ML16342D937

Provides Summary of 971216 Meeting W/Nrc & Util Re Staff Approach to Conduct of on-line Maint,Lessons Learned During Preparations for & Conduct of Recent Replacement of Unit 2 Startup Transformer & Plans for Upcoming Refueling Outage

ML16342D937
Person / Time
Site:	Diablo Canyon
Issue date:	12/31/1997
From:	Gwynn T NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION IV)
To:	Rueger G PACIFIC GAS & ELECTRIC CO.
References
NUDOCS 9801070323
Download: ML16342D937 (74)

Text

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ACCESSION NBR:9801070323 DOC.DATE: 97/12/31 NOTARIZED: NO DOCKET FACIL:50-275 Diablo.-Canyon Nuclear Power Plant, Unit 1, Pacific Ga 05000275 50-323 Diablo Canyon Nuclear Power Plant, Unit 2, Pacific Ga 05000323 AUTH.NAME AUTHOR AFFILIATION GWYNN,T.P.

Region 4 (Post 820201)

RECIP.NAME.)..,

'RECIPIENT AFFILIATION RUEGER,G.M.

Pacific Gas

&. Electric Co.

SUBJECTs Provide's summary of mgt meeting w/PG&E held on 971216 at NRC Region IV ofc re PG&E staff'pproach to" conduct of

'on'-line maint,lessons learned during preparations for 6

'conduct'of recent replacement of Unit 2 startup transformer.

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TITLE: Summary of Significant Meeting with Licensee (Part 50)

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Vl UNITED'STATES NUCLEAR REGULATORY COMMISSION REGION IV 611 R<AN PLAZA DRIVE, SUITE '00 ARLINGTON,TEXAS T6011.8064 OEC 3't t997 Gregory M. Rueger, Senior Vice President and General Manager Pacific Gas and Electric Company Nuclear Power Generation, N9B P.O. Box 770000 San Francisco,. California 94177

SUMMARY

OF MEETING WITH NRC AND PACIFIC GAS 8 ELECTRIC COMPANY-DECEMBER 16, 1997

Dear Mr. Rueger:

A management meeting, open to public observation, was held on December 16, 1997, in the NRC Region IV office. The meeting was conducted to discuss your staff's approach to the conduct of on-line maintenance, the lessons learned during preparations for and conduct of the recent r'eplacement of the Unit 2 startup transformer, and plans for the upcoming refueling outage in Unit 2. The meeting attendees are listed in Enclosure 1. The documents used. in your staffs presentation are provided in Enclosure 2.

During the meeting, your staff presented the factors considered in the evaluation of maintenance activities to be performed on-line. Your staff discussed the work control process used to plan and schedule on-line maintenance work, including use of a 12-week rolling schedule, use of system outage windows, and use of two schedule reviews performed by the operations department.

Your staff indicated that they had recently formalized these processes by incorporating them into a written policy. Specific examples of the types of maintenance activities which had been performed and those which had been considered, but later deferred, were described.

Your staff acknowledged that, while extensive planning for the Unit 2 startup transformer replacement had been performed, there had been insufficient consideration of compensatory actions to cope with potential problems that could occur during the transformer replacement.

While the evolution was performed successfully, additional evaluation of worst case scenarios would have been prudent and should have more fullyconsidered the need for simulator training and procedure walk-throughs for restoration of off-site power through the main transformers.

In addition, your staffs risk evaluations focused on static conditions and not transient conditions which would exist during the evolution.

Your staff discussed the plans for the upcoming Unit 2 refueling outage, scheduled to begin February 14, 1998. Of particular note were the plans for early midloop operations (4 days after shutdown).

Midloop operations would last approximately 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> in order to install steam generator nozzle dbms. The plans for midloop operations included having two of three vital 4 kV busses available with the associated emergency diesel generators and having both off-site power. sources and both residual heat removal pumps available.

Your staff indicated that work aot associated with midloop operations would be suspended during the evolution. Due to the 980i070323 97i23i PDR ADOCK 05000323 P

PDR IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII

Pacific Gas and Electric Company risk significance of this evolution and the problems encountered by other licensees performing this evolution, detailed discussions and observations willbe performed by the Region IV inspection staff.

The discussions during the meeting were helpful in understanding your, on-line maintenance evaluation process and the considerations foF the upcoming Unit 2 refueling outage.

The discussions reinforced the need for early communication between your staff and the NRC for those evolutions of greater risk or those which could lead to a unit being in an unusual operating

- condition.

tEl ll ~

Sine Iy omas wy n, Dir ct r Division of Rea tor P oje s

Docket Nos.:

50-275 50-323 License Nos.:

DPR-80 DPR-82

Enclosures:

1. Meeting Attendees

2. Licensee Presentation Slides cc w/enclosures:

Dr. Richard Ferguson Energy Chair Sierra Club California 1100 lith Street, Suite 311 Sacramento, California 95814 Ms. Nancy Culver San Luis Obispo Mothers for Peace P.O. Box 164 Pismo Beach, California 93448 Chairman San Luis Obispo County Board of Supervisors Room 370 County Government Center San Luis Obispo, California 93408

Pacific Gas and Electric Company

. Mr. Truman Burns)Mr. Robert Kinosian California Public Utilities Commission 505 Van Ness, Rm. 4102 San Francisco, California 94102 Robert R. Wellington, Esq.

Legal Counsel Diablo Canyon Indepehdent Safety Committee 857 Cass Str'eet, Suite D

Monterey, California 93940

'r. Steve Hsu Radiologic Health Branch State Department of Health Services P.O. Box 942732 Sacramento, California 94234 Christopher J, Warner, Esq.

Pacific Gas and Electric Company P.O. Box 7442-San Francisco, California 94120 Robert P. Powers, Vice President and Plant Manager Diablo Canyon Power Plant P.O. Box 56 Avila Beach, California 93424 Managing Editor Telegram-Tribune 1321 Johnson Avenue P.O. Box 112 San Luis Obispo, California 93406

Pacific Gas and Electric Company bcc to DCD (IE45) bcc distrib. by RIV:

Regional Administrator DRPDirector Branch Chief (DRP/E, WCFO)

Senior Project Inspector (DRP/E, WCFO)

Branch Chief (DRP/TSS)

WCFO File Resident Inspector DRS-PSB MIS System RIV File M. Hammond (PAO, WCFO)

DOCUMENT NAME: R:tt DCttDC1216MS.DRP To receive copy of document, indicate In box: "C"= Copy without enclosures "E""-Copy with enclosures "N"= No copy RIV:C;DPR/E HJWong" 12/29/97 (BJO)

"previously concurred D:DRP TPGwynn 12/Ql/97 OFFICIAL RECORD COPY

Pacific Gas and Electric Company bcc to DCD (IE45) bcc distrib. by RIV:

Regional Administrator DRP Director Branch Chief (DRP/E, WCFO)

Senior Project Inspector (DRP/E, WCFO)

Branch Chief (DRP/TSS).'CFO File Resident Inspector DRS-PSB MIS System RIV File M, Hammond (PAO, WCFO)

DOCUMENT NAME: R:tt DciDC1216MS.DRP To receive copy of document, Indicate in box: "C" = Copy without enclosures "E" = Copy with enclosures "N"= No copy RIV:C:DPR/E HJWong" 12/29/97 (BJO)

"previously concurred 07nno,,

r D:DRP TPGwynn 12/5(/97 OFFICIAL RECORD COPY

MEETING ATTENDEES MEETING:

NRC & Pacific Gas and Electric Company DATE December 16, 1997 LOCATION :.Arlington, Texas ENCLOSURE.1 NAME D...L

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NEETING ATTENOEES MEETING NRC 8 Pacific Gas and Electric Company DATE December 16, 1997 LOCATION:

Ar 1 ington, Texas NAME 6 PONAlg AFFILIATION/TITLE V/ca-p.

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ENCLOSURE 2

'genda Maintenance Safety Management Program I,t A

TQPIcs 10:45-10:50 am 10:50-10:55 am 10:55-11:25 am 11:25-12:05 pm 12:05-12A5 pm Introduction Operational Perspective On-line Maintenance Outage Maintenance Summary B. Powers J. Molden J. Becker B. Hinds B. Powers

OPERA TlONALPERSPECTlVES

~ Operational and Maintenance Guiding Principles

~ Means to Monitor Effectiveness of Principles

'IABLOCANYONPOWER PLANT ON-LINEMAINTENANCE December 16, 1997 James R. Becker - Assistant Maintenance Services-Manager

ON-LINEMAINTENANCE OVERVIEW

~, Scheduling and Risk Assessment Process

~ On-line Maintenance Performance Policy

~ Example of Jobs Performed On-line

~ Examples of Jobs Deferred

~ Lessons Learned

On-Line Maintenance. Scheduling and Risk Assessment

~ 12 week rolling matrix Weeks organized by bus and SSPS train

~ Coordinated with surveillance tests and maintenance outage windows

~ Normally only one MOW per cycle Scheduled for no more than 1/2 AOT Continuous work hours for 72 hr A.S.

~ Schedule is overseen by OPS scheduling SS

~ Maintenance risk assessment performed during scheduling, and immediately prior to implementation

On-line Maintenance Scheduling and Risk Assessmenf cont.

~ Risk assessment based on PRA Effect on key safety functions

~ Risk assessment results used to approve, disapprove, or require OPS director approval

Policy B-12

~ Written in November 1997 to standardize current practices

~ Contains screening criteria for risk/benefit considerations Job quality Outage risk reduction Outage duration Trip risk SSC unavailability PRA allowed outage time Technical Specifications

~ Planning considerations include:

Post maintenance test performance Written contingency plans Previous lessons learned Detailed schedule Proper train/bus week Tailboard Operator training Independent SRO review Enhanced management coverage

Examples ofJobs Performed On-line

STP M-75 (4 kV relay testing)

~ Diesel fuel oil storage tank replacement

~ Start-up transformer replacement Service cooling water heat exchanger work

Examples ofJobs Deferred

~ Power range NIS calibrations

~ Auxiliaryfeedwater pump pressure transmitters

~ PORV channel calibrations

~ Unit 2 air side seal oil pump repairs,...

~ Service cooling water pumps/control circuitry

Reason:

Cycle extension Considerations:

Special test/evolution Procedure revised with crew input Management tailboardslcoverage Unloaded bus Other work re-scheduled as necessary

Diesel Fuel Oil Storage Tank Re lacement Reason:

Underground storage tank concerns Considerations:

Temporary procedures written to cover various aspects Increased manning JIT training on fuel oil transfer Conditional surveillances

Start-up Transformer Replacement Reason:

Upgrade S/U off-site power supply

'capability Considerations:

Special test/evolution Temporary Procedure covered all aspects Management tailboard/coverage Increased operator manning Weekend work, to minimize conflicts JIT training on simulator and on tap-changing Other pre-req's

Lessons Learned

Operator training

~ Work in high-risk areas

~ Temporary procedures

~ Advance review by performing organizations

~ Joblproject "owners"

~ Manning requirements

~ External factors

~ Management coverage

'IABLOCANYONPOWER PLANT OUTAGE MAINTENANCE.

December 16, 1997 Brad Hinds - Director, Outage Planning and Scheduling

OUTAGE OVERVIEW

~ Outage Safety Plan

~ 2RB Activities

OUTAGE SAFETYPLAN

~ Describes Major Work to be Performed During the Outage

~ Describes Defense in Depth Strategies for Key Safety Functions

~ Identifies Higher Risk Evolutions and Required Contingency Plans

~ Identifies Special Tests and Infrequently Performed Evolutions

Outage Safety Schedule Logic Shiftly by the operations crews and,the. outage safety coordinator

~ Prior to outage plant configuration. changes such as:

inventory changes mode changes core alterations electrical power configuration changes

~ Outage Risk Assessment Management (QRAM)

Program also is used to verify safety schedule logic

2R8 ACTIVITIES

~ Infrequently Performed Tasks or Evolutions

~ Activities That Could Impact:the Operating Unit

~ Higher Risk Activities

Infrequently Performed Tasks or Evolutions

~ Midloop Operations prior to core offload after core reload

~ DC Control Power Jumper to Vital 4 kV Bus H support vital DC Battery 2-3 replacement

~ Plant Startup

Activities That Could Impact the 0 eratin Unit

~ New capacitor banks to the 230 kV (startup power) switchyard

~ ASW pump maintenance windows

~

U1 startup power to remain energized

Higher Risk Activities

- Periods when passive decay heat removal is not available 1

Example:

Refueling cavity flooded with upper internals installed

~ Period between voiding SG U-tubes and establishing a hot leg vent path

~ Period between vessel head detensioning and flooding the refueling cavity

~ Period between setting the vessel head and running the RCPs (RCS filled and vent)

~ Midloop operations

Midloop Operation

~ Prior to core offload Outage day 4 Approximately 15 MWdecay heat load Time to boil approximately 15-20 rriinutes I

~ After core reload Outage day 22 Approximately 4 MWdecay heat load Time to boil approximately 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />

Midloop Contingencies

'o activities allowed that could result in'loss of RCS inventory

~ Optimize AC power supplies

~ Operator training

~ Special management oversight of the evolution

~ Pre-job tailboard 4

Midloop Contingencies cont.

~ At least 2 steam generators filled to >15% NR

'ontainment closure or closure capabilit maintained

~ WR and NR RVRLIS and LI-400 agree within tolerance

~ Frequent RVRLIS walkdowns

~ Sl pump available as a backup

~ Operator stationed in containment

~

ravity fillmakeup flow path to the RCS from the RWST

~ Operational containment PA system

Midloop Contingencies cont.

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~ Time to boiling, time to core uncovery, and ECCS flow requirements are calculated at least orice per shift C

~ Vent hoses are staged to expedite returning an::

RHR pump to service after vortexing

~ 2 CFCUs available iftemporary penetrations are installed

Communications

~ OCC Personnel

~ Plan of the Day Memo

~ Sensitive Equipment Controls Postings

Lessons Learned

~ Self-assessment of each outage performance

~ Over 6QO lessons learned were submitted for 1RB, over 3QQ for 2R7

~ Examples of some important lessons learned Electrical bus walkdowns once per shift.

Perform walkdown of off-site power supply equipment to remain in service prior to clearing the other off-site power supply Station an operator inside containment at all times when there is water on the SG nozzle dams

~I'

~

Lessons Learned cont.

~ Examples of some important lessons learned cont.:

Operations crews, along with the significant other players involved in the shutdown.

sequence, will perform real time shutdown sequence training. Good practice observed at STP Nozzle dam installation and removal coordination practice - Comanche Peak Additional operations crew staffing