title Ta bl.e No. HIGH !!EAD SAFETY INJI:,CTIOti SYSTtC1 MAINTER%CE OUTAGES 1. 1-1 (a) Accumulators ania Injection Lines in Containment - Unit 1 1-1 (b) Refueling Water Storage Tank - Unit 1 1-1 (c) High Head Safct Injection Pumps and nehtted - Unit 1 Injection Lines Outside of Containment 1-2 (a) Accumulators and Injection Lines in Containment - Unit 2 1-2 (b) Refueling Water storage Tank - Unit 2 1-2 (c) High Head S.;tety Injection Pumps and helat.ed Injection Lines Outside of Containment - (Init 2 2. LOW IIEAD SAFETY INJECTION SYSTEM MAINTEMANC2. OUTAGES Low Ifeack Saf ety Injection System - Unit 1 2-1 '2-2 Low Ilead Safety Injection System - Unit 2 'J..CONTAIIO1ENT SPRAY SYSTEM MAINTENANCE OUTAGES 3-1 Containment Spray Syste:a - Unit 1 3-2 Containment Spray System - Unit 2 COMPONENT COOLING WATER PUMPS MAINTENANCE OUTAGCS '4. 1 4-1 Component Cooling Water Pumps - Unit 4-2 Ccmponent Cooling Water Punpa - Unit 2 5. BORIC ACID STORAGE TANKS MAINTENANCE UUTAGES - UNIT 1 AND 2 SERVICE MATER PUMPS MAINTENANCE OUTAGES - UNIT -1 AND 2 6. ~HIGH HEAD SAFETY INJECTION PUMPS TEST AND ROUTIllE MAINTENANCE 7. OUTAGES .7 - 1. High Head Safety Injection Pumps - Unit 1 2 7-2 !!igh Head Safety Injection Pumps - Unit 8. RESIDUAL HEAT REMOVAL PUMPS TEST AND ROUTINE MAINTENANCE OUTAGES-8 Residual Heat Removal Ptunps.- Unit 1

1 Residual Heat Removal Pumps - Unit 2 8-2 PUMPS TzST AND EOUTINE 21AINTEUANCE 9.. COMPOMEST COOLl!!G NATER OUTAGES 1 9-1 Component Cooling Watcr Pumps - Unit 2 9-2 Component Cooling Water Pumps' - Un2.t TEST AND ROUTIME MAINTRNMICE OUTAGCS -

10. SERVICE WitTE2 PUMPS UNIT 1 AND 2

11. INSERVICE TEST CUTAGES

12. TECHNICAL SPECIFICATION SURVEILLANCE TEST OUTAGEb

13. SERVICE WATER PUMPS PERIODIC CHECK TEST OllTAGE!i e

b b 4-

1 ~ REFERENCES Tables 1 thru 6 Syste:a and Equioment Maintenance Outage Data is tabulated from the following cources: Maintenance Requests (XXXXX) Modification Requests (M-XXX) Licensee Event Reports (LER-YR-OXX) Significant Operating dvent Reports (SOS-YR-GXX) Westinghouce Drawing Number 1iOE017 Sheet 1 of 3, Revision 22 Sheet 2 of 3, Revision 16 Sheet 3 ef 3, Revision 14 Machinery Histories Technical Specifications Station Los3 Annual Operating Reports-Tables 7 thru 10 Test and Routine Maintenance Outage Data is tabulated'from the following sources: Call-up Cards-High-Head Safety Injection Pumps (Table 7) Call-up Cardo - Residual Heat Removal Pumps (Table 8) Call-up Cards - Component Cooling Water Puraps (Table 9) Call-up Cards - Service Water Pumps (Table 10) Table 11-Inservice Test Catage Data is taLulated from the Operations Department. These tests are requirec by Technical Specifications and are in accordance with ASME Code, Section IX, liiP, Subsection 1100. Source' data. for this-table is at the beginning 'of Table 11 and data. lists the tests used to compile the Taole 12 Technical Specification Surveillance Test Outage D 'a is tabulated fron the Operations Department. Source data for this -table is at the beginning ot Table 12 and lists the tests used to compile the data. Table 13 Periodic' Check Outagen for Service Water Pumps Data is tabulated from Periodic Check:No. 16 (PC-16). -

CONCLUSIOff In accordance with the " Clarification ot 'IT4I Action klan - Requirements" letter issued by the imC in SeptemMr of 1 W,0, all of the outage data was re'riewed to determine if any changes couit l be made to improse unavailability time of the h::lergency Core Cooling System Eculpment. The. results of this review have determined tnat there van no - significant trend of broahdotaw or replacenients for any or the components in the Emergency Core Cooling Systera There was +.130 no indication that a problem ekisted for any of tne cc:re.nn - compenents in the system.. It ha:s also been determanec that tne testina program.is adequate and asaants in identirying poseable problem areas. G =f 4 f k G . -) ; + --.a.m.

s .g. TABLE 1 Sheet - 1 of 6 HIGil HEAD SAFETI INJECTION SYSTEM MATNTF.NAtEE OUTAGES.. - (Jnit 1 1-1(a) s Accunsuulators' and Injection Lines in Containment. Dates and Corrective Action' 'Ienoth Re f. Cause of Outane fomeonent Mr E e t b I 5 e i 4 [ >e e F vf a

TABLE 1 1-1 (b) Refueling Water Storage Tank - Unit 1 Cheet 2 of 6 Dates and Com ponent Ref Caune of Outaoe correerive Action Length MVO-8258-25919 After valve remains shut for a period of Increased "open torque setting 2/25/80 a SI. pump suction time it will not open. Only'an inter-9 hr from RWST mediate position indication is received. MOV-0253 22025 Failed to open completely on first test Checked torque setting and cycled 1/10/79 attempt valve 5 hr MOV-825b 15407 Packing leak Replaced valve stem, tightened packing 1/30/76 as much as possible, took current 15 hr readings MOV-825A 15406. Packing leak Repacked stem, tightened packing 1/30/15 is nr MOV-856B 19277 Will not open on first attempt Lubricated stem 6/23/77 5 hr* HOV-656B 19521 Valve does not open without manual Increased torque setting on 6/5/78 assistance opening torque switch 6 hr* H0V-870A 14699 bevel gear. housing cover hold down/- Removed broken studs and replaced 2/4/76 KWST to lifting stud broken oft with steel bolts 9 hr Containment Spray Ncw AOV added to M-129 Valve should be added and controlled Completed and functional test 9/4/79 SI line such that when 826B and C leave the 8 hr . botween valve shut condition the AOV will shut. 894 and check valva 895 MOV-836B (SOE-80 Only opened 20% during testing Cycled shut and then opened okay 4/26/76 -007', 4 hr* CNo outage require.d for maintenance work e

a TABLE 1 1-1 (c) liigh lleaa. Safety II. ject. ion Pumps and Related Injection Lines Outside of Containment - Unit 1 Sheet 3 of 6 Dates and cbmionant per cause of Outaqo correct ive Action 1,ena t n Bd9A 17646 Plugged up - no water will flow through Pressurized with air to frco drain 12/18/76 SI purap dcck vnive 6 hr* OV-89th 14699 Devel gear housing cover hold down/- Removed broken studs. Itoplaced with 2/4/76 litting stud broken ofi 3/8 in socket head stool bolta 9 hr OV-86tA 19502 11eeds repacking Repacked 11/12/77 sI Pump 11L Chalgd on 6.5 hr nld leg ) injection line OV-865D 19502 Needs packing adjusted or repacking Repacke'd with 187I 11/21/77 l 8.0 hr >tio outage required for maintenanco work

4 a TABLE-l 1-2 (a). Accummulators and Injection Lines in Containment - Unit 2 Sheet. 4 of a Dates and 'Comgonent Ref Causo of Outage Corrective Action Length DV-878D 18521. Norm i.ever ground, defective,'needs Worm replaced with a new ground one 4/30/78 replacing 14 hr DV-878D '23871 Electric interlock prevents valve from Adjusted "Open" limit w itch 4/7/ 9 4 stroking 4.5 hr* N3 outage required for maintenance work.. e e 9 e e e e

TALLE 1 1-2 (b) Refineling Water Storage Tank - Unit 2 Shcct 5 of 6 Dates and Compone rat Ref Cause of Outaae Corrective Action Lenqth 3V-856A 18122 Valve motor overheated and tripped Tightened stem nut, lock nut, replaced 5/15/77 IR Pump breaker motor was very hot gaskets on handwheel mechanism. 9 hr .setion from Adjusted torque ( 4ST 3V-870A 213:46 Packing leak Repacked with 1871 and 1625 4/16/79 antainment 7 hr pray punp action from 24719 Packing leak Repacked with 187I and 1625. Moved 4/22/80 DST lantern ring oft bottoi.1 of valve for 7 nr better packing seal J e

a TABLE 1 1-2 (c) High Head Saf ety Injection Pumps and Related Injection Lines Outside of Continment - Unit 2 Sheet 6 of 6 Dates and Component Ref Cause of Outane Corrective Action Ler.qt h '15B SOE-Found rough motor bearing Inspected - found oil ring improperly 4/17/77

o SI Pump 77-007 installed. Replaced bearing 14 itr 287 olist Valve.

21958 Repair and test Relapped and cut nozzle and disc seats. 9/1/79 Installed new bellows protection to body 14 hr and gasket. Set litt prossure at 1,745 psi. Leak test ok @-924 15909 Leak at flow orifice for core Meluge Replaced with new flexatallic gaskets 7/28/76 93angs orifice and retorqued 7 hr 6-887 M-172 Require upgrading of valve to raise Installed rew relief valve, rebuilt 10/11/76 design pressure of SI relief f or new set pressure not available /15A 27857-Sheared coupling and keys Replaced pump rotating assembly, 11/17/80 %" SI' Pump LER-80 replaced motor rotor coupling and 36 total hr -010 assembly U.2 H.S.D 12 hr l i15A 28178 Outboard end overheated and started Installed new shaft sleeve and seal 12/3/80 Q# SI Pump to leak 9 hr o u.

TABLE 2 TDW HEAD SAFETY INJECTIOt3 SYSTEM Malt 3TENANCE OUTAGES 2-1 Low 11ead Safety Injection System - Unit 1 Sheet 1 of 3 Dates and Component Ref Cfuse of Outane Corrective Action Length TCV-626 19425 Leaks through with air in service Readjusted travel on stem for closing 2/26/79 MIR !!x Dypass 6 hr* 27618 Flx a bad leak inside the cover of Replaced valve stem and parts 9/18/d0 the valve positioner 4.5 hr ICV-624# 19288 With 501 set on the controller, the Adjusted I/P and lbnit switch. 7/5/77 n.c **A Plow valve is only 10% open Stroked valve 4.5 hr Control Valve Air Regulator 15475 Regulator has a ruptured diaphragm Replaced diaphragm, installed mis sing 2/17/76 Gor 11CV-6254 retaining rings 4.5 hr JDV-701 16186 Ilas a leak Installed new gasket 11/b/77 IMIR Suction 14 hr 8solatica Valve 904A 18923 Packing leak Repacked 11/29/77 yanual Suction 9 hr Valva from Loop A Ilot Leg 9DV-850B 24759 Did nct open during testing Changed Pl! directional valve 2/5/d0 SOE-9 hr 80-002 MOV-851B 18927 Oil leak where the valve stem enters the Packed with 1625 and 1871 11/30/77 ' Sump "B" to B motor operator and packing leak in the 9 hr lMIR Pump R11R pump suction valve gallery Crosby 3XLX4 M-455 Setpoint of the RI!R satery valve should. Change of valve springs, valve spring 6/5/76 21R Safety be changed from 625 psig to 500 psig. washers, reassembly of the valve, 21.5 hr 5hlve Change requires removing spring, veritying readjustment of setpoint and tcsted new set point and changing name 1:llo outage required for maintenance work eMaintenance data lists this valve as an llCV. Westinghouse drawing reference lists valve as FCV.

~TABLL 2 2-1 Low 11ead Saf ety Injection System - Dnit 1 Sheet 2 of 3 Dates and Component Ref Cause of Outage Corrective Action Ienqth T/-625# 19288 Wi'ch the controller set at $0%, the Adjusted I/P and limit switch. 7/5/77 4.5 hr* b1R lleat ' valve is only 20% open schang:r Outlet CV-525s 25963 Doesn't stroke properly Slight adjustment of zero 8/7/80 4.5 hr CV-6255 25287 Doesn't have full stroke capacity Adjust I/P and stroked valve 10/4/79 4.5 hr Maintenance data lists this valve as an IICV. Westinghouse drawing reference lists valve as FCV.

4 TABLE 2 2-2 Low !!ead Satety Injection System - Unit 2 sheet 3 of 3 Dates and Compon~nt Ref Cause 'f Outane Corrective Action Lenoth @-6200. 22171 Only opens 70% checked limit switch-Checked I/P and. stroke status 4/18/79 arm movemont 4.25 hr 6-625# 22214 Flange leak Changed gasket and added new packing 4/18/79 9 ht' iA 21320 Packing leak Repacked with 1871 and gratoil 4/16/79 llot ' Lig - 9 hr i ction Line f '7Am 21323 Flango leaks Replaced flange gasket 4/17/79 6.5 hr a 21323 Flange. leaks Replaced flange gasket 4/17/7) l 6.5 hr 03 *50B SOE-Valve tailed to stroke during testing by Valve opened and closed using mar.ual 7/19/u0 J 80-006 control room actuation back up. Elcctrical repaired - replaced 4 hr with new valve 19-351B 16221 Breaker trips after 15 sec Cycled valve and adjusted torquo 7/14/77 SOE-setting 5 hr 77-008 rosby M-456 Set point of the R:1R satety valve to be Cnange of valve springs, valve spring 6/5/78 KLX4 R11R changed from 625 psig to 500 psig. washers, reassembly of valve, 11.5 hr afety valve Change required removing spring, verify-readjustment of son point and tested ing new set point and changing name Flaintenance. data lists this valve as an t!CV. Westinghouse drawing reference-lints valve as IVJ.

l TABLE 3 CONTAItMEtiT SPPaY SYSTD4 MAI!1TENANCE OUTAGES 3-1 Containment Spray Systesa - Unit 1 Sheet 1 of 2 Dates and Ccantonent Ref Cause of Outage Corrective Action Length 14B 21374 Breaker has a badly bent latch lever Racked out breaker and straightened b/30/78 and lever bracket latch lever and lever Lracxet. kacked 7 hr breaker b:tch in DV-860B 15391 During test closing of valve, breaker Inspected, f ound valve stem dry. 1/21/76 tripped on overload. After resetting Lubed and stroked valvo a few times 6 hr breaker, manual cycling of valve was difficult. bntainment LER-Relay would not latch during testing. Readjusted latch and tested 3/18/80 pray R21ay 80-003 The latching mechanism was misaligned 4.5 hr t

TAbL2 3 3-2 Containment Spray System - Unit 2 Sheet 2 of 2 Dates and Component Ref Cause of Outage Ccrrective Acticn 1.enoth '14A 26's58 Casing drain plug leaks Put Teflon tape on plug and 7/8/30 26598 tightened 5 hr 27208 Motor side flango 1caks Replaced flexitallic gasket 7/8/80 14 hr CV-836B 17216 Valve failed to travel full stroke, Valve had numerous problems: 1/21/77 uOu Idditive stops at 75%

1. Valve has been swapped and 6.5 t.r labeled u?q (cv)

2. Found I/P reg. set at 60 psi reset at 20

3. Found valve reg. set at 30 psi reset to 70 4.

Found valve stroke zero way of f - reset

5. Found the open limit switch operating at 251 stroke. Reset to operate at 100% open OV-860C LER-Starter broaker overloads tripped Reset 78-005 DV-860C 20912 Breaker overloads and trips Installed a new torque switch and 6/16/78 LER-adjusted torque setting on new switch 9 hr 78-007 TT-930 22208 Inlet Ilange leak Replaced flange seal 4/6/79 spray additive 6 hr

low

'T-930 13575 Transmitter has a flange leak Replaced gasket and calibrated 3/10/77 spray additive 4.5 hr ank flow ransmitter

i I TA14E 4 i COMPONENT COOIJNG WATER PUMPS MA'lNTENANCP. OUTAGES 4-1 Component Cooling Water Pumps - Unit 1 Sheet 1 or 2 Dates ana component Ref cause of Outano corrective Action Jenqth H11 A 115653 Mctor side leaks' Replaced motor side seal and bearing. 4/23/76 o Component Aligned motor to pump. Wolded jacket 49 hr boling Pump screws to motor base to align motor 15291 Check pump f or excessive thrust move:nent Installed new QA bearing and oil seal 2/26/76 34 hr 21654 Outboard seal has excessive' Installed new mechanical seal bearing 8/17/78 and leakage and oil seal 21319 22528 Excessive seal leakage on outboard motor Replaced seal and bearings 11/13/78 24 hr Illa '24488 Outboard mechanical seal leaking Replaced mechanical seal and outboard 1/25/d0 ?At* Cotaponent bearing 14 he boling pump 4h. 21710 Valve failed to seat for 30 sec after Built up stop by weldiuj. Disc was 8/17/78

• cch. Check pump was secured jamming on sides of valve 9 hr Iva on 1P11A 9

9

) i TABLE 4 4-2. Component Cooling Water Pumps Unit 2 Sheet 2 of 2 Dates and component Ref' cause of Outano corrective Action 14noth P11A '18772 Inboard seal leans Replaced bearing and mechanical seals 11/30/77 CAO. Component 19 hr Opoling Pump 21569 Uses a lot of oil Installed new auto-oiler and new piping 7/14/78 to bearing cover. Dralled small vent 8 hr hole in vent plug 20505 Inboard seal has excessive oil leak Installed new oil seal 3/2/78 4 24 hr 21291 Excessive end float in pump shaf t. Installed new bearings and new -9/7/78 Replace bearing and oil. seal mechanical seal 14 hr I 16579 Has. excessive oil leakage on inboard keplaced inboard oil seal and put in 9/28/75 bearing a new mechanical seal 24 hr , P11B 21212 Noisy. mot 6r bearing Cleaned motor and replaced bearing 6/26/80 "B" Component 14 hr ' Cooling Pamp; 21025 Excessive vibration of bearing Replaced motor and pump bearing, ground 6/27/80 impeller ror balance. Replaced seals 24 hr and gaskets 18780 Excessive vibration checked coupling alignuent and found 9/24/77 motor low. Shimmed 0.010" on motor 9 hr l l l-I t

1 g o d 1 na t it e st e eo e h tn S a e. 4 Df no 2 i t m c. l T A a 1 v i T t I c N e U rr oC S E GATUO E $J N 5 ET E N L I B A A M T S KNA e O T E e G a A a R .t O u T O e S n f o D o N I C e A su C a T C RO B_ a e M Q 3 ^ in m [ g op mo C e b

m. l' l' TABLE 6 SERVICE WATER PUMPS MAINTENANCE OUTAGES - UNIT 1 AND 2 Sheet 1 of 1 -Compone n .Ref Cause of Outage D2A-Corrective Action Dates and Length 24438 Excessive seal leakage Tight (ned packing and greased stuffing box 11/2W/79 h2A'. '15790 -Need to: dismantle, inspect, replace 6 hr ~ impellers, repack,-stuffing box, test Replaced bronzed impellors with .run and return to service stainless steel and reassembled. 7/14/70 44 hr D23. Repacked stuf fing oox with gratoil 15790 Dismantle, inspect, replace 3mpellers, ' Replaced bronzed impellers with repack stuffing box, test run and return to service stainless steel and reassembled. 7/14/76 54 hr i Repacked sturfing box with grafoil amp ditcharge 1929( Kck valve - . Appears to be stuck open Post on valve disc worn. Made and 7/7/77 installe'd new post h2C' 20116-24 hr High vibratice on pump motor ~ Analyzed'by W,i vibration analysis 1/20/78 f2C group. No correction required 6 hr 21567 Excessive vibration 3 vibration analysis person.nel brought onsite to evaluate the pump. 11/3/78 7 hr No correction required. 2C 21611 Upper bearing making a lot of noise Replaced both upper thrust bearings 7/26/78 p discharge. 19180-21.5 hr seck valve. Stuck open when pump is secured l pressure drops Cleaned up bore in clappor arm made new 6/10/77 disc post. Installed post with interrace 14 hr tit and seal welded on back side t i I I t

llIl 1 1 I l ) ,!!]' li l l l ll 2 f o 1 e t c e n e a h n S e tn i a M r r r r r r r r r r r e r r r r h h h h h h h h h h h h h h h h r o 6 t "I 5 8 5 5 0 6 6 7 5 8 S 5 0 f 1 1 3 I 1 3 S in E i G T A 6 9 6 9 T 6 8 9 0 7 7 7 6 8 9 0 1 7 7 t 6 7 7 7 3 / 7 / 6 7 7 7 8 / 7 / 1 O 7 / / / / 9 / 0 7 / / / / 9 / 0 e / 7 7 0 5 2 1 1 / 7 7 0 5 2 1 1 E t 9 1 i 1 1 / / / 9 1 1 1 1 / / / c a / / / / / 0 1 0 / / / / / 0 1 0 h D 2 1 1 1 1 1 1 1 2 1 1 1 1 1 1 1 A 1 1 ? !T t N i T n A U N RN a I p T m l u tO P R n D o F i A t n 7 c e T e k E S j a L E n T L T I A n T S y o P t i e e o o o o o e o o e o o o o e 1 o t n n n n n n n n n n n n n n n n I! I t c o o o o o o o o o o o o o o o o P a A D D D D D D D D D D D D D D D D S N O d l l T a i i T e o o C H E r r J h f i f i N g o o o o I i fd v fd v H son r son r Y t a sc t a e T us gs us s E 1 nas n o 'o nas aee F ep irs ep grs A 7 mrm r a mrm n a S eau a go eau i ge t p enr t p rnr D sn big sn ai g A o n r in er i.oarag o oabag r e mi u vdieoen vdie en li d l etrtbi l etrrbi e atcao l atcao l G c vae mpp vae tpp T o cjp mu cjpomu H r oonmduo oonmmuo P tliuepc tli u pc a pt a pt csy coo csy cee ietyegg iotyegg rvoapnn rveapnn blt rsaa b l f. rsaa uaapnhh ua pnhh LvssIcC LvmsICC p A B m 5 5 a 1 1 P G .P ,l

J TABLE 7 7-2 liigh 11ead Safety Injection Pumps -' Unit 2 Sheet 2 of 2 , Pumn Procedure Action Taken Date Tirm for Maintenance .P15A Lubricate valve stem nuts of valves located in area of safety injection pumps and spray pump ares Inspect motor bearings Change pump bearing reservoir oil Change coupling grease Done 2/9/76 6 hr Done 1/17/76 6 hr Done 1/17/78 7 hr Done 1/10/79 5 hr Done 1/15/ 80 8 hr Done. 4/2/77 10 hr Done 4/12/78 10 hr Done 4/28/80 10 hr P15D. Lubricated valve stem nuts of valves located in areas of ~ safety injoction pumps and spray pump area Inspect notor bearings Change pump bearing reservoir oil Change coupling grease Done 2/9/76 6 hr Done 1/17/76 6 hr Done 1/4~*/78 7 hr Done 1/10/79 5 hr Done 1/15/80 8 hr Done 4/2/77 10 hr Done 4/2/78 9 hr Done 4/23/80 9 hr

i TABLE 8 RESIDUAT, HE AT ret 40 VAT, PUMPS TEST AllD ROUTINE MAINTEN ANCE OUTAGES 8-1 Residual Heat Removal Pumps - Unit 1 Sheet 1 of 2 ump Procedure Action Taken Date Time for Maintenance '.10 A Change pump bearing oil Grease valve stem nuts Grease motor (remove drain plugs while greasing) Done 10/30/76 5.5 hr Done 5/8/78 6 hr Done 2/5/79 5.5 hr Done 6/9/80 6 hr Done 2/5/79 5.5 hr ?10B Change pump bearing oil Grease valve stem nuts Grease motors (Remove drain plugs while greasing) Done 10/30/76 5.5 hr Done 5/8/78 6 hr Done 2/5/79 5.5 hr Done 6/9/80 6 hr Done 2/5/79 5.5 hr

a TABLE 8 8 -2 Residual' heat Removal Pumps - Unit 2 Sheet 2 of 2 Pump Procedure Action Taken Date Tite for Maintenance P10A . Change pump bearing oil Grease valve stem nuts Grease motor (Remove drain plugs while greasing) Done 7/19/77 5.5 hr Done 7/11/78 6 hr Done 2/5/79 6 hr Done 3/31/80 5 hr Done 2/5/79 5.5 hr P103 Change pump bearing oil Grease valve stem nuts. Grease. motor (Remove drain plugs while greasing) Done 7/19/77 5.5 hr Done 7/11/78 6 hr Done 2/5/79 6 hr Done 3/31/80 5 hr Done 2/5/79 5.5 hr

TABLE 9 COMPO!:ENT COOLING WATER PUMPS TEST At40 }]UTINE MAINTENANCE OUTAGES 9-1 Component Cooling Water Pumps-Unit 1 Sheet 1 of 2 amp Procedure Action Taken Date Tine f or Maintenance 11A Grease valve yoke nuts in whole area Lubricate coupling Drain and refill pump bearing housing Grease motor (: Remove drain plugs while greasing) Done 2/9/76 5.5 hr Done 2/9/77 5 hr Done 1/10/78 5 hr Done 1/10/79 6 hr Done 3/31/80 6 hr Done 1/15/79 6 hr '13 Grease valve yoke nuts in whole area Lubricate coupling l Dra.n and refill pump bearing housing Grease motor (Remove drain plugs while greasing) Done 2/9/76 5.5 hr Done 2/9/77 5 hr Done 1/10/78 5 hr Done 1/10/79 6 hr Done 3/31 80 6 hr / Done 1/15/79 6 hr

TAh!.E 9 9-2 Component Cooling hts.r Pumps - LAtit i Eheet 2 or 2 Purap Procedure Action Take33 Ikst e Titdt for flaintenance 'P11A Grease valve yoke nuts an wt. ole area Lubricato coupling Drain and refill pump bearing housing Grease motor (Runove drain heraove draan plu a while greasing) Dono v 2/9/7b 5.5 hr Done 2/9/77 5 hr Done 1/10/7tf 5 hr Done 1/1's/73 6 hr P113 ' Grease valve yoko nuts an whole area Lurar1cate coupling Droit.'and retill pump bearing housing Grease motor (Remove drain plugs while greasing) Dono 2/3/76 5.S br Done 2/s/77 5 nr Done 1/10/7u 5 hr Don. 1/lL/TJ b hr Donu 3/31/bo 6 str Done 1/15/79 6 hr

. _.. ~ t 4 TABLE 10- .SERVTCE WATER - PUMPS TEST AND ROUTINE MATNTENANCE OUTAGES - UNIT 1 A'D 2 - SilEET 1 OF 1 .Euuirm*nt-Procedure Action Taken Date Time for Maintenance

P32A,B,C l Change oil in upper D;E,6F

' bearing Done 10/26/76 o hr Done 10/21/77 6 hr Done 9/30/78 6 he l i Done 11/4/79 10 hr Done 9/2c/80 12 hr l Y I

Sheet 1 of 19 TABLE 11 INSERVICE TEST OUTAGES Index of Tests: IT-01 liigh Head Saf ety Injection Pumps - Unit 1 IT-02 High 11ead Safety Injection Pur:rps - Unit 2 IT-03 Low 11ead Safety Injection Pumps - Unit 1 IT-04 Low Head Safety Injection Pumps - Unit 2 IT-05 Spray Pamps S Eductor Supply Checx Valven 847AGS - Unit 1 IT-06

f. pray Pu:nps & Eductor Supply Check Valven 8471$5B - Unit 2 IT-07 Rotation of Service Water Pumps P32A,B,C,D,E IT-30 Chemical and Volutae Control Valves - Unit 1

-IT-35 Chemical and Voluna Control Valves - Unit z IT-40 Safety Injection Valves - Unit 1 IT-4S Safety Injection Valves - Unit 2 y IT-50 Containment Sprsy Velves - Unit 1 IT-55 Containment spray Valves - Unit 2 KEY: Estimated times from control operators . Total _ time for test run, does not include any line-up as per initial conditions. The +4 hrs takes into consideration line-up time. CL-7A and SA are valve position check lists used at Point Beach Nuclear-Plant.

4 TABLE 11 Sheet 2 of 19 INSERVICE TEST 01TAGES Inservice Test No. 01 (SIS is lined ap as per CL-7A) Test No. Date_ Train A OOS* Ig3in B UOS* IT-01 1/27/78 1.25 hrst + 4 hrs 1.25 hrs # + 4 nrs IT-01 2/24/70 1.2S hrst + 4 hrs 1.25 hrso + 4 hra IT-01 3/24/70 1.25 nrst + 4 hrs 1.25 hrs # + 4 hrs IT-01 4/29/73 1.25 hrse + 4 hrs 1.25 hrs # + 4 hrs IT-01 5/26/78 1.25 hrse + 4 hrs 1.2S hrse + 4 hrs IT-01 6/23/78 1.25 hrs # + 4 hrs 1.25 brs* + 4 hrs IT-01 7/28/78 1.25 hrs # 4' 4 hrs 1.25 hrs / + 4 nru IT-01 8/2b/78 1.25 hrst + 4 hrs 1.25 nrse + 4 hrs IT-01 10/12/76 1.25 hrse

• 4 hrs

1. 25 nrn e-

• 4 nrs IT-01 10/27/78 1.25 hrs # + 4 hrs 1.25 hrst + 4 hrs IT-01 1~/24/73 1.25 hrse + 4 hrs 1.25 hrst + 4 hrs IT-01 v2/22/7G 1.25 hrse + 4 hrs 1.2 5 hrs + + 4 hrs Total Time OOS tor 1978: 63 hrs 63 hrs IT-01 1/26/79 1.25 hrs * + 4 hrs 1.25 hrs # + 4 hrs IT-01 2/23/79 1.25 hrst + 4 hrs 1.25 nrs# + 4 hra IT-01 3/23/79 1.23 hrs 1 + 4 hrs 1.25 hrst + 4 nrn IT-01 4/27/79 1.25 hrse + 4 hrs 1.25 hrss

+4 hrs IT-01 5/25/79 1.25 hrse + 4 hrs 1.25 nrse +4 nrs IT-01 6/29/79 1.25 hrst + 4 hrs 1.25 hrs # + 4 hrs IT-01 7/27/79 1.25 hrc# +4 hrs 1.25 hru# + 4 hrs IT-01 8/26/79 1.25 nrs# + 4 hrs 1.25 nrne + 4 hrs IT-01 9/28/79 1.25 brs# + 4 hrs 1.25 hrst + 4 hrt IT-01 10/20/79 1.25 hrse + 4 hrs 1.25 hrow + 4 hra IT-01 .11/24/79 1.25 hrst + 4 hrs 1.25 hrse + 4 hrs IT-01. 12/29/79 1.25 hrse + 4 hrn 1.25 hrst + 4 hrs Total Time OOS for 1979: b3 hrs IJ hrs ~~ 1T-01 1/25/80 1.25 hrs # + 4 hrs 1.25 hrse + 4 hrs IT-01 2/22/80 1.25 hrs? + 4 hrs 1.25 hrst + 4 hrs j IT-01 4/5/B0 1.25 hrst + 4 hrs 1.25 hrst + 4 nrs IT-01 4/27/80 1.25 hrse + 4 hrs 1.25 hrst + 4 hrs IT-01 5/24/80 1.25 hrs # + 4 hrs 1.25 braA + 4 hrs IT-01 7/1/80 1.25 hrse + 4 nrs 1.25 hrst + 4 hrs - IT-01 8/12/80 1.23 hrs #.+ 4 hrs 1.25 hrs * + 4 hrs IT-01 8/15/80 no test 1.5 hrs IT-01 9/3/d0 1.25 hrs * + 4 hrs 1.25 brst +.4 hrs - 1T-01 10/3/80 1.25 hrst + 4 hrs 1.25 hrse + 4 hrs IT-01 10/31/80 1.25 hrs # + 4 hrs 1.25 hrst + 4 hrs IT-01 12/1/80 1.25 hrs #'+ 4 hrs 1.25 hrst + 4 hrs IT-01. 12/27/80 1.25 hrs # + 4 hrs 1.25.hrst + 4 hrs Total Time OOS ' for : 1960: $!! hru 60.5 hrs

TABLE 11 Sneet 3 or 10 g!SETWICE TEST OfM%GIiS Inservice Test No. 02 (SIS is lit ed up as per CL-7A) Tert No. Date Train A 00S$ Train B GOS* IT-02 1/27/78 1.25 hrss + 4 hrs 1.25 hrst + 4 nrs I'r-Oe 2/24/70 1.25 hrst + 4 hrs 1.25 hrc# + 4 nrs IT-02 3/28/78 1.25 nrst + 4 hrs 1.25 nrst + 4 hrs 17-02 4/16/78 1.25 hrse + 4 hrs 1.25 nrc# + 4 hrs .IT-02 4/29/78 1.25 hrse + 4 hrs 1.25 hrse + 4 hrs IT-02 5/26/78 1.25 hrst + 4 hrs 1.25 hrst + 4 nr.s IT-02 6/23/78 1.25 hrst + 4 nrs 1.25 hrse + 4 hrs IT-02 7/28/78 1.25 hrsA + 4 hrs 1.25 hrst + 4 :.ra IT-02 8/26/78 1.25 hraf + 4 hrs 1.25 hrse + 4 nrc IT-02 9/22/78 1.25 hrs * + 4 hrs 1.25 hrst + 4 hrs IT-02 10 27/78 1.25 hrc# + 4 hrs 1.25 hrse + 4 iirc / ~ IT-02 11/24/78 1.25 hIa# + 4 hrs 1.25 hrse + 4 hrn IT-02 12/22/78 1.25 hrs * + 4 hrs 1.25 hrse + 4 hrs Total Time OSS for 1978: 68.25 hrs 68.25 hrs ~~ IT-02 1/26/79 1.25 hrst + 4 hrs 1.25 hrst + 4 hrs IT-02 2/23/79 1.25 hrs # + 4 hrs 1.25 hrse + 4 hrs IT-02 3/23/79 1.25 hrs * + 4 hrs 1.25 hrse + 4 nrs IT-02 4/11/79 1.25 hrst + 4 hrs 1.25 hrst + 4 hru IT-02 4/27/79 1.25 hrse + 4 hrs 1.25 hrst + 4 hrs IT-02 5/25/79 1.25 hrsy + 4 hrs 1.25 hrs # + 4 hrs IT-02 6/29/79 1.25 hrst + 4 hrs 1.25 hrse + 4 hrs IT-02 7/27/79 1.25 hrse + 4 hrs 1.25 hrst + 4 nrs IT-02 8/26/79 1.25 hrs # + 4 hrs 1.25 nrse + 4 hrs IT-02 9/28/79 1.25 hrse + 4 hrs 1.25 hrse + u hre IT-02 10/26/79 1.25 hra# + 4 hrs 1.25 hrse + 4 hrs IT-02 11/24/79 1.25 hrst + 4 hrs 1.25 hrst + 4 nrs Total Time DOS for 1979: 63 hrs b3 hrs IT-02 1/25/80 1.25 hrs * + 4 hrs 1.25 hrst + 4 hrs IT-02 2/8/80 1.25 hrsr- + 4 hrs 1.25 hrst + 4 hrs IT-02 2/22/00 1.25 hrse + 4 hrs 1.25 hrs # + 4 hrs IT-02 3/22/60 1.25 hrse + 4 hrs 1.25 hrse + 4 hrs IT-02 5/10/80 1.25 hrse + 4 hrs 1.2S hrse + 4 hrs IT-02 5/24/80 1.25 hrs # + 4 hrs 1.25 hrs # + 4 hrs. IT 7/1/80 1.25 hrse + 4 hrs 1.25 brat + 4 hrs IT-02 8/2/80 1.25 hrs * + 4 hrs 1.25 hrst + 4 hrs TT-02 9/2/80 1.25 hrs; + 4 hra 1.25 hrse + 4 nrs IT-02 10/3/80 1.25 hrst + 4 hrs 1.25 hrse + 4 hrs IT-02 10/31/80' 1.25 hrs # +4 hrs 1.25 hrse + 4 hrs IT-02 11/17/80 1.25 hrst + 4 nr3 1.25 hrst + 4 hrs .IT-02 -11/18/00 1.25 hrst + 4 nrs 1.25 brs#'+ 4 hrs IT-02 12/2/ 80 1.25 hrs # + 4 hrs 1.25 nrsi

• 4 hrs

TABLE 11 Sheet 4 of 19 INSEFVICE TEST OUPAGLO Inservice Test No. 02 (SIS is 1ined up as per CL ~/A) Teest' No. Date Train A OOSf Train is 00:2* IT-02 12/3/d0 1.25 hrst +4 hrs 1.25 hrc> + n hrn Total Time OOS for 19ts0: 73.5 nrs EU./.5 hra m e ]

• e,

~ I m f m t-t q ' ^ 'l t. J' i ~ 4 _= .n

I T.'.P L F. 11 Sheet, 5 co 1's ItJSMVICE TEST OUT!.G!.S Inservice Test Mo. 03 (SIS is lined up.ns per CL-7A) Tent !!o. DAte Train A CC.i* Train b OOS* IT-03 1/13/78 1.25 brst + 4 hrs 1.2s bra; + u an + 4 hrs 1.25 hens + 4 2.r3 IT-03 1/27/78 1.25 hrn+ IT-03 2/10/78 1.25 hrut

• 4 hrs 1.25 hrst + 4 nrn IT-03 2/24/78 1.25 hrst + 4 hrs

1. 2 5 hrn e + 4 *irn IT-03 3/10/78 1.25 hrs * + 4 hrs 1.25 ars+ + n oca IT-03 4/ 14/78 1.25 hrst + 4 hrs 1.25 nrse + 4 : rc IT-03 5/8/7e no test 1.25 hrnt + 4 pro

+ 4 hrs 1.25 hest IT-03 5/12/78 1.25 hrst + u nre IT-03 6/9/70 1.25 hrsi + 4 hrs 1.25 hrst + 4 t r3 IT-03 7/14/78 1.25 hrse + 4 hrs 1.25 nrs* + 4 're IT-03 8/11/78 1.25 hrse + 4 hrs 1.25 hrst + 4 ors IT-03 9/6/78 1.25 hrst + 4 hrs 1.25 hrst + 86 ru IT-03 9/11/78 no test 1.25 nest + 4 .cc 10-03 9/13/78 no test 1.25 nrse + 8. nr3 IT-03 9/13/78 1.25 hrsr + 4 hrs no tect 4' hrs 1.25 nrss + 4 nrn IT-03 11/10/18 1.25 hrst + IT-03 12/8/78 1.25 hrsr

• 4 hrs 1.25 h ar + :; nrs

= Total Time OOS for 1978: 73.5 hru 84.0 hrs IT-03 1/12/79 1.25 hrs * + 4 hrs 1.25 hrst + 4 new IT-03 2/9/79 1.25 hrse

• 4 hrs 1.25 hrst + 4 bru IT-03 3/9/79 1.25 hrse + 4 bra 1.25 brs$ + 4,nrs IT-03 4/13/79 1.25 hrs *
• 4 nrs 1.25 brse + 4 t.r e IT-03 5/11/79 1.25 hrse'+ 4 hrs 1.25 hrst + 4 hrr IT-03 6/15/79 1.25 hrut + 4 hrs-1.25 nrst + 4 :rc 4 hrs 1.25 nrs* + 4 nrs IT-03 7/13/79 1.25 hrst r IT-03 8/19/79 1.25 hrse + 4 hrs 1.25 hree + 4 nrs IT-03 9/7/79 1.25 hrse + 4 hrs 1.25 hrs, + 4 ars

~IT-03 10/9/79 1.25 hrst + 4 hrs 1.25 hrce + 4 ars IT-03 11/20/79 1.25 hra/ + 4 hrs 1.25 braw + 4 hrs IT-03 12/9/79 1.25 hrse + 4 hrs 1.25 brst + a urs = Total Time COS for 1979: b3 hrs 63 hrs IT-03 1/11/80 1.25. hrs # + 4 hrs 1.25 hrs # + 4 hru IT-03 2/0/80 1.25 hrut + 4 hrs 1.25 hrst + 4 hrs IT-03 2/23/80 no test 1.25 hrst + 4 hrs IT-03 4/5/80 1.25 hrs # + 4 hrs 1.25.hrse + ~4 nrs 17-03 u/11/HO 1.25 bra # + 4 hrs '1.25 brse + 4 hrs -IT-03 5/3/80 1.25 hrse + 4 hrs 1.25 hrst + 4 hrs IT-03 5/20/H0-1.25.hrsA + 4 hrs 1.25 hrs * + 4 hrs IT-01 -6/21/80. 1.25 hrst + 4 hrs 1.25 hruw + 4 hrs IT-63 7/25/80-1.25 hrst + 4 hrs 1.25 hrus + 4 hrn IT-03 8/22/u0 1.25 hrsA +.4 hrs 1.25 hrse + 4 hrs

d n TA!M.E 11 Sheet 6 or 19 INSERVICP, TEST 01)fAGES Inservice Test No. 03 - (SIS is lined up as per CL-7a) 'rnin A OOS* Train 15 COS* 1 Test No. Date IT-03 9/26/80 1.25 hrse > 4 hrs 1.25 bruf + 4 isru IT-03 10/25/80 1.25 hrc/ + 4 hrn 1.25 hree + 4 firn IT-03 11/23/u0 1.25 hrs / & 4 hrs 1.25 hrst +4 nri. IT-03 12/20/80 1.25 hrse + 4 hrs 1.2S best +4 1.rn Total Time OOS for 1980: bd.25 hrs 73.5 hrs i J s i f 4 4 t 6 m L s)

TA3LE 11 sheer 7 or 1 'f INSERVJCC Trr.T GUTAW S I nnervice Test 14o. 04 (SIS is linmi up as per CL-/h) W nt No. D.ite Tric.n A (KG

• Tr< tin n 095+

IT-04 1/1;/78 1.25 hrse +4 hrs 1.25 hrer + 4 : ire IT-04 2/10/70 1.25 hrse + 4 hrs nu test 1T-04 2/10/78 1.25 hr3# + 4 hrs 1.25 hrst + 4 u. IT-04 2/10/78 1.25 hrs # + 4 bra no test IT-04 3/10/78 1.2S hrse + 4 nra 1.25 hrsi + 4 ite IT-04 4/16/78 1.25 hrse + u hru 1.25 brav + 4 n r.1 IT-04 4/29/7a 1.25'hrst + 4 hrs 1.25 hras + 4 nro IT-04 5/9/78 1.25 bras + 4 hrs r.o tout IT-04 5/12/78 1.25 hrs * + 4 hrs 1.25 hrs * + 4 hru IT-04 6/9/78 1.25 hrs * + 4 hrs 1.25 brse + 4 f.rs IT-04 7/14/78 1.25 hrst + 4 hrs 1.25 hrst v 4 hrs IT-04 7/15/78 no test 1.25 hrst + 4 nra IT-04 8/11/78 1.25 hrse + 4 hrs 1.25 brst + 4 brs IT-04 9/8/78 1.25 hrs # + 4 hrs 1.25 hrst + 4 hrs IT-04 10/13/78 1.25 hrs # + 4 hrs 1.25 hrst + 4 hrs IT-04 11/10/78 1.25 hrse + 4 hrs 1.25 nrst + 4 hrs IT-04 12/8/78 1.25 hrs * + 4 hrs 1.25 nrst + 4 hra Total Time 00S for 1978: 84 hrs 73.5 nrs IT 1/12/79 1.25 hrst + 4 hrs 1.25 hrse + 4 hrs IT-04 2/9/79 1.25 hrs * + 4 hrs 1.25 hrs * + 4 nra IT-04 3/9/79 1.25 hrse + 4 hrs 1.25 hrse + 4 nrs IT-04 4/13/79 1.25 hrst + 4 hrs 1.25 brst + 4 hrs IT-04 5/11/79 1.25 hrse + 4 hrs 1.25 brat + 4 nrs IT-04 6/15/79 1.25 hrsa + 4 hrs 1.25 nrst + 4 hrs IT-04 7/19/79 1.25 hrs # + 4 hrs 1.25 hrs / + 4 hrs IT-04 F/10/79 1.25 nrse + 4 hrs 1.25 hrse + 4 hrs IT-04 J/10/79 1.25 hrse + 4 hrs 1.25 hrst + 4 ! rs IT-04 10,"1/79 1.25 hrs # + 4 hrs 1.25 hrst + 4 hrs IT-04 11/9/79' 1.25 hrse + 4 hrs 1.25 hrst + 4 hrs IT-04 12/8/79 1.25 hrs * + 4 hrs 1.25'hrst + 4 hts Total Time 003 for 1979: 84 hrs 73.5 IT-04 1/11/80-1.25 hrse + 4 hrs 1.25 hrst t 4 hrs-IT-04 2/8/80 1.25 hrse + 4 hrs 1.25 hrse + 4 nrs IT 3/16/80 1.25 hrst +4 hrs 1.25 hrst + 4 hrs IT-04 3/13/00 1.25 hrs / + 4 hrs 1.25 hrst + 4 hrs IT-04 3/28/80 1.25 hrsA +4 hrs 1.25 hrsA + 4 hrs IT-04 5/11/80 1.25 hrs # + 4 hrs 1.25 hrse + 4 bru .IT-04 5/12/80 1.2S brse + 4 hrs 1.25 nrst + 4 nrs IT-04 5/30/80 1.25.ars# + 4 hrs 1.25 brat + 4 hrs IT-04 6/19/80 1.25 hrse + 4 hrs 1.25 hrse + 4 1.cs IT-04 6/21/80-1.25 hrst + 4 hrs 1.2's hrst + 4 1.rs IT-04 6/23/00 1.25 hrse + ': bra no test

i TAB

• C l'

bricot 8 vi l'1 It1SCRVICR TES7 OUTI.Gh8 Inservice Test !!o. 04 (SIS is lined up as per CL-7A) Test 1:n. Dite' Trait A OOS* Tr a i n n ( >0.

• i IT-04 7/25/80 1.25 hrs * + 4 hrn 1.25 hrce + 4 _:s 1T-04' 8/22/30 1.25 hrn/ + 4 h r.1 1.25 h:.se

+4 .n Ir-04 9/26/b0 1.25 hrst + 4 hrs 1.26 hrc> + 4.ru IT-0.4 10/25/d0 1.25 hrss + 4 hrc 1.25 hest + 4 c. c 3 IT-04 10/29/80-1.25 hrse.+ 4 hr:n n> test IT-04 10/30/80 1.25 hrsi + 4 hrn no tee,t IT-04 11/23/80 1.25 hrce + 4 hra 1.25 tirns + 4 'tr i 17-04 12/23/80 1.25 href + 4 hrs 1.25 hrcs + c P:s Total Time COS tor 1990: >9.75 hrs tu nrc i b i L \\ l e A Y N 4 r s ( .k.

o TABLE 11 9 ot W INMERV7CE TEST OllTAGES Inservice Tent No. 05 (SIS is lined up as per CL-7A) Tast No. Dato Train A OO!i* Train H 00".* IT-05 1/20/ 8 0.5 hrst + 4 hrs 0.5 brse + 4 hrs 7 1T-05 2/17/78 0.5 hrs # + 4 hrs 0.5 hrne + 4 hrs IT-05 3/17/78 0.5 hrse + 4 hrs 0.5 href + 4 hru IT-05 4/21/78 0.5 hrse + 4 hrs 0.5 hree + 4 hra IT-05 5/19/78 0.5 hrs # + 4 hrs 0.5 brat + 4 nrs 1T-05 6/16/70 0.5 hrsA + 4 hrs 0.5 hrs # + a hrs IT-05 6/30/78 0.5 hrst + 4 hrs 0.5 brot + 4 hrs IT-OS 7/21/78 0.5 hrs, + 4 hrs 0.5 hrne + 4 hrs IT-05 8/ 18/78 0.5 hrse + 4 hi s 0.5 hrst + 4 hru IT-05 9/15/78 0.5 bess + 4 hrs 0.5 hrne + 4 hrs IT-05 10/12/73 0.5 hrs # +4 hrs 0.5 hrse + 4 hrs IT-05 10/20/78 0.5 hrst + 4 hrs 0.5 hrse +4 h.c n IT-05 11/17/!8 0.5 hrs * + 4 hrs 0.5 hrue + 4 nrc IT-05 12/15/78 0.5 hrst + 4 hrs 0.5 hrse + 4 hrs Total Time OOS :or 1978 63 hrs 63 hrs IT-05' 1/10/79 0.5 hrse + 4 hrs 0.5 hrst + 4 h.cs IT-05 2/16/79 0.5 hrse + 4 hrs 0.5 hrse + 4 hrs IT-05 3/17/79 0.5 hrse + 4 hrs 0.5 hrse + 4 n:s If-05 4/20/79 0.5 hrst + 4 hrs 0.5 hrse + 4 nrs IT-05 5/18/79 0.5 hrst & 4 hrs 0.5 hrst + 4 hi s IT-05 6/22/79 0.5 hrse + 4 hrs 0.5 hrse + 4 hrs IT-05 7/20/79 0.5 hrst + 4 hrs 0.5 hrse + 4 hrs IT-05 8/18/79 0.5 hrst + 4 hrs 0.5 hrs # + 4 hrs IT-05 9/14/79 0.5 hrs e + 4 hrs 0.5 hrst + 4 hrs IT-05 10/26/79 0.5 hrse + 4 hrs 0.5 hrut 4 hrs + IT-05 11/21/79 0.5 hrar +4 hrs 0.5 hrse + 4 hrs IT-05 12/14/79 0.5 hrse + 4 hrs 0.5 hrse + 4 hrs Total Time OOS for 1979: 54 hrs 54 hrs IT-05 1/8/00 0.5 hrse + 4 hrs 0.5 brse e 4 hrs IT-05 2/16/80 0.5 hrst + 4 hrs 0.5 hrst + 4 nrs IT-05 4/5/80 0.5 hrse & 4 nrs 0.5 hrsw

• 4 hrs IT-05 4/13/80 0.5 hrst + 4 hrs 0.S,hrst + 4 hrs IT-05 5/16/80 0.5 hrst + 4 hrs 0.5 nrat + 4 hrs IT-05 6/13/80 0.5 hrst + 4 hrs 0.5 hrnr + 4 hrs

^ IT-05 7/18/80 0.5 hrse + 4 hrs 0.5 hrnw + 4 hrs IT-05 8/16/80 0.5 brs* + 4 hrs 0.5 hrJ# + 4 hr t IT-05 9/19/80 0.5 hrne + 4 hrs 0.5 hrst + o hr. IT-05 10/18/u0 0.5-brse + 4 hrs 0.5 hrst + 4 ni s IT-05 11/17/B0 0,5 nrst + 4 hrn 0.5 hrne + 4 hrs 1 IT-05 12/28/30 0.5 hrse + 4 hrs 0.5 hrne + 4 hrs ~ Total Time'OOS tor 1980: 54 hrn 54 hrs

TABLE 11 SI:eot 10 n. 1) INS L:WIrt. TE::T OT'Mirl Innervice Test to. 06 (SIS is lj nc:t up as per CL-b) Test No. Date Tran: A 00:a Train t1 OOM+ IT-Ob 1/20/78 0.5 hrs t +4 hre o.5 hrs * + 4 h; s IT-06 2/17/70 0.5 hrse + 4 hrs 0.5 nru* + 4 ha IT-06 3/3/78 0.5 hrst + 4 hrs 0.5 hrut + 4 hrs IT-06 3/17/73 0.5 hrst + 4 hrs 0.5 hrse + 4 nrs IT-36 4/16/78 0.5 hrst + 4 hrs 0.5 hrst + 4 acs IT-06 5/19/78 0.5 hrut + 4 hrs 0.5 hrst + 4 his IT-Ob 6/16/78 0.5.hrst + 4 hrs 0.5 hrst + 4 hrs IT-06 7/21/78 0.5 hrs # + 4 hrs 0.5 hrst + 4 bcs IT-06 8/ 18/78 0.5 hrse + 4 hrs J.5 hrst + 4 hrs IT-0 6 9/15/78 0.5 hrst + 4 hrs 0.5 hrst t 4 hru IT-06 10/20/78 0.5 hra# + 4 hrs 0.5 hrs * + 4 hrs IT-06 11/17/78 0.5 hrse + 4 hrs 0.5 hrs * + 4 hrs IT-06 12/15/78 0.5 hrs # + 4 hrs 0.5 hrs 7 6 4 hrs Total Time OOS for 1978: S8.5 nrs Sb.5 hrs IT-06 1/9/79 0.5 hrst + 4 hrs 0.5 hrst + 4 hrs IT-06 2/16/79 0.5 hrse + 4 hrs-0.5 hrse +4 hrs IT-06 3/17/73 0.5 hrst + 4 hrs 0.5 hrse + 4 brs IT-06 4/11/79 0.5 hrs * + 4 hrs 0.5 hrs # + 4 hrs IT-06 4/20/79 6.5 hrs # + 4 hrs 0.5 hrse + 4 hrs IT-06 5/19/79 0.5 hrse + 4 hrs 0.5 hrse + 4 hr;s IT-Ob 6/22/79 0.5 hrst + 4 hrs 0.5 hrsa + 4 hrs IT-06 7/20/79 0.5 hrs * + 4 hrs 0.5 hrse + 4.v. s IT-06 8/17/79 0.5 hrs # + 4 hrs 0.5 hrs? + 4 nrc IT-06 9/14/79 0.5 hrse + 4 hrs 0.5 hrse + 4 nrs IT-06 10/19/79 0.5 hrse + 4 hrs 0.5 hrse + 4 brs IT-06 11/16/79 0.5 hrst + 4 hrs 0.5 hrs 7 + 4 hrs IT-06 12/14/79 0.5 hrse + 4 hrs 0.5 nrs# +4

r. :s Total Time 00S ror 1979: 5875 hrs 50.5 hrs IT 1/18/80 0.5 hrs #

+4 hrs 0.5 hrs # + 4 hru IT-06 2/16/80 0.5 hrat + 4 hra 0.5 hrss + 4 hrs IT-06 3/15/80 0.5 hrse + 4 hrs 0.5 _ hrse + 4 hrs IT-06 5/11/80-0.5 hrse + 4 hrs 0.5 hrst + 4 hrs IT-06 6/7/80 0.5 hrse + 4 hrs 0.5 nrst + 4 hrs IT-06 6/13/530 0.5 hrs # + 4 hrs 0.5 hrs # 1 4 hrs IT-Ob 7/8/80 0.5 hrse + 4 hrs no test IT-0 6 7/18/60 0.5 hrs * + 4 hrs 0. :) hrst + 4 hra IT-06 8/16/80 _0.5 hrs * + 4 hrs 0.5 hrs # + 4 h:s I'r -0 6 9/19/80 0.5 hrue + 4 hrs 0.5 hrse + 4 bra-IT-Oo 10/18/80 0.5 hrst + 4 hi s 0.5 nest + 4 nrs IT-06 11/80/00 0.5 hrst + 4 hrs 0.5 hrst + 4 hcs IT-06 12/17/80-0.5 hrse + 4 hrs 0.5 nrs# + 4 hcs Tor.al Tune 003 f or 1980: 58.4 hrs 54 nrs

TTDLE 11 Sheet 11 ut 19 I ftC Ei4 V I C P. T E!j]T O tJT A G E S Inservic+* Test !!o. 07 (Normal 2-Unit Full Po W r Service E ter Lineup) ^ T.ent tio. Datt-Rotatioa & Tirt.e OOS ItotritJ on n Time. 00.", 17-07 1/11/78 P32toD 1 hr + 4 hr P32 lgs I hr + 4 hr IT-07 1/25/76 P32B;E 1 br + 4 hr P3/CGF 1 hr + c ht I', -0 7 2/9/78 P32C6F 1 hr + 4 hr P32Ar.D 1 hr + 4 hr IT-07 2/22 78 P32A&D 1 hr + 4 hr P32861 1 he v 4 hr / IT-37 3/8/78 P32 BEE 1 hr + 4 hr P32Cor 1 nr +

• hr IT- 07 3/23/7u P32h0F 1 hr + 4 hr P32 ADS 1 hr d 4 hr IT-07 4/s2/78 P32bCU 1 hr + 4 hr P32CGF 1 1.r + a hr n -07 4/20/78 P32Ct.F 1 br + 4 hr P.L:A6D 1 hr +

hr IT-07 5/10/78 P326&D 1 hr + 4 hr F32BGE 1 fir + 9 hr IT-07 5/24/78 P323SE 1 hr + 4 hr P22 CSP 1 hr : a hr 11-07 b/14/73 P32C0F 1hr+4 hr P3/A;D 1 hr + 4 hr IT-07 b/28/78 P 3 2.'.S D 1 h r + t, hr P323S E 1 h e + <> F r it-07 7/12/78 I-32DGE 1 hr + 4 hr P3;CEF 1 br < nr 4 IT-07 7/22/78 P32btF 1 hr + 4 hr PS2AuD 1 hr, a hr I~'-0 7 7/2tt/7 H P32C6F 1 hr + 4 hr no test IT-07 8/9/78 P32ASD 1 hr 4 4 nr P32rGE 1 1.r + 6 nr IT 8/23/78 P32P.GE 1 hr + 4 hr P32 CSP 1 hr + 1 hr IT-07 9/13/78 P32CFD 1 br + 4 hr P321.DP 1 hr + 4 hr-1T-07 9/27/78 P321s&D 1 hr + 4 hr P32bGE 1 hr +.. hr IT-07 10/14/7b P323CE 1 hr + 4 hr P32E5E 1 hr + 4 br IT-07 10/25/78 P32C6F 1 hr + u hr no test 1T-07 11/8/78-P32ASD 1 hr + 4 hr P32c6h 1hr+4 hr IT-07. 11/24/7s. P32BGE 1 hr + 4 hr P32C&F 1 hr + 4 hr IT-07 '12/6/78 P32C6F 1 hr.+ 4 hr P32AOD 1 hr + ': hr IT-07 12/20/78 P32ACD 1 hr + 4 hr P32dSC 1 hr + % hr Total time'OOS. for P32A: 85 hrs Total time 00S for P32B: 85 hrs Total time 00S for P22C: 80 hrn Total tine 00S for P32D: 80 hrs Total. time COS for P32L: 85 brs . Total time OOS for-P3"F: 80 hrs a

e s TABLE 11 Sheet 12 of 19 _INShiNICE_ TEST OilTAGES Inservice Test No. 07 (Normal 2-Unit Full Power Service Water Lineup) Test No. Date Rotation & Tim OO;i Rotetion G Ti.me OOS 1T-07 1/3/79 P3236E 1 hr + 4 hr P32CCF 1 hr + 4 hr IT-07 1/17/79 P32C6F 1 hr + 4 hr P32LGD 1 hr + 4 hr IT-07 1/31/79 P32A6D 1 br + 4 hr P32uGE 1 br + 4 hr IT-07 2/14/79 P32PSE 1 hr + 4 hr P32 CSP 1 hr + 4 nr IT-07 2/214/79 P32C0F 1 hr + 4 hr P32?.G D 1 hr

• a-hr IT-07 3/19/79 P3/A5D 1 hr + 4 hr 03236h i tr + 4 hr IT-07 3/30/79 P32CbF 1 hr + 4 hr P32hr.D 1 hr + 4 hr II-07 4/25/79 P32A6D 1 hr + u hr P3236L 1 he + 4 'r IT-07 5/9/79 P32 ICE 1 hr + 4 hr P'.S e C6 F 1 he + 4 nr

.IT-07 S/23/79 P32CCF 1 hr + 4 hr P32A6D 1 hr + t nr IT-07 6/19/79 P32h6D 1 hr + 4 hr P32hCF 1 hr + 4 hr 1T-07 7/5/79 P32F6L 1 br + 4 hr P32 Cur 1 hr 4 t. hr L 1T-0 ~/ 7/20/79 P32CGF 1 hr + 4 br P327.SD 1 br > <a hr IT-07 8/1/79 P32A6D 1 hr + 4 hr P32BSL 1 hr + 4 hr 1T-07 8/15/~t 9 r32DSE 1 hr + 4 hr . P3aCSF 1 hr + + hr IT-07 9/2/79 P32CSF 1 hr + 4 hr P32/4D 1 hr + 4 hr IT-07 9/26/?9 P32E6E 1 hr + 4 hr P3/C& F 1 hr + 4 hr IT-07 10/10/79 P32CCF 1 hr + 4 hr P32ALD 1 hr + 4 h.: IT-07 '10/17/79 P32AGD.1 hr + 4 hr P32DSE 1 hr + 4 hr IT-07 10/24/79 P32LGr. 1 hr + 4 hr P32/4D 1 hr + 4 hr I"'-0 7 10/31/79 P32B&E 1 hr + 4 hr P32CSF 1 hr + 4 tr 'IT-07 11/18/79 P32CSF 1 hr + 4 hr P32ALD 1 hr + 4 hr -IT-07 11/28/7? P32ASD 1 br + 4 hr P32B03 1 hr + 4 hr IT-07 12/13/79 P32BCE 1 hr + 4 hr P32Cr,F 1 hr + 4 h; IT-07 12/26/79 P32C6F 1 hr + 4 hr P321GD 1 hr + 4 hr Total time OOS for P32A: 85 nrs Total time COS for P32B: 80 hrs Total time OOS for P32C: 85 hrs Total time OGS for P32D: 80 hrs Total' time 00S for P32E: 95 hrs 9 Total-time 00S for.P32F:. 80 hrn u

-= TABLE 11 Sheet 13 u:: 39 _INSE:1VTCE TFST GUTAGE.1 Inservice Test No. 07 (Gormal 2-Unit Full Power service Nter Lineup) Ter.t No. Date Rotation 6 Time OOS helt,$ tion

t. T29; offj IT-07 1/9/80 P32n6D 1 hr + 4 br P32BSc 1 hr + 4 hr IT-07 1/25/30 P32B5E 1 hr + 4 hr P32C&F 1hr+4 nr IT-07 2/20/60 P34CSF 1 hr + 4 hr P32h60 1 hr t 4 ht 1T-07 2/20/80 P32AGD 1 hr + 4 ar P32BLE 1 hr + 4 hr IT-07 3/5/80 P32Bf.E 1 hr + 4 nr P s2 Ch t' 1hr+4 hr IT-07 3/19/80 P32C6F 1 hr + 4 hr P32A6D 1 hr + 4 hr IT-07 4/2/00 PJ2;dD 1 br

• 4 hr PJ2BGE 1 br + :I hr IP-07 4/3/80 P32Ar.D 1 br + 4 hr P32 Hot. 1 hr +. Lr I?-07 4/16/G0 F32D62 1 hr + 4 hr P32C6F 1 hr e 4 hr IT-07 5/1/80 P32C&F 1 br + 4 hr P32ALD 1 hr + 4 hr IT-07 5/14/80 FJ2ACD 1 nr + 4 hr P32nSE 1 hr + 4 hr IT-07 5/28/H0 P32bGE 1 hr + 4 hr P'52Cr,F 1 hr e I Pr IT-07 6/11/80 P32 cdp 1 hr + 4 br I32A69 1 hr + o hr IT-07 6/25/SO P327.oD 1 hr + 4 hr P32:36 E 1 nr + 4 hr IT-07' 7/9/80 P32BGP. 1 hr + 4 hr P32Ct;P 1 hr + 4 hr IT-07 7/23/80 P32Cd7 1 hr + 4 hr P22AbD 1 nr + 4 br IT-07 8/6/80 P32ACD 1 hr + 4 hr P3236E 1 bc *

+ hr IT-07 8/20/80 P32BCs 1 nr + 4 hr PadO6F br+4 nr ~ IT-07 9/17/80 P32A6D 1 hr + 4 hr P3250E 1 br + 4 hr IT-07 9/30/60 P32BCF 1 hr + 4 hr P32 ADD 1 br + 9 hr IT-07 10/1/80 P32DGE 1 hr + 4 hr P32C&F i br + 4 hr iT-07 10/7/80 P32CSF 1 hr + 4 hr P32ACD 1 hr + 4 hr IT-07 10/15/SO P32CSF 1 hr + 4 hr P32A6D 1 hr + 4 hr 17-07 10/29/80 P32CSF 1 hr + 4 hr P32ALD 1 hr + 4 hr IT-07 11/12/00 P32SE 1 hr + 4 hr P32CcF 1 hr + 4 hr IT-07. .11/26/80 P32CSF 1 hr + 4 hr P32A&D 1 hr + 4 nr IT-07 12/10/80 P32ASD 1 hr + 4 hr P32ESE 1 hr + 4 hr IT-67 12/26/80 P32BGE 1 hr + 4 hr p32CLF 1 hr & 4 hr Total time DOS i for P32A: 100 hrs Total tbne DOS for P32D: 100 hrs Total time OOS for P32C 95 hrs Total time DOS for.P32D 90 hrs Total time OOS for P32L 95 hrs Total time 005 for-P32F 95 hru 9 u - u

l l TADIE 11 Sheet 1/..i." I : INSERVlt!!i TLET ODTAGELJ Incervier? Test No. 30 (CVCS is linen up as per C1.-5,-) i Tent. tio. Dhte Trnan A_OOSS Triini D (VVi* IT-30 1/1e,/78 0.25 hrs # + 4 hrs 0.25 rirnA + 4.uc IT-30 4/21/70 0.25 hraa + '4 hrs U.2S hu; r + 4.:re. 17-30 7/17/18 0.25 hrse + 4 hru 0.25 hrao + a tir;a IT-30 10/1b/78 0.25 hrst +4 hrs 0.25 hree + o ur t, Total Ti:ne OOS for 1978: 17 brS 17 hrs, IT-30 1/.5/79 0.25 hrr# + 4 nra 0.25 hrce + c hrc IT-30 4/16/79 0.25 hrse + 4 hrs 0.25 brsA + (* .~.r s IT-30 7/13/79 0.25 hrst + 4 hrc 0.25 hrs / 4 4 n r. n IT-30 10/12/79 0.?S hrse +4 ars 0.n hra s- +

• arn i

l Total Time OOS for 1979: 17.hrc' ~ 17 hrs l IT-30 1/12/80 0.25 hrse +-4 hrs 0.25 hrs * + 4 hru l IT-30 4/1/80 0.25 hrse + 'I hrs 0.25 hrse + 4 hrs l IT-30 7/11/80 0.25 hrs # + 4 hra 0.25 nrst + 4 nre IT-30 10/11/00 0.25 hrse + 4 hru 0.25 nrse +4 hrn i Total timo 00S for 1980: 17 hrs 17 hrs e i L l b L h h r m

TABLE 11 Sheet 1f c:'19 INSERVICE TEST GUTAG1S Innervice Test No. 35 (CVCS is lined up as per CL-5A) Test No. _Date Train A OOS* Tra in B 003* .IT-35 1/16/78 0.25 bra s- + 4 hrs 0.25 hrs + + 4 hrs IT -35' 4/21/78 0.25 hrst + 4 hrs 0.2S hrse + 4 hrn 17-35 7/17/73 0.25 hrne + 4 hrs 0.25 hrs / + 4 isrs IT-35 10/16/78 0.25 hrse + 4 hrs 0.25 hrst- +4 n r.c. Total Time 003 for 197c1: 17 hr5~ 17 hrs IT-35 1/15/79 0.25 hrse + 4 hrc 0.25 brsr +4 hrs IT-35 4/16/79 0.25 hrst. +4 hrs 0.2S hrst + 4 nrs IT-35 7/20/79 0.2S hrse + 4 hrs 0.25 hrs + + 4 hrs IT-35 10;'2/79 0.25 hru 4 4 hrs 0.!:S hrso + 4 hra Total Titae DOS f or 1979: 17 hrs l'1 nrs IT-35 1/12/30 0.25 brst + 4 hro 0.25 hrst + 4 n:s IT-35 4/11/80 0.25 hrst + 4 bro 0.2S hrat + 4 hra IT-35 7/12/00-0.25 hrse + 4 hrs 0.25 hrst + 4 hrs 'IT-35 10/11/80 0.25 hrs 7 + 4 hrs 0.25 hrs 4 + 4 hrs Total Time OOS for 1900: 17 hrs 17 hrs a O

9 ThDL'i. 11 She < H 'f' U; INSERVI'.'E TEST _ OUTfAQS Inscrvice Tent No. 810 (SIS is lined up ac per CL-7A) Ter,t No. Date Train A GM* Triin U 0036 IT-40 1/9/7ii 0.5 nrs# + 4 hr. c G.5 hrne + 't nrc IT-40 4/14/78 0.5 hrst + 4 hre 0.5 hr.2e * '6 hra IT-40 7/10/7S 0.5 hrni + 82 hra 0.5 hrse + 4 hs IT-40 10/16/?S 0.5 isra s + 4 hrn 0.5 L::31 + 4 hru Total Ti:ne OOS for M74: IU hrs its brs ~ s IT-40 1/3/79 0.5 hrse + 4 hru 0.5 hrse e f6 h rJ. IT-40 4/9/79 0.5 hrs,t + 4 hrt: 0.5 hrno + 4 hrs IT-40 7/7/79 0.S brs/ 6 4 hrt 0.5 hrss + 4 hrs IT-40 10/1/79 0.5 hrse

• 4 nrs 0.5 bror + to su a Total Timo 003 for.1979: 15 brs it! bru IT-40 1/5/80 0.5 brs* + 4 hrs 0.5 brat & 4 hra IT-40 4/7/80 0.5 hrse + 4 hra 0.5 hrne + 4 hrs 17-40 7/5/80 0.5 hrs / + 4 hrs 0.5 hree + 4 hre IT-40 10/b/SO 0.5 hrse + 4 hrs 0.5 hrst + 4 nrn Total Time OCS for :1980: 22.5 hrs 22.5 hrs G

.e Y .l..'_ .a w + e

TABLE 11 Sheet 17 of 19 INSERVICE. TEST OUTAGES Inservice Test No. 45 (SIS is lined '1p as per CL-7A) Test No. Date Train _A OOS* Train B OOS* IT-4 5 1/9/78 0.5 hrst + 4 hrs 0.5 hrst + 4 hrs IT-4 5 4/16/78 0.5 hrst + 4 hrs 0.5 brst + 4 nrs ~ IT-45 7/10/70 0.5 hrs? + 4 hrs 0.5 nrs t- + is nr r. IT-45 10/9/78

0. 5 hrst + 4 hrs 0.S hrse + 4 hrs Total Time OOS for 1978: 10 hrs 18 hrs

~ IT-45 1/8/79 0.5 hrst 4 hrs 0.5 hrst r 4 hrs + IT-45 4/ 14/ 7 9

0. 5 hrs e + 4 hr s 0.5 hrst + 4 hrs IT-45 7/19/79' O.5 hrny + 4 hr s 0.5 hrer

< 4 hra IT-45 11/2/79 0.5 hrst + 4 hrs 0.5 hrn* + 4 hrs . IT-'I S 11/20/79 0,5 hrse + 4 bra 0.5 hrut + 4 hra Total Time OOS f er 1979: 22.5 hrs 22.5 hrs IT-45 1/5/80 0.5 hrst + 4 hrs 0.5 nrs* + 4 hrs-IT-45 4/7/80 0.5 hrst + 4 hre 0.5 hrnr +4 hrs IT-45 7/5/80 0.5 hrst + 4 hrs 0.5 hrs + + 4 hrs IT-45 10/19/80 -0.5 nrs* + 4 hrs 0.5 hrst + 4 hrs Total Tm.e 00S for 1-80: 18 bra It, hrs e e --A - - - - - ' - - - - ^ - ^ - ' ' " ' ^ ^ ' ' ^ ^ ~ ^

3: TABLE 11 Sheet 18 of 19 INSERVICE TEST OUTAGES Inservice Test No. - 50 Tent Nc. Data Train'A OOS* Train B OOS* .I*-50 1/2/75 0.5 hrs / + 4 hrs 0.5 hrse + la hrs IT-50 4/9/78 0.5 hrse + 4 hr.4 0.5 nrse + 4 h r.2 IT-50 6/1o/78 0.5 hrst + 4 nrs 0.5 hrsA + 4, hru IT-50 3/7/78 0.5 hrs:# + 4 hrs 0.5 hrs? 4 4 hru IT-50 10/2/78 0.5 hrs / + 4 hrs

0. 5 hrs # + 4 1.r r Total Time OOS for 1978:

~2.5 bra ~2.1.5 hrs 4 1T-50 2/2/79 0.5 hrse + 4 hrs 0.5 hrs # v 4 hrs IT-50 .4/2/79 0.5 hrst + 4 hrs 0.5 hrse r 4 hrs IT-50 7/2/79 0.5 brse + 4 hrs 0.5 hrs * + 4 hrs IT-50 10/26/79 0.5 hrs * + 4 hrs 0.5 hrs / + <, hrs Total Time OOS for 1979:.1d hrs itt hrs IT-50 1/25/80 0.5 hrs # + 4 hrs 0.5 hrse + 4 hra IT-50 5/o/80 0.5 brse + 4 hrs 0.5 hrst 4 4 :.rs IT 7/25/80 0.5 hrse + 4 hrs 0.5 hrs.* + 4 hrs IT-50 10/18/80 0.5 hrs # + 4 hrs 0.5 hrsa + 4 hrs Total Time.COS for 1Y60: 16 hrs 10 hrs .O e m

TAPLS 11 Cheet 19 of P1 INSERVICE TEST OUTAGES Inservice Test !:o. 55 (SIS is lined up as per CL-7A) Test No. Date Train A OOS* Train B OOS* 17-55 1/2/78 U.5 hrse & 4 hrn 0.5 hrst + 4 hrs IT-55 4/9/78 0.5 hrs-/ + 4 hru 0.5 hrst +4 hrs IT-55 6/16/78 0.5 brar + 4 hrs 0.5 hrse + 4 hrs IT-55 3/ //78 0.5 brse +4 hrs 0.5 hrse + 4 hrs IT-55 10/2/78 0.5 hrst + 4 hrs 0.5 hrs * + 4 hre Total Time 00S for 1978: 22.5 hrs 2e.5 hrs IT-55 2/2/79 0.5 hrst + 4 hrs 0.5 hrse + 4 hrs IT-55 4/2/79 0.5 hrse + 4 brs 0.5 hrse + 4 hrs IT-55 7/2/73 0.5 hrse + 4 hrs 0.5 hrst + 4 hrs IT-55 10/26/79 0.5 hrst + 4 hrs 0.S hrse + 4 hcs - Total Time OOS fcr 1979: 18 hrs 18 hrs ' 1T-55 1/25/80 0.5. hrs * + 4 hrs 0.5 hrs 7 + 4 hrs IT-55 5/6/80. 0.5 nrse + 4 hrs 0.5 hrse + 4 hrs - IT-55 -7/25/80 0.5 hrse + 4 hrs 0.5 hrst + 4 hrs iT-55 10/18/80 0.5 hrse + 4 hrs 0.5 hrst + 4 hrs F Total Time OOS for 1980: 18 nrs la hrs Y r

Sheet 1 of 4 TIiDI.E 12 TECHNIci\\1. SPECIFICATION SURVEIIIANCE TEST-OtJTAGES Technical Specification Surveillance Tests were pertor:ned icr each unit to verify the operabilaty of the Emergency Core Cooling System prior to the AStis section XI Tent ("Innervice Tests l done a in September ot 1977. The test ntweber and system (n) tested are givc.n below: t ^ Test - hunbar-S.yste:n Tasted TS-1A Iligh IIcad Saf ety Injection, Pu:npa and Valves - Unit 1 1 TS -1 B iligh Head Satety Injection, Ptuapa and Valves - Unit 2 TS-2 Low ilead Safety Injection and Valves Units 1 and 2 TS-3 Spray Pittps, NaGH Additive Valves and Suction anri Discharge Valves - Unit 1 and 2 Table' 12 gives the test, date perfomed, test dura cien, and cotal time out or ' service due to testing for each test by unit. a 4 s +- O f I d m m. m-. ..m l u

e Sheet 2 of 4 T7sBLE 12 TECHNICAL SSE.CI?!CATTO'I SURVE!LL?.UL'E TEST ~ Test Total Tine To.st_ Mwaber -Date Duration Out r.f service TS-1A 1/2/76 1 hr 22 nrs (Train A) (Ur.it 1) 2/23/76 1 hr 22 hrs (Train e,) 2/27/76' 1 hr 3/25/76 1 hr 4/23/76 1 hr 5/28/76 1 hr 6/24/76 1 hr 7/22/76 1 hr 8/25/76 1 hr 9/23/76 1 hr '10/27/76-1 hr 11/18/76 1 hr 11/20/76 1-hr 12/23/76-1 hr 1/2t/77~ 1 hr 2/24/77' 1 hr 3/24/77 1 hr 4/28/77 1 hr S/26/77 1 hr 6/23/77 1 hr 7/28/77 1 hr 8/25/77 1 hr LTS-2 1/2/76-0.5 1; h 2 -(Unit 1) 2/12/76 0;5 3/11/76 0. 5. - 4/8/76 0.5 - 5/13/75-0.5 6/10/76

0.5 7/8/76-0.5-8j12/76 0.5 9/9/76

_0.5 10/16/76 0.5 .11/10/761 0.5 11/22/761 0.5 -12/9/76' O.S. 1/13/77-0.5 2/10/77 0.5 3/10/77-0.5 4/14/77 0.5 5/12/77 -0.5 6/9/77 0.5- .7/14/77 0.5 S/11/77 .0.5: 9/.4/77: ! 0.5;

Sheet 3 of 4 TABLE 12 TECHi!ICAL SPECIFICATIO!4 SURVSlf.LAMCE '1 hST Test Total Time - Test liumber Date Ddra tion Out of Service; -TS-3 1/2/76 4 hrs 80 hrs (Unit 1) 1/17/76 4 brs 2/20/76 4 nra 3/ 19/76 4 hrs 4/16/76 4 hrs 5/21/76 4 hrs 6/ 10/76 4 hrs 7/16/76 4 hrs 8/20/76 4 hrs 9/17/76 4 hrs 11/19/76 4 hrs 12/17/76 4 hrs 1/20/17 4 hrs 2/10/77 4 hrs 3/10/77 a hrs 4/22/77 4 hrs S/10/77 4 hrs 6/17/77 4 hrs 7/22/77 4 hrs 8/19/77 4 hrs TS-1B 1/23/76 1 hr 22 hrc (Train A) (Unit 2) 2/27/76-1 hr 22 nrs (Train B) 3/23/76 1 hr 4/23/76 1 hr 5/28/76-1 hr 6/24/76 1 hr 7/22/76 1 hr 8/26/76-1 hr 9/23/76' 1 hr 10/28/76 1 hr 11/25/76 -1.hr 12/23/76 1 hr 1/26/77 1 hr 2/24/77 11 nr 3/24/77. 1 hr ~4/ 17/77 1 hr~ 4/28/77 1 hr 5/26/77 1 hr. 6/23/77 1 hr ~.7/2 8/77_ 8/25/77._ 1 hr' 1 hr a e 6

{ Sheet 4 of r. TAlsLE 12 TECHMTCAL S"ZCIFICATION SUFVEII.l.b.!;Ch Th.ST Test Totcal Time Tent Nt2mber' Date Duration Out of Service TS-2 1/0/76 C.5 hr 11 hrn (' nit 2) 2/12/76 0.5 hr U 3/11/76 0.5 hr 3/24/76 0.5 hr 4/8/76 0.5 hr S/13/76 0.5 hr 6/10/76 0.5 hr 7/8/76 0.5 hr 3/12/76 0.5 hr 9/9/76 0.5 hr 10/1S/76 0.5 nr 11/11/76 0.S hr 12/9/76 0.5 hr 1/13/77 0.5 hr 2/10/77 0.5 hr 3/10/77 0.5 hr 4/14/77 0.5 hr 5/12/77. 0.5 hr 6/9/77 0.5 hr 7/14/77 0.5 hr 8/11/77 0.5 hr 9/9/77 0.5 hr TS-3 1/17/76 4 hrs 80 hrs (Unit 2) 2/20/76 4 hrs 3/19/76 4 hrs 4/16/76 4 hrs 5/21/76 4 hrs 6/18/76 4 hrs 7/16/76 4 hrs 8/20/76 4 hrs 9/17/76 4 hrs 10/22/76 4 hrs /19/76-4 hrs- '17/76 4; hrs ,21/77 4 hrs 1 2/18/77 4 hrs 3/10/77 4 hrs 4/17/77 4 hrs i 5/20/77~ 4 hrs 6/17/77 4 hrs. 7/22/77 4 hrs 8/19/77 4-hrs-

Sheet 1 of ' TABLE 13 SEltVICE WATER PUMPS PERIODIC CI!P.CK TEST OUTAGES Prior to " Inservice Tests" the Service Unter Firnps wt re tested by Periodic Check No. 16 (?C-16) Inservico Testlng of Service hater Pumps P32A-E. Total testing duration was 40 hrs with only 2 ot U pumps out of service at any one time. Fumr;s Teated Date Tent Dt;ra ticn ASD-BSE 10/26/76 2 hrs ( 1 hr/ Set) CSP ASD 11/9/76' 2 hrs (1 hr/ set) AGD-BSE 11/23/76 2 hrs (1 hr/ set) BSE CSF 12/14/76 2 hrs (1 nr/ set) AGD B6E 1/11/77 2 hrs (1 br/ set) ASD 'PSE 1/25/77 2 hrs (1 hr/cet) D C *l CSF 1/25/77 2 hra (1 hr/ set; CSF ASD 2/8/77 2 hrs (1 hr/ sat} ASD USE. 2/22/77 2 hrs (1 hr/ net) ESE CSF 2/22/77 2 hru (1 hr/ set) add BSE 4/12/77 2 hrs (1 hr/ set) Ef,E CSF 4/26/77 2 hr.3 (1 hr/sec) CSF ASD S/10/77 2 hrs (1 hr/seL) ASD BSE S/24/77 2 hrs (1 hr/ set) BSE CSF 6/14/77 2 hrs (1 hr/ set) CSF A6D 6/28/77 2 hrs (1 Irfe. t) BSD) BSE 7/12/77 2 hrs i1 hr/ set! ESE CdF 7/26/77 2 hrs (a hr/ set) CSF ASD 8/10/77 2 hrs (1 hr/ set) ASD BSE 8/24/77 2 hrs (1 hr/ ret.) Repplaced cy IT-07 on 9/19/77 Total Time Our. of Service tor each Pump P32-A 13 hrs P32-B-16 hrs .P32-c 11 hrs TG L-D 14 hrs P32-E 15-hrs P32-F~ 11 hrs e}}