Text

Summary of 851209 Meeting W/Util in Bethesda,Md Re Status Rept on Course of Action.List of Meeting Attendees & Info Presented by Util Encl
	ML20138P884
Person / Time
Site:	Davis Besse
Issue date:	12/17/1985
From:	De Agazio A; Office of Nuclear Reactor Regulation
To:	; Office of Nuclear Reactor Regulation
References
	NUDOCS 8512260322
	Download: ML20138P884 (148)
	v • d • e

{{#Wiki_filter:. December 17, 1985 Docket No. 50-346 LICENSEE: Toledo Edison Company FACILITY: Davis-Besse Unit No. 1

SUBJECT:

STATUS REVIEW - DAVIS-BESSE COURSE OF ACTION MEETING: DECEMBER 9, 1985 On December 9, 1985, Toledo Edison Company presented a status report regarding the Davis-Besse Course of Action. Enclosure 1 is a list of meeting attendees. is a summary of the information presented by Toledo Edison Company. At the conclusion of the presentation, Toledo Edison Company was requested to prepare a brief statement regarding the major issues addressed by-the Course of. Action and the significant accomplishments of the overall program for use at the Commission briefing scheduled for December 18, 1985. 041nal sicum4 W Albert De Agazio, Project Manager PWR Project Directorate #6 Division of PWR Licensing-B

Enclosures:

As stated cc w/ enclosures: See next page PBD-6 ADe Agazio;cr 12 /85 8512260322 851217 PDR ADOCK 05000346 P PDR

i I l Enclosure I 9 TOLEDO EDISON COMPANY - NRC MEETING BETHESDA, MARYLAND DECEMBER 9, 1985 1 Name Organization A. DeAgazio PWR-B/PD-6 Project Manager l

0. Parr PWR-2/PEICS f

D. Kosloff USNRC Davis-Besse R. I. B. O'Connor Ass't. Plant Mgr. Toledo-Edison S. Jain Toledo Edison J. Wood Toledo Edison . p J. Lingenfelter Toledo Edison P. Hildebrandt MPR Associates, Inc. k S. Smith Toledo Edison i T. Myers Toledo Edison J. Williams Toledo Edison J. Hirsch Toledo Edison k J. Williamson Chairman, Toledo Edison O. Mavro Toledo Edison / Stoney K. Farr Toledo Edison M. Stewart Toledo Edison J. Pearson B&W S. Piccolo Bechtel Power Corp. S. Quennoz Toledo Edison [ D. Bauser Shaw, Pittman, Potts & Trowbridge R. Peters Toledo Edison l T. Beeler Toledo Edison l M. Schefers Toledo Edison J. Taylor B&W B. Dunn B&W j R. Ellison B&W S. Mitra Impell D. Ingmire Management Consultants, Inc. M. Fertel Delian Corp. --- :t

I e _2 Name Organization J. Fay Bechtel E. Ray Bechtel C. VanDenburgh USNRC III R. Jones NRS/PBRS D. Crutchfield NRR/PWR-B C. Rossi NRC/IE { I. Jackiw NRC/ Region III D. Persinko NRC/DHFT f G. Cwalina NRC/DHFT P. McKee NRC/IE r A. Howell NRC/IE f J. Sharkey NRC/IE J. Hannah Associated Press l G. Dick NRC/NRR W. Paulson NRC/NRR J. Wermiel NRC/NRR R. Hernan NRC/NRR/PPAS D. Eisenhut NRC/NRR [ J. Keppler NRC/NRR J. Taylor NRC/NRR G. Edison NRC/NRR 4 9 e Oe.gw.-+.-- . ~ -.

h 1 Y NRC/ Toledo Edison Meeting Agenda i December 9,1985 i John R Williamson Introduction Oatman I Joe Williams,Jr. Mission Management Changes, An Senior Vee Presdent Update Nudear s Steve Smith Status of Maintenance AssmentPlantManagec Organization ActMties Mansnan Bill O'Connor Status of Operational AssemntPlantManaget and ProcedumiChanges @alud i John Wood Status of EventInvestigation NudsarPlant (Equipmentinvestigation) \\ SyAemsDredor SushilJain Auxiliary FeedwaterSystem l NudsarSabtyManager Modifications and Decay Heat Removal Phil Hildebrandt independent Process Review Y IPFC Gkuman Committee i Jacque Lingenfetter System Review and Test Program Cparabons 5gw-irogManagw Joe Williams, Jr. Closing Remarks a i i p. _m-~%w-...,. , -. - - - -, -, -.. -, - ~..--,_.-,,-.- ~ _... ---,-.---,--wn.--,--,---- -~-

o i Nuclear Mission Organization ~ Senior Vice President Nuclear f Assistant Vice i President ] CnletofStalfFunction

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!l !I !i Nuclear Nuclear, f Nuclear Nuclear Safety Ouality Nuclear r r nfonnation, I pg,,, Projects l Engineering l Training and Licensing Assurance Services l Management i Gro Director Director Director Manger Director L _up Director __J L _ Director __J Director 4 u i l 4 I i

-c. _#~.,..,...., l; ij 1 ji p--_q i Nuclear l' I Engineering l Gr L _oup Director __J an l1 Il r Nuclear-7 !j l' l Engineering 1

.l Gen L _eral Manager __J 1

.i i r-- 7 Nuclear Facility i Nuclear Plant ,i I Systems Directo,1 Engineering Director L___J 4 l l 4 Advanced l Planning t i l. I I I ( Operations Nuclear M an all ElectJControls E W eg e Engineering Sh Mgr Engineering Engineering j.l Manager Manager En9imin9 Manager Manager 'l 1 i I l I l I

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.__n. . _ - - ~. - -- - -. . ~ ~.. -.- - 1 I ? i i Nuclear Projects Director i I i i f t ,t i l f I I I I I 1 r-- Facility Resource and Cost & l l Modification Commitment Administration Lead Projects Materials L___J Planning Manager Manager Manager Manager Manager ) {

-.4... i i i ] Quality Assurance Director i l 't j j. l 3 I r-- 7 I Ouality i I l Engineering l l Mana L _ _ger J 1, i i l l l i t 4 I I I Code inspection Quality Control Operations OA Quality Systems Supervisor Supervisor Supervisor Supemsor En ine,,,ng 3,,,,,, 4 1 1 i 1 1 I

y .. - -.. ~ ? i i Assistant Vice President. Nukw r r !t Personnel l Administraler l l 1 i a ~ .i i l l i 1 e t t 3 r--- Nuclear Services information l Management l I ~ Dire:ter Director L___J i 2 I I I l' r-- Environmental & r - - , r - - , rDocument Control, Nuclear Fuel Emergency g Special Programs g g Systems Manager l l Ws Mgr l l Correspondence g Computer and Manager Preparedness Manager l Manager Manager

i ? l Summary of Major Changes 1 Within The Nuclear Mission 4 e A new centralized Planning Department, reporting l to the Plant Manager, has been established and an { experienced manager has been hired as Superintendent. e The previous PIant Manager has assumed the duties as head of the expanding Engineering 5 Division. m The Nuclear Engineering Division has been substantially enlarged and is being etaffed. i '~ The position of Nuclear Plant Systems Director has t been filled by the former Manager of Mechanical / ) StructuralEngineering. fI i

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t Summary of Major Changes Within The Nuclear Mission m A new Plant Managerisin place, a The position of Assistant Plant Manager, Operations has been established and filled. e m The position of Assistant Plant Manager, i Maintenance has been established and an i r experienced maintenance manager has been hired i forthat position. m The. Maintenance Department has been reorganized, enlarged, and experienced personnel 8 have been hired for all positions. i l' s The position of Materials Manager has been established. An experienced manager has been hired. Organization is functioning smoothly. l t I f l 4 e l '. zr :,=**- - - - : 2 -- - - ~- - r-rr;= := :::-

i Summary of Major Changes ? Within The Nuclear Mission t a Position descriptions for all management positions in the Nuclear Mission were completed October 15,1985. e All Nuclear Mission personnel, except the Nuclear i ;i Fuel Department, have been moved to the site. .t j u A new Quality Assurance Director has been hired. 1ll m The previous Quality Assurance Director has assumed the position of Manager of the expanding l Quality Engineering organization. 1 ~s m A new Information Management Division has been i formed to provide better management of data processing, records, documents and ,} corre:.,mndence. i i i ( l ' : :rr n::2-

}. ) Summary of Major Changes Completed m New organization structure approved. Staffing Increases from 690 to 930 to more than 990 with Records Management / Document Control, t Procedures and reorganization of QA/QC. r e Salary increase $ approved. 60% of increase on i January 1,1986 and 40% on January 1,1987, depending on performance.

On-shift SRO license bonus increased from $550 to l

$800/ month; on-shift RO license bonus increased t from $485 to $550/ month. l l i l l i e

i l I Recruiting Three Career Days 125 Applicants i 46 Offers 28 Acceptances 3 Offers Pending i 22 Future Offers Being Developed I Two Care'er Days Planned in December 35 Applicants l Manning Status l 644 July 1 f 686 December 1 244 Vacancies (1985 and 1986 positions) f 88 Contractors secunded 1 56 Of those contractors secunded are r engineers l s O -- = --

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1 g g + Reassignment of PEP and SALP Improvement Program Activities High priority-will receive commensurate g j emphasis and resources: } m Prepare detailed position descriptions for new 2 l organization (completed)

i a Merit Review and Salary Administration Program (completed) l a Configuration Management (in process) l' s ManagementTraining(in process)

I a Management By Objectives (resume after restart) a Fire Protection (in process) s Nuclear Mission Procedures (in process) a QA Awareness Program (in process) j i m Non-outage Work Prioritization (resume after j l' restart) .j m STA Assume interim EDO Function (completed) f 1 i L Z 1 1 Z 1 J.1 ~-~~ Z:. Z Z.T :~i

i. Configuration Management 1 [in processD 4 i m Program Manager established - Toledo l Edison /MPR. i a Program Basis: Component / system data base. System descriptions / design basis. I Validated vendor manuals. e' Control of drawing and manuals. l Accurate spare parts allowance. 1 a Plan to beissued l 8 Schedule - completion by December,1987. l 120 man-years of work. l l 8 Prototype program - Four Systems High pressure injection. 4.16 KV electrical system. Instrument air. SFRCS. l f a Containment equipment information walkdowns l 12 teams; 25 people. l I i l ~ i

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,{ t s Configuration Management Plan a Establish the as built configuration of the plant. i E Develop an orWine computerized equipment data base. E Use ashbuilt infonnation to validate design documentig. Wndor drawings and technical manuals Piping & Instrument Drawings Updated Safety Analysis Report (USAR) l E Develop system descriptions which include the following on j both a system and componentlevel: System design bases Limiting Conditions for Operation 1 Technical Specifications requirements E Establish procedures to ensure that all controlled information stays current throughout plant modifications and maintenance. Equipment data base t wndor documentation F System descriptions P & ids and electricalelementaries l l Otherdesign documents l } E Program will be implemented on a system basis. After the prototype phase is complete (approximately 7/1/86), groups of systems will progress through the program. 4 ,..,,,,m_ e- .m-m_._, y ---1,,-.-.----

I i i Fire Protection Program m Interim Fire Protection Compliance Assurance Manager assigned. 8 TWo phase program developed, action plans drafted I November,1985. PHASE 1 Regulat6ryimprovement (October 1985-February,1986). i 830 technical and programmatic issues related to Fire Protection compliance assigned and prioritized. 8 Development of detailed action plans underway. l 8 Final Appendix R assessment (compliance assessment report) with revised exemption requests to be submitted to NRC - March 6,1986. 8 Updated Fire Hazards Analysis Report to be j submitted March 6,1986. L E Revised Technical Specifications to be submitted June 1,1986. I 0 e e M*

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e e f Fire Protection Program 4 a Engineering design package development. FCR'sidentified to date: 64 } FCR's to be completed by 5th refueling: 24 (Engineering scheduled to be completed by 12/31/85) 17 Barrier Modifications (upgrade walls, install new dampers, etc.) l; 6 Safe Shutdown Modifications (reroute / protect cable; j electricalisolation) j FCR's to be completed by 6th refueling: 40 (Engineering scheduled to be completed by 12/1/86) FCR schedule based on a PRA Risk Assessment l PHASE 2 Program development and ongoing i implementation (February - August,1986). E Finalization of the Fire Protection organization and identification of staffing requirements - { January 1,1986. e Fire Protection responsibility and commitment document, draft, April,1986. I a Resolution of remaining technicalissues (August,1986) with follow up action plans as necessary. I l LE:: :: T r r ~~ ~ ~ 22 - ,C::~ ~ ~ ~ ~ * ~

,y l y. i Interim Fire Protection Functional Organization i Nuclear Engineering ! l, Group Director l j I 1 Fire Protection g Compliance g Assurance l Manager l !i l 1 Ii ji Nuclear Plant Nuclear Facility Nuclear Licensing Davis-Besse Systems Engineering (Part-Time) Operations I Fire Protection Mechanical Senior Licensing Fire Protection i Systems Engineer Engineer Specialist Supervisor Electrical Fire Protection Engineer Coordinators ~

'l 4 i Davis-Besse Procedures s Nuclear mission procedures (NMPs) are being prepared to: 1 implement commitments and Corporate / Mission policies. I Controlinterfaces between Nuclear l Mission Divisions. Provide basis for review and upgrade of Division procedures. I Establish consistency throughout Nuclear mission. i l NMP Project Team is planning, scoping and scheduling all procedure efforts. I 20 Toledo Edison personnel directly supporting NMP effort supplemented by 20 contract writers. l e Division procedures are being revised or prepared to: implement applicable NMP requirements. Upgrade selected maintenance, operations, test l procedures and environmental qualification procedures. 20 Toledo Edison personnel preparing or revising Division procedures supplemented by about 35 contract writers. e Procedure Integration NMP and Division procedures coordinated by NMP Project Team to ensure continuity of programs during procedure Implementation by: Monitoring cross-referenced procedures. Ensuring cross-functional reviews. i i i i l

f Davis-Besse Procedures Effort f Required Additional For Restart in 1986 l Nuclear Mission Procedures 18 55 Division Procedures Station i Administrative 5 90 Maintenance 112 801 j Operations 75 229 Other 0 318 Sub-Total 192 1,438 Engineering l EnvironmentalQualification 40 0 t Test 95 i Other 7 63 Sub-Total 142 63 Quality Assurance 13 17 NuclearTraining 32 NuclearServices 90 l Nuclear Projects 20 Nuclear Safety & Licensing 15 Other Divisions 35 i Total 365 1,765 l Complete 12/2/85 28 In Process 12/2/85 201 l l l e - -. y -3..

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i Training Program Enhancements i Management involvement 8 Training Department elevated to Division status. l Recognition. Desirability. Morale. l .i a Director level management reporting to i Senior Vice President, Nuclear. l Uppermanagement attention. g Support. Better able to address training issues. I I I i i y,...---.--.-- - - - - - - - - - - ~ ~ ~ ~ - = - ~ - - - ~ < = ~ ~ ~ ~ - - - - - - -

t i t b i f Training Program Enhancements Staffing a Training supervisors to manager level. Promotion path within Training. Appropriate leve to work with Mission counterparts. I aTraining instructors elevated to comparable level with Station positions. l Attract high caliber personnel. Alternate career option. In line with other utilities. r a i i l l I 1 l l _2:.__~_*____ .;.,;,_'.l',_*^*

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i. t Training Program Enhancements ll Staffing (Cont'd) m NuclearTraining staffing levels. 1 ) 54 positionscurrentlyapproved.. 43 filled by Toledo Edison people. 4 new eniployees will report by 2/86. !I This is being supplemented by 10 additional contract personnel. [l m Progress 8/84 8/85 11/8 5 i Approved Positions 24 41 54 l l Toledo Edison Staff 17 35 43 i Contractinstructors 2 10 10 a Mditions Additional staff is being added to support l the simulator and expanded maintenance training. I l l i ) ._ 7 _J,_J: 1__.-..-_~Z_ Z*- i. L . * -~ ~ ~~ ' r ? -~~

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.t i I I I Training Program Enhancements Program improvements alNPO Accreditation.

NUMARC commitment.

All prograrps ready by December 1986. i a Operator Programs (NLO, RO, SRO/SS) Expect to submit Self Evaluation Report to INPO by 12/31/85. 4 m Rernaining programs (Mechanical, Electrical, i l&C, Chemistry, Health Physics, Shift Technical Advisor, Technical Staff and Managers). 4 f Concerted effort to have these programs ready priorto December,1986. Expect the three maintenance programs to be f ready closerto mid-1986. a Clarification of responsibilities for training I functions. l l = Mission procedure defining responsibilities. Training responsible for development and l implementation. Line organization responsible for training and qualification of assigned people. s Will be complete prior to restart. j l )

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i. i l-t Training Program Enhancements i Upgrading of Facilities j u New Training offices and classrooms completed. r a Doubled number of classrooms. I a Much improved leaming environment. [ a Dedicated Training labs to be completed this month for: Mechanical j-Electrical i instumentation & Control Chemistry Health Physics Quality " Hands On" Training is being emphasized. t i i i I .I i e m,----,n.-n ,,-. - - --.. -.,,,- _,n,. _, - - ._n--_____,y,--, _, ,_w,-------,.-.--

e 1. I. i Laboratory Facilities Mechanical Maintenance Lab ~ Area-1440 square feet Major equipment includes - fully equipped machine shop, air conditioning and refrigeration f equipment, vibration analysis equipment, valve test stand, wide variety of plant specific items. i Electrical Maintenance Lab Area-850 square feet l Major equipment includes - motor control center, numerous circuit breakers, soldering stations, i motor generator trainer, electrical test equipment. l Instrumentand Control Lab l t k Area-1300 square feet i Major equipment includes - sophisticated Lab-Volt process control simulator, control rod drive part c task trainer, functional Reactor Protection System channel, electronic test equipment. Chemistry and Health Physics Labs t Area-1120 square feet total Major equipment includes - spectrophotometers, gas chromatograph, gamma ray spectroscopy l! systems, counting and survey equipment. e o

Training Program Enhancements Upgrading of Facilities (Cont'd) m Plant specific simulator will be built. a Design specifications finalized and out for bid. s Bid review processin early 1986. m 32-36 month lead time. J m On site and operable by December,1988. l m Nearly 300 simulated malfunctions will be available to test and evaluate operators. 1 i l i l l. i Z $ ~ I "' ~ " ~ ~ . ~ ~ ~ ~

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t i i i Maintenance improvement 7 Program I Changes have been implemented in these broad areas: i e Organization and Staffing. e Training. s Maintenance Administrative and Technical j Procedures. I a Maintenance Activities. m Spare Parts and Material Control. j u Engineering interface and Support. m Plant Cleanliness and Material Readiness. m Facilities. a t h a t _.... ~..... -. - ._--.-~~.......s... . - - - ~ - - - ~... ~... e

Plant Maintenance i t Assistant Plant 4 Manager Maintenance

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i Maintenance Maintenance Maintenance l Superintendent l l Superintendent l l Superintendent l l8C Mechanical Electrical L___J L___J L___J l

I I e I I I I I I P P P LeadI& C General Foreman Lead Mechanical General Foreman Lead Electrical General Foreman Engineer lac Engineer Mechanical Engineer Electrical l i r-- r-- r-- -l Training Foreman 1 -l Training Foreman l -l Training Foreman l L___J L___J L___J Engineer Foremen Engineer Foremen Engineer Foremen t Maintenance "#"I'"'" Maintenance Cft Craft Craft l Specialist Specialist Specialist e 4

t. I L e I 1 Organization a New management personnel. e increased supervisory personnel for each I discipline, i m improved supesisor/ craftsman ratios. t l 8 Improved department communications. 1 m Training Foreman. P l t t 9 b l l A I ~~ ~. Z -^~~"

).'. t f i . Training W l.

Each discipline has a designated Training Foreman.

8 Training shift concept has been adopted. a Training Councils formed in each discipline. L r a Outside organizations or facilities are utilized to lt provide training. t f ? i e i F f =....

.i j. I Plant Cleanliness and i Material Readiness u Continuing program in place. I a General improvement accomplished. 26,000 manhours in 3% months. s Significant improvements in specific areas. Watertreatment plant. Service watertunnel. l Turbine Building 658 and 643 elevations. t f r { l i l j l ~ i l = - :: = - - - -

i i 4 i Spare Parts and i Materials Control i a Responsibility transferred to Materials Manager. ,1 New position in Nuclear Projects Division. r Onsite with Warehouse office. a Program developed and implemented. i a Spare parts adequacy and inventory control implemented. a Surplus identified and inventoried and being j evaluated fordisposition. l i l l i -L-

t. t t Engineering Interface and Support e Engineering attendance at Plan of the Day meeting. t' e Duty Manager' Roster System. m Station Technical Support Section. m Request for Engineering Assistance Process. e I r L t i i L i i l ~ ., _ =,,. _ - _. _.. - -

l ~ f l Maintenance Procedures Administrative l 6 procedures required for restart. l 3 approved. ~ 2 in the review cycle. 90 will be completed after restart. Technical r 112 procedures required for restart. approved. 13 in the review cycle. j , 801 will be completed after restart. t b L i i t f 9 ' ' ~

Corrective and Modification Work Orders Backlog: 1339 Corrective work orders open on June 9. l 898 Of thoseclosedasof December 4. I 111 Facility Change Requests open on June 9. 40 Of those closed as of December 4. i Current: i 3394 Corrective work orders issued since l June 9. 1674 Of those closed as of December 4. 574 FCR's issued since June 9. j 159 Of thoseclosedasof December 4. i i -e. . - ~ _._,-,----n,--- +-~--r-, -,,, -. -- - - -- - - - ~ ,, -,, - --.-... - - -~ - --,, - - -,, --

t. j. Preventive Maintenance Backlog: 405 Work orders open on June 9. 368 Of those closed as of December 4. f Allwill be closed priorto restart. j. Current: [ 895 Work orders opened since June 9. 615 Of thoseclosedasof December 4. 4 i At restart - no backlog PM work orders will i be outstanding. I [ i l! l t l l l W. e e*=o-= ese g amee

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s t A = New Maintenance. Facilities Five-story structure being constructed. a Adds 100,000 square feet of shop and office space. = On schedule for occupancy-November,1986. i Adding additional test and support equipment. e MOVATS for testing of Limitorque Valve i f Actuators. m Test system for Hydromotor Damper Actuators. = New Metrology Laboratory with new reference standards. i 1 [. I l 8 1 . ~.. _... _.. _ _.. _ _ _ _ _ _., _ - _ _ _ - _ _ -, _ _

4 Operational and Procedural Changes I Training / Administrative m increased emphasis by management and training i on adherence to procedures. Training for L operators to begin 12/16. m Pre-startup training of all operators on high i priority-infrequent operator actions (e.g. AFFT-trip throttle valve). Begins 12/16 except for AFFT i which will be done in Mode 3. i a Manual vs. automatic safety system actuation. 's Operating philosophy requiring Reactor l Operator to inform Senior Reactor Operator of J intent to manually actuate system. AD 1839.00 modified. Training to begin 12/16. e Pre-startup training for licensed operators to t begin 12/16. a Loss of feedwater events. p a Control logic and operation of AF 599/608. m SFRCS changes and actuation. s Control of steam header pressure following a reactor trip. s Simulator training completed 12/8/85 includes SFRCS mock-up and manual P-T plotting (assumes inoperable SPDS). m Other new FCR modifications. S w,__-,. - -,,. - _ -_,.____------_,,,..,._-sm

,i. I i Operational and Procedural Changes j Emergency and Abnormal Procedures 't u EP 1202.01 will be modified to: 9 m Provide definitive criteria for Makeup /HPI cooling.. s Correct SFRCS response verification.

Realignment of Auxiliary Feedwater mini-recirculation flowpath.

m MSIV status verification. a New motor driven feedwater pump operation. m Criteria forAFW suction transfer from service water to the CST. (SP.1106.06 AFP operating procedure modified.) l f r . i e e i O 6 , e .--,.-.-,_.-.?---~....-, _,._x,._- .--._-.__ _. _,,mm.,_. c. ,.,--,3- -.--. -. i, -y m-

f e Operational and Procedural Changes Emergency and Abnormal Procedures a SRO required to remain in the Control Room Panel area directing actions of the RO once EP 1202.01 is implemented. (AD.1839.00 modified) l 8 Review all Em'ergency/ Abnormal Procedures to i assure clarity of instructions when unusual '{ actions are required. (Completed 11/15) l u Reveiw all Emergency / Abnormal Procedures to assure Control Room instrumentation is adequate j to support the decision statements requiring operator action. (Completed 11/15) !j u Provide manual pressure-temperature plotting capability on the operator console. (Completed 10/30) i + 9

Operational and Procedural Changes NRC Notification i a Checklist provided in the Control Room to ensure ~ information provided to the NRC Duty Officer is i timely and accurate. AD.1839.00, Enclosure 6, provides checklist for ,J Control Room operators. (Completed 11/23) s Additional training will begin 12/16 for personnel i responsible for NRC emergency notifications. t k t r I t 4 +- ,---4 e ya,u - mes --ee-s.,. ere-woww er e em ew eve e *wy-T-,m.% y- -et w -rwa--= c.

}.'. 1 h, Operational and Procedural Changes {, Shift Technical Advisor (STA) a Shift schedule changed from 24-hour duty day to rotating 12-hour shifts. (Completed 10/30) a STA spends entire shift within protected area. (Completed 9/1) a STA office located within 1-2 minutes of the Control Room. (Completed 9/1) I a Trained as Interim Emergency Duty Officer to advise the Shift Supervisor in event classification and Protective Action Guidelines. i (Completed 11/6) m New class of STA'S currently in training will be SRO licensed and part of normal shift complement. l l l

7. -

t ,d . Equipment investigation ~ t i

Purpose:

Determine root cause of equipment malfunctions in order that appropriate and effective ccm= dive actions are implemented. I Scope: ThiNeen (13) areas of equipment concem were identified forinvestigation. Seven (7) systems wereimpacted:

1. Auxiliary Feedwater

2. Main Feedwater j

3. Steam Feedwater Rupture Control j

System

4. Main Steam r

5. Reactor Coolant System (pilot operated relief valve only) f

6. Nuclear Source Range Instrumentation

7. Safety Parameter Display System e

l l l l 1 L'

~ Equipment Investigation ~ 3 i Methodology: Eva'sallen & Analysis i i 1 r t Actlen Plan l l t { 1 r Tremblesheeting 1 r Findings & Ret Caun System Reviews (................. Generic implications Corrective Actions 1 r i Additional Actions l l

I .I f EquipmentInvestigation ,l Majorissues: [ A. AuxiliaryFeedpumpTurbines j u installing new steam admission valves. i e Designing for high energy line breaks. ulnstalling,new govemor on AFPT #1. a lmproving trip / throttle valve reset capability. I B. Pilot Operated Relief Valve (PORV) = No. specific stiot cause identified. m Performing control panel changes. 4 m Rebuilding PORV with new parts. a Testing program. performed / planned. C. Motor--Operated Valves

Resetting limit switches / torque switches.

a Using MOVATS test equipment. a Performing differential pressure tests. p a Correcting / Checking other features Pre-LLRT Stem checks Post-LLRT Lubrication checks ! l T-Drains Current signatures Space heaters Parts check Wiring checks Valve design data EQ wire checks Operator design data l' i ~

Equipment investigation Findings: Detailed in reports generated for each of the 13 areas of concems. ) Root causes identified in the areas of: I Design Maintenance i Testing [ Procedures Training I Corrective Root cause conective actions to be done l Actions: priorto restart. Include: 15 Design modifications 1 l 13 Maintenance / replacement activities 5 Proceduraland/ortraining issues I I e i 4 p.. w a, e, 4 u - w= w -

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Piping Supports Walkdown Phase I-Priorto Restart A. Inspect and complete evaluation of 945 supports. i Three complete systems-Auxiliary Feedwater, High Pressure injection, Low Pressure injection. Four systems, containment portion only-1 Core Flood, Containment Spray, Hydrogen Dilution, Pressurizer Relief. j Results: Inspection complete-875 NCRs i i 80% acceptable as-found 20% minor rework B. Inspect and preliminarily evaluate 1465 t supports. Addresses balance of in-containment piping supports. Results: Inspection complete. ,li No major problems noted. , Phase Il-After Restart Complete inspection and evaluation of all safety-related piping supports prior to end of next refueling outage. Adds 2500 supports. 1 . c:::::Trr:: a r T ~~~~

1 I Environmental Qualification Environmental Qualification (EQ) program assures that safety-related electrical equipment will perform i their important functions under accident I environmental conditions (e.g., temperature, g pressure, radiation). I EQ Program Activitiesinclude: } m Review and upgrade of the Qualification Files. a Review and reissue of the EQ Equipment Master List. a Preparation of programmatic and implementing procedures. } 8 Walkdown (baseline survey) of "as-installed" plant 3 { 't EQ equipment. A Review and documentation cf to-date maintenance !l and surveillance of EQ equipment. 4 l i Outage Related EQ Activities: i a Evaluation of the reconfigured auxiliary feedwater 4 system and the newly installed motor driven feedwater pump for high energy line break and EQ impacts. f 8 Modification or replacement of non-qualified EQ equipment. ~ I i - - -.. _ ~

I P 9 Main Feedpump Turbine i' (MFPT) ~ f Concern: Overspeed tripping of MFPT 1-1 j initiated a plant runback. Findings: Failed circuit board capacitorin General Electric controlsystem. Corrective

1. Replace faulted board.

Actions:

2. Check and test control circuits for i

both MFPT 1-1 & 1-2. . Generic None-problem is specific to MFPT Implications: control circuits. I i i I l p. e.. ee

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1 Steam Feedwater Rupture Control System (SFRCS) Concern: Spurious SFRCS actuation closed both main steam isolation valves and Isolated steam to main feedpump turbines. } Findings: Turbine trip caused pressure oscillations which SFRCS detected as low steam generatorlevel. Level i pressure tap was made moresensitive due to transmitter changeouts. Corrective Add electronic filtering to signals. I Action: 1 Generic Increase in sensitivity / response can implications: result due to transmitter changeouts. Installing filtering in Reactor [ Protection System flow transmitter l circuitry.

i i

e ..-,em.s .w _**geh.. 9 N. -

- h*"N* * * * " " *** ' " " * ' * * ' ' ~ '^

1 Auxiliary Feedpump Turbines Concem: Both auxiliary feedpump turbines tripped on overspeed - this prevented supply of water to steam generators. Findings: Condensation in long steam inlet l lines disrupts proper turbine control. f Corrective

1. Keep lines hot with steam to I

Actions: greatly reduce water formation.

2. Increase steam trap capability.

3. Improve govemor controls.

i Generic None-no other qui 6k start steam implications: driven turbines. I, D l ' i e I 'l

~ Auxiliary Feedpump Turbine Trip and Throttle Valves i Concern: Operators experienced problems resetting the valves-delayed initiation of auxillary feedwater to steam generators. k Findings: Procedures and priortraining not i sufficient. Corrective

1. Provide improved hands-on training.

j Actions:

2. Provide placards andlocal indicators on T&TV to help operators.

3. Enhance communications between pump rooms and from pump rooms to ControlRoom.,

r ' Generic Other crucial operator actions performed implications: kcally. Covered byOperator Actions ( review. 1 i l 1 l l l F r r n .. c.

21x: -

~ Auxiliary Feedwater Valves AF 599 and AF 608 j Concern: Valves failed to open on demand t after closing earlier-would have prevented auxiliary feedwater flow. e Findings: Motoroperators on valves were not properly adjusted allowing valves to " torque out". Corrective

1. Readjust AF 599 and AF 608.

Actions:

2. Evaluate and readjust other motor operated valves.

3. Test valve operations.

4. Provide new maintenance procedures.

Generic: Applicable to other motor operated Implications: valves

i

.i t t .. ~ CCZ Z T. ~ ~.' 111 '.11' - *~~ ~ ' ~ ~ ~ ~1

7 Pilot Operated Relief Valve (PORVJ 1 Concern: During transient PORV failed to close properly afterthird opening f -closure of the block valve isolated the PORV andit ( reseated. I Findings: No physicalevidence found to i explain improper closure- [ foreign materialin pilot cannot be ruled out-performance i similarto industry experience. t l Corrective

1. Testing of valve-old/new.

} Actions:

2. Add acoustic monitorflow indication light on PORV control panel.

p

3. Change PORV annunciator f

light from white to red.

4. Improve panellabeling of solenoid open/close switch.

5. Provide for PORV exercising during shutdowns.

Generic None-no valves of simliar implications: design. l l

Main Steam Headers i Concem: After closure of main steam isolation valves, pressure control problems j were experiencedin the main steam headers. l Findings: Manualactuationof atmospheric vents valves (AW)causedlarge I pressure drop in header #1 - AW l controlcircuitry on header #2is a lesser concem. Switch contacts corroded on ICS module. t Corrective

1. Full check-out and adjust. ment of f

Actions: AW control circuitry.

2. Testing and refurbishment of main steam safety valves.

3. Refurbishment of ICS modules for AW circuitry.

Generic Switch contacts being evaluated and implications: refurbished on other ICS modules. i i l i 8

e,

,,---,-w-- ,,,-----n-,,,,_,.--n- --,-n,-- m----- ,, -~,,,,

i \\ Main Feedwater Startup Control Valve il Concern: Operators were uncertain of status of control valve SP-7A due to blown light ( bulb. 8 Findings: Valve operated properly - technician inserted incorrect voltage lamp during event. i l Corrective Provide additionalinformation to Action: operators. i ' Generic None-no significant findings. l implications: 6 r l i l --=:= =.. -

i 4 Auxiliary Feedwater Pump

1 Suction Supply Concern:

Pump suction transferred from normalto backup watersupply about l 20 minutes after reactortrip. Findings: No impact to steam generator-transientlow suction pressure l caused transfer. Corrective

1. Revise strainer arrangement.

Actions:

2. Revise transfer switch setpoints.

y

3. Provide time delay.

i Generic Other pump suction transfer systems. j implications: l I i l i .o-t a U*~'"[i"' i~'^. T

7. '.E " _,. :Zi"_NT.~ *-* ~

~'T~':*~ ~ * '" ~ ~ ~ ~ ' ~~ * ~ ' -

~ l Main Steam Valve MS-106 Concern: Valve position indication recorded as closed to not closed to closed in i about one-third the expected time-i this valve is used to admit steam from steam generator #1 to auxiliary l feedpump turbine #1. } Findings: Motoroperatoron valve was not j properly adjusted. l Corrective Readjust, inspect, and test valve., r Action: I l Generic Other motor operated valves. j 1mplications: i I .] I l A m w e, e....

1 e i Nuclearinstrumentation Neutron Source 4 i Range Detectors l Concern: Prior to event NI-1 was inoperable and NI-2 failed during transient - previous problems had been experienced. Findings: Ni-1-inadequate grounding of shield found at preamp due to paint and lack of star washers. f NI-2-intermittent failure of containment penetration cable center conductor. Triax cable connectors also found ll degraded in each detector string. Corrective

1. NI-1-proper ground established.

)' Action:

2. NI-2-replacing l

penetration / module.

3. Replacing / refurbishing connectors as required.

I Generic Preventative maintenance program Implications: needed for source range, intermediate range, and power range connectors. f i i !i I -r-r,----gr------ cw ,w- - - - - - =, - ---w-- -w,---., -.--w-m.-w-e, --..w =----e--

\\. 7 i j Turbine Bypass Valve Concern: Pneumatic actuator assembly cracked i and failed during cooldown operations several hours following { reactortrip. Findings: Internalvalve components became disengaged and caused hammer blow t forces which damaged actuator. Corrective

1. Repair damaged valve.

j Action:

2. Repair steam traps and drains.

i

3. Refurbish otherturbine bypass l

valves.

4. Revised operating procedure to assure proper drainage of headers.

Generic Applies to both turbine bypass valve implications: headers. i 8 4 I y l

9 b Safety Parameter Display ^ System (SPDS) Concern: Both SPDS Control Room display devices were inoperative during event - they are intended to be used by the. operators during transients. Findings: Bad fiberoptic cable and faulty terminations on data transmission cable. Corrective

1. Use spare cable.

-Action:

2. Correct terminations.

3. Replace obsolete terminal.

Gene'ric None-no otherfiber optic systems. implications: l f l l l . f. ZTi ~ .. ' T 1. E.. [l~ . 2 11121.. [

Decay Heat Removal Reliability improvement Program Task Force Effort s Chartered to review all systems used for decay heat removal. Main Feed and Steam 4 ~ AFW SUFP SFRCS Feed and Bleed m identified changes to improve operational } reliability and to reduce complexity of

i SFRCS.

s Broad Membership a Experience in design, engineering, j operations. ,t eincluded outside expertise: i MPR Associates Babcock and Wilcox Cygna l x.

-:: ==== 22 -

2. : - - ur : -'

j. 4 f. I l i Task Force Objectives: s Reduce frequency of demand for i k emergency decay heat removal. a Reduce number of automatic system responses required to initiate auxiliary feedwater. i a Reduce potentialfor common mode failure. l m Evaluate diverse and redundant means of decay heat removal. Goal: m Provide equipment recommendation that would improve reliability of systems used i for decay heat removal. Specific

ll improvements forthe AFWshould i.

eventually achieve SRP reliability criteria. i n.________,_ ___._._,._.._____.-__.___._.Zi2_,.___._____.__

h f Task Force Methodology a Multiple " techniques" used. Deterministic i Preliminary Scoping Analysis Engineering Judgment J Assessment cf existing PRA's I e Reviewed Documentation. m Evaluated past operating experience. m interviewed Toledo Edison personnel. i ,I l I r l i __..__.,.-...__,_.-_-___=_-ee.,_-_-_____._,,.._--.e._ yy

AFW/SFRCS Reliability l Reduction of spuriousinitiators: a Filter existing steam generator level signals. eimprove SFRCS powersupply i performance. a Remove main steam and main feedwater isolation on SG lowlevel. I f i I I 6 6 pg

ue een.

e nm e,w 6m m e - em*

w e4 - se w w.qm N O e e

==

AFW/SFRCS Reliability AFWinitiation to SG-improvements:

i a Provide hot steam lines to AFW pumps. - i a Valve motor operator improvements.

Depower CST to AFWPT suction valves.

j u Eliminate deaerator suction paths. a Disable feed isolation to last steam generator depressurized. a SFRCS manual initiation improvements. s Raise ICS low levellimlit. 4 I i e 9

.y r r i AFW/SFRCS Reliability AFW continuation improvements: aInstall PGG govemor on AFPT-1. j u Provide seal-in manual reset for SFRCS full trip alarm. j f a Remove AFW pump suction strainers. l I a Resize strainer form CST. s a Revise AFP suction transfer schem'e.

Install local AFPT trip throttle valve ind' ication.

i h l i 1 I i 9 e l b ~1 " I *E . Y 77 *' * * * *

7.* ** * ~_* *, '*** *l*._TJ**_^*f*.*.'*L__..lai_____'_,_.*_.-_._,__._.

l i Original Layout l sFncs l i l ManualInitiation Switches l '/ i / Tnppedt .Tr$ ed' 8G 11 Lew 4 / 3G 12 Law STM Press o o STM Press Tnp Tnp r F F F t / Tnoped / T 1 rwed:- ,I N1 Lew / SGI1Lew STM Press o o STM Press Tn,p / Tn.p l ,Tnpped f "Tnpped j sa i.1 / se i.: mdP 3 / MAP l f o Tdp g j Tnp I / t inpped / .Inpped isttL so12Lew WTM LVL WTR LYL I o <3 Tnp Trip 1 ) 'TM) 9'Toppedi g-Ls.e te.s.e RCP: o o RCPs i Tn.p r Trip 5 e r l 1 l i \\- n n_,_.,

~ SFRCS ManualInitiation Switches CHANNEL 1/3 CHANNEL 2/4 4% (' Q4 SG 1/2 SG 1/2 LEVEL HIGH. LEVEL i HIGH .o LEVEL 0 HIGH Trip F Trip F F V t \\\\\\\\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ \\ T g 'M 'OM b l e $a w:4r . g.., - I SG 1 ~-3 Tnpped d, Tripped i STM PRESS PRESS SG 1 STM PRESS LOW 0 S'31 0 LOW Trip F / Trip F-1 F we. F ( e{3

~

SG 2 i e l,,,,,,s , N ' s N s, ;, N r, i i N i ' T, x ; 7,,, s, a,, s 4 \\ ., s,, s., s,, u.. \\\\\\\\3 s so.1p ws SG 2 wm. SG 2 STM PRESS (* 1ESS STM PRESS LOW 6G-2 0 LOW Trip Trip F" F f \\ \\ \\ \\ \\ TT, ', i \\ \\_ \\ \\ ', \\, N \\_ \\ \\ \\ '. '. \\ \\_ \\ T, \\ \\ Til \\\\\\\\h <\\\\\\\\ss'a n'. \\\\Niy \\\\\\,.\\,N\\\\su'1,\\\\\\\\\\ ~~ y. e c +:., Tripped) ipped y . c w, 1 SG 1/2 SG 1/2 I i s. ' I AP 0,P Ap STM / FW O O STM / FW Trip F Trip F -~ F-F MAGNETIC s e, LOCK N\\\\\\\\xWNWnWWWnx\\\\\\\\\\'nNx siii\\\\\\\\ i ww, SG 1/2 ' l' - d SG 1/2 LEVEL LOW / LOW LEVEL LEVEL LOW / O RCPM O LOSS OF RCP'S LOSS OF RCP'S Trip F Trip F F F 74-9 pen ** e=='*e.w-

s =e *_o-e =e espe w e '

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Installation of Motor Driven !i Feedwater Pump l' New pump design features: m Provides 100% capacity auxiliary feedwater 4 i flow. i m Pump discharge aligned to the auxiliary } feedwater headers during normal fuil power operation. a Pump suction normally from the Condensate Storage Tank. t a Pump capable of being started from the ,I Control Room. s Pump motor can be supplied from either emergency diesel generator following a loss of offsite power. j u Can be manually realigned to feed the Main, 1 Feedwater System. This will be the normal l alignment during low power operation. Pump suction in this alignment will be from the l l Deaerator Storage Tank. l m Eliminates high energy line break concerns casociated with existing start up feedpump. l! a Resolves some fire protection compliance i items. I i

* ' ?"'

_, _.L *.L : *. _,. ~ L _ :, - T- ~- ~. =, ,?. m ,w,,n_,,__

r. t ) Summary of AFWS Reliability i Analysis j u Analysis conducted in accordance with the scope [ and methodology provided in NUREG4611. a Events modelled Loss of main feedwater(LMFW) LMFWwith loss of offsite power LMFWwith loss of onsite AC power j uThree configurations analyzed l June 9,1985 AFWS (two pump) AFWS at restart (two pump configuration) l AFWS at restart with motor driven feed pump (three pump configuration) i j s Results lt Unavailability of the Davis-Besse AFWS (at restart) 'l wKh the motor driven feed pump is within the SRP 104.9 acceptance criteria. 4 l l 1 l t . -. u... 1...

i. 1 LongerTerm Decay Heat Removal Reliability. improvements

Provision of primary system blowdown valves for enhancement of feed and bleed capability.

I a Restoration of existing startup feedwater pump and s provison of Control Room capability for associated valves. 3 a Provision of Control Room capability for the motor driven feedwater pump discharge valves to the l } AFW header. a Further AFW valve flowpath reductions. l 'simprove AFWlevelcontrol. e improve margin between SFRCS and ICS low level setpoints. e SFRCS logic revision to further minimize isolation. a Control Room " mimic" panel for finalized [ AFW/SFRCS. h 9 J-

1 Chronology of PORV Flowrate Data September,1977 PORV nameplate flowrate. 112,000 lbm/hr. at 2300 psig i February,1983 EPRITest Flowrate Extrapolation 245,000 lbm/hr. j August,1985 Initial Feed and Bleed analysis with 10 min. [ operator action at 6100F RCS hotleg j temperature. Results acceptable. 226,000 lbm/hr. 3 t October,1985 " Preliminary" Marshall Station test results. 174,000 lbm/hr. November,1985 Error discovered in Marshall flow device 1 data application. November,1985 Corrected Marshalltest resuits. 213,000 lbm/hr. lI November,1985 Modified PORV nozzle and seat. Low pressure test extrapolation. 229,000 lbm/hr. Marshall test-232,000 lbm/hr. i December,1985 Feed and Bleed analysis with10 min. operator action at 6000F RCS hot leg temperature. Results acceptable. 211,000 lb,Ihr. (including inlet pipelosses) All flowrate data at 2500 psig, unless otherwise noted. peo see = w m i = .a e <e e e 4 e4

e. em e-e t.+-m e.

a

Davis-Besse Auxiliary Feedwater System June 9,1985 8 ,-N.i-N-,.* (s,- e-8--M-M,=-, :::::. 1 -i = i I i1 1 1 1 l cc 3 X.XXX. -1 if e ta i l tweea. nO On I w.9.....

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I Davis-Besse Auxiliary and Motor Driven Feedwater Systems Start-Up Configuration B B -N,.,- N -,e,, s,.. M - L, - _s u 1 1 1 I i (((( n.casim mesmew l , ca, eto l i T.r m. '::-;~ p O m. ' ' ' ~ ' ~ t ~ h h.. I ,, O -E V P'" "'"I V H-O - S,g z-,,. -,,,2 s i___,3 c___. 1 F,3 M,9 i -,o -ru E Oi.,u,. IO,, t .t. g.i us 4,3 u,. l , s. w tr- ~-. o g.. ,b H, ., 30 1 i .i, , s. M.. .N. u,. u i I }.{}.. Q.g. I p,-. -- e c........... ............) g., ~ I0. t 0,9 = .....N....2.,.

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1 r i Davis-Besse Auxiliary Feedwater System Long Term Configuration

a e

... y... e, a VVVV e nenne'> --o< x .....v CO,4, C0t48 C0 t44 Cotte y 6 w.ee r e, --s .... ~..... +.......

I System Review and Test Program Objectives j For systems important to safe plant operation: e ldentify important and recurring design, maintenance and operations problems and i determine whether corrective actions are required prior to restart or can be taken over j long term. I a Evaluate scope of existing periodic testing to l identify any additional testing needed to ensure required functions will be performed. a Conduct test program to assure these systems j i are functional. Testing will also be performed to verify adequacy of system modifications completed during outage. L This program will be completed prior to. restart of Davis-Besse. i i I ] i l _: ~-.

1 1 ( i System Review and Test Program Scope Review encompasses 31 systems judged important to safe operation of Davis-Besse. j Attributes considered in system selection included. i a Performs an active safety function. 'r s Malfunction could lead to challenges to safety jj systems. 1 a Malfunction could result in abnormal plant ji transients. e important to preventing, detecting, controlling or mitigating plant transients. a History of unreliable performance. u Associated with June 9,1985 event. The 31 systems are listed on the following two pages. TWo additional systems were identified j to have a limited review (gaseous radwaste i and post accident sampling system). 1 i-_

) System Review and Test Program Systems Selected i Reactor Coolant System High Pressureinjection System [ Core Flooding System Decay Heat Removal and Low Pressure injection System l Containment Spray System l Containment Emergency Ventilation System l Containment Air Cooling and Hydrogen Control System - l Makeup and Purification System I Electrical 125/250 VDC System (includes Battery Room H&V) Electrical 4.16 KV System (13.8/4.16 KV transformers) t f Electrical 480 V Distribution (includes inverters and. L required transformers) Electrical 13.8 KV System (includes startup and auxiliary transformers) Emergency Diesel Generators (includes "Q" fuel oil r tanks and dieselroom ventilation) ~ instrument AC Power Syste.m (includes inverters and required transformers) i e [ *- ' +9 m er**- oaen .s 4-a e, .%,og w w#,,,.,

i t System Review and Test Program. Systems Selected l Anticipatory ReactorTrip System i ControlRod Drive ControlSystem incore Monitoring (includes core exit thermocouples) Reactor Protectio'n System I Steam and Feedwater Rupture Control System l Safety Features Actuation System l Integrated ControlSystem { Security System l Control Room Normal and Emergency H&V Systems I Station and Instrument Air l Station Fire Protection Component Cooling WaterSystem t i Service WaterSystem j Auxiliary Feedwater System Main Steam System Steam' Generator System ~ Main FeedwaterSystem F G

I i l i . System Review and Test Program j Approach l e " Team" for each system. l Headed by Toledo Edison engineer. Supported by highly-qualified industry personnel. t a Focused interviews of operations, maintenance and engineering personnel. m Review of selected records for Davis-Besse experience (E.G., Licensee Event Reports, NPRDS Data, Maintenance Work Orders, Transient l Assessment Program Reports, Deviation Reports). e ldentify corrective actions for problems. Priorto restart. Long term. m Prepare report including summary of system functions, problems and corrective actions. I I i

l. s 1 It System Review and Test Program. [ Test Review l m Review periodic test requirements for each system to ensure required functions are adequately demonstrated and confirmed. m Prepare report summarizing results of test review l and identifying test changes required. s Prepare test outlines and procedures for: Post-modification testing. I f New periodic testing. l Revised periodic testing. One-time tests supporting restart. l m Review results of test program and prepare test L summary. i-l l i 9 ~

Independent Process Review Committee l m Overall review of system review and test program. [ m Ensure system review and corrective action i process in combinaton with system and equipment j testing will adequately demonstrate the operational j readiness of the systems and equipment important to safe operation of Davis-Besse. i a Committee membership combines a broad backgmund of nuclear industry experience with i specific knowledge of the Davis-Besse plant j design. i l e Concurrence with: ~ i Scope and depth of review by " Teams". System functions. Corrective actions required prior to restart and overlong term. f Periodic test review. Test. requirements to support restart. Test results. l l 7-----

I. i l m Independent Process Review l Committee Membership P.C. Hildebrandt c Chairman (MPRAssociates) R.S. Brodsky (BETA) J.D. Carlton V (B&W) E.C. Novak (TED Engineering) f J.P. O'Hanlon (UESC) L.P. Simon I (TED Operations) J.G. Walker i (Bechtel) 1 C.A. Hengge Secretary l (TEDNuclearSafety) i l, -m.-

INDEPENDENT PROCESS REVIEW COMMITTEE ROBERT S. BRODSKY Bob Brodsky is a principal managing partner of Basic Energy Technology Associates, Inc. (BETA), a consulting firm serving clients in the nuclear industry and at all levels of government. He has over 25 years of experience in the naval nuclear program. As Assistant Director for Reactor Safety and Computation in the Naval Reactors Division at the -{ Department of Energy, he was responsible for design and operational 4 safety of the Navy's shipboard nuclear propulsion plants, the Department ? of Energy's naval nuclear prototypes, and the Shippingport Atomic Power _N l Plant. e JAMES D. CARLTON i Jim Carlton is currently manager of Performance Analysis in B&W's Nuclear Engineering Department. He is responsible for the performance, safety, ECCS, radiation and reliability analysis of B&W and competitor NSS's. 4 Prior to his current position, Mr. Carlton managed integrated organizations j for B&W and B&W's licensee in Germany. His responsibilities in this integration function included overview of the design, specification, l and analyses of B&W's scope of supply in the NSS. Mr. Carlton was also r a systems and components design engineer at B&W for several years. His i activities included design and operating experience on the NSS Savannah. l He participated in the design of B&W's 177 and 205 FA NSS by activities such as the reactor. coolant system design, the once-through steam-generator design and prototype' testing, and development and prototype testing of the Integrated Control System. I CRAIG A. HENGGE, SECRETARY Craig A. Hengge is a Senior Assistant Engineer in the Nuclear Safety Department at Toledo Edison Company. He began full-time employment with Toledo Edison as an Assistant Engineer in 1981. Mr Hengge has been ~ involved in probabilistic risk assessment and system reliability activities at Davis-Besse. Most recently, he participated as a member of the Decay Heat Removal Group which conducted an in-depth review of various systems utilized for reactor decay heat removal at Davis-Besse and identified specific improvements to those systems. Mr. Hengge also ~ serves as Secretary of the Company Nuclear Review Board. He holds a B.S. degree in Nuclear Engineering from the University of Cincinnati and was employed at Toledo Edison from 1978 through 1980 as a Co-op Student, t 4 s Wm me m ap e~ -r-w m + sa w - -w*~e

_.--yx_*-v-_________

]

a PHILIP C. HILDEBRANDT, CHAIRMAN l

Phil Hildebrandt is a consulting engineer with MPR Associates, Inc. of y Washington, D. C. He has been with MPR Associates since 1979 involved i with a wide range of engineering tasks for both nuclear and fossil-fired power plants. Prior to joining MPR he was a design engineer with Duke Power Company, responsible for resolution of nuclear steam generator related problems and design for specific fluid systems. Mr. Hildebrandt was with the Naval Nuclear Propulsion Program f6r ten years. He was on Admiral Rickover's staff and was responsible for nuclear steam generator l operation, maintenance and design, and earlier, involved with the design of fluid and mechanical systems for submarine propulsion plants. He is a registered professional engineer in the Commonweath of Virginia. i EUGENE C. NOVAK 4 Eugene C. Novak is Director of Fossil Facilities Engineering and ,j Construction at Toledo Edison Company. In that capacity he is I responsible for all capital improvements projects and offsite engineering support activities for the Company's non-nuclear electric generating facilities. Mr. Novak is also chairman of the Company Nuclear Review g Board. Mr. Novak began full-time employment with Toledo Edison as 4 s Assistant Engineer in 1959. For ten yegrs he held various engineering positions at the Company's fossil fueled generating facilities. From 1970 I through 1980 Mr. Novak was directly involved in the Davis-Besse project holding various engineering positions including Project Engineer and y Director of Power Engineering and Construction. Mr. Novak holds a B.S. [ degree in Mechanical Engineering and an M.S. degree in Industrial 4 Engineering from the University of Toledo, and an M.S. Degree in Nuclear Engineering from the University of Michigan. He is a registered professional engineer in the State of Ohio. 3 b k JAMES P. O'HANLON I James P. O'Hanlon is the manager of the operations service division for United Energy Service Corporation in Atlanta, Georgia. Mr. O'Hanlon has over 20 years supervisory and management experience in the nu. clear industry. His experience includes that of a general manager of a multi-unit operating nuclear station responsible for all onsite activities.- It also includes experience as Assistant Director of l j Evaluation and Assistance at the Institute of Nuclear Power Operations with responsibility for direction of evaluations of all nuclear utilities in the U.S. ,.-.-.m.,--.

i LOUIS P. SIMON Louis Simon maintains an Senior Reactor Operator's license for Toledo Edison's Davis-Besse Nuclear Power Station. He is Operational Projects Supervisor in the Operations Engineering Department. Mr. Simon has over 27 years steam plant operating experience, naval, industrial, and utility. Mr. Simon joined Toledo Edison in Fossil Operations in 1962. He participated in the Davis-Besse cold licensing program and was a Shift Supervisor through startup and commercial operation. Mr. Simon became Operations Supervisor in January 1979 an.d held this position until December 1985. i JOHN G. WALKER t I l John Walker is manager of operating plant services for Bechtel Power Corporation in Ann Arbor, Michigan. He has been with Bechtel since 1966 l involved with the startup of numerous nuclear and fossil power plants in the U.S. and foreign countries. He served as chief startup engineer for eight years and was 's project manager for three years prior to becoming j manager of operating plant services. Prior to joining Bechtel, Mr. l Walker was s' plant operations supervisor for Texas Electric Service Company. He graduated from Texas A&M with a B.S. degree in Mechanical [ Engineering and is a licensed professional engineer in California and Texas. i } ei i D

g_

=

A

i f I i i Determination of Corrective l Actions Required Prior to Restart l 8 Corrective actions necessary to ensure safe and I reliable plant operation. l u Based on collective experience and judgment of independent Process Review Committee considering a Plant design basis described in the Updated Safety Analysis Report. j u Technical Specification requirements. j u Reliable plant operation. a Protection of personnel, systems and equipment. a Prudent engineering practice. f I k i r 6 k l 4 y il -,w

Current Status of System Review and Test Program a identification of specific system and equipment probierns requiring resolution prior to restart is complete. j u System review reports summarizing system functions, problems, and required corrective i actions complete. i- - a Review of periodic tests for system operability I i i t 0 ) .l l

i h Problem Areas identified During System Reviews j u Forthe 31 systems Approximately 140 problem areas require j resolution priorto restart. Approximately 200 problem areas require resolution ove'rlong term. l 8 Resolution ranges from engineering evaluation to hardware changes in plant. } m Facility Change Requests, Maintenance Work j Requests or Requests for Engineering Evaluation . have been prepared to address all problems that 1 { must be resolved priorto restart. I I. l ~ - 1

i i i Examples of Important i Problem Areas e Control Room Emergency Ventilation System. i e Auxiliary feedwater discharge piping i overpressurization. m Potential floodirig of pit containing decay heat removal valves (DH-11 and 12 motor operated valves). m inadequate ventilation in service water pump room. I e Widespread station and instrument air system leaks and dependence on temporary diesel air compressor. i l L t F 9 i k i o .. _ _. -.. _.,., ~ _ _ _,

i I i i. Recurring Problem Areas f . m inattention to heating / ventilation / air conditioning requirements. ainoperable nitrogen regulators. m inadequate maihtenance for hydromotor actuators. k u Tracking and replacement of limited life components (e.g., seals, elastomers, electrical l components). m Valve packing leakage. j u Steam trap maintenance. I a l&C preventive maintenance / calibration. p i I A I

i I 8 i System Review and Test Program Objectives [ For systems important to safe plant operation: a ldentify important and recurring design, maintenance and operations problems and determine whether corrective actions are required prior to restart or can be taken over l long term. i a Evaluate scope of existing periodic testing to identify any additional testing needed to ensure required functions will be performed. k e Conduct test program to assure these systems are functional. Testing will also be performed to verify adequacy of system modifications [ completed during outage. This program will be completed prior to h I I restart of Davis-Besse. .l l i t ..i .,. _ _ _. ~ _

}.' i i, System Review and i Test Program Test Review

Evaluate each system important to safe plant operation considering the effects of modifications I

made during the outage. m For each system function important to safe plant i operation: b

1. Identify existing periodic tests which

[ adequately demonstrate the function l or I I

2. Prepare outlines for new or revised test which j

will adequately demonstrate the function s or )

3. Provide Justification that the function cannot or should not be tested prior to restart.

a Document the results of this evaluation for review by the Independent Process Review Committee. m independent Process Review Committee concurs r with scope of testing to be performed. i

Restart Tests To Be Conducted Preliminary results of the test review have ll identified: a 46 Existing periodic tests to be performed { prior to restart to demonstrate system functions. a '87 New or modified periodic tests or one time tests necessaryto demonstrate functions including tests required as a result of modifications. 4 7 Integrated tests to demonstrate system m functions involving multiple systems. a140 TotalTests a Average test duration is approximately 12 t hours excluding test setup time. j u Total test program will require approximately 11 weeks including power escalation testing. l i l l _n ^ ~ ~ ' ~ ~ ~

l l Restart Test Program Approach t t = Use existing station administrative procedures to implement and control the restart test program to the extent possible. m New procedures developed to control activities unique to the restart test program include: I Organization structure, functions, and responsiblities of the various groups and committees supporting the system review and . test program. 4 } Development of test procedures for new or j modified tests: l Independent Process Review Committee concurs with scope. Joint Test Group approves test procedures. ' Station Review Board and Plant Manager approve test as usual. Conduct of new or modified test by special test organization. ): Results of all test conducted to demonstrate + functions important to safe plant operation to be reviewed by Joint Test Group and Independent i Process Review Committee. f 9 6 4 ,--,------.{ - - ~ - - - "*~?,.~~ ~

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

^

1 i System Review and Test Program (SRTP) ) Organization i i F-- se , President Nuclear, L___J .t r-- i .ss ee................ e, l L___J 1 1 i independent i Process Review ,RTP Caerdinator t l Committee Advisory Group f. i? .Bechtel l ! .B&W.S&W l 1 l I I I i r-- Jelat Test Group System Review Restart Test ! Quality Control l Group Organization i L_ _J

_.._...z.. Restart Test Organization l Independent Process Joint Test Group Review Committee

Approve Test Procedures l

. Approve Test Outlines

Approve Test Results
Approve Test Summary
Maintain Test index Results
Schedule (Input) l Test Manager

. Prepare Test Procedures 0ealify Test Personnel . implement Test .Sammartre Test Results . Schedule Tests 4 i Assistant Test i! Manager liii .l 1 h I i I i! Administrative Planning and 8' Procedure Writers Test Leaders Assistant Scheduling Coordi r l it l Records I I l I

i. 1 t f I 4 r t i. i t 4 I + 4 I t i } I 3 - 1 f 1 k 1, l SYSTEM REVIEW AND TEST PROGRAM f r i

SUMMARY

OF CORRECTIVE ACTION ITEMS n FOR DAVIS-BESSE l J 3 .\\ t t t i I s h I i h P 1 i t I e i l I 1 i .[;,vn-- -,, -, ~ -,.. ---~:.' , ~ ~~ T-l T 'T^'---' ~~ -

i t i Reactor Coolant System i PriorTo Restart i j m improve stroke time on containment isolation valve. l m Repair leakage from RCS to nitrogen system. a Repair / replace and calibrate PORV d!scharge line temperature ele' ment.

Install PORVloop seal drain line.

s Modify PORV status indications. I a Realign hot leg Rosemount RTDs to TSAT meter. l Long Term a Repair end plugs on out-of-service pressurizer heater elements. I a lmprove maintenance capability for RC drain tank. a Repair / replace nitrogen regulator for RC drain g tank. e Repair / replace Tave digital readout. a Evaluate RC pump seal or motor parameters to be used forsecuring pumps. P a Calibrate RC pump vibration instrumentation. j u Improve core exit temperature measurement capability. a Modify pressurizer heat bank operation to handle larger heat losses. 1 t

l l

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I + i i High Pressure injection System {i PriorTo Restart m Confirm HPl pump capability at high flow, low head conditions. l m Confirm HPI pump capability at high suction g temperature. m investigate standing water from unidentified sources in several areas (e.g., ECCS room #1; l containment vesselannulus floor). a Remove startup strainers from HPI pump suctions. e Modify HPl pump suction check valves (HP10 and HP11) to facilitate proper disk seating. r I e Verify proper operation of several HPI pump component cooling water stop check valves. s Revise plant documentation to reflect higher i a design pressure capability of section of piping l downstream of discharge check valve HP23. a investigate increasing trend in inboard bearing vibration for HPl pump 1-1. l l l l / l l

) r j High Pressure injection System (Cont'd) Long Term l m Evaluate need for design modification to HPI pump component cooling water stop check valves to preclude " sticking". i i e Calibrate HPI pu'mp motor temperature j instrumentation. a Eliminate low flow nuisance alarm on HPI pumps. m Replace improper flow measurement orifice in HPI pump 1-1 minimum recirculation line. l [ u Relocate control cable for AC lube oil pump for HPI j pump 1-1 per Appendix R requirements. a lmprove communications capability between ECCS rooms and Control Room. a Resolve means of leak testing for back-to-back check valves in HPI discharge valves. l l a Evaluate cyclic life of % inch elbowlets attached to HPldischarge line. l? } i I I i I 1 ~ ~ ~ ~ ~

t l 1 Core Flood System PriorTo Restart ^ a Confirm location of level taps on Core Flood tanks. I m inspect / repair nitrogen regulator for Core Flood 4 tanks. Long Term !l e Pre ~ pare calibration procedure for Core Flood tank levelinstrumentation. m Evaluate required purge time for sampling of Core Flopd tanks. a Calibrate sampling purge flow meter. i l ~ r 1 ? h i t i l 11 f ~~~ ~ Z Z Z _.,_ l'I Z.12?T_T__T _.__.,_:__1 T~1 I ? !i __ ___, _ _. _ _ _ _ _ _ _ _ _ _ _. ~

f [ j Decay Heat Removal System f PriorTo Restart a install level indicating capability for DH11 & DH12 valve pit. i m install modified packing in DH11 & DH12. m Modify procedures to preclude overpressurization of decay heat pump suction. i a lmprove cold weather operation of BWST levelinstruments. a Reinstall mis-assembled studs on decay } heat pump. l l = Calibrate boron dilution flow transmitter instrument strings. f f I E, l l l 9 %, m

i 1 i ? Decay Heat Removal System i i (cont'd) 4 l Long Term j u Evaluate means of eliminating sealed pit design for valves DH11 & DH12. s Evaluate possible system modifications to preclude decay heat pump suction overpressurization. a Ensure spare parts availability for BWST recirculating pump and heater.

Add temperature alarm on BWST; evaluate improved temperature control.

l s Evaluate altemative means of precluding over-ranging of low range decay heat pump suction j pressure gauges. m Evaluate more easily read oil level indicators for 1 decay heat pumps. a Evaluate means of reducing leakage from cyclone separators on decay heat pumps. a lmprove preventive maintenance for pneumatic valves DH13A & B. m investigate means of improving disk seating for i l check valves DH76 & DH77. l 1 l i i

f 1 I i Containment Spray System I i PriorTo Restart i a Verify torque switch and torque switch bypass. - settings for two Containment Spray System va!ves (CS1530 and CS1531) r a Determine specific operator response required when containment emergency sump level indicatcir lights are illuminated. Long Term u Evaluate adequacy of oil level sight glasses for 4 i containment spray pumps. i m Evaluate need for containment spray pump discharge pressure indication in Control Room. 't i l I l 1 4 a l ! i' ^ i ,7**"W****vM !++* m y, _ s w g t_ u socp3-, g e+weg o p g e-y g y 6m e w e as ~ w" p* ' N * - w w ~ =-+r w' * ""r--~ +r-*-e -e- -T

t 3 4 Containment Emergency Ventilation System Prior To Restart l e Provide weather shield for EVS fan controller j sensing line to ensuring operability. j u Replace seals on hydromotor actuator for ? ventilation dam er. i Long Term L e Provide protection for instumentation controls [ for fans. I l t I n L e o k ---..--._n.-

j ? l Containment Air Cooling System and Hydrogen ControlSystem j PriorTo Restart s Repair backdraft dampers for Containment Air Cooling System fans. m Confirm proper operation of fans when shifted from l high tp low speed (overload indication is being i received). a Bench test hydrogen dilution system relief valve. i Long Term a Confirm flow balancing of Containment Air Cooling i System. + { m Replace failed retum bend on cooler C1-1. s Evaluate installation of flow meter in purge test line to facilitate performing surveillance tests. a lnstall soft seat for valve CV210 (containment isolation checkvalve. a Confirm hydrogen recombiner is compatible with t-Davis-Besse system and can be made operable within required time. l l -,

I i Makeup and Purification System Prior To Restart j a Repair or replace failed containment isolation valve MU33. l u Remove any sta,rtup strainers in system. i a Confirm correct valve trim in MU32. a Repair or replace leaking reactor coolant letdown pressure reducing valve (MU6) and controls. s Provide indicator of makeup flow for use during feed and bleed operations. t a Remove inoperable and unused reactor coolant pump (RCP) sealleakage indication. 4 t i t 9 =-m +NNN' W - f T = 9e N " h-9*M" W 'm ** a - meme eeaev a-W--e**e--w-e e ea--w==ir=- - - - - = = - + --v <---w-w =w-- w ~ -<-T = -

Makeup and Purification System (Cont'd) j Long Term i a Repair / replace leaking reactor coolant batch makeup flow control valve, MU39 (currently isolated). a Repair / replace batch controller. ,y a Repair minor oil leaks on makeup pumps. ,1 m Evaluate and repair leaking valves MU19 (RCP seal l injection valve) and MU216 (RCP seal injection bypass valve). a Evaluate and repair boronmeter. i a Perform review of problems with hydrogen system j (for maintaining makeup tank overpressure). a Repair MU1903 (Cation demineralizer, inlet isolation I valve). a Repair / replace seal injection stop check valves. a Replace letdown block orifice. a lmprove communications capability between 'i makeup pump room and control room. s Evaluate intended function of boron permissive light. m Perform review of failure modes of makeup system equipment (e.g., power supplies) and ability of l operators to recognize problem and take corrective action. t Y,. ~~~~L.'~1..-,.,

j t 250/125 Volt DC System Prior To Restart aNone r Long Term a lmprove temperature control in battery room. a lmprove ground fault detection and location. a Evaluate design change for low voltage relays to reduce failures. I l I i 5 i t e e e p= ** _-e

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4160 Volt AC System i PriorTo Restart ~ s Confirm operability of several breakers with original levering-in device. f a Replace CVE synchrocheck relay with different l design. } m Resolve tap setting for 4160/480 Volt transformers j and reset alarm accordingly. Long Term s Review consequence of paralleling bus tie i transformers out-of-phase. l m Visually inspect all 4160 Volt breakers in "Q" cubicles for "E' Iring damage. [ m Control noni'Q" 4160 Volt breakers to ensure they are not utilized in essential applications. 'I e Provide improved control of circuit breaker and 1 relay setting records. t } t 6 P j e 0 -9 _,4.m.-__. - --, --- i - - -, - ---+- - - - - - = - - - ~ * * ~ - - - - ~ - ' ' - * - - - ' " * - - ' - - - ' - ~"

i l 480 Volt AC Distribution System PriorTo Restart a Confirm operability of switchgear cabinet door and stab withdrawal interlocks to ensure 480 VAC g breaker operability. Long Term I a Evaluate removal of stab withdrawal interlock feature. I a Evaluate altemative means of providing ground-fault protection for 480 Volt AC motor. control centers. . l m Establish program for tracking limited life components in motor control centers. I s improve preventive maintenance on switchgear cabinet door hardware and gasketing. i h e ,r.,,. ---._ -,-, ,,,n- .-, _ _, _ _,, -,,..., ~. -.. _, _,. -, -.,.---,,, _.

I 13.8 KV System l PriorTo Restart a lnvestigate cause of fast transfer breaker failures and calibrate relay timing. Long Term e improve method for racking in/out of 13.8 KV ~ breakers. 4 m Repair small oil leak in Auxiliary Transformer. l t 5 i f I I u 6 0 7, _ _. _. _ '$ ?._E i[. _

t i I 1 i Emergency Diesel Generators y { PriorTo Restart a Eliminate electrical noise problems associated with diesel govemor to improve stability. I a lmprove temperature control for diesel generator room by changes to control / alarm system and 7 maintaining ventilation damper actuators. a lmprove reliability of lubricating oil soak back pumps. Replace set. Check condition of filters and strainers. a Test multiple air start capability of diesel generator. j u Calibrate low cooling water flow alarm switch. m investigate cause of SCR diode failure nuisance alarm. s Minimize ice buildup on diesel generator air intake. I f l l l ~ ~ -

j. g. 3 Emergency Diesel Generators i (Cont'd) f Long Term a Evaluate improvements to diesel generator air start f system and improve reliability of air compressors. I e implement improvements for emergency diesel fuel i oil system. ~ a Replace cooling water flow gauge. 3 m Perform evaluation of overall improvement to l diesel generator air intake configuration. u improve diesel generator speed and electrical t' j frequency control capability. a Correct erratic bearing temperature indications for diesel generatom. t u improve Control Room / diesel generator room communications capability. r i i j ) I O e e 9 n- __ _ .., = = _ - - - -_ .~

t 120 Volt instrument AC Power t PriorTo Restart a Install larger power rating resistors in essential inverters W1, W2, W3 and YV4. l Long Term s Install ventilation fans for inverters. m Evaluate installation of static transfer switches and/or tank circuits to reduce potential for losing-1 an inverter when a ground fault occurs. i h i i 4 I e w. w r - -~ e-

==-.m w- - - --m--- m-o e e --,e~~,---w-m~=,,w~~--

e e Anticipatory Reactor Trip System PriorTo Restart m Evaluate adequacy of no actuation of annunciator alarms when ARTS cabinet dooris open. E Long Term a Modifylamp test circuit. ) a Provide labeling to minimiza problems in correlating channel and breaker designations. m Evaluate separating ARTS channel signal inputs to computer to facilitate determining which parameter initiated an ARTS trip. m Review main turbine stop valve testing as potential source of spurious low pressure ARTS trips. I k lf i e

3 J. l I i Control Rod Drive Control System l. PriorTo Restart m Determine improved power supply fuse size and I design; perform inrush current and current waveform test. a improve cleanliness of CRDCS cabinets to reduce contact fouling problems. I a Ensure adequate forced air cooling of reactor service structure. i t I e i 9 ) 'k.

Control Rod Drive Control System (Cont'd) i Long Tem 1 a Evaluate altemate control rod direction error circuit design. j u Evaluate control rod motion momentary interrupt circuit. l u Review overall service structure cooling design. m improve power cable mating and handling procedures. 'i a Evaluate use of higher temperature silicon power i cables. a inspect all control rod leaf spring anti-rotation i devices at each refueling outage. i !I a Evaluate improved control rod drop time test l, techniques. s To preclude low voltage problems, check voltage j . output of CRD transformers frequently; clean and j'. Inspect Inductrol voltage regulator and lubricate l motor-generator set every refueling outage. I a Determine long-term resolution of CRDM nozzle flange leaks. m Evaluate means of minimizing occurrence of low insulation resistance in CRD stators. i 1 .4m. ,a._,_.,., .r,%_,.,. _.c%--,m_._~mm,-w,-------,.

incore Monitoring System i PriorTo Restart j u Determine proper correction factors for neutron detectors. l Long Term l a lmprove reliability of incore neutron detectors for 15% to 30% reactor power. a Evaluate need for two incore instrumentation multipoint recorders. i l i l I l I e _m.=..

e e l Reactor Protection System !l PriorTo Restart s Repair / replace defective components in NI Source Range string contributing to erratic noise and loss i of signal problems. ) e Install electronic filters on reactor coolant flow i transmitters to reduce flow turbulence noise. I Long Term f a Evaluate Technical Specification change to permit placing a defective channel in manual bypass. a Evaluate providing more reliable power range il signal to Integrated Control System. s Eliminate noise spikes in NI Source Range channels apparently due to door alarm switches on RPS cabinets, I h I I i I I 1 ,_p___....-. .y..-.--- ..-1 e-.,. _4_..;_,,.

l. i i l l j Steam and Feedwater Rupture Control System (SFRCS) i PriorTo Restart a Provide filtering of steam generator level transmittersignal. a Modify SFRCS to preclude isolation of main feedwater and rhain steam on low water level in 4 j steam generator. !I e Modify SFRCS to isolate only first steam generator for which low pressure is detected. j j u Modify SFRCS such that atmospheric vent valves i are closed by a full SFRCS trip (actuation) rather than % trip. f a Modify SFRCS to provide open signals to MS106A and MS107A for all SFRCS actuation conditions. m Rearrange manual SFRCS actuation switches and provide protection against inadvertent actuation. e improve Control Room annunciator indl cation of which steam generator has been source of SFRCS I actuation. i h I f

s Steam and Feedwater Rupture Control System (SFRCS) PriorTo Restart (Cont'd) l 8 Relocate reset buttons for startup feedwater valves to the control board. e improve temperature control of SFRCS steam generator pressure switch sensing lines. a Revise labels on manual resets for indicating lights r associated with steam generator level l Instrumentation. 1 m Provide separate manual reset for "SFRCS Full i Trip" alarm. i a improve SFRCS power supply operation. Install forced cooling to cabinets. Measure power supply loading and estimate useable service life. Perform engineering evaluation of and measure response time for replacement amplifier / calibration boards for steam generator level transmitters. t 4 e a 9 m ee - - n ei.e p - w, mie,s.e,.4an..- 2 -,. -

i I i li i ) Steam and Feedwater Rupture Control System (SFRCS)(Cont'd) Long Term i i a Remove automatic close signals to AF599 and AF608 and leave valves open to improve overall \\ reliabilityof AFWSystem. a Modify SFRCS fo preclude isolating both steam generatons if coincident low pressure signals are i received for both steam generatons. a Evaluate modifying control circuitry for main steam i isolation valves to improve reliability. t a Evaluate several additional changes to SFRCS to i improve system reliability and improve decay heat ,j removalcapability e Evaluate additionalimprovements of Control Room l j i annunciator indication of SFRCS actuation. 1 t i a Evaluate removing SFRCS close signals to l atmospheric vent valves.- j u Establish improved record keeping for SFRCS t power supplies and trend to better determine !l expected service life. l e Monitor, periodically, the 125 Volt DC bus to ensure j noise is at acceptablylow level.

Modify steam generator level instrument monitors.

i. --l- - 1

===--

7 i i i Safety Features Actuation System PriorTo Restart s Modify SFAS to avoid ungrounded power supply common problems by installing separate sensor channelpower supplies. m Confirm AC and DC contact current in SFAS output relaysin within design capability. s Repair / replace surveillance light cards having damaged components or electrical connections. Long Term I a Evaluate attemate surveillance card design. a Evaluate elimination of SFAS closure of main steam f isolation valves. s investigate spurious SFAS incident level 1 trips due to spiking of radiation monitor strings. a lmprove human engineering considerations i associated with (1) relative location of SFAS manual trips and associated reset pushbuttons, (2) location of reactor coolant pump seal injection, and (3) seal l retum valve control switches. t I t 9 e i N a mum m.s -a .-o e y >sy g e s_ mmil m - <~w^~~~ ~~- ~ ' ~ -

i I i Integrated Control System Prior To Restart l a lmprove main feedwater pump runback control upon unit trip (rapid feedwater reduction circuitry). i 1 m Replace inoperable fuse holders. m Calibrate selected control modules, a Perform action plan 16 requirements. s Modify load balance control for turbine bypass valves. m Upgrade selected control modules. } Long Term t u Evaluate altematives to rapid feedwater reduction control scheme. a lmprove preventive maintenance system. L a improve proportional and integrating i module reponse. a Provide additional cooling for ICS cabinets. s Provide monitoring capability for selected ICS parameters (diagnostic). s Replace power selector switches. a lmprove transfer capability for pressure inputs to ICS for turbine bypass valves. I l ~

.i t i i i t i Security System i i PriorTo Restart j u Evaluate / modify security requirements to improve operator access, a Review electrical loads on uninterruptible l power supply. i a Revise procedures in event of loss of ventilation to Central Alarm Station. 3 Long Term l 8 Perform evaluation of several operational / reliability a improvements forsecurity system. f 1 l 1 4 i 9 d _,__.,_-.__.,.m.._

t. 'll Control Room Normal and Emergency Ventilation Systems i t PriorTo Restart t s Modify overall control scheme for water-cooled and air-cooled condensing modes of Emergency Ventilation System (EVS). e Manually adjust Service Water System cooling flow a to water-cooled EVS condenser to accommodate l l seasonal changes. )', a Replace refrigerant solenoid control valves and Jnstall additional stop and check valves to facilitate 3 refrigerant control for EVS. mincrease cooling capacity of EVS. e improve air distribution across cooling coils. a install / repair gaskets on Control Room door and security room door to limit air leakage. l u a Calibrate control and indicating instrumentation. i f ll e 0 l l -N'"*[",*.-..-,...._.._._

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i i Control Room Normal and Emergency-Ventilation Syr 5p f Long Term (/ s Install flow modulating control valve in service water cooling path for EVS. i a Further increase cooling capacity of EVS.

Limit use of manual switches on local control panels associated with EVS.

r s Perform air flow balance of normal ventilation i

I system.: a Review overall adequacy of normal ventilation i

system. j u Develop improved preventive maintenance i procedures for entire system including dampers t and actuators. e inspect and refurbish air handling duct work and associated insulation, filters and differential pressure units to improve cleanliness conditions in control room. l e improve operator indications and control regarding normaland EVS operation. L a Clean and repair humidification system. Evaluate alternate designs. m Evaluate causes of failures of chlorine detectors l' and station vent air particulate monitors. l ,i i i i I

1 i i = t Station Air and Instrument Air lj Systems PriorTo Restart t j a lsolate and repair leakage in Station Air and l Instrument Air systems to maximum practical I extent. l i m Perform required station air compressor preventive j maintunance. m Test setpoints of control valves used to maintain 4 instrument air header pressure in the event of l t station air system failure. a Revise procedures and testing to identify the t ) temporary diesel air compressor as the backup air j supply.

Provide improved reliability of. diesel air compressor during inclement weather.
Procedurally blow down drains from SA28 to

) remove accumulated moisture in station air system. a Provide filtering of air supply through SA2010 to g i minimize debris accumulation. l!' i l l i

t i i I Station Air and instrument Air Systems (Cont'd) l Long Term e Perform engineering study of Station Air and Instrument Air systems to evaluate several areas for l improving overall reliability e.g., required emergency air dompressor (size; isolable vs. non- ) . isolable loads; need for 100/100 psig regulators; leakisolation flexibility). l e Install moisture trap on SA28 to improve draining. g i a Segregate air intake and diesel exhaust for diesel l i air compressor. 4 m Modify Station Air and Instrument Air systems to prevent dumping system air to atmosphere when the dryers are bypassed. 4 I m increase frec;uency of dewpoint check on instrument a r receiver to detect unacceptable moisture leakage from station air headers to instrument air headers; install permanent air. dryer j around IA408. i l 6 m Evaluate providing capability to start station air compressor 12 from Control Room. a lnstall flow meter to permit trending of air system degradation., l l 1 1 i ' ?

2 211.11*_J.C 22:?? '" **111*Ll,_L. __. _-_____ ____

i Il j l i i i Station Fire Protection PriorTo Restart ,l m Provide audible fire alarm in Control Room. Long Term a Maintain fire ala,rm location backup on security computers. a Revise circuitry for ionization smoke detectors to avoid spurious alarms. a Evaluate improving testing and maintenance j accessibility of several smoke detectors and )i tempemture switches. ll ' Resolve operational problem with ionization smoke 1 detector installed above control rod drive breakers. a Complete fire protection enhancement program on schedule consistent with Appendix R i commitments.

Provide time delay for diesel fire pump start to r

minimize unnecessary starts while the electric fire pump brings up system pressure. a Resolve power supply problems with Viking fire panels. i

Modify fire alarm display in Control Room so that 2

both panel number and zone number are provided. i ~ : =2.== = - =- =:=== ---

s Component Cooling Water System j PriorTo Restart a Functionally test CCW pump room ventilation fans.. a Repair or replace nitrogen regulator for CCW f surge tank. I Long Term I e Add CCW room ventilation fan periodic test. l s implement attemate pressure control for CCW l surge tank. m Fix small oilleaks on CCW pumps. 1 l k 5 e _.--,,,,--,-.--,.,,,,,-w,--y---- ,r., w,-,w, _.n_, -,, _ - - -,,,--,.. ~,

e. --_e-B4-- A 4 _m Je 4m a a -- -~._ -a. g i 0 + i Service Water System l l PriorTo Restart e Modify.entilation for service water pump rooms. i a Perform ultrasonic test of selected portions of piping and fittings. j u Resolve service water flow through containment air coolers. Long Term t l 8 Periodically ultrasonically test selected portions of Service WaterSystem. I a Review service water pump shaft performance i post-modification. t

Evaluate apparent increased head and flow on service water pump 3-1.

a Evaluate tube corrosion / erosion performance in ECCS room coolers, i j a Modify containment air cooler valves to improve I stroke time. r m inspect tubes in component cooling. water heat 4 l; exchangers. a lmprove temperature control for Component Cooling Water System. f f --.----.,,...-.,---,_.p. _,_,.-.__.,,-._,___,,,$N,,,,,,__,_

3 i I Auxiliary Feedwater System l PriorTo Restart a install air operated steam admission valve near each auxiliary feedwater pump turbine (AFPT); resolve associated high energy line break items. g a Ensure operability of steam traps on AFPT steam supply lines and periodically reconfirm operability. I a Revise AFW pump automatic suction transfer setpoints for switching from condensate storage tank to service water. I a Resolve overpressurization problem for discharge piping from AFW pumps. m install PGG governor on AFPT #1, as currently on AFPT #2; revise low speed stops to accommodate changes in governor operation time. m Evaluate coincident AFW and MFP feed to steam generators. Confirm AFW pump discharge valves will open for i maximum credible differential pressure. l I e e e e

a .i Auxiliary Feedwater System f Prior To Restart (Cont'd) a Remove individual suction strainem to AFW pumps and enlarge mesh on common strainer from condensate storage tank. ) a Remove control power from suction valves FW786 and FW790 to preclude spurious closure. m increase time delay on suction pressure switch actuation which isolates steam supply to AFPTs. s implement improvements to AFPT overspeed trip mechanism. j u Calibrate AFW pump flow instrumentation. l s implement controls to preclude steam binding of AFW pumps (NRC IE Bulletin 85-01) m install pressure switches to detect main steam line j breaks upstream of MS106, MS106A, MS107, MS107A. i I e 4 m

1 f. i 6 Auxiliary Feedwater System (Cont'd) f Long Term j . investigate means of monitoring for condensate in u l AFPT steam supply lines. e improve steam generator level control capability when using AFW pumps. l m Evaluate leaving AF3870 and AF3872 open during 3 lj plant operation to further improve AFW System reliability. l[- m Evaluate potential for contamination from Service WaterSystem to AFW pump suction. I e Improve operability of manual mechanical overspeed trip on AFPTs. almprove access to AFW pump #1 room. i m inspect internals of AFW pump and turbine during l-next refueling outage. m Provide accurate means of monitoring AFW pump recirculation flow. t a lmprove AFW pump rooms ventilation control. m improve Control Room board control, indication and reset layout. 1

f h i Main Steam System I Prior To Restart a Refurbish and check setpoints for all main steam safety valves (MSSV's). m install lift stop collars on "R" orifice MSSV's. a install lateral snubber on "A" main steam header. a Recalibrate atmospheric vent valve controls, m Administratively require plant shutdown if both t. 1050 psig setpoint MSSV's on a header are inoperable. a Test smaller inlet bore size for MSSV's. u Establish le~ak rate for testing of main steam [ non-retum valves. i Long Term l eInstall MSSV monitoring system. a lmprove mechanical design of main steam isolation valve position switches. m investigate increased noise and general vibration L with full arc admission to main turbine. I e _._.._-.-,__r-_

i i Steam Generator System Prior To Restart m Provide engineering analysis regarding l-acceptability of having~ exceeded procedural pressure / temperature limits during testing. Long Term s improve reliability and accuracy of steam generator shell thermocouple temperature readings. m Evaluate modifications to condenser steam jet air ejector radiation monitors. i L M

P I b Main Feedwater System -l Prior To Restart i e investigate and correct cause of power suply j failures for main feedwater pump turbine (MFPT) j controlsystem. a lmprove reliability of MFPT low pressure drainage header pumps. u Evaluate via testing ability for automatic vs. manual ~ control of main feedwater pumps between 15% and i 45% plant power. e Minimize potential for overfeeding steam i generators after reactor trip by modifying interlocks between startup valve and main feedwater ( block valve. I e improve reliability of MFPT oi! system by installing accumulator. 1 s Resolve apparent vibration problem on MFPT 1-1 pump end bearing (instrument problem). t f ---.---.v,-- -, -, _

k..?. t i i I Main Feedwater System (Cont'd) ( Long Term m Perform overall reliability study of main feedwater I system and associated support systems. r a Evaluate modifipations to high pressure drain system to minimize flashing and vibration. m Repair or replace level indicating sight glasses on high pressure feedwater heaters. a Correct variance among MFPT turbine l speed indicators. j u Improve reliability of MFPT turning gear system. m improve flow control during feedwater cleanup operations performed prict to each reactor plant [ startup. t l t t i e i

p. I i j MEETING

SUMMARY

DISTRIBUTION Licensee: Toledo Edison Company f .i

Copies also sent to those people on service (cc) list for subject plant (s).

i l Docket File i NRC PDR L PDR l PBD-6 Rdg JPartlow (Emergency Preparedness only) JStolz ADe Agazio f OELD EJordan r BGrimes ACRS-10 h NRC Participants I OParr L RJones DCrutchfield CRossi L IJackiw DPersinko I GCwalina PMcKee AHowell JSharkey GDick WPaulson [ JWerniel RHernan DEisenhut JKeppler JTaylor GEdison t CVanDenburgh DKosloff i i i ? k 1 2 a w

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ML20138P884

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