ML18151A656

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Forwards Summaries of Visit to Plant During Wk of 930628 & 930728 Meeting in Atlanta,Ga Re Edsfi Insp Scheduled for Wk of 930816,per .List of Attendees Also Encl
ML18151A656
Person / Time
Site: Surry  Dominion icon.png
Issue date: 08/04/1993
From: Gibson A
NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II)
To: Stewart W
VIRGINIA POWER (VIRGINIA ELECTRIC & POWER CO.)
References
NUDOCS 9308130013
Download: ML18151A656 (70)
v • d • e


Text

.*

August 4, 1993 Docket Nos. 50-280, 50-281 License Nos. DPR-32, DPR-37 Virginia Electric and Power Company ATTN:

Mr. W. L. Stewart Senior Vice President - Nuclear 5000 Dominion Boulevard Glen Allen, VA 23060 Gentlemen:

SUBJECT:

MANAGEMENT MEETING

SUMMARY

Your letter to the NRC dated June 3, 1993, requested that we cancel or reduce the scope of the Surry EDSFI inspection scheduled for late this month.

Your letter described self-assessments and corrective actions that you had completed and stated that additional NRC inspection would be of marginal value.

Milton Shymlock of our staff visited Surry the week of June 28, 1993, to review your self-assessments and corrective actions and your staff met with the NRC staff in Atlanta on July 28, 1993, to further discuss these matters.

The results of the site visit are documented in Enclosure 1 and a summary of the meeting and it's attendees is provided as Enclosure 2.

The self-assessments that you have completed are similar in scope to EDSFI inspections performed pursuant to TI 2515/107, Electrical Distribution System Functional Inspection.

Your assessments at Surry have included areas identified as deficient during the NRC EDSFI at North Anna.

In consideration of these self-assessments, we agree that the full scope NRC EDSFI previously planned for Surry is not needed.

Accordingly, we will reduce the scope of this EDSFI to include one week onsite by a team leader and three inspectors.

The focus of our inspection will be to assess the corrective actions taken and planned in response to your self-assessmentso This inspection will be led by Milton Shymlock during the week of August 16, 1993.

. In accordance with 10 CFR 2. 790 of the NRC's "Rules of Practice,"

a copy of this letter and its enclosures will be placed in the NRC Public Document Room.

9300130013 6~gggi00 PDR ADOCK PDR G

Virginia Electric and Power Company 2

August 4, 1993 Should you have any questions concerning this letter, please contact us.

Enclosures:

1. Site Visit
2. Meeting Summary
3. Handouts cc w/encls:

M. L. Bowling, Jr., Manager Nuclear Licensing Virginia Electric & Power Company 5000 Dominion Boulevard Glen Allen, VA 23060 M. R. Kansler Station Manager Surry Power Station P. o. Box 315 Surry, VA 23883 Ray D. Peace, Chairman Surry County Board of Supervisors P. o. Box 130 Dendron, VA 23839 Dr. w~ T. Lough Sincerely, (ORIGINAL SIGNED BY J; P. JAUDON FOR)

Albert F. Gibson, Director Division of Reactor Safety Virginia State Corporation Commission Division of Energy Regulation P. o. Box 1197 Richmond, VA 23209 Michael W. Maupin Hunton and Williams Riverfront Plaza, East Tower 951 E. Byrd Street Richmond, VA 23219 (cc w/encls cont'd - See page 3)

Virginia Electric and Power Company (cc w/encls cont'd)

Robert B. strobe, M.D., M.P.H.

State Health Commissioner Office of the Commissioner Virginia Department of Health P. o. Box 2448 Richmond, VA 23218 Attorney General Supreme Court Building 101 North 8th Street Richmond, VA 23219 bee w/encls:

G. Belisle, RII B. Buckley, NRR Document Control Desk NRC Resident Inspector 3

U.S. Nuclear Regulatory Commission Route 1, Box 166 Surry, VA 23883 NRC Resident U.S. Nuclear Route 2, Box Mineral, VA Inspector Regulatory 78-A 23117 Commission P:\\SURRY.MBS e~

4{Qf~

DOCUMENT NAME:

RII~.

RS

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8/t /93 RI~fRP AB~sle s/,\\/93 MP7fanich 8/'1 /93 August 4, 1993

e Vir~inia Electric and Power company (oc w/encla cont'd)

Rob*rt a. Strobe, M.D., M.P.H.

state Health commi*aione~

office of the commissioner Virginia Department of Health P. o. Box 2448 Richmond, VA 23218 Attorney General supreme court Building 101 North Bth Streat Richmond, VA 23219 bee w/encl*:

G. Bali*le, RII B. Buckley, ND Document Control Desk 3

NRC R**idant Inspector u.sv NUclear Regulatery commiaaion Route 1, BOX 156 Surry, VA 23883 NRC Resident ?n*pector u.s. Nuclear Regulatory Commission Route 2, Box 7S*A Mineral, VA 23117 DOCUMENT NAME:

P1\\St1RRY.MBS RII:DRS MShymlocJc*

8/

/93 e121'd RI'l::DD ABelisle 8/

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August 4, 1993 R:t:C:DRS CJulian 8/./93

e ENCLOSURE 1 SITE VISIT

SUMMARY

During the week of June 28, 1993, the Section Chief of Plant Systems Section in the Division of Reactor Safety vis.ited the Surry Power Station to review those areas identified in your request letter.

The overall approach to your self-assessments was reviewed.

The Electrical Distribution System Functional Assessment (EDSFA) performed by the Corporate Nuclear Safety (CNS) group was reviewed.

The scope of the EDSFA was compared to the scope of the Temporary Instruction 2515/107, Electrical Distribution System Functional Inspection.

The level of effort in some specific areas and team members qualifications were discussed with the EDSFA Team Leader and other licensee personnel both at the station and at the Corporate Engineering offices.

The follow-up of several items identified during the North Anna EDSFI and their applicability to the Surry station were reviewed.

Other assessments performed, i.e., assessment of switchyard and the Transmission and Distribution's Department's assessment of the switchyard were also discussed during this visit.

Plant tours were conducted to verify that several modifications were correctly performed and a sampling of Electrical Distribution System (EDS) equipment was inspected to assess its material condition.

A sample of Electrical Calculations was discussed with engineers at the Corporate Engineering office.

e ENCLOSURE 2 MEETING

SUMMARY

An NRC and Virginia Power management meeting was conducted at the Region II office on July 28, 1993, to discuss the licensee's request for not performing an Electrical Distribution System Functional Inspection (EDSFI) at the Surry Power Station.

The Director of the Division of Reactor Safety opened the meeting by stating that the NRC was interested in what the licensee had done since the EDSFI at North Anna and why the Electrical Distribution system (EDS) at Surry was acceptable.

The Manager, Nuclear Licensing and Programs, provided opening remarks for Virginia Power.

He discussed how much money they felt it would cost to perform the EDSFI and stated that it would be better spent on fixing problems currently identified.

An overview of the presentation was then discussed using handouts, Enclosure 3.

The Manager, Nuclear Electrical Engineering, then discussed the Programmatic Enhancements for the 1990 and those since the North Anna EDSFI using handouts, Enclosure 3.

The Assistant Station Manager, then discussed the overall station support to the electrical distribution system and to the tracking of the items identified during their own Electrical Distribution System Functional Assessment.

The corrective actions for some of these items were also discussed using handouts, Enclosure 3.

The presentation was closed by Virginia Power stating that the initiatives completed or underway in the electrical distribution area provided sufficient assurance that the systems would perform adequately.

The NRC management closed the meeting by thanking Virginia Power for the presentation and stated that we would get back to them soon with our decision.

MANAGEMENT MEETING LIST OF ATTENDEES Virginia Electric and Power Company (Virginia Power)

M. Bowling, Manager, Nuclear Licensing and Programs A. Price, Assistant Station Manager - Surry G. Flowers, Manager, Nuclear Electrical Engineering Nuclear Regulatory Commission - Region II A. Gibson, Director, Division of Reactor Safety (DRS), Region II (RII)

J. Jaudon, Deputy Director, DRS, RII

c. Julian, Branch Chief, DRS M. Sinkule, Branch Chief, Division of Reactor Projects (DRP), RII B. Buckley, Licensing Project Manager, Nuclear Reactor Regulation (NRR)

A. Belisle, Section Chief, DRP, RII 2

M. Shymlock, Section Chief, DRS, RII M. Branch, Senior Resident Inspector, Surry R. Moore, Reactor Inspector, DRS, RII J. Jacobson, Engineer, Special Inspection Branch, NRR F. Ashe, Engineer, Electrical Engineering Branch, NRR D. Tamai, Intern, DRP, RII

ELECTRICAL DISTRIBUTION SYSTEM PROGRAMMATIC IMPROVEMENTS Rec'd w/ ltr dtd 8/4/93...... 9308130013

-NOTICE-THE ATTACHED FILES ARE OFFICIAL RECORDS OF. THE INFO~RMATION &

REPORTS MANAGEMENT BRANCH.

THEY HAVE BEEN CHARGED TO YOU FOR A LIMITED TIME PERIOD AND MUST BE RETURNED TO THE RE-CORDS & ARCHIVES SERVICES SEC-TION P1-22 WHITE FLINT. PLEASE DO NOT SEND DOCUMENTS CHARGED OUT THROUGH THE MAIL. REMOVAL OF ANY' PAGE(S) FROM DOCUMENT FOR REPRODUCTION MUST BE RE-FERRED TO FILE PERSONNEL.

-NOTICE-

I Surry Power Station Etectricm Distribution System Programmatic Im s

VIRGl/t/lA POWER PT1DOA.1

M. L Bowllng Manager - Nuclear Licensing and Programs

Introduction M. L. Bowling Overview/ Self Assessment.

M. L. Bowling Engineering Programmatic Improvements G. H. Flowers Surry EDS Actions J. A. Price Conclusions M. L. Bowling PT100A.3.

Self Assessment Operating Experience Corporate Engineering and Maintenance Corrective Action

  • PT100A.

NAPS EDSFA - April, 1991

  • NAPS NRC EDSFI and Follow-up - August 1991 &

September, 1992 SPS EDSFA and Follow-up - May & December, 1992 CNS RHR/LOOP Assessment - August, 1990

  • CNS Shutdown Management and Follow-up (NUMARC 91-06 Implementation)-January, 1992 & March 1993 CNS Assessment of Switchyard - February-April, 1992 T & D Assessment of Switchyard - June-December, 1992 INPO Outage Assist Visit at Suny - February, 1992 NRC Outage Inspection at North Anna - April, 1992 PT100A.*

Post Modification Testing (PM1) and Follow-ups -

Feb., 1991, Nov., 1991 & Mar., 1993 Equipment Qualification (EQ) Program *and Follow-up -

April, 1993 & June, 1993 Engineering Charige Control and Follow-ups -July-Aug., 1991, May, 1992 & April, 1993 Software Control - Nov.-Dec., 1991 Vendor Information - June-July, 1993 Equipment Classification and Follow-up - Oct., 1992 &

Mar., 1993 Drawing Control and Follow-up - Oct., - Nov., 1992 &

May, 1993 Configuration Management Project-Jan., 1993

NAPSEDSFA NAPSEDSFI SPSEDSFA Design and Calculation Design Calculational Design Basis Calculation Discrepancies Issues Assumption Verification Control of Configuration Setpoint Issues Control of labeling Fuses, Setpoints Setpoints, Fuses UFSAR Acruracy UFSAR Deficiencies TS and UFSAR Discrepancies TS Testing by T & D Procedures for Suiveillance SUIVeillances of Electrical Electrical Personnel and Testing, lack of Equipment, lack Corrective Action of Corrective Action V & V, Training on Revised Procedure Deficiencies Procedure Deficiencies Procedures Technical ls.5ues Technical ls.5ues Technical ls.5ues Safety Evaluation of Safety-related Interface Modifications Boundaries Work Control and Training Review of Electrical Design of Switchyard Contractors Basis Documents Q-List Component Changes and Validation PT100A.7.

Operating Experience Electrical Items Reviewed GL 88-15 Electrical Power Systems - Inadequate Design Control IN 88-45 Problems in Protective Relay and Circuit Breaker Coordination IN 88-86-Sl Multiple DC Distribution Sy&em Grounds IN 88-88-Sl Degradation of Westinghouse ARD Relays IN 89-63 P05.5ible Submergence of Electrical Circuits, Above Flood Level - Water Intrusion/Lack of Drainage IN 89-64 Electrical Bus Bar Failures IN 89-83 IN 90-42 IN 91-29 IN 91-81 IN 92-(Y;)

IN 92-52 IN 92 -69 IN 92-04 O&MR 361 SEN 80 SER 1-90 SER 11-90 SOER 90-1 Sustained Degraded Voltage on the Offsite Electrical Grid and Loss of Other Generating Stations Failure of Electrical Power Equipment Due to Solar Magnetic Distutbances Deficiencies Identified During Electrical Di&ribution System Functional Inspections Switchyard Problems 1hat Contribute to Loss of Offsite Power Overloading and Subsequent Lockout of Electrical Buses During Accident Conditions Misapplication and Inadequate Testing of Molded Case Circuit Breakers Water Leakage From Yard Area Through Conduits Into Buildings Potter & Brumfield Model MDR Relay Failures Replacement Circuit Breaker Characteristic Curves Can Affect Circuit Protection Coordination Motor Control Circuit Fuses Undersized for Degraded Voltage Conditions Unplanned Plant Transient and Damage to Major Electrical Buses Due to Ground Main Transfonner Damage and Fires Caused by Static Electrification Ground Faults on AC Electrical Distribution Systems PT100A.*

Major Operating Experience Electrical Actions Assigned

  • Verify design basis calculations.
  • Develop, enhance, and revise procedures for maintenance, operation, and testing of electrical equipment.
  • Detennine impact of moisture on EQ circuits, possible undeiground water infiltration routes.

Ensure actions for breaching EQ baniers are developed.

  • Coordinate review of "Transmis.5ion Bus Voltage Regulation During Severe System Conditions"..
  • Evaluate generator, transfonner and capacitor bank monitoring scheme to provide protection from GIC.
  • Review NAPS Voltage Profile calculation. Trend protective relay setpoint data for setpoint drift.
  • Review MCCB coordination and characteristic curves.
  • Review 120 VAC motor control circuit fuse sizing.
  • Review voltage and current ratings of components in isophase bus grounding..

Status: 29 Major OE Issues, 73° o Complete PT100A.9.

Reliability Centered Maintenance (RCM) Program for Electrical Items Motor Operated Valve (MOV) Program Circuit Breaker & Associated Switchgear Maintenance Program *

Q-List.

Electrical Calculation Upgrade Program.

Component Labeling Vendor Manual Upgrade

  • Administrative Procedure Upgrade PTIOOA.10.
  • Assignment of EDSFA Items
  • Status of*EDSFA Items:

791 Total Items, 890/o* Complete

  • Incorporation of Lessons Learned Into.

Applicable Programs PT100A.11.

1'800Ud 11:IIIAOd trl/f/lSIIIA

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mivqug 3flUUIWV.tS<MJ fo tnaJ(laH Su,µaaii1Sug (V3µPJJFf aw.m~IV'-

G.HFlowers Manager - Nuclear Electrical Engineering Innsbrook Technical Center PT100B.2

Station Modification Support Work Centered on Station Modifications (A/E as Engineering Lead)

  • Single-Discipline In-House Work Selection Amount of Work Allowed Disciplines To Be Selective -

. Broader-Based Issues Tended To Be Assigned to A/E

  • Reliance on A/E for Issues Resolution Although Some In-House Engineering Studies Were Performed, We Maintained a Heavy Reliance on SWEC for Design Basis Issues Resolution
  • Assimilation of EE Engineering Programs The Recent Reassignment of EE Engineering Programs Required Attention and Resources PT100B.3

Organize for In-House Multi-Discipline Project Support Work Improve Communications and Capability to Support Multi-Discipline Work Establish Single Point of Contact for Most Projects

  • . Organize for In-House Issues Resolution Develop and Retain Expertise In-House
  • Identify Resources for Programmatic Enhancement To the Extent Feasible, Assign Dedicated Personnel for Each EE Program Obtain Dedicated Department Funding (Not.Fully Obtained Until 1992)

PT100B.4

Balance Program Commitments with Daily Station Support Needs With Reduced A/E Role, Recognize that Daily Station Support Needs Will Require Resources as Well Identify Issues and Track Commitments Identify Major Virginia Power EDS Issues Establish EE Task Tracking System (First Half of 1990)

Set Short-Term Issues Resolution Priorities (WLS Level 1 Tas~)

Elevate Known Major Issues, Such as EDG Loading and Fault Current Calculations, to WLS Level 1 Tasks Develop Plans for Long-Term Issues Resolution Develop an Initial Comprehensive Plan for Resolving Known EDS Issues Recognize that Not All Issues Could Be Immediately Resolved PT1009.5

Strengthen Electrical Calculation Bases and Assumptions Resolve Gaps and Ambiguities in Assumptions and Basis Information Decide NOT to have the A/E perform a "Crash" Cale Upgrade, but Recognize that There Could Be Many Open Items for the First EDSFI (NAPS or SPS)

  • Acquire, Train and/or Develop Expertise Emphasize Development of Expertise In-House Recognize that Such Development Would Take Time
  • Assess Progress Utilize Internal Assessments (EDSFA) to Measure Progress PT100B.8
  • filectrical Distribution System (EDS)

Resolve Issues and Upgrade Calculations

  • Equipment Qualification Revise/Update QDRs and EZDs Resolve Issues Backlog Strengthen Station Support
  • . Appendix R Fire Protection Update Appendix R Reports Strengthen Station Support PT100B.7

Instrument and Power System Setpoints Establish Cale Basis for:

Instrument Setpoints Supporting the Safety Analysis Other Tech Spec Instrument Setpoints EDS Tech Spec Setpoints EDS Protection Device Setpoints Convert Setpoint Documents to Electronic Format

  • Self-Contained PC Version Station Network Version Instrument Loop Scaling Calculations Provide Scaling Calculations for RPS and Complex Instrument Loops R.G.1.97 Provide Complete Documentation of Compliance PT100B.8

Civll/Mechanical Engineering EDG Support Systems, HVAC System Calculations, Seismic Issues Configuration Management System Walkdowns and Equipment Information Documentation System Design Basis Documents (SDBDs)

Equipment Tagging Vendor Manuals PT100B.9

  • filectrical Strategy Concentrate on Resolving Industry Issues and those Associated with Higher-Level Calculations Recognize that Lower-Level Calculation Upgrades Would Have To Wait - But Provide Justification for Extension Resolve NAPS Issues First and Apply Results to Suny Preparation Continuously Reconfirm Issues, Prioritize and Assign Seek Input from All Available Sources - EDSFI Clearinghouse, Major Cales, IOER Issues, Meeting at.

SWEC - 1/91, Other Utilities, Vendors, SDBD Open Items Participation NAPS EDSFA - Participant AND Support - Same People All Others - Support Only PT100B.10

Lessons Learned Participation in NAPS EDSFA Was a Leaming Experience (Strength) But Also a Weakness (Missed TS Issues, Resulting in Violations)

The Need to Incorporate Whitesheet" Information into TS SuIVeillance Procedures The Need to Perform Compliance Reviews for TS SuIVeillance Procedures Better Control, Coordination and Indexing of Electrical Calculations Required - (EE-029)

Breadth of NAPS EDSFI Ensured Breadth of Suny

  • Preparation PT100B.11

Calculation Development Hierarchy Calculation Relationship Logic 1992 Re-Review

  • . Current Status for Suny Status of Identified Issues Status of Calculations Future Scope PT100B.12

Nuclear Management Expectations High Expectations Expressed Through Level 1 System

  • Good Unit Performance Strong Unit Performance in 1990 - 1992 Provided Time for Concentration on Design Basis Issues Engineering Management and Supervisory Experience The Experience and Training of the Engineering Management and Supeivisory Team has Enhanced the Ability of Engineering to Support the Stations Nuclear Business Plan The Reduction in Work Order Backlog, Among Other Things, has Contributed to Improved Material Condition PT100B.13 r

Major Modification Backlog Reduction _

A Reduction in Overall Modification Backlog has Contributed to a Reduction in Design Work and has Allowed Engineering to Focus More on Programmatic Issues

  • Training and Team Development
  • Coordinated Training has Established a Strong EDSFI Response Team for Suny Development of In-House Expertise -

Station and Corporate Reducing Reliance on the A/E Has Been Difficult at Times, but the Expertise Now Available Within Engineering Is a Strength r

PT100B.14

Strong Communications Frequent Contacts Within the Engineering Organization have Facilitated a Comprehensive Effort to Resolve the Suny EDS Issues Commitment Management

. The Comprehensive EDS Task Database has Facilitated a Coordinated Response to Open Items Strategy for Resolving EDS Issues

  • Tlllling of SPS Pre-EDSFI Inspection PT100B.15

A/E Calculations Definitive Calculations With Simplifying Assumptions Bounding Calculations With Definite Assumptions With Fully Defined Assumptions

.... I D_C Ba_tt_er....;;..y_S_iz_in=g __ _,~ - - - - -l DC Battery Sizing & Duty Cycle I - - - - DC Model/New Software

.... I D_C_Vo_lt_ag;;;...e_D_ro....;.p __

___.~ - - - - -l EDG Bkr Close Coil Voltage Drop

.... I D_C_R_e_la ___ y_Se_tpo

___ in_t _ __.~ - - -

- -l UV/DV Relay Setpoint CSA Cale 1-- - -

UV/DV Relay Optimum Setpoint

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - I SR 4KV/480V Protect/Coordination I I RCP UV/UF Relay Setpt ~ - - - -

- - - - - - - -.- - - --1 CSA Cale - RCP UV/UF Relay Setptl I EDG Loading/Transient

~ - - -l EDG loading Refined I_ -J EDG LOOP/LOCA Analysis I -, - -! EDG Transient Testing I

I MOV Voltage Drop Cale

~ - - - -

GL 89 - 10 MOV Cale I Vital Bus Fault Current

~---- - ----- - ~-----------!Vital Bus Fault Current

!D_C_R_a_u_lt_Cu_r_rn_nt __ __,~----------------------~

.... D_C_~_u_lt_C_u_rrn_n_t _____

SR 4KV/480V Loading NSR 4KV/480V loading

- - - - - -1 SR 4KV/480V Loading Motor Voltage Drop Impedance Diagram I

I I

.... I A_C_Vi_o_lta.....;;g:;._e_P_ro_fi_le __

__.~ - - - - -l AC Voltage Profile 1---

PT1009.18

  • KC888

S & W 12846;20-3 7/4/81 Impedance Bases Diagram Station EE-029 Drawings 6/17/88 Station Electrical

  • Walkdown Load List Data 4160 & 480 I

l_r NSR Buses Operating SR Buses Data L+

~

~

r

/' I"\\

I"[\\...

~

EE-0045 EE-0035 ~

10/15/~2 5/3/89 EDG EDGq Volt/Freq Loading

Response

S & W 13930.09-4 2/5/82 Bounding Bus-To-Load Voltage Drops S & W 14257.29-E-1 11/16/83 Bounding SR MCC CPT Secondary Voltage Drops System Fault Current Studies EE-0334 8/30/90 SR4160/480V EE-0372 4/15/92 NSR4160/480\\I

i-.

EE-0034

~

6/15/93 Voltage Profiles 500KV To 480V I

I EE-0502 I

I I

I 12/31/92 4160V DV /UV Relay Setpoints t

PT100B.17

  • KC885

. NorthAnna Surry Man-Man-Systems Tasb Start Finish Hours Tasks Start Finish Hours 120V AC Vital 3 10/93 11/93 400 5

11/94 3/95 1260 Bus System Review 125VDC 7

11/93 10/94 2600 11 3/95 7/96 3740 System Review AC System 17 11/93 7/96 7800 16 8/96 7/98 5700 Review

  • Each system review contains a detailed circuit/length review which is not presently sc PT100B.18

EDSFI VIRGl/f/lA POWER PT100.1

J.A. Price Assistant Station Manager -

Nuclear. Safety and Licensing Surry Power Station PT100.2

Planning And Preparation PT100.3

Purpose

~ Prioritize and Track EDSFI Preparation Development of Level II January, 1992 Specific Suny Actions Established Database for Tracking Action Items Weekly Management Updates

  • Established Surry Task Team January, 1992 Bi-Weekly Meetings Review of Industry Electrical Issues Resolution of Station Actions
  • Development of Database February, 1992 791 Items Currently Entered Tracks Actions From North Anna, EDSFA and Reassessment Identification of Departmental Contacts April, 1992 Trained on EDSFI Attributes PT100.4

S'OOU.d

Surry Database Includes North Anna EDSFI/EDSFA Questions.

Responses Were Prepared and Action Plan in Place to Address All Items

  • . Suny/Cotporate Electrical Engineering Participation in EDS Clearinghouse Working Group Focusing on Action Items From Other Plants EDSFI Results From Similar Plants Have Been Evaluated for Applicability to Surry and Action Items Assigned When Appropriate
  • PT100.8
  • 287 EDSFA Items 241 Complete

[ 84%]

  • 319 North Anna Questions 307 Complete

[ 96%]

  • 185 Self Identified Actions 156 Complete

[ 84%]

  • 791 Total 704 Complete

[ 890/o]

Identified Issues

- Calculations 191 Completed

- Procedural 105 Completed

- Programmatic 87 Completed

- Setpoints 77 Completed

- System Design 167 Completed

- Documentation 77 Completed Totals 704 Completed PT100.7

EDG Load Sequencing Load Blocks Designed to Ensure That Performance Capabilities Are Not Exceeded EDG Cool Down Cycle 900 RPM Modification

  • . Sequencing and Load Testing of EDGs Extensive Testing Performed to Ensure Performance
  • Switchyard Improvements 34_.5 KV Buses 5 and 6 Reliability Enhanced Material Condition
  • Vita1Bus PT100.B

Operating Experience Program Reviews Electrical System Issues From Other Utilities Operating System Windows Daily Nuclear Safety Annunciator Wmdows Program "At Power Wmdows Outage System Wmdows Outage Safety Planning Computerized Safety System* Operability Review of Outage Schedule Allows Effective Scheduling of Electrical System Maintenance PT100.II

2 3

Surry Unit 1 Operating Critical Parameters Fuel Cladding RCS Integrity Containment Integrity.

4 5

6 7

Safety Systems ESF Systems Heat Sink Ele~trical Power Suppli~

ESF Instruments

& Controls Reactivity 8

9 10 Monitoring and Assessment Fission Product

  • Barrier Monitoring Radiological Assessment Accident Assessment Capability 14 i5 16 17 I

i Plant.

i Availability I

  • I i

Reactor I

Powe~

I Regulatory Significant Systems Secondary Systems Control Instrumentation Component/Equipment/System Out-Of-Service that causes the YELLOW, ORANGE or RED Condition above.

Equipment 2

1-RC-PCV-1455C 12 1-RM-RMS-159.

1-RM-RMS-160.

15 Fire Protection 4

1-VS-E-4C 1-VS-F-58A 5

2-FW-P-3A This Pressurizer PORV was identified to be leaking-by during the Unit start-up. The associated block valve is closed and deenergized.

Containment Particulate Rad Monitor became inoperable due to water intrusion.

Containment Gaseous Rad Monitor is inoperable due to flow problems on skid.

Fire watches are required in the Cable Vault, Cable Spreading Room, MER #2, ESGR, MER

  1. 3, and the Cable Tunnel as compensatory actions for JCO's 89-3-002, C-92-005, C-92-001, C-92-002, and DR S-92-0921.

The 'C' MCR is considered inoperable due to tagout of the #2 EOG. Unit 1 cannot invole Tech Spec 3.0.2 since no EOG LCO is in effect for Unit 1. 7-Day LCO expires 3/18/93.

The 'C' MCR is considered inoperable due to tagout of the #2 EOG. Unit 1 cannot invole Tech Spec 3.0.2 since no EDG LCO is in effect for Unit 1. 7-Day LCO expires 3/18/93.

2-FW-P-3A is considered unavailable to support AFW X-tie due to #2 EOG T/0 14-Day LCO in effect and expires 3/25/93.

Fully Operable Condition Green Date: 3-11-93 Time: 0600 Acceptable but degraded/LCO of> 6 hrs to HSD may be in effect. Condition Yellow

  • Degraded Condition/HSD may be required within 6 hrs Condition Orange - Contingency actions may be required Unacceptable condition/Unanalyzed Condition Condition Red PTIU11

EQUIP FOR PRI Y/BACKUP COOLING METHODS AVAILABLE (AS PER 2-0SP-ZZ-tXl4) 8 NO Date 03/11/93 Time:

0600 Surry Unit 2 CSD & R Critical Parameters RF.ACTIVITY CORE CON'l;\\INI\\JF.NT INVENTOR\\'

RCS SUPPORT COOi.iNG INTEGRITY SYSTEMS REFUELING

~REMENTS MET

~

YES NO RCS JNlJ\\CT N/A 8 NO CTMT REFUELING INTEGRITY ESTABLISHED E] YES NO CONTAINMENT CLOSURE TEAM ESTABLISHED a YES NO PRESSURIZED CTMT ISOLATION ESTABLISHED

. El YES NO D

EMERG HHSI

  • PUMPS REACT OPMS MCR LHSI POWER MGMT CHILLERS PUMPS SUPPUF..S Fully Operable Acceptable Condition Green PRIMARY BACKUP COOLING METHOD AS PER 2-0SP-ZZ-004 Component(s) Degraded or 1 Power Supply Unavailable Acceptable but degraded Condition Yellow Component Inoperable Function or System Inoperable Condition Orange - Contingency actions may be required Function or System Requirement Unacceptable Unacceptable condition Condition Red AUX*

VENT P'Tlllll

  • Scope Technical Procedures Used at Station, Including:

Electrical System Suiveillance Procedures Electrical System Maintenance Procedures Electrical System Operating Procedures Process Includes Multiple Reviews:

Engineering/Technical Reviews to Ensure/Maintain Design Basis Validation by Procedure User Human Factors

  • Schedule To be Completed by 1996 PT100.10

Llne-by-Llne Review of Technical Specification Surveillance Requirements Ensures That All Technical Specification Sutveillance Requirements Are.Met by Our Testing Procedures

  • . Tracked by Station Level.I Scheduled Completion October 1993 PT100.11

-- ---------~

110 Work Requests Initiated From Self Assessment Activities Self Assessment Walkdowns Identified and Corrected General Housekeeping Items and Material Condition Issues Preventative Maintenance Program Reliability Centered Maintenance Post Maintenance Testing Program PT1D0.12

Agastat Surveillance Methods and Trending Timing IntetVal Acceptance Criteria - Contact Functioning Trended by System Engineer Developed Database EOG Surveillance Testing Methods and Performance Extensive Number of Parameters Monitored During Periodic Tests 100 Successful Starts Since Last Failure Relays*

Monthly Thennography Inspection to Identify Hot Spots Failure Rate Trended by System Engineer Battery Programs Routine System Walkdowns Controlled by SSES-3.01 "Controlling Procedure for System Engineer

Walkdowns Include Material Condition, Work Orders Tracked and Submitted, and System Perfonnance PT100.13

Fuse Schedule Development Safety Related and Non-Safety Related Fuses for Which Information is Readily Available Instrument and Power Fuse Schedules Were Issued in 1992

  • Labeling New Labels Have Been Hung as Well as Removal of Improper labels Component labeling Project Completed in June 1993 4160 and 480V Breakers and 480V MCCs Have Been labeled Level I Tracking labeling of Lighting Panels Comprehensive Program Developed to Address Future Routine Labeling Requirements PT100.14

SURRY PO TATION -

NEE POWER EDSFA SCOPE AND STATUS REPORT 1992SCOPE Original Actual MHR Remaining Number Description Start Finish Actual Est MHR To-Date MHR

% CMPL NAME A101 DC Fault Current Cale. Revision 9/1/92 11/30/92 11/30/92 100.00 100.00 0.00 100.00 NARCISSE 120VAC Vital Bus Fault Current 9/1/92 12/15/92 12/15/92 150.00 150.00 0.00 100.00 KING 159 4KV Ground Detection Study 10/1/92 12/15/92 12/15/92 30.00 30.00 0.00 100.00 KING A106 Degraded Voltage Setpoint Cale.

10/1/92 12/31 /92 1/15/93 250.00 250.00 0.00 100.00 RUDDY A 113.1 Lightning Protection Recommendation 9/1/92 12/31/92 12/31/92 40.00 40.00 0.00 100.00 GRIFFIN A154 EDG Loading Cale Revision 10/1/92 12/31/92 12/31/92 160.00 160.00 0.00 100.00 RUDDY 112 Index of SPS Calculations 6/1 /92 12/31/92 12/31/92 4.00 4.00 0.00 100.00 STACY 14.2 Lightning Protection Review 7/15/92 12/31/92 12/31/92 80.00 80.00 0.00 100.00 GRIFFIN I 1992 SubTotals 814.00 814.00 o.ool 100.00 9 1993 SCOPE Original Actual MHR Remaining Number Description Start Finish Actual Est MHR To-Date MHR

% CMPL NAME 1184 Appendix R Power Source 11 /1 /92 2/1/93 2/1/93 4.00 4.00 0.00 100.00 STALLINGS 1185 Appendix R Isolation Breaker 11/1/92 2/1/93 2/1/93 4.00 4.00 0.00 100.00 STALLINGS 1154 Accident Loading on Inverters 2/1/93 2/15/93 3/9/93 20.00 20.00 0.00 100.00 CARTER 1107 Inverter Input Voltage Options 2/1/93 2/15/93 2/12/93 10.00 10.00 0.00 100.00 GRIFFIN 138 System Stability - memo to Mistr 2/1/93 2/15/93 2/5/93 4.00 4.00 0.00 100.00 PHILLIPS A11.4 DBD Revision -

EE signoff 2/1/93 2/15/93 2/5/93 4.00 4.00 0.00 100.00 PHILLIPS A160.1 Switchyard Battery -

review calc 2/1/93 2/15/93 2/15/93 8.00 8.00 0.00 100.00 STALLINGS A46 Blind Fast Transfer Recommendations 2/1 /93 2/15/93 2/15/93 40.00 40.00 0.00 100.00 ZAFAR A76.4 Vital & EDG Battery Cross-Ties 11/1/92 2/17/93 3/19/93 10.00 10.00 0.00 100.00 RUDDY 1118 EDG Questions 2/1/93 2/19/93 3/11 /93 10.00 10.00 0.00 100.00 RUDDY A105 Overall Cale Upgrade Program schedule 2/1/93 3/1/93 5/7/93 60.00 60.00 0.00 100.00 STALLINGS 140 UFSAR Changes -

schedule due 2/1/93 3/1/93 3/22/93 10.00 10.00 0.00 100.00 STALLINGS A157.2 Aged Battery Condition 3/1/93 3/15/93 3/22/93 4.00 4.00 0.00 100.00 CARTER 1179 HVAC HP Values 2/15/93 3/15/93 3/12/93 5.00 5.00 0.00 100.00 GRIFFIN 1101.1 Degraded Voltage Logic Review 3/1/93 3/15/93 3/4/93 8.00 8.00 0.00 100.00 PHILLIPS 1316 OUTLINE -

EDG Load Sequencing 3/1/93 3/15/93 3/15/93 10.00 10.00 0.00 100.00 RUDDY A93.2 Clarify Calculation Equation 3/1/93 3/15/93 3/4/93 4.00 4.00 0.00 100.00 STACY 1251 Vital Bus Non-Safety Loads Review 3/1/93 3/15/93 3/9/93 8.00 8.00 0.00 100.00 WHITAKER A167 CPT overvoltage issue 3/1/93 4/1/93 3/16/93 4.00 4.00 0.00 100.00 STACY A47 Drawing 11448-FE-1A2-REV.4 5/5/93 5/7/93 5/7/93 1.00 1.00 0.00 100.00 STALLINGS A204 Offsite Power Source Definition 5/7/93 5/28/93 5/14/93 4.00 4.00 0.00 100.00 PHILLIPS 1154.1 EDG load duty cycle justification explanation 3/11/93 6/1/93 5/18/93 1.00 1.00 0.00 100.00 RUDDY 1243 EDG Closing Coil Voltage Drop 2/1 /93 6/1/93 6/25/93 20.00 20.00 0.00 100.00 CARTER A105.1 MCC Control Ckt. Voltage Drop 5/8/93 6/1/93 5/17/93 4.00 4.00 0.00 100.00 PHILLIPS 1316.1 PRESENTATION -

EDG Load Sequencing 4/1/93 6/1/93 6/30/93 10.00 10.00 0.00 100.00 RUDDY A 178/202.1 /1231 EDG LOCA post-LOOP Analysis 1/15/93 6/15/93 6/25/93 40.00 40.00 0.00 100.00 GRIFFIN 112 Cale Index 2/1/93 6/21/93 6/18/93 8.00 8.00 0.00 100.00 WHITAKER 27-Jul-93

SURRY PO TATION -

NEE POWER EDSFA SCOPE AND STATUS REPORT 1993 SCOPE £cont'dl Original Actual MHR Remaining Description Start Finish Actual Est MHR To-Date MHR

%CMPL NAME A107 Revise Cale EE-0034 Voltage Profile 10/1 /92 6/15/93 6/15/93 200.00 200.00 0.00 100.00 PHILLIPS 1233/1228 EDG Loading Cale - Appendix R Loads 4/1/93 6/30/93 6/30/93 100.00 100.00 0.00 100.00 GRIFFIN 140 HVAC description (pg 8.5-3) 4/1/93 6/30/93 6/24/93 20.00 20.00 0.00 100.00 NARCISSE A218 SR Protective Relaying Cales 9/1/92 6/30/93 2/1/93 300.00 300.00 0.00 100.00 PHILLIPS 140 Load ctr tx load update 4/1/93 6/30/93 6/17/93 20.00 20.00 0.00 100.00 PHILLIPS 140 GDC-17 analysis reference (pg 8.5-10) 4/1/93 6/30/93 6/17/93 20.00 20.00 0.00 100.00 PHILLIPS 140 normal supply clarification (pg 8.5-7a) 4/1/93 6/30/93 6/25/93 20.00 20.00 0.00 100.00 ZAFAR 140 Dbl ended sections (pg 8.4-2a) 4/1/93 6/30/93 6/25/93 20.00 20.00 0.00 100.00 ZAFAR 140 LHSI 75% start capability (pg 8.5-8) 4/1 /93 6/30/93 6/15/93 8.00 8.00 0.00 100.00 ZAFAR 140 L TC #steps/volt band/time bypass(pg 8.5-1) 4/1/93 6/30/93 6/25/93 20.00 20.00 0.00 100.00 ZAFAR 157 EDG Protective Relaying 1/15/93 7/1/93 6/25/93 40.00 40.00 0.00 100.00 RUDDY 135.1 EDG Largest load restart analysis (see A154) 5/7/93 7/1/93 6/24/93 1.00 1.00 0.00 100.00 RUDDY A11.1 DBD Open Items -

review for justifications 2/1 /93 7/1/93 6/30/93 60.00 60.00 0.00 100.00 STALLINGS A101 Update DC Fault Current Cale 4/1/93 8/1/93 60.00 56.00 4.00 93.33 NARCISSE A76.8 DC Fault Current (4 BCs) 4/1/93 8/1/93 30.00 24.00 6.00 80.00 NARCISSE 1329/1170/A 106 UV/DV Tech Spec vs UFSAR (see 1299) 11/1/92 8/15/93 40.00 32.00 8.00 80.00 RUDDY A144/1102 4KV Fault Current (Time Constants) 10/15/92 8/30/93 120.00 64.00 56.00 53.33 ZAFAR A128 Revise Cale. EE-0046 (DC Loading) 4/1/93 9/1/93 160.00 20.00 140.00 12.50 CARTER 140 residual volt time delay (pp 8.5-6/7/8) seel329 9/1/93 20.00 16.00 4.00 80.00 RUDDY 140 DV setpt update (Table 8.5-1) seel139 9/1/93 20.00 16.00 4.00 80.00 RUDDY 140 EDG start/loading times (pp 8.4-6, 8.5-5/6) seel329 9/1/93 60.00 48.00 12.00 80.00 RUDDY 140 250MVA bkr sht ckt (pg 8.3-1) see A144 7/1 /93 9/15/93 20.00 20.00 0.00 CARTER 1302 Verify DC loading in Cales 3/1/93 9/15/93 60.00 10.00 50.00 16.67 CARTER A154 EDG -

Loading Analysis (remaining items) 4/1/93 9/15/93 40.00 10.00 30.00 25.00 RUDDY 155 Containment Penetrations -

coordination 6/17/93 9/30/93 40.00 4.00 36.00 10.00 WHITAKER A176 Addend EE-0334, sh19, 30ka rating 7/1/93 10/1/93 20.00 20.00 0.00 ZAFAR I 1993 SubTotals 1834.00 1444.00 390.001 78.74, 1994 SCOPE Original Actual MHR Remaining Number Description Start Finish Actual Est MHR To-Date MHR

% CMPL NAME A188 EDG Parallel to Grid -

Protection 4/1/93 2/1/94 100.00 100.00 0.00 RUDDY A93.1 Clarify Cale EE-0044 11/1/93 12/1 /93 200.00 200.00 0.00 STACY I 1994 SubTotais 300.00 0.00 300.00 I 0.001 I Totals 2948.00 2258.00 690.001 76.591 27-Jul-93

Correlation Matrix -EDSFI Temporary Instruction / Surry EDSF A Plan

!TI No.

I Description I EDSFA Plan No.

05.02.a Evaluate as-built configuration via inspection of modifications 05.02.a.1 Implementation of regulatory requirements, 1.A.18 (UFSAR), 6.w, x licensing commitments l.A.17, 18 05.02.a.2 Adequacy of size and rating of electrical 1.A.2 (gen'l) equipment: motors, breakers, fuses, contactors, MCCs, load break switches cables l.A.15 (specific) buses, transformers, penetrations, EDG, 1.A.2 (gen'l) batteries, inverters, chargers, capacitors, reactors and TOLs 05.02.a.3 Adequacy ofload study, 1.A.8 voltage profiles, 1.A.8 voltage drop calculations, 1.A.8 motor starting study, load shed, 1.B.3 ESF bus load sequencing, 1.A.5, l.B.2 overload trip settings to include DV conditions 1.A.3 (relay setpoints) 05.02.a.4 Short circuit calculations, 1.A.7 design of protective relay logic and setting l.A.3, 5 calculations, grounding calculations, coordination studies 1.A.3, 12 05.02.a.5 Redundancy, single failure criterion, 1.A.11 potential for "sneak circuits" 05.02.a.6 Separation criteria 1.A.9 isolation ofnon-lE loads 05.02.a.7 Proper system control logic and translation l.A.5 (logics-gen'l) into elementary diagrams 05.02.a.8 Correct setpoints for over current relays for:

1.A.3 (relay stpts-gen'l) coordination, 1.A.3 thermal limits on motors, penetrations, cable 1.A.3 (relay stpts-gen'l) insulation, starts under DV, pre-trip alarms 05.02.a.9 Setpoints and time delays for UV, UF, reverse 1.A.3 (relay stpts-gen'l) power ground faults 1.B. 7 (EDG-only) differential current, TOL and phase synch.

1.A.3 (relay setpoints) 05.02.a.10 Mechanical loads correspond to actual normal 1.A.8 (load studies, and accident conditions and are reflected as lists) the correct electrical load and are on the load list 05.02.a.11 Support systems can support design basis 1.A.14 (HVAC), l.C conditions: EDG air-start, cooling water, fuel (EDG support) oil & transfer, HVAC July 22, 1993 1

Correlation Matrix -EDSFI Temporary Instruction / Surry EDSFA Plan

!TI No.

I Description I EDSFA Plan No.

05.02.a.12 Switchyard design, 1.A.13 independent power sources, 1.A.13 bus transfers 1.A.10 independence of onsite and offsite distribution 1.A.13 systems 05.02.a.13 Accuracy ofload list 1.A.8, 2.i 05.02.a.14 Adequacy of root cause analysis, 2.z, aa, 4.m corrective actions, 2.z, aa, 4.s, x, 5.1 50.59s, 2.c, t temp mods 2.t-y, 4.k 05.02.a.15 Engineering input to Post Mod Testing and 2.h (gen'l) acceptance criteria for same 05.02.a.16 Design basis & operating limits addressed in 5.a (EOP-gen'l), 5.m OPsandEOPs (setpoints) 05.02.a.17 Procurement specs, environmental conditions, 6.x (overall UFSAR etc. in compliance with FSAR and other compliance)

I design commitments 05.02.a.18 Indication and of bypass and inoperable status, 5.e requirements for annunciation and operator 1.C.5 (EDG support),

response to same 5.u 05.02.a.19 Support system functional requirements 1.C.4 translated to logic and elementary diagrams 05.02.a.20 Proper commercial dedication of NSR and 2.g (component qual),

equivalent components 4.n (replacement cntrl) 05.02.a.21 Engineering calculation performance and 1.A.1 control program 05.02.a.22 Load growth monitoring and control program 1.A.6 05.02.a.23 Setpoint calculation and control proeram 1.A.4 05.02.a.24 Self assessment program, 4.s, 5.k, 6.v, 7.n (NSR) including QA audits 05.02.a.25 Design mod, 2.a-s (mod cntrl-gen'l)

T mod control program 2.t-y (T mods-gen'l) 05.02.b Examination of implementation of load 2,3 paths selected in 05.02.a 05.02.b.1 Field verification of installed EDS equipment 3.a-z (walkdown) corresponds to design, drawings, Q-list, (Report-p19) setpoint list, 2.f ( updating)

drawings, 3.m separation criteria, 3.n II over I, 3.d (seismic), (Rpt-p16)
seismic, 3.d HELB,MELB, floodini?

05.02.b.2 Material condition of electrical equipment 3.a, 4.z July 22, 1993 2

Correlation Matrix - EDSFI Temporary Instrnction / Surry EDSF A Plan

!TI No.

I Description I EDSFA Plan No.

05.02.b.3 Surveillance and testing of: protective relay 3.v (walkdown), 6.a

settings, (test procedures) timer settings, 4.o (setpoints) breaker settings, 6.a (test procedures)

EDG load sequencing and staring logic, 6.a (test procedures) lE battery capacity, for: consistency with 6.a (test procedures) setpoint calculations, correct intervals 05.02.b.4 Review WOs and T mods for: inadvertent 2.z (DRs), 3.r design changes, root cause analyses for failures and recurring 2.z, aa, 4.1

problems, 50.59s for T mods 2.t 05.02.b.5 Adequacy of PMT 4.d 05.02.b.6 Engineering involvement 2.o 05.02.b.7 Self assessment programs, including QA 4.s, 5.k, 6.v, 7.n (NSR) audits 05.02.b.8 Control of vendor information, 6.o consistency of maintenance of electrical and 3.u (equip condition),

mechanical components 3.w (outstanding WRs) 05.02.b.9 Design assumptions regarding operator action 5.i. (TS actions), 5.m incorporated into procedures (EOP, OP setpoints) 05.02.b.10 Maintenance program maintains operability, 4.a-z (maint-gen'l)

EQ of equipment 4.t 05.02.b.11 T mods to SR systems are tracked, controlled 2.u, w, x, y and eiven timely technical evaluation 05.02.b.12 Control room drawings reflect actual "as built" 3.m (as-built)

NOTE:

Although some areas were not specifically mentioned in the Assessment Plan (as indicated by a " - " mark), many of these topics were either reviewed during the assessment or covered under other EDFSI program efforts (Ex. NAPS EDFSI questions).

July 22, 1993 3

Numbered Surry EDSFA Assessment Plan for NRC Temporary Instruction Matrix SCOPE: Design, modification, testing, maintenance, operation and reliability of all electrical distribution system equipment providing power relied upon to remain functional during and following design basis accidents:

  • 500 kV/230 kV and 230 k.V/34.5 kV OFFSITE POWER
  • 34.5 kV/4.16 kV TRANSFER SWITCHGEAR and TRANSFORMERS
  • 4160V/480V TRANSFER SWITCHGEAR and TRANSFORMERS
  • 480V/120V AC EQUIPMENT
  • 120V AC and 125V DC DISTRIBUTION
1. One week of preparation and team training (May 11 - 15). Contractors should plan on 2 days during this week, May 14 (training at Innsbrook) &

May 15 (badging at Surry). (Ref. TI Sec. 06-Conduct of Inspection, Week

1)
2. Three weeks at Surry and Innsbrook Engineering (May 18 - June 5). (Ref.

TI Sec. 06-Conduct of Inspection, Weeks 2-4)

TEAM: S. Eisenhart (Supervisor NSR)-

M. Surface (NSR-Team Leader) (Ref. TI Sec. 06-Conduct of Inspection, Team member a)

M. Earle (NSR-Assistant Team Leader) (Ref. TI Sec. 06-Conduct of

  • Inspection, Team member c)

F. Terminella (NSR)

F. Cicchetto (NSR)

D. Wootten (NSR)

D. Wagner (NSR))

S. Koblyarz (Lead Electrical Design Engineer-Ogden) (Ref. TI Sec. 06-Conduct of Inspection, Team member b)

S. Pettersen (Electrical Design Engineer-Ogden) (Ref. TI Sec. 06-Conduct of Inspection, Team member b & d)

J. Ullo (Electrical Design Engineer-Ogden) (Ref. TI Sec. 06-Conduct of Inspection, Team member b & d)

REFERENCES:

  • NRC EDSFI Inspection Guidelines
  • NRC SSFI Inspection Module 2515 - 93801
  • NSAC/121 Guidelines For Performing SSFI's
  • NRC Summary of EDSFI Results
  • NRC EDSFI Reports (Including NAPS Report and Va. Power Responses)
  • Lessons Learned from NAPS EDSFA
  • IOER Search July 22, 1993 4

Numbered Surry EDSFA Assessment Plan for NRC Temporary Instruction Matrix ASSESSMENT OUTLINE

1.

DESIGN A.

Electrical: (Contractor Electrical Engineering Sub-Team) Review design packages for selected distribution system load paths to ESF loads from all available power sources and at all voltage levels. Determine adequacy of:

1.

calculations and assumptions

2.

size and ratings of electrical equipment

3.

relay setpoints and coordination

4.

setpoint control

5.

system logics including load sequencing and interlocks

6.

load growth control and monitoring

7.

short circuit calculations

8.

load studies and lists, voltage profiles, voltage drop calculations

9.

separation of class lE loads

10.

fast transfer schemes

11.

single failure criterion

12.

breaker coordination

13.

switchyard design and independence between onsite and offsite distribution systems

14.

HV AC design and capacity (battery, switchgear rooms, etc.)

15.

cable tray loading and capacity ratings

16.

seismic and EQ qualification

17.

NRC Commitment implementation

18.

UFSAR accuracy B.

Diesel Generators -Electrical (Contractor Electrical Engineering Sub-Team)

1.

EDG loading calculations

2.

sequencing and protection relay setpoints

3.

start/load logics

4.

voltage regulation

5.

protection logics

6.

electrical equipment temperature ratings

7.

ground fault protection C.

Diesel Generators-Mechanical (Mechanical Team) EDG support systems design including fuel oil transfer, air start, cooling, and HV AC:

1.

capacity

2.

single failure criteria

3.

seismic qualification

4.

logic/sequencing

5.

alarms/protection

6.

relay setpoints and coordination

7.

design calculations and assumptions

8.

UFSAR accuracy July 22, 1993 5

Numbered Surry EDSFA Assessment Plan for NRC Temporary Instruction Matrix

2.

MODIFICATION/CONFIGURATION CONTROLS: (Contractor Electrical Engineering Sub-Team & Mechanical Team)

Select several significant modification (DCP/EWR) packages associated with the electrical distribution systems (Vertical Assessment) and the emergency diesel generators and evaluate:

a.

impact on plant and accident analysis

b.

cumulative impact of load growth

c.

safety evaluation (10CFR50.59)

d.

calculations and assumptions

e.

consideration of system interactions and functionality

f.

updating of relay and alarm setpoints

g.

qualification of installed components

h.

post-modification testing

1.

updating and control ofload list J.

seismic and EQ evaluations

k.

updating of instrument list I.

updating related procedures

m.

updating drawings

n.

installation (conforms to requirements)

o.

engineering involvement

p.

fuse control

q.

adequacy of modification package (review field changes)

r.

updating UFSAR

s.

control of design bases documents Evaluate Control Over Temporary Modifications to Electrical Distribution System, EDGs, and support systems (Mechanical Team):

t.

safety analysis

u.

independent review and approval

v.

independent verification (installation /removal)

w.

control of numbers

x.

monitoring status

y.

control of duration and extensions

z.

disposition of Station Deviation reports aa. disposition of Potential Problem Reports

3.

WALKDOWNS (Operations Team & Contractor Electrical Engineering Sub-Team-as needed): Conduct detailed walkdowns of electrical systems and equipment and of the ED Gs and support systems. Determine the adequacy of:

a.

material condition

b.

instrument maintenance and calibration

c.

MOV maintenance

d.

seismic qualification/maintenance

e.

electrical PM's including contacts July 22, 1993 6

Numbered Surry EDSFA Assessment Plan for NRC Temporary Instruction Matrix

f.

equipment cleanliness/housekeeping

g.

labeling/color coding

h.

control of operator aids related to EDS

1.

local procedure maintenance J.

EQ maintenance

k.

battery condition

1.

HV AC/room temperatures

m.

drawings vs. as-built plant

n.

cable separation/loading

o.

emergency lighting

p.

maintenance oflocal control panels, alarms, indicating lights

q.

name plate ratings versus design

r.

temporary modification control

s.

concurrence with UFSAR and Design Basis

t.

fuse control

u.

condition of relays, contacts, conduit, electrical connections

v.

relay settings

w.

outstanding deficiency tags/work requests

x.

valve/electrical alignments

y.

accessibility

z.

work scope controls

4.

MAINTENANCE (Mechanical Team): Through observation of maintenance activities, review of completed and open work orders, review of selected Deviation Reports/LERs, and interviews, determine adequacy of:

a.
b.

C.

d.
e.
f.
g.
h.
1.

J.

k.
1.
m.
n.
o.
p.
q.
r.
s.
t.
u.

v.

w.

July 22, 1993 maintenance planning and scheduling preventative maintenance (including electrical controls and relays) switchyard maintenance and controls post-maintenance testing MOV maintenance check-valve maintenance fuse control procedures foreign material exclusion controls procedural use and adherence temporary modification controls failure root-cause analysis/documentation component failure tracking/trending replacement control setpoint controls calibration program control of work assignments/qualifications contractor/vendor controls verify response to previous NSR corrective action recommendations restoration ofEQ/seismic status post-maintenance housekeeping lubrication control limit and torque switch control 7

Numbered Surry EDSFA Assessment Plan for NRC Temporary Instruction Matrix

x.

corrective actions to event and IOER

y.

predictive analysis

z.

material conditions electrical equipment EDG HVAC fuel oil air start cooling systems

5.

OPERATION (Operations Team): Through review of selected operational events, interviews, and walkdowns of electrical and EDG systems and procedure with operators, determine adequacy of:

a.
b.

C.

d.
e.
f.
g.
h.
i.

J.

k.
1.

.m.

n.
o.
p.
q.
r.
s.
t.
u.
v.

July 22, 1993 EOPs and training emergency lighting accessibility labeling alarms/indications temporary modification control operator aid control tagging controls Technical Specification compliance/actions response to IOER verify response to previous NSR corrective action recommendations corrective actions to events/IERs/Deviation Reports EOP and operating procedure setpoint controls procedure revision controls interface with Control Operations and System Operations interface with Maintenance system alignment controls fuse control replacement indicating light controls operator rounds of electrical/EDG systems and equipment alarm response procedures and setpoints operator familiarity and training EDG trips and restoration electrical interlocks and transfer schemes EDG loading restrictions loss of all AC loss of DC.

backfeed 8

Numbered Surry EDSFA Assessment Plan for NRC Temporary Instruction Matrix

6.

TESTING I REGULATORY COMPLIANCE (TS/Surveillance Team): Review Surveillance Testing associated with the electrical systems and EDGs and support systems and determine adequacy of:

a. test procedures
b. scheduling
c.

interdepartmental coordination

d. acceptance criteria (vs. TS., etc.)
e. scope of coverage (i.e., TS. and all required components)
f.

heat exchanger testing

g. procedure update following modifications
h. management controls over changes to acceptance criteria
1.

impact on operability and TS. LCO entry J.

valve testing in required direction of operation

k. identification and review of non-acceptable results
1.

control of M & TE

m. control over pre-conditions or special adjustments to pass PT
n. missed/late surveillances
o.

meeting vendor recommendations for frequency & acceptance criteria

p. testing compliance with accident analysis
q. control operators testing
r. EDG fuel oil testing
s.

verification of TS covered by PTs

t.

lessons learned from the NAPS EDSFA

u. electrical/EDG LERs
v. verify response to previous NSR corrective action recommendations
w. NRC NOVS, IRs and Va Power responses to electrical issues

. x. Overall UFSAR compliance

7.

TRAINING (Operations Team): Through review of training records, event root causes, response to IOER action plans, observation of maintenance activities, operator walkdowns and interviews, and review of selected modifications, determined the adequacy of operator, maintenance, and system engineer training on:

a.

system modifications

b.

EOPs

c.

alarm response procedures

d.

IOER *

e.

response to loss AC/DC

f.

loss AC due to fire (Appendix_ R)

g.

specific job tasks (JPMs)

h.

surveillance testing

i.

special tests

j.

local valve and breaker operations during loss of AC or DC

k.

10CFR50.59 training

1.

MOV training

m.

plant systems

n.

verify response to previous NSR corrective action recommendations July 22, 1993 9

CORRESPONDENCE BETWEEN NAPS EDSFA AND EDSFI ISSUES

~

EDSFI VIOLATIONS AND FINDINGS CONCLUSIONS ViQlatiQn A (Findin~ 91-17-19}; General programmatic weaknesses in implementing TS Procedures for Surveillance testing by T&D personnel cited by this violation were

...J.a.

L..!

anu a,esw.ng u*aaequate noted by the EDSFA. The specific example of the wrong setpoint was known to Electrical Engineering but was accepted.

ViQlatiQn B (Findin~ 91-1'.Z-2Q}; These procedures were not selected by the EDSF A team DRs not written when load and were thus not discovered.

sequence timers found out of tolerance.

ViQlatiQn C (Findin~ 91-1'.Z-21}; The specific failure to identify generic implications of Corrective action not taken EDG timer drift is an outgrowth of the failures to submit when EDG load sequence deviation reports found during the EDSFI discussed timers found out of tolerance under violation B. Programmatic issues concerning identification of trends and collective problems were identified during the EDSFA.

Findin~ 91-1'.Z-Ql; Degraded Finding covered programmatically. Issues involving grid voltage relay calculations calculation, accuracy, control and documentation of did not include errors in setpoints were addressed in an EDSFA recommendation.

setpoint A specific reference to the calculations that support setpoint document values for protective devices was made. It was acknowledged that these calculations were under development during the EDFSA, had not been reviewed, and needed to be verified. A general comment in a CNS sheet stated, "numerous changes, additions, and enhancements should be made to the protective relaying sections of the setpoint document."

Find.in~ 91-1'.Z-Q2; Lightning This technical issue was not identified by the EDSFA.

protection of RSST buses inadequate Findine: 91-1'.Z-Q3; Inadequate control of desirn calculations

1. Informal calculations on Not identified.

RSST output power cables

2. lack of documentation for Identified programmatically. The EDSF A found UFSAR, each 500/34.5 Xformer examples of incorrect information in the UFSAR sections can supply 3 RSSTs dealing with the EDS. The discrepancy in this example appears to be due to lack of updating from a design change, a pro2Tammatic problem noted by the EDSFA.

1 July 21, 1993

CORRESPONDENCE BETWEEN NAPS EDSFA AND EDSFI ISSUES

~

EDSFI VIOLATIONS AND FINDINGS CONCLUSIONS

3. no evaluation for voltage Identified programmatically. Weaknesses in the EDG profile ofEDG bus for faults in load study were noted in the EDSF A. The subject of NSR circuits non-safety related loads on the,11.tal inverter buses was raised, although the specific area of NSR loads on the 480V level was not.
4. known instrument errors for Identified programmatically. See response to Finding DV relay setpoints not used in 91-17-01.

calculations *

5. no system for tracking Not identified.

interrelated calculations

6. no basis for assumption in
  • The corrective action for the issue identified by the calculation EE-012 EDSFA would also address the NRC's concern. The issue of voltage drop through control cable as used in calculation EE-012 was specifically discussed in the EDSFA report. Although the cable mentioned was not the cable from the distribution box to the battery, the test information mentioned in the EDSFA report that would verify that concern would also verify the NRC's concern.
7. inadequacies in EWR Of the two issues not cited elsewhere, one was identified calculation:

programmatically and one was not identified.

Weaknesses in the EDG load study were noted in the EDSFA report. Lack ofEDG protection for motoring, negative sequence or underexcitation was not identified.

8. errors in X/R values for large Not identified.

motors

9. current voltage analysis for Identified programmatically in the EDSFA. Concerns EDG neglected transient with EDG transient voltage analysis were identified.

current under negative sequence in damage calculations

10. relay coordination curves Programmatic concerns with relay setpoint calculations extrapolated beyond given identified in the EDSFA. See Finding 91-17-01 for values in relay settings discussion. This specific technical issue was further explained in the Va Power EDSFI response letter and was accepted in the NRC follow-up inspection.
11. calculation for EDG day Identified programmatically. Discrepancies on EDG fuel tank level had error & did not oil system setpoints between a number of sources were include instrument drift, oil identified. In addition, the error found by the NRC was density due to a misunderstanding and was found to be correct during the follow-up inspection. Although instrument drift and oil density factors were not identified, they were found to be insignificant in a subsequent calculation.

2 July 21, 1993

CORRESPONDENCE BETWEEN NAPS EDSFA AND EDSFI ISSUES EDSFI VIOLATIONS AND FINDINGS

12. deficiencies in calculations
13. no voltage drop for cable between battery and switchboard in EE-0009
14. operation of vital bus inverters at 101V not justified
15. use of measured loads to represent accident loads in calculations
16. inadequacies in load study for inverter accident loading
17. lack of design documentation for EDG batteries and charger
18. impact of larger replacement battery on fault calculations not evaluated
19. HV AC calculations were inadequate: ability to serve SR equip indeterminate
20. deficiencies in voltage and short circuit calculations for system~SOV
21. no calculations ofEDG louvers loading due to tornado
22. comments on vital bus loading calculation EE-025 Findin~ ~1-1'.Z-Q4; UFSAR deficiencies 3

CONCLUSIONS Of the two unresolved issues not cited elsewhere, one was identified programmatically and one was not identified. The issue of miscoordir...ation at 480V breaker with upstream devices an example of programmatic concerns with relay setpoint calculations, discussed in Finding 91-17-01. The issue ofno as-built data for motor starting and running power factors was not identified.

Two items were technical issues that were further explained in the Va Power EDSFI response letter and accepted in the NRC's follow-up inspection.

The corrective action for the issue identified by the EDSFA would also address the NRC's concern. See Finding 91-17-03, example 6.

This issue was specifically identified during the EDSF A.

See Finding 91-17-23, example 5.

This issue was specifically identified during the EDSF A on an Observation Sheet.

This issue was specifically identified during the EDSFA.

See response to Finding 91-17-23, example 3.

This issue was specifically identified during the EDSF A.

See response for Finding 91-17-23, example 4.

Not identified.

Identified programmatically and specifically by the EDSFA. The EDSFA report discussed the need for calculations to determine maximum and minimum EDG room temperatures. HV AC calculations for the Main Control Room and relay room were also addressed.

The two issues not discussed in other sections were not identified.

Not identified.

Identified programmatically. Weaknesses in the EDG load study were noted in the EDSFA report.

Identified programmatically and specifically by the EDSFA. Most of the specific examples of UFSAR discrepancies found by the EDSFI were also noted by the ED FSA. Programmatic causes of the problems were also covered by the EDFSA.

July 21, 1993

i CORRESPONDENCE BETWEEN NAPS EDSFA AND EDSFI ISSUES EDSFI VIOLATIONS AND FINDINGS Findin~ 91-1'.Z-Q6; Procedure deficiencies Findin~ ~1-17-Q6; Inadequate supervision, surveillance and analysis of auto fast transfer Findin2: ~1-17-Q'.Z; Inadequate 4160V SR bus short circuit currentrating:breaker interrupting rating less than calculated short circuit fault current Findin2: ~1-17-QB; EDG transient loading calculation concerns Findin2: ~1-17-Q~; EDG electrical protection 4

I CONCLUSIONS Two of the three examples in the finding were covered prograroroatically. Concerning acceptance criteria for RSST tap changers; it was found dur..ng the EDSFA that testing performed by Commercial Operations personnel was not in accordance with nuclear program requirements. On the margin being too close for acceptance criteria for 4KV relay settings, general issues involving calculation, accuracy, control and documentation of setpoints were addressed in an EDSFA recommendation and are discussed under Finding 91 01. One observation sheet noted that numerous changes, additions, and enhancements should be made to the protective relaying sections of the setpoint document." The methodology of relay testing not always requiring a check of 2 points on curve was not identified.

Not identified. The fast transfer on Unit 1 was removed due to the installation ofa generator breaker. At the time of the EDSF A, the installation of a similar breaker on Unit 2 was scheduled. The team may have chosen not to concentrate on the Unit 2 fast transfer because it was due to be removed as on Unit 1. The new breaker was not installed at the time of the EDSFI.

This was determined not to be an issue by the NRC during the follow-up inspection.

Two of the three issues were specifically identified by the EDSFA. The NRC mentioned that these two loading issues had been identified by the EDSFA in the NAPS follow-up report. The software verification issue was not identified durin~ the EDFSA.

This specific issue was not identified by the EDSFA, although EDG electrical protection was examined in the EDFSA. The EDSFA team apparently accepted the idea that the protection scheme was based on regulatory guidance at the time of the original design. This was accepted by the NRC in the follow-up inspection.

July 21, 1993

CORRESPONDENCE BETWEEN NAPS EDSFA AND EDSFI ISSUES EDSFI VIOLATIONS AND CONCLUSIONS

.FINDINGS Findin2: 91-1'.Z-lQ; Potential for This issue was specifically identified during the EDSF A.

EDG overload when parallel to the grid during testing since overcurrent relay is set at 230% of full bus voltage Find.in" 91-17-11; Inadequate Not identified.

RCP motor electrical penetration overload protection/surveillance Find.in" 91-17-12; Tap settings Not identified.

on U2 4KV-480V transformers were not in accordance with voltage profile calculation.

Findin" 91-17-13; Elimination Not identified.

of E!'I'ounds from DC systems Find.in" 91-17-15; Corrective action for the issue identified by the EDSFA

' Temperature rise of ambient would also address the NRC's concern. The EDSFA air entering EDG room before report discussed the need for calculations to determine reaching radiator may limit maximum and minimum EDG room temperatures. Such operating time at temperature calculations would also incorporate the anticipated extremes.

temperature rise across the room.

Find.in" 91-17-16; EDG high This issue was specifically identified in the EDSFA.

temperature alarm setpoints above vendor values for normal and short term operation:

Finding ~1-17-1'.Z; Biological One example was specifically identified by the EDSFA, growth in EDG fuel oil the other was not. The lack ofbiocide addition was noted in the report as also noted in example 2, but the problem with the discovery of biological growth as in example 1 was not identified.

Find.in" 91-17-18; Seismic The EDSFA identified 1 of 8 of the 2 over 1 seismic issues issues in the EDSFI.

Find.in~ ~1-17-22; Equipment Not identified.

not identified prior to exceeding service life-SW isolation valve breaker exceeded service life 5

July 21, 1993

CORRESPONDENCE BETWEEN NAPS EDSFA AND EDSFI ISSUES

.,. I EDSFI VIOLATIONS AND

.FINDINGS CONCLUSIONS Findin2: ~1-lZ-23; Improperly Four of the five issues were specifically identified in the sized equipment or less than EDSF A. Calculation EE-008 was specifically mentioned, required voltage as well as the fact that voltages may be less that the minimum required for certain loads and that the problem is "global." Calculation short circuit ratings over MCCB breaker ratings was specifically addressed.

MCC loading was not identified, but inverter loading was identified. Battery charger loads and sizing issues were specifically addressed. A potential problem with the capability of the inverters to function at reduced voltage was specifically identified during the EDSFA.

6 July 22, 1993

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