ML20203G146

Nuclear Operations, Crdr Summary Rept

ML20203G146
Person / Time
Site:	Vogtle
Issue date:	06/10/1986
From:	GEORGIA POWER CO.
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l VOGTLE ELECTRIC

! GENERATING PLANT UNIT ONE NUCLEAR OPERATIONS i

CONTROL ROOM DESIGN REVIEW

SUMMARY

REPORT l

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JUNE 10, 1986 l

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8607310362 860613 PDR ADOCK 05000424 E PDR

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CEORGIA POWER COMPANY 1 CONTROL ROOM DESIGN REVIEW

SUMMARY

REPORT TABLE OF CONTENTS PAGE

1.0 INTRODUCTION

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4 1.1 HISTORY -----------------------------------------5 1.1.1 GEORGIA POWER COMPANY COMMITMENT =-- =--

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5 1.1.2 PRELIMINARY CONTROL ROOM DESIGN REVIEW----- -----6 1.2 OBJECTIVES OF THE CONTROL ROOM DESIGN REVIEW-----7 2.0 SIGNIFICANT CHANGES TO THE VEGP PROGRAM PLAN FOR THE IMPLEMENTATION OF THE CONTROL ROOM DESIGN REVIEW--------------------------------------=-- =--

--10 2.1 THE CHARACTERISTICS USED TO REVIEW THE LICENSE EVENT REPORTS ------------------------------------10 2.2 REPETITION OF 1981/1982 PRELIMINARY CRDR SURVEY ITEMS----- -----------------------------==----- -12 2.3 ADDED NUREG 0700 AS A SOURCE FOR CONTROL ROOM SURVEY INSTRUMENTS--------------------------------13 2.4 HED CATEGORY REVIEW --------==----- ----- -- ---15 1

2.5 TASK ANALYSIS PRODUCTS------------------- ----

16 2.6 INSTRUMENTATION & CONTROL CHARACTERISTICS REVIEW--17 l 2.7 THE ADDITION OF A NEW ASSESSMENT CATEGORY 4A ---18 l 3.0 RESULTS OF CONTROL ROOM DESIGN REVIEW----------- - -20 l

l l 3.1 CONTROL ROOM DESIGN REVIEW HED

SUMMARY

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3.2 IMPLEMENTATION OF CONTROL ROOM IMPROVEMENTS --- -21

CEORGIA POWER COMPANY 11 3.3 VEGP CONTROL ROOM DESIGN CHARACTERISTICS CONSIDERED BENEFICIAL TO THE OPERATING CREW-------22 4.0 CRDR PROCESS DETAILS--------------------------==-- - -24 4.1

SUMMARY

OF THE CRDR PROCESS---------- ----

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24 4.2 DETAILS OF EACH PHASE----------- --- ----- -

---28 4.2.1 PLANNING PHASE--- --- --------------------28 4.2.2 EXECUTION PHASE--------------------- --- = 37 4.2.3 ASSESSMENT PHASE---------------------------44 4.2.4 DOCUMENTATION PHASE ---- - ----------------50 4.2.5 CORRECTION PHASE---------------------------55 4.2.6 EFFECTIVENESS PHASE--------------- ------- 56 4.2.7 COORDINATION WITH OTHER ACTIVITIES-- ----- 57 4.3 CRDR METHODOLOGY AND RESULTS ---- ----- =--------60 4.3.1 OPERATING EXPERIENCE REVIEW----------------61 4.3.2 OPERATING PERSONNEL SURVEY-----------------66 4.3.3 PROBLEMS REPORTS---------- --- === - ------70 4.3.4 SURVEYS & CHECKLISTS-- = =--- ------- -----73 4.3.5 TASK ANALYSIS---------------== =- ===- ==79 l

j 4.3.6 INSTRUMENTATION AND CONTROL l CHARACTERISTICS REVIEW------------ ====-- --91 4.3.7 VALIDATION OF CONTROL ROOM FUNCTIONS--- ---95 4.4 DETAILS OF THE HED RESOLUTION PROCESS------ ===---102 4.4.1 HED DEVELOPMENT PROCEDURE------ ------ ----102 4.4.2 METHODOLOGY OF DETERMINING SCHEDULING PRIORITIES--- -- =-- =-- =-- ==106 4.4.3 DEPARTURES FROM SCHEDULE PRIORITIZATION - =-----=--- ===---- =-- =109 4.4.4 HED CATEGORY REVIEW PROCESS =---- ===-------109 5.0 CRDR IMPLEMENTATION VERIFICATION PROGRAM- ------ -------115 l

l CEORGIA POWE2 COMPANY iii

6.0 APPENDICES

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120 6.1 OPERATING EXPERIENCE REVIEW

SUMMARY

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120 6.2 INSTRUMENTATION & CONTROL CHARACTERISTICS ----- --133 REVIEW 6.3 HED RESOLUTION AND IMPLEMENTATION STATUS-- -----150 CATEGORY 4A HED JUSTIFICATION----=---- -----------179 CANCELED HEDS-------------------------------------199 6.4 RESPONSE TO THE IN PROGRESS AUDIT (APPENDIX B)----203 6.5 HED CATEGORY REVIEW AND THE CRDR TEAM RESOLUTIONS------------- --------225 6.6 NRC AUDIT SURVEY-------------========-- ----------235 6.7 QUALIFICATIONS OF CRDR PERSONNEL-------=-- =-- ---245

CEORGIA POWER CCAPANY 4 CONTROL ROOM DESIGN REVIEW

SUMMARY

REPORT

1.0 INTRODUCTION

The Vogtle Electric Generating Plant (VEGP) in Burke County, Georgia is tne wstw vi s=v . . . . . . . ,

units, scheduled for commercial operation in 1987 and 1988. The plant contains two identical four loop Westinghouse pressurized water reactors (3411 Mwt) with General Electric turbine generators (1157 Mwe).

Unit 1 is the subject of this review.

This Control Room Design Review (CRDR) has been performed to review and upgrade the control room, emergency response facilities, and operating procedures. Although the CRDR was directed toward the existing control room, it also reviewed the design of a Safety Parameter Display System (SPDS), Post Accident Monitoring (PAM) instrumentation, and Emergency Operating Procedures.

Guidance for the CRDR has been provided by various NUREGs and Regulatory Guides. A Nuclear Utility Task Action Committee (NUTAC) with staff support from the

CEORGIA POWER COMPANY 5 Institute of Nuclear Power Operations (INPO) has developed a generic control room design review implementation plan from these guidelines. NRC guidance and NUTAC guidelines were used by Georgia Power Company (GPC) for the development of the CRDR process and the contents of this report.

This summary report describes the manner in which GPC conducted a review of the VEGP control room. GPC did not wait for NRC approval of the CRDR Implementation Plan (September, 1984) before commencing this review.

However, GPC did incorporate the NRC In-progress Audit comments in the plan.

1.1 HISTORY 1.1.1 Georata Power Company Commitment I

Georgia Power was committed to a well designed control room from the beginning of the project. A full scale control room mockup was constructed and used for planning instrument and control layout.

Operator input at that stage helped ensure a design l

without significant operational problems. Following j the Three Mile Island accident and subsequent NRC guidance on human factors in design, GPC commissioned a review by Dr. Zena Sabri (Iowa State University)

CEORGIA POWER COMPANY $

and Dr. Lynn Weaver (Georgia Institute of Technology) to identify human engineering design problems for correction.

GPC has invested an estimated four and one half man years in the CRDR project from 1984 thru April of this year. This includes Georgia Power supervisors and contractors.

1.1.2 Preliminarv Control Room Desian Review When further NRC guidance (NUREG 1580) was issued, a preliminary control room design review was conducted in 1981/1982. The purpose of this review was to identify control room human engineering deficiencies l at an early stage of the control room design in order that they could be corrected in the final design and/or incorporated into operator training and station administrative programs. Because the l

1981/1982 Preliminary CROR was not conducted in accordance with final guidance (NUREG 0700), it is not included in this report. The preliminary CRDR was more limited in scope and only assessed the t

following:

i i o Control room layout, l

CEORGIA POWE03 COMPANY 7 o The adequacy of the information provided to the control room operators, o The arrangement and identification of important controls and instrumentation displays.

The current review is intended to stand alone in documenting compliance with NRC requirements. Many design changes recommended in the 1981/1982 review were already incorporated, resulting in fewer design deficiencies when reviewed by NUREG 0700 guidance.

However, sixty-four items identified in 1981/1982 had not been incorporated into the design. To ensure problems were not overlooked, those items were incorporated in the current review as Human Engineering Discrepancies (HEDs #1001 to 1064) for review and resolution.

1.2 OBJECTIVES OF THE CRDR l

To ensure that the CRDR fulfilled its stated purpose, several objectives were identified and met during the review. The following specific objectives were defined for the CRDR:

CEORGIA POWER COMPANY 8 1.2.1 To perform a control room survey that compares the existing control room with accepted human i

engineering criteria.

1.2.2 To review relevant plant operational experience using appropriate documentation and operator questionnaires.

[ 1.2.3 To determine the information and control 1

requirements of control room operator tasks during emergency conditions.

1.2.4 To identify human engineering discrepancies (HEDs).

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1.2.5 To evaluate the extent and importance of identified discrepancies.

1.2.6 To formulate and implement solutions for significant discrepancies (as evaluated in 1.2.5).

1.2.7 To ensure that the proposed solutions do, in fact, eliminate or mitigate the discrepancies for which they are formulated without creating new discrepancies.

t GEORGIA POWER COMPANY 9 1.2.8 To verify that implemented solutions eliminate or mitigate identified discrepancies.

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CEORGIA POWER COMPANY 10 2.0 SIGNIFICANT CHANGES TO THE VEOP PROGRAM PLAN FOR THE IMPLEMENTATION OF CONTROL ROOM DESIGN REVIEW 2.1 CHANGE NUMBER 1 The characteristics used to review the License Event Report data base.

2.1.1 Plan Section 4.1.1 "Since INPO maintains a complete License Event Report (LER) data base, they will be requested to provide VEGP with a printout of LER's sorted using the

! following characteristics:

LER's From: Westinghouse PWRs Listing Errors By: Licensed Operators l

l Involving Either: Human error or procedural deficiency l

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CEORGIA POWER COMPANY 11 2.1.2 Summarv Reoort Section 4.3.1.1 Since INPO maintained a complete Pre-1984 LER data base, they provided VEGP with a printout of LER's sorted using the following characteristics:

LER's From: Westinghouse PWR's Listing Errors By: Licensed Operators Involving: Control Room LER's dated post 1984, were screened for the same characteristics utilizing NUREG 2000 reports.

2.1.3 Explanation l

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The Program Plan was developed using the NUTAC Control Room Desian Review Implementation Guideline (INPO 83-026), as a reference. It was not determined until after the program plan was submitted that the INPO data base could not be sorted using the guidelines in the NUTAC document. Furthermore, the post 1984 LER data base is in a different format and not suitable for this historical document review. The l

review of NUREG 2000 reports met the intent of the original program plan.

CEORGIA POWER COMPANY 12 2.2 Chanae Number 2 Repetition of 1982 Preliminary CROR Survey Items.

2.2.1 Plan Section 4.2 Items previously surveyed will be compared to revision in criteria since the original work and any additional HEDs identified. Previously completed survey items will not be repeated if the Review Team determines that the duplication of effort would reveal no new information.

2.2.2 Summarv Reoort Section 4.2.3.1 Items previously identified as HEDs and not incorporated into the latest control room design were carried forward as open HEDs in the present Control Room Design Review effort.

2.2.3 Exolanation The present CRDR was conducted without a concern of potential repetition. NUTAC and NUREG 0700 survey instruments were utilized as if the 1982 Preliminary CRDR was never conducted. However, the known HEDs outstanding were included in this review to ensure

CEORGIA POWER COMPANY 13 that items were not overlooked.

2.3 CHANGE NUMBER 3 Added NUREG 0700 as a source for control room survey instruments.

2.3.1 Plan The plan did not utilize NUREG 0700 as a source for control room survey instruments.

2.3.2 Summarv Reoort Section 4.3.4.1 0 Items not included in the NUTAC surveys listed in Appendix B-H of The Control Room Desion Review Survev Develooment Guideline (INPO 83-042) were reviewed against NUREG 0700 Section 6 guidelines as an additional survey.

O Labeling, Mimics, and Demarcation This area was supplemented by an additional survey using NUREG 0700, Section 6.6.

CEORGIA POWE3 COMPANY 14 0 Control Room Computer Checklist The NUTAC control room computer checklist was replaced by NUREG 0700, Section 6.7 (Process Computers).

O Lighting Survey The NUTAC survey was replaced by NUREG 0700, Section 6.1.5.3/4.

O Noise Survey The NUTAC survey was replaced by NUREG 0700 Section 6.1.5.5 0 Anthropometric Survey This area was supplemented by an l additional survey using NUREG 0700, Section 6.1.2.

O Annunciator Survey The NUTAC survey was supplemented by NUREG 0700 Section 6.3.

CEORGIA POWER COMPANY 15 0 Communications Survey The NUTAC survey was replaced by NUREG-0700 Section 6.2.

O Control Room Computer Survey The NUTAC survey was replaced by NUREG-0700 Section 6.7, (Process Computers).

2.3.3 Exolanation The NRC In-progress Audit Team advised GPC their I

audit would be conducted using NUREG 0700 as a basis and the use of NUTAC Guidelines could delay the l

review and impact licensing.

2.4 CHANGE NUMBER 4 l

l l HED Category Review I

2.4.1 Elan The NRC In-progress Auditors felt the plan lacked in the development of auditable records or documented guidelines which formally stated the details of the HED assessment methodology and evaluation criteria

CEORGIA POWER COMPANY 16 used by the CRDR Team.

2.4.2 Summarv Reoort Section 4.4.4 An HED category review was conducted to provide assurance that each HED identified during the execution phase of the CRDR was properly categorized.

The CRDR Team also developed more detailed explanations of their decisions on HED categorization and resolution.

2.4.3 Explanation The NRC In-progress Audit Team found no auditable records of the assessment guidelines and this review was conducted to supply this material.

2.5 CHANGE NUMBER 5 l

Task Analysis Products l

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l 2.5.1 Plan Section 6.4 l

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"The Summary Report for the CRDR will provide a list of major systems and subsystems, and their major I

components."

GEORGIA POWE3 COMPANY 17 2.5.2 Summarv Reoort The Summary Report will not contain this listing of major systems and subsystems, and their major components. This information is supplied in the VEGP FSAR 2.5.3 Exolanation This list would be redundant to the information supplied in the VEGP FSAR.

l 2.6 CHANGE NUMBER 6 i

Instrumentation and Control Characteristics Review 2.6.1 P,lgn l

l The Plan lacked details in the task analysis review of instrumentation and controls.

2.6.2 Summarv Reoort Section 4.3.6 In response to the NRC In-progress Audit concerns that the task analysis did not identify instrument and control (I&C) needs as compared to the I&C control room inventory. An independent review of the

CEORGIA POWER COMPANY 18 VEGP control room instrumentation and control characteristics was conducted.

2.6.3 Explanation The NRC In-progress Auditors felt that the GPC Task Analysis based on the Vogtle Emergency Operating Procedures was not a sufficient independent determination of the control room operators i instrumentation and control needs and I characteristics.

2.7 CHANGE NUMBER 7 l

The addition of a new assessment Category 4a l

l 2.7.1 Plan Section 5.2 Category 4-HEDs that do not fit into Categories 1 through 3. These HEDs are Judged by the Review Team as unlikely to affect emergency operation, not documented as causing problems during normal operation, and not simple or cheap to fix.

CEORGIA POWER COMPANY 19 2.7.2 Summarv Reoort Section 4.2.3.2 Category 4 - HEDs that do not fit into Categories 1 through 3. These HEDs are Judged by the Review Team as unlikely to affect emergency operation, not l documented as causing problems during normal operation, and not simple or cheap to fix. However, corrective action is recommended.

Category 4a - Such a minor deviation from standards it is not expected to cause a problem. No corrective action is recommended.

2.7.3 Explanation Category 4a was added to provide a convenient method of discriminating between those Category 4 items when some form of correction was recommended (4) and those for which no action was needed (da).

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CEORGIA POWE3 COMPANY 20 3.0 RESULTS OF THE CONTROL ROOM DESIGN REVIEW 3.1 CONTROL ROOM DESIGN REVIEW HED

SUMMARY

Appendix 6.3 contains the complete listing of Human Engineering Discrepancies with the resolutions. This section presents a summary of the HEDs by origin and category. Table 3.1 summarizes the HEDs:

CATEGORY l______________________________________________________l l l 01 l 02 l 03 l 04 l 4A l TOTAL l l______________________________________________________l l1981/2 l l 2 l 23 l 10 l 21 l 56 l l CRDR l l l l l l l l______________________________________________________l l TASK l 2 l 2 l 33 l 4 l 9 l 50 l l ANALYSl l l l l l l l______________________________________________________l l OER l 3 l 14 l 33 l 3 l 4 l 57 l l l l l l l l l l______________________________________________________l l SURV. l l l 7 l l 9 l 16 l l l l l l l l l l______________________________________________________l l CHECK l 1 l 2 l 18 l l 22 l 43 l l LISTS l l l l l l l l______________________________________________________l l NUREG l l l 19 l 5 l 38 l 62 l l 0700 l l l l l l l l______________________________________________________l l TOTAL l 6 l 20 l 133 l 22 l 103 l 284 l l______________________________________________________l

• (39) l l (1) l l (36) l (1) l (1) l l l______________________________________________________l

• NUMBERS IN ( ) HED CORRECTIVE ACTION IMPLEMENTED DURING THE CRDR PROCESS

l CEORGIA POtfER COMPANY 21 i 3.2 IMPLEMENTATION OF CONTROL ROOM IMPROVEMENTS

GPC did not wait until the completion of the CRDR l

l process to start implementing HED corrections. Twenty i

I Four percent of the HEDs requiring corrective action were completed prior to the submittal of this report l

l and only seven percent were deferred until after Unit One fuel load (see Table 3.1 and Figure 3.1). GPC will make every offort to complete the remaining i Sixty Eight percent prior to fuel load. No HEDs with i

safety significance will be left uncorrected.

M CORRN DW450G CRGt i

mmarD u rr.so COhPLETED 39 Ct4.4M BY FIEl. LOAD 109 88.1%

FIGdRE 3-1

GEORGIA POWER COMPANY 22 3.3 VEGP CONTROL ROOM DESICN CHARACTERISTICS CONSIDERED BENEFICIAL TO THE OPERATING CREW o

The Operating Personnel Survey generated positive responses that identified design characteristics considered beneficial by the operators. The following is a summary of those characteristics :

0 1st Out Annunciator Panel; O Parameters with an alert alarm status that annunciates prior to the required action condition; O Escutcheon color scheme used as equipment locator aids; O Functionally related controls, and annunciators; O Proteous disol.ie t o :ated at the operator work station; O Operator work platform; O Shift Supervisor work station; O Control room lighting;

CEORGIA POWER COMPANY 23 0 General panel layout; O Electrical panel mimics.

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CEORGIA POWED COMPANY 24 4.0 CRDR PROCESS DETAILS To achieve the stated objectives of the CRDR, several activities were completed during the review. The CRDR was split into six nominal phases: planning, execution, assessment, correction, effectiveness, and documentation.

4.1

SUMMARY

OF THE CRDR PROCESS Planning Phase The Planning Phase of CRDR was the development and implementation of the CRDR Program Plan (September 1984).

Execution Phase l

l The Execution Phase constituted the data gathering portion of the CRDR. During this phase, the control l

room survey instruments compared the characteristics l

of the existing control room with appropriate human engineering design guidelines. An examination of operating experience, both generic and plant-l specific, was conducted by the review of historical operational documents, such as Significant Operating Experience Reports (SOER's), Significant Event l

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GEORGIA POWER COMPANY 25 Reports (SER's) and Licensee Event Reports (LER's);

and through questionnaires and interviews with control room operators, and experience gained at the plant specific simulator. During task analysis, the Westinghouse symptom oriented Emergency Response Guidelines were analyzed to determine the systems operated and the tasks required of operators during emergencies. The instrumentation and control requirements for those tasks were established based on plant Emergency Operating Procedures, and the adequacy and completeness of existing instrumentation and controls was evaluated by the analyst during procedure walk downs and dynamic simulation of emergency scenarios. The product of the Execution Phase was identified HEDs.

Assessment Phase During the Assessment Phase, discrepancies identified in the Execution Phase were analyzed, and the potential impact of each discrepancy on emergency plant operation was evaluated. Discrepancies were classified according to their potential impac t on plant operation, and recommendations were formulated for acticn to correct or ameliorate the discrepancies. Significant discrepancies are in the process of being resolved through enhancement,

GEORGIA POWER COMPANY 25 modification, or other means, such as changes to procedures and training. Any actions proposed to resolve significant discrepancies were analyzed for their offact on operation.

Documentation Phase The Documentation Phase included the development of this report for submittal to the NRC. This report:

1. Summarizes and provides details of the overall review process

2. Summarizes identified human engineering discrepancies

3. Describes the disposition of discrepancies for which no changes were made

4. Describes control room design improvements implemented during the course of the review

5. Identifies existing design characteristics that are beneficial

GEORGIA POWED COMPANY 27

6. Identifies proposed design improvements that were not implemented during the review and their schedules for implementation Correction Phase The coordination of control room design improvements with other post TMI programs occurred during the validation of control room functions and improvements (see Section 4.2.7 of this report for details).

Implementation of the resultant control room improvements were not specifically scheduled item by item. The implementation goals are inherent in the HED classification process (see Section 4.2.3.2 and 4.4.2 of this report for details). The implementation items were assigned to Operations, Training, Engineering or Maintenance Departments for implementation in 1986 as personnel and materials were available. To ensure the Operator Training Program was updated to include control room design improvements, the changes were implemented in the simulator as soon as practical, with the objective that the simulator reflect the ultimate design of the cont.aol roon during operator training as the control room is made ready for plant operation.

Administrativo follow-up will rely u pon assigned personnel from the Operations organization.

GEORGIA POWE3 COMPANY 28 Ef f ectiveness Phase A CRDR Implementation Verification Program (Section 5.0 of this report) will be implemented at VEGP to ensure the control improvements resulting from HED resolutions have been properly installed and provide the necessary corrections.

4.2 DETAILS OF EACH PHASE 4.2.1 Plannina Phase 4.2.1.1 CRDR The ultimate responsibility for the VEGP CRDR resided f

with the GPC General Manager, Vogtle Nuclear Operations. Figure 4-1 shows the CRDR project organization. The day-to-day conduct of the review, t

l however, was the responsibility of a Review Team l established specifically for this CRDR. The Review l

l Team was responsible for planning, scheduling, and coordinating the total, integrated CRDR. The Review l Team was composed of members of the VEGP Operations and Engineering Departments.

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GEORGIA POWER COMPANY 29 FIGURE 4-1 CRDR ORGANIZATION GENERAL MANAGER, VOGTLE NUCLEAR OPERATIONS G. 80CKHOLD,Je.

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MANAGER, UNIT OPERATIONS H. WALKER I

V OPERATIONS SUPERINTENDENT N.F. KITCHENS l

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V CRDR REVIEW TEAM LEADER E.J . KOZINSKY l

l 1 i i V V l CORE REVIEN TEAM DISCIPLINE SUPPORT l

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

GEORGIA POWER COMPANY 30 4.2.1.2 REVIEW TEAM The Review Team was a multi-disciplined team of individuals with the wide range of skills necessary to perform the design review. The team included the following members (Appendix 6.7 of this report contains the personal resumes):

Edward J.Kozinsky -Review Team Leader i

John D. Hopkins -Senior Reactor Operator I

Riley R. Johnson -Operations Technical Advisor l

Greg L. Hooper -Instrumentation and Controls Specialist l

Paul M. Kochery -Design Engineer Alan L. James -Instrumentation and Controls Specialist (alternato]

I The core team was supplemented, as required, by other site disciplines such as mechanical, electrical, industrial engineering, training, computer operations, procedures, licensing, health physics,

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GEORGIA POWER COMPANY 31 e

and emergency preparedness. In addition to the above, technical support was supplied from JVS Corporation, Westinghouse Electric Corporation, Consultec Service Company and General Physics.

4.2.1.2.1 Review Team Leader The Review Team Leader was E.J. Kozinsky. He provided administrative and technical direction for the project and had responsibility for the project.

Access to information, facilities, and individuals providing useful or necessary input to the team was coordinated by the Review Team Leader. He.provided a cohesive force for the various VEGP depar tmen t personnel involved with this project. Plant operations personnel provided input to the Review Team through contact with the Review Team Leader. The Review Team Leader coordinated the VEGP CRDR with work on the Plant Hatch CRDR and development of the VEGp Safety Parameter Display System.

It was the responsibility of the Review Team Leader to resolve human factors questions on j findings, assessments, or HED corrective actions.

CEORGIA POWER COMPANY 32 The Rev-lew Team Leader also acted as the human factors specialist on the project and ensured task performance quality was maintained at a level necessary for a valid and comprehensive review.

4.2.1.2.2 Instrument and Controls (I&C) Specialist The I&C Specialist assisted in the identification of plant system design features and served as the Review Team expert on the capabilities and limitations of controls and instruments. The I&C Specialist also provided input to the team during the Assessment Phase of the review, especially when the Review Team considered proposals for mitigating HEDs.

4.2.1.2.3 Senior Reactor Operator (SRO)

One SRO (Instructor Certified) from the VEGP Operations group served as a member of the core l

Review Team. The SRO assisted in identifying operator tasks and served as the Review Team expert on the operational constraints for manipulations of plant systems.

GEORGIA POWEO COMPANY 33 4.2.1.2.4 Operations Technical Advisor One previously licensed Reactor Operator with an SRO Certification served on the core Review Team as an operations specialist. This advisor participated in all phases of the CRDR, by providing assistance in identifying required or expected operator tasks related to industry practice.

4.2.1.2.5 Design Engineer The Design Engineer assisted in the identification of plant system design goals and functions and served as the Review Team expert on the factors affecting the design decisions at the plant. The Design Engineer provided input or interfaced with project engineering as necessary during the analysis of functions and tasks for any plant systems and during the assessment, implementation, and effectiveness phases of the CRDR.

4.2.1.3 REVIEW TEAM ORGANIZATIONAL INTERFACES 4.2.1.3.1 Site Interfaces In order to perform the CROR expeditiously while utilizing and broadening the experience in our

GEORSIA PON C COMPANY 34 personnel, CRDR tasks were performed by Operations and Training personnel as often as possible, supplemented as necessary with technical specialists.

The Review Team Leader had the authority to contact the appropriate supervisor of each department to establish a cooperative working relationship with mai usiwn t personneI.

4.2.1.3.2 Corporate Interface The Review Team existed as a special project in the VEGP organization, but the normal corporate and site organization provided a structure of authority and supervision.

4.2.1.3.3 Coordination It was essential that the CRDR be coordinated with other ongoing activities that involved potential physical changes to the plant, such as the construction and manning of emergency response facilities (ERF's). To ensure that such coordination l

took place, the Review Team Leader coordinated with l and provided input to all ongoing work on ERF's and the control room design.

SEORGIA POWE~2 COMPANY 35 4.2.1.4 REVIEW TEAM ORIENTATION Each member of the Review Team brought their own in-depth knowledge of specific topics to the team. It was important, however, that the Review Teara be able to conduct the CRDR from a common basis of understanding. The entire Review Team underwent an orientation program to provide each team member with 1

certain basic knowledge. The purpose of the orientation was to acquaint each team member with the other disciplines represented on the team, not to make each team member an expert in all specialties.

The following topics were covered during the five half-day orientation course:

0 Overview - History of Human Factors i

0 Human Factors in the Nuclear Industry 0 Human Factors Guidelines and Standards 0 Human Performance Evaluation 0 Operator Reliability 0 Performance Shaping Factors

CEORGIA POWE3 COMPANY 35 0 Control Room Design Review Methods 0 Emergency Response Guidelines /EOP's O System Functions / Task Analysis l

0 Controls and Indicators 0 Procedures O Computer Displays O Control Board Layout and Labeling 0 Maintenance 0 Operations / Communications 4.2.1.4.1 Human Factors

! Orientation provided for the Review Team was to familiarize the team with principles of human factors and their application to the control room review.

Included in this area was a brief synopsis of the history of the CRDR requirements and its ultimate goals. This orientation area was slanted toward those Review Team members with little or no background in

GEORGIA POWER COMPANY 37 human engineering.

4.2.1.4.2 Emergency Response Guidelines (ERG)

Orientation on the development and status of Westinghouse ERGS provided Review Team members with a basis for the task analysis phase of the CRDR.

4.2.1.4.3 Post Accident Monitoring System (PAMS)

Orientation on the current status of Regulatory Guide (RG) 1.97 instrumentation at VEGP assisted the Review Team in integrating the CRDR with RG 1.97 implementation.

4.2.1.4.4 CRDR Familiarization Support personnel participating in the CRDR received an overview indoctrination of the CRDR and specific instruction on the methodologies for performing their support tasks. The CRDR Team Leader provided this i

l instruction.

4.2.2 Execution Phase l

The objective of the CRDR was to determine the extent to which the VEGP control room provides the operators

GEORGIA POWEO COMPANY 38 with sufficient information to complete their required functions and task responsibilities efficiently under emergency conditions. The review also determined the human engineering suitability of the designs of the instrumentation and equipment in the VEGP control room. This section of the Summary Report describes the process that was used to accomplish those overall objectives.

4.2.2.1 1982 PRELIMINARY CRDR STATUS EVALUATION Recognizing that the 1982 Control Room Design Review would provide valuable input to the current Control Room Design Review, each of the 113 identified deficiencies / discrepancies were reviewed. The review consisted of one team niember performing a Deficiency Status Evaluation on each deficiency and the results reviewed and approved by the entire CRDR team. The l

evaluation was aided by the use of the following I

l checklist:

o Action reflects the recommended intent and resolves the HED.

I I o Action reflects the recommended intent but does not resolve the HED.

, . , - , - - - - - - - , , ,n - - - , . _ , , ,_n,,, _ , , , . , , - - , - - - -

GEORGIA POWE3 COMPANY 39 o Action does not reflect the recommended intent.

o Actions taken creates other HED(s).

o No action taken, deficiency remains.

o No action taken, deficiency resolved by resolution of HED.

o New HED(s) generated; HED numbers (1001 to 1064).

o Other (Explain) 4.2.2.2 OPERATING EXPERIENCE REVIEW l

The Vogtle Electric Generating Plant is under I construction with no operating history. And the on-site experience of operational personnel and data j from plant operation documents provided little information for the CRDR. Accordingly, the Operating Experience Review focused primarily on industry l

experience at similar plants and considered the experience gained from the VEGP plant-specific l

l simulator.

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GEOftGI A PO96ER COMPANY C0

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Two separate steps were involved in reh(ewing operating experience. The first was to review available and applicable historical documentation pertaining to plant-specific and generic occurrences.

The second step was to survey operating personnel.

Operating personnel surveys (Operator Questionnaire) identified specific problem areas in the VEGP coritrol room that may occur during normal and emergency operation. The Operator Questionnaire was extracted from the Control Room Design Review Survey Development Guideline (INPO 83-014) (NUTAC).

4.2.2.3 PROBLEM REPORTS I

An open ended Control Room Design Problem form was sent to all control room and simulator personnel.

Copies are made available in the control room and the simulator. This allowed any problem noted to be promptly reported. These problem reports were evaluated for possible HEDs by the Review Teae Leader. In many cases the problem reports identified items already documented by surveys or prior problee reports

GEORGIA POWE3 COMPANY C1 4.2.2.4 CONTROL ROOM SURVEY Surveys of the existing VEGP control room were conducted during the CRDR. The purpose of the survey was to compare the design features of the existing control room with applicable human engineering design guidelines. The survey was conducted by the CRDR Review Team. The survey team used questionnaires, checklists, and surveys to compile information  ;

regarding the as-built characteristics of the VEGP control room.

4.2.2.4.1 Checklists, and Surveys The NUTAC on CRDR developed a set of questionnaires, checklists, and surveys that addresses the human

! engineering design considerations applicable to nuclear power plant control rooms. VEGP used these survey instruments in conjunction with the guidance presented in NUREG 0700, Sept. 1981 with as little l

modification as possible.

4.2.2.4.2 Engineering Department Questionnaire

{

In addition to the Operator Questionnaire discussed in Section 4.2.2.2 and 4.3.2 the NUTAC survey instruments included the Engineering Department

GEORGIA POWE2 COMPANY 42 Questionnaire. The Engineering Department Questionnaire was designed to compile information concerning the function and operation of various plant systems, such as the annunciator and emergency lighting systems. This questionnaire also solicits information on the failure modes and opinions about the adequacy of certain existing system characteristics.

The purposes of the Engineering Depa r tmen t Questionnaire was to educate the Review Team concerning the design attributes of certain plant systems and to provide an engineering input for the assessment of HEDs during the review process. The Review Team Leader distributed the Engineering

< Department Questionnaire to the GPC Engineering Department for completion. The completed Engineering Questionnaire was reviewed by the CRDR Team for information. No HEDs originated directly from this

! questionnaire.

I 4.2.2.5 TASK ANALYSIS The operating experience review and the control room survey identified as HEDs, control room characteristics that have caused, or nearly caused, problems during normal operation and simulator

CEORGIA POWE3 COMPANY 03 exercises and characteristics that do not conform to certain human engineering design criteria. The major activity in the CROR Execution P hase , the task analysis, identified the tasks operators must perform during emergency operation and determined whether the instrumentation, controls, and equipment were available and suitable to perform those tasks. In addition to determining the availability of suitable instrumentation, controls, and equipment, the tack analysis validated that the emergency tasks identified can be performed in real time under simulated emergency conditions in the VEGP control room.

l The task analysis used as its basis the Emergency l

l Response Guidelines (ERGS) developed by the Westinghouse Owners Group (WOG). These ERGS have been designed to support the generation of plant specific Emergency Operating Procedures (EOPs) for Westinghouse nuclear plants. When using the ERGS, the analysis done as part of the systems review in ERG development can be applied to developing a plant specific task analysis for VEGP.

i

e GEOftGIA POtfE2 COMPANY 44 4.2.3 Apsessment P hase 4.2.3.1 OBJECTIVES The objectives of this phase of the CRDR were:

0 Evaluate the significance of the HEDs identified in the previous phases of the CRDR.

O Where HEDs are found to be of minor significance, describe the technical and operational basis for such a finding.

O Where HEDs are found to be significant, formulate changes to the control room design, procedures, operator training, or any combination thereof to mitigate those HEDs.

Of these' objectives, the most conceptually difficult l

l was to evaluate HED significance. A fairly straightforward set of criteria for HED evaluation is described in the next section.

l An extensive review of the VEGP control room against NUREG 1580 guidelines was conducted in 1981/1982. The results of that CRDR was reviewed, especially the

GEORGIA POWEQ COMPANY 45 HEDs and their resolution. Items previously identified as HEDs and not incorporated into the latest control room design were carried forward as open HEDs in the present control room design review effort.

4.2.3.2 EVALUATION CRITERIA Human engineering discrepancies found during the control room survey, the operating experience review, and the task analysis were evaluated by the Review Team for their potential to adversely af fect normal and emergency operation. A categorization scheme was used that required each HED to be assessed by the Review Team and prioritized for resolution. The following five categories were designed to be unique so a consensus could be obtained from the Review Team as to which category each HED should be assigned.

O Category 1 (Safety Significant) -

HEDs i

I that have caused errors in or are Judged likely to adversely affect the management of emergency conditions by control room j operators.

O Category 2 -

HEDs that are known to have

! caused problems during normal operation.

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C l

l GEORGIA POWE'] COMPANY 46 0 Category 3 - HEDs that can be " fixed" with simple and inexpensive enhancements, so called "peint, tape, and label" (PTL) fixes. This may seem to be an implementation rather than an assessment category. However, there probably will be HEDs that the Review Team feels are very easy to fix but difficult to assess as the effect on emergency opera tion . This category is for such HEDs.

O Category 4 -

HEDs that do not fit into Categories 1 through 3. These HEDs are Judged by the Review Team as unlikely to affect emergency operation, not documented as causing problems during normal operation, and not simple or cheap to fix.

However, corrective action is recommended.

O Category 4a -

Such a minor deviation from standards it is not expected to cause a problem. No corrective action recommended.

Categorization was done in CRDR Team Meetings with at least three members present. All members were required to review and concur in the categorization before it was considered final. These meetings and

GEORGIA POWER COMPANY 07 reviews were documented in the CRDR Team Meeting Minute Book. Any Review Team member who felt that an HED had been assigned too low a priority was able to put that opinion in writing and have the written statement included in the permanent record of the CRDR. No such cases occurred.

4.2.3.3 RESOLUTION OF HEDS One of the final responsibilities of the Review Team was to propose solutions to the HEDs that were identified and categorized. There are, in general, many ways to solve specific human engineering problems. Correction of HEDs were accomplished by enhancement (use of color, mimics, or labels), class improvements (grouped indicators or controls by type i or model number) or individual discrepancy corrections (case-by-case). In some cases, a change in training or procedures was developed.

Multiple characteristics were considered by the Review Team when evaluating methods for HED correction. The following characteristics were considered if applicable, and discussed by the CRDR Team in selecting a resolution:

O System safety;

e GEORGIA POWE3 COMPANY 48 0 Impact on operating effectiveness; O Impact on plant availability; O Consistency with existing features; O Compliance with regulatory design guidelines; O Cost; O Impact on control room staffing; O Impact on Operator Training Programs.

Selection of an HED resolution was done by CRDR Team Meetings similar to categorization and documented in the CRDR Team Meeting Minute Book.

l l

l l When a correction involved movement, modification, addition, or deletion of instrumentation, then these corrections were evaluated with respect to their l

1mpact on the existing control room including operator performance, training, and procedures.

Before any large scale changes are approved, the proposed modifications were built into the simulator, where practical, and evaluated to determine their i

(- ,

GEORSIA POWE2 COMPANY 49 effectiveness.

The training simulator will be modeled to duplicate the plant control operator functions in the control room and to closely match non-functional architecture details and non-plant control hardware details.

During the time of the CRDR (1981-1986) the plant design continued to change, These changes were sometimes installed in the simulator first, sometimes in the plant first. Construction and training sc hedules and hardware availability dictated the installation schedules. GPC plans to bring the simulator into conformance with the main control room design in time for operator licensing training and examinations in 1986. These changes will include changes resulting from the CRDR which are planned in the control room prior to fuel load. The major changes included the following:

O Control room furnishings l

0 Monitor light box modifications O Control and instrumentation arrangements 0 Hierarchical labeling O Label nomenclature

e

_ a GEORGIA POWE1 COMPANY 50 0 ERF/SPDS computer 4.2.4 Documentation Phase Adequate documentation and document control created a traceable and systematic translation of information from one phase of the CRDR to the next. The CRDR Team had access to a comalete, up-to-date set of design documents to manage and execute the various steps and phases of the control room reviews.

This section describes the functional requirements i

that were fulfilled by the documentation system GPC used to support the control room design review.

4.2.4.1 GENERAL DOCUMENTATION REQUIREMENTS i

l Many documents were referenced and produced during the CRDR project. The documentation system met the following requirements:

O Provide a record of all documents used by the Review Team as references during various phases of the CRDR;

e GEORGIA POWER COMPANY 51 0 Provide a record of all correspondence generated or received by the Review Team during the review; O Provide a record of all documents produced by the Review Team as project output; O Allow an audit path to be generated through the project documentation; O Retain project files in a manner that allows future access to help determine the offacts of control room changes proposed in the future.

4.2.

4.2 REFERENCES

The following documents have been identified as reference material used during the review project.

l

1. VEGP Final Safety Analysis Report

2. Westinghouse Emergency Response Guidelines (ERGS) ,

i 1

i

, _ . . - , , . . - . _ . . - .m. _.. .

I GEORGIA POWER COMPANY 52

3. VEGP Procedures Emergency (19000 series)

Operations Administration (10000 series)

Plant Administration (00000 series)

4. Regulatory Guides (e.g., RG 1.97 and RG 1.47)

5. NRC guidance documents (e.g., NUREG-0700 NUREG-0800, NUREG-0801 draft & Standard Review Plan 18.1)

6. VEGP training materials

7. Control room drawings (floor plan, panel l layout, etc.)

8. Human factors design information f a) H.P. VanCott and R.G. Kinkade, editors, Human Engineering Guide to

Equipment Design (1972) i i

l

e GEORGIA POWER COMPANY 53 b) E.J. McCormick and M.S. Sanders. Human Factors in Engineering and Design (Fifth Edition) (1982) c) D.J. Osborne, Ergonomics at Work (1982) d) W.E. Woodson, Human Factors Design Handbook (1981) e) Mil-STD - 1472C

9. Vogtle piping and instrumentation drawings (P& ids)

10. Vogtle process computer software descriptions

11. Results of preliminary 1981/1982 control room review activities l

12. INPO/TVA Pilot Systems Review (INPO 82-014)

13. CRDR NUTAC documents l

a) Control Room Design Review Implementation Guideline (INPO 83-026)

e GEORGIA POWE2 COMPANY 54 b) Human Engineering Principles For Control Room Design Review (INPO 83-036) c) Control Room Design Review Survey Development Guideline (INPO 83-42) d) Control Room Design Review Task Analysis Guideline (INPO 83-46) 4.2.4.3 REVIEW DOCUMENTATION Through the review process, documents were processed to record data, analyses, and findings. Standard forms were developed and used. The bulk of the documentation generated by the review process made it necessary to do the following:

0 Document the criteria used for each review activity; I

O Record the results of the survey, operating experience review,and systems review; O Compile HEDs and associated data for review and assessment,

I GEORGIA POWE3 COMPANY 55 In order to facilitate recording control room design review activities, GPC utilized standard forms based on INPO NUTAC reports and NUREG, 0700 Section 6.

4.2.5 Correction Phase The actions frequired to resolve significant H EDs varied as did the time required to complete proposed changes. It was essential, however, to set some end point for completing the proposed changes for each HED category.

4.2.5.1 IMPLEMENTATION Modifications required to resolve significant HEDs have been implemented using approved GPC Nuclear Operations or GPC Nuclear Construction Department procedures.

Since the plant modification process for selected HEDs may take a considerable amount of time for implementation, the implementation ,and follow-up activities will rely upon assigned personnel from the Operations organization. Therefore, it is imperative that the HEDs and the resulting modification request (s) are very explicit as to what is to be done. See Section 4.4.1 of this report.

e CEORGIA POWER COMPANY SS The use of existing plant modification procedures ensures that plant operators will be made aware of impending changes and will be trained to use the modified control panels and systems, since the current station modification process is to involve the VEGP Training Department in the early stages of the modification.

This approach to the implementation of changes will help ensure the success of the post fuel load modifications and will give the line organization a

! tool for developing their techniques for long-term support of the control room.

4.2.6 Effectiveness Phase Recognizing the need for verification of the control room changes resulting from the CRDR, GPC will implement a CRDR Implementation Verification Program j at VEGP in the summer of 1986. See Section 5.0 of l

this report.

i i 4.2.6.1 FUTURE CONTROL ROOM CHANGES In order to ensure adequate human factors considerations for control room changes that are considered after the CRDR is completed, the results L__._._ -

r GEORGIA POWE3 COMPANY 57 of the CRDR in this report will be available for Engineering and Operations personnel to reference.

This will provide a standard to evaluate the human factors acceptability of all proposed control room modifications.

The control room basis, or current configuration, will be reflected in the simulator maintained at the VEGP site. This will provide a tool for use when evaluating proposed control room changes before the changes are actually implemented.

4.2.7 Coordination With Other Activities The CRDR process described in this report was coordinated with other post-TMI activities in several ways. These activities included the following:

0 Upgrading Emergency Operating Procedures:

l l

0 Detailed Control Room Design Review

( (Program Plan for Implementation of CRDR)

O Post-Accident Monitoring System (FSAR 7.5- R.G. 1.97 Requirements)

CEORGIA PLWER COMPANY 58 0 Safety Parameter Display System (FSAR 9.5.10) 0 Upgrading emergency response facilities, The mechanism for coordination of con trol room improvements with other programs was the Emergency Operating Procedures Validation Program.

The coordination was achieved by (1) having several members of the CRDR Team Members serve as members of the EOP Observation Teams during the EOP Validation Exercises; (2) the Task Analysis was a common basis for both the CRDR and EOP Programs; and (3) the findings or discrepancies identified during the validation exercises related to man and machine interfacing was processed via the CRDR HED Assessment Process.

In addition, control room modifications that resulted l

l from the Emergency Operating Procedures Validation Program are to be addressed in the CRDR Verification Plan to ensure design improvements provide the l

(see necessary correction Section 5.0 of this report).

e CEORGIA POWE*! COMPANY 59 4.2.7.1 EMERGENCY OPERATING PROCEDURES The Task Analysis portion of the CRDR used the Westinghouse ERGS as plant s peci fic EOPs as its starting point. Thus, the task of upgrading emergency procedures is inherently integrated into the CRDR.

The simulator validation of the task analysis was combined with the VEGP EOP Validation Program (See Sections 4.3.5. and 4.3.7 of this report.)

4.2.7.2 SAFETY PARAMETER DISPLAY SYSTEM GPC used the SPDS during the EOP Validation Exercise, and evaluated it to NUREG 0700 Section 6.7 (Process Computer) guidelines. Some HEDs identified during the EOP Validation exercise, and the Computer Survey and Judged to be significant by the Review Team were resolved by incorporating certain features into the i

l SPDS and associated displays. In addition, the CRDR l

Team Leader was Chairman of a Control Room Computer Task Force and participated in developing displays and key board arrangements. This served to incorporate human factors requirements into the design of .he SPDS and further integrate it into the CRDR process.

F GEORGIA POWE3 COMPANY 60 4.2.7.3 REGULATORY GUIDE 1.97 The design of RG 1.97 instrumentation was essentially complete at the time of this review. This instrumentation was evaluated in the CRDR survey and task analysis.

4.3 CRDR METHODOLOGY AND RESULTS Each activity of the CRDR was controlled with an implementing procedure. The procedures helped ensure that each CRDR Team member performed his assigned activity with consistency, and handl ed the documentation in a prescribed manner. The implementing procedures in general, addressed the following areas:

O Purpose of the activity; O Reports to be reviewed; O Discussion of the activity and background infccmation; O Activity logs; O Documentation;

CEORGIA POWER COMPANY $1 0 Disposition of the findings and date; O Activity close out.

To ensure concurrence of the CRDR Team, every procedure was reviewed and approved by the Teca Leader and all team members before the procedure was implemented.

4.3.1 Ooeratina Experience Review As part of the Execution Phase of the CRDR and parallel with the Operating Personnel Survey, an examination of generic operating experiences was conducted by a systematic review of historical industry operational reports.

4.3.1.1 Historical Documentation Review i

l It was recognized that documentation originating elsewhere in the industry should be reviewed to l

l ascertain whether or not generic problems have been l

l found that might relate to VEGP. Significant l

Operating Experience Reports (SOERs) and Significant l

Event Reports (SERs) distributed by the Institute of Nuclear Power Cperations (INPO) were screened for applicability to VEGP control room.

e CEORGIA POWE3 COMPANY C2 The final generic documentation to be reviewed was Licensee Event Reports (LERs) from plants of the same design vintage and vendor type as VEGP. Since INPO maintained a complete pre-1984 LER data base, they provided VEGP with a printout of sorted LERs using the following characteristics:

LERs from: Westinghouse PWR Listing errors by: licensed operators Involving: control room LERs dated post 1983 were screened for the same characteristics utilizing NUREG 2000 reports.

Copies of reports involving control room operator, control board equipment failure and/or design arrangement errors were obtained. The reports I

obtained were screened to determine if the report describes and documents a control room design j problem. Reports that passed the selection criteria were further reviewed for applicability to and impact on Vogtle operations.

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F i

GEORGIA POWEQ COMPANY 83 i

The following historical reports that were available for 1982, 1983, 1984, and 1985(partial year) were reviewed:

1. Significant Operating Experience Reports (SOERs) (not limited to the type of plant)

2. Significant Events Reports (SERs) (not limited to the type of plant)

3. Licensee Events Reports (LERs)

(limited to Westinghouse PWRs)

The reports were first screened to select those events that occurred or were initiated from the physical confines of the control room or remote shutdown panel, and contributed to an operating crew error.

The CRDR Team Leader, with the assistance of a reactor operator reviewed those reports selected as applicable to the control room operating crew, and determined if a potential for error exists at VEGP, due to the control room design. If applicable to VEGP an HED was written.

r GEORGIA POWE2 COMPANY $4 All industry events that are known to have previously contributed to a control room operating crew error as documented in a LER, SOER, and SER and were determined to be potential errors ist VEGP due to the control room design were documented Category 2 HEDs, unless previously identified an categorized 1 or 3 in CRDR surveys.

Those reports that were determined to be applicable l

to the control room operating crew were documented on the Operating Experience Review Problem Analysis Report.

The report form contained a series of statements designed to aid the reviewer in assessing if the industry report was due to a control room design l deficiency.

Seven HEOs were generated as a result of the Operating Experience Review, and were handled according to the HED Procedures.

4.3.1.2 SCREENING PROCESS Recognizing that the large majority of industry reports are not related to control room operating crew errors, it would have been unreasonable for the

r-GEORGIA POWER COMPANY 65 CRDR Team members to evaluate all historical reports for applicability. Therefore, it was desirable to appoint a qualified individual (Mr. D. Crouch, resume included in Appendix 6.7 of this report) to screen all the industry reports generated since 1981 for applicability to the CRDR effort.

If an industry event met any one of the following criteria it was selected for review:

0 The event involved control room instrumentation.

O The event was a result of a personnel error.

O The event involved a licensed operator or an SRO.

O The event was a direct result of inadequate equipment status in the control room.

l 0 The event involved control room annunciators.

l 1 0 The event involved equipment labels.

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m .,_.___.m _ _ _ _ . _ _ ._

r GEORGIA POWED COMPANY C5 0 The event involved communications from the control room.

O The event was a result of wrong unit, wrong train as initiated from the control room.

O The event was a result of inadequate indication (i.e., valve position).

t 4.3.2 Ooeratina personnel Survev Review (Operator Ouestionnaire)

The most valuable source of data on operational problems is the person who has operated the plant or the plant-specific simulator. The intent of the opera ting personnel survey was to gain as much firsthand information as possible on actual and potential operational errors from such operators. The 1

survey consisted of a self-administered questionnaire and alternate problem notification report form.

I l

The responses to the Operator Questionnaires were reviewed to identify specific design problems in the l

I l VEGP control room. These responses were based on l

l recent operating experiences gained in the VEGP control room and simulator. The training simulator l

1

GEORGIA P000E 2 COftPANY 37 experiences were a particular valuable source for identifying control room human engineering shortcomings, because the trainees have not yet l

I learned to compensate for design deficiencies.

l l

4.3.2.1 QUESTIONNAIRE An open ended, self-administered questionnaire approach was adopted. The survey covered 10 topics.

Specifically, the areas covered were as follows:

l 0 Workspace layouts and environment; O Panel design; O Annunciator system; O Communications; O Process computer; O Corrective and preventive maintenance; O Procedures; O Staffing and Job design; O Training;

r SEORSIA POWEO COMPANY 88 o comments.

The purpose of the Operator Questionnaire was to tap the operational knowledge of VEGP personnel and relate that knowledge to the human engineering characteristics of the VEGP control room or plant specific simulator. It was not feasible to keep all subjective opinion out of the responses to such a questionnaire. However, the individual questions were posed as objectively as possible and, by using data from many individuals, isolated individual " pet peeves" could be weighted lightly during the analysis of the information obtained.

4.3.2.2 ADMINISTRATION The Review Team Leader distributed the Operator Questionnaire to Plant Operators, Shift Supervisors, Shift Technical Advisors and On-Shift Operating Su pervisors in the VEGP Nuclear Operations Depar tment after the Unit I control room was manned in 1985. A cover letter was attached to each questionnaire. The cover letter (1) explained the purpose, (2) described the questionnaire and provided instructions, and (3) conveyed what will be done with the results.

Questionnaires were given to simulator trainees and simulator instructors in 1984 early in the CRDR 1

GEORGIA PONC COMPANY se process.

The questionnaires, when returned, were logged in,and reviewed item-by-1 tem. All responses, both positive and negative are summarized in the Questionnaire Item Summary Data Base. Positive, negative and neutral comments on the control room and simulator features were identified on the questionnaire data base.

Further investigation, was carried out for each item on the responses to determine the potential impact on control room operations. Negative responses were investigated further to identify potential HEDs. If the response met the following criteria it was documented in accordance with the HED Procedure:

1) The response was component or design specific, not a global statement concerning the control room.

2) The response identifies a problem that has contributed to confusion or errors on the VEGP simulator or in the VEGP control room.

HEDs generated as a result of the Operating Personnel Survey Review- were handled according to the HED Procedure. The unstructured comments received with

m SEOftGI A POWO COMPANY 70 the questionnaires were handled according to the Problem Report Procedure.

All HEDs that were known to have contributed to a control room operating crew error on the simulator or in the VEGP control room (when operational), as documented in the Operator Questionnaires, were categorized as Category 2 HEDs unless previously identified and categorized 1 or 3 in CRDR surveys.

4.3.3 Problem Reoorts Problem Reports provided a flexible means for opera tions personnel to identify problems to the CRDR. A Problem Report form is shown in Figure 4-2.

Upon receipt of a problem report the Review Team Leader, or his designee, assigned a sequential control number, and completed an entry in a Problem Report Log.

The Review Team Leader evaluated the report and initialed the most appropriate disposition on the log, either to initiate an HED (or refer to an existing HED) or take no action since the problem report did not represent a human engineering problem.

~

r-CEORGIA POWER COMPANY 71 Each team member reviewed the problem reports dispositioned as "NO SIGNIFICANT IMPACT-FILE FOR REFERENCE *. Agreement with this disposition was signified by the team member initialing the log. If a Review Team member disagreed with the 'NO SIGNIFICANT IMPACT' disposition, he could initiate an HED. No disagreements occurred.

HEDs generated as a result of a problem report were handled according to the HED Procedure. Close out of a problem report was accomplished when one of the following dispositions was indicated in the Problem Report Log:

0 Reviewed by CRDR Team as not an HED:

O HED number assigned or referenced.

f 1

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GEORGIA POWE2 COMPANY 72 CONTitQL ROOM DESIGN PROBLEM REPORT FROM: DATE:

TO: E. J. Kozinskv CONTROL / INDICATOR (4 AND NAME):

PROBLEM:

RECOMMENDATION:

FIGURE 4-2

r' GEORGIA POWEO COMPANY 73 4.3.4 Control Room Survevs and Checklists The surveys and checklists utilized during the Execution Phase of the VEGP CRDR were extracted from the Control Room Design Review Survey Development Guideline (INPO 83-042: NUTAC) and NUREG 0700.

4.3.4.1 SURVEYS Eleven separate surveys were completed during the CRDR survey activity. Some of the surveys consist simply of recording (or determining) control room conventions, such as color usage and instrument arrangement. These surveys were used in other CRDR activities to determine where particular instruments or systems depart from the overall convention.

Operator and human factors input were required for some of these surveys.

Other surveys measure certain physical quantities, such as illumination and sound level, and compare these measurements to acceptable, or preferred human engineering standards for such quantities. For this type of survey, the only specialized skill required l

1s the ability to operate and read the measuring instruments. HEDs would be written for l

characteristics that fall outside the acceptable .

GEORGIA POWE3 COMPANY 73 band.

The individual surveys were:

O General Design Convention Survey (NUTAC 83-042);

O Design Convention Survey for Repetitive Groupings (NUTAC 83-042);

(

0 Lighting Survey (NUREG 0700 Section 6.1.5);

O Noise Survey (NUREG 0700 Appendix E);

O Anthropometric Survey (NUTAC 83-042 and NUREG 0700 Section 6.1.2);

l l

0 Annunciator Survey (NUREG 0700 Section 6.3);

O Communication Survey (NUREG 0700 Section 6.2; O Abbreviation and Acronym Survey (NUTAC 83-042);

O Color-Coding Survey (NUTAC 83-042);

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GEOReIA POWE2 COMPANY 75 0 Control Room Computer Survey (NUREG 0700 Section 6.7);

O NUTAC 83-042 Appendices B-H Survey (using applicable NUREG 0700 guidelines).

These surveys were done independently. They functioned as a frame work within which various measurements were recorded. Some of the surveys consisted of simply describing control room conventions such as color usage and instrument arrangement. The information obtained in these surveys was used in other CRDR activities to determine where par ticula r instruments or systems depart from the overall convention. For these surveys, in particular, operator input was required to describe how certain controls functioned and the meaning assigned to particular colors. It should be noted that, in general, HEDs were not written during convention surveys. Instead, the information obtained was used during assessment.

4.3.4.1.1 Personnel Assignments It was not necessary for the entire CRDR Review Team I to be involved in the day-to-day conduct of the control room survey. The actual surveys were

GEORGIA P000E0 C000PANY 78 conducted by Review Team members supported by members of various VEGP departments.

4.3.4.2 CHECKLISTS The checklists contain short, declarative sentences that address specific control room design characteristics. When the checklist item was answered yes, then the existing feature of the control room was considered to conform to the criterion on which that checklist item is based. For example, item two in the overview checklist states: " Sanitary Facilities and Drinking Water Are Easily Accessible."

If the individual (s) using the checklist make(s) the Judgment that the statement is true or correct for the control room under review, then that item is checked off, and no further action is necessary concerning the characteristic. If a particular checklist item was not adhered to by the control room, then one or more HEDs were generated to document deviations from the underlying design criterion.

Four checklists were utilized from the NUTAC and NUREG 0700 survey instruments. These are an overview checklist (NUTAC); operator-assisted checklist (NUTAC); a labeling, mimics, and demarcation

GEORGIA POWE3 COMPANY 77 checklist (NUTAC and NUREG 0700 Section 6.6); a general panel checklist (NUTAC). Each checklist is designed to allow one or two people to walk around the control room and determine whether individual checklists items are satisfied by the existing control room design.

4.3.4.3 DEFERRED SURVEYS AND CHECKLISTS The following surveys, checklists and individual items have been deferred for the cited reasons:

1) Overview Checklist OC-12 Storage space for the crew's personal belongings, on hold until the control room is closer to completion, OC-20 Control room speaker adjustment, on hold until the control room is closer to completion.

2) Operated Assisted Checklist OAC-23, 24, 26, and 28 are on hold until the control room is closer to completion.

! GEORGIA POWE3 COMPANY 73

3) Computer survey ATSI Computer is not operational at this time PSMS Computer is not operational at this time

4) Communication Survey Rev.1 The survey is on hold until the control room is closer to completion.

5) Lighting Survey Rev.1 The survey is on hold until the control room is closer to completion. The planned completion is September 1986.

6) Sound Survey The survey is on hold until the control room is closer to completion. The planned completion is September 1986.

7) Annunciator Survey Section 6.3.2.1a, c,.d This survey item will be performed in conjunction with the Sound Survey.

I GEORGIA PO90E] COMPANY 73 4.3.5 Task Analvsis The objectives of the CRDR Task Analysis were to identify the operator tasks required to support emergency operation and to determine whether the design of the control room allows and supports those tasks. Final results consisted of HEDs identified during the program.

4.3.5.1 Task Identification l

Starting with generic Westinghouse ERGS, all tasks within the ERGS were identified and analyzed to I determine the instrumentation and controls required.

! All Emergency Response Guidelines and Functional l

Recovery Guidelines were task analyzed. However, these contained steps which appear in many ERGS and FRGs. In these cases the task analyses completely analyzed the step only once and referred to that analysis when the step is duplicated in other i

guidelines.

1 8eyond the ERG tasks to be analyzed, certain plant systems were referenced in the ERGS as resources to be used during emergency operation. As part of the task identi .*1ca tion , the tasks necessary to use the 1

plant systems, as they are required to be used in the

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'8EORGIA POWED COMPANY 80 ERGS, were delineated. Any instruments and controls necessary to complete these tasks were determined. In some cases the operator tasks required for specific system operation were determined using existing VEGP procedures. Where this was not the case, additional analysis required to determine system-specific tasks was performed and documented in th'e task analysis.

After the required tasks were delineated and the necessary instruments and controls identified, a two-step process was undertaken that (1) verified that the required instruments and controls were present in the control room and were of the appropriate range with the appropriate scales and labels, and (2) validated with walk throughs, and dynamic simulation that all ERGS and system-specific steps could be completed in the VEGP control room by the normal complement of operating personnel.

The Task Analysis Procedure for the CRDR involved three items:

l O Task Analysis Method, 0 Verification of Instruments and Controls; and

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GEORGIA POWE3 COMPANY 31 0 Validation of Emergency Operating Procedures 4.3.5.2 TASK ANALYSIS METHODS 4.3.5.2.1 Task Sequence Chart (See Figure 4-3)

The Task Analysis Data collection utilized a hierarchical approach. The task description was entered on the Task Sequence Charts in the order as they appeared in the Westinghouse Emergency Response Procedure Guidelines. A Review Team member (R.

Johnson) extracted tasks and steps required to complete each Emergency Response Procedure Guideline listed on a Task Sequence Chart.

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GEORGIA POWEB COMPANY 33 Sequence numbers and titles were taken directly from the Emergency Response Guidelines. The " STEP" or

" ACTION / EXPECTED RESPONSE" columns in the Emergency Response Guidelines provided the task numbers and task titles.

The " RESPONSE NOT OBTAINED" column in the Emergency Response Guidelines provide the sequence number, task number, and title in the " SEQ./ TASKS POTENTIALLY BRANCHED TO" columns of the Task Sequence Chart. The task number should be designated with a "RNO

• prefix, for ' Responses not Obtained' tasks within a given; Emergency Response Guideline.

4.3.5.2.2 Task Data Form (See Figure 4-4)

The Task Data Form was the primary data collection record for each task and was used to identify the i activities of control room operators at the task l

element level. Each row of the form constituted one task element, such that when the line entry is read left to right, the information is presented as a consistently formatted "model sentence". When all Task Data Forms had been completed by hand they were entered in the CRDR computer data base, edited, and copies made for the Summary Report. All computer data was verified against the working forms. The printed

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GEORGIA POWE3 COMPANY 33 The Task Data Forms were completed by CRDR Team members, assisted by operators or other EOP validation observers. The Task Data Forms leading data was extracted from the Task Sequence Chart. The task elements were then added by reference from the

( plant specific Emergency Operating Procedures (EOPs) j and System Operating Procedures (SOPS) used in support of. the EOPs. The " Behavior Verb" and the l "Immediate Object of Action" was filled in at this

(

stage. Reference to installed control room

! instrumentation was needed to complete this stage, and added to the TDFs along with specific instrument numbers and locations. When CRDR Team members noted any control room design problems at this point, HEDs were written.

4.3.5.2.3 Task-ERG Matrix (See Figure 4-5)

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l Some tasks were duplicated in many Emergency Responso Guidelines, this duplication was documented on the Task-ERG Matrix Forms. TDFs for every ERG step were I

prepared and checked off on the Task-EGR Matrix form to support the validation goal of covering every task in the ERGS. In the preparation of Task Data Forms where a task was duplicated in another ERG, the Task Data Form was annotated in the " Comments" section to refer to the step where a detailed Ttak Data Form

GEORGIA POWED C00EPMY p fill-in was performed. No additional Task Data Form data was entered on such duplicate task forms.

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GEORSIA POWE2 COMPANY gg 4.3.5.3 INSTRUMENTS AND CONTROLS The Task Data Forms were used along with draft EOPs to walkthru all ERGS in the control room. This helped verify the presence in the control ' room of instrumentation required to perform each task. During the walkthru the Task Data Forms were checked for each task element, verifying " Beha vior Verb" and "Immediate Object of Action" data.

The control room walkdown was conducted by CRDR Team members, John Hopkins or Riley Johnson and two operators who had completed RO or SRO training. The operators walked thru the specific instructions in the ERG and recorded the instruments and controls used to operate specific plant systems on Task Data Forms (TDF). This was not a dynamic check of the adequacy of the control room layout, but it indicated whether or not appropriate instrumentation was available in the primary control area to carry out the tasks called for in the ERGS. Since task numbers based in Emergency Response Guidelines did not map exactly to EOP numbers, the EOP step number, if different, was shown in the " Comments" section of the Task Data Form. During the verification /walkthru the suitaoility of the instrument or control to perform each task element was reviewed using the guidelines

GEORGIA PONED COMPANY 90 in Attachment 1 of the Task Analysis Procedure Any HEDs noted are in the "H.E.D. ID. NO.* column.

4.3.5.3.1 Verification of Instrumentation and Controls The process of verifying that the VEGP control room contains appropriate instruments and controls was completed in two steps. First, a determination was made as to whether the instrumentation and controls necessary to make the decisions and implement the task identified previously were present in the control room.

The second step of the verification process consisted of an examination of the instrumentation and controls located in the first step (above) to determine its human engineering suitability for the task or decision it is supposed to support. Although the control room survey examined all control room instrumentation for conformance with human engineering design criteria this verification step was required to determine if a meter, for example, has the appropriate range and scale graduations to support a particular ERG task or sys tem-s peci f ic task. This step was accomplished by Review Team personnel observing the verification. They based their determination on the task analysis HED

r GEOftGIA P000E3 COMPANY 31 principles and noted HEDs on the TDF.

1 4.3.6 INSTRUMENTATION AND CONTROL CHARACTERISTICS REVIEW In response to the NRC In-progress Audit concerns that the task analysis did not 'dentify i instrument and control (I&C) needs as compared to the I&C control room inventory, an independent review of the VEGP control room instrumentation and control characteristics was conducted. The Instrumentation and Control Characteristics Review Program identified the instrumentation, controls and c haracteris tics that were necessary for proper operator response to emergency transients. This review program first identified generic characteristics based on the Westinghouse Owners Group high-pressure reference plant design, followed by the identification of plant specific deviations. The characteristics of the installed-control room instrumentation was Justified with the development of or reference to appropriate generic or plant specific basis documentation.

r j GEORGIA POWE2 COMPANY 32 The Emergency Response Guidelines and the ERG background documents were reviewed to identify:

a) All operator tasks necessary to support the operator functions.

b) Operator information and control needs necessary to support the operator functions and major actions.

c) Plant systems necessary to provide information and control needs.

d) Plant instrumentation and controls necessary to provide information and control needs.

For the required plant instrumentation and controls identified above, characteristics were determined based on the information and control needs. The characteristics for the instrumentation included the following:

O Setpoints, 0 Units, O Range,

r T GEORGIA POWEO COMPA88Y 33 0 Resolution, O Type of Display, Characteristics for controls included the following:

O Positions, O Type of Control (e.g., varia bl e) .

From the information gathered in the characteristics review, a Required Characteristics Justification Table was developed for required instrumentation.

This table identified operator action categories and associated operator information needs, criteria, and characteristics. The basis for each action category or information need was described or a reference to other documentation was provided.

Following identification of the required characteristics the Vogtle specifics were identified.

The Vogtle specific characteristics consisted of applicable generic characteristics and plant specific deviations. To identify Vogtle specific instrumentation and controls and their associated required characteristics, the Vogtle Emergency Operating Procedures were reviewed to identify

o SEOftGIA POWEO COMPANY y deviations froe the Emergency Res ponse Guidelines.

These Vogtle specific characteristics were then entered in the Required Characteristics Justification Tables.

Generic and Vogtle specific required characteristics were reviewed and the limiting required characteristics were summarized in Characteristics Requirements Tables.

4.3.6.1 VERIFICATION The verification of the installed control board instrumentation'with respect to the above defined required instrumentation and control characteristics was performed. The CROR Team developed an inventory of Vogtle control board instrumentation and controls.

The CROR Team then compared the inventory to the Instrumentation and Control Characteristics Requirements Tables for consistency.

This verification provides assurance that the operator does in fact have the required instrumentation and controls assumed in the Westinghouse Owners Group Transient 1

Analysis for response to emergency transients.

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GEORGIA POWE."2 COMPANY 33 4.3.6.2 RESULTS The complete Instrumentation and Controls Charac teris tics Review contains proprietary information and will be submitted for NRC review under separate cover. The plant inventory and summary of deviations is presented in Appendix 6.2. Five new HEDs resulted from this rev1ww.

4.3.7 VALIDATION OF CONTROL ROOM FUNCJ1QN3 4.3.7.1 VALIDATION OF EMERGENCY OPERATING PROCEDURES The final analytical step in the task analysis was to validate t ha t the tasks delineated earlier were indeed the tasks that must be performed to carry out emergency functions and t ha t those tasks can be completed in the VEGP control room by the normal operating crew. This evaluation was accomplished in conjunction with EOP validation on the VEGP Unit 1 simulator. Specific transients were selected that required operators to use the EOPs. These transients were run on the VEGP simulator, and a VEGP operating crew performed the actions that were required by the EOPs.

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l GEORGIA POWE3 COMPANY 06 The transients run on the simulator were chosen from the list of scenarios used by the Westinghouse Owners Group to validate their ERGS on the Callaway Nuclear Power Plant Training Simulator (Summary Report -

Emergency Response Guidelines Validation Program, Westinghouse NCAP-10204, September 1982). The following specific transients were run during the simulator exercises:

0 Reactor trip, O Spurious SI, O Anticipated transient without scram (ATHS),

O Stuck open pressurizer PORV, l

0 Large break LOCA, O Small break LOCA with loss of off-site power, O Small break LOCA with out charging /SI pumps and safety injection pumps, o Failed open S/G safety valve, l

0 Steam line leak inside containment, l

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

- 4 GEORGIA POWE3 COMPANY 37 0 Steam generator tube rupture (SGTR) with secondary breaks O SGTR with a loss of heat sink, O SGTR with stuck open S/G PORV, O SGTR with RCP seal failure, O SGTR with loss of off site power, O Loss of heat sink, O Feedline break inside containment and SGTR, l 0 Loss of all feedwater, O Spurious SI followed by LOCA, 0 Natural circulation, O Loss of electrical distribution, O Steam generator atmospheric relief valve stuck open, O TMI UNIT 2 replay,

r s GEOneIA P000E3 COMPANY g3 0 Steam generator depressurization, O LOCA outside containment.

The above scenarios were developed to direct the operating crew thru all EOPs and to exercise all procedure transition points. A complete operating crew was assembled at the simulator. The crew members took their normal positions relative to the control boards. An Observation Team was assigned to record the crew's movements and to note any deviations from toe appropriate EOP. The transients were run in real time so t ha t the events in the simulator occurred in the same time frame as in the actual plant. A second run was made if needed to complete data collection.

l Two crews independently ran most scenarios. The simulator runs were video-taped and sound recorded.

The tapes served to assist post run debriefs and were saved for archival purpose. Specific analysis of the tapes was not conducted.

4.3.7.2 DATA RECORDING AND ANALYSIS Various data was recorded by the members of the Observation Team during the simulator scenarios. The movements of each crew member was traced on a control

r-GEORSIA P000E3 C000PA80Y gg room outline drawing by an observer. This information was examined to determine the main paths between panels and panel sections and to identify any significant need to access back panel indications or controls. In addition to crew movements, ' observers traced the path of the crew through the appropriate ERGS and plant systems. Notations were made of significant communication links used during each transient and any instances of crew member conflict (either physical access problems or communication problems) was noted. HEDs were written to document any human engineering problems noted due to board design, the EOPS, lay out of the control room, and the dynamic interaction of the operating crew during emergency operation.

4.3.7.3 PERSONNEL ASSIGNMENTS The task identification described in Section 4.3.5.1 of this report was characterized by extensive analysis of ERGS and emergency response systems before any walk-through validation was done. The analysis of system function and operator task were conducted by meebers of the Review Team, aided by Operations personnel.

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GEOReIA POWE3 COMPANY 10J After the pre-analysis was completed, the control room walk-throughs and simulator runs required the intermittent participation of some Review Team members. The CRDR Team Leader was responsible for scheduling crews to walk through the selected ERGS in the control room and for scheduling both crew and simulator time for transient runs in the VEGP simulator.

For the dynamic simulator validation, each crew member was tracked by a separate observer, whereas the control room walk-throughs were not as time-critical and a single CRDR Team member observed the control room personnel.

During the validation process selected scenarios were run on the plant simulator and ERG tasks were performed on the simulator by a crew of VEGP operators. An Observation Team was assigned to observe the crew's movements and to note any deviations from the appropriate Emergency Response Guidelines. The simulator runs were video-taped and sound recorded for post scenario debriefing support.

The movement of each crew member was traced on a

! control room outline drawing by an observer either l during the scenario or later during a videota pe I

review. A record was made of significant l

GEORGIA POWE2 COMPANY 101 communication links used during each transient. This was not a detailed record of all face-to-face communications in the control room. Debriefing sessions held after each scenario provided time to review actions, discuss problems, clarify communications (who, how, where), and identify HEDs relating to performing the task during dynamic simulation. A Review Team member was in the Observer Team debriefing for at least one run of each task.

During the validation, a copy of the Task-ERG Matrix was annotated to insure each task was performed in the simulator.

4.3.7.4 SIMULATOR WALKTHRU During the two week validation effort it was not l

l possible to force the dynamic scenarios thru every task in the ERGS. The remaining tasks were walked thru in the simulator by the operating crew and observed by the CRDR Review Team members E. Kozinsky and R. Johnson. The TDFs were completed for those tasks during that walkthru, discussing with the operators their actions as they were simulated.

GEORGIA POWER COMPANY 102 4.4 HED RESOLUTION PROCESS 4.4.1 HED Develooment Procedure The purpose of the HED Procedure was to provide a consistent method and documentation for HED tracking and resolution. The procedure outlined the requirements for the following items:

0 HED NUMBER: To avoid confusion with the 1981/1982 review, numbers will be assigned consecutively beginning with 1001.

O ITEM (S) INVOLVED: Describe the item (s) which are Judged to be out-of-acceptance limits. Include tag number for controls and indications, as well as name.

l 0 ORIGIN: List the guideline source document or survey and number which originated the HED.

O HED DESCRIPTION: Give clear concise details of the problem.

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e GEORGIA POWE2 COMPANY 103 0 ORIGINATOR: Signature of the person describing this HED and the date of this report.

O CATEGORY: Assigned by the CRDR Teae.

This denotes the relative severity of the discrepancy and prioritizes the HED for resolution.

O PROPOSED RESOLUTION: Describe the resolution agreed upon by the CRDR Team.

O REA NUMBER: The number assigned by document control to the Request for Engineering Assistance form when assistance is requested in resolving an HED (not used in all cases).

l 0 WORK ORDER NUMBER: The number assigned to I

the Maintenance Work Order or Request For Assistance to accomplish the proposed resolution (not used in all cases).

r GE0 ASIA POWEO COMPAffY 104 0 HED LOG: Each HED written will be entered in the HED Log. Each entry will consiet of the assigned HED number, a brief description of the HED, the entry date, and the initials of the person making the entry.

Each HED was added to the HCD tracking data base, where its status was maintained current along with additional remarks and details describing the CRDR Teams Justification for 'NO ACTION" for applicable HEDs.

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V0GTLE ELECTRIC GENERATING PLANT HUMAN ENGINEERING DISCREPANCY (NED)

HED Number Item (s) Involved:

Origin HED

Description:

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Signature Date Category:

l Proposed Resolution:

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r GEOneIA POWE1 COMPANY 108 4.4.2 Methodoloav of Determinina the Schedulina Priorities of HED Corrections The method of determining the scheduling priorities of HED corrections was inherent in the categorization of identified HEDs. The following HED categories established the scheduling goals:

O Category 1 -

(Safety Significant) -

HEDs that have caused errors in or are Judged likely to adversely affect the management of emergency conditions by control room operators.

Goal -

Category 1 HEDs are to be completed prior to Unit 1 Fuel Loading.

O Category 2 -

HEDs that are known to have caused problems during normal operation.

Goal -

Category 2 HEDs are to be completed as soon as practical but, no later than first refueling.

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GEOfteIA POtfE3 COMPANY 107 0 Category 3 -

HEDs that can be " Fixed" with simple and inexpensive enhancements, so-called " paint, t a pe , and label" (PTL) fixes. This may seem to be an implementation rather than an assessment category. However, there probably will be HEDs that the Review Team feels are very easy to fix but difficult to assess as to effect on emergency operation. This category is for such HEDs.

Goal -

The correction of Category 3 HEDs have no targeted completion date. However, due to the simple nature of these items, all are expected to be completed by fuel load.

O Category 4 -

HEDs that do not fit into Categories 1 through 3. These HEDs are Judged by the Review Team as unlikely to affect emergency operations, not documented as causing problems during normal operation, and not simple or cheap to fix. However, corrective action is recommended

GEORGIA POWEQ COMPANY 100 Goal -

The correction of Category 4 HEDs have no targeted completion date, but the team recommended to managomant that corrc;tivs action be reviewed for implementation at some time after fuel load. These items may be done 1 prior to fuel load when more economical to do so. ,

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O Category 4a -

Such a minor deviation from standards it is not expected to cause a problem. No corrective action is recommended.

Goal -

Correction of Category 4a HEDs is not planned.

It should be recognized that these completion dates i

are goals and that some changes are still pending after these dates. GPC will make all reasonable l efforts to meet these goals. A more detailed implementation status and schedule for each HED is presented in Appendix 6.3 of this report.

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GEOfteIA P000E3 COMPAffY 109 I 4.4.3 Denartures from Schedule Prioritization The departures from the schedule have been positive in nature; sixteen Category 02s and fourteen Category 04s will be completed prior to Unic One fuel load (See Appendix 6.3 for details).

4.4.4 HED Cateoorv Review Process The last aspect of the Assessment Phase was en independent HED category review. This review was in response to NRC audit concerns that the team meeting minutes did not provide sufficient auditable records.

It also increased assurance that each HED was properly categorized. The independent review was performed by an individual not on the CRDR Review Team, D. Crouch. HEDs that were identified as potentially in a less conservative category were presented to the CRDR Review Team for consideration and change as needed. H EDs identified after the HED Category Review were categorized utilizing the some algorithm as in the review process.

The HED category review was conducted to provide assurance that each HED identified during the Execution Phase of the CRDR was in fact ' properly cat.goriz d. The CRDR Team also developed more

GEORGIA PONE 2 COMPANY 110 detailed explanations of their decisions on HED categorization and resolutions.

HEDs were initially categorized using a subjective approach that reflected the consensus Judgment of the multi-disciplinary CRDR Team. This HED category review employed a systematic approach based on the assessment process identified in NUREG 0800, and NUREG 0801 (Draft).

HEDs that have been identified via the control room checklists and surveys as presented in NUREG 0700 and NUTAC 83-042 are considered to have their basis derived from human factors standards, with no additional screening for performance shaping factors

)

l necessary. HEDs identified via the Operating

( Experience Review, operator questionnaires and paoblem reports are a result of a screening process utilizing the performance shaping factors presented in NUREG 0800 (Appendix 'A' Exhibit 2-2) l l

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GEORGIA POWE~1 COMPANY 111 HEDs identified from both the above processes were evaluated with respect to the following seven l attributes and subjected to the following algorithm (Figure 4-7) to determine their significance and effects on plant safety:

ITEM 1 HEDS IDENTIFIED THROUGH THE OPERATING EXPERIENCE l

l REVIEW OR ACTUAL PROBLEMS IDENTIFIED IN THE OPERATOR QUESTIONNAIRE.

ITEM 2 HEDS IDENTIFIED DURING THE EOP VALIDATION EXERCISE.

ITEM 3 HEDS EXPERIENCED (EOP VALIDATION) OR ASSESSED (SURVEYS OR CHECKLISTS) AS HAVING A HIGH PROBA8ILITY OF CONTRIBUTING TO OPERATOR ERROR.

ITEM 4 HEDS ASSOCIATED WITH ESF SYSTEMS ITEM 5 HEDS, THAT COULD RESULT IN UNSAFE OPERATION OR VIOLATION OF A TECHNICAL SPECIFICATION.

r GEORGIA POWE2 COMPANY 113 ITEM S HEDS DETERMINED TO BE EASILY CORRECTA8LE WITH PAINT, TAPE, LASELS, ENGRAVING CHANGES OR WORK SPACE ENVIRONMENT IMPROVEMENTS.

ITEM 7 HEDS DETERMINED TO CONTRIBUTE TO THE OPERATOR MENTAL WORK LOAD (CUMULATIVE EFFECTS) RESULTING IN FATIGUE, CONFUSION OR DISCOMFORT

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GEORGIA POWE3 COMPANY 114 An additional side benefit of this review was to create an audit trail from the HED category to its resolution.

The process of category review utilized this algorithm to aid in category determination and provided some repeatability and consistency for future audits.

The evaluation of the cumulative effects of category 04 HEDs left uncorrected will be submitted as a supplemental report i

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CEORGIA PONER COMPANY 115 5.0 CRDR IMPLEMENTATION VERIFICATION PROGRAM The CRDR Implementation Verification Program as presented in this report will serve to ensure the control room, procedures and training improvements resulting from HED resolutions have been properly implemented and provide the necessary corrections.

I 5.1 RESPONSIBILITY The CRDR Team Leader shall have overall responsibility for the implementation verification i

process.

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l l 5.2 IMPLEMENTATION VERIFICATION PROCESS The process of implementation verification consists of three phases:

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0 Resolution.

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CEORGIA POWEQ COMPANY 115 5.2.1 Preoaration Phase The preparation phase consists of the following activities:

o Designating an individual to conduct the verification; o Obtaining and reviewing the CRDR HEDs and Data Bases; o Reviewing Section G of NUREG 0700.

5.2.1.1 DESIGNATE PERSONNEL The CRDR Team Leader will assign an individual as evaluator to conduct the verification of an HED. Team members or staff (D. Crouch) will conduct most

( verifications, but others may be appointed based on operating experience and understanding of the CRDR process as Judged by the Review Team Leader.

1.

5.2.1.2 OBTAIN AND REVIEW THE CRDR HEDS AND DATA BASES The HEDs identified during the CRDR shall serve as the controlling documents for this verification. The evaluator will compare the actual control room

GEORGIA POWER COMPANY 117 component, location, wording or other changes to the proposed resolution or attachments to the HED.

The HED data base will serve as a scheduling aid to track the process of the CRDR implementation.

Verification will begin in the summer of 1986 when implementation nears completion.

5.2.2 assessment Phase In the Assessment Phase, the evaluator shall perform the following:

0 Review each HED and compare the proposed resolution to the actual control room design, procedure or training improvement; i 0 Identify the applicable guideline in Section 6 of NUREG 0700 (Figure 5-1) and l evaluate if control room improvement l

corrected the HED or created a new human engineering discrepancy condition;

CEORGIA POWER COMPANY 118 0 If the actual control room improvement agrees with the HED resolution and does not create a new human engineering discrepancy, date and sign the CRDR Verification Form.

5.2.3. Resolution Phase In the Reso'lution Phase, a CRDR Team Member shall review the evaluator's comments and determine a resolution for each new or continued discrepancy. New discrepancies resulting from implementation will be treated as new HEDs and processed in accordance with CRDR Procedures.

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CEORGIA POWER COMPANY 119 CRDR IMPLEMENTATION VERIFICATION HEDS________________ Unit _____ Pa9e ___of ____

NUREG 0700 Cross Reference Section 6 ________________

_______ Change in place. .

_______Chan9e corrected the HED condition.

_______ Change does not cause an additional condition.____________________________________

Verification Completion Date:_____/_____/_____

Performed by:________________________________________

Reviewed by: ________________________________________

All actions required by the verification have been completed and approved.

______________________________Date: _________________

Review Team Leedme FIGURE 5-1

GEORGIA POWER COMPANY 120 APPENDIX 6.1 OPERATING EXPERIENCE REVIEW

SUMMARY

The Operating Experience Review process screened 333 INPO SOERs and SERs for applicability to the VEGP control room design. The INPO documents yielded 19 reports that were in turn reviewed by the CRDR Team Leader and a reactor operator.

In addition to the above, all LERs from 1980 through part of 1985 were screened, yielding 15 reports to be reviewed.

The following Operating Experiences were reviewed and resulted in HEDs:

NO.3 SOER 83-8 REACTOR TRIP SREAKER FAILURES, The 1st Out Annunciator was inadvertently reset Resolution HED 1210, The resolution was to install a flip up cover on the 1st Out Annunciator l reset push button, making it a two step j

operator action.

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GEORGIA POWER COMPANY 121 NO.8 SER 14-83 REACTOR TRIP BREAKER FAILURES, See SOER 83-8 Resolution HED-1210 Same as NO.3 above.

NO.12 SER 59-83 RESIDUAL HEAT REMOVAL (RHR) PUMP SUCTION VALVE CLOSURE DUE TO CONTROL CIRCUIT DESIGN, unexpected valve operation when power was restored with no low flow alarm.

Resolution HED 1235, Provide an RHR low low flow alarm in the control room (Annunciator, or Protous or the ERF Computer).

NO.13 SER 60-83 LOSS OF RESIDUAL HEAT REMOVAL

.: COOLING DURING REACTOR VESSEL DRAIN DOWN, unreliable level indication.

Resolution HED 1219, Install temporary instrumentation following NSAC-52 guidelines

GEORGIA POWE3 COMPANY 122 NO.14 SER 78-83 INADEQUATE CONTROL OF COMPUTER INPUTS, computer alarm inputs deleted due to a lack of control.

Resolution HED 1234, Establish administrative controls for the removal of computer alarms by the operator.

NO.15 SER 71-84 RESIDUAL HEAT REMOVAL PUMP DAMAGE CAUSED BY OPERATION WITH SUCTION VALVE CLOSED, no alarms to warn operators of a low flow ,

condition.

Resolution HED 1235, Same as NO.12 above.

NO.16 SER 79-84 LOSS OF SHUTDOWN COOLING DUE TO INACCURATE LEV 2L INDICATION, during maintenance l outages.

Resolution HED 1219, Same as NO.13 above.

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GEORGIA POWER COMPANY 123 NO.24 LER 339-83038 INADEQUATE RCS LEVEL INDICATION AND MONITORING Resolution HED 1219, Same as NO.13 above.

NO.29 LER 334-84002 INADVERTENT OPERATION OF THE MANUAL SI PUSH BUTTON INSTEAD OF RESET PUSH BUTTON Resolution HED 1019, The Reactor Trip, Safety Injection and Containment Isolation switches are color coded and located away from the routine controls. Covers are not considered necessary. But the Safety Injection and Steam Line Isolation controls will be colored red.

NO.33 LER 395-84037 STEAM GENERATOR LEVEL INDICATION.

l l COLD (WR) VS. HOT (NR) HOT CALIBRATIOt:

l Resolution HED 1233, The Steam Generator discrepancy

, will be added to the operator Training Program, and the plant data book will l provide information for correcting " COLD" l

l

GEORGIA POWE[D COMPANY 124 calibrated to corresponding " HOT" calibrated Steam Generator levels.

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l t

l INDUSTRY DOCUMENT APPLICA3ILITY TO VEGP CRDR 125 INDUSTRY DOCUMENTS REVIEMED FOR THE VEGP CRDR OPERATING EXPERIENCE REVIEW SOER # APPLICABILITY 82-1 NO-BWR 82-2 NO-BWR 82-3 NO-AFW OPERATIONS OUTSIDE CONTROL ROOM 82-4 NO-DISSIMILAR SYSTEM DESIGN RHR & CNMT SPRAY CROSSCONNECT 82-5 YES-LS RCP SEAL INSTRUM ENT AT ION ADEOUA'E 82-6 YES- S PORV & SAFETY VA .VE INST ADEOUA'E 82-7 NO-TRAINING & PROCEDURE 3 82-8 NO-OPERATIONS OUTSIDE CONTROL ROOM 82-9 NO-OPERATIONS OUTSIDE CONTROL ROOM 82-10 NO-FIRE PROTECTION OUTSIDE CONTROL ROOM 82-11 NO-OPERATIONS OUTSIDE CONTROL ROOM 82-12 NO-NOT OPERATIONS RELATED 82-13 NO-OPERATIONS OUTSIDE CONTROL ROOM 82-14 . NO-8WR 82-15 NO-OPERATIONS OUTSIDE CONTROL ROOM 82-16 NO-OPERATIONS OUTSIDE CONTROL ROOM 83-1 NO-OPERATIONS OUTSIDE CONTROL ROOM 83-2 NO-PROCEDURES & TRAINING 83-3 NO-OPERATIONS OUTSIDE CONTROL ROOM 83-4 NO-BWR 83-5 NO-PROCEDURES ONLY 83-6 NO-CONTROL DESIGN & PROCEDURES 83-7 NO-I & C GROUP MAINTENANCE 83-8 __

YES-CONTROL ROOM ALARMS 83-9 NO-OPERATIONS OUTSIDE CONTROL ROOM 84-1 NO-AQUATIC LIFE 84-2 NO-PROCEDURES ONLY 84-3 .

NO-OPERATION OUTSIDE CONTROL ROOM 84-4 '

YES-IS FEED & STEAM FLOW INST ADEOUATE NO-MECHANICAL OUTSIDE CONTROL ROOM 84-5 84-6 NO-OPERATIONS OUTSIDE CONTROL ROOM 84-7 NO-OPERATIONS OUTSIDE CONTROL ROOM 85-1 NO-OPERATIONS OUTSIDE CONTROL ROOM 85-2 YES-CONTROL SW-LABELS

l IMOUSTRY DOCUME14T APPLICASILITY TO VEGP CRDR 126 SERN APPLICABILITY 1-82 NO-CONTROL CKT 3-82 NO-MECH PROCEDURE 4-82 NO-COMPONENT FAILURE 5-82 NO-MAINTENANCE ERROR 6-82 NO-RELAY FAILURE 7-82 NO-COMPONENT FAILURE 8-82 YES-ALARM SEALIN CKT 9-82 NO-COMPONENT FAILURE l 10-82 NO-SGTR & SOV 11-82 NO-CORROSION 12-82 NO-TRANSMITTERS 13-82 NO-FREEZE PROTECTION 14-82 NO-OPERATIONS NOT IN C/R 15-82 NO-EFFLUENT MONITORING 16-82 NO-H2 LEAKS-MAIN GEN 17-82 NO-S.G. CHEM 18-82 NO-HANGERS l

19-82 NO-LIMITORQUES 20-82 NO-SYSTEM CLOSURE INSTRUCTIONS 21-82 NO-STUD FAILURE 22-82 NO-MATERIAL SELECTION 23-82 NO-PROTECTION SYSTEM OESIGN 24-82 NO-IGSC 25-82 NO-COMMUNICATIONS 26-82 NO-DESIGN NOT IN C/R 27-82 NO-OPERATIONS NOT IN C/R 28-82 NO-TANK TEMP 29-82 NO-OPERATION NOT IN C/R -

! 30-82 NO-OPERATION NOT IN C/R 31-82 NO-INST FAILURE 32-82 NO-FOREIGN MATERIALS 33-82 NO-RX FUEL 34-82 NO-COMPONENT FAILURE 35-82 NO-FLOW VIBRATION 36-82 NO-IN CORE MONITOR l 37-82 NO-COMPONENT FAILURE 38-82 NO-OPERATION NOT IN C/R 39-82 NO-COMPONENT FAILURE 40-82 NO-VALVE FAILURE 41-82 NO-PIPE EROSION t 42-82 NO-COMPONENT SELECTION l 43-82 NO-FUEL-IGSC l 44-82 NO-RCS FLOW 45-82 NO-INVERTER FAILURE 46-82 NO-FIRE BARRIERS 47-82 NO-MSIV's BWR's 48-82 NO-RCS THERMAL SLEEVES 49-82 NO-MOV OPERATION 50-82 NO-SAFETY VALVES 51-82 NO-OPERATIONS NOT IN C/R

, _ _ _ - - - - _ - ~ . . _ _ _ _ . .__ . _ . _ _ - _ __ _ _ _ _ -

F INDUSTRY DOCUMENT APPLICA9ILITY TO VEGP CRDR 127 52-82 NO-FIRE PROTECTION DESIGN 53-82 YES-CONTROL ROOM INST COMMENT 84 54-82 NO-COMPONENT FAILURE 55-82 NO-NOT C/R RELATED 56-82 NO-COMPONENT FAILURE 57-82 NO-OPERATIONS NOT IN C/R 58-82 NO-COOLER FAILURE 59-82 NO-DESIGN ELECTRICAL 60-82 NO-EXCITER FAILURE 61-82 NO-FOREIGN OBJECTS 62-82 NO-DESIGN ERROR 63-82 NO-VALVE FAILURE 64-82 NO-COMPONENT FAILURE 65-82 NO-RX FUELS 66-82 NO-BOLT FAILURE 67-82 NO-D.G. BEARING FAILURE 68-82 NO-RELAY FAILURE 69-82 NO-BWR-IGSC 70-82 NO-D.G. FIRE 71-82 NO-RELAY FAILURE 72-82 NO-NIS CALIBRATION 73-82 NO-VALVE MAINTENANCE 74-82 NO-RAD MONITOR FAILURE 75-82 NO-OPERATIONS NOT IN C/R 76-82 NO-POWER SUPPLY FAILURE 77-82 NO-RELAY - MISOPERATIONS 78-82 NO-DESIGN ERROR 79-82 NO-DESIGN ERROR 80-82 NO-VALVE DESIGN SERS APPLICABILITY 1-83 NO-F.W. CONTROL FAILURE 2-83 NO-VALVE APPLICATION 3-83 NO-BWR - IGSC 4-83 NO-RELAY FAILURE 5-83 NO-OFF-SITE FIRE 6-83 NO-WORK ACTIVITIES 7-83 NO-F.W. LINE CRACKING 8-83 NO-SPENT RESIN 9-83 NO-ENVIRON OVAtIFICATION 10-83 NO-FLOW VI8' N 11-83 NO-VALVE FAi 12-83 NO-BWR-PUMP SwA FAILURE 13-83 NO-NO-BWR-RHR FAILURE 14-83 YES-TRIP BKR FAILURE COMMENT S1 15-83 NO-FUEL HANDLING 16-83 NO-BWR-VACUUM BREAKERS 17-83 NO-GENERATOR FAILURE 18-83 NO-TURBINE-CONTROL VALVE 19-83 NO-8WR-CONTROL ROOM OPERATOR ERROR 20-83 NO-CHECK VALVE FAILURE

INDUSTRY DOCUMENT APPLICABILITY TO VEEP CRDR 128 21-83 NO-D.G. LOGIC 22-83 YES-C/R WRONG UNIT COMMUNICATIONS 23-83 NO-VALVE FAILURE 24-83 YES-WRONG RAI W COMMENT #4 25-83 NO-D.G. STA RT _OGIC 26-83 NO-BOLT FAILURE 27-83 NO-VARIOUS COMPONENT FAILURES 28-83 740-BWR-8KR FAILURE 29-83 NO-OPERATIONS NOT IN C/R 30-83 NO-RX VESSEL 31-83 NO-FUEL HANDLING 32-83 NO-CRDR UNLATCHED 33-83 NO-CONTROL SW FAILUrc 34-83 NO-RELAY FAILURE 35-83 NO-BWR-CNMT INTG 36-83 YES-LOSS OF F.W 37-83 NO-BWR - REMOTE S.D. PANEL 38-83 NO-LOSS OF OFFSITE PWR 39-83 NO-LOOP STOP VALVE 40-83 NO-IGSC 41-83 NO-H2 FIRE 42-83 NO-OYSTERS & MUSSELS 43-83 NO-FIRE PROTECTION 44-83 NO-LOOSE PART 45-83 NO-MOV FAILURE 46-83 NO-I & C 47-83 NO-BIO-FOULING 48-83 NO-D/G ROOM VENTS 49-83 NO-CO2 CAUSED FAILURES 50-83 NO-GE MODE SW 51-83 NO-GENERIC VALVE ALIGNMENT 52-83 NO-BOLT FAILURE 53-83 NO-BWR-ELECT FAILURE 54-83 NO-CL2 RELEASE 55-83 NO-BWR-RHR 56-83 NO-TANK DAMAGE 57-83 NO-8.A. PIPE CRACKS 58-83 YES-PORV INDICATION COMMENT 82 59-83 YES-VALVE CON"ROLS 60-83 y,, -

YES-RX LEVEL :NDICATION 61-83 NO-CONDUIT FAILURE 62-83 NO-RCP FAILURES 63-83 NO-FAN FAILURES 64-83 NO-SMALL BORE PIPE 65-83 NO-AFW PUMP BEARINGS 66-83 NO-EXCITER FIRE 67-83 NO-TRAVELLING SCREENS 68-83 NO-PIPE LINING 69-83 NO-ACID-INJURY 70-83 NO-D.G. CONTROL VENT 71-83 NO-D.G. CONTROLS 72-83 NO-80LT CORROSION

r-INDUSTRY DOCUMENT APPLICA'JILITY TO VEGP CROR 129 73-83 NO-LOSS OF AC 74-83 NO-S/G TUBE CRACKS 75-83 NO-CKT BKRS 76-83 NO-REF LEG FAILURES 77-83 NO-RHR VALVE FAILURES  !

78-83 YES-PLANT COMPUTER 79-83 NO-FUEL DAMAGE BWR 80-83 NO-D.G. CONTROL CRT 81-83 NO-CHECK VALVE SELECTION 82-83 NO-D.G. LOAD SEG.

83-83 NO-ORGANIC MATERIALS-RCS i 84-83 NO-CONTROL ROD MISALIGN-8 & W 85-83 NO-8WR-SCRAM TIMING 86-83 NO-CONTROL ROD MISALIGN 87-83 NO-INST AIR FAILURES SERS APPLICABILITY 1-84 NO-COMPONENT VI8 RATION 2-84 NO-FUEL OIL TANKS 3-84 NO-FIRE PROTECTION 4-84 NO-AIR OP VALVE 5-84 NO-AFW BACK LEAKAGE 6-84 NO-HEAVY WATER LEAK '

7-84 NO-MOV LUBRICATION 8-84 NO-PRIMARY PLANT H2 FIRES 9-84 NO-PORY LOGIC 10-84 NO-GE LINE STARTER 11-84 NO-DEPT COMMUNICATIONS 12-84 NO-HTR DRN PUMP EXPANSION FAILURE 13-84 NO-CKT BKR FAILURE 14-84 NO-BWR TORUS CRACK 15-84 NO-INTAKE BAY ICE 16-84 NO-ASIATIC CLAMS 17-84 NO-M.S. NRV FAILURE i 18-84 NO-D.G. RELAY PROBLEMS 19-84 NO-WATER IN C/R 20-84 NO-RHR VALVE BINDING 21-84 NO-PORV FAILURE 22-84 NO-8WR SCRAM TIMES 23-84 NO-LOAD REJECTION 24-84 NO-TRANSFORMER FIRE 25-84 NO-JARRED RELAYS-RX TRIP 26-84 NO-MFIV FAILURE 27-84 NO-D.G. FAILURE 28-84 NO-REFUELING 29-84 NO-DEGRADED LTOP 30-84 NO-CNMT SPRAY BY I & C TECH 31-64 NO-RX TRIP - LIGHTNING 32-84 NO-RCS-COMTAMINATION I 33-84 NO-EHC FAILURE 34-84 NO-GEN GROUNDING i

(

INDUSTRY DOCUMENT APPLICAGILITY TO VEGP CRDR 133 I 35-84 NO-GEN FAILURE 36-84 NO-SOV MAINTENANCE 37-84 NO-SLOW RX TRIP BKR 38-84 NO-TANK DAMAGE 39-84 NO-SI PUMP FAILURE 40-84 NO-VITAL & D.C. BUSES 41-84 NO-RTD BYPASS VALVES 42-84 NO-SYSTEM INTERDEPENDENCY 43-84 NO-IN CORE TUBE FAILURE 44-84 NO-H2 EXPLOSION - GENERATOR 45-84 NO-VALVE STEM FAILURE 46-84 NO-CIRC WATER - LOW TIDE 47-84 NO-RCP DAMAGE 48-84 NO-8KR DAMAGE 49-84 NO-BWR - CHECK VALVES 50-84 NO-PLANT FLOODING 51-84 NO-RCP DAMAGE 52-84 NO-GENERATOR FAILURES 53-84 NO-SENSING LINE FAILURE 54-84 NO-WELD FAILURE 55-84 NO-CAST IRON CORROSION 56-84 NO-PLANT STATUS CONTROL 57-84 NO-FIRE PROTECTION 58-84 NO-SAFETY VALVE FAILURE M.S.

59-84 NO-SAFETY VALVE - SETPOINTS ,

60-84 NO-PERSONNEL CONTAMINATION 61-84 NO-GLYCOL INTRUSION (RCS) 62-84 NO-INCORE PROBE WITHDRAWAL 63-84 NO-BWR - OVER PRESSURE 64-84 NO-BWR - MSIV FAILURE 65-84 NO-TOTAL LOSS OF AC 66-84 NO-FUEL ASSEMB FLOW BLOCK I 67-84 NO-MOV FAILURES 68-84 NO-8WR - CORE SPRAY 69-84 NO-F.W. HAMMER 70-84 NO-DIESEL GENERATOR INSULATION '

71-84 YES-RHR SUCTION VALVE CLOSURE 72-84 NO-SEAL CAVITY SEAL RING FAILURE 73-84 NO-MICRO-8IO-CORROSION 74-84 NO-SER WTR PMP FAILURE 75-84 NO-VALVE BINDING - HPSI 76-84 NO-LOSS OF ALL SITE POWER 77-84 NO-MAINTENANCE ON PRESSURIZED SYSTEMS 78-84 NO-DIESEL GEN FAILURE ,

79-84 YES-LOSS OF S.D. COOLING RX VESSEL LEVEL 80-84 NO-RCS TO RWST 81-84 YES-SIMULATOR - C/R DIFFERENCE l 82-84 NO-RADIOACTIVE OBJECTS 83-84 NO-ST8Y GAS TREATMENT 84-84 NO-PORV COMPONENT FAILURE 85-84 NO- F.W. LINE CRACKING i

86-84 NO-INJURY - ELECTRICAL SHOCK 1

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

r--

INDUSTRY DOCUMENT APPLICA2ILITY TO VEOP CRDR 131 l

87-84 NO-BWR - F.W. HTR LEVEL CONTROL 88-84 NO-EXTRACTION STMLINE BRK 89-84 NO-RCP - BOLT FAILURE l 90-84 NO-FIRE-COOLING POWER SWGR l 91-84 NO-STEAM DUMP FAILURE - (OPEN)

NO-FUEL BLOG SEAL 92-84 93-84 NO-BWR - VESSEL INTERNALS l

SERS APPLICABILITY

! 1-85 NO-BWR - DRYWELL 2-85 NO-VESSEL HEAD LIFT 3-85 NO-D.G. RELAY FAILURES 4-85 NO-FATAL FALL OUTSIDE C/R 5-85 NO-THERMAL FATIGUE 6-85 NO-H2 FIRE 7-85 NO-BATTERY PROBLEMS i

8-85 NO-FIRE DAMPERS 9-85 NO-D.G. RELAY FAILURE 10-85 NO-RX TRIP TEST EQUIP 11-85 NO-FOX 8ORO PWR SUPPLY 12-85 NO-UPPER HEAD INJECTION PNCB.

13-85 NO-LOSS OF OFF-SITE POWER 14-85 NO-GEN RELAY FAILURE 15-85 YES-CONTROL PANEL INDICATOR 16-85 NO-D.G. FAILURE 17-85 NO-IRRADIATION STRESS CORROSION 18-85 NO-TRANSMISSION 19-85 NO-RCP SEAL FAILURES 20-85 NO-D.G. TRIPS 21-85 NO-FATAL FALL 22-85 NO-AFW BACK LEAKAGE 23-85 NO-PIPE EROSION 24-85 NO-POWER TILTS - NOT DESIGN RELATED 25-85 NO-D.G. FAILURE 26-85 NO-LOSS OF AC POWER 27-85 NO-PIPE BREAK 28-85 NO-SI PUMP DEGRADATION 29-85 NO-LOSS OF F.W.

30-85 NO-FATALITY - REFUELING 31-85 NO-REFUELING 32-85 NO-INTERNAL FLOODING 33-85 NO-PREMATURE CRITICALITY 34-85 YES-WATER IN C/R

, 35-85 NO-DIESEL GENERATOR START 36-85 NO-FATAL BURNS 37-85 NO-6WR - PREMATURE CRITICALITY 38-85 NO-BWR - ADS OPERATION 39-85 NO-DECON FACILITY FIRE

IN00STRY DOCUMENT APPLICAOILITY TO VEGP CRDR 132 LER'S FROM 1980 THROUGH 1985 WERE REVIEWED THE FOLLOWING LER's HAVE BEEN SELECTED FOR CRDR TEAM REVIEW:

PRE 1984 LER REVIEW LER8 CAUSE 316-83095 FAILURE T'O RECOGNIZE ALARM - AUDIBLE FOR ONLY ONE SECOND 348-83019 IMPROPER PRESSURIZER CHANNEL SELECTION 338-82021 CONTROL SW SLIPPED RE-ENERGIZED PUMP 339-80008 PROTECTION CHANNEL LABELING 339-83038 INADEQUATE MONITORING OF RCS LEVEL 282-82028 COMPUTER - ANNUNCIATED CONDITION WENT UNRECOGNIZED 282-83012 OPERATOR DISTRACTED BY ANOTHER ALARM 282-83029 D.G STATUS POST 1984 REVIEW 327-83104 OPERATOR FATIGUE

(

334-84002 OPERATED SI (SET NOT RESET) 250-84003 INADVERTENTLY OPERATED RT8-A WITH 8YPASS BREAKER OPEN 304-84001 MISOPERATION OF RTB's 395-84037 STEAM GENERATOR COLD CALIBRATION 305-84021 TANK SELECTOR SWITCH SEE SER8 15-85 483-84034 CONFUSING ALARM I

l. . ._ __. _ ___ - .. _ . -- _ . . _ _ . _ _ ___-

CECRGIA POWER COMPANY 133 APPENDIX 6.2 INSTRUNENTATION AND CONTROL CHARACTERISTICS REVIEN AND INVENTORY l

l l

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GEORGI A POWE*! COMPANY 134 CONTROL ROOM INVENTORY OF INSTRUMENTATION IDENTIFIED IN THE VEGP ICCR WEST INSTRUMENTATION INSTRUMENTATION UNITS MIN MAX RESOLUTION ACC NO. NUMBER NAME

=============== =============== ========== ====== ======= ========== ==

001 TSLB-3 SI ACTUATED N/A N/A N/A N/A N/A BPLB WINDOW 002 ALB09-A4 SI ANNUNCIATORS N/A N/A N/A N/A N/A 003 ALB GROUP 1 & 4 CNMT ISO PHASE N/A N/A N/A N/A N/A A MONITOR LIGHTS 004 CNMT ISO PH 8 NO ISO OCCURS N/A N/A N/A N/A N/A ON PHASE 8 005 TSL8-4 CONTAINMENT N/A N/A N/A N/A N/A SPRAY STATUS 006 TSL8-1 LOW STMLINE N/A N/A N/A N/A N/A PRESS SI SIGNAL STATUS 007 TSL8-3 LOW PRZR PRESS N/A N/A N/A N/A N/A SI SIGNAL STATUS 008 1-LI-0990A REFUELING WATER % 0 100 2 3.7 STORAGE TANK NOTE 1 009 AL806-E5 RWST EMPTY N/A N/A N/A N/A N/A ALARM 010 1-FI-0918 SAFE INJ PUMP GPM 0 800 20 3.6 P6003 DISCH NOTE 1 011 1-FI-0917A CVCS CHG PMP TO GPM 100 1000 20 3.7 80R INJ TK V6 NOTE 5 NOTE 1 012 1-PI-0947 80RON INJECT PSIG 0 3000 20 3.0 TANK 013 1-PI-0919 SAFE INJ PUMP PSIG 0 2000 50 3.0 P6003 DISCH NOTE 2 NOTE 6 014 1-NI-00418 POWER RANGE- 1  % FULL 0 120 2 5.2

% FULL POWER POWER NOTE 1 015 1-NI-00368 INTERMEDIATE AMPS 10E-11 10E-3 1 10.2 RANGE-2 016 1-NI-0035D INTERMEDIATE DPM .-5 5 .1 N RANGE-1 STRT UP AVAIL l

GEORGIA POWER COMPANY 135 CONTROL ROOM INVENTORY OF INSTRUMENTATION IDENTIFIED IN THE VEGP ICCR WEST INSTRUMENTATION INSTRUMENTATION UNITS MIN MAX RESOLUTION ACC NO. NUMBER NAME

========================================================================e 016 1-NI-0036D INTERMEDIATE DPM .-5 5 .1 N RANGE-2 STRT UP AVAIL 017 1-NI-00328 SOURCE RANGE-2 CPS 10E0 10E6 1 11.0 COUNT RATE 018 1-NI-0032D SOURCE RANGE-2 DPM .5 5 .1 N STRT UP RATE AVAIL 019 N/A ROD BOTTOM N/A N/A N/A N/A N/A LIGHTS 020 1-RE-0002 AREA MON MR/h 10E-1 10E4 DIGITAL >20.0 CONTAIN OP LEVEL 020 1-RE-0005 AREA MON MR/h 10E-3 10E11 DIGITAL >20.0 CONTAIN OP LEVEL 021 1-RE-0019 STEAM GENERATOR UCI/cm3 4E-7 4E-2 DIGITAL >20.0 LIQUID 022 1-RE-0021 STM GEN BLWDN UCI/cm3 4E-7 4E-2 DIGITAL >20.0 TO CONDENSER 023 1-RE-12839A SJAE & STM DKG N/A N N AVAIL DIGITAL >20.0 EXH RAD MCNITOR AVAIL 023 1-RE-128398 SJAE & STM PKG N/A N N AVAIL DIGITAL >20.0 EXH RAD MONITOR AVAIL 023 1-RE-12839C SJAE & STM PKG N/A N N AVAIL DIGITAL >20.0 EXH RAD MONITOR AVAIL 024 1-RE-0024A SELECT COMP UCI/cm3 1E-10 1E-5 DIGITAL >20.0 CUBICLE 024 1-RE-00248 SELECT COMP UCI/cm3 SE-7 SE-2 DIGITAL >20.0 CUBICLE 025 1-RE-13119 MAIN STEAM LINE N/A N N AVAIL DIGITAL >20.0 MON AVAIL 026 1-RE-12442A PLANT VENT UCI/cm3 1E-11 1E-6 DIGITAL >20.0 026 1-RE-124428 PLANT VENT UCI/cm3 1E-11 1E-6 DIGITAL >20.0 026 1-RE-12442C PLANT VENT UCI/cm3 SE-7 SE-2 DIGITAL >20.0

CEORGIA POWER COMPANY 136 CONTROL ROOM INVENTORY OF INSTRUMENTATION IDENTIFIED IN THE VEGP ICCR WEST INSTRUMENTATION INSTRUMENTATION UNITS MIN MAX RESOLUTION ACC NO. NUMBER NAME

==== =============== =============== ========== ====== ======= ========== =====e 027 1-AI-12979 CONTAIN H2  % 0 10 .1 N MONITOR TRN A AVAIL 027 1-AR-12979 CONTAIN H2  % 0 10 .1 N MONITOR TRN A AVAIL 028 1-PI-0934 CONTAINMENT PSIG 0 80 1 3.0 NOTE 1 029 1-LI-0764 CONTAIN EMERG  % 0 100 2 3.7 FLOOR DRNS NOTE 1 LEVEL 030 1-FI-0930 SPRAY ADDITIVE GPM 0 800 5 3.2 TANK IN 031 1-LI-0931A SPRAY ADDIT TK  % 0 100 2 3.7 T6001 LEVEL NOTE 3 NOTE 6 032 1-PI-0408 REAC COOLANT PSIG 0 3006 50 3.0 LOOP 1 HOT LEG NOTE 1 033 1-TI-0412 REAC COO LOOP 1 DEGREE F 530 630 2 3.6 TEMP AVERAGE NOTE 2 034 CORE EXIT T/C T/C's DEGREE F 0 2400 .1 N AVAIL 035 1-UI-13134A RCS SU8 COOLING DEGREE F N N AVAIL N AVAIL N MONITOR AVAIL AVAIL l

036 1-TI-0413A REAC LOOP 1 DEGREE F 0 700 10 3.7 WIDE RANGE HOT NOTE 1 l

037 1-TI-04138 REAC LOOP 1 DEGREE F 0 700 10 3.7 WIDE RANGE COLD NOTE 1 038, 1-LR-1310 REACTOR VESSEL  % 60/0 120 1/2 3.3 39, WATER LEVELS NOTE 1 40 041 1-TE-173 RCP #1 SEAL DEGREE F N N AVAIL NOTE 2 N TEMP AVAIL AVAIL 042 1-FI-0414 REAC COOLANT  % 0 120 2 3.0 LOOP 1 042 1-FI-0444 REAC COOLANT  % 0 120 2 3.0 LOOP 4

GEORGIA POWER COMPANY 137 CONTROL ROOM INVENTORY OF INSTRUMENTATION IDENTIFIED IN THE VEGP ICCR WEST INSTRUMENTATION INSTRUMENTATION UNITS MIN MAX RESOLUTION ACC NO. NUMBER NAME

==== =============== =============== ========== ====== ======= ========== =====e 043 1-PI-0455A PRESSURIZER PSIG 1700 2500 10 2.5 VAPOR NOTE 2 044 1-TI-0453 PRESSURIZER DEGREE F 100 700 10 3.7 LIQUID 045 1-LI-0459A PRESSURIZER  % 0 100 2 3.6 NOTE 1 046 1-TI-0468 PRESSURIZER DEGREE F 50 300 5 3.7 RELIEF TANK 047 1-LI-0470 PRESSURIZER  % 0 100 2 3.7 RELIEF TANK NOTE 2 NOTE C 048 1-PI-0469 PRESSURIZER PSIG 0 100 2 3.0 RELIEF TANK NOTE 2 NOTE C 049 1-TI-0449 PRESSURIZER DEGREE F 50 400 10 3.7 POWER RELIEF 050 1-TI-0464 PRESSURIZER DEGREE F 50 400 10 3.7 i SAF3TY VALVE DISC.4 051 1-FI-0618A RESID HT REMOV GPM 0 5000 100 3.6 LP RET BYPASS A NOTE 2 052 1-PI-0614 RESID HT REMOV PSIG 0 800 20 3.0 PUMP 1 DISCH NOTE 2 053 AL806-A1 & S1 RHR PUMP DISCH N/A N/A N/A N/A N/A HIGH PRESS ALARM 054 1-FI-0183A EMERG 80 RATION GPM 0 150 2 3.2 055, 1-FR-0110 BORIC ACID  % 0 160/40 2/1 2.8/3.0 67 BLEND CONTROL NOTE 5 NOTE C 056 1-TI-0103 BORIC ACID TANK DEGREE F - 50 150 2 3.7 T4003 NOTE 5 NOTE 3 NOTE C 057 1-FI-0121C CHARGING LINE GPM 0 200 10 3.7 NOTE 5 NGTE 2 058 1-FI-0142A REAC COOLANT GPM 0 20 0.5 3.7 PUMP 4 SEAL WATER

CEORGIA POWER COMPANY 138 CONTROL ROOM INVENTORY OF INSTRUMENTATION IDENTIFIED IN THE VEGP ICCR WEST INSTRUMENTATION INSTRUMENTATION UNITS MIN MAX RESOLUTION ACC NO. NUMBER NAME

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059 1-FI-0132C LETDOWN FLOW GPM 0 200 5 3.7 060 1-FI-0406A REACTOR HEAD GPM 0 150 2 3.7 LETDWN LINE 061 1-FR-0156 REAC COOL PMP gal 0 1.0 .02 3.4 1AND2 L RANGE NOTE 5 LK 062 1-FR-0158 REAC COOL PMP GPM 0 6.0 .2 3.4 3AND4 H RANGE NOTE 3' LK 063 1-PDI-0150 REAC COOLANT PSID 0 400 10 3.0 PUMP 4 NO 1 SEAL 064 NOTE 4 RCP SEAL N/A N/A N/A N/A N/A INJECTION SUPPLY TEMP 065 1-PI-0120A CHARGING HEADER PSIG 0 3500 50 3.0 066 1-LI-0185 VOL CONTROL  % 0 100 2 3.7 TANK 068 1-PI-0131A LO PRES LETDWN PSIG 0 600 10 3.0 069 1-PI-0124 EXCES LETOWN PSIG 0 250 5 3.0 HEATEXCH DISCH 070 ZLB-12,13,&14 A8 BREAK DETECT N/A N/A N/A N/A N/A SYS STATUS LIGHT 071 1-FT-19052 RCP CCW THERMAL N/A N/A N/A NOTE 4 N/A 8ARRIER FLOW 072 1-FE-1929 CCW FLOW TO RHR N/A N/A N/A NOTE 4 N/A HX's 073 1-PI-1874 COMPO CW PUMP PSIG 0 200 5 3.0 TRAIN A DISCH 074 1-PI-1977 AUX COMPO CW PSIG 0 200 5 3.0 PMPS DISCH 075 1-FI-1876 COMPO CW PUMP GPM x 10E2 0 150 2 3.6 TRAIN A DISCH

r CEORGIA POWER COMPANY 139 CONTROL ROOM INVENTORY OF INSTRUMENTATION IDENTIFIED IN THE VEGP ICCR WEST INSTRUMENTATION INSTRUMENTATION UNITS MIN MAX RESOLUTION ACC NO. NUMBER NAME

========================================================================e 076 1-TE-1967 ACCW SUPPLY DEGREE F N N AVAIL NOTE 2 N TEMP AVAIL AVAIL 077 ALBO4-83,4,5,&6 ACCW RCP COOLER N/A N/A N/A N/A N/A FLOW ANNUNCIATOR 078 1-PI-9361 INSTR AIR DRYER PSIG 0 150 2 3.0 TO SCS EQUIP 079 1-PI-1636 NUC SERV CW PMP PSIG 0 200 5 3.0 TRAIN A DISCH 080 1-FI-1640A NUC SERV TRAIN GPM X10E3 0 25 .5 3.6 A RETURN FLOW 081 1-PI-0514A STM GEN LOOP 1 PSIG 0 1300 20 3.0 STM NOTE 1 082 ALB13-F1 STEAM PRESSURE N/A N/A N/A N/A N/A RATE ALARM 083 1-LI-0517 STM GEN LOOP 1  % 0 100 2 3.6 NOTE 1 084 1-LI-0501 STM GEN LOOP 1  % 0 100 2 3.6 WIDE RANGE NOTE 1

, 085 1-SI-5316 SGFPT A SPEED RPM X10E3 0 8 .2 N l

TACH IND RMT NOTE 3 AVAIL N

086 1-PI-0508 FEEDWTR PUMP PSIG 200 1500 20 3.0 DISCH 087 1-FI-0510A STM GEN LOOP 1 MPPH 0 5 .1 4.0 FEEDWTR 088 1-PR-6292 LPT A & B PSIG 0 30 0.5 2.6 EXHAUST HOOD NOTE 2 PRESS N 089 1-FI-5150A AUX FEEDWTR GPM 0 500 10 3.6 SUPP TO STM GEN NOTE 5 4

090 1-SI-15109A AUX FW TURB RPM x10E3 0 6 .1 N SPEED AVAIL i

l

CEORGIA POWER COMPANY 140 CONTROL ROOM INVENTORY OF INSTRUMENTATION IDENTIFIED IN THE VEGP ICCR WEST INSTRUMENTATION INSTRUMENTATION UNITS MIN MAX RESCLUTION ACC NO. NUMBER NAME

=============== =============== ========== ====== ======= ========== ==

091 1-PI-5107A AUX FEED PMP TD PSIG X10 0 200 5 3.0 P4001 FW DISCH NOTE 1 092 1-LI-5101 CONDENSATE  % 0 100 2 3.7 STORAGE TANK 1 NOTE 1 093 1-JI-40132 GENERATOR A-C MEGA 0 1500 20 1.0 JI-G1HM NOTE 2 094 1-PI-6338 HYDRAULIC FLUID PSIG x10E3 0 2 .5 N PRESSURE AVAIL 095 1-JI-40113 DG1A WATT KILOWATTS 0 10E4 200 1.0 OUTPUT NOTE 2 095 1-JI-40114 DG18 WATT KILOWATTS 0 10E4 200 1.0 OUTPUT NOTE 2 096 1-EI;401378 DG1A OUTPUT AC VOLTS 0 5000 100 1.0 ,

VOLTAGE NOTE 2 096 1-EI-401388 DG18 OUTPUT AC VOLTS 0 5000 100 1.0 VOLTAGE NOTE 2 097 N/A 13.8KV BUS VOLTS 0 18000 200 1 VOLTAGE 098 N/A 13.8KV BUS HZ 57 61 .5 1 FREQUENCY 099 N/A 4.16KV BUS VOLTS 0 5000 10 1 VOLTAGE 100 N/A 480 VOLT BUS N/A N/A N/A N/A N/A POTENTIAL LIGHTS 101 N/A AC EMERGENCY VOLTS 0 5000 10 1 BUS VOLTAGE 102 1-LSHL-0625 SPENT FUEL N/A N/A N/A NOTE 4 N/A LEVEL 103 1-FI-0631 SFPCPS FLOW N/A N/A N/A NOTE 4 N/A 104 N/A CONTROL ROOM MIN /HR 00:01 24:00 00:01 N CLOCK AVAIL

CEORGIA POWED COMPANY 141 NOTE 1 THIS INSTRUMENT AS INSTALLED ON THE CONTROL BOARD DOES NOT MEET THE REQUIREMENTS OF THE WESTINGHOUSE ICCR, BUT THE PLANT SAFETY MONITORING SYSTEM SUPPLIES THE RECOMMENDED PARAMETER RESOLUTION IF NEEDED BY THE OPERATOR. IT IS INTERESTING TO NOTE THAT TO MEET THE ICCR RESOLUTION AND PROVIDE ADEQUATE SEPARATION SETWEEN DIVISION MARKS WOULD REQUIRE METERS APPROXIMATELY FOUR FEET HIGH FOR MANY OF THESE INSTRUMENTS.

NO. 8 1-LI-0990A REFUELING WATER STORAGE TANK RESOLUTION AS IS =2%

REQUIRED = 1 %

NO.10 1-FI-0918 SAFE IN'J PUMP P6003 DISCH RESOLUTION AS IS = 20 GPM REQUIRED = 5 GPM NO.11 1-FI-0917A CVCS CHG PMP TO 80R INJ TK V6 RESOLUTION AS IS = 20 GPM REQUIRED = 5 GPM NO.14 1-NI-00418 POWER RANGE

% FULL POWER RESOLUTION AS IS =2%

REQUIRED = 1 %

PSMS DISPLAYS RE-13135A1/81 WITH

• . RANGE OF 1.0E-3 TO 2.0E2 NO.28 1-PI-0934 CONTAINMENT RESOLUTION AS IS = 1 PSIG REQUIRED = .1 PSIG NO.29 1-LI-0764 CONTAIN EMERG FLOOR DRNS LEVEL RESOLUTION AS IS =2%

REQUIRED = 1%

NO.32 1-PI-0408 REAC COOLANT LOOP 1 HOT LEG RESOLUTION AS IS = 50 PSIG REQUIRED = 5 PSIG NO.36 1-TI-0413A REAC LOOP 1 WIDE RANGE HOT RESOLUTION AS IS = 10 *F REQUIRED = 1 *F NO.37 1-TI-04138 REAC LOOP 1 WIDE RANGE COLD RESOLUTION AS IS = 10 *F REQUIRED = 1 "F

GEORGIA POWER COMPANY 142 NO.38 1-LR-1310 REACTOR VESSEL 39,40 WATER LEVELS RESOLUTION AS IS =2%

REQUIRED = 1 %

NO.45 1-LI-0459A PRESSURIZER RESOLUTION AS IS =2%

REQUIRED = 1 %

NO.81 1-PI-0514A STM GEN LOOP 1 STM RESOLUTION AS IS = 20 PSIG REQUIRED = 5 PSIG NO.83 1-LI-0517 STM GEN LOOP 1 RESOLUTION AS IS =2%

REQUIRED = 1 %

NO.84 1-LI-0501 STM GEN LOOP 1 WIDE RANGE RESOLUTION AS IS =2%

REQUIRED = 1 %

NO.91 1-PI-5107A AUX FEED PMP TD P4001 FW DISCH RESOLUTION AS IS = 50 PSIG i REQUIRED = 10 PSIG l NO.92 1-LI-5101 CONDENSATE l STORAGE TANK 1 l RESOLUTION AS IS =2%

l REQUIRED = 1 %  ;

CEORGIA POWER COMPANY 103 MOTE 2 THIS INSTRUMENT AS INSTALLED ON THE CONTROL BOARD DOES NOT MEET THE REQUIREMENTS OF THE WESTINGHOUSE ICCR, BUT THE PROTEUS OR EMERGENCY RESPONSE FACILITY COMPUTER SYSTEMS SUPPLY THE RECOMMENDED PARAMETER RESOLUTION IF NEEDED BY THE OPERATOR NO.13 1-PI-0919 SAFE INJ PUMP P6003 DISCH RESOLUTION AS IS = 50 PSIG REQUIRED = 5 PSIG NO.33 1-TI-0412 REAC COO LOOP 1 TEMP AVERAGE RESOLUTION AS IS = 2 *F REQUIRED = .5 *F NO.41 1-TE-173 RCP #1 SEAL TEMP RESOLUTION AS IS = NOT AVAILABLE REQUIRED = 10 *F NO.43 1-PI-0455A PRESSURIZER VAPOR RESOLUTION AS IS = 10 PSIG REQUIRED = 5 PSIG NO.47 1-LI-0470 PRESSURIZER RELIEF TANK RESOLUTION AS IS =2%

REQUIRED = 1 %

NO.48 1-PI-0469 PRESSURIZER l

RELIEF TANK RESOLUTION AS IS = 2 PSIG REQUIRED = .5 PSIG NO.51 1-FI-0618A RESID HT REMOV LP RET BYPASS A RESOLUTION AS IS = 100 GPM REQUIRED = 10 GPM NO.52 1-PI-0614 RESID HT REMOV

( PUMP 1 DISCH RESOLUTION AS IS = 20 PSIG i REQUIRED = 5 PSIG NO.57 1-FI-0121C CHARGING LINE FLQf RESOLUTION AS IS = 10 GFm REQUIRED = 2 GPM NO.76 1-TE-1967 ACCW SUPPLY l

TEMP RESOLUTION AS IS = NOT AVAILABLE REQUIRED = 5 *F

CEORGIA POWER COMPANY 144 NO.88 1-PR-6292 LPT A & 8 EXHAUST HOOD PRESS RESOLUTION AS IS = .5 PSIG REQUIRED = .1 PSIG NO.93 1-JI-40132 GENERATOR WATTS JI-G1WM RESOLUTION AS IS = 20 MW REQUIRED = 5 MW NO.95 1-JI-40113 DG1d WATT OUTPUT RESOLUTION AS IS = 200 W REQUIRED = 50 W NO.95 1-JI-40114 DG18 WATT OUTPUT RESOLUTION AS IS = 200 W REQUIRED = 50 W NO.96 1-EI-401378 DG1A OUTPUT VOLTAGE RESOLUTION AS IS = 100 VAC REQUIRED = 20 VAC NO.96 1-EI-401388 DG18 OUTPUT VOLTAGE RESOLUTION AS IS = 100 VAC REQUIRED = 20 VAC t

GEORGIA POtfER COMPANY 145 NOTE 3 SEE HED 1317 INSTRUMENT GRADUATIONS AS INSTALLED ON THE CONTROL 80ARD DO NOT MEET THE REQUIREMENTS OF THE NESTINGHOUSE ICCR. IN ALL CASES THE HALF GRADUATION VALUE MATCHES THE ICCR RESOLUTION. THE OPERATORS CAN ACCURATELY MAKE HALF GRADUATION READINGS SO THE GRADUATION RESOLUTION WILL NOT ADVERSELY AFFECT THE OPERATORS ABILITY TO JUDGE THE PROPER OPERATION OF THE SYSTEM OR COMPONENT NEEDED FOR A TIMELY AND ACCURATE RESPONSE TO PLANT CONDITIONS.

NO.31 1-LI-0931A SPRAY ADDIT TK T6001 LEVEL RESOLUTION AS IS =2%

REQUIRED = 1 %

NO.56 1-TI-0103 80RIC ACID TANK T4003 RESOLUTION AS IS =2 "F REQUIRED = 1 *F NO.62 1-FR-0158 REAC COOL PMP 3 AND 4 H RANGE LK RESOLUTION AS IS = .2 GPM REQUIRED = .1 GPM NO.85 1-SI-5316 SGFPT A SPEED TACH IND RMTN RESOLUTION AS IS = 200 RPM REQUIRED = 100 RPM

CEORGIA PotHQ COMPANY 145 NOTE 4 SEE HED 1318 THIS PARAMETER IS NOT PROVIDED IN THE CONTROL ROOM. HOWEVER, THE OPERATOR IS PROVIDED WITH AN ANNUNCIATOR IF THE SYSTEM IS OPERATING OUT SIDE NORMAL LIMITS.

NO.64 RCP SEAL INJECTION SUPPLY TEMP THE OPERATOR USES VOLUME CONTROL TANK TEMPERATURE NO.71 1-FT-19052 RCP CCW THERMAL BARRIER FLOW NO.72 1-FE-1929 CCW FLOW TO RHR HX's NO.102 1-LSHL-0625 SPENT FUEL LEVEL NO.103 1-FI-0631 SFPCPS FLOW i

GEORGIA POWER COMPANY 107 NOTE 5 SEE HED 1314 THE FOLLOWING INSTRUMENTATION DOES NOT MEET THE MINIMUM RANGE REQUIREMENTS OF THE WESTINGHOUSE ICCR:

NO.11 1-FI-0917A CVCS CHG PMP TO BOR INJ TK V6 RANGE AS IS = 100 TO 1000 GPM REQUIRED = 0 TO 750 GPM THIS SYSTEM HAS NO THROTTLING CONTROLS WHEN ALIGNED TO SAFETY INJECTION, AND FLOW CAN NOT BE REDUCED BELOW 100 GPM WHEN FLOW IS ESTA8LISHED. A NO FLOW INDICATION AT 100 GPM WOULD REQUIRE THE SAME OPERATOR ACTION AS A ZERO INDICATION.

NO.56 1-TI-0103 BORIC ACID TANK T4003 RANGE AS IS = 50 TO 150 *F REQUIRED = 40 TO 160 *F THE MINIMUM TEMPERATURE ALLOWED FOR THIS TANK BY TECHNICAL SPECIFICATIONS IS 65*F (T.S. 3.1.2.6), AND THE BUILDING VENTILATION SYSTEMS ARE DESIGNED TO MAINTAIN 80-120*F.

OPERATION OUTSIDE THE INDICATED 50-150*F RANGE IS NOT PROBABLE AND OPERATOR ACTIONS WOULD NOT BE ANY DIFFERENT IF THE INDICATION REACHED THE HIGH OR LOW LIMIT OF INDICATION.

l NO.57 1-FI-0121C CHARGING LINE FLOW RANGE AS IS = 0 TO 200 GPM REQUIRED = 0 TO 220 GPM THE NORMAL FLOW FOR THE VEGP SYSTEM IS 120 GPM IN NORMAL OPERATION; THEREFORE INDICATION OVER 200 GPM IS UNNECESSARY.

NO.61 1-FR-0156 REAC COOL PMP 1 AND 2 LOW RANGE SEAL LEAK OFF RANGE AS IS = 0 TO 1.0 GPM REQUIRED = 0 TO 1.2 GPM NORMAL RCP SEAL LEAK OFF IS 0.2 TO 5.0 GPM.

THE WIDE RANGE INDICATION (O TO 6 GPM)

ON 1-FR-158/160 IS AVAILABLE TO MONITOR FLOW GREATER THAN 1 GPM.

CEORGIA POWER COMPANY 148 NO.67, 1-FR-0110 BORIC ACID BLEND CONTROL RANGE ,

AS IS = 0 TO 160 GPM REQUIRED = 0 TO 180 GPM THE AVAILABLE RANGE OF 160 GPM EXCEEDS THE DESIGN FLOW CAPACITY OF THE SYSTEM, SO INDICATION ABOVE 160 GPM IS UNNECESSARY.

NO.89 1-FI-5150A AUX FEEDWTR SUPP TO STM GEN RANGE AS IS = 0 TO 500 GPM REQUIRED = 80 TO 1280 GPM THE REQUIRED IS BASED ON TOTAL FLOW TO ALL STEAM GENERATORS OR 320 GPM PER GENERATOR.

THE INSTALLED PER STEAM GENERATOR FLOW INSTRUMENTS, IN AGGREGATE MEET THE REQUIREMENTS DEFINED BY THE ICCR.

l 4

_ . - . . . - , _ - _ _  % , ._- ,__ _. . _ - - ~ _ . _ _ _ , . . _ _ .

- . . ~.m. _ _.-.--s, - - _ _ _

GEORGIA POWE"2 COMPANY 109 NOTE 6 SEE HED 1315 THE FOLLONING INSTRUMENTATION DOES NOT MEET THE MINIMUM ACCURACY REQUIREMENTS OF THE WESTINGHOUSE ICCR:

NO.13 1-PI-0919 SAFE INJ PUMP P6003 DISCH ACCURACY AS IS = 60 PSIG REQUIRED = 48.2 PSIG NO.31 1-LI-0931A SPRAY ADDIT TK T6001 LEVEL ACCURACY AS IS = 3.7 %

REQUIRED = 3.0 %

NO.47 1-LI-0470 PRESSURIZER RELIEF TANK ACCURACY AS IS = 3.7 %

REQUIRED = 3.0 %

NO.48 1-PI-0469 PRESSURIZER RELIEF TANK ACCURACY AS IS =3 PSIG REQUIRED = 2.7 PSIG NO.55, 1-FR-0110 80RIC ACID 8 LEND CONTROL ACCURACY AS IS = 4.2 GPM REQUIRED = 2.8 GPM NO.56 1-TI-0103 BORIC ACID TANK ACCURACY AS IS = 3.7 %

REQUIRED = 3.0 %

THE ABOVE PARAMETERS DO NOT AFFECT THE OPERATORS A8ILITY TO VERIFY THAT PLANT AUTOMATIC SYSTEMS HAVE ACTUATED CORRECTLY, DIAGNOSE THE STATE OF THE PLANT RELATIVE TO PREDEFINED EVENTS AND CHALLENGES TO l CRITICAL SAFETY FUNCTIONS OR MONITORING

/ REGULATING PLANT PROCESS PARAMETERS REQUIRED TO ACHIEVE THE DESIRED PLANT STATE I

l l

CEORGIA POWER COMPANY 150 APPENDIX 6.3 HED RESOLUTIONS AND IMPLEMENTATION STATUS (PAGE 151)

CATEGORY 4A HED JUSTIFICATION (PAGE 179)

CANCELED HEDs (PAGE 199) l l

l

CEORGIA POtfER COMPA88Y 151 V0GTLE ELECTRIC GEIERATIM PLANT MAIAll ENGINEERING DISCREPANCY (NED) STATUS REPORT HED NUMER ORIGIll HED DESCRIPTION CATEGORY PA0 POSED RESOLUTI(Il STATUS 1803 1982 PRELIMINARY CROR A M UNCIATOR LETTER SIZE IS 03 letal REPLACIIIG TILES FOR (NED103),LMD-2 SMALL FOR NORNAL VIENING TEXTCHANGESUSE1/4' DISTAhCE. LETTERS IF INFOMATION CONTBIT PEMITS.

INFONIATIGl CGITBIT WILL TAllE PRECEDENCE OVER THE NINOR BEVIATIGI IN LETTER SIZE.

1804 1982 PRELIMIllARY CRDR A HIERARCHICAL SYSTEN OF 03 UTILIZE A HIERARCHICAL OPS WORKING, ON (NED201), LND CK,12, 2 LA8ELIll6 IIAS IIOT UTILIZED ON LASELING SYST81 FOR ORDER VIA (07006.6.1.2. THE IIAlli CONTROL 80ARD. IllSTIRNEllT LA8ELS 18 TERE RFS-4-86-481, 10ARD LAYOUT PE MITS. 682, 683, led CEIITEDL AmmANai WILL GENERALLY PREVEllT THIS APPR0401 OUE TO LIMITED SPACE.

1809 1982 PRELIM!llARY CRDR GROUP 4110NITOR LI9tTS REQUIRE 03 110111 TOR EXES WILL OE DONE (NED212) FOUR PAllELS AS COMPARED TO TWO IDENTIFIED WITH LA8ELS PAllELS FOR OTHER GROUPS. SHOWIIIG GROUP AND TRAIN 1010 1982 PRELIMIIIARY CROR THERE ARE NO REFER 91CES ON 03 N0111 TOR IDXES WILL BE DONE (NED213) PAllEL 1A1 OR 1A2 AS T0 leilCH IDelTIFIED WITH LA8ELS AINIUIICIATOR IS ASSOCIATED WITH Sh0NIIIG GNOUP AllD TRAIN 1811 01 STATUS PAllEL.

1012 1982 PRELIMINARY CRDR THE LA8ELS FOR LET00lel ORIFICE 03 RELA 8EL 91011111G FLOW TO ENGINEEOG (NED215) VALVE SWITCHES HS8149A, 81498, RATE.

8149C 00 NOT SUPPLY SUFFICIElli IllF0lNIATIGl FOR PROPER USE.

1013 1982 PRELIMINARY CR0R THE 4FN Pulf SillTCHES FOR 03 DROP IRN18ERS FROM LA8ELS, TO ENGINEEllllG (NED219) PulFS 1, 2 A110 3 HAVE ON THEIR USE TRAIN LETTERS.

LA8ELS THE LETTERS C, A A110 8 1014 1982 PRELIll! NARY CROR HS-0455A AllD HS-0456A HAVE THE 03 RELA 8EL TO DELETE 'IS0' TO ENGINEERING (NED221) EXTRAllEOUS WORD *150' IllCLUDED O'; Thel.

CEORGIA pot 0ER CO88PANY 152 V0GTLE ELECTRIC 6 BERATING PLANT Hlal4NENGINEERIII6 DISCREPANCY (NED)STATUSREPORT HEDIMEER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUTION STATUS 1815 1982 PRELIN!!IARY CROR SC-3151 & SIC-5898 ARE LA8ELED 03 RELA 8EL CONSISTBITLY 'A*. TO ENGINEERING (NED223) A Allo 1 RESPECTIVELY 1016 1982 PRELIMINARY CR0R LA8ELS ON THE QEA8 NEED 110RE 03 RELA 8EL SHONIll6 LOAD OR OPS WORKING, ON (NED229) INFOMATION thall JUST THE IICC OR LOCATION ORDER VIA ES BREMER C00E. 4-86-638 1017 1982 PRELIMINARY CRDR THE LA8EL ON THE QEA8 NINIC 03 A00 YOLTAGE TO LA8ELS ON DONE INSTALLED (NED230) BUS DOES NOT IllCLULE A BUSES . IN NCR AND SIN.

VOLTAGE DESCRIPTION, BUT IS NARCH 17,86 EJK COLOR CODED.

1019 1982 PRELIMINARY CRDR CRITICAL SNITCHES 00 Il0T HAVE 03 REAC TRIP SAFETY TO B16111EERING (NED236),OPEXP829 PROTECTIVE COVERS INJECTION & CTNT ISOL - DELETE RED SNITCHES ARE COLOR CODED HA110LES SISTIllCTLY & LOCATED ANAY FRON ROUTINE CGITROLS. NO COVERS ARE CGISIDERED IECESSARY. THESE & STil LINE 130 Hall 0LES NILL BE COLORED RED.

l l 1020 1982 PRELINIllARY CROR THE ALANIS ON THE QEA8 Allo 02 ADJUST TO OlFFERENT TO NAINTENANCE (NED237),PR70, QNC8 PANELS SOUND OFF NITH THE TONES. A00 HOMS T011C8 A 1910 SIMITTED 8700(6.3.2.1) SALE T0llE, Allo THERE ARE 110 Allo 8 FOR THEIR 3-25-86 FOR DIRECTIONAL CUES FOR THE AINMICIATORS. ADJUSTIENT ALARIES GI lilE QNC8.

1822 1982 PRELIMINARY CROR THE ORDER!ll6 0F LOOPS ON 04 ARRAll6E 8Y LOOP TO ENGINEERIN6 (NED240) AINMICIATORS IS IllCONSISTENT VERTICALLY.

FN0ll STATUS PAllEL TO STATUS PAllEL.

1024 1982 PRELIMINARY CRDR ACCN HS-1974, 1975, 1978 & 83 RELA 8EL AS 111C/00C QIli DWlE (NED243) 1979 ARE ORDERED RETURN-T0 ISOLATIONS.

SUPPLY (LEFT-TO-RIGIT).

THIS VIOLATES THE DESIM CONVBITICII.

1025 1982 PRELIMINARY CRDR THE SAFETY lilJECTI0ll SYSTEN IS 64 REVISE ARRAlI6BIBIT PER TO ENGINEERING (HED244) Il0T ARRAll6ED FUllCT10llALLY. TNE ATTACHED REA.

FLON PATH IS Il0T FOLLONED IN THE ARRAllGBIENT OF THE CONil10LS, A110 THERE IS NO CGIISISTENT TOP TO 80TT0ft ORGAllIZATIGl.

GEORGIA POWER COMPANY 153 VOSTLE ELECTRIC GENERATI M PLANT iMIAN Ell 61NEERING DISCREPANCY (NED) STATUS REPORT HED NUMER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUT10ll STATUS 1826 1982 PRELIMINARY CR0R ACCultiLATOR TAllK LEVEL & 03 HIERARCHICAL RELA 8EL DONE (HED245) PRESSURE INDICATORS ARE SEPARATED, AND ARE NOT m a n n IN THE FLON PATH IIIDICATED SY BEmTEL GUIDELINE 11.2.8 1031 1982 PRELIMINARY CRDR CONTROL R00 SWITCH MD 04 ROLL 'IN' & '0UT' LIGHTS TO ElI61NEERIl16 (NED252) INDICATOR LIIRCS ARE NOT TO PUT GUT ON TOP TO RBICTIONALLY mw3D. MTCH RPI. N0 fmMRruM ON CHAll6E TO CONTROL SilITQl, LEAVE AS IS.

1834 1982 PRELIMIKARY CROR P0OR ARRAIIGGENT OF DIESEL 03 GUARD NOR ML STOP BUTTON. TO MiliTENAllCE (HED258) GENERATOR CONTROL AREA THAT 1810 SUINilTTED IIAY RESULT IN POSSIBLE 3-31-86 ACTUATION OF DIESEL GENERATOR START - STOP SulTQlE3 islEll SiftlOIRONIZIINI.

1836 1982 PRELINIllARY CROR THE RESIOUAL HEAT RE10 VAL 04 REVISE ARRAll681ENT PER TO ENGINEERING (NED261) SYSTEN IS Il0T APRAll6ED ATTACHED REA HalCTIONALLY.

1039 1982 PRELIllINARY CRDR PRESSURE INDICATORS PI-5500 & N 110VE IN LIllE NITH OTHER AFTEd FUEL LOAD (NED265) PI-5501 ARE IlOT NEAR INDICATORS. HONEVER THIS ASSOCIATED CONTil0LS. IS NOT A SIGilIFICAllT OPERAT10llAL PR00LEll.

VERY LON PRIORITY.

1M3 1982 PRELINillARY CROR THEQEA8HAS29VOLINETER 03 COLOR HAllDLES IsilTE. OPS HORXIll6 -

(NED2TC) SELECTOR SWITCHES OPERA 8LE BY CODE GROUPS A, 8, C, D 131E OF THREE HAl10LES. (CURR81TLY 111 CONTROL ROON).

IN5 1982 PRELIMINARY CRDR THE STATUS LIGHTS AllD PUSH 03 PUT P8 00TS 8EL011 DONE (NED403) BUTTONS ON TM TUR8IllE PAllEL PUSH 8UTTONS.

ARE VERY SilllLAR IN APPEARAllCE.

CEORGI A PotfER C004PANY 153 V06TLE ELECTRIC GENERATING PLANT leNI411 Fil61NEERING 0!SCREPANCY (NED) STATUS REPORT HED IM SER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUTI(Ni STATUS 1848 1982 PRELilllNARY CADR COLOR C001116 NAS NOT BEEN 03 A00 GRES 8 Allo TO NETER OPS NOMING A00 (NED404) UTILIZED TO DEFillE Il0RNAL FACE, 8Y FUEL LOA 0. 8 Allo LIMITS TO LilllTS FOR OPERATIONAL IIO01FY RANGES BY FIRST INVENTORY BATA PARANETERS. REFUEllll6. 8ASE 1949 1982 PRELIMINARY CRDR THE PRESS TO TEST FEATURE ON 04 PROVIDE ST00L/LA00ER FOR 00NE - STOOL IN (NED408) NANY OF THE STATUS PANELS ARE TEST AND ANNUNCIATOR CONTROL ROM TOO FAR ANAY TO 8E EFFECTIVELY SERVICE. THIS IS A SIMPLE UTILIZED. FIX COlFARED TO RELOCATION 0F THE TEST IUTTON.

1050 1982 PRELillINARY CRDR AINIUNCIATOR LETTERIll6 IS TOO 03 SEE HED 1230. ISIElf (NED410) SMALL. REPLAClll6 TILES FOR TEXT CHANGESUSE1/4' LETTERS IF IllF0MATIGl CONTENT PElullTS. INF0BIATIGI CONTEllT WILL TANE PRECEDENCE OVER THE Nil 10R DEVIATION IN LETTER SIZE.

1851 1982 PRELIlllllARY CRDR CONill0L Hall 0LES ARE Il0T SHAPE 03 CODE VALVES, DAfPEltS - OPS WORKING -

(NED411) CODED. 'T' PWrS, FANS, HANDLES Ema'i 'J'. RECEIVED -

INSTALLfiAELES WITH LAKl.

QlAll6E 1952 1982 PREllillNARY CR0R THERE ARE IllLTI-POINT 04 REPLACE NITH L & N 250 GR AFTER FUEL LOAD (NED412) RECORDERS IN THE CONTROL ROON, SilllLAR RECORDER.

WITH OUT SillGLE POINT SELECTI0ll.(ITJR-3000, 1TJR-1690,1TJR-1691,1-ZR-4R) 1954 1982 PREllllIllARY CR')R THERE IS 110 EASY REFEREllCE FOR 03 ADO (A,8,C-1,2,3] 00NE INSTALLED (NED 414) (NUREG 0T00 LOCAT!Il6 SPECIFIC AINIUllCIATOR llATRIX llARKillGS. A,8,C IN SIN Allo ICR 6.3.3.3.) N!N00NS DOW THE LEFT SIDE,1,2,3 ACRCSS TOP. ON QEA8 IIAKE

.S INCH LETTERS AND PLACE OUTSIDE AINENI 80K FRAIE ON OTHERS USE .3T511101 LETTERS FOR 12 FOOT VIEN DISTANCE Allo PLACE IN 80X FRAllE IIARGIN.

CEOftGIA POS$EO COSIPANY 155 V0GTLE ELECTRIC GENERATING PLANT IMIANElIGINEERilIGDISCREPANCY(NED)STATUSREPORT HED Nh0ER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUTION STATUS 1855 1982 PRELIMINARY CROR INK CARTRIDGE RECORDERS ARE 04 REPLACE IllK CARTRIDGE AFTER FUEL LDAD (NED415) O!FFICULT TO REFILL AFTER RECORDERS ISIEll NAJOR CLOG 61116. REPAIRS OR REPLACBElli IS REQUIRED.

1856 1982 PRELIMIIIARY CROR THE PEANISSIVES ON PMEL SC1, 04 R m e m ANO N00lFY NO ACTION (NED502) LA8ELED PSLB, ARE POORLY LEGE110S.(LA8ELSONLY) PLAIERED man Allo SUBJECT TO RISINTERPRETATI(El.

1857 1982 PRELilllllARY CRDR THE STATUS LIGHTS FOR TH5 02 A00 OR IIDVE LIGHTS TO TO ENGINEERING (NED503) STEAll GENERATOR ATNOSPHERIC 181. LEAVE STEAN DUIFS AS RELIEF VALVES AND THE STEAll IS, SillCE CUltRElli GEllERATOR STEAll DUW VALVES POSITION IS A 0000 ARE Il0T IN CLOSE PROXINITY TO C01FRONISE SETWEEli R0 Allo THEIR RESPECTIVE CONTil0LS. P0. Il0VE ARV'S TO ZL8 ON 181.

1859 1982 PRELIMINARY CROR THE STATUS LIGIT BOX ON 1A2 04 REARRAllGE OR ADO GROUP AFTER FUEL LGAD (NED505) (TSLS-4) IS .4RRAll6ED POORLY. LABELS. - DECLillED IESTIINBIOUE PROPOSAL 1861 1982 PRELINillARY CROR THE SAFET) !AJECT10ll 03 LASEL SI AND ACCUIRILATOR DONE LAIELS (NEDSO4) ACCulRlLATOR ISOLATION VALVES SECTIONS OF 80 Alto. INSTALLED AltE HARD TO LOCATE. DOIARCATION A00E0 1963 1982 PRELIMINARY CROR THE PRIORITY ALAliflS ARE Il0T 03 COLOR CODE RED A110 YELLON TO EleG. Alel l EASILY 100lTIFIED. ANO leilTE ANNullCIATOR (NED510) WIN 00NS GI i NIN00NS. SITE. IllSTALLES IN SIN.

1970 AllTHROPallETRIC SURVEY AlelullCIATORS ARE A80VE THE 03 IIILL A101UNCIATOR N0005 ON TO MAINTEllANCE (AS-12) REcoleIDIDED HEIGHT FOR QPCP, QHVC AND THE QEA8 - SHAVE THE TOP VERTICAL 80 Alt 05. TO EXPOSE THE LOWER LINE OF AIARNICIAT0ft OF BIGRAVIIIG. Iloi NEEDED TILE SEZELS TO (El QNC8 OUE THE TILT OF RBIDVE SHAODIG THE A10RNICIATOR FRAIES. 4-85-86

l CEOttGIA PO90ER COMPANY 155 V06TLE ELECTRIC GENERATING PLANT leslAN ENGINEERIll6 DISCREPANCY (NED) STATUS REPORT HED NUMER ORI6111 NED DESCRIPTION CATEGORY PROPOSED RESOLUTION STATUS 1874 AllTHROPONETRIC SURVEY NONITOR ON DESK TOP AT 03 RELOCATE TEMINAL SO AS (AS-20) SilRlLATOR PREVENT SEElll6 NOT TO OLOCK PAllEL VIEN.

INSTRUIENTS AND CONTROLS FRON A SEATED POSITION.

1975 PROOLEN REPORT 20 REACTOR TRIP SWITCHES TRIP TO 01 RENIRE ANO RELA 8EL TO EN61NEERIII6 LIFT & RESET TO RIGIT. THIS SWITCHES TO TRIP - IESTil1910llSE VIOLATES A POPULATIONAL CLOC MISE & RESET COUNTER NORKil16 STERE 0 TYPE TO 'FlalCTImi' TO CLOCMISE'(MS 40007 RIGIT ONLY).HS-40002,40002A, THE *FlalCTION' BElll6 REACTOR 409028,40007. ELININATE TRIP. CURRENT DESim TREATS FLAG ON HS-40007.

THIS AS MFAEFR ONLY,110T A RalCTION. ERRORS Ill ACTUATI0ll NOTED IN SiltlLATOR 1976 Pfl08LEN REPORT 9 ARRANGEIENT OF TILES ON GROUP 01 REGROUP LIGITS ON GROUP TO EN61NEERIl16 follTOR LIGITS IS IlOT 110NITOR PA11ELS, Allo - OECITEL CCP CONSISTENT WITH FUNCTI0llAL RENIRE Ill TEMINATION 810235J IN GROUPS leilCH ltiST BE VERIFIED CA8INETS TO GROUP FOR PROGRESS INE0P'S(IE:SI, CIA,CVI). SUPPORT OF E0P'S.

I 1977 PR08LDI REPORT 14 FI 132C A110121C (LET00lel Allo 02 RESCALE F1-121C Fil0N TO ENGIllEER!al6 QIARGIN6) IETERS 011 IIC8-1A2 0-200 GMI Ill 5 GPil RFQ-05-23061&

ARE SIDE BY SIDE FOR lilCREMENTS T0 flATCH GPP 10386 CGIFARISON, RIT HAVE O!FFERENT FI-132C. ALSO W alr SCALES. THIS IIAKES CollPARISON FI-121A ON QNC8-C 0-200 l

OlFFICULT All0 ERROR LIKELY. GMl TO BE CONSISTENT Allo

( FACILITATE CO FARISGI T0 i FI-132A.

1000 PR-41 FQI-110 & FQI-111 LA8ELill6 83 RELA 8EL:FQI-110'80RIC TO ENGINEERING DOES NOT DESCRIBE PARAIETER ACIO TO OLE 110ER*

Ill0ICATED. FQI-111'TOTALllAKEUP' 1003 LNO QiECKLIST LMD-6 NINICS 011 QNC8 82 HAVE 03 LA8EL DISCO MECTS IN THE TO Ell 61NEERING Im AarlFD O!SC010lECTS ON THE SAllE STYLE AS OTHER LilES FROM THE 184 111 GDIERATOR DISColelECT LA8ELS.

& 60!116 TO GOSHEN NO. 2 l

t I

CEOltGIA POtfER COMPANY 157 V0GTLE ELECTRIC GENERATI N PLANT lutAll ENGillEERING OISCREPMCY (NED) STATUS 290RT HED IM WER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUTIM STATUS 1884 LND CHECKLIST US-10 MINIC LINES OVERLAP ON THE 03 N00!FY NINIC TO S ON OPS WORKING 234KV SECTIGl W THE LEFT OF COMECTIONS A110 MEARS.

THEQEAS.

1086 PR-50 LA8ELS D0110T RELATE NI OLOCK 03 RELA 8EL BLOCK SWITCHES TO OPS WORKING SillTCHES TO PERillSSIVE LIGHTS REFER TO APPLICAELE P-6 & P-10. PERISSIVE.

108T OC-5 PLAlulED CIRCULAR 800KCASE 03 REVISE anMM DESIM DME 085TRUCTS THE PLAllT OPERATORS All0 ADO 800llCASE SPACE AT VIEN OF SPOS TEMIllAL, PROTEUS OUTER PERINETER SURFACE TEMIllAL AND THE NODULAR COVER OF OPERATORS DESK. DELETE 00STIBICTS TUR8INE OPERATORS NODULAR COVERS. SINCE VIEN 0F TUR81NE AND SWITCHYARD PElBIS IS DELETED PAllELS. (REA-1-85-319)IIDVE PROTEUS TElWIINAL T0 luf OPERATOR DESK. A00 PERFORATED lETAL ColR. TO CWCEAL WIRES.

1044 OPERATOR EXPERIENCE CVCS ON 1108 IS Il0T 02 REARRAIIGE CVCS PAllEL TO ENGINEERING QUESTI0lelAIRE FUIICTI0llALLY ARRAl16ED AND IS LAYOUT.

CWFUSill6 TO OPERATE, FLolf PATHS ARE NOT EVIDEllT IN CWTROL LAYWT.

1949 OC-7 80RON lilJECTION TAllK VALVES 01 REN0VE DISCONNECTED HAllD TO ENGINEERING ARE TO E DISC 01NIECTED Bli SWITCHES FRoll THE PAllEL. - NESTillWOUSE LEFT INSTALLED IN PANEL. THESE FILL HOLES WITH IETAL NORKING DEAD SNITCHES WILL ADO TO BLANES.

CNONDillG IN CVCS PANEL A110 Stolf OPERATIWS IN E0P RESPGISE.

1091 GENERAL PAllEL CHECKLIST INDICATORS ARE LAID OUT IN 02 REARRAllGE 111 TO ENGluF m ini (6-2) DECREASillG NUIERICAL ORDER IN IIICREASING ORDER, FRoll LEFT TO RIGHT. FRON LEFT TO RI NT.

1095 GENERAL PAllEL CHECKLIST SYllC LINTS FOR llAIN GOIERATOR 03 LA8EL LIETS. DONE INSTALLED (G-6) AND AUTO SYllC LIGHTS FOR NAlli IN IICQ AND $1N

& OIESEL GOBERATORS 00110T NAR 17,86 EA HAVE LAIELS.

CEOftGIA POtfE3 CostPANY 158 VOSTLE ELECTRIC GENERATIll6 PLANT IGNIANENGI!:EERINGDISCREPANCY(NED)STATUSREP0ti HED IRNER ORIGIN HED DESCRIPT!W CATEGORY PROPOSED RESOLUTION STATUS 189T GENERAL PANEL CHECKLIST HS-43028 & HS-43048 HAVE TWO 83 RE-LA8EL SWITCH PLATE TO ENSIsrFa n (6-12) SE150FOPEN/CLOSELle(TSEACH WITH VALVE lENBERS WITHOUT DIRECTIONS AS TO lellCH IDENTIFYING LiefTS.

Lleti 60ES WITH let!CH VALVE (EACHHSOPERATESTWOVALVES).

1998 GENERAL PAllEL CHECKLIST SWITCH HAS 3 RED LIGITS WITH 03 LA8EL SWITCH PLATE LIGHTS TO ENGINEERING (6-12) NO LE6D D PRESENT. AS TO FUNCTION.

1100 GENERAL PAllEL CHECKLIST NO LE6080 EXIST AS TO IEMlll6 03 lellTE LIGIT IS GN IF VLV 091E TRAINIE (6-12) 0F lef!TE LIGITS ON AFW NOT FULL OPEN 1910 AFW INCORPORAT54 INJECTION VALVES. ACTUAT 0N IS PRESENT. INTO RD-LFJ8 &

EXPLAINIll6 LOGIC ON LAt4L Sa0-LP-54 87 T00 NotN.110 MARONARE LOCATim /

CHANGE NEEDED. A00 T0 (!!.A.4.h TRAINill6 ON IEAllING 0F 2/3/84 LlelT.

1101 601ERAL PANEL CHECKLIST SWITCH OPERATES TWO VALVES AND 03 LA8EL SWITCH PLATE TO TO Ell 61NEERING (6-12) THETWOSETSOFOPEN/CLOSE IDDTIFY LIG(TS.

LIGiTS ARE NOT IDelTIFIED AS TO 10(10{ LIGIT GOES WITH lei!CH VALVE.

I 1102 GENERAL PAllEL CHECKLIST HS'S HAVE 3 ListTS (1 RED & 2 03 LA8EL SillTCH PLATE TO TO Ell 6INEERIES (6-12) AlWER)A110100LE6010TO IDDITIFY LIG(TS.

l DESCRIBE LIGHTS FUNCTION.

1104 G D ERAL PANEL CHECKLIST SWITCH HAS 3 CLEAR LIGHTS 03 LA8EL LIGITS TO INDICATE TO 0161NEERING (6-12) WITHuUT LE6010 AS TO LI9fTS R21CT191.

FUllCTION.

1105 GENERAL PAllEL CHECKLIST 110 LE6010 EXIST AS TO REICTI0ll 03 LA8EL LIGITS TO INDI* ATE TO 016!11EERING OF LIGIT 011 HAND SWITQi (3 FUNCTION lefl1ELIGITS) 110T GGERAL PAllEL CHECKLIST 19 FL0li & LEVEL lil0ICATORS IN 03 PROVIDE TANK 800K OPS WORKIII6 -

UlllTSOF%:[RCSFLON}[ CST (GALLONSTO% CURVES)FOR COORDINATE WITH LEVEL)[RIISTLEVEL][VCT TAllES. OTHER PARAIETERS, 808 LICE -

LEVEL] [S6 LEVEL] [CINIT Ssr  % DISPLAY IS APPROPRIATE. ElIGillEERIll6 LEVEL)[lISCWBSNLEVEL)042 RESCALE CONTAllNEllT IIONITOR][AC3111 LEVEL][8AST REClllC SUIF LEVELS TO LEVEL) [ SAG TK LEVEL) [PRZR IIICHES TO HATCH PSIIS LEVEL] [0PDT & OPOP] [STN DIF DISPLAY PSR l161-9T.

0190] [IllPl3 PRESS) REVISE E0P'S.

CEORGIA POtfE2 COstPANY 159 V06TLE ELECTRIC GENERATING PLANT iMIANEM61NEERIII6OISCREPANCY(NED)STATUSREPORT HEDIMWER ORIGIN HED DESCRIPTI0li CATEGORY PROPOSED RE30LilTIW1 STATUS 1111 681ERAL PAllil CHECKLIST PROCEDURES 00 NOT REQUIRE 03 INCORPORATE AIN10TATION OF OPS MORXING (6-45) OPERATORS TO IIARK CHART AS CHART RECORDERS IN OIECK PROCDURE SCALE IS CHAll6ED FROM SR, IR, 10000-C 'CONOUCT OF OR PR DURIII6 STARTUP. OPERATIGIS' OR OTHER APPROPRIATE PROCSURE.

1112 GGERAL PAllEL CHECKLIST Sill 6LE POINT RECORDIll6 IS NOT 02 REPLACE WITH L & ll AFTER FUEL LOAD (6-46) AVAILA8LE ON IRJLTIPOINT RECORDER 250 OR RECORDERS IN THE CONTROL ll00N. EQUIVALENT. SAE AS HED 1952.

1115 TA E0P E-0 STEP 16 CHECKS 03 REVISE PROCEDURE TO THE DONE PRESSURE (1610 PSIG. IETERS NEAREST CollSERVATIVE 1/2 READ IN 54 PSIG IllCRBUTS, GRADATI0li (258) VALUE.

TOO FINE FOR NETER SCALE.

E-0-21 (1373 PSIG - SALE PR00L81.

till TA IICS PRESSURE (285 03 REVISE PROCEDURE TO ONE (1373 E0, STEP 21 IIEARESTCONSUVAT!YE1/2 EDP E-0 STEP 16 NETERS IN 20 GRADAil0N(10)

PSIG INCR8ENTS T00 FINE FOR READIIIB.

lETER SCALE 1118 TA E-3 STEP 13 03 REVISE PROCEDURE TO DONE CAN 110T READ 264 PSIG NEARESTCONSDVATIVE1/2 FIM-1 STEP 7 Call IIOT LEAD 665 GRADATION (258)READIll6.

l PSIG FR-C-1 STEP 11 CAN 110T READ 124 PSIG.

1119 TA E-3 STEP 14 SGPRESSUREREQUIREDINSLB 03 REVISE PROCDUEE TO DONE l

IllCRBEllT, BUT METER Ill 50'S. IIEAREST CONSERVATIVE 25 USE 50 OR 100L5 DIVIS!0N PSIG READ!l16.

1120 TA 20A E-0 STEP 21, NO PLANT C0NullCATION AT RCP 02 PROVIDE PAGE OR SOUND AFTER FUEL LOAD ESO.2 17 THROTTLE VALVES. PONER PHONE AT THROTTLE COWullCATIONS IIEEDED FOR E0P VLV STATION.

SUPPORT.

t

l GEORGIA POtfER CO8OPANY 100 V06TLE ELECTRIC GENERATIIIS PLANT MEMN ENGINEERING DISCREPANCY (NED) STATUS ilEP0ET NED RESER ORI6111 NED DESCRIPT!GI CATEGORY PROPOSED RESOLUTION STATUS t

l 1121 TA SC8tARIO SA (NUREG PCP ALARN HOM IS NOT NOTICEO 03 A0JUST PITCH TO T0 llAINTBMNCE 07006.3.2.2.) UNTIL FRONT E8 ALAMS ARE DIFFERENIIATE - 20 SUMITTED SILENCfD. NEEDS IIORE 3-31-46 OISTIETIVE SOUND.

1122 TA 7A F-0 NUISANCE ALA M Fil0Il SR SUR 03 SN00TH SUR OR INCREASE TO DONE POSITIVE DUE TO N0!!! AT LON >O SET POINT TO STOP SR Col 5fTS. NUISAllCE ALA M.

1123 TA 7A ESO.2 STEP 12 STEM TA8LES NEEDED TO BACKUP 03 ENGRAVE STEAll TA8LE ANO TO NAINTENAllCE CGWUTER Allo FOR QUICK PLACE GI 181 (MS VLV REFEREEE. AREA). USE SATURATION CURVE VALVES 20 ENGRAVE IN TAKE F0M.

1124 TA ESO.2 STEP 13 7A C00LD05 REQUIRES COORDINATION 03 ADO PT TO A SU8 COOLING OPS NORKING -

0F SU8C00LIIIS All0 PRESSURE CURVE. USE 100% C00L00lel OlECK SIRILATOR TEIFERATURE LINITS. CURVE FOR T.S.

3.4.9.IIFLEIENT GI ERF CGWUTER. ALREADY IN IRIIT OPERATilI6 PROCEDURE.

1125 TA GA ECA 00 STEP 3,6 Illa 0 EQUATE ENER681CY LI91Till6 01 UPGRADE ENER601CY TO [MGINEERING AT PCP All0 QHVC, ALSO LIGITilI6 AT I)(VC Allo QPCP REA 1-84-4821 Illa 0 EQUATE IN THE SIltJLATOR.

CHECK CONTROL 200N PUNS. SME AS E0P DISCREPAllCY 86.

1127 TA IllCLUDE Ill THE E0P'S, ROOM 03 REVISE E0P PEOCEDURE T0 llANAGEMENT NAIES Allo IUWERS FOR LOCATION IllCLUDE N00M NUIIBERS ANO REJECTE0 0F RBIOTE OPERATIONS Ill PLAllT llAIE FOR RENDTE i

110 011 LABELS. COIF 011EllTS.

1128 TA SCBIARIO 2A NVISAllCE ALARNS 011 AT POWER, 04 AFTER FUEL LOAD, IDDITIFY REVIEN AFL VALIO AUUBI OllLY FOR SI A110 ELINIllATE NUISAllCE CONCITION? ALANIS Fitall THE LOGIC.

1129 TA 2A E8 LIG(TS ON IN IRREEJLAR 03 RD10VE LIGIT BUL85 Allo OPS NORKIN6 -

PATTEM. LI9tT BLAllES TO FILL PAINT TILES FLAT BLACK.

OUT 8 LOCKS OR RONS.

i

CE00tGIA POWE."! COMPANY 151 VUETLE ELECTRIC A N N TING PLANT lANIAN ENGINEERING DISCREPANCY (NED) STATUS EPORT HED IREGER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUTIGl STATUS 1130 TA 23A FR-H.1 STEP 2 Call IIOT RED AFW FLON TO 550 03 fEVISE SilRILATOR T0 IIATCH TO MINTEllANCE GPN. CHAll6E TC 500 GPil OR RELY CSTROL 110 011. CONTROL letITE SIN D.R.

l ON PROTEUS, PSIIS & ERF. 80GI IIETERS SHON: 200, CGFINI IIAJOR ltARK AIOVE O IS *100." A110 RELAEL IETERFACE TO SIDW 100 Gill.

I 1131 TA 23A. E-0 FR-H-1 STEP 110 RED PATH. LOGIC UP6ftADE 03 IEVISE LOGIC 011 ERF TO DONE SIltlLATOR 2 IIEEDED. CURRElli IID0EL ON FLON SET FLAG ON IlllTIAL AFW D.R. 442 Oil DELTA-P DOES 110T FLAG Floll > 550 GPil. IF FLON VALVES OUT Of LINE. USE FLON > GOES <550 GPil OlECK 550 TO SET FLAG BEFORE ltELYIIIG SIFFICIElli M5F DELTA-P i WI DELTA-P AVAILAILE. THIS AVAILA8LE TO PROVIE >550 WILL CHECK IIONIAL VLV L/0 AT GPII.

SEGilslING 0F SC81ARIO.

1133 TA 1PA AND OTHERS CALCULATOR NEEDED IF. CONTil0L 03 INSTALL DESK CALCULATOR DONE 8031 TO DO POT SETTIIIGS IN C.R.

CALCULAT10llS. EllSultE CALCULATOR lli C.R. AllD/Olt ADD Ralr. TION TO EltF.

1134 TA 18A FRH-1 STEP 9 NEED 25% Wit S/S LEVEL F0ft LOSS 03 OIAll6E LON ALARil ON N.R. OPS WORK!Il6 -

0F HEAi SIllK F.

R. PROCEDURE

. S/6 LVL TO 25% Ill IWDE O NAKE IID0E G W.R. 25% ALANI. GI THE ERF ColrUTER.

OPERATORS FEEL E0P HAS SUFFICIElli EIFHASIS.

1135 TA 25A 6A ECA1.1 STEP 6 CONTAlllllENT SPRAY SUCTI0llS 03 REVISE HS LA8ELS TO EN6!11EERIll6 FRoll SUIF ARE 110T ADE@lATELY LiEELED.

1136 TA 3A 19221 STEP 0 STARTUP REFERS TO PROCEDURE. 03 ENERAVE S/U fil0N stall 08Y DGIE (FilC.1) L0ll6. EllGRAVE S/U Fil0N STAllD8Y AT PCP. SUPPLEIENT ALANI 011 LOCAL PLATE. C3eION IIDDE LAEL.

ALANI 011 H. IUllTOR - 194AT DOES IT IEAll?

i l

l l

l

CEORGI A POtfE3 C004PANY 162 V06TLE ELECTRIC GENERAllll6 PLAlli mulAN EN6118EERill6 OISCREPANCY (MG) STATUS REPORT HED IU WER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUTION STATUS 113T TA 25A E-0 STEP 29 NEED fl0RE LOCATION INFO leflCH 03 PROVIDE POSTil16 0F OPS WOREIN -

CUBICLE IS SELECTED. SELECTED CUBICLE IN PROCHURES A110 WI SELECTIGlVALVE.

1138 TA PA, E-1, STEP 3 SI OCCURS ON 48 C3 NIT, 61Vili6 03 ADO 'AF.'ERSE QNIT* TO SI TO ENGINE RIE I

ADVERSE CINIT. A00 ' ADVERSE AIIMICIATOR.

CINIT* TO AINUICIATOR Mll100N ON St.

1140 TA IA CONTROLS FOR ALAIBl CRT ARE AT 04 A00 ALAIBl CRT CONTROLS AT AFTL?. P.'EL LDA0 UTILITY CRT, BEYOND VIENING IC1.

DISTAllCE. IIAY NEED CONTROLS (2 suTTmS)ON80ARD.

l 1142 TA 1A FRC.1 STEP 8/FRZ.1 H2 AllALYZER IS IlolBIALLY IN 02 ADO A SPECIFIC STEP 111 THE OPS WORKING l STP T STAllD8Y A110 INDICATES ZERO 011 E0P TO START THE H AllALYZER IETERS, RECORDER, PSIE, SPO$. THE ERF COlF. MILL DISPLAY 110 IN01 CATI 0ll THAT IT IS BAD OR OUT OF RANGE INST.

ISOLATED NEAR IETERS 1143 TA, HED 1051 SINILAR PWF SNITQfES All0 CRITICAL 03 USE 00UOLE HIGI, 80LD TO ENGINEERING CGITROLS ARE SofETilES LETTERS FOR PUIFS Ill DIFFICULT TO LOCATE IN ARRAYS ESFAS SYSTEM (SIP, Wit, 0F VALVES. HA110LE SHAPES 00 CCP,SLI,CS)

NOT STANO OUT.

1144 TA E-0 STEP 141810 llETER APPEARS TO BE LOG SCALE. 03 MARK HETER FACE TO SHOW TO MAINTENANCE 80 GPil IS Il0T CLEARLY 80 GPil.

Ill0ICATO.

1149 TA 2TA STEP G FRC.1 8LUE PS ON 8ACK OF RECORDER 03 PAINT OLDE PEN RED A110 OPS WORKING -

IS INVISIBLE. PUT RED PEN 111 RED PEN BLUE, CHANGE INK BACK, OLUE Ill Fil0NT. R0 COLORS Allo RECORDER MISTOOK NIDE RA116E FOR UPPER LE68 0 PLATE.

( HEAD SCALES. CONSIDER llAIE CHAll6E.

i l

CEOftGIA PotfER COMPANY 163 VOSTLE ELECTRIC GENERATING PLANT lANIAN ENGINEERING DISCEPANCY (NE0J STATUS REPORT HEDIMSER ORIGill HED DESCRIPTION CATEGORY PROPOSED RESOLUTIM STATUS 1150 TA NEED All SPOS USERS GUIDE IN 03 WRITE $0P. DWE THE SIIRILATOR 1152 TA THERE IS 110 A10MICIATOR FOR 04 A00 LON OIIT INST AIR AFTER FUEL LOAD LOSS OF IllSTIRNIDIT AIR TO PRESSURE ALAM.

CONTAIIBENT.

1153 TA OBSERVATION CONTROL 200 SNITCH HAllGS UP IN 01 SN00TH PLASTIC AREA DONE BY THE WITHORAN POSITION. CAUSilI6 SNITCH TO STICK. CONSTRUCTIS-1154 TA SCSARIO 25A TST E0 AUXILIARY LfAK DETECTION 03 A00 SUPPL 8 ENTAL LAIELS OPS WORKING -

STEP 29 SYSTDI DCES NOT HAVE LOCATIONS AT TOP 0F ZLB AND REVISE FOR CHAlelELS LA8ELED. ' LEVEL ENGRAVING TO D' A110 ' AUX ILD6*. CLAtlFY LOCATION.

1155 TA SC8tARIO 25A TEST VRVE NUN 8ERS ARE CONFUSillG 03 A00 VRVE LASEL NAIES TO OPS WORKING -

AND ERROR PRONE (Al TAILPIPE RECORDER LIST. DESim SUPPORT TBF, IRILTIPOINT RECORDER. LAEL 1156 TA SCENARIO 25A TST FULL, OYllAlllC, AliD UPPER SCALE 03 POST NINIC A110 Il0lul4L OPS WORKINE, T0 i

FRC.1 STP6 LEVELS ARE CONFUSillG. DYllAlllC VALVES. NINIC IS TRAINillG, l

SisPPLDENT RECORDER LASEL WITH 011 PSIE. letAT A80UT [0ESIGIED RINIC RX VESSEL DIAGRAll, CollSIDER 0 N01 BIAL 7 OUT OF LAllINATE BASE REFERENCE FOR FULL & RFS4-06-631]

UPPER SCALE. THI3 IS ALSD A TRAINING ITEll. POST II01BIALS FOR (4RCP.

l 11ST TA SC8lARIO 25A TS THE 480V DIST BREAKERS TO R:: 03 A00 SUPPLBENTAL LAIELS DONE E,0,STP 1ll110 OPOIED 011 All ATNT llEED TO OE BELON llINIC. 'CR0li 15' HIWLIGITED.

1160 TA 23A TEST ESO.2 STEP G C00LD0lel TREND O!FFICULT TO 03 A00 100*F/HR SLOPE TO RCS DONE USE. A00 100*F/HR SLOPE ON TBF PLOT WI SPOS.

TElf TREND.

1161 TA 23A TEST OPERATORS Call 110T TELL 191101 03 A00 SUPPLBENTAL LAIEL OPS WORKilIG VALVES ARE A0V'S,110V'S, HOLD 'N' STICIER TO N0LD TYPE TO OPDIATE OR ltETAIN CONTACTS VLYS. 110T ElIGRAVED.

(IHVENAPLESHASLISTSFR0ll LOSS OF AIR STUDY.) OR flAltK EXCEPTIONS & TitAlli 31 IIM0lt!TY.

CEORGIA POtfE3 CO84PA88Y 164 V0GTLE ELECTRIC GEN GATING PLANT EMN ENGINEERIN DISCREPANCY (NED) STATUS REPORT HED NUNIER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUTION STATUS 1162 TA SCSARIO 1A ESO.1 INSTRUCTIONS TO CONTROL A 03 REVISE PROCEDURE OR DONE TRAINING PARARETER *AT* A VALUE ARE IMPLEMENT TRAINING TO INCORPORATG OVERLLY RESTRICTIVE AND CONTROL AT APPROXIM TE INio R(H.P-238 INLIED CONTROL BANDS ARE iALVE. AT LOCATI(M SU5 JECT TO RISINTERPRETATION. II.B.3.b.1(c) 1/31/86 1164 TA SCENARIO 11A ESt.3 ECCS LINEUP 15 DIFFICULT TO 03 ADO SIMPLIFIED ECCS TO EM INEERING STEP 3 FOLLON IN PROCEDURES. LAYOUT TO PROCU M E. A00 & MANAGEMNT ECCS P & ID TO ERF REJECTED Ct31PUTER. [ATLANTAGNOUP INPUTING P610'S]

1165 TA SCENARIO 11A E-1 STEP VALVES NITH LOCl(OUTS CAN NOT 03 ADO ' LOCK OUT' OR SYM8OL OPS WORKI E -

17 BE READILY IDENTIFIED. CODE TO HS PLATE DESIGN NS ADO ' LOCK OUT' ENGRAVING MulPULATI(NIS TO P90CDURES.

1167 TA SC D ARIO 21A ESO.2 HOTLEGSUCTIONVALVES[8701A 03 RELA 8EL AS ' HOT LE6 TO ENGINEERING STEP II &8)AND[8702A&8]ARE SUCTION' VICE 'RHR MISLEADINGLY LA8ELED. REVISE 8 LOCKING VLY'.

LA8EL.

1168 TA SCENARIO 21A FEEDNATER CONOUCTIVITY ALA M 84 8 LOCK ALARN ON FEED NATER REVIEW AFL ON PCP IS NUISANCE ALAM IN ISOLATION OR W P TRIP.

POSTTRIP/FEEDISOLATIONBUT REINSTATE W S BLOCK REQUIRES OPERATOR TO LEAVE E8 AND TRIP CLEAR.

TO CHECK.

1174 PR 1 NINDON AL89 - E2 SAYS 'RX TRIP 03 REVISE EN6 RAVING. TO ENGINEDING DUE TO TUR8 TRIP

• SHOULD BE

' TURBINE TRIP DUE TO REACTOR TRIP' IX6AY01-245-3.

1175 PR-2 LIC 580 NANEPLATE IS 03 REVISE ENGRAVING TO Eh61NEERING NISSNUN8ERED 590 1176 PR-6 BFIV'S HV 15196, 7, 8, 9 ARE 03 REVISE LABEL BYPASS FEED TO ENGINEERING LA8ELED 'S61 AFW 8YPASS' 'SG2 ISOLATION VALVE - BFIV AFW 8YPASS' 'S63 AFW BYPASS

• USE MFIV, BFRY, NFRV FOR

'S64 AFW BYPASS' OTHER MAIN FEED VALVES.

GEO8tGIA PO88E3 COMPANY 165 V06TLE ELECTRIC SalERATING PLANT IRNinal ENGINERIES DISCREPANCY (NED) STATUS REPORT HG llulEER ORIGIN HED DESCRIPil0N CATEGORY PROPOSED RESOLUTION STATUS 1177 PR-7 AAI VALVES TO $6'S IS ERROR 03 USE LARGE S/6 8'S ON HS. TO Ell 61NEalNG LIEELY FOR NDTOR ORIVD AFW RETAIN CURRENT LAYOUT, VALVES. RECom!!Ill6 THAT PUlr ORDER IS REVERSED, BUT 1W05 00110T IIFROVE SITUATION OUE TO TIET BOARD.

1180 PR 15, 62 ARY SEQUEllCE IS *14 23' OUE 04 RELA 8EL NITH PRONINBli TO EN61NEERIII6, TO FIRE SEPARATION CRITERIA LOOP 8'S. RELOCATE STEAll FORTRAINA/B OlNF CONTil0LS A110 nFaaaamar ARV'S.

1181 PR-17 BORIC ACIO AND luti VALVES ARE 02 RELABEL (HS 1118&1108], TO 816IllEERIll6 NOT CONSISTST NITH FIC'S All0 SilAP (MS 110A & 111A]

RIGIT, LEFT. SUGGESTI0ll TO GILY.

MAP [115118A,111A] All0

[1188,1118] & IELA8EL 1151118

• E FEDFa GUTLET TO VCT' HS 1188 *m FunFa WTLET TO CHAllBING PLNFS*.

1182 PR 18 HIIH ENER6Y LINE BP G KS TBF 03 REVISE AllD SUPPLEMENT DONE SELECTOR USES ROM I'S. NED LAEL NITH 200N NAlE.

ENNI AND ESilP NAIE TO AID OpetATOR.

1183 PR 22 LA8EL IS MISLEAD!II6, REVISE. 03 RELA 8EL 'LON STN PRESS

• TO 0161NEERIll6 l 'Si/Su BLOCx-l 1184 PR 27 LAELS ON HV 8438 & 8104 REFER 03 REVISE LA8EL TO USE TO ENGINEER!ll6 TO 016 PPI. SHEILD BE CCP-A & 'OER6 80 RATE' TO CCP-8 TAG IRNERS IlOT USED IN CCP-A/CCP-8 GPERATIONS.

CEORGIA POWE3 COB 8PA88Y 166  ;

VOSTLE ELECTRIC BENERATillG PLMT EBIANENGINEERIIIGDISCRL7ANCY(NED)STATUSREPORT HED NUleER ORI61K HED DESCRIPil0N CATEGORY PROPOSED RESOLUTI0li STATUS 1185 PR 28,29 POOR LA8ELS ON: (PRZRSPRAY) 03 REVIEW LA8ELS, REVISE AS TO ENGINEERING (PIC-455A,8,C)(HV-8098] NEEDED.

1186 PR 30 LETD0lel ISOLATION VALVES 03 ADO SUPPLDENTAL LA8ELS OPS WORKill6 -

(HV-8164,8152] AREIIOT (STICKON)WITH'CI',

IDENTIFIE0 AS Outi ISO VALVES, 'SI*, 'CVI' TO VALVES IN AND REVISE OTHER ONIT 150 E0P CHECRISTS.

VALVES THAT SHOULD BE IDENTIFIED.(PRTFILL,RECIRC, ISO 8434,8028] (RCDTYENT&

DISOI7136,18436,7126, 7154].

1188 PR-37 LA8ELED IllCORRECTLY, ALSO 03 REVISE LABELS. IO ENGINEERING OIECK OTHER RX IRJ NTR VALVES FOR POSSIBLE RELA 8ELIIIG.

1190 PR-47 CAN'T DETEmillE FROM PRESBT 03 REVISE LABEL OPS WORKING -

LABEL THE DIRECTION OF INTE110ED FLOW (T0100TIELL OR TOCST) 1192 PR-51 SWITCH lilSLA8ELED AS VACUlst 03 REVISE LA8EL TO ENGillEERING PINF.

1195 PR-60 SEVERAL OF THE LIGHTS 03 REVISE P-9 WINDON TO TO Ell 611tEERIIIS l ILLUlilllATE leta THE PERISSIVE 'TUR8 TRIP /ItX TRIP' l CINIES IN, fe PL ILLUlilNATES 8 8 LOCKED P-l l 10-181CA, tellLE OTHERS ARE l ILL1511NATED WITNGIT THE l PEINIISSIVE, IE P1 & P9 1196 PR-57 letEll THESE VALVES ARE OP8tED 04 INSTALL AUTO START 011 REVIEW AFL YOU llAY OR flay IIOT GET FLGI, PUlFS lelEll VALVES OPEll.

AS THE TRAllSFER PUlFS llAY NOT i E 182511116. CGISIDER AD0lilB AN AUTO START TO THE MNFS 10lElf THE VALVES AllE OP81ED.

1197 PR-63 ADO SUPPLEIENTAL LA8ELS TO 125 03 ADO 'OIARGE' ' DISCHARGE

• DGIE LAELS VDC AINIETERS TO INDICATE LA8EL IllSTALLED

'OUUlGE' Olt ' DISCHARGE *.

ww_w - - - - - - -, + , - - - - - -

CEO8tGIA POWER C088PANY 167 V06TLE ELECTRIC GENERATIIIS PLANT IRNIANENGINEERINGDISCREPANCY(NED)STATUSREPORT l

, MEDIRESER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUTION STATUS i

1188 PR-54 Cleli 150 PHASE 8 HAS NO EFFECT 02 REMOVE ACTIVATION & RESET TO ENGINEERING NS. REMOVE AleamCIATOR l Nill 00N.

1189 PR-34, PR-44 LABELSFORHS-88758(ACCUM 03 REVISE LA8ELS. TO Ell 61NEER!ll6 l N2), MS-2859C (T8 SNORE SYSTEN), NEED TO BE REVISED TO 310RE CLEARLY Iil01CATE Rn1CTIGl.

1200 PR-66 & PR-67 AL811E01 & AL838081 ENGRAVill6 03 REVISE EN6RAVlil6S TO E116111EERING DOESIlOTADEQUATELYREFLECT INTENDED IESSAGE. [ALB11E81 PRZA HI LEVEL CHAIBIEL ALERT)

[AL838001 D618 PRESS FUEL OIL)

I 1201 PR-65 8OTH Illa 05 VM SWITCHES ARE 03 REVISE LA8EL TC EN6118EERIl16 l LABELED 'l10Ril IllCOIIIN6', OllE OF THEll IS NISLABELED All0 SHOULD READ ' ALT INColllll6*.

t 1206 A88tEVIAT!0ll & ACRONYli Il0NENCLATURE IlOT STANDARDIZED, 03 REVISE LA8ELS PER TO El161NEERIl16, SURVEY SEE AAS. REVISE NORDIll6 0F APPROVED A88 REY. LIST.

l THIS HED l

1207 PR-68 P-13 81STA8LES ORDERED ON 03 REVERSE PI'S TO NATCH TO Ell 61NEERIll6 TSL8-2 [TUR8 PNR P-13 CH I 81 STABLES AllD SEquBICE P9-545A] [TURS PIEt P-13 CH 11 tilST. 505,586.

P9-586A] IETERS ARE ORDERED

[1PI-546&IPI-585]

120! PR 69 '1' AND 'I' 180T 03 REVIEN AND REVISE OPS WORKIl16 distill 6UISHA8LE. Ell 6RA"!IIGS AIERMCIATOR EllGRAVll16.

IN ERROR. LISTATTADIED(4 PAGES).

l

GEORGIA pot 0ER COMPANY 168 V06TLE ELECTRIC GENERATING PLAllT 1R81A11ENGINEERIII6 DISCREPANCY (NED)STATUSREPORT HED IR5BER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUTIGI STATUS 1289 PR-71 ACCIDENTAL NMIPULATION OF A00 03 RBIOVE HANDLE ANO XEEP OPS WORKINE -

CGITROL STARTUP RESET SWITCH ADilINISTRATIVE CONTROL PROCEIRIRE WIPES OUT 1100 PROGRAll. ILIST SINCE IT IS USED GILY SUGGESTIE IIOT BE OPERATED AT POWER. DUR!ll6 STARTUP. SUB11TTED, EST.

1-MS-40038. CCIF. DATE 30, JULY 1210 C0lgullCATION SURVEY BY DAll INADVERTENT PUSHill6 0F TEST 03 GUARD TEST SUTTON WITH OPS WORKING -

NILSil RITTON DUR!ll6 CASUALTY FLIP UP COVER. FLIP UP COVERS DISIRIPTS OPERATIONS A110 RECEIVED AS DISTRACTS ALL OPERATORS NEN ESCUTOEON llulENTARILY. PLATES GI GRDER 1211 Al81Ull. SURVEY (Alls-3) ATTACHED LIST OF Al91UllCIATORS 03 WRITE AlERAsCIATOR OPS WORKING (IIURE607006.3.3.4.) ARE 'IEJLTIPLE CHOICE' RESP 0llSE PROCEDURES TO AlBUICIATORS. DETAll IllPUTS FOR 1RILTIPLE CHOICE AIBMICIATORS. PROVIDE CGITil0L A0G1 Ill0!CATIGI FOR HI/LO AUUBIS T0 ALLOW OIAGNOSIS.

1212 A10MI. SURVEY (AAIS-3) A LISTIIIG OF A101UllCIATORS WITH 03 816 RAVE NEW ANNUllCIATORS TO ENGINEERIll6 (HURE607006.3.3.4.) LAIAPPfl0VED A88REVIATICIIS To llATCH ABBREVIATION - OPS ICIKING LIST. ON PROQlRBEllT

- ORDER AIERRICIATOR EAllK PLATES 1213 OPERATOR CalgENT, llVREG ALAlul CLEAR Holti SOUNDS 04 REPLACE HOW WITH 8 ELL OR TO DIGInrFR mR 8700(6.3.1.5.) CONTINUOUSLY UllTIL ALL CLEARED TillE OUT HORIl (1 SEC.)

ALAlWIS CII ALL PAllELS ARE IIESET. CollTINUOUS IIDISE IN PLANT UPSETS IS FATIG!!II6 ANO DISTRACTING. NUltE6 8700 ItECOBOENOS FINITE DURATION.

Silt!LAT0ft PREVIOUSLY USED ELL.

1215 PR08LEN REPORT 875,108 AleMI. 001 & EDI D0110T 03 AISIUNCIATOR WIN 00NS WILL TO BIGINEERING ACCURATELY DESCRIBE THE BE IIODIFIED TO REFLECT SY ADO ON PRESSURIZER CollDITI0ld AS THE ACTUAL PLAllT DETECTED BY THE COIFARATOR C0NDITION AS DETECTED BY OUTPUT 81 STABLES THE CHAlelEL COIFARATOR CUTPUT.

CEO8tGI A POWER COMPANY 169 V06TLE ELECTRIC GENERATING PLANT MNIAN ElI6!IIEERIll6 DISCREPANCY (NED) STATUS REPORT HED NUM ER OR16111 NED DESCRIPTION CATEGORY PROPOSED RESOLUTION STATUS 1216 PR08L91 REPORT 876 AINI. AL851805 EN6RAVIll6 DOES 03 AmuMCIATOR WINDON WILL OPS NORKINS -

NOT AGREE NITH DRANINGS BE IIDOIFIED DIANGE NITH EN6 Penrsm ar IN FEB 86 1217 PR08LEN REPORT 877 AINI. AL811A01 DOES NOT 03 AINUICIATOR WillDON NILL OPS IEIRKING -

ACCUU TELY DESCRIBE ALAINI BEIIO0!FIED CHANGE NITH EN6 INPUT PROCOURE FE8 86 1218 PR-78 HAND CONTROLS HIC-606A 6 60TA 03 RELABLE HIC TO CORRESPONO OPS WORKING -

AltE LA8ELED REHEATER HXI(2) TO MAIEPLATE LA8EL CHANGE WITH ENG OUTLET. THESE ARE IIHR OUTLETS, PROCU MtE IN llAIETAGG 1X6AV02-259-2 ARE FEB 86

'186R HX DIS 01' ' TRAIN A(8)*

1219 0.E.R. SER 79-84 N0ll!TORIl16RCSLEVEL(00RIII6 02 tilSTALL TElrollARY DONE DRAINED 00101 CONDITION) U51116 tilSTRUIENTATION FOLLONING TY90N TUBIll6 C01BIECTED TO THE ilSAC-52 GUIDELINES

,. RCS HAS CAUSED IMEROUS IllSTANCES OF IllCORitECT LEVEL INDICATION AllD RESULTED IN A LOSS OF SillTDOIII COOL!NG.

RE H ISAC-52, SER 60-83, SER 78-81, & I.E. 81-89 l

1221 ElI6, QUESTI0lNIAIRE, HED RAIRJAL CONTROL ACTI0llS ARE 03 REVISE CONTROLLER TO LET OPS NORKIll6 -

1141 IllCONSISTEllT WITH POPULATI0llAL 'UP' SUTTON RAISE THE STERE 0 TYPES, TRAINIII6, AllD PROCESS PARAIETER IN INDUSTRY CONVEllTIONS. Sole Pfl0 CESS CONTil0LS AllD OPSI CONTil0LLERS RAISE THE VLV IN YLV CONTil0LS.

PAltAIETER ON PUSHIll6 THE 'UP' LA8EL CLEARLY INDICATE AltN0llS, SCIE DECREASE. PROCESS OR VLV CollTROL.

LA8Elll16 IS S01ETIIES SPLYNT D01A110 INDICATI(Il IllSLEADIIIG. WITH ' Opal

• Olt OTHER INDICATIGl. IIAIRIAL CONTil0L OVERRIDE Olt AUT0/

1224 IIUREG 0700(6.3.3.1.) LAIF REPLACEMBli REQUIRES THAT 03 IIRITE UPPER LEFT DONE CORPLETED AINUICIAT0ft TILES BE ROIOVED, C00RDIllATE ON BEZEL TO 5-7-86 TH8tE IS 110 IMIBER OR AIG Ill REPLACBENT.

IDOITIFIER ON THE TILE TO SISultE IT IS ItEPLACED IN THE ColtitECT LOCATIGl.

CEOftGIA Pot #EQ COMPANY 170 V06TLE ELECTRIC GENERATING PU NT IRINM ENGINEERilI6 DISCREPAllCY (NED) STATUS REPORT HED NUMBER ORI6ill HED DESCRIP110N CATEGORY PROPOSED RESOLUTION STATUS 1225 HURE60700(6.3.3.2.) 1HERE IS NO C00!Il6 AllD ADNIll 03 USE GREBI FOR NORNALLY ON DONE -

CONTROL FOR A10MICIATORS 16lICH Will00NS (LIFT PLar AllD SR PROCEDURE IRAST BE ON FOR EXTEllDED VOLTAGE).REVISEOUTOF APPROVED PERI 005 DURIN6 NORNAL SERVICE PROCEDURE TO FLAG 3/19/86-OPERATICIlS. FAILED OR Ill0P 10018-C AIBMICIATORS.

1227 IluRE60700(6.3.4.2.) AISMICIATOR CONTROLS ON THE 03 COLOR CODE THE OPS WORKIE.

QPCP & ()(VC ARE IIOT COLOR AINMICIATOR CONTROLS WITH NEN ESCUTOEM CODED DISTIl1CTIVELY. QllCS USE All ORANGE THAT IS OF A PLATES 3 1911TE, DIFFERBIT Fil0N SHADE IIOT TO BE CONFUSED ORDER, SEE ED SMITCHES, NT PCP & HVC HAVE WITH SAFETY INJECT!0Il 1224 ALL CONTil0LS leilTE, AllD QEA8 SYSTER COLOR.

IS IIDSTLY EACK.

1229 IlURE60700(6.6.2.1.) QHVC IETER 8EZEL THICDESS FOR 03 SPACE UPPER LA8ELS OUT OPS WORK! E -

UPPER RON OF IETERS. WITH 1/2' PLASTIC STOCK. WRITEREQFOR ASSIST 1233 OPERATill6 EXPERIENCE DURIII6 E0P VALIDATION AT 02 ADD THE S.G. DISCREPAllCY OPS REViEN 833 SUlelER 81 A DISCREPAllCY llAS TO THE OPERATOR TRAINIII6 NORRING,TRCIIING LER-395-84037 OBSERVED BETWEEN THE 5.6. WIDE PRO 6itAll AllD PROVIDE 6 IIICORP. N RANGE ANO llAllR0lf RAlIGE LEVEL INFOIBIATION FOR SR-LP-478, INDICATIONS AT 100% S.6. CORRECTING ' COLD

• 3.8.1,2,3 LEVEL. THIS SHOULD HAVE BEEN CALIBRATED TO All EXPECTED ltESPONSE, BUT llAS CORRESPSDIII6 HOT PLAllT HIERARCHICA; IIOT COVERED Ill 0PR TilH. DATA STEAll GENERATOR LEVELS, LASEL ORDEED.

BOOK HAS 110 CONVERSI0115. Ill THE PLAllT DATA 800K.

1234 OPERATING EXPERIENCE SER 78-83 ColeEllT 83 RD10 Vill 6 02 ESTA8LISH ADilINISTRATIVE OPS N0llKIE REVIEW 814 AUUBI INPUTS- Fil0N PROCESS CONTROLS FOR ROIOVAL 0F COIFUTER PElBIITTED THE PLAllT ColNUTER ALAINIS BY THE TO OPERATE OUTSIDE ESTA8LISHED OPERATOR. AD0 TO UNITS WITHOUT llAllNIH6 THE AleMICIATOR STATUS OPERATOR.110 ADRIN CONTil0LS PROCEDURE.

EXIST FOR ltD efAL ALAIBl POINTS.

1235 OPERATIll6 EXPERIEllCE A RHR PL2F LON FL0li ALAllil IS 02 PROVIDE All llHR LON FL0li AFTER FUEL LDAD REVIEN 812 & IIS 100T PROVIDED TO IIAllN THE ALAIBI IN THE CollTil0L 1100N CONTROL ROON OPEAATOR OF All (ANNUllCIATOR, OR PROCESS, W R LON FLON CONDITION. ORERF).

CEORGIA POWEQ COMPANY 171 VOSTLE ELECTRIC GENERATIIIS PLANT ltIHN ENGillEERING DISCREPANCY (NED) STATUS REPORT HEDIUWER ORIGIll HED DESCRIPTION CATEGORY PRCPOSED RESOLUTICII STATUS 1236 CGITROL ROON COMPUTER OPERATOR /COMPUTERDIALOGUE 03 ERF COMPUTER AND PROTEUS OPS WORKIE THE SURVEY N.R. 0700 COWUTER QJTPUT TEXT USES COWUTER USE PROTEUS REVIEN 5.1.1.2. A88REVIAT10NS MD CONTRACTIONS A88REV!ATIONS TO IIATQI IS COWLETED AND SHCULD BE AVOIDED. OTHER PLAllT WT NOT N(NEMCLATURE, AND IWLDENTS, NAXINIZE INF0 M ATI(Il N THE ERF REVIS GlE PRINT LINE. BOTH NILL HAS NOT STARTED BE REVIEED FOR CONSISTBCY NITH PLANT A88REVIATIGl AND ACRWlYN LWT.

1239 COW UTER SURVEY N.R. COMPUTER KEY BOARDS USE 03 REMOVE EXTRMEOUS KEYS DONE APRIL, 0700 S.7.1.4. EXTRANEOUS KEYS A110 SYN 80LS. A110 8LAllK OVER H0LES. 1986 PROTEUS (INRISED KEYS &

SYN 80LS) ERF(VIDEOCOPY) 1242 CGIPUTER SURVEY N.R. PAGE DESIGNATOR, ERF COMUTER 03 REVISE ERF HEAT SilE OPS WORKING -

0700 E.7.2.5.H DOES IIOT DISPLAY THE PAGE PAGESTO*1/20F2'.THE REVIEN AND IMWER All0 THE TOTAL IMWER OF INPUT GROUPIllG FullCTItal NRITE LETT B -

PAGES 1818 DATA IS CONTAINED IIAY DEVELOP IRJLTI-PAGE CHECK SIIER ATOR GIItiLTIPLEPAGES(HEATSINK). LISTS RJT OPERATOR l PRO WTS LEAD THE OPERATOR TO PAGE F0MARD OR BACE.

1246 COW UTER SURVEY N.R. DATA POINT IN0!CES, SPECIFIC 03 DEVELOP A HAlto COPY CROSS TO ENGINEBING 0700 8.7.1.8. PolllT 10: THAT Call 8E CALLED REFERDICE FOR THE UP SY THE OPERATOR ARE IlOT PROTEUS. THE ERF ON-LINE CROSS-INDEXED BY THE CAPA81LITY EXCEEDS THIS FOLL0NilI6: 1) ALPHANUERIC, 2) SJIDELINE.

IIOUN NAIE, 3) SYSTEN, 4)

RNICTI(NIAL Gil0UP. IN A00!TIGI, A HARD COPY CROSS-INDICES SHOULD E PROVIDED IN QITL 151 1255 AllTHROPONETRIC SURVEY PROVISICII IS 110T IIADE SO THAT 03 THE DESIGil PROVIDES DONE N.R. 0700 6.1.2.6 PROCEDURES AND REFERENCE ADEQUATEDESKSPACEFOR RATERIALS CAN BE CONSULTED PROCEDuitE LAYOUT EASILY 181ILE TASK SEQUBICES IlOEDIATELY BEHIND THE AllE PERF08ED AT THE Ntm. OPERATOR. H0 LEVER, E WILL PROVIDE A RAIL IEMITED TRAY AND A lEISIC stall 0 FOR CGITlWL B051 USE Allo EVALIAATE OPERATolt ACCEPTAllCE Allo USE.

CEORGIA POWER COMPANY 172 V06TLE ELECTRIC GENERATil16 PLANT IRflAll EM61NEERIl16 DISCREPANCY (NED) STATUS REPORT HEDIRESER ORIGIN HED DESCRIPil0N CATEGORY PROPOSED RESOLUTION STATUS 1260 8-H SURVEY 0700 N.R. THE GROUPIll6 0F DIGITS ON THE 03 ADO A DECI K POINT TO OPS WORKING -

6.5.5.1.a(3) TOTALIZER ARE IN EXCESS OF 4 THE 80RIC ACID TOTALIZER ROZIllSKY TO DIGITS AND ARE IIOT SEPARATED AND T)RENRetEEL. ADD PAINT DECI E BY CapelAS AND DECINAL POINTS. COIIIAS IN 3 DIGIT POINT ON SE9ENTS. TOTALIZER 1261 COlFUTER SURVEY N.R. A COPY OF THE CURRBIT 03 IIAINTAIN A COPY OF TO B16111EERIl16 0700 6.7.1.1.b beiRATill6 SOFTWARE IS NOT SOFTWARE IN DOCUNENT STORED IN SECURE RBIOTE CONTROL LOCATION 1265 COIIPUTER SURVEY N.R. COMPUTER CRT ARE NOT PROVIDED 03 110 ACTION, CRT GLARE OPSISREING 0700 6.7.2.1.b WITH AllTI-6LARE SCREBIS TO PROBLBIS HAVE NOT 8EEN ORDER NININIZE REFLECTED GLARE AT REPORTED IN THE CONTROL ANTI-GUutE IIONIAL OPERATOR VIEN!Il6 All6LES R0011 OR THE SIltiLATOR SCREBIS, l MITH IIOWIAL LIGITil16. THE [PROTEOUSAND l CRT'S AltE FOR OCCASIONAL ATSI)

VIBIING,11DT FOR l

l CGITilRIOUS USAGE AT CLOSE 4 DISTANCE telERE GLARE NAY RESULT Ill OPERATOR DISCGEORT.

1266 COWUTER SURVEY N.R. DATA THAT IS PRESBITED IN 04 REVISE DISPLAYS TO AFTER FUEL LOAD 07006.7.2.4.j(1) TA8ULAR FOSI THE IMERIC DATA PRESBIT CONSISTENT IIUISER IS RIGIT JUSTIFIED RIT THE OF DECIllAL PLACES. THE DECIllALS AltE IIOT ALIGIED DEVIATIC11 NAKES THE l COLINEl LOOK CLUTTEltED Eli WILL 110T CAUSE EltRORS IIFACTING OPBtATIGl 1268 COIFUTER SURVEY ll.R. GRAPHIC CODES ARE IIOT USED 04 RBENE IION IllSTilulENTED TO ENGIllEERIll6 0700 6.7.2.7.h CGISISTEllTLY, VALVE OUTLINE VALVES Fil0N THE DISPLAYS F0lt 11011-IllSTIMENTED VALVES TO AVOID CONFUSION. 011LY DOES Il0T IEAll THE VALVE IS VALVES FOR lei!Of POSITIO11 OPEN. IS IWOINI SHOULD BE SH0lm.

l 1273 8 & H SURVEY N.R. 0700 SONE ROTARY SELECTOR SWITCHES 03 REPLACE WITH POINTER T DONE

! 6.4.4.5.d.(1) ARE NOT PROVIDED WITH THE SWITCH HANDLE TO RATQI REcolelENDED POSITION GUIDELINE. THIS ALSO

.. . . . . g, wu.ia aj, CORRECTS HED - 1275.

(DELTAT&TAV6] DEFEAT SELECTOR SW (TS 411E & F All0 TS412T).

CEORGIA POWER COMPANY 173 V06TLE ELECTRIC 680ATING PLAllT lANt4N Ell 6!IBEERIII6 DISCREPANCY (NED) STATUS REPORT HED IREWt ORI61ll NED DESCRIPTION CATEGORY PROPOSED RESOLUT!WI STATUS 1275 8 & H SURVEY N.R. 0708 THE FOLLOWill6 CollTil0LS ARE NOT 03 REPLACE NS-411 Allo 412 DSE 6.8.3.1. SEPARATED BY THE RECOMENDED WITH T SHAPE POINTER DISTANCES: MS-411E & F AND HAllDLES. THIS ALSO HS-412T ARE NOT INSTALLED WITH C0ltitECTS HED- 1273.

THE RECOINEllDED SPACE 8ETWEEN

'J' HAllDLES.

1276 LA8ELIllG, NINICS, & THE CURRENT REV-0 0F THE 03 REVISED 10009-C OPERATOR DONE 10009-C DDIARCATION 0700 OPERATOR AIDS PROCEDURE DOES AIDS PROCEDURE ADOED NEN PROCEDURE 6.6.5.1.b,6.6.5.2.b(3) IIOTREQUIRETEMPORARYLA8ELS STEP 3.3.3 ATTACHED. APPROVED TO CFAF01BI TO 6000 HUMAN 3-19-86 8161NEERIll6 PRIllCIPLIS.

1277 LABEL!ll6,RINICS,& THE CURR0li REV-0 0F THE 03 REVISED 10009-C OPERATOR DONE 10009-C DO ERCATI0ll N.R. 0700 OPERATOR AIDS PROCEDURE DOES AIDS PROCEDURE SEE STEP PROCEDURE 6.6.5.1.c IIOT PROVIDE IllSTRUCTIONS THAT 3.4.1 APPROVED REQUIRE TB@0RARY LABELS 00 3-25-86 NOT 08SCURE PERNMENT LA8ELS.

1278 LA8ELIII6, NIlllCS, & THE CURRENT REV-0 0F THE 03 REVISED 10009-C OPERATOR DONE 10009-C

DDIARCATION N.R. 0700 OPERATOR AIDS PROCEDURE DOES AIDS PROCEDURE ADDED IIEW PROCEDURE

! 6.6.5.2.b.5 110T REQUIRE A DETERillllATION OF STEP 3.3.5 APPROVED I

THE IIFACT OF THE USE OF THE 3-19-86 TBrORARY LAEL 011 OTHER SYSTBIS AllD EQUIPIElli.

1279 LA8ELil16,NINICS,& THE CURRDIT REV-10F THE PLANT 03 REVISE PROCEDURE 00254-C DONE DOIARCATI0li ll.R. 0700 HOUSEKEEPIll6 AllD CLEANilESS T0 tilCLUDE CLEAll!II6 6.6.2.4.d CONTil0L PROCEDURE DOES IIOT LABELS umem THE CLEANIII6 0F LAELS.

1280 AINIUllCIATOR SURVEY N.R. PLAllT PROCEDURES 00 Il0T 03 REVISE TUR110VER PROCEDURE DONE i 07006.3.4.1.d(2) REQJIRE THE PERIDOIC TESTill6 TO IllCLUDE TEST OF Pil0CEDURE l OF AINRalCIATORS. ANNDilCIATORS EACH SHIFT 11872-C 5/1/86 1281 AINIUllCIATOR SURVEY N.R. REFLASH CAPASILITY SHOULD BE 04 IllSTALL All AUDIBLE AllD TO 07006.3.1.2.c(3) PROVIDED FOR 1RJLTI-IllPUT VISUAL ltEFLASH 011 THE ERF ENGINEERING.ATL AINIU11CIATORS TO ALLOW COMPUTER FOR ALL AllTA FOR EF SU8 SEQUENT AUUNIS TO ACTIVATE RAG lATION ALAIBIS. INSTALLATIS THE AUDITORY ALERT IIEQlAlllSil A110 ItEFLASH THE VISUAL TILE EYBI IF THE FIRST AUUpl llAY NOT HAVE BEBI CLEAltED. (EX.

IIIS, 8US Tit 0U8LE ALARMS) l

CEORGIA POWER COMPANY 170 V0GTLE ELECTRIC GENERATING PLANT ENN BI6INEERING DISCREPANCY (NED) STATUS REPORT HED RISER ORI61ll NED DESCRIPTION CATEGORY PROPOSED RESOLUTION STATUS 1283 PROBLEN REPORT 895 HS-814TA IS INCORRECTLY 03 RELA 8EL TO CORRECT ERROR OPS WORKIE -

USELED HV-1847 ON ORDER 1284 PROBLEN REPORT 8100 1PI-50T S.G. HEADER PRESSURE 02 RESCALE INSTRUNEllTS TO TO IIAINTEllANCE AND 1PI-508 F.P. HEADER IDENTICAL RANGE TO PRESSURE ARE USED TO SETUP THE FACILITATE COIFARISON.

1st F.P. Ill AUTO CONTNOL. THE SCALES ARE DIFFERENT MAKING IT AINQlARDTOSETUPTHEOP.(50T IS 0 TO 1300 PSIG & 508 IS 200 TO1544PSIG) 1285 PR00LER REPORT 8101 NR-45 NUCLEAR INST. RECORDER. 02 N00!FY OR REMOVE 000R TO TO NAlllTBNCE IT IS DIFFICULT TO SEE IIFROVE SCALE VISIBILITY. - M 0 SURITTED INDICATING PBIS Allo SCALES WITH THE ItECORDER 000R CLOSED.

128T OPERATOR QUESTIOWAIRE 8 THE BREAKER CONTROLS LOCATED 02 ADMINISTRATIVELY BAR OPC WNtKING -

0040-08, 0057-02 & NEAR THE SS PLATFONI IN THE TRAFFIC Ill THAT AltEA. SumIfTED 0028-23 QEA8 ARE SU8 JECT TO REVI9 31 TO INADVERTEllT OPERATION SY REG. ( M .

PASSIE TRAFFIC. 3-?? 46 1288 OPERATORQUESTI0MAIRE SOIE IIAIN CONTROL 80ARD 03 ItEPLACE INDICATOR OPS WORKIE -

0080-12 & 0028-26 INDICATOR LEllS IIERE DAMAGED BY LBIS/ WIN 00NWITHM81 0.R 110-461 THE USE OF A CLEAllIII6 S0LVENT IION-6LARE PART. ITBI15 Allo AllE 11011 OlFFICULT T0 ItEAD.

l 1289 OPERATORQUESTI0mAIRE S6 84 LEVEL CONTROL AND BYPASS 02 USE A SUPPLDEllTAL LA8EL OPS IIORKIE -

0033-01 & 0067-G1 VALVE CONTil0LLERS ARE LOCATED TO TIE TOGETHER THE LAEL HAS EEll CLOSER TO SG 83 LEVEL RECORDER CONTil0LLER Allo REcolt0ER FA8RICATED l thall THEY ARE TO SG 84 LEVEL LASELS.

ItECORDER. THIS HAS ItESULTED IN

! CONFUSION IN THE SilWLAT0ft.

1290 OPERATOR QUEST 10lulAIRE THE CONTROL SWITCHES F03 THE 04 REPLACE SWITOI IIOCULES OPS WORKING, 80080-01 AIR COIFRESSoftS VIOLATE WITH A C81 TRAL AUTO INDUSTRY STANDARDS BY USIll6 A POSITION THAT DOES IIOT

' PULL TO LOCK AUT0' POSITICII, CONFLICT WITH THE ' PULL IIDWIAL CONFIGURATION IS ' PULL TO LOCK

• OFF INDUSTRY TO LOCK' THAT ltE40VES CONTil0L CONVBITICII.

PONER.

GEOftGIA pot $ER COMPANY 175 V06TLE ELECTRIC GENERATIM PLANT IRNIAN ENGINEERIll6 DISCREPANCY (NED) STATUS REPORT HED IRSER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUTIGI STATUS 1291 OPERATORQUEST!0lNIAIRE THE STEM & FEED NATER FLON 03 RELA 8EL T0 llATCH LEFT - DONE 80058-01 CONTROLLill6 CHAlNIF.L RIG (T SWITCH DIRECTION.

TOGGLE-SNITCHES ARE CONFUSIII6 AS 70 ist!CH DIRECTION THE SWITCH IRIST BE OPERATED TO SELECT A CHAlulEL FOR CONTROL.

1293 COLOR C00lll6 SURVEY LOOPS 1, 2, & 3 0F THE 03 CORRECT COLOR ERROR, ALL OPS WORKIN6 -

FEEDNATER ISOLATION VALVES ARE IFIV's SHOULD OE DAllK ON ORDER COLOR-CODED GRAY, LOOP 4 E.UE.

FEEDilATER ISOLATION VALVES ARE COLOR-C00ED OLUE. (ESCUTCHEGI PLATES).

1294 AINR41CIATOR SURVEY N.R. THE ADJUSTIIENT OF THE CONTil0L 03 ADO THE APPROPRIATE OPS NORKI M 0700 6.3.2.1 & OAC 9 ROON AINIUllCIATOR ALARil TONES STATENENT TO THE 'C W OUCT i IS Il0T CONTil0LLED SY OF OPERATIONS

• PROCD URE l AGIINISTRATIVE PROCEDURE. 10000-C l

1297 GENERAL PANEL CHECKLIST CONTROL ll00N INDICATORS ARE 03 REPLACE THE RECORDER TO IIAINTalAllCE I

6-29 110T SCALED WITH SUB0lVIS!0lls SCALE TO CONFOINI TO THE Ill DECIllAL IRILTIPLES OF 1, 2, al!DELIllE.

OR5.[ RECORDERS 1-UR-12627&

12628VIOLATETHISElIDELINE) 1299 GENERAL PAllEL SURVEY 6-7 THE ATTACHED LIST OF LA8ELS 03 REVIEN AND NDDIFY LA8ELS. OPS WORKING -

l (QHVC) ARE NOT ACCURATE WITH RESPECT HS Gl ORDER AND l TO ITS FUllCTI0ll OR INPUT llAIE PLATE HAS i SIlillAL, OR A88REVIATION AND SEEll FAMICATED ACRONYllLIST. [0NLYINSTALLED IN THE SilRILATORJ 1300 GEffERAL PAllEL SURVEY 6-7 THE ATTACHED LIST OF LA8ELS 03 REVIEN AND IIDOIFY LABELS. OPS WORKIll6 -

(QPCP) ARE Il0T ACCURATE WITH RESPECT ON ORDER TO ITS RNICTIGl OR INPUT SIstAL Gl A8MEVIATIGI AllD AcaGIYli LIST.

I y ,-.---- -

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r - - - - - - - - - - - - - - , ----

CEORGIA POWER COMPANY 176 10GTLE ELECTRIC GENERATIIIS PLANT Hl51ANElIGINEERINGDISCREPANCY(NED)STATUSREPORT HED IRASER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUTION STATUS 1301 G81ERAL PAllEL QiECKLIST THE ATTACHED LIST OF LA8ELS 03 REVIEN AllD N00lFY LABELS. OPS NORKING -

G-7QNC8 ARE NOT ACCURATE WITH RESPECT NAIEPLATES IN TO ITS FUNCTION OR INPUT THE SIlulAL OR ABOREVIATION A110 MIERARDilCAL ACRONYliLIST. LAEL PACMEE AMI ltS LAE15 W OROEI 1384 P.R. 186 ACS LOOP 1 A110 4 PRESS 03 RELA 8EL PI-408 TO ACS OPS IRMEING -

j Ill0ICATORS ARE NISLA8ELED AS LOOP 1 HL PRESS III, THE IIAIEPLATE

LOOP 1,2,3,4, AllD AS IIARil0N PI-418 TO RCS LOOP 4 HL IS IN THE RAIIGE. ALL AltE ON LOOPS 1 OR 4 PRESS IV, PI-428 T0 llCS HIERARQlICAL l All0 ALL ARE FULL RANGE. LOOP 4 HL PRESS II, LABEL PACKAGE PI-438 T0 llCS LOOP 1 HL PitESS 1.

l

( 1305 PR 107 PI-403/405 ARE IIISLA8ELED 'RC 03 RELABEL PI-403 T0 llCS OPS WORKIIIG -

LOOP 1(4)HLWIDERAlIGE' LOOP 1 HL PRESS, PI-405 THE IIAllEPLATE SIlICE ALL PitESS Ill5Tul5ENTS TO RCS LOOP 4 HL PRESS IS IN Tile

. ARE FULL RAllGE 'NIDE RAlIGE' IS HIERARDIICE tielECESSARY. LA8EL PACKAGE 1307 PR 109 WITH RELOCATION OF HS FOR A0V 03 SIIITCH LOCATI0li 0F HS OPS IIOREllIG -

110A AND 111A SY HED-1181, HS 1108 AIID 1118 T0 IIATCH FCRIAtITTEN 1108 AllD 1118110 LONGER LINE LOCATI0llS IN HED-1181.

UP LOGICALLY OR IN FLON PATH ALSO ltELA8EL TO SHoll F0lt 1101 BIAL OPERATItal. 19I101 GOES TO T0P/80TT(31 0F VCT.

, 1309 PR 79, 110 BISTA8LE ENGitAVIIIG ON TSLS-1 03 REVISEEN6RAVINGTO(SG-X TO ENGINEERING l IS NISLEADING. RATE TRIP NEG , PitESS RATE , P8]

l 81 STABLES AltE ElIGitAVED 'HI Allo (SG-X , L0 PRESS ,

l PItESS' AND Loll PitESS TRIP IS P8]

l ' Loll PR RATE' (A RATE VARIABLE l SETPOINT).THISCONFUSESTHE l TWO TRIPS TO THE OPERATolt.

1310 Pil00LEll itEPORT (PR) 111 IIHR HOT LEG SUCTI(Ni BLOCK 02 SidAP THE LOCATION OF BOTH TO ENGINEERIllG VALVES (Ill80 Alto AllD OUTBOARD THE A & B VALVES

[CINIT]) ARE 110T LOGICALLY [HS-8701A & 8 HS-8782A m m (Il THE IIAIN CONTil0L & 8) F0ft 80TH TRAlltS T0 80ARD. THE OUT80 Alt 0 VALVE IS ItEFLECT ColtRECT Floll PLACED BEFoltE [A80VE) THE SEQUBICETOPTO l

IIN10 Alto VALVE. 80TTOII.

l

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CEOftGIA POWER COf4PANY 177 VOBTLE ELEETRIC EENERATIN PLANT lulAN 961NEDIl10 DISCREPANCY (NED) STATUS REPORT HED NimBER ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUTION STATUS 1311 COWUTER SURVEY NUREG THERE IS NO EAF COWUTER 64 REPLACE THE PRBS PRINTS AFTER FUEL LGAI 0T006.T.3.1.a.(1) PRINTEA IN THE CONTROL ROON WITH AN ERF SYSTBI PilNTER SINCE ALL PElIIS RADIATIGl DATA IS ElPLICATED GI THE ERF CONUTER.

1313 QUESTIONNAIREI HS-901T8, THE RMST SUPPLY TO 02 RELOCATE MAND SNITCH ONE AFTER FUEL '.CA:

0068-02-01 Osti SPRAY PiNF-8 IS GlE SPACE SPACE TO THE RIGHT.

TO THE LEFT CO WARED TO TRAIN A LAYOUT. IRNIN THE Hallo SillTOI ONE SPACE TO THE RIGIT IR11LD liFNOVE THE TRAIN SEPAAATION Allo AAAE THE LAY 0llT lEME CIESISTElIT.

1316 REVIEW 0F CONTROL E0P 19012-1 STEP 10 REQUIRES 03 REVISE THE APPLICAR.E OPS WORKIII6 l REQUIRBENTS BASED CII THE OPERATOR TO PLACE ALL STEPS Ill THE EDPs AllD TASK AllALYSIS PRESSURIZER HEATERS IN THE CORRECT THE SIIRILATOR l PULL TO LOCK .*t)SITIGl. THE DISCREPANCY.

l QIE2 CONTROLS 00 NOT KAVE THE PULL TO LOCK POSITION. THE SIltiLATOR Allo THE E0Ps ARE IN ERNOR.

1320 CONTROL ROON EXPERIDICE POSITION INDICAT!all COLORS ON 01 CHAIIGE LIElli COLORS ON OPS NORKINE CONTROLLERS ARE INCGISISTENT IN VALVE CONTROLLERS SO THAT llAINTAlllll16 A 00181. SillT, THE DOINI RITTON : SIGJT =

GREBI CGIVSTIGl. GREDI AND UP = OPEN:

RED. DELETE INE COLOR 011 IN31 VALVE CONTROLLERS AND TIC P90 CESS CONTaruirm NITH POSITIGI 115. W PNOCESS CGIT110LLERS NITH GIT IND NAINTAlli REl>0P81 REEAROLESS

l CEORGIA POWER COMPANY 178 i

l I

i l

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GEO8tGI A pot #ER COMPANY 179 Cullum. upon etsim utvits CATEGORY 4A JUSTIFICAT! W REPORT HED ORIGill DESCRIPTlWI PROPOSED RESOLUTIGl 4A JUSTIFICATION

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1001 1982 PRELIMINARY THE TOP RON OF NETERS ON THE NO ACTION. N0 PR00LBIS NOTED DISPLAY HEIGHT:

CR0R(NED101&105) IIAlli CONTROL BOARD & QHVC ARE IN SINULATOR. THE CONTROL RO0li INDICATORS LOCATB

& AS11 T00 HIGH. A80VE THE 74 INCH GUIDELIllE (Il PANELS IpfVCANDQNC800NOTREQlIRE PRECISE ORFREQUSTUSEDURINGROUTINEPLANT EVOLUTIG:3. IN ADDIT! W , DIFFICULTIES NERE NOT ENCOWTERED BURING THE SP VALIDATION EXEllCISES CGWICTED W THE VEGP SIWLATOR. THIS NAS THOUG(T TO E A PROEBt R1R1116 THE 1982 SURVEY WE TO PARALLAX ERNORS IN THE lETER READINGS. THE STYLE OF IETERS CURRBITLY llISTALLED NOVE THE POINTER IN THE SAIE PLANE AS THE SCALE, NOT ABOVE IT, 30 PARALLAX ERNORS 00 NOT OCCUR.

1992 AS-8 80TTGI RON OF SWITCHES AND NO ACTI0ll. 110 PROGLBI NOTED CONTROL Allo DISPLAY HEIGIT:

1982 PRELIMINARY METERS ON THE QEA8, QPCP, AND IN SIhULATOR. THE CONTROL 800N CONTROLS AND CRDR HED 102, 106 QHVCAREBELONTHENINIIRNI IllOICATORS LOCATED BELOW THE 34 INOi HEle(T SUGGESTED Ill THE ElIDELINE ON PANELS I)(VC, QPCP AS EUIDELINES. QEA800NOTREQUIREFRElplalTOR PRECISE USE DURING NRITIllE PLANT EVOLUTIGIS. IN A00 life DIFFICULTIES lERE NOT DICOWTEIEB OURING M EDP

VALIGATIGl EXENCISES CGIWCTED W TIE VEGP SIIRILATOR.

l CONTROL GROUP!IIG:

l 1005 1982 PRELIMINARY THE CCN PUNP SWITCHES ON PAllEL NO ACTION. TRAIN GROUPIllG CRDR(NED205) 1A1ARELA8ELED:PUNPS:[1,3,5)TAKESPRECEDalCEOVERIIUNBLR SAFEGUARDS COIF 0llEllTS THAT ARE GERIPED

[2,4,6]& TRAIN:[A,A,A) SEQUDICE. OPERATI0li IS BY BY PONER SUPPLY llAKE TIE J08 0F

[8,8,8] TRAIN GROUPilIG. COIFGIST VERIFICATIGl AS IlEQUIREB BY THE BEMOICY OPERATING PWCEDUES ERE EFFICIEllT AND ACCURATE. THIS ALSO IIF110VES DIE CUE FOR TIE RESPGISE TO DIESEL GBIERATOR FAILURE AS IllOICATED BY THE LOSS OF GlE TRAIN.

1986 1982 PRELIlllllARY THE IISCW PUIF SWITCHES ARE 110 ACTI0ll. TRAIN GROUPIIIG SEE HED 8 1985 CRDR(HED207) LABELED, LEFT TO RIGIT: PUIF TAKES PRECEDOICE OVER NUMBER

[1,3,5,7][2,4,6,8]& TRAlli SEQUENCE. OPERATI0li IS BY

[A,A,A,8] [B,8,8,A] TRAIN GROUP.

CEORGIA POWER COMPANY 180 CGITROL ROOR DESIM REVIEN CATEGORY 4A JUSTIFICATION REPORT HED ORIGIN DESCRIPTION PROPOSED RESOLUTION 4AJUSilFICATION

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1888 1982 PRELIllINARY THE IISCW VALVE SWITCHES FOR 110 ACTION. TRAIll GROUPill6 SEE HEDS 1005 CRDR(NED209) THE CONTAlifENT COOLER VALVES TAKES PRECEDENCE Ill OPERATION.

ARE LA8ELED: [1 & 2 T M A)

[5 & 6 TM A)

[3 & 4 TIII 8]

(T & 8 T M 8].

1821 1982 PRELININARY S0llE SYNCHR0llIZIll6 SWITCHES NO ACTION, SWITCHES HAVE LEFT THE OPERATION OF THIS SIIITCH IS NOT CRDR(HED239) NERE TO BE ARRANGED SO THAT & RIGHT 'ON' POSITIONS AS EXPECTED UNDER STRESSFUL CGIDITIWS, THEY TUM 'Oll' WITH A COUNTER IllCONIII6 OR RUNNile6 PONER letERE OPERATOR CTIONS IRIST BE CLOCMISE IlOVEIENT. SOURCE, RESPECTIVELY. BREAKER C01 SLITTED T0 IENORY. IN AUIDST ALL ALIGNENT DICTATES teIICH WILL CONDITIWS THE OPERATIGl 0F THIS BE SELECTED. THIS IS IISiERENT SMITQI WILL BE OPERATED IAIDER THE IN THE SWITQtIII6 DESIW.110 C(NTROLS OF PLAllT Pwmf't,181EE ACTICW NECESSARY. Sill?QI POSITION WILL OE STATED IN TE APPJCAILE STEP.

182T 1982 PRELINIllARY THE PRESSURIZER LEVELS ARE 110 ACTICII, CHAlelEL DESIWATION THE l13All NUIERALS NILL HELP THE CRDR(NED24T) ARitAll6ED AS FOLL0llS: PRZR AIDS Ill LOCATIll6 81STA8LES FOR OPERATOR IDENTIFY A PARTICULAR LEVEL II, I, III TRIPPIll6 8AD CHAltlELS. SEE HED lilSTRINENTATION QiAISEL DURIIIS 1094.1101BIALLY 110T LOOKED AT SURVEILLAllCE TESTIl16 OR IIAINTBIAllCE.

l 8Y lilDICATOR QiAlelEL. SEE HED THIS IIAY HELP PREVBIT OPERATOR EREIRS 1992. IllVOLVll16 THE INIONG TRAIN.

l 1828 1982 PRELIMINARY THERE IS 110 PROVISI0ll FOR 100 ACTION. IIAINTAIN VERTICAL THE ItEACTOR C00LAllT TElrERATURE CRDR(NED249) LOOP-TO-LOOP C01FARIS0NS OF LOOP ARRAll6 BENT C011VEllTICII. RECORDER WILL PROVIDE THE NECESSARY THE REACTOR C00LAllT LOOP CGFARISIM ON THE C(IITROL 80AN, TBFERATURE. Ill ADl'ITION, THE PROTEUS AND THE ERF COIFUTERS PROVIDE NINIC STYLE PRESBITATI(M 0F REACTOR C00LAllT SYSTBE LOOP PARAIETERS.

1829 1982 PRELININARY THE FL0li INDICAT0ltS FOR THE 110 ACT!0ll. CURRENT ARRAll60ENT REACTOR C00LAllT PJNP SEAL CRDR(NED250) REACTOR COOLANT PUlr SEALS ARE PLACES INDICATI0ll MITH SEAL lilSTIMEllTATIGI IS CUltitBITLY LOCATED NOT Ill CLOSE PR0XINITY TO THE FLOW CollT110LS AllD ALAmtS. ON THE CVCS PoltTI0ll 0F THE CONTROL PUN #S. BOARD, THIS LOCATION IS BETTER SUITED FOR OPERATOR CONTROL THAN A LOCATIE IEAlt TNE REACT 0lt C00LAIIT PINFS. ALL OPERATOR ACTIGl WITH REGARD TO PINF SEAL FLGIS OCQlRS FRWI THE CVCS SECTI(E OF THE CGITIOL PANEL.

_ ._ , _ . _ _ _ _ _ _ . _ _ _ ~_._ _ _ _ _ _ _ . _ _ __ . _ . . _ _ _ _ _ . _ _ . _

CEORGIA POWER COMPAfiY 181 usinut muun utsim inivits CATEGORY 4A JUSTIFICATION REPORT HG ORIGIN DESCRIPTION PROPOSED RESOLUTIS 4AJUSTIFICATION

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1830 1982 PRELIMINARY THE REACTOR C00LAlli LOOP NO ACTION. 80TH READA8LE, THE PHYSICAL APPEARMCE OF TE CROR(NED251) TEMPERATURE RECORDERS 433A, SAME SCALE. INSTRUNENTATION DOES NOT DISTMcT FRW 4338 A110 413A, 4138 SERVE THE THE RECORDERS ABILITY TO TRANSFER SAIE FUNCTION 011 O!FFERST INFORETION TO THE OPERATOR, LOOPS, BUT THEY ARE DIFFERENT PROVIDIll6 THE SCALES, ENGINE SING TYPES OF INSTRINENTS, AND ARE UNITS Allo RANGES ARE THE SAIE.

IN DIFFERENT LOCATIONS.

1932 1982 PRELIMINARY THE GSERATOR SYNCHROSCOPE ON NO ACTION. METERS USED mRE SEE HED8 1001 CRDR(NED256) PAllEL 182 IS A80VE THE OFTS ARE LONER.

GUIDEllllE HElelT.

1933 1982 PRELIMIllARY THE 3YNCH CHECK SYPASS SWITCH NO ACTION, SWITCH IN PARALLEL SWITQi POSITION IN THIS CASE, ODES NOT CRDR(HED257) NAY BE LEFT IN A PARALLEL POSITION HAS 110 IMPACT ON VIOLATE HUMN FACTORS STANMANS. TIE POSITION. EQUIPMENTOPERATION,50 REQUIRED POSITION IS All ASINISTRATIVE RELIAllCE ON ADMINISTRATIVE FUNCTION THAT DOES NOT IW ACT THE RITUM TO NORNAL POSIT 10ll IS OPERATORS WORK LOAD OR EFFECT PLANT thFFICIENT. OPERATI0ll.

1035 1982 PRELIMINARY THE COLOR CODING SYSTEM IS NOT NO ACTION, THE EXISTING TRAIN THE COLOR CODING USED IN THE CGITEL CR0R(NED259) CONSISTDT ACROSS ALL THE CODE ETCHES THE ELECTRICAL ROOM IS PRillARILY USED AS RI STATI M BOARDS.FOREXAWLE,QNCBIS TRAIN COLOR CODES. THIS CUES All0 NOT FOR THE IDENTIFICATIE OF COLOR C00E0 BY SYSTER, BUT THE DISTINCTION IFROVES TRAIN PLANT SYSTENS. TRAIN SEPARATIE IS OF DIESEL GENERATORS ON THE QEA8 SEPARATION IN DIESEL THE UTNOST IWORTAllCE GI THE i ARE COLOR C00E0 8Y TRAIN. OPERATION. N0 ACTIN RESilRED. ELECTRICAL DISTRIRITION PAELS.

l l 1837 1982 PRELIMINARY TS-411E, OT DELTA-T SET POINT NO ACTION. 6ROUPED WITH OTHER THE NIS AND PROTECTION Qi4NEL CROR(NED262) SELECTOR IS NOT Ill CLOSE SELECTORS AND IS IN EASY VIEN SELECTOR SWITCHES ARE LOCATB W TNE PROXIMITY TO ITS DISPLAY. OF RECORDER. 801CH80ARD PORTI0ll 0F THE CETROL BOARD, GROUPED TOGETHER IN CLOSE PROKINITY TO THE REACTOR CSTEDLS AND THE APPLICAKE RECORDERS. RELOCATIE OF THE OVERPONER ANO DELTA T SELECTOR SWITQlES NEXT TO THE senaarm igu8 NAXE OPERATION THE CGITBOLS LESS CGIVSIST.

I 1838 1982 PRELIMINARY THE LEFT Hall 0 COMER OF PAllEL A00 VALVE POSITION TO LIGHT THE BLON00101 ISOLATION VRVES AE NOT CROR(NED263) 181 IS T00 CRONDED, AND THERE 80X ON 181. FREQUSTLY OPERATED, RIT TIE VEVE IS NO DIRECT Ill0ICATION FOR POSITI0ll IS REQUIRED TO E VERIFIS IN THE SG 8LON00101 VALVES THE E0P'S. THE VRVE POSITIE STATUS (HS-7683A,8,C,0)THIS LIGHTS ON THE MAIN CGITROL 2451A1

[ IN0!CATORISONTHEQPCP. PROVIDES THIS IN0! CATION. IN ADDITIW ,

PRO 8LBIS llERE NOT OBSERVED ElRING THE E0P VEIDATION EXERCISE.

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CEORGIA POWER COMPANY 182 cuuluut muun utm e evits CATEGORY 4A JUSTIFICATIO11 REPORT HED ORIGIN DESCRIPTION PROPOSED RESOLUTION 4AJUSTIFICATION

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1840 1982 PRELIMIIIARY HS-5208, HS-5209 & FIC/FI-4499 NO ACTION - NO PRACTICAL NOVE THE VALVES TMT REC 21VE A FEEONATER CRDR(NED266) ARE NOT IN CLOSE PROXINITY TO FOR FIC SIllCE IT IS NOT ISOLATION SIMAL ARE GROUPED TOGETHER THE IIAlli FEED PUlFS. ASSOCIATED WITH FEED PUIF. ON SECTION 181 0F THE IIAIN CONTROL BOARD, THIS GROUPIll6 FACILITATES FEEDNATER ISOLATION VERIFICATIGI 00 RING PLAllT UPSETS. THIS GROUPING 00ES NOT INTERFERE NITH ROUTIIIE SYSTEN OPERATIONS.

1841 1982 PRELIMINARY THE ATSI CRT IS TOO HIGH. NO ACTION. NO PR08 LENS NOTED THE ADVANCED TURBINE SUPERVISORY CROR(NED268) IN S!!RJLATOR. INSTRUNENTATION SYSTEN IS AN IIIFOINIATION DISPLAY TE1IIINAL ONLY, NOT UTILIZED FOR DIRECT TURBINE CONT EL.

1842 1982 PRELIMINARY THE AREA A80VE THE TUR8INE NO ACTION, RETAlli CURRENT THE 181 PANEL LOCATION IS CRDR(NED269) PANEL ON 182 IS NOT ARRAN6ED LOCATION. CURRENT LOCATION IS APPROXIllATELY EQUAL DISTAlli (6 FT)

IN A FUNCTIONAL llAINIER, AllD A 6000 C01FRONISE BETWEEN R.0. FRON BOTH REACTOR AND TUR81NE CGITROL DOES Il0T IllCLUDE THE TUR8IllE AND T.0 STATIONS. STATIONS, ALLONING BOTH OPERATORS TO IIFULSE PRESSURE INDICATORS VIEN IT AllD C0 ORDINATE THEIR CGITMLS.

PI-505 AllD PI-506.

1044 1982 PRELIMINARY THE RIVER NATER FLON RECORDER NO ACTION THE CURREllT LOCATION IS ONLY 12 IMOIES CROR(NED2T3) IFR-T252 011 THEQPCPISIlOT OFFSET FROM THE SWITCHES. THE LA8ELS LOCATED DIRECTLY OVER THE ARE CLEAR AS TO FUllCTION AND THERE IS RIVER IIATER VALVES. NOCLOSECOUPLEDOPERATIONREQUIRING USE OF THE HAND SNITCHES 10lILE REFERRIll6 TO THE RECORDERS.

1046 1982 PRELIMINARY CONTROL SWITCH INDICATOR NO ACTION. MINOR CONCERN, THE DESIGN OF THE SWITCH CONTROL CRDR(NED404) LIGHTS HAVE NO ' PUSH TO TEST

• BASIC DESI611 ISSUE. CIRCUITS IS THAT AT LEAST OllE LIGHT CAPACITY. SHOULD BE ON AT ALL TILES, telEN CGITHOL PONER IS APPLIED. CONTROL i

SilITCHES FOR CGNGIElli CIRCUIT NEAKEllS WILL ALilAYS INDICATE EITIER OPElf (GREEN) OR CLOSED (RED) WITNGJT All INTEINEDIATE POSITIO11. THE DESIS OF THE VALVE CGITROL SillTCHES IS TilAT AT LEAST ONE LIGIT SHOULD E 011191 Ell THEVALVEISEI1HEROPEN(RED)OR CLOSED (GREEll) Allo BOTH LIGITS GI I8IEN THE VALVE IS IN THE INTERNEDIATE POSITION. THEREFORE AN Il10PERA8LE LIGIT OR poler SUPPLY IS EVIDeli BY BOTH POSITION Il10!CATORS BEING 0FF.

BACIUP VALVE POSITIGl IllDICATIGl IS PROVIDED FOR flAllY VALVES GI THE ININITOR LIGIT 80XES [ZL8 / IL8] AND THE ERF & PROTEOUS COMPUTERS.

CEORGIA pot (ER COMPANY 183 C NTROL R0 W DESi m REVIEN CATE90RY 4A JUSTIFICATION REPORT HED ORI61is DESCRIPTION PROPOSED RESOLUT!0ll 4A JUSTIFICATION

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1847 1982 PRELIMIAARY THE SET-POINT MOS FOR THE NO ACTION. FOLLONS THE F0PULATIONAL STERE 0 TYPE FOR CRDR(NED405) CONTROLLERS DO NOT HAVE POPULATIONAL STERE 0 TYPE CLOC MISE = INCREASE, RElllFORCS DI'ECTI3AL llARKilI6S. (CLOC10llSE IKREASE) MD HAS NITH IEREASIII6 NUISERED POSITIWS NUN 8ERED SETTill65. 08VIATES ANY NEED FOR A DIRECTI WAL ARR0N.

1953 1982 PRELIMINARY THERE IS NO IIETH00 0F 110 ACTION. KEEP AS IS TO ThE MAIN CONTROL BOARD'S LACK OF A CRDR(NED413) SILEEING M ALARN ON A BACK IMPROVE RELIABILITY OF ALARN SILEllCE PUSH 8UTTON FOR THE 8 ACE (WRE6 0T00 PMEL FRON Ally POSITION ON THE RELOGNITION & RESPONSE. PANELS IS A DESIRED GEORBIA poler 6.3.4.1.) MIN CollTROL BOARD. OPERATill6 PHILOSOPHY, IT NILL ACT AS A FONCING RBICTION TO REQUIRE OPERATR ATTSTION TO THE STATUS OF THE NACI PAllELS.

l 1960 1982 PREllll! NARY THE AUXILIARY FEEDWATER 310 ACTION. CONTROLS EASILY THIS hED IIAS 6 BERATED FRON A CETEDL CRDR(NED507) INDICATORS ARE LOCATED TOO FAR READ FROM CONTROL STATION. PANEL NOCEUP NITNOUT ACTUAL allay FROM THE CONTROLS TO BE IllSTRUIENTATIOW. DIFFICULTIES MVE NOT READ ACCURATELY FROM THERE. 8EEN IDENTIFIED ON THE ACTUAL CGIm0L PAllEL OR THE SIIRILATOR. THE VIBilE i DISTANCE IS APPROXIETELY 36 INDE5.

l 1965 AllTHROPONETRIC BDICH80ARD, NITH RAIL 110 ACTION. RAll NAS ADDED TO THE CHANGE IN THE CONTROL PANEL DEFTil SURVEY (AS-1) lilSTALLED, EXCEEDS THE CORRECT HED ON IllADVERTENT AS A RESULT OF THE RAIL IllSTALLATIE REC 0lOEN0ED DEPTH OF 28111CHES. ACTUAT!011. IS A NINOR DEVIATION FN0li THE (ACTUAL IEASURDENT 30 5/8*). REcolelEllDED alIDELINE. THE TRADE WF IS POSITIVE IN LIGHT OF THE amsa POSSIBILITY OF IllADVERTEllT CMTELS ACTIVATION.

1066 AllTHROPONETRIC DISPLAYS ON THE Q11C8 110 ACTI0ll. DISPLAYS ARE PART THE NUTAC SURVEY IllSTRillENT 18AS IN SURVEY (AS-6) BENCHBOARD ARE BELON THE OF VENDOR PAllEL, USED IN ERROR, THE LONER LillIT IS FOR VERTICAL RECGNENDED HEIGHT. (TUR811tE C011JullCTI0ll WITH TH0:;E CONTROL PAllELS 110T DISPLAYS IRRITEB ON SUPERVISORYDISPLAYSONLY). CONTROLS.110 Fil00LDIS 110TED IN BDICH 80ARD STYLE CONTROL PANELS.

SIIRILATOR. IlURE6 0700 DOES NOT ADORESS TH15 ISSUE.

1067 ANTHROPONETRIC THE AINiullCIATORS ON THE QNC8 110 ACTION. NITHIN LIMITS FOR THE AINMICIATORS ARE 110UNTED S0 TilAT SURVEY (AS-7) ARE A80VE THE REC 0lW1 ENDED TILTED SECTION 011 VERTICAL THEY ARE NITHIll THE UPPER LIllli 0F THE HEINTOF80 INCHES (94*TO PAllELS. NO PR08LDIS Il0TED IN VISUAL FIELD (70 DEG. AIOVE THE THETOP). U WLATOR. HORIZONTAL LINE OF SIGHT) 0F THE Sch PERCENTILE FBIALE (REF. NURE6 8794 S.1.2.2). THE WTAC allDELINE APPEARS TO HAVE ASSINED A VERTICAL PAllEL.

o

CEORGI A POWER C004PANY 184 CONTROL 200N DESIR REVIEN CATEGORY 4A JUSTIFICATION REPORT HED ORIGIN DESCR!Ill(31 PROPOSED RESOLUTION 4A JUSTIFICAT Mh 1968 AllTHROPONETRIC C0llTROLS ARE A80VE THE NO ACTION. CONTROLS SELDON THE CONTROLS ASSOCIATED WITH THE NIS SURVEY (AS-9) REC 0lelENDED HEIGHT OF 70* OPERATED. STOOL AVAILA8LE. AND INCORE DETECTOR PANELS ARE INFREQUEllTLY USED. THEY ARE Lill!TED TO CHAlelEL TEST CIRCUITS AllD INCORE DETECTOR OPERATIGl. THESE CGITROLS ARE NOT UTILIZED FOR ENERGEllCY PLAllT OPERATIGIS.

1969 AllTHROPONETRIC DISPLAYS ARE 8ELOW THE NO ACTION. SELDON USED SEE HED 8 1848 SURVEY (AS-10) REC 0lelENDED HEIGHT OF 41' DISPLAG. Call 8E READ (ACTUALHEIGIT13') ACCURATELY IF NEEDED.

1971 AllTHROPONETRIC SPDS CollSOLE DOES NOT HAVE THE NO ACTION. USED FOR ONE BUTT 0ll THE SPDS OPERATOR CollSOLE WILL NOT E SURVEY (AS-13) REcolelENDED 18 IllCHES OF MEE C01slAllDS NOSTLY. NO OPERATOR UTILilED AS A WORK STATI(Il letERE THE 200N (ACTUAL NEASUROBli 15 SITS AT IT ROUTIllELY. OPERATOR WOULD BE EXPECTED TO E 1/2 IllCHES). SEATED FOR LONG PERICOS OF TillE.

THEREFORE, FATI WE WOULD IIOT BE A FACTOR IN OPERATOR PERF0lplAllCE WRING l STRESSFUL CGIO!!!GIS.

t I

1972 AllTHil0PollETRIC SPDS C0llSOLE DOES Il0T HAVE THE NO ACTION. filNOR DEVIATI0ll SEE HED 8 1071 SURVEY (AS-14) REcolelEllCED 25 IIICHES UNDER 1/4'. FOOT REST A00ED FOR SURFACE HEIGIT WITH FOOT REST OPERATOR COIFORT.

IllSTALLED (ACTUAL NEISIT 24 3/4'WITH3' FOOTREST).

1873 AllTHROP0llETRIC CONTROLS ARE NOT SEFARA'E9 8Y NO ACTION. CONTROLS SMALLER THE NUTAC SURVEY INSTRUNENT DOES NOT

?)RVEY(AS-17) THE REC 3DENDED 4' FOR 'J' thall COINION USAGE. ALL0llS ADOKESS THE SIIALLER SIZE 'J' HAllDLE HANDLf3 iJo 2' FOR OTHER CLOSER SPACIIIG. USED Ill THE VEGP CL% TROL 110 011, SEE HED CONTROLS. (IIOST J HAllDLES ARE 81275 FOR Pil0lN. DIS WITH THE SMALLER 3*A110RCIAffARE11/2'). CollTil0L SillTCH.

1081 Lie 5 DiECKLIST SOIE LA8ELS ARE NOT WITHIN THE 110 ACT!0ll 011 IIC8, HVAC, PCP REPLACBEllT LABELS ARE BEllIG ORDEED LIE-1 LIlllTS FOR STROKE WIDTH / CHAR. SINCE PAllEL LA8ELS ARE NOT WITH THE LETTER SIZES THAT CC1F05 TO HEIGHT RATIO & CHAR. USED BY OPERATORS THE APPLICABLE GUIDELINES.

WIDTH / CHAR HEI9fT RATIO. PANEL I.D. IS PICXED UP IN TRAIN!I16.110 ACTICII GI SitJTD0101 PANELS TO SilFLY IIICREASE LTR SIZE, BUT NEN ElIGRAVIIIGS WILL LEET l EllDELINES l

CEORGIA POWER COMPANY 185 CONTROL ROGI DESim REVIEW CATEGORY 4A JUSTIFICATIGI REPORT PED ORIGIN DESCRIPTION PROPOSED RESOLUTION 4A JUSTIFICATION 1082 LIC CHECKLIST LND-2 IN SOIE CASES THE HEIENT OF NO ACTION CORPONENT LA8EL LETTER SIZE IS LARIE THE CHARACTERS ARE NOT WITHIN EN00 m FOR ACTUAL VIENING DISTANCE.

THE NINIIIst HEJ E T. TH00Gi ZL8 LEGENDS ARE BELON GUIDELINES SIZES, THEY ARE THE CGEOlENT DESIR.

1985 LNO CHECKLIST LND-14 THE FOLLONING DISPLAYS ARE NOT NO ACTION THIS IS GENERAL CONVENTION FOR TIESE A80VE OR TO LEFT OF THEIR CONTROL AND INDICATOR NODULES. SIE CONTROLS: S.6. RECORDERS S.I. 8Y SIDE, N00ULAR CONSTWCTION arimrn ACCLII. PRESSURE, PRESSURIZER PR08ABILI!Y 0F ERROR. S.G. LEVEL PRESSURE, NAlli F.W. PL5F O!L RECORDERS, FEED CONTROLLERS WILL E PRESSURE, AUX. STEAll TO 5A & TIED TOGETHER 8Y HIERARCHICAL LAELS 58 F.W. HEATERS (NED-1004) 1890 OC-22 LA8ELS ARE WITE ON DARK NO ACTION. WITE ON DARK A STUDY NAS CONOUCTED THAT COIFAEB 8ACFSROUND IN MANY CASES, NOT OFFERS ADEQUATE CONTRAST AllD THE LEGI8ILITY OF lellTE CHARACTERS GI DARK ON ISIITE AS REC 0 MENDED. LESS POTENTIAL FOR DISTRACTION A DARK neucan an ANO OLEX CHARACTERS ISIICH A PATCH OF lellTE, ON A 10 LITE arumanen 80TH HAVING THE CATCHIll6 THE EYE, COULD CAUSE. OPTIIRBI STROKE NIDTH T0 HEIENT RATIO.

THE STUOY DETEINIINED THAT 10 LITE CHARACTERS WI A DARK 8ACK6AOLA10 CAI OE SEEN FROM A GREATER DISTANCE THAN 1801 BLACK OIARACTERS NERE USED. THE CMSE 114Y E DUE TO THE IRRADIATING EFFICT OF THE letITE arunamen 'spgEADIE OUT' IllTO THE OLACK AREAS NT 110T TIE CGIVERSE. (REF. FacnunmICS AT NOK -

MVID J. OS80ME - PAGE 95) 1992 681ERAL PMEL LEVEL & PRESSURE INDICATORS S/2 LEVELS & PRESSURE THE IbDICATORS ARE LOGICALLY ARRANEED CHECKLIST (6-2) ARE Il0T Ill 8 ORDER LOOP 1 INDICATORS ARE Il0RNALLY LOOKED ON THE CONTil0L 80ARD ACCORDil16 TO THE

[LI-518,519,Sli,551] ATSYLOOP(S/61,2,3,0R4) REACTOR C00LAllT LOOP IRNERS IlOT THE

[PI-514A,516A,515A] LOOP 2 AllD 110T SY INDICATOR NUM8ER INSTRullENT TAS NUIIBERS. THE OPERATOR

[LI-528,529,52T,552] LOCATES T'iE IllDICATOR All0 THE

[PI-524A,526A,525A] LOOP 3 ASSOCIATED CONTROLS ON THE CONTil0L

[LI-53s,539,53T,553] PANEL, SY HON THEY RELATE TO THE

[PI-534A,536A,535A] LOOP 4 APPROPRIATE STEAll GENERATOR, (110S LOOP

[LI-548,549,54T,554] NUMBER AND STEAN GENERATOR 18518ER

[PI-544, 546, 545 AGREE) 1107 THE IllSilRNElli TAG IRNER.

CEORGIA POWER COf8PANY 186 CONTROL RO M K SIM REVIEN CATEGORY 4A JUSTIFICATIGI REPORT HED ORIGIN DESCplPTION PROPOSED RESOLUTIGI 4A JUSTIFICATION

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1093 GEllERAL PMEL CONTAINNENT PRESSURE NO ACTION - ORDER NOT THE ORDER OF THE CONTAll0ENT Pm!w CHECKLIST (6-2) INCICATORS ARE NOT Ill IllPORTMT Ill0!CATORS ARE IRRELEVAllT BECAUSE

! NUIERICAL ORDER PI-935 PI-93T THERE ARE NO OPERATOR CONTROLS THAT PI-934 PI-936 ARE FialCTICIIALLY RELATED. THESE ARE

RERAIDANT QIAlelELS GROUPED TOGETHER FOR SIICE C01FARISON.

l l 1994 GENERAL PMEL THE FOLLONIll6 IllDICATORS USE 100 ACTION, QWelEL DESIGNATION SEE HED 81927 OlECKLIST(6-3) RONAN IIUllERALS Ill LA8EL AIDS Ill LOCATIII6 BISTAKES FOR DESCRIPTIGl 0F lETER: (4)PRZR TRIPPIll6 8AD CMelELS PRESSURE (12)RCPFLON (16)S/G LEVEL (12)S/6 PRESSURE (4)CGITAlBENT PRESSURE 1096 GENERAL PANEL NOST IIETERS HAVE VERTICAL 110 ACTHNi ONLY PRACTICAL MY THE IRITAC SURVEY INSTRNENT MY HAVE CHECKLIST ORIENTATION FOR UNITS 011 VERiitAL IETERS BES IN ERROR, IIUREE 0708 SECTIS

6.S.2.4 ADDRESSES Ilu1ERAL ORISTATIGl l NOT THE ElI61NEERING IRIITS.

i 1999 6BERAL PAllEL WO LEGENn FY.!ST FOR IIEMlll6 0F 100 ACTION AllBER TRIP LIGHT IS A CONVENTION AND OIECKLIST AllBER TRIF 'lciT3 110 LE6810 IS REQUIRED. ADEQUATELY COVERED IN TRAINIII6.

1103 GENERAL PAllEL BLUE LIGHT ON RCP LIFT OIL 110 ACTION LIENT IS A START PEittISSIVE FOR EP OIECKLIST(6-12) PUlF DOES IIOT HAVE A LE6 B D (OILPRESSURESUFFICIENT)THISIS DESCRIBill6 BLUE LIGHT FUNCTI0li TAUINT Ill TRAINIII6 A110110 LE6810 REQUIRED 1106 GENERAL PANEL TOGGLE & Il0CKER SillTCHES ARE DIRECil0MS LA8ELED AllD LIMITED THE IRITAC SURVEY INSTRNENT MY HAVE DIECKLIST(6-14) Il0T CONSIST S TLY VERTICAL OR CHOICE OF DIRECTI0ll NAKE3 8ES Ill ERROR, IRJRES 0700 SECTIGI HORIZO11TALVERTICAL-AC/DC ERRORS UllLIKELY 110 ACTION E.4.S DOES NOT A00RESS CGISISTEllCY REGULATION MIN 8ASE, QEA8 BETNES SYSTEllS.

SYllC OIECK BYPASS, QEA8 'R' SWITQlES HORIZO11TAL -

RAISE /L0lER CII GEN. PAllEL, S/6 LEVEL STEAll & FEED FLOli SELECTORS 1108 GDIERAL PAllEL INDICATORS USilI6 Sill 6LE 110 ACTION, THE OPERATOR CAN THE IIETER ENGINEERING Ull!TS ARE OlECKLIST CHARACTERS FOR PROCESS UllITS LOOK AROUND POINTER, POINTER 08V10US FROM THE LA8EL A110 THE CONTROL (0F, %, ETC) Call OE 08SCURED SELDON AT THAT POSITICII, LA8EL CIRCUlf APPLICATI0ll.

SY POINTER llFLIES UlllTS. (110 ACTION)

CEORGIA POWER COMPANY 187 4

CONTROL RO M DESI M REVIEN CATEGORY 4A JUSTIFICATIM REPORT HED ORIGill DESCRIPTION PROPOSED RESOLUTION 4A JUSTIFICATION

== -

1109 GG ERAL PANEL ELECTRICAL IIETERS HAVE M 1/8' NO ACTION, THESE NETERS ARE THIS REQUIRBENT IS BASED 5 THE CHECKLIST (G-26) BETWEEN POINTER TIP MD VERY C0 ARSE SCALES SO THE 1/8' REDUCTION OF POTSTIAL PAnanar PROCESS UNITS. (ROUND TYPE GAP POSES N0 PR08LEN. 110T P908 LENS MS OPERATOR ADJUST 1ENTS ARE NETERS). USED FOR PRECISE READIllGS. MADE TO CONTROL CIRCUITS leiERE PRECISItal IS A NECESSITY. THE lETERS IN QUESTI M ARE NOT REQUIRED FOR PRECISE OPERATOR CONTROL.

1110 GENERAL PMEL IV 48 INDICATORS HAVE NO ACTION, THE IllDICATORS ARE MANY OF THE INDICATORS THAT 00 NOT CHECKLIST (G-28) GkEATER thall 9 GRADUATIONS ADEQUATELY GRADUATED FOR THE SATISFY THIS GUIDELINE IN THAT THE SETWEEN NUINIERED MARKINGS. ACCURACY OF READIllG REQUIRED, NUN 8ER OF GRADUATIONS IETIES IRNERALS A110 IIAJOR AllD lill10R EXCEED llINE GRADUATIONS, DO HAVE NINE GRADUATI0llsAREADEQUATE.NO OR FENER GRADUAT131S BETIES IIAJOR ACTI(II. DIVISIONS. OTHER INDICATORS IN DICESS OF llINE 6RADUATI(It3 BETWEB IIAJ02 DIVISIONS DID HOT PRESBIT OPERATGA PROILBIS OURIl1G TMI E0P VALETIQI EX81CISE.

l 1113 GBIERAL PANEL DISPLAY (COUNTER) IS RECESSED NO ACT10ll, SLACK NITH leilTE SEE HED 3 1090 CHECKLIST (G-48) BELON PAllEL ELEVATION LETTERS PROVIDE READA81LITY EVBI RECESSED (110 ACTI(II).

1114 TA E-0 STEP 9 & 10 ONE CCN & ilSCW PUlF LIGHT IS 100 ACTION, THE AS IS THE FACT THAT THESE LIGHTS ARE DARK 110lIIALLY OFF (IE.8) IN A 8 LOCK CONFIGURATI0ll PROVIDES IIORE PROVIDES 110 MAL SYSTBI ARRANGBENT OF 'ON* LIETS FOR SI. RO'S IllFORNATIO11 TO THE OPERATOR INFORMATI0ll TO THE OPERATORS.

PREFER THIS AS IT THE GIVES STATUS OF ESF ALL PUIFS (Il ILS. THE ALTEMATIVE IS TO DELETE THE 3RD PUIF LINT (2 ,

110MALLY START).

Illi TA 100 STATUS OF CIA SIGilAL. NEED NO ACTION TnE STATUS OF THE CIA & CVI SIM ALS TO SEE CHAllGE ON RESET. ADO ARE PROVIDED 011 THE ERF ColpVTER. THE CIA AINIUNCIATOR OR IILS OR ERF COIFUTER IS IIAIN1ED BY THE SHIFT j LIllHTS 011 SWITCHES. TEQellCAL ADVISER DURIl1G All0 AFTER A SAFETY INJECTION,1910 NOULD NDTIFY THE OPERATORS OF SUCH PLAllT C(IIDITIES.

l l

l l

l l

CEORGIA POWER COMPANY 1CS CGITROL ROGI DESIM REVIEN CATEGORY 4A JUSTIFICATION REPORT IED ORIGIN DESCRIPTION PROPOSED RESOLUTION 4A JUSTIFICATION

= ___

1132 TA 18A E0 STEP 2 A ZL8 LIGHTS ARE HORIZONTAL NO ACTION, N!l10R DEVIATION THE CURRENT CONFilRIRATION ALLONS FOR FOR 3 ONLY, VERTICAL FOR ALL FROM CONYSTION AllD CURRST RAPID OPERATOR RECOGNITION OF THE I

OTHERS ON THAT 80X. REARRAll6E, CONFIGURATION USED IN TRAINING TUR81NE STATUS. THE OTHER VERTICE IIAY BE NEGATIVE TRAlllll16 AS QUICK CHECK ON T.T. *g 680UPIll6S IIATCH THE VERT ICAL 1 TIEl 4 EFFECT. SHAPE. STEAll GSERATOR INSTRUIENTATI(NI LAYOUT. THESE 3 AUTOSTOP OIL LON PRESSURE LIGHTS ARE NOT LOOP RELATED.

IT liAS THE MKRMIM OF THE CRDR TEAll NOT TO ALTER THIS NONITOR 80X.

1139 TA 8A IIAIN STEAll VALVES FOR TUR8INE 110 ACTION, SINCE 110 CONFUSION IT NAS THE CONSalSUS OF THE CRDR TEAll DItIVEN AFW Pir C ARE ON IIL8 Il0TED AllD THESE ARE TRAIN A & THAT A P908LEll DOES Il0T EXIST AND TRAIN A & 8, IE.81, 2 POSSIBLE 8 POWERED VALVES. POSITION AllD CONFUSION NAS 110T 110TED DURIl16 THE E0P CONRISION, NOT IIOTED IN E0P TRAIN INF0lulATI0li IS AVAILA8LE VALIDATION EXERCISE.

VALIDATI0li 011 THE HAllDSillTCH AT THE AFW STATI0ll.

1146 TA E0 STFP 19 REQUIRES 110 ACTION ADEQUATELY COVERED IN TRAINIll6. CHECK TEIFERATURES TO E VERIFIED AT IS 'TitEllDIll6 TO 557' tellCH IS All 557 F IIETER INCRDIENTS ARE 10 APPil0XIllATI0li A110 STABILIZED VRUE, F IIOT A CHECK ltEADill6. THE IllSTRNENT l GitADUATIGl 0F 555 F IS SUFFICIEllTLY CLOSE.

1159 TA 1TA TEST ES 1.1 OltIFICE FLOWS ARE REDUCED AT 110 ACTI0ll TRAINIll6 COVERS REDUCED FLOll AT STEP 13 LON PRESSURE, DD 110T llAllE IN REDUCED PRESSURE. LABEL OltIFICES BY l (#I 6PM AS PLAlulED (NED 1912) 1189 PR-45 AINRalCIATORS THAT PRESSTLY THESE ARE REFLASH F0ft FSAR AND THE AINRRICIATORS THAT UILASH Ill IRIS HAVE ItEfLASH AltE SEBIINGLY T.S. CGulITIENTS. THEY POSE HED AltE DESIlulED IllTO THE SOLID STATE i SINGLE INPUT LAIITS. IF S0, NO NVISAllCE TO THE OPERAT0lt PROTECTION SYSTEli TO IIIF0lut THE l THIS NEGATES THE NEED FOR AllD 00110T CAUSE AIIY OPERATOR OPERAT0lt 0F COlFONST OPEllA81LITY REFLASH. ERROR. NO ACTI0li ilEEDED. REQUIRBENTS. EXAIFLE, SI ACCUIRILATOR ISOULTIGI VALVE AINIUIICIAT0ltS WILL llEFLASH IF RCS PitESSpitE IS GitEATS thall 1980 PSI 6, AllD NILL CGITIIRIE TO REFLA91 UllTIL VALVES ARE OPSIED.

l 1 1202 E0P VALIDATI0ll Oil ENEll6 8US FAULT D6 STARTS THIS IS A VERY LON PR08A81LITY THE SIIRILATOR 18A5 UPDATED TO C0ltRECT DISCREPANCY 87 RIT WILL 100T LOAD. EVERY 90 FAILURE, AllD IF IT OCCURRED THIS A110llALY ON FEB WARY 9, 1986.

SEC. 'L0li JACKET NTR PRESS' & THE DIESEL NOULD TRIP Oil HIllH

'06 FAIL TO START

• JACKET TBF IN 3 IIIN. S0 THE '

l AINRNICIATORS REFLASH - REFLASH NOULD 1107 CONTIIRIE.

IRJISAllCE 1X50N107-2, THE PR08L81Il0TED llAS A 1X4AK01-42 [PS-22H] [AL838F05] SIIRILATION A110NALY.

l

7 CEORGIA POWER COMPANY 189 CGITROL ROOM DESIM REVIEll CATEGORY 4A JUSTIFICATION REPORT HED ORI6111 DESCRIPTION PROPOSED RESOLUTlWI 4A JUSilFICATION

==

1203 GEN PANEL CXLST, INDICATORS HAVE 24 DIVISIONS MAJOR & IIINOR DIVISIONS ARE SEE HED 8 1110 QPCP G-28 BETWEENNUMERALS(ALI-275238 DISTINCT & THERE IS LITTLE AllD PISL-9699) POTENTIAL ERROR IN READING.

ALSO NEITHER INST IS SAFETY RELATED.110 ACTIGl.

1204 GS PANEL CKLST, ' PUSH TO TEST' PUSH BUTTONS ON 110 ACTION TEST BUTTONS ARE PHYSICALLY OFFSET QPCPG-40 STATUS LIGHT BOARDS ARD'T FROM OTHER LIGHTS AllD ARE LA8ELED UNIQUE. TEST.

1222 NUREG 0700 IN THE EVENT OF A REACTOR NO ACTION. THE DISTINCTIVE FLASH OF THE FIRST OUT (6.3.1.3.) TRIP, THE TILE ASSOCIATF0 NITH IS SPECIFICALLY DESIMED TO THE EVENT ILLUNINATES. OTHER DIFFERENTIATE IT FROM LATER ALAINIS.

TILES ILLUNINATE, COUNTER TO SUBSEQUENT ALARMS CoIE IN WITH NONW.

0700. FLASH. THE LATER ALA M FOR SAFETY INJECTION IS SPECIALLY NEEDED TO SUPPORT THE E0PS.

1223 NUREG 0700 THERE IS NO TUR81NE TRIP FIRST THIS INFO MATION IS NOT TUR8INE FIRST GUT INFOMATION IS (6.3.1.3.) OUT. TUR81NE TRIPS Oil AL819 REQUIREDFORSAFEOPERATIONS SUPPLIED BY THE ADVANCED TUR8INE

MD AL820ARE NOT FIRST GUT OF THE PLMT. AlIY TURBINE SUPERVISORY INSTRUMENTATION SYSTEli, l AIIIUNCIATORS, AS REC 0 pup 0ED TRIP PRELUDES A REACTOR TRIP CONTROL ROOM PRINTER. AND IS ALSO IN 0700. WICH IS AINIUllCIATED ON THE RX AVAILA8LE 011 THE TUR8IllE TRIP 8 ACE FIRST-0UT. TURBINE TRIP PAllELS IN THE CONTROL R0W.

INFORMATION FOR LATER DIAGNOSIS IS AVAILABLE ON THE EHC BACK PAllELS IN THE IICR.

1226 IRJREG 0700 THERE IS NO SILEllCE FEATURE IN 110 ACTION THIS IS A DESIGN FEATURE, SELECTED SY (6.3.4.1.) THE AlulullCIATOR SYSTEll, AS MAllAGBEllT TO PRECLUDE SILENCE OF M DISTIllCT FROM AC1010lfLEDGE. ALAM AND SUBSEQUElli FAILURE TO INVESTIGATE IT. THIS IRRILD HAVE AN ESPECIALLY SIMIFICAllT ERROR POTENTIAL 0118ACK PAllELS IF SILEllCED ROM TIE IIAIN AREA.

1228 IRJRE6 0700 ANNUllCIATOR CONTROL BUTTONS 110 ACTION THE BUTTONS ARE Cai3ISTENTLy asoamun (6.3.4.2.) ARE NOT SHAPE OR COLOR CODED. TOP TO BOTTON AC90NLEDGE/ RESET / TEST.

ALL ARE tellTE WITH 8 LACK PLAlulED AD0ITION OF COVERS TO THE TEST HJIICTI0ll LA8ELS. BUTTall NILL ALSO SERVE AS A SHAPE CODE l

BY suARDINs.

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l

CEGAGIA POWER COMPANY 190 CERITROL ROM DESIR REVIS CATEGORY 4A JUSTIFICATION REPORT HED ORIGIN DESCRIPiloll PROPOSED RESOLUTI(Il 4A JUST,IFICATION 1230 NUREG 0700 SOE A10MICIATORS ARE Ell 6 RAVED 110 ACTION WE WILL USE 1/4' LETTERS G1 MM (6.3.3.5.) WITH Il1 CONSISTENT LETTER AINENICIATOR TILES AS IIESSAGE LSETN SIZES. THIS IS All ON-SITE RE: PElullTS TO IIFil0VE VISIBILITY.

(AL804) FABRICATION PR00LEN.

1231 IRlREG 0700 ON SilALL COIITROLS THE 100 ACTION SIllCE THE PURPOSE OF THE CLEARANCE IS (6.6.5.1.) CLEARANCE TA6 08SCURES THE TO PREVEllT OPERATIGI, OBSCURING THE Hall 0 SNITCH LA8ELS. LA8EL HAS NO OPERATIONAL EFFECT. A SIIALL, APPROKIll4TELY TWO INCH S@lAE TAG IS USE0 FOR CIIITROL SWITOES. A SIALLER TAS WOULD E LESS VISIKE 20 Il1 CREASE THE PROBABILITY OF EMOR.

1232 NUREG 0700 THE CLEARAllCE TA6 DOES Il0T 110 ACTION A CONTROL SWITCH N mwr TAS IS FOR (6.6.5.1.) PHYSICALLY PRESST ACTUATION IllF0IBIATION TO OPERATOR. PROTECT!W OF 0F A CGITil0L. PmmelF1 AllD EQUIPIEIIT IS ACColpLISIED Iy namFR 0*ENING GP.

RACIRIT OR LOCEGIT, OR FUSE PULLING OR YALVE ISOLATIGI 0F THE AFFECTED EQUIPIsli (REF. 00304-C) 1217 CONTil0L R00ll THE ERF COIFUTER DOES Il0T 110 ACTION THE SYSTEll DESIR IS FOR SELECTIGI 0F i CGFUTERSURVEYN.R.PROVIDEASEQUSTIALHISTORY DISPLAY FOR CUllRENT USE. TMS E IS ND 0700 6.7.1.3. FILE OF OPERATOR EllTRIES, INTEREST IN lelAT llAS PREVIOUSLY AVAILABLE UPON REQUEST. DISPLAYED.

1230 CalrUTER SURVEY N.R. THE ERF COIFUTER DOES Il0T WO ACTION THE ERF COIFUTER USES All A,B,C EEYPAD l

0700 6.7.1.4. CONFOINI TO THE STAllDARD FOR ENTRY. THIS IS SUPERIOR FOR

'QNERTY' KEYBOARD ARRAlI6EllENT. LIIIITED ENTRY (2-3 OIARACTER IIAX) IY NON CLHICAL OP0tATORS.

1240 COIFUTER SUltVEY N.R. THE PROTEUS OPERATIl16 110 ACTION THE PHILOSOPHY OF QUR OPERATING 0700 6.7.1.8. PROCEDuitE 13504-1 REV.0 00ES PROCE21RES IS TO COVER OPEllATOR NOT DESCRI K THE OVERALL IIITERACTIONS WITH THE SYSTEll GILY.

CGWUTER SYSTHI, Allo THE SYSTal DESCRIPTIMS AltE Ill OTHER I CGrl'TER SYSTEli COIFONENTS TRAINIII6 OR TEQIIICAL fil!TERIAL.

WITH 19110f THE OPERATOR CAN INTERFACE.

1241 CONPUTER SURVEY ll.R. DATA PRESSTATION, PERIOOS ARE 110 ACTION THE IElti SELECTIGI IMIBERS (1,2.3,...)

0700 6.7.2.4.K 110T PLACED AFTER ITEli PROCEED THE DESCRIPTIGI AND ARE SELECTIGI DESIGIATORS AND AT BRACKETED F0ft DISTIl1CTICII. THIS lEETS THE E110 0F SalTEllCES. THE INTENT OF THE WIDELINE.

CEORGIA POWER COMPANY 191 CONTROL ROON DESIM REVIEN CATEGORY 4A JUSTIFICATION REPORT HED OR: GIN DESCRIPTION PROPCSED RESOLUTION 4A JUSTIFICATION 1243 COWUTER SUiiVEY N.R. ERROR CORRECTION GUIDANCE NO ACTION ' INVALID EllTRY' IESSAGE PROWTS 1700 6.7.2.6. ERROR RESSAGES 00 NOT CONTAIN OPERATOR TO TRY AGAlli. INPUTS ARE INSTRUCTIONS TO THE OPERATOR LIMITED TO 5-7 CHARACTER INPl!i REGARDIII6THEREQUIRED IDENTIFICATIONS.THISISADE43dE CORRECTION. FEED 8ACK OF THE OPERATOR.

1244 COWUTER SURVEY N.R. SYSTEM STATUS FEED 8ACK, THE NO ACTION SYSTEN OPERATION IS TRANSPARENT TO THE 0700 6.7.2.6. PROTEUS DOES NOT PROVIDE CONTROL 200N OPERATOR. FAILURE IS FEED 8ACK TO THE OPERATOR AS TO EVIDDIT BY LACE OF COWUTER RESPWSE COWUTER SYSTEli STATUS TO OPERATOR IllPUT, OR LOSS OF DISPLAY.

(fe..lIAI, STOP, FAILED, ONLINE).

1247 COMPUTER SURVEY N.R. THE 8 LINK RATE OF A SYN 80L OR NO ACTION THE BLINK RATE OF 1 SEC. IS A NINOR 0700 6.7.2.7.E NESSAGE IS SLONER thall THE DEVIATION FRON GUIDELINES NITH NO REC 0lWENDED GUIDELINES OF ~2-3 IWACT (31 OPERATOR.

OLIM S PER SECONO NITH A RINIIRNI 50 RSEC *0N' Tile ETNES BLANES.

1248 COWUTER SURVEY N.R. INVERSE VIDEO IS USED FOR NO ACTION THIS IS A IIINOR DEVIATION FRON 0700 6.7.2.7.F APPLICATIONS OUT SIDE THE GUIDELINES AllD HAS NO IWACT GI GUIDELIllES PRESalTED IN 0700. OPERATION.

THE ElIDELINES STATE INVERSE VIDE 0 SHOULD EE USED FOR HIELIETIII6 IN DEllSE DATA FIELOS, SUCH AS IE)ROS IN A PARAGRAPH NOT BITIRE CRT SECTICIIS: PROTEUS-ALAIBI, ERF-CSFST 1249 COWUTER SURVEY N.R. USE OF COLOR, COLORS USED ON NO ACTION THE USE OF RED - GREBI FOR VALVE 0700 6.7.2.7.K BOTH THE PROTEUS AND THE ERF POSITI0ll CN GRAPHICS SUPPLBEllTS TIE CRTS TO CONVEY lilF0IIIATION ARE OUTLIllE - SOLIO GRAPHIC FOR OP81-3RIT.

Il0T CONSISTENT IN USE AllD THIS IS CollSIST81T NITH NC8 OP88-SRIT IEAllIll6 NITH OTHER COLOR CODES COLORS AND DOES NOT PRESBIT A CGELICT

( RED & GREDI ) IN THE CollTROL NITH RED - GREBl/AUUBHIDINIAL R00ll. CONVBITICII DUE TO TRAINIII6.

1250 COMUTER SURVEY N.R. IRILTIPLE PAGE CONSIDERATIONS, 110 ACTIGl THIS FEATURE IS INIIECESSARY IN TIE 0700 6.7.2.8.8 leiEN PAGES ARE ORGAllIZED Ill A SHALLON 3 LEVEL HIERARCHY DISPLAYS HIERARCHICAL FASHION, USED. DISPLAY LA8EIS IDGITIFY 10lICH 4AITAINIII6 DIFFER 81T PATHS HIERARCHY THEY AltE PART 0F.

lHil0U91 A SERIES, A VISUAL AUDIT TRAIL 0F THt 010lCES IIADE ARE 110T AVAILABLE UPGl OPERATORREQUEST.

CEORGIA POWER COMPANY 192 CONTROL ROM DESIM REVIEW CATEGORY 4A JUSilf! CATION REPORT HED ORIGIN DESCRIPTION PROPOSED RESOLUTION 4A JUSTIFICATION

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1251 ANTHROPOIIETRIC THE SENQlBOARD DESIM SLOPE, NO ACTION THIS NINOR DEVIATION Call E SURVEY N.R. 0700 IN CONJullCTION WITH THE DESIGN COIFEllSATED FOR EASILY BY OPERATE 6.1.2.2.c DEPTH, DOES Il0T RESULT IN ALL FliXURE. ONLYINFREQUSTLYOPERATS THE CONTil0LS belli 6 WITHIN THE CONTROLS ARS OUTSIDE THE RANGE GI THE REACH RADIUS OF THE 5th YERTICAL SECTION OF 80ARD.

PERCENTILE FERALE.

1252 ANTHROPONETRIC HORIZONTAL DISPLACEMENT, THE 100 ACTION, THE DESIGN IS TO PANEL DESIM IS SUQI THAT AIERRICIATORS SURVEY N.R. 0700 08LIQUE AN6LE FR0ll THE LillE OF READ AllD EVALUATE THE ALAlut ARE PLACED A80VE THE APPLICA E E 6.1.2.2. SIGHT TO All AliNUNCIATOR FRoll DIRECTLY IN FRONT OF THE CONTil0LS, NOT THAT THE AaBMICIATR LOCATED TO EITHER SIDE OF THE PAllEL, NOT THE ACl010NLEDGE AC M OWLEDGE STAT 10ll E LOCATED IN AC MOWLEDGE STATION IS LESS STATI0ll. THIS IIINOR DEVIATION CLOSE PROXIRITY TO EAQI AIBUICIATE THAN45 DEGREES.[HS-40051, DOES IlOT IIARRAlli THE AD0lTICII PANEL GROUP.

52, 55, 56, 57, 109, 110, AND OF ACROWLEDGE STATIONS.

QPCP & (pfVC) i 1253 ANTHROPCNETRIC CONTROL HEIGHT, PAllEL DESIGli 100 ACTICII, THE 73* HEIGIT IS A SEE HED 81001

! SURVEY N.R. 0700 PLACES CONTROLS A80VE THE lill10R DEVIATION Allo WILL IIOT l 6.1.2.5 REC 0lelENDED 70' A80VE THE CollTRIBUTE TO OPERATOR ERROR.

, FLOOR. THE CollTil0L IS SELDON OPERATED.

l 1254 AllTHROPONETRIC DISPLAY HEIGHT, PANEL DESIGN 110 ACTION, TME Mll10R DEVIATI0lt SEE HED 8 1001 SURVEY N.R. 0700 PLACES IllDICATORS ABOVE THE (5'-11') A80VE THE allDELINE 6.1.2.5.b RECOIIIENDED 70' A80VE THE WILL 100T CAUSE OPERATOR ERROR.

FLOOR, AllD ALSO PLACES THE D.G. VOLTIIETER (31 QEA8 A80VE THE ItEC0fgl ENDED 65* A80VE THE FLOOR.

1257 841 SURVEY N.R. 0700 CONTROL PANELS QPCP & QNVC 100 ACT!0Il THE 11' DEVIATION Flpt EllDEliHE IIILL 6.1.1.3.f NERE NOT DESIMED AllD HAVE NO EFFECT ON OPERATOR IllSTALLED WITH THE REcolgGDED PERF01BIAllCE. IT IS A MIIIOR DEVIATI(Il 50' SEPARATI0ll BETWEEN THE WITH 110 ERROR POTENTIAL. THESE SPACES PANEL AllD THE OPPOSIlIG ARE IIOT l'5fD FJR 110lgIAL TRAFFIC AS SURFACE. 39' PROVIDu, PERSGelEL ACCESS WITNIN OSHA STANDARDS.

1254 84l SURVEY N.R. 0700 THE 80RIC ACID BLENDER 110 ACTION THE SNALLER THAN GUIDELINE THUlI816iEEL 6.4.5.1.d(2) TOTALIZER THUMBE EELS 00 100T IS A MINIATURE CONTROL AND THE NILITARY CONF 0 m TO THE REcole B DED TYPE SPECIFICATI01l IN THE WIDELIE IS DIIEllSIONS AS SPECIFIED. IllAPPROPRIATE. 110 OPERATOR ERROR R DIFFICULTY HAS KEN llEPORTED IN ll5ING THIS TIRileelEEL.

CEO6tGI A POtfER COMPANY 193 CM TROL 80 5 DESIM REVI S CATEGORY 4A JUSTIFICATIGl REPORT HED ORIGIN DESCRIPTION PROPOSED RESOLUTI0li 4A JUSTIFICATION

= -.

1250 OPERATOR THE IIFULSE PRESSURE NO ACTION Ally 'FIX* NOULD EITHER REQUIRE EITNER QUESTI0lNIAIRE81-7-1 INDICATORSPI-505/506ON1B1 IIOYEMENT OF INDICATORS OR HIGHLINTil16 ARE DIFFICULT TO LOCATE. THEY OF INDICATORS. SillCE BOTH REACTOR &

ARE IN All AREA 0F NAllY SIN!LAR TUR8IllE OPERATOR USE THESE IETERS, Ally INSTaulENTS. NOVEIENT WOULD CREATE ANOTHER PROES.

HIELIGITING IETERS NOULD CAUSE DISTRACTIONS let!LE USING IllDICATORS IN THE VICINITY. HIERARCHICAL LASELING WILL IIFROVE VISIBILITY.

i 1262 COMPUTER SURVEY N.R. THE PRC!EUS COMPUTER DOES NOT NO ACTION THE ALLONED OPERATOR ACTIGIS, CHAN61116 0700 6.7.1.1.d REQUIREOPERATOR ALANIS HASES, ARE REVERSIBLE AllD 00 AC1010EEDGENT (ie..ARE YOU NOT IlrACT SYSTS OPERATIGl. TH15 SultE) BEFORE AIIY OPERATOR GUIDELINE IS INAPPROPRIATE FOR THESE REQUESTSAREPROCESSEDTHAT APPLICATI0llS.

NOULD REMN.TIl16 A PElulAllENT l CHAll6E TO EXISTil16 DATA 1

1263 CollPUTER SURVEY N.R. THE KEY 80AROS ON 80TH THE ERF NO ACTION THE Mll10R DEVIATION Ill KEY 80AltD ANGLE 0700 6.7.1.4.g AllD THE PROTEUS HAVE SLOPES OF APPROXINATELY 12 DEG2EES VICE 15 l LESS thall THE RECOMENDED 15 DEGREES HAS 110 IIFACT ON OPERATOR j DEGREES NINIIRill RNICTION.

( 1264 CalrUTER SURVEY ll.R. leiEN PROTEOUS CRT's ARE 100 ACTION THE CONTROL 0F DISPLAYS BY THE SYSTM l 07006.7.1.5.c(1) SUILIECT TO OPERATION WY A TEINIINAL IN THE ColpUTER ROON IS NOT SECOND CGITil0L STATI0ll USED EXCEPT FOR IIAlllTENANCE.

(RBIOTE) POSITIVE INDICATION ADDITI0llALLY THE RENOTE DOES NOT IS IlOT PROVIDED 011 THOSE CRT's CONTil0L THE SCRES, IT Sell 0S A IDENTIFYING THE CONTROL DISPLAY. THE IICR CAN CHAll6E DISPLAY STATION AS D5 SIRED.

l 1267 C01FUTER SURVEY N.R. ITEllS CONTAINED IF A NUllBERED NO ACTION THE ERF COMUTER IElcTI-PAGE INPUT 07006.7.2.5.J LIST AND DESCRIEL IN GROUPIII6 Call E RECALLED BY LOGICAL

'CollTINUE PAGES' ITEMS ARE Il0T ColelllATIO11S OF KEY WORDS. IT IS SEQUENTIALLYNUlWEREDRELATIVE tUWERED BY C0lrUTER POINT I.D., TIE TO THE FIRST PAGE. SEQUEllCE Ill THE LIST HAS 110 SIMIFICAllCE SO SEQUSTIAL IIUIEERIlti IS NOT 4 2DED.

f

CEOftGI A POWER COMPANY 194 C M TROL RO M DESIR REVIEN CATEGORY 4A JUSTIFICATION REPORT l

NED ORIGIN DESCRIPTION PROPOSED RESOLUTION 4A JUSTIFICATION ,

~

l 1269 COWUTER SURVEY N.R. THE PRINTER USED IN THE NO ACTION, THE PRINTER IS NOT THE PROTEUS PRINTER IS USED TO ANALYZE 0700 6.7.3.1.d, CONTROL ROON FOR RECORDIII6 A LPN TYPE, BUT IS A CHARACTER PLMT DATA AFTER THE FACT AllD THE 6.3.1.2.c.(2) TREllD DATA, CCWUTER AUUutS 00 PER SECOND RATED PRINTER. THE RETDITION OF RELEVAllT DATA LOGING llCT HAVE THE RECONIENDED OUTPUT IS NOT NEEDED FOR SAFE INFORMATI0ll[lelEREPRINTERSPEEDIS PRINTIINi SPEED OF 300 LINES OPERATION 0F THE PLAllT, BEING IWORTAllT) IS IRRELEVAlli.

PER NIIRITE USED flAINLY FOR PLAlli ANALYSIS AND TRIP REVIEN.

1270 COWUTER SURVEY N.R. PROVISIONS ARE NOT INCLUDED TO NO ACTION THIS FEATURE IS OF NO UTILITY TO THE 0700 6.7.3.2.c PROVIDE. UPON OPERATOR OPERATOR, THERE IS N0 IW ACT IN REQUEST,PRINTOUTSSYALARN OPERATION.

GAOUP(eg.SYSTBI,SU85YSTEN, COWON81T) 1271 8 & H SURVEY N.R. MANY CONTROL RO0li INDICATORS NO ACTION THE IETERS HAVE GRADUATIGl HEIGITS 0700 6.5.1.5.b HAVE A GRADUATION HEIGHT LESS FRON .01' TO .15' BELON THE EUIDELINE.

THAN REColgiENDED FOR THE 3 FT THIS IS A IIINOR DEVIATION AllD HAS N0 VIBIING DISTANCE. 08 SERVED OR EXPECTED EFFECT ON OPERATIES.

1272 3 & H SURVEY N.R. THE AC VOLINETERS 011 QEA8 DO NO ACTION THESE NETERS Call BE ALIGNED TO A 17006.9.1.2.c.(4) NOT READ OFF - SCALE LOW leiEN Nul8ER OF SOURCES. THE OPERATOR WILL j

NOT SELECTED. ONLY BE USIll6 THIS lETER IN

CGLANICTION WITH SELECTING A PARTICULAR SOURCE. THE NOINIAL ZERO READIll6 MAS 110 OPERATIMAL S?911FICAllCE.

1274 8 & H SURVEY N.R. ROCKER SWITCHES ON THE IIAIN i80 ACTION THIS IS A TYPE OF IIONENTARY CfWiliOL 87006.4.5.4.b(2) GENERATOR EXCITER CONTil0LS ARE INPUT AND IS NOT DESIGIED TO MAINTAIN IIOT FLilSH NITH THE PAllEL POSITION. SYSTEll STATUS IS SH0181 IN SultFACE Ill THE 011 POSIT 10ll AND ADJACEllT Mill!C LI9fTS. THE SIZE

! THE NIDTH AND DISPLAC8IENT ARE GUIDELINE IS IllAPPROPRIATE FOR THIS l

LESS thall THE REC 0lOEll0ED APPLICATI0ll.

DIIIBISIONS.

1 1282 ANilVNCIATOR & ALL AlefullCIATORS SHOULD BE 110 ACTION REACTOR TRIP IllPUTS LEET THIS CW FUTER SURVEY 0700 RECORDED ON HARD COPY All0 GUIDELINE. EXTEllSIGl TO OTHER PLAfri 6.3.1.2.c(2) leiERE JRILTI-INPUT AlelullCIATORS PARAllETERS/ALAIBIS IS A ItEDESIGl EFFORT 6.7.3.2.a(2) ARE USED All ALARN PRINTOUT BEYOND THE SCOPE OF NURE6 07371.D.1 1 SHOULD IDOITIFY THE INDIVIOUAL ALAIII INPUTS IN THE ALAlpt CGIDITIGl.

l l

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l CEORGIA POWER COMPANY 195 CONTROL 200N DESIM REVIEN CATEGORY 4A JUSTIFICATION REPORT NED ORIGIN DESCRIPTION PROPOSED RESOLUTION 4A JUSTIFICATION

==

1292 AleMICIATOR SURVEY THE AlgluuCIATOR PMEL N0 ACTI0li THE DESIGN IllTENT IS FOR THE OPENTOR N.R. 0700 IDENTIFICATION LABEL HEIGHT TO READ THE A10MICIATOR AT THE PAIEL.

6.3.3.1.b(2) (LETTER SIZE) IS LESS thall THE IllCREASIh6 THE LA8EL SIZE NOULD NGT REC 0lgENDED Hl.6HT, IF VIENED INPROVE OPERATION.

FRON A CENTRA! POSITION N!THIM THE PRINARY Of ERATING AREA.(815.5 n . LETTER SIZE SHOULDATLEASTBE.75')

1295 GENERAL PAllEL NAllY ESCUTCHEON PLATE LA8ELS 110 ACTION THE EQUIPMENT llAllE IS A80bE THE QlECKLIST(6)6-10 ARE 08SCURED FRON VIEli BY THE HMDSWITCH AND RENAINS VISIBLE. TIE HAllD OR Alpt IsiEli THE SNITCH IS HAllDSWITCH IMWER IN THE LOIER LEFT OPERATED. ColulER IS SolETIIES terstarn RIRIs OPERATI0ll,RIT NO REFERENCE IS Il48E TO THIS IllF0lulAi!ON AFTER THE SMITOI IS SELECTED.

1296 GENERAL PAllEL THE SCALES ON THE AUTO-ilAllUAL 110 ACTION THESE LIGIT 8AR IllDICATORS USE A LIGIT OlECKLIST 6-22 STATI0llS WITH THE PLASilA 8EMIND A GLASS SCREEli WITH IIIITE EALE DISPLAY ARE NOT BLACK llARKill6S IIARKS. THESE PROVIDE BETTER CGITNIST IN A leilTE BACR6fl0UND. FOR THIS TYPE DISPLAY. THE Ell 8ELIE IS IllAPPROPRIATE FOR THIS TYPE DISPLAY.

1298 GENERAL PAllEL THE DIGITAL C0lalTERS 011 THE 110 ACTI0ll, THE leIITE ON 8 LACK SEE HED81890 OlECKLIST 6-47 BORIC ACID TOTALIZER A110 THE PROVIDES ADEQUtTE CONTRAST, CONTil0L 1100 STEP IllDICATGilS ARE Il0T NEEDED IN L0li LIGIT AltE IIOT BLACK NullBERS ON leilTE CONDITIONS, MD ARE PROTECTED BACK61101510, CONTRARY TO THE Fil0N DIRT 8Y COVERS.110 QIAlIGE ItEC0lOEllDED GUIDELIllE. IS NEEDED.

1302 601ERAL PANEL THE FOLLONIll6 COUNTERS ARE 110 ACTI0ll, THE tellTE LETTERS SEE HED 8 1098 QiECKLIST G-47 leIITE NUMBERS Ill A BLACK PROVIDEADEQUATECONTRAST.

BACK6ROLIID CGITRARY TO THE RECcleENDED al!DELINE: DelT C00Lil16 IsilTS TO SL51P IK1-17890 & 94 A110 IIASTE IIATER TOTALIZEEAFQ1-7628.

1303 GG ERAL PAllEL THE FOLLONIll6 INDICATORS 110 ACTI0ll THESE CVCS FLOW INDICATORS ARE OtECKLIST G-28 CONTAlli GREATER THAN THE ADEQUATELY GRADUATED FOR THE MNY NAXIlUI 0F NINE INTERNEDIATE OF READIll6 ItEQUlltED AllD NAJOR Allo GitADUATIONS BETIEEll IIUMBERED nil 10R GRADUATI0llS AltE ADEQUATE. 50 flAltKil165: IFI-1388, 4068 & ACTI0ll. SALE AS HED-1118.

4878.

CEORGIA POWER COMPANY 196 CONTROL ROON DESIM REVIEW CATEGORY 4A JUSTIFICATIGI REPORT HED ORIGIN DESCRIPTION PROPOSED RESOLUTIOW 4A JUSTIFICATION

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1308 8 E H SURVEY AUTO NAlIVAL STATIONS 00 NOT NO ACTION THESE CONTROLS ARE NEVER OPERATED PROVIDE THE REC 0lgENDED SPACE SilRlLTME00 SLY AllD THE ROTARY CONTROL BETWEEli THE ROTARY COUNTER MD CONTAlllS A LOCKIll6 DEVICE. GUIDELIE THE PUSH 8UTTON. IS INAPPROPRIATE FOR THIS TYPE NODULAR tal!T.

1312 COMPUTER SURVEY IitSTRUCTIONS FOR RELOADIll6 100 ACTION THIS IS NOT NORMALLY AN OPERATOR TASK, ilURE6 0700 PAPER OR RIB 80ll NO IIOT APPEAR IT IS PERFORNED BY IEC TE00llCIAllS.

6.7.3.1.e.(3) ON AN INSTRUCTION PLATE ON THE ADDITIONALLY THE TASK IS EASY TO PRINTERS. ACCOIFLISH DUE TO CARTRIDGE RI80 MIS THAT SLIP IN A TYPEINtITER STYLE PAPER FEED.

1314 NESTill6 HOUSE ICCR THE FOLLONIl86 IllSTRUNENTATION NO ACTION. THE RANGE OVER SEE THE ICCR RESULTS SECTION OF THE INVENTORY 00ES NOT NEET THE Il!Nilpl IGi!CH THE PARAllETERS VARY SulgWtY REPORT ,

RANGE REQUIREIENTS OF THE DURIll6 SYSTEM OPERATION AS ICCR: 1-FI-0917A, 1-FI-0110 VERIFIED OURIll6 THE E0P 1-TI-0103, 1-FI-5150A, VALIDATION EXERCISE DID 110T 1-FI-0121C Allo 1-FR-0156. EXCEED THE RAlIGE OF THE IllSTALLED INSTRUNENTATI0ll.

1315 NESTill@0USE ICCR THE FOLLONIll6 INSTRUNENTATION 110 ACTION. THE A80VE LOOP SEE THE ICCR RESULTS SECTION OF THE INVENTORY EXCEEDS THE IIINIlut LOOP PARAllETERS 00110T PROVIDE SuppWlY REPORT

/CCURACY AS SPECIFIED IN THE IllFORilATI0ll NEEDED SY THE ICCR: 1-PI-0919,1-LI-0931A, OPERATOR FOR ColtRECTIVE ACTION '

1-LI-9470, 1-PI-0449, CUES TO NAIRIALLY llAINTAIN THE 1-FR-0110 All01-TI-0103. PRIllAltY PLAllT NITNIN LIMITS.

PUUIT SPECIFIC ACCURACIES HAVE BEEN IllCORPORATED Ill SETPOINTS USED Ill INIITING E0Ps 1317 IIESTINGHOUSE ICCR THE FOLLOWill6 IllSTRUNENTS 110 ACTION SEE THE ICCR RESULTS SECTION OF THE l IllVENTORY EXCEED THE NINIlut ItESOLUTI0li SUleWtY ltEPORT AS SPECIFIED IN THE ICCR:

1-LI-0931A,1-TI-0183, 1-FR-0158 AND 1-SI-5136.

1318 IIESTillGHOUSE ICCR THE FOLL0lilll6 PARAllETERS, AS 110 ACTION SEE THE ICCR RESULTS SECTION OF THE IllVENTORY IDENTIFIED IN THE ICCR ARE NOT SuleWtY ltEPORT IN0!CATED Ill THE CollTil0L ROON:

1) IICP SEAL INJ Tele 2) RCP ACCN THEWAL 8ARRIER FLOW 3)

CCN FLoll T0 IHt HX 4) SPENT FUEL POOL LEVEL 5) SPENT FUEL POOL C00LIll6 NATER FL0li

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CEORGIA POWER COMPANY 197 '

CONTROL RO M DESIN REVIEN CATEGORY 4A JUSTIFICATION REPORT i HED ORIGIN DESCRIPTION PROPOSED RESOLUT!W 4A JUSilFICATION

==

1319 DESIM CHANGE A DESIM CHANGE NAS INITIATED NO ACTICII THE PROTEUS COlFUTER PROVIDES MNF AND CCP-S-1-0054-M THAT CREATED ELTIPLE INPUT N0 TOR BEARIII6 TBFERATURES AND 13.MV AINRINCIATORS WITHOUT AVAILA8LE SNGR AIFS. THIS INF0 MATIM IS INSTIMENTATION TO DIA90SE SUFFICIENT OT DIAGNOSE THE 'E LTIPLE WICH INPUT CONDITION IS CHOICE' ALAaN, LON PIT LEVEL OR LOSS CAUSING THE ALAM ON THE CIRC 0F UTILITYETER.

NATER PUIF

GEORGIA POWER COMPANY 198

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CEORGIA PO86ER COMPANY 199 CtBITIOL B0(Il DESIM REVIEll CAmm Rn NEDs HED ORI6111 DESCRIPTION PROPOSED RESOLUTION

==

1807 1982 PRELINIIIARY THE IISCW TRAIN A AllD TRAIN 8 IETERS THIS IS M AN0llALY OF THE 1982 NOCEUP. CURRENT CRDR(NED208) SEPARATIONISINADEquATE. DESIGN HAS 10 INCHES OF SEPARATION.

1911 1982 PRELININARY HS-8870A & HS 88708 ARE LA8ELED '8IST* THE SNITCHES HAVE 8EB REMOVED FRON THE CONTROL CADR(NED214) 80ARD.

1918 1982 PRELININARY THE DAIFER POSITION INDICATORS ON THE QHVC THIS WAS M ANONALY OF TME 1982 NOCKUP. THE CRDR(HED235) ARE IlOT LA8ELED. POSITIONS ARE LA8ELED.

1923 1982 PRELIMINARY THE CIRCULATIII6 IIATER AllD INSTRUNENT AIR THIS IIAS M ERROR IN THE NOCNUP USED FOR THE 1982 CRDR(NED242) NETERS ARE NOT FUNCTIONALLY ARRANGED NITH CRDR. CURRST LAYOUT IS FUNCTIONAL.

RESPECT TO THE CONTROL LAYOUT.

, 1058 1982 PRELIMINARY THERE IS 110 ANIENICIATOR FOR HIGH RADIATION IN THERE ARE SPECIFIC STEM GENERATOR RADIATION CRDR(NED504) THE STEM JET AIR EJECTOR LINE. IN FACT, ALARNS ON THE ERF C01FUTER DISPLAYS, NOT DESIMEJ THERE ARE ONLY THREE Aa010NCIATORS FOR IN 1982.

RADIATION 10llCH LEAD TO PERNS.

1862 1982 PRELIMINARY THERE IS NO INDICATION OF C0OLING IIATER FLON ERROR IN ORIGINAL SURVEY.

CRDR(NED509) TO THE CONTAllNIENT SPRAY HEAT EXGAlIGERS.

1964 82 PRELillINARY CRDR THIS CONCERilS NORKIl16 ENVIROINIENT P90EBIS THESE AREAS NILL BE SEPARATELY ADORESSED IN THE (NED501-606) SUCH AS LIGITill6 LEVELS,110!SE CONTROL, CURRENT SURVEY.

TEIFERATURE, IRNIIDITY, AND COLORS.

l 10T8 P1108LEN REPORT 39 ANNUllCIATOR LE6DDS SAY ' CRUD LEVEL' VICE BEYOND ins SCOPE OF CRDR (ON LOCAL PANEL) l l ' CRUD TANK LEVEL'. 'HIGH-Loll' AllD 'L0lHil91' LE6SDS AltE CONFUSil16. ON PAllEL 1-1224-PS-F8P/DRAllill6 IX4M06-312.

! 1079 Pfl08LEN REPORT 40 BACK FLUSHABLE FILTER PAllEL 1-1224-PS-F8P BEYOND SCOPE OF CRDR (ON LOCAL PMEL)

ORANIIIG 1X4A1106-290 USES GRES/0P3, RED / CLOSED VALVE INDICATION - OPPOSITE FROM PLMT CONVENTION.

1126 TA THERE IS 110 STATUS OF CIA SIGIIAL. ADO TO CMCEL SANE AS 1117 l

AINIUNCIATOR CVI & CS ALSO.

l 1141 TA 26A ECA3.3 STEP TRIN POT IS REVERSE ACTIll6 FOR VALVE, SEE HED l'221 13 POSITIVE FOR TEMP. OPERATOR 10lEN & OPERATED CORRECTLY, BUT NOTED REVERSE ACTION. SEBIS TO HAVE ADEQUATE TRAINilIG COVERAGE.

CEORGIA PotfER COf4PANY 203 CONTROL ROON DESIM REVIEN CANCELED HEDs HED ORIGIN DESCRIPTION PROPOSED RESOLUTION

==

1144 TA 19A E-0 STEP PATTEM 0F E8 LINTS IS IRREGULAR AllD CMCEL SME AS 1129 6-12 Il1 CREASES WORK LOAD TO IDENTIFY OUT OF POSITION EQUIPMENT 1145 TA E0 STEP 13 CHECKS PRESSURE AT 585 PSI THE CMCEL SANE AS 1118 IETER IllCRBENTS ARE 20 PSI 114i E0 STEP 21 CHECKS PRESSURE < 1373 PSI METER CMCEL SAME AS 1116 INCRBEllTS ARE EO PSI ALSO E0,35:

E0,CAllTION:

1151 TA IIEED T0 INVESTIGATE THE POSSIBILITY OF CANCELED, RCP STATUS IS ON THE PROTEUS DISPLAY.

. ARRAN6ING A GROUP ON THE SPDS lellCH WILL ALLOW A QUICK IEANS OF EVAlllATING RCP CINIDITIOkL.

1158 TA SCEMARIO 16A E 8'S 60 0FF ON LOSS OF 0FF-SITE POWER. THIS E8'S ARE POWERED FRON VITAL POWER TEST,6A ECAD.0 SHOULD BE VITAL AC TO SUPPORT E0P'S 1163 TA SCENARIO 11A IS OPERATOR CM NOT TELL NEAlulESS TO SETPOINT SI;!JLATOR ANONALY. NO RATE TRIPS AT CATAMBA, 8.2 STEP 9 FOR RATE SENSITIVE REACTOR TRIPS, STEM LINE CALLANAY, FARLEY PER PAUL II. K0CHERY TELELES, PRESSURE AND PRZR PRESSURE OFTEN RESULTS IN REVISE S!IllLATOR (DR 8435)

STEAll LillE RATE TRIP AS $0(Il AS LON PRESS.

TRIP IS ROCKED 1166 TA SCENARIG 21A 8YPASS VALVES HAVE REVERSE INDICATION GI SEE HED 1221 ESO.2 STEP 18 CONTROLLER.

1169 TA SCENARIO 21A ES ADVERSE CONTAINNENT CONDITIONS PER E0P'S CAllCEL, SAIE AS 1138 1.2/6,11-13 OCCUR IF CINIT HI PRESS SI OCCURS AT 4 PSIG 1170 TA SCENARIO 22A EO FIRST OUT SHOULD LOCK IN EVEN IF CLEARED. IF CMCEL. THIS IS A SIltlLATOR A110ll4LY. THE FIRST GUT STEP 4 CONDITION CLEARS, ALARM GOES allay M0 NILL BE DISTINCTIVELY FLASHED UllTIL A0X110NLEEER DIAG 110 SIS IS DIFFICULT. IT CM THEN 8E CLEARED IF THE ALAlti CONDITION NO l LONGER EXISTS.

1171TASCENARIO6ASTEPSiltiLATORENER681CYLIGHTilI6ISINADEQUATEAT CMCEL SME AS 1125 3EH/ECA 0 PCP AllD QHVC CHECK CONTROL ROOM 1172 TA ScalARIO 4A PROCEDURE SPECIFIED VALVES IN RBIOTE CMCEL, SME AS 1127 FR-S.1 STEP 7 LOCATI0llS WITHOUT 61 Vill 6 ANY LOCATIO11 INF0lNIATION

CEORGIA POWER COMPANY 201 Cl3l TROL ROON DESIR REVIEli CA m n HEDs ED ORIGIN DESCRIPTION PROPOSED RESOLUTION

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lits PR 12 flINIC BUS IS CONTINU0US AT CROSSIllGS BEYOND THE SCOPE OF CRDR (0UT SIDE TE CONTIDL ROON) 11TI PR-t NITH BOTH PORY & COPS TRMSFER SWITCHES Ill LOCAL CONTROL IS NOT DISA8 LED, ALL CONTROL IS

• LOCAL *, LOCAL CONTROL IS DISA8 LED. MANL'AL 8Y DESIW.

11T9 PR-13 DEVIATI0ll NETER DIRECTION VIOLATES THIS IS A SIltlLATOR A110NALY. THE CONTROL ROON POPULATIONALSTEREOTYPE[UPISCOLO)[00101IS INSTRUNENT(TI-412A)DISPLAYSTavg-TrefMITN NOT] ' HOT' AT THE TOP 0F THE lETER (+18*F) AND ' COLD' AT THE BOTT(31 (-30*F). THE DIRECTIMS IIATCH THE POPULATIONAL STERE 0 TYPE FOR INCREASING TEINTRATURE ,

= UP. ,

1 IIIT PR-31 PR-43 ESCUTCHE0ll PLATES ARE Il0N RED IN COLOR. CANCEL. THIS COLOR NATCHES THE SYSTS COLOR CHAll6E TO YELLON, ALSO EVALUATE OTHER RESET CONVENTION.

SNITCH COLORS FOR POSSIBLE CHAll6ES.

1191 PR-48 RED & BLUE PENS NEED TO 8E DESIGilATED ON SIIEJLATOR AN0llALY RECORDER LA8EL. ALSO CHECK OTHER RECORDERS FOR PROPER LA8ELS.

1193 PR-52 LA8ELED ARE REVERSED 8ETWEB HIC AND ZI SAME AS HED 1194.

1194 PR-53 LA8ELS REVERSED BETWEB HC AllD ZI. SEENS TO Silt)LATOR A110NALY E A ColgION P900LEN THil0UGHOUT THE CONTROL 200N.

1205 GEN PAN CKLST, QPCP RECORDERS HAVE LA8ELS FOR PEN-1 / PEN-2 BUT THE RECORDERS HAVE 8EEN REMOVED FRON THE Cr/ TROL 6-44 PENS ARE RED & 8 LACK ROOM 1214 PR08LEli REPORT IT3 ENER6ENCY OPERATill6 PROCEDURE E-0 IDENTIFIES AleMI. A06 & 806 HAVE BEEN DELETED FR0ll Pill. AL505 ALARMS EOS, FOS, A06 & 806 AS REACTOR TRIP A191UN. E06 & F06 ARE CORRECT AS IS, THE INTElli IS IllPUTS, THEREFORE THEY SHOULD BE 011 THE FIRST TO AlJull 011 INTElulAL NALFUIICTION 110T REACTOR TRIP CUT ALAl81 Pill. A110 THE NOR01116 SHOULD 8E lilPUTS. THE E0P' SHOULD BE REVISED CHAll6ED TO ALERTS OR PRE-TRIP INPUTS 1220 PR-79 TSLB / IX6AV02-165-4 EN6 RAVING FOR STN LillE REPLACED BY HED 1309 PRESSURE RATE TRIP IS NISLEADIII6 STN LP HI PRESS

CEORGIA POWER COMPANY 202 CONTROL R0131 DESIR RFYIElf

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CANCELD dGs HED ORIGIN DESCRIPTION PROPOSED RESOLUTION 1245 COMPUTER SURVEY DELAY FEED 8ACK, telEN SYSTER FUNCTIONS THIS IS M ERROR IN SIltilATION. THE PLAllT SYSTBI N.R. 0700 6.7.2.6.K REQUIRES THE OPERATOR TO STMD-8Y, PERIOOIC NEETS THE GUIDELINE.

FEED 8ACK IS NOT PROVIDED TO INDICATE 110AML SYSTEll OPERATION AllD THE REASON FOR THE DELAY. .

1256 MTHROPONETRIC THE SPDS IlORK STATION Ill THE CONTROL ROON NAS SEE HED8 1071 SURVEY N.R. 0700 DESIGNED NITH LESS thall THE REcclelENDED REE 6.1.2.7.d.(6) ROON DEPTH OF 18'.

1246 OPERATOR CONTAINIIENT PRESSURE INDICATORS PI-934, 935, SIllVLATOR AN0llALY. THE IIAIN CONTil0L ROON llETatS QUEST!0101 AIRE 936 & 937 ARE IN 000 INCRDIENTS OF 21/2 ARE SCALED IN ONE POUND IllCR81ENTS.

80004-02 PS!6.

1306 PR 108 A8.811-D01 ALAllli 'PRZR L0 LEVEL' SHOULD BE DUPLICATION OF HED 1215

'PRZR L0 LEVEL DEVIATIO11', THIS ALABI IS FOR A PRESSURIZER LEVEL DEVIATION FR0ll A VARIA8LE PROGRAll LEVEL, NOT All ABSOLilTE LEVEL.

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CEORGIA POWER COMPANY 203 APPENDIX 6.4 RESPONSE TO THE NRC IN-PROGRESS AUDIT (APPENDIX 8)

GEORGIA POWE3 COMPANY 204 FINDING 2.1.2 a) The Audit Team does not believe the CRDR Team Leader can provide the necessary CRDR support with only a 50% time commitment.

b) The Audit Team recommends that GPC dedicate additional appropriate personnel to the CRDR effort.

RESPONSE

a) The CRDR Team Leader no longer has line responsibility for the radioactive waste management program. Therefore, he is able to devote a greater proportion of time in l support of CRDR activities, b) In August of 1985 an additional full time contractor w a.; assigned to support the i

CRDR program. Another part time contractor was added in November 1985.

l

GEOftGIA POWE3 COMPANY 205 FINDING 2.2.2 a) The Audit Team could not determine that the GPC task analyses was performed down to a level of detail that identified parameters and variables associated with each task. In addition, identify specific characteristics of those parameters and variables such as the following that must be provided for the operator to successfully accomplish each task:

o Magnitude o Range o Accuracy o Variability o Tolerance o Trend and Rate of Change l

b) Each licensee and . applicant must describe the process for using the generic guidelines and documentation to identify the characteristics of needed instrumentation and controls.

GEORGIA POWER COMPANY 203 c) For each instrument and control used to implement the Emergency Operating Procedures, there should be an auditable record of how the needed characteristics of the instruments and controls were determined.

d) Task analysis process and methodology should be fully documented in the Summary Report, and should include the following:

o Discussions of approaches and information sources used.

o Rationale and methodology used in the selection of event sequences and how it was verified that the sequences covered the complete range of needed i systems, t

l I

o Process used to identify the functions, systems, subsystems and events.

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RESPONSE

a) See Section 4.3.6 of this report.

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CEORGIA POWER COMPANY 207 b) See Section 4.3.6 of this report.

c) See Section 4.3.6 of this report.

d) See Section 4.3.6 of this report.

I GEORGIA POWED COMPANY 208 i

l FINDING 2.3.2 '

l l

l GPC has not performed an independent determination of l information and control needs and c harac teris tics

$during the task analysis. Therefore, without this information a rigorous and systematic comparison of the control room inventory and control display requirements cannot be made. The Summary Report shall contain descriptions that demonstrate that the inventory is auditable and fulfills the intent of NUREG-0737.

o Identify I & C Equipment or Panels o Describe I & C Characteristics o Be Current (As Built)

RESPONSE

l See Section 4.3.6 of this report.

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GEORGIA POWED COMPANY 209 FINDING 2.4.2 a) The NRC Audit Team advised GPC that it would be necessary to compare the guidelines of the NUTAC document to those of NUREG-0700. .

b) GPC should re-evaluate its survey process to see if the difference in HEDs identified by the NRC Audit Team and by GPC review is indicative of a systematic deficiency in the GPC control room survey.

c) Include the above re-evaluation in the Summary Report.

RESPONSE

l l a) Vogtle CRDR program plan modifications to address NRC audit concerns on NUTAC vice NUREG 0700 survey usage.

Reference:

NRC Review of NUTAC 83-042 by R. W. Foelich, April 5, 1984.

GEORGIA POWE.2 COMPANY 210 I. NUTAC Section 2 definitions: The definitions section was not incorporated in our program.

II. NUTAC Section 3 survey development methodology

1. The Human Factor Specialist on the CRDR Team has personally inspected all equipment covered by the surveys for HED conditions and reviewed all survey reports. We have also provided a mechanism for operator input to supplement, not substitute for review against human factors guidelines.

i

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2. The experience level of our CRDR team was evaluated as satisfactory during our in progress audit.

3, 4, 5, 6, 7, 8. Items not included in the NUTAC surveys. Listed in Appendix B-H will be reviewed against the Vogtle design as an additional survey using NUREG 0700 guidelines.

CEORGIA POWER COMPANY 211 III. NRC comments on Appendix A:

1. Engineering Department Questionnaire no NRC comments.

2. Operator Questionnaire These are used to supplement, not substitute for, the specific guideline checks used in other surveys. We feel that operator concerns are a valid input to the design review process.

3. Overview Checklist OC-1. Mirror imaging is not used in the main control board or any part of our panels. Left-right relationships are preserved in duplication of equipment, such as train a/b.

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GEORGIA POWEO COMPANY 212 OC-4. The Shift Supervisor work station is located in the main control room, in view of the control panels, so "near" was not otherwise defined.

4. Operator Assisted Checklist i No NRC comments

5. Labeling, Mimics, and Demarcation This area will be supplemented by an additional survey using NUREG 0700, Section 6.6.

6. General Panel Checklist No NRC comments l 7. Control Room Computer Checklist i

j No NRC comments --- however, this and the control room computer survey will be replaced by NUREG 0700, Section 6.7, process computers.

CEOftGI A POWE"3 COMPANY 213

8. Design Convention Survey No action planned. The intent of this survey is not to identify all conventions, but to serve as an aid in identifying design i convention violations on the components covered.

9. Lighting Survey This survey will be replaced by NUREG 0700 Section 6.1.5.3/4.

10. Noise Survey This survey will be replaced by NUREG 0700-E1.

11. Anthropometric Survey This area will be supplemented by an additional survey using NUREG 0700, Section 6.1.2.

f

- --- - - - , - - -, , , , - - - -, .m,-v,-w,----- - - - - - - - . . ,-,,,--,a-,,,--,,,,-e-,,--,,,---------,c-n

,,,,e. -- ---------,--,---,-,,m-,-----n,----.,. -

CEORGIA POWER COMPANY 210

12. Annunciator Survey This survey will be supplemented by NUREG -0700 Section 6.3.

13. Communications Survey This survey will be replaced by NUREG - 0700 Section 6.2.

14. Abbreviations and Acronyms Survey No negative NRC comments

15. Color Coding Survey No NRC comments

16. Control Room Computer Survey This survey and the computer checklist will be replaced by NUREG -

0700 6.7, process computers.

CEORGIA POWER COMPANY 215 IV. Appendix B-H Items not included in the NUTAC surveys, listed in Appendix 8-H of NUTAC 83-042 will be reviewed against the Vogtle design as an additional survey.

b) See Appendix 6.6 of this report.

c) See Appendix 6.6 of this report.

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GEORGIA POWED COMPANY 216 FINDING 2.5.2 a) Tho NRC Audit Team found that no auditable records or documented. guidelines are available which formally state the details of the HED assessment methodology and the evaluation criteria used by the GPC CRDR HED Assessment Team, b) The criteria, as written, in the CRDR Program Plan does not clearly describe the characteristics of HEDs intended to be placed in Category 4.

c) The NRC Audit Team was not preserited with information which would explain the much smaller proportion of significant HEDs identified at GPC compared to other plants. This observation, coupled with the results of the NRC Audit Team mini-audit, leads the staff to conclude that GPC should carefully reassess its identification and assessment criteria and results.

GEORGIA POtHQ COMPANY 217

RESPONSE

a) The consideration of each HED was documented in the CRDR Team Meeting Minutes Book. The use of a multidiscipline team to develop an engineering consensus is a valid approach and met the requirements of NUREG 0737. However, to address audit concerns, additional work was done in this area. See Section 4.4.4 and Appendix 6.3 and Appendix 6.5 of this report.

b) See Section 4.4.4. of this report.

c) There are five principal reasons for the comparatively low number of HEDs:

1) Many design changes occurred in 1979 and 1980 due to increased awareness of human engineering.

2) The survey conducted in 1981/1982 against NUREG 1580 guidelines identified and prompted the correction of other items.

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CEORGIA POWER COMPANY 218

3) When a survey guideline identified a general deviation in many instruments, a single HED was written listing the instruments vice writing a separate HED for each instrument.

4) NUTAC surveys usad prior to the NRC In Progress Audit did not contain numerous trivial items in the NUREG 0700 guidelines.

5) The survey effort was less than fifty percent complete at the time of the NRC In Progress Audit.

_ _ , . - . . . ,. , , - - - - - , -.. _ _ , _ ..-,y.. , - - , - -_ --. ,, .-..--.--- , .% w.-- - - --,r- - - - . - -

CEOftGIA POtfE';l COMPANY 219 FINDING 2.6.2 a) The NRC Audit Team through discussions with GPC determined that the CRDR Review Team subjectively and collectively considered many significant factors but the selection process was not formalized in writing.

b) The selection and specification of corrective actions and alternate corrective actions were stated by GPC to be performed and documented by the CRDR team. Changes were reviewed by operating personnel or built into the simulator before approval and implementation. The regular plant processes were used to handlo the implementation of corrective actions.

But, details of the above were not available in written form.

c) The method described for recording HEDs and following the process to completion of implementation is not complete and systematic.

GEORGIA POWER COMPANY 220 d) The system for coordinating and correlating changes with EOPs and operator training was not completely described.

e) The approach used to explore the interaction of HEDs and the proposed corrective . actions with other HEDs was not described or discussed.

f) GPC stated that HED categories are used to determine implementation priorities and schedules, but systematic details of how this is accomplished were not identified.

RESPONSE

a) See Section 4.4.4, and Appendix 6.5 of this report.

b) See Appendix 6.3 of this report, c) The status of all HED, will be tracked using the computerized HED data base. See Appendix 6.3 of this report. Monthly reports on implementation status are provided to management.

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

CEORGIA POWER COMPANY 221 d) See Appendix 6.3 of this report.

e) See Section 5.0 of this report.

f) See Section 4.4 of this report.

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r GEORGIA POWE2 COMPANY 222 l

FINDING 2.7.2 l

l The NRC Audit Team confirmed that a formal and auditable description of the verification process to provide feedback that corrections to HEDs do not introduce new HEDs has not been writtan.

RESPONSE

See Section 5.0 of this report.

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GEORGIA POWE2 COMPANY 223 FINDING 2.8.2 The CRDR Plan did not include specific descriptions of a comprehensive system whereby the Team Leader is formally consulted and/or advised by others concerning matters which should be coordinated (e.g.

training, interfaces, simulator, procedures, SPDS).

RESPONSE

The coordination of thwse activities is achieved by the personal involvement of the CRDR Team Leader. A control room computer task force, chaired by the CRDR Team Leader, was established by plant management to review, advise, and coordinate all control room computer interfaces, including the SPDS. The team leader and another team member participated in six weeks of Emergency Operating Procedures validation, plus follow-up work on resolution of procedure discrepancies. This work is detailed in Sections l 4.3.5 and 4.3.7 of this report and the VEGP report to the NRC on EOP development. All engineering changes involving the control room operator interface were

reviewed by the CRDR Team Leader to maintain l

consistent human factors conventions.

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r GEORGIA POWEO COMPANY 224 Training in pu ts from the CRDR were transmitted to the Training Superintendent via official project correspondence and implementation will be verified by review of resulting training programs / materials in accordance with the Implementation Verification Plan.

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GEORGIA POWE2 COMPANY 223 APPENDIX 8.5 CROR RESOLUTIONS OF CATEGORY REVIEW The resolution of differences between original categorization and this review focuses on planned actions for correction. It is not the intent to change categories simply to match the review algorithm. Since the objective of the CRDR is the correction of significant HEDs, this focus on planned actions is appropriate. The changing of category numbers would simply introduce a clerical drill to revise previous paperwork and not contribute to control room improvement. For those HEDs with an original categorization more conservative than that reached by the this review, no action will be taken regarding the category. Resolution of the HEDs in the original but more conservation category will provide resolution for this review.

For those HEDs with nn original categorization less conservative than that reached by this review, resolution will be provided by three methods:

GEORGIA POWER COMPANY 226 A. Implementation is already planned prior to fuel load for the below listed HEDs. No action will be taken with regard to a change in the original category.

Many category 3 items fall into this class. It was the intent of our Category 3 to correct the problem rather that spend time researching potential impacts.

Implementation of correction action under the original category will provide resolution for this review.

8. No action is planned in category da for the below listed HEDs. The Justification fcr the 'No Action' recommendation provided in Appendix 7.3 will provide resolution for this review.

C. Implement resolution before fuel load. HEDs 1142, 1181 and 1268 fall into this category.

Corrective action had been recommended for all these prior to Category Review, and will be completed before fuel load.

CEORGIA POWER COMPANY 227 I

NOTE 1 Modify the EOP LOCA procedure to specifically start hydrogen analysis. Additionally, the ERF computer display will be modified to show purple (bad data) when this or any reading is out of range low or high to alert the operator that this data may not be valid.

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GEORGIA pot 0E'] COMPANY 228 IRNIAN ENGIKERING OISCREPANCY REVIEN CROR TEAll RESPONSE HED ORIGIN IDDTIFIED ITEN 1 ITEN 2 ITEN 3 ITEN 4 ITEN 5 ITEN 6 ITEN T RESULTMT CR0R REC 0pulENDATION IRJNSER DESCREPAllCY CATEGORY CATEGORY

______ m__, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___

9 1142 TA 1A FRC.1 H2 MALYZER IS NORMALLY .F. .T. .T. .T. .T. .F. .F. 01 02 'C' NOTE 1 STEP 8/FRZ.1 IN STMD8Y MD IN0! CATES STP T ZERO ON IIETER3, RECOR K R, P9IS, SPOS. NO INDICATION THAT IT IS ISOLATED NEAR ETERS 1124 TA ESO.2 STEP C00LD0leiREQUIRES .F. .T. .T. .T. .T. .F. .F. 01 03 'A' 13 TA C00R0lNAT10N OF SUIC00LillG A110 PRESSURE TEIFERATURE LINITS.

1131 TA 23A. E-0 110 RED PATH. LOGIC .F. .T. .T. .T. .T. .F. .F. 01 03 'A' l FR-H-1 STEP 2 UPGRADE NEEKO. CURRENT IID0EL ON FLON OR DELTA-P 00ES NOT FLAG VALVES OUT OF LINE. USE FLON > 550 TO SET FLAG NEFORE RELYlil6 ON KLTA-P t AVAILA8LE. THIS N!LL OIECK II0IIIAL VLV L/0 AT IEGIIIlllIG 0F ScalARIO.

l 1136 TA 3A 19221 STARTUP REFERS 70 .F. .T. .T. .T. .T. .F. .F. 01 03 'A' i STEP 8 (FilC.1) PROCEDURE. LONG. ENGRAVE

! S/U Filopl STMorf GN LOCAL PLATE. COINION IIDDE ALAINI ON H. NONITOR - letAT DOES IT IEAll?

1149 TA 2TA STEP $ 8LUE PEN ON BACK OF .F. .T. .T. .T. .T. .F. .F. 01 03 'A' fhC.I iiG; : !$ lirilS!8LE.

PUT KD PD Ill 8ACK, EUE IN FRONT. 20 illST00K i WI K RANGE FOR UPPER HEAD l SCALES. CONSIKR llANE C a sE.

l 1154 TA SCDIARIO 25A AUXILIARY LEAR KTECTI0li .F. .T. .T. .T. .T. .F. .F. 01 03 'A' TST E0 STEP 29 SYSTEN DOES Il0T HAVE LOCATIONS FOR OtAINIELS LASELED. ' LEVEL D* A110

' AUX ILO6*.

l GEOftGIA POWED COMPANY 229 MflAN ENGIEERIIIG OISCREPANCY REVIEW Ca0R TEAll RESPWSE  ;

NED ORIGIN 100TIFIED ITCt 1 ITEM 2 ITEN 3 ITEN 4 ITEM S ITER 6 ITEM i RESULTMT CROR RECOIIIENDATION IRAWER DESCREPANCY CATEGORY CATEGORY

_ _ _ . ,.-____ ._ = --. - _.

____ u-1155 TA SC8 TAR 10 25A VALVE NUMBERS ARE .F. .T. .T. .T. .T. .F. .F. 01 03 'A' TEST CONFUSill6 MD ERROR PRONE GI TAILPIPE TDP, IRN.TIPOINT RECORDER.

1156 TA SCDARIO 25A FULL, DYNMIC, 20 UPPER .F. .T. .T. .T. .T. .F. .F. 01 03 'A' TST FPC.1 STPS SCALE LEVELS ARE CONFUSING. SUPPLBENT RECORDER LASEL NITH RX VESSEL DIAGRAN. CGISIDER I BASE REFERDICE FOR FULL

& UPPER SCALE. THIS IS ALSO A TRAINING 1T81.

POST NOWIALS FOR (4RCP.

11ST TA SCSIAA0 25A TiiE 480V DIST BREMERS TO .F. .T. .T. .T. .T. .F. .F. 01 03 'A' TS E,0,STP 11N10 K OPENED ON M ATVT NEED TO E HIGtLielTED.

1164 TA SCDIARIO 11A ECCS LINEUP IS O!FFICULT .F. .T. .T. .T. .T. .F. .F. 01 93 'A' E31.3 STEP 3 TO FOLLON IN PROCEDURES.

1165 TA SCSARIO 11A VALVES NITH LOCl0UTS Call .F. .T. .T. .T. .T. .F. .F. 01 83 'A' E-1 STEP IT NOT E READILY IDolTIFIED.

116T TA SCDARIO 21A HOT LEG SUCil0N VALVES .F. .T. .T. .T. .T. .F. .F. 01 03 'A' ESO.2 STEP 18 (IT01A & 8] MD (8T02A &

B)AREMISLEADINGLY LASELED. REVISE LASEL.

1975 P900LDI REPORT REACTOR TRIP SNITCHES .T. .F. .F. .F. .F. .F. .F. 02 01 CROR NORE 20 TRIP TO LEFT & RESET TO CONSERVATIVE RI9ti. THIS VIOLATES A POPULATIONAL STERE 0 TYPE TO 'RAICTI(Bl* TO R19fi THE 'R41Cil0N' IEllI6 REACTOR TRIP. CURReli DESIGil TREATS THIS AS 8tEMER CIlLY, NOT A RAICTION. ERRORS IN ACTUATION NOTED IN

$11RlLATOR

l GEORGIA POtfE3 COMPANY 230 IRINAN ENGINEERIIIG DISCREPANCY REVIEN CRDR TEAN RESPONSE HED ORIGIN IDOTIFIED ITEM 1 ITEN 2 ITEN 3 ITEN 4 ITEM 5 ITEN 6 ITEN T RESULTANT CRDR REcomENDai!0h NUISER DESCREPANCY CATEGORY CATEGORY

, - -. w m -----, ---- , ---- , w m -..--. ----- -

1976 PR00LEN REPORT ARRANGEMENT OF TILES ON .T. .F. .F. .F. .F. .F. .F. 02 01 CROR NORE 9 GROUP NON! TOR LIGHTS IS CONSERVATIVE NOT CONSISTENT WITH FUNCTIONAL GROUPS lei!CH mlST BE VERIFIED 111 E0P'S (IE:$1, CIA,CVI).

1153 TA 08SERVATION CONTROL ROD SNITCH HANGS .F. .T. .T. .F. .F. .T. .F. 03 01 CROR NORE UP IN THE NITHDRAW CONSERVAT!YE POSITI(31.

1181 PR-17 BORIC ACIO AND Rlul VALVES .F. .F. .F. .F. .F. .T. .F. 03 02 'C' ARE NOT CONSISTENT WITH FIC'S RI ET, LEFT.

SUGGESTIONTOSNAP[HS 110A,111A)ANO(1108, 1118]& RELA 8ELHS1118

• EfMBER QUTLET TO VCT' HS 1100 'IL810ER OUTLET TO CHARGING PUIFS'.

1268 COMPUTER SURVEY GRAPHIC CODES ARE 180T .F. .F. .F. .F. .F. .T. .F. 03 04 'C' N.R. 0700 USED CONSISTENTLY, VALVE 6.7.2.7.h OUTLINE FOR NON-INSTRillENTED VALVES DOES NOT IEAN THE VALVE IS 0 41.

1005 1982 THE CCW Pt.MP SWITCHES ON .F. .F. .F. .F. .F. .T. .F. 03 4A '8' PRELIMINARY PAllEL 1A1 ARE LA8ELED:

CRDR (NED 205) PUIFS:(1,3,5) [2,4,5) &

TRAIN:(A,A,A)(8,8,8) 1006 1982 THE IISCW PUNP SWITCHES .F. .F. .F. .F. .F. .T. .F. 03 4A '8' PREllN! NARY ARE LA8ELED, LEFT TO CRDR (NED 207) RIET: PL5F (1,3,5,7]

(2,4,6,8)& TRAlli (A,A,A,l] [B,B,B,A]

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CEOftGI A POWEQ COMP,dlY 231 IRNMN ENGINEERING DISCREPANCY REVIEN CROR TEAN RESPGISE HED ORIGIN IDENTIFIED ITEN 1 ITER 2 ITER 3 ITEN 4 ITEM S ITEM 6 ITER 7 RESULTANT CRDR REC 0lNODATION ENIBER DESCREPANCY CATEGORY CATEGORY

_ .__ --- u - --- . u ----- ,= w a = u u n u = = a w = u = = ,----- u --- __ -------

1808 1982 THE IISCW VALVE SWITCHES .F. .F. .F. .F. .F. .T. .F. 03 4A '8' PRELIMINARY FOR THE CONTAl uENT CROR (NED 209) COOLER VALVES ARE LABELED: [1 & 2 TM A)

[5 & 6 T M A)

, [3 & 4 T M 8)

[7 & 8 TM B).

1035 1982 THE COLOR C001116 SYSTEM .F. .F. .F. .F. .F. .T. .F. 03 4A '8*

PRELINIIIARY IS 180T CONSISTENT ACROSS CROR (NED 259) ALL THE 80AR05. FOR E74fpLE,QIICSISCOLOR C00ED SY SYSTEll, WT THE DIESEL GalERATORS ON THE QEA8ARECOLORCODEDSY TRAIN.

C1 LM0 5 CHECKLIST Sone LA8ELS ARE 1807 .F. .F. .F. .F. .F. .T. .F. 03 4A 'O' US-1 NITNIN THE LINITS FOR STROKENIOTH/ CHAR. HEIGHT RATIO & OIAR. NIDTM/OtAR HEIGHT RATIO.

i 1002 LII0 CHECKLIST lli SONE CASES THE HEIGHT .F. .F. .F. .F. .F. .T. .F. 03 4A '8' LND-2 0F THE DIARACTERS AllE NOT NITHlu THE NINilul HEllBIT.

1090 00-22 LA8tLS ARE WHITE ON DARK .F. .F. .F. .F. .F. .T. .F. 03 4A '8*

a m m m0 IN llANY CASES, NOT DARK ON leIITE AS RECOIIBOED.

1994 GENERAL PAllEL THEFOLLONINGINDICATORS .F. .F. .F. .F. .F. .T. .F. 03 4A '8' CHECKLIST (G-1) USE 110114N IRIMERALS IN LA8EL DESCRIPTION OF lETER: (4)PRZR Pamuer (12)RCPFLON (16)S/S '

LEVEL (12)S/G PRE 3SURE (4)CONTAllNENT PRESWRE

GEORGIA PotfE3 cot 4PANY 232 IRNIM EMIKEAIN IISCREPANCY REVIEW CADR TEAR RESPONSE

=

NED ORIG!ll 10EhilFIED ITEN 1 ITEN 2 ITDI 3 ITEM 4 ITEM 5 ITEN 6 ITEM 7 RESULTMT CADR REC 0mENDATION IRNGER 00CREPANCY CATEGORY CATEGORY u ---_.,uzu - mu..-_,.,---..__----.-

1999 GENERAL PMEL N0 LEG 010 EXIST FOR .F. .F. .F. .F. .F. .T. .F. 03 4A '8' OIECKLIST IIEANIIIG OF AMBER TRIP LIGITS 1103 GENEAAL PAllEL SLUE LIGHT ON RCP LIFT .F. .F. .F. .F. .F. .T. .F. 03 4A 'O' CHECKLIST CIL PUlr DOES NOT HAVE A (G-12) LEGEN0 DESCRI8ING 8LUE LI91T FUNCil0N 1110 GDERAL PMEL MANYQuCBINDICATORSHAVE.F. .F. .F. .F. .F. .T. .F. 03 4A 'O' CHECXLIST GREATER thall 9 (6-28) GRACUAil0NS SETWEEN NUN 8ERED NARKINGS.

1139 TA 8A MAIN STEM VALVES FOR .F. .T. .F. .F. .F. .T. .F. 03 4A '8' TUR81NE DRIVEN AFW Pir C ARE ON 15.8 TRAIN A & 8, E 8 1, 2 POSS18LE CONFUSION, NOT IIOTED IN E0P VALIDA110N 1146 TA E0 STEP 19 REQUIRES .F. .T. .T. .f. .F. .T. .F. 03 4A 'O' TEIFEAATURCS 70 SE VERIFIED AT 557 F lETER INCASENTS ARE 18 F 1159 TA 17A TEST ES ORIFICE FLOWS ARE REDUCED .F. .T. f. .F. .F. .T. .F. 03 4A '8' 1.1 STEP 13 AT LON PRESSURE, 00110f NAME 111 GMI 1203 GD PMEL INDICATORS HAVE 24 .F. .F. .F. .F. .F. .T. .F. 03 4A 'O' CELST QPCP O! VISIONS KTNEEN G-28 NUNEAALS [All-276238 A110 PISL-9699]

1204 GEN PMEL ' PUSH TO TEST' PUSH .F. .F. .F. .F. .F. .T. .F. 03 4A '8' CRLST, QPCP 8UTTONS ON STATUS LISMT G-40 80AR06AR0l'T18tigUE.

GEORGIA POtfE3 C000PA81Y 233 leflAN S GINEERING OISCREPANCY REYlEN CN R TEAN RESPONSE MED ORIGIN IDDITIFIED ITEN 1 ITEM 2 ITEM 3 ITEN 4 ITEN 5 ITDI E ITEN 7 RESULTANT CR0R REcomENDATION lANWER DUCREPANCY CATEGORY CATEGORY

_ _ . _ . -. ., um _

, um= ____ __ m.m, __ _ _ __ umm , -

____m, .

1220 NUREG 0700 ANNUNCIATOR CONTROL .F. F. .F. .F. .F. .T. .F. 03 4A '8' (6.3.4.2.) BUTTONS ARE 110T SHAPE OR COLOR CODEO. ALL ARE 1811TE NITH EACK FUNCTION LABELS.

1230 NUREG 0700 SONE AllNUNCIATORS ARE .F. .F. .F. .F. .F. .T. .F. 03 4A '8' (6.3.3.5.) EN6 RAVED WITH IIICONS!$ TENT LETTER SIZES. THl3 !$ AN ON-SITE K:(AL884)FAIRICATION Pn0eLEN.

1240 COMPUTER SURYEY THE PROTEUS OPERATING .F. .F. .F. .F. .F. .T. .F. 03 4A '8' N.R. 0700 PROCEDURE 13544-1 REY.0 6.7.1.8. DOES IlOT DESCRISE THE OVERALL COMPUTER SYSTEll, AND THE CCWUTER SYSTEli CC W GNENTS WITH 101101 THE OPutATOR Call INTERFACE.

1243 COMPUTER SURVEY ERROR CORRECT!all Gul0AllCE .F. .F. .F. .F. .F. .T. .F. 03 4A '8' N.R. 0700 UtAOR i n e 00 IIOT 6.7.2.6. CONTAIN lilSTRICTIONS TO THC OPERATOR M4ARDING THEREQUlKOCORRECilm.

1244 COMPUTER SURVEY SYSTEN STATUS FEEDSACK, .F. .F. .F. .F. .F. .T. .F. 03 4A '8' N.R. 0104 THE PROTEUS 000 NOT 6.7.2.6. PROVIDE FEE 00ACK TO THE OPERATOR AS TO C0W UTER SYSTDISTATUS(fe..AAI, STOP,FAILEO,ONLINE).

1282 COMPUTER SURVEY THE PROTEUS COMPUTER DOCS F. .F. .F. .F. .F. .T. .F. 03 4A 'O' N.R. 0700 NOTREQUIREOPERATOR i 6.7.1.1.d ACl010NLE00NDT(fe..ARE YOU SUE) KFORE Ally OPERATORREQUESTSAAE PROCESSED THAT NOULO KSULillIG A PERMANENT CHANGE TO DISTING DATA i

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GEORGIA POtfE'] COMPA88Y 233 MNW1 ENGINEpilIG OISCREPANCY REVIEN C80R TEAR RESPONSE MED ORIGIN 100lTIFIED ITEN 1 ITEM 2 ITEN 3 ITEN 4 ITEN 5 ITEM 6 ITEM i RESULTANT CROR RECOMENDA* ION IRAWER 00CREPAllCY CATEGORY CATEGORY

.____ _ .. ____ ,_____ ,_ ___ _ _ _ ______ ______ __ _ , m _a ,_ __,

1271 8 & N SURVEY NAllY CONTROL ROON .F. .F. .F. .F. .F. .T. .F. 03 4A '8' N.R. 0700 INDICATORS HAVE A 6.5.1.5.b GRADUATION Helm i LESS THAN REC 0 MENDED FOR THE 3 FT VIENIIIG O! STANCE.

1292 ANNUNCIATOR THE ANNUNCIATOR PANEL .F. .F. .F. .F. .F. .T. .F. 03 4A 'd*

SURVEY N.R. IDENTIFICATION LA8EL 0700 HElmi(LETTER $1ZE)IS 6.3.3.1.b(2) LESS thall THE REcomENDED HEleT, IF VIEMED FRoll A CGTRALPOSITI(IlMITHIN THE PRilWlY OP DATIIIG AREA.(815.5FT. LETTER SIZE SHOULO AT LEAST IE

.75')

12M GGERAL PAllEL THE SCALES ON THE .F. .F. .F. .F. .F. .T. .F. 03 4A '8' CHECEIST G-22 AUT(HIAllVAL STAil0NS WITH THE PLASNA DISPLAY ARE IIOT ILACE IIARKINGS IN A 10llTE 84CX600U110.

1343 GGERAL PAllEL THE FOLLONING IN0!CATORS .F. .F. .F. .F. .F. .T. .F. 03 4A '8' CHECRIST G-28 CONTAIN GitEATER thall THE IIAXIltNI 0F N!NE INTEJsIEDIAIE GRADUAI!0NS OETNEG NUIIIGED flARKINGS: 1F1-1348, 4068

& 4818.

CEORGIA POWER COMPANY 235 APPENDIX 6.6 NRC AUDIT SURVEY l

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GEORGIA POWE3 COMPANY 236 NRC AUDIT TEAM HEDs A001 Lettering size is inconsistent on annunciator tiles.

A002 There are no alph-numeric coding of annunciator tiles to prevent interchange of tiles if two or more are removed at the same time.

A003 Many annunciator tiles indicate more than one specific condition (i.e., HI/LO).

A004 Non glare coatirg on meter covers is not uniform and causes readability problems.

A005 There is not presently a location identification system for legend indicator lens to prevent interchanging when removed for bulb changes.

A006 There is a lack of hierarchical labeling on panels.

A007 Labels are not consistent in the use of white and black letters.

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GEORGIA POWE3 COMPANY 237 A008 There is some question whether the torque required to operate some J-handle switches for a period of time would result in operator discomfort.

A003 Inconsistent use of indicator arrows on T-handle switches.

A010 Some trend recorders are not operational and should be reviewed for human factors prior to placing in operation.

A0ll There appears to be excessive use of J-handle switches on control panels. This could lead to operator confusion under stress.

A012 Some meters appear to fail at zero rather-than off scale while others fail off-scale.

I A013 Scale size on controllers is too small to read from operating position.

A014 There is a general lack of color banding j or limit markings on meter scales, i

A015 There are many instances of several sets of switches with identical labels. (i.e.

nomenclature)

GEORGIA POWER COMPANY 238 A016 Some annunciator panels have more than 50 tiles.

A017 There are instances of meter strings with more than the recommended 5 meters in a row.

A018 Some switch label engravings are filling up with dirt. This will result in readability problems.

A019 There is a general lack of demarcation on display panels in the control room.

A020 There are many labels which are held in place by tape.

A021 There are two switches with tan faceplates in the middle of a grouping of system switches with green face plates. The tan switches are not system related.

CEORGIA POWER COMPANY 239 NRC AD0li TEAN HEDs COIFARED TO VEGP CRDR HEDs NRC VEGP ITEMSINVOLVED ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLL'TIGI HED HED A001 1003 AIEMICIATOR 1902 AleulCIATOR LETTER SIZE 03 lelEN REPLACING TILES WINDOWS PRELINillARY IS SMALL FOR 110lulAL FOR TEXT CHANGES USE CROR(NED VIEWING OISTAllCE. 1/4'LETTERSIF 103), US-2 INF0lulATION CONTST PERNITS. INF0m4TIGI CGITEllT WILL TE PRECE001CE OVER THE nil 10R DEVIATIGI IN

~ LITTER SIZE.

A001 1050 AINIUNCIATORS 1982 AlelullCIATOR LETTERIllG IS 03 SEE HED 1230. leiEN PRELIlllNARY TOO SMALL. REPLACING TILES FOR CROR(NED TEXT CHANGES USE 410) 1/4'LETTERSIF llIF01BIATION CONTBIT PaullTS. lHF0mLTIGI CONTEllT WILL TANE Percrn N r OVER THE NINOR DEVIATIGI IN LETTER SIZE.

A001 1230 AleUICIATOR LETTER NUREG OTOO SOME A181UllCIATORS ARE 4A NEWILLUSE1/4' SIZE lilCONSISTENT (6.3.3.5.) ElI6RAVEDWITH LETTERS 0111881 Il1 CONSISTENT LETTER A10MICIATOR TILES AS SIZES. THIS IS All ON-SITE NESSAGE LBIGTH RE:(AL804)FA8RICAT10ll PE M ITS TO IIFRCVE P900LBl. VISIBILITY.

A002 1224 AINMICIATORS NUREG OT00 LAleP REPLACENDIT REQUIRES 03 IIRITE UPPER LEFT (6.3.3.1.) THAT AlelullCIATOR TILES 8E C00R0!AATE ON OEZEL RBIOVED, THERE IS 110 TO AID IN IM WER OR IDDITIFIER ON REPLACBEllT.

THE TILE TO DISURE IT IS l

REPLACED IN THE CORRECT LOCATION.

A003 1211 CONTROL ROOM ANNUN. SURVEY ATTACHED LIST OF 03 WRITE ANilVNCIATOR AleUICIATORS (AltS-3) A10MICIATORS ARE RESPONSE PROCO URES (NUREGOT00 'lllLTIPLECHOICE' TO DETAIL INPUTS FOR 6.3.3.4.) AleMICIATORS. IRlLTIPLE CHOICE AIEMICIATORS.

PROVIDE CGITROL ROON Il101CATIONFORN!/LO ALJuelS TO ALLOW OIAGNOSIS.

CEORGIA POBfER COMPANY 24']

NGC AD0li TEAll HEDs CGFARED TO VEGP CROR NGs NBC VEGP ITERS INVOLVED ORIGill HED DESCRIPTICII CATEGORY PROPOSED RESOLUT!W HED HED A003 1281 A10MICIATORS ANNUNCIATOR REFLASH CAPASILITY SHOULD 94 INSTALL All AUDIEE REFLASH SURVEY N.R. OE PROVIDED FOR AND YlSUAL REFLASH 0T00 IRILTI-IllPUT A101UNCIATORS ON THE ERF COMPUTER 6.3.1.2.c(3) TO ALLON SUBSEQUENT FOR ALL RADIAT!W ALAIBIS TO ACTIVATE THE ALAIBIS.

AUDITORY ALERT lECHAlllSN AND REFLASH THE VISUAL TILE EVEN IF THE FIRST ALAlpi ilAY IIOT HAVE BEEN CLEARED. (EX. RMS, SUS T110UOLE ALAlBI5)

A004 1288 QNC8!NDICATOR OPERATOR SONE IIAIN CONTROL 80ARD 03 ItEPLACE Ill0!CATOR LOIS QUESTI0llAIRE IN0!CATOR LBIS NERE LalS/ WIN 00N WITH NEN 0080-12 & OAAAGED SY THE USE OF A IION41UUtE FAlti.

0028-26 CLEAll!NG S0LVali All0 ARE NON DIFFICULT TO ltEAD.

A005 1224 ANNUNCIATORS NUREG 0T00 LAlf REPLACDENT REQUIRES 03 IntITE UPPER LEFT (6.3.3.1.) THAT ANNUllCIATOR TILES BE C00R0!IIATE 011 SEZEL ltBIDVED THERE IS 110 TO AID IN IM 8ER OR IDalTIFIER CII ItEPLAC8ENT.

THE TILE TO ENSultE IT IS REPLACED 111 THE CORRECT LOCATIGl.

A006 1004 NA!N CollTROL 1982 A HIERAllCHICAL SYSTEM OF 03 UTILIIE A BOARDS PRELINillARY LA8ELill6 IIAS Il0T UTILIZED HEIRANDilCAL CRDR ON THE NAIN CONTil0L LASELING SYSTBI FOR (NED201), LJW BOARD. INSTRUIENT LA8ELS CK, 12, 2 lelERE 80 Alto LAYOUT (0T00 Pupl!TS. CollTROL 6.6.1.2. m m m ui WILL GalERALLY PREVBIT THIS APPROACH OUE TO LIMITED SPACE.

A006 1026 ACCUIRAATOR LEVEL 1982 ACCulIULATOR TANK LEVEL & 03 HIERARCHICAL RELABEL

& PRESSURE PRELill! NARY PRESSURE Ill0ICATORS ARE INDICATORS CR0lt (NED SEPERATED, Allo AltE NOT 245) AltRAlIGED IN THE FLON PATH INDICATED BY IEDITEL WIDEllllE 11.2.8

CEOftGIA pot $ER COMPANY 241 NE AUDIT TEAN HEDs COWARED TO VEGP CROR HEDs NNC YEGP ITERS INVOLVED ORIGIN HE0 DESCRIPTION CATEGORY PROPOSED RESOLUTIM HED HED A00T 1035 COLOR CODING 1982 THE COLOR CODING SYSTEN 4A THE EXISTING TRAIN PRELIMINARY IS NOT CONSISTENT ACROSS CODE ETCHES THE CRDR(NED ALL THE BOARDS. FOR ELECTRICAL TRAIN 259) EXANPLE,QRC8ISCOLOR COLOR CODES. THIS CODED 8Y SYSTER, BUT THE DISTINCT!0N IMPROVES DIESEL GENERATORS W THE TRAIN SEPERATI(NI IN QEA8 ARE COLOR C00E0 BY DIESEL OPERATION. NO TRAIN. ACTIONREQUIRED.

A00T 1090 NC8 LA8ELS - W ITE 0C-22 LA8ELS ARE WITE ON DARK 4A NO ACTION. lellTE ON LETTERS 8ACKGROUND IN MANY CASES, DARKOFFERSADEQUATE NOT DARK ON lellTE AS CONTRAST ANO LESS REC 0p.Ol0EO. POTENTIAL FOR DISTRACTION 10lICH A PATCH OF 10 LITE, CATCHING THE EYE, COULO CAUSE.

A008 THE N00EL 20K WITQlES FNW ELECTRO-WITCH WERE TESTED (Ni All ANTEX TORSINAL TESTING MACHINE CURING THE 1981/82 PRELIMINARY Cmt, ALL CONTROLS lERE SATISFACTORY EXCEPT THE REUeLED l

200 TYPE. THE 208 TYPE HANOLS ARE TC IE ELIMINATED.

A009 1273 QRC8 CONTROL 8 & H SURVEY SOME ROTARY SELECTOR 03 REPLACE WITH PolNTER WITCHES N.R. 0700 SITCHES ARE NOT PROV10F0 T 21T01 HANDLE TO 6.4.4.5.d.(1) WITH THE REcolNIEll0E0 MTCH GUIDELIllE.

POSITI0liINDICATION-(OP THIS ALSO CORRECTS DELTAT),[0ELTAT& HED - 1275.

TAV6]OEFEATSELECTORSil (TS411E&FANDTS 4127).

CEORGIA POWER COMPANY 242 IIRC AUDIT TEAN HEDs COWARED TO VEGP CRDR HEDs NRC YEGP ITENS INVOLVED ORIGIN HED DESCRIPTION CATEGORY PROPOSED RESOLUT!(Il NED HED A010 THE CONTROL ROM RECORDERS NERE REVIEMED IN SURVEYS, TASK MALYSIS AND THE ICCR.

A011 1051 CONTROL HMDLES 1982 CONTROL HANDLES ARE NOT 03 CODE VALVES, DANPERS PRELIMINARY SHAPE CODED. -

'T' PUNS, CRDR(NED FANS, BREMERS -

411) 'J'.

A011 1143 Ptw SWITCHES, Allo TA, HED 1051 PURP SWITCHES MD 03 USE DOUBLE HIGt, CRITICAL CONTROLS SilllLAR CRITICAL CONTROLS ARE BOLD LETTERS FOR SOETIES DIFFICULT TO PUWS IN ESFAS LOCATE IN ARRAYS OF SYSTERS (SIP, IBR, VALVES. HANDLE SHAPES 00 CCP,SLI,CS)

NOT STAllo OUT.

A012 1142 HYDROGEN NONITOR TA 1A FRC.1 H2 AllALIZER IS NORNALLY 02 ADO INOP STATUS STEP 8/FRZ.1 IN ST2 08Y AND INDICATES LIGIT AT 1A1 OR STP 7 ZERO ON ETERS, RECORDER, DRIVE ETERS OFF PSMS, SPOS. NO INDICATION SCALE LON. WEli THAT IT IS ISOLATED llEAR DETECTOR IS OFF OR ETERS STAN08Y.

A012 12T2 QEA8 - AC VOLT 8 & H SURVEY THE AC VOLTNETERS ON QEA8 4A N0 ACTI(31 - THESE NETERS N.R. 0700 00 NOT READ OFF - SCALE ETERS Call BE 6.9.1.2.c.(4)LONlelENNOTSELECTED. ALINED TO A NUMER OF SOURCES. THE OPERATOR NILL (IN.Y E USIIIS THIS ETER Ill CONARICTIGl MITH ,

SELECTill6 A PARTICULAR SOURCE.

TE Il0NIAL ZERO READING HAS 110 OPEMTI(IIAL SIBIFICAR2.

A013 THE DOIAND SIGilAL DISPLAYS Gl THE -

HAGM CGITil0LLERS ARE USCD BY THE CPERATOR TO DETERI E RELATIVE CGITROLLER OUTPUT All0 IIOT QUAllTITATIVE SYSTER PERFORRANCE.

1

CEORGIA POWER COMPANY 243 NNC AUDIT TEAll HEDs CarARED TO VEGP CRDR HEDs NRC VEGP ITEMS INVOLVED ORI61ll NED DESCRIPTION CATEGORY PROPOSED RESOLUTIS HED HED

__= = - - =- - -------------- ....

A014 1848 NETERS 1982 COLOR C001116 HAS NOT BES 03 A00 GRES BAND TO PRELIMINARY UTILIZED TO DEFINE Il0RNAL E TER FACE. W FUEL CROR(NED LIMITS FOR OPERATIONAL LOAD. N00lFY RANGES 406) PARAIETERS. W FIRST REFUELIIIG.

A015 1135 CONTAllNIENT SPRAY TA 25A GA CONTAINNENT SPRAY 03 REVISE HS LA8ELS SUCTION VALVES ECA1.1 STEP G SUCTIONS FRON SL W ARE FROMRNST/SUW NOTADEQUATELYLABELED.

A815 1299 CHVC LABELS GENERAL PMEL THE ATTACHED LIST OF 03 REVIEN 20 N00!FY SURVEY G-7 LA8ELS ARE NOT AC G RATE LAKLS.

(QHYC) NITH RESPECT TO ITS FWCTION OR IllPUT SIMAL, OR A88REVIATI(NI AllD AC20NYN LIST.

A015 1300 QPCPLABELS CGERAL PMEL THE ATTACHED LIST OF 03 REVIEN A110 N00!FY SUkaY G-7 LA8ELS ARE NOT ACCURATE LAELS.

(QPCP) NITH RESPECT TO ITS RNICTION OR IllPUT SIMAL Gl A88REVIAT!0ll AllD ACRONYIILIST.

A015 1301 QNC8 LABELS GGERAL PAllEL THE ATTACHED LIST OF 03 REVIEN Allo N00lFY OIECKLIST G-7 LA8ELS ARE Il0T ACGRATE LAELS.

QNC8 NITH RESPECT TO ITS FINICTION OR IllPUT SIMAL OR A88REVIATICII AllD Aca0llYM LIST.

A016 THIS ITEll llAS Il0TED IN THE 0700 SURVEY, WT IT IS PRESBITED AS A SUGESTICII lei!CH IS IET W THE IIAIN C/8. OTHER PAllE15 IIAVE >54 TILIS NT OPERATOR ERNORS OR nrwwn NORELGAD IS NOT EXPECTED.

CEORGIA POtfER COMPANY 204 IIRC AUDIT TEAll HEDs Ct3 FARED TO VEGP CROR HEDs NRC YEGP ITERS INVOLVED GRIGIN HED DESCRIPTION CATEBORY PROPOSED RESOLUTIGI HED HED A017 THE HIERARCHICAL LA8ELI N BEING UTILIZED ON THE IIAIN CGITROL BOARD NILL IIFROVE THE OPERATORS ABILITY TO LOCATE INSTR 8ENTS.

A018 1279 EQUIPNENTLABELS LABELING, THE CURRST REV-10F THE 03 REVISE PROCEDURE NINICS,& PUWT HOUSEXEEPil16 Allo 00254-C TO INCLUDE DOIARCATION CLLAlelESS CONTROL CLEANIll6 LA8ELS N.R. 0700 PROCEDURE DOES NOT E.5.2.4.d ADDRESS THE CLEAN!!I6 0F LAELS.

A019 1004 NAlli CONTROL 1982 A HIERARCHICAL SYSTEN OF 03 UTILIZE A BOARDS PRELIMINARY LABELIll6 NAS NOT UTILIZE 0 HEIRARCHICAL CROR ON THE MAIN CollTROL LAELING SYSTEN FOR (HE0201), LND ODARD. IllSTREENT LA8ELS CE,12, 2 10iERE BOARD LAYOUT (0700 PEINIITS. CONTROL 6.6.1.2. ARRANGBENT NILL GENERALLY PREV 8IT THIS APP 90ADI MIE TO LIMITED SPACE.

A020 THIS HAS A TEIFORARY CGISTRICTI(El CINDITION. ALL LA ELS NILL E POBIANEllTLY ATTADIED PRIOR TD ftEL LOAD.

A021 THE TM0 Tall ESCUTOEDil PLATES ARE TO E REPLACED AS THE CONTROL ROGI LAELS ARE REVIEIED Allo IWOIFIED. SEE HED 1301

l CEORGIA POWER COMPANY 245 APPENDIX 6.7 QUALIFICATIONS OF CRDR PERSONNEL

)

RESUME NAME: Edward J.(Ed) Kozinsky DATE OF BIRTH: August 28, 1946 DATE EMPLOYED: January 23, 1984 TITLE: Operations Supervisor EDUCATION: Bachelor of Science (Chemistry)

Baylor University,1968 LICENSE / CERTIFICATIONS: Engineer Officer, Naval Reactors ERDA,1975 SRO Instructor, NRC, June 1985 WORK EXPERIENCE:

SUMMARY

4 years Navy Nuclear Power School Instructor 4 years Navy Nuclear Power Plant Operations 6 years Nuclear Power Plant Operations Research 6 weeks participation at a PWR (Sequoyah) 2/84 & 5/85 NUCLEAR (CPC) Position: Operations Supervisor Dates: January 23, 1984 - Present Location: Plant Vogtle, Burke Co., GA Plant Status: Under Construction & Startup Job

Description:

Responsible for safe and efficient operation of the plant during initial test program and commercial operation.

Direct review of control room design, equipment labeling, consumables procurement, and Radwaste Program Plan Safety Parameter Display System (SPDS)and Control Room Computer applications.

NUCLEAR -

OTHER Position: Senior / Principle Engineer Dates: February 28, 1978 - January 22,1984 Location: Ceneral Physics Corporation Chattanooga, TN Job

Description:

Conducted research programs dealing with nuclear power plant control room design, operator performance and reliability, and computer based operator aids. Work with Electric Power Research Institute (EPRI) produced a Performance Measurement System for Nuclear Power Plant Simulators. Department of Energy work defined a Disturbance Analysis and Surveillance System (DASS) for nuclear power plant use.

RESUME Edward J. (Ed) Kozinsky Page 2 NUCLEAR OTHER (CONT'D) Nuclear Regulatory Commission sponsored research included the Safety Related Operator Action (SROA) program at Oak Ridge National Laboratories and simulator studies on operator error rates for Sandia National Laboratories.

Position: Division Officer, U. S. Navy Dates: February 1974 - February 1978 Location: Atlantic SSBN645/SSN638 Job

Description:

Responsible for the safe operation and maintenance of naval nuclear power plant systems. Qualified as Engineering Officer of the Watch and Engineer Officer.

Position: Instructor, U. S. Navy Dates: May 1969 - August 1973 Location: Naval Nuclear Power School Bainbridge, MD Job

Description:

Develop lesson materials and exams and present a 12 week course of instruction on power plant chemistry, radiological fundamentals, and reactor materials to officer and enlisted students.

TRAINING l NUCLEAR Course

Title:

U. S. Navy Nuclear Power Program i

Dates: August 1973 - February 1974 Total Course Hrs.: 1280 Vendor: Nuclear Training Unit, Windsor Locks, CT

Description:

A program of classroom and on the job training on the SIC pressurized water reactor. Qualified as Engineering j

Officer of the Watch.

L l

RESUME Edwtrd J. (Ed) Kozinsky Page 3 NUCLEAR OTHER (CONT'D) Course

Title:

Engineer Officer School Dates: November 1975 Total Course Hrs.: 160 Vendor: U. S. Navy, Charleston, S.C.

Description:

A program of classroom and self study to prepare for the Engineer Officer examination (on the S5W naval nuclear power plant) Administered by the Naval Reactors branch of the Energy Research and Development Agency (ERDA).

Course

Title:

Hot License Training Dates: March - April 1978 Total Course Hrs.: 240 Vendor: General Physics Corporation

Description:

A program of classroom (120 hr.)

and simulator (120 hr.) training for hot license certification on the Sequoyah (Westinghouse-PWR) plant.

f TRAINING OTHER Course

Title:

University of Tennessee, Chattanooga 1979 Advanced Calculus 1980 Fluid Mechanics 1983 Statistics 1983 Marketing Management 1983 Operations Management Course

Title:

Substation Operation Dates: September 10-14, 1984 Total Course Hrs.: 40 Vendor: GPC - Division Operations

Description:

Covered design and operation of 230/500 kv switchyard.

Course

Title:

New Supervisors School Dates: August 13-17, 1984 Total Course Hrs.: 40 l Vendor: GPC-Training Department l 7

Description:

Provided company background, labor t

I 7 relations, communications skills.

(

?

l -! e l

RESUME Edwtrd J. (Ed) Kozinsky Page 4 TRAINING (OTHER)(CONT'D) Course

Title:

Technical Communications Dates: August 27-31, 1984 Total Course Hrs.: 40 Vendor: Nielson Associates

Description:

Provided instruction and exercise in written and spoken communications, leadership and teamwork.

Course

Title:

Quality Circle Leader Dates: April 15-18,1985

' Total Course Hrs.: 24 Vendor: GPC

Description:

Principals of Quality Circle Organizations. Problem solving Techniques.

Course

Title:

Oil Spill Response Dates: January 23-24, 1986 Total Course Hrs.: 16 hrs.

Vendor: OHM Corporation

Description:

Oil and hazardous materials spill response procedures and precautions.

l

RESUME NAME: Donald A. Crouch DATE OF BIRTH: March 17,1946 DATE EMPLOYED:

TITLE: Senior Engineer EDUCATION: 2 years - Penn State University, School of Engineering LICENSE / CERTIFICATIONS: Senior Reactor Operators License Beaver Valley Power Station (Docket No. 55-5619, License No. SOP-2768)

WORK EXPERIENCE:

SUMMARY

11 years Duquesne Light 11/2 years Louisiana Power and Light 2 years institute of Nuclear Power Operation 6 months J.V.S. Corp.

NUCLEAR Position: Senior Engineer J.V.C. Corp.

Dates: 1985 to Present Location: Vogtle Electric Generating Plant Georgia Power Company Waynesboro, GA Plant Status: Under construction & startup Job

Description:

Team member on the Readiness Review Project. Responsible for identifying Regulatory commitments related to Nuclear Operations Department Responsible for verifying that Nuclear Operations quality related programs have been developed and implemented in accordance with regulatory requirements

Position

Senior Protact Manager Dates: 1983 to 1985 Location: Institute of Nuclear Power Operations Atlanta, CA Plant Status:

Job

Description:

Responsible for the management i of projects related to Human Performance in the areas of: Human Error, Presentatio of Technical Information, Procedures (Operations & Maintenance).

Responsible for the development of Human Performance Guidance documents that provide assistance to nuclear utilities in the area of plant procedure improvements.

Provided assistance and monitored the verification of Emergency Operating Procedures.

Rcsums Don:Id A. Crouch Page 2 NUCLEAR (CONT'D) Reviewed plant operating and maintenancc procedures (prior to INPO evaluations) for potential Human Performance problems.

Provided assistance and participated in INPO plant evaluations in the operations area.

Reviewed Industry Event Reports for applicability to the Human Performana Department.

Monitored Owners Group activities in the area of Emergency Operating Procedures Development.

Participated in specialized training in the areas of Management Oversite and Risk Tree Analysis, and Accident Investigation.

Position: Nuclear Operations Supervisor Dates: 1981 to 1983 Location: Waterford 3 S.E.S.,

Louisiana Power and Light Company Plant Status:

Job

Description:

Directed activities of the Operations Department during plant start-up testing.

Responsible for the preparation and review of operating and administrativ@

procedures and programs.

Appointed acting Operations Superintendea during his absence.

Completed NRC Cold License Training.

Participated in Control Room Design Review.

Responsible for coordination of startup and Operations Department activities.

Representative: Louisiana Power and Light Company - Combustion Engineering Owner's Group Meetings, for preparation and implementation of emergency procedures.

Rcsume Donald A. Crouch Page 3 NUCLEAR (CONT'D) Alternate: Plant Operations Review Committee, Waterford 3 S.E.S.

Position: Nuclear Shift Supervisor Dates: 1978 to 1981 Location: Beaver Valley Power Station Duquesne Light Company Pittsburgh, PA Plant Status:

Job

Description:

Responsibilities of senior staff personnel on shift: Directing licensed activities of licensed and non-licensed operations during plant start-up, routine operations, plant shutdown, and emergency operations.

Directing plant security.

Coordinating activities of maintenance and construction personnel.

Directing radiation control functions.

Training nuclear operators and nuclear control operators.

Preparing and implementing of operations procedures.

Supervising and documenting, for operations group, design changes and modifications.

Monitoring Chemistry Department functions.

Refueling Shift Supervisor: Directing the activities of licensed and non-licensed personnel during refueling.

Representative: Duquesne Light Company, Westinghouse Owner's Group meetings, for preparation and implementation of emergency procedures.

Alternate: Onsite Safety Committee, Beaver Valley Power Station.

Rssume Donald A. Crouch Page 4 NUCLEAR (CONT'D) Position: Operating Foreman Dates: 1977 to 1978 Location: Beaver Valley Power Station Plant Status:

Job

Description:

Responsible for routine job and operating coordination of all activities on shift.

Responsible for reviewing station logs and operations surevillance tests.

Position: Nuclear Control Operator Dates: 1976 to 1977 Location: Beaver Valley Power Station Plant Status:

Job

Description:

Directly involved in plant power escalation program, all routine operations, surveillance testing, and clearance of equipment for maintenance.

Position: Nuclear Operator Dates: 1974 to 1976 Location: Beaver Valley Power Station Plant Status:

Job

Description:

Responsible for preparation of NRC licensing, plant auxiliary operations.

Licensed with NRC as Senior Reactor Operator: July 1,1976 (Docket No. 55-5619, License No. SOP-2768).

UTILITY (OTHER) Position: Automatic Controlman Dates: 1970 to 1974 Location: Sub-Stations and Shops Department Duquesne Light Company-Pittsburgh, PA Plant Status:

l Job

Description:

Responsible for testing, maintenance, I and cut-in of protective three-phase i

relaying devices.

l Position: Machinist Mate l Dates: 1965 to 1969 Location: United States Navy

, Plant Status: N/A l Job.

Description:

Directly involved in operations and i

maintenance of main propulsion turbines and boilers.

1 I

4

RGsume Donald A. Crouch Page5 Position: Draftsman Apprentice Dates: 1964 to 1965 Location: Wean United Engineering Company Pittsburgh, PA Plant Status: N/A Job

Description:

1 i

i a

i i

i  ?

i I * .

I L

RESUME NAME: Paul M. Kochery DATE OF BIRTH: March 18,1945 DATE EMPLOYED: February 22,1977 TITLE: Plant Engineering Supervisor EDUCATION: BS (Electrical Engineering)

BS (Physics & Mathematics)

LICENSE / CERT.lFICATIONS: NRC SRO Certification Vogtle Simulator Feb.1985 WORK EXPERIENCE: PRB Member 1985 July -Now CRDR Team Member

SUMMARY

NUCLEAR (CPC) Position: Plant Engineering Supervisor Electrical and instrumentation Group in Plant Engineering Services Dates: July 1985 - Present Location: Plant Vogtle - Nuclear Operations Plant Status: Under Construction Job

Description:

Coordinate technical specifications, regulatory, licensing, and Coerations Assessment Program items assigned to Plant Engineering & Services.

Supervise and coordinate the preparation of surveillance procedures assigned to Plant Engineering & Services.

Coordinate and control protective relay, and breaker settings for all 480V and under, switch gear and MCC breakers.

Position: Plant Engineering Supervisor Dates: February 23,1983 to June 1985 Location: Plant Vogtle - Nuclear Operations Plant Status: Under Construction Job

Description:

Coordinate electrical DWC reviews design reviews, control room design reviews, Equipment Qualification Program, Plant Telecommunication system, MET Tower, EOF Communication

. Instrumentation and Control System Reviews, Scaling, Proteus Computer, Secondary Plant Performance and implementation of Reg.1-97 and Reg.0700.

Rcsume Paul M. Kochery Page 2 NUCLEAR (CPC) CONT'D Position: Sr. Plant Engineer Dates: March 20,1982 to February 22,1983 Location: Plant Vogtle - Nuclear Operations Plant Status: Under Construction Job

Description:

Group Leader - coordinate electrical DWG reviews, design reviews, control room design reviews, Equipment Qualification Program, Plant Tele-communication system and implementatio of Reg.1-97 and Reg 0700.

Position: Construction Engineer Dates: November 5,1979 to September 3,1979 Location: Plant Hatch - Temp. Assignment Plant Status: Operating Job

Description:

Supervisor - Problem Solving Night Shift: Pipe support modification to concur with NRC bulletin 79-04 and 79-014.

Position: Construction Engineer Instrumental and Control Dates: November 4,1979 to November S,1979 September 3,1979 to September 29, 1979 Location: Plant Vogtle - Construction Plant Status: Construction Job

Description:

Review specification, generate construction (instrumentation) dept.

procedure, review instrumentation

& awing, resolve any installation problems.

Position: Construction Engineer Instrumentation and Control Dates: February 22, 1977 to November 4,1978 i Location: Plant Hatch Plant Status: Construction, start-up and operation Job

Description:

Complete responsibility of installing all instrumentation and tubing at Plant Hatch, Unit 2. Also helped Mechanical Section in Hanger Surveillance and provided engineering support for insulation installation.

l

Resume Paul M. Kochery Page 3 NUCLEAR (OTHER) None NON-NUCLEAR (CPC) Position: Field Engineer - Piping, instrumentation and Control Dates: September 29,1979 to March 20, 1982 Location: Plant Scherer Plant Status: Construction, start-up and operation Job

Description:

Resolve piping and pipe support problem, material take off and requisitionic Coordinate activities of all the contractors in installing piping and instrumentation and piping support.

Evaluate the bids and specification, re-design control air system, coordinate start-up and outage work. Planning and scheduling of inst installation and cost evaluation of instrumentation installation contract.

NON-NUCLEAR Position: Instrumentation Engineer (OTHER) Dates: February 5,1975 to February 22,1977 Location: Plar.t Wansley Davis Electrical Contructors Plant Status: Construction, start-up and operation Job

Description:

Coordinate the activities for Plant Wansley, Unit #2 instrumentation installation. Solve all installation problems.

Position: Project Electrical Engineer Dates: January 5,1975 to February 5,1976 Location: Lone Star Cement Roanoke, VA Davis Electrical Plant Status: Construction - start-up l

Job

Description:

Provide supervision and coordination for the installation of the H-V switchyard.

All equipment and instrumentation and control prepared the lay out for stacker and reclaimers. Plan and schedule the outage activities, including manpower and material.

Rtsume Ptul M. Kochery Page 4 NON-NUCLEAR (OTHER)

CONT'D Position: QC and Test Engineer Dates: May 1,1974 to December 30, 1974 Location: Cutler Hammer Canada Toronto, Ontario, Canada Plant Status: Operating Job

Description:

Develop Test procedures and direct the QC personnel. Help customers QC programmer.

Position: Electrical Engineer Dates: May 1972 to May 1974 Location: Cape Fear, NC DuPont Fiber Plant Davis Electrical Constructors Plant Status: Construction, start-up and operation Job

Description:

Design lighting for General Plant.

Resolve installation problem. Schedule the shutdown work. Re-design the control circuit for cutting and bailing machine. Supervision of Drafting Section, Shop and Warehouse.

Position: Engineer Trainee Dates: September 2,1970 to September 5,1971 Location: State Electricity Board Kerala, India Job

Description:

Review specification, inspect the instaliction of 66 KV substation.

TRAINING Course

Title:

Operation Technology Training Total Course Hrs.: 16 wks Vendor: Georgia Power Company Course

Title:

AWS Certification Total Course Hrs.: 40 Vendor: Georgia Power Company Course

Title:

Visual Insp: .: ion - Level 2 i

Total Course Hrs.: 16 Vendor: Georgia Power Company Course

Title:

Liquid Pentrant Testing - Level 2 Total Course Hrs.: 32 Vendor: Georgia Power Company t

Course

Title:

Magnetic Particle Testing Total Course Hrs.: 16 Vendor: Georgia Power Company Course

Title:

Inst. and Control Inspection Total Course Hrs.:

Vendor: Georgia Ppwer Company i

Resume Paul M. Kochery Page 5 TRAINING CONT'D Course

Title:

Mech. Structural inspection Total Course Hrs.: 40 Vendor: Georgia Power Company Course

Title:

Inspection 2} in. and Smaller Pipes Total Course Hrs.: 26  ;

Vendor: Georgia Power Company '

Course

Title:

Standard First Aid Total Course Hrs.: 4 Vendor: Georgia Power Company Course

Title:

Cardiopulmonary Resuscitation Total Course Hrs.: 4 Vendor: Georgia Power Company Course

Title:

Safe Work Procedure for Closed Vessel Total Course Hrs.: 8 Vendor: Georgia Power Company Course

Title:

Codes and Standards Total Course Hrs.: 16 Vendor: Georgia Power Company i

Course

Title:

Tech. Communication Total Course Hrs.: 40 Vendor: Neilson

'l

, -- ,,w--- , , . , - - - - - --w.- -m.,w , - - ,. ..g,. - n,-- , , ,.

RESUME NAME: Cregory L. Hooper DATE OF BIRTH: September 9,1958 DATE EMPLOYED: March 1,1982 TITLE: Associato Engineer EDUCATION: Bache' ors in Electrical Engineering LICENSE / CERTIFICATIONS:

WORK EXPERIENCE:

SUMMARY

NUCLEAR (CPC) Position: Associate Engineer Oates: July 23,1984 to Present Location: Plant Vogtle Plant Status: Under Construction Job

Description:

Test Supervisor for the PROTEUS plant computer and the Main Control Board.

Position: Associate Engineer Dates: November 21,1983 to March 21,1984 Location: Westinghouse Plant Status: N/A Job

Description:

Wrote software for the PROTEUS plant computer.

Position: Associate Engineer Dates: March 1,1983 to July 19,1983 Location: Plant Vogtie Plant Status: Under Construction Job

Description:

PROTEUS plant computer, Main s Control Board, Human Factors Engineering Position: Junior Engineer Dates: March 1,1982 to March 1,1983 Location: Plant Vogtle Plant Status: Under Construction Job

Description:

P AMS (RG 1.97) instrumentation, PERMS radiation monitoring computer, MET Tower, PROTEUS plant computer,

- Main Control Board, Human Factors Engineering, I & C.

i l

Rcsume Gregory L. Hooper Page 2 NON-NUCLEAR (CPC) Position: Co-op Dates: December 1976 to March 1980 Location: Macon Division Plant Status: N/A Job

Description:

Energy Services Dept.

NON-NUCLEAR (OTHER) Position: Assistant Engineer Dates: June 29,1981 to February 19,1983 Location: Fluor Eng. & Constr.

Plant Status: N/A Job

Description:

Instrumentation, Draf ting, Heat Tracing.

TRAINING NUCLEAR Course

Title:

Start-up Training Dates: July 9,1984 to July 20,1984 Total Course Hrs.: 80 Vendor: CPC Training Dept.

Description:

Reviewed Start-up procedures, CAT procedures, and Test Supervisor responsibilities.

Course

Title:

Simulator Training Dates: June 25,1984 to July 6,1984 Total Course Hrs.: 80 Vendor: CPC Training Dept.

Description:

Simulated plant heat-up, load changes, start-up and accidents.

Course

Title:

Engineering Technology Dates: April 4,1984 to June 22,1984 Total Course Hrs.: 480 Vendor: CPC Training Dept.

Description:

Nuclear Physics, Plant systems operations, thermodynamics, electrical concepts, integrated plant operations.

Course

Title:

PWR Dates: July 19,1982 to July 23,1982 Total Course Hrs.: 40 Vendor: GPC Training Dept.

Description:

Brief overview of nuclear physics and PWR plant systems.

NON-NUCLEAR Course

Title:

PROTEUS computer training Dates: July 25,1983 to November 18,1983 Total Course Hrs.: 680 Vendor: Westinghouse

Description:

Detailed hardware and software training.

RESUME NAME: Alan Lee James DATE OF BIRTH: November 10,1959 DATE EMPLOYED: July 6,1981 to 1985 TITLE: Associate Engineer EDUCATION: Electrical Engineering (Bachelors)

LICENSE / CERTIFICATIONS:

WORK EXPERl5NCE:

SUMMARY

NUCLEAR (CPC) Position: Plant Engineer Dates: July 6,1984 to 1985 Location: Plant Vogtle Plant Status: Under Construction Job

Description:

PERMS, Control Room Workspace Modification Class 1E 125 VDC Lead Test Supervision Position: Associate Engineer Dates: January 6,1983 to July 6,1984 Location: Plant Vogtle Plant Status: Under Construction Job

Description:

Telephone System, Plant Manual Review Coord., PERMS, Control Room Workspace Modification Position: Junior Engineer Dates: July 6,1981 to January 6,1983 Location: Plant Vogtle Plant Status: Under Construction Job

Description:

PAM's, PERM's, Equipment l

Qualification Position: PEO Dates: July 9,1981 to July 26, 1981 Location: Plant Hatch Plant Status: Operational Job

Description:

PEO Work NUCLEAR (OTHER) NONE l NON-NUCLEAR (CPC) NONE NON-NUCLEAR (OTHER) NONE

Resume Alan Lee James Page 2 TRAINING NUCLEAR Course

Title:

STA Course Dates: February 1,1982 to June 18, 1982 Total Course Hrs.: 640 Vendors: Ceneral Physics

Description:

In depth study on Plant Vogtle and its associated systems.

Course

Title:

Simulator Training Dates: June 21,1982 to July 30,1982 Total Course Hrs.: 120 Vendor: General Physics

Description:

Four hours per day classroom instruction followed by four hours of instruction using the Plant Vogtle Simulator.

Course

Title:

PWR Course Dates: August 17,1981 to August 21,1981 i Total Course Hrs.: 40 Vendor: Georgia Power Company

Description:

Study of a general PWR.

Course

Title:

Respirator Training Dates: July 12,1981 Total Course Hrs.: 8 Vendor: CPC, Plant Hatch

Description:

Use of different types of respirators.

Course

Title:

Health Physics and Security Training Dates: July 10,1981

, Total Course Hrs.: 8 Vendor: CPC, Plant Hatch

Description:

Ceneral Health Physics Training and Emergency Procedures Course

Title:

PERMS Training Dates: June 18,1984 to June 29,1984 July 6,1984 to July 13,1984 Total Course Hrs.: 120 Vendor: Westinghouse

Description:

Study of the Radiation Monitoring System.

Course

Title:

Startup Class Dates: April 9,1984 to April 19,1984 Total. Course Hrs.: 36 Vendor: CPC

Description:

Studied different CAT's and Startup l Procedures.

Rcsume Alan Lee James Page 3 TRAINING -

NON-NUCLEAR Course

Title:

Decision Making Dater: February 1,1982 to February 3,1982 Total Course Hrs.: 24 Vendor: Process Management Skills

Description:

Study of different types of the decision making process.

Course

Title:

Principles of Leadership Dates: September 12,1983 to September 16, 1983 Total Course Hrs.: 40 Vendor: GPC

Description:

How to be an effective supervisor.

Course

Title:

Dimension PBX Comm. Star Training Date: September 22,1983 Total Course Hrs.: 8 Vendor: Southern Bell

Description:

Working of the telephone system at Plant Vogtle.

OTHER NONE (Applicable to Powc.r Plant or Related Industry)

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RESUME NAME: Riley R. Johnson DATE OF BIRTH: November 21,1947 DATE EMPLOYED:

TITLE: Operations Support Supervisor EDUCATION:

LICENSE / CERTIFICATIONS:

WORK EXPERIENCE:

SUMMARY

NUCLEAR Position: Operations Support Supervisor Consultec Services, Inc.

Dates: July 1984 to Present Location: Vogtle Electric Generating Plant Waynesboro, CA Plant Status: Under construction & startup Job

Description:

Provide assistance to VEGP Nuclear Operations in areas of procedure, review, training, plant testing / operations and human factors evaluations.

Temporarily assigned to V.C. Summer Operations Training Staff in support of the VECP SRO Licensing Program.

Position: Operations Supervisor for Deseret Generation and Transmission at a 400 MW coal fired plant.

Dates: January 1984 to July 1984 Location:

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Plant Status:

Job

Description:

Duties include supervising the testing, l

. startup and operation of various plant equipment and supervising a shift of 6 operators.

Position: Principal Engineer Ebasco Services, Inc.

Dates: January 1982 to January 1984 Location: Waterford lil Nuclear Station Taft, LA A 116S MW Combustion Engineering PWR Plant Status:

Job

Description:

Served as the operations oriented member of a multidiscipline review team (System Operability Assurance Review Team) whose function is to perform detailed reviews of plant

R;sume Riley R. Johnson Page 2 NUCLEAR (CONT'D) systems to identify design discrepancies and operational concerns and to complete detailed analysis of system reaction to single component or control failures. Later participated in the Waterford lli control room design review and the resolution of the human engineering discrepancies (per NUREG 0700). Also developed plant systems training lectures for the technician training program.

Position: Staff Engineer NUS Corporation Dates: May 1980 to January 1982 Location: Virgil C. Summer Nuclear Station Jenkinsville, SC Plant Status:

Job

Description:

Responsible for writing and reviewing plant surveillance test procedures.

Later assigned to the Activities Coordination Team whose function was to act as liaison with the various construction, startup, operating and maintenance factions to minimize interference and the duplication of effort during pre-operational testing.

In addition to the Activities Coordination Team, I served as Task Leader for the operations assistance group whose function is to advise the Shift Supervisor on the correct and proper operation of plant equipment during startup and operations and to conduct on shift training for the operations group.

Position: Primary Plant Startup Supervisor Westinghouse Electric Corporation Dates: April 1979 to May 1980 Location: Krsko Project Krsko, Yugoslavia Plant Status:

Job

Description:

Responsible for reviewing, rewriting, and recommending for approval startup tests and plant operating procedures, also responsible for supervising a test team in performing various startup tests on 600 MW Westinghouse design pwr and evaluating the results of those tests.

Rtsume Riley R. Johnson Page 3 NUCLEAR (CONT'D) Position: Control Room Operator Dates: July 1978 to April 1979 Location: Colorado UTE Electric Association Craig, Colorado Plant Status:

Job

Description:

Responsible for performing various startup tests, operating major pin ts of equipment, and directing the operation of auxiliary e quipment of a 450 MW coal fired power plant.

Position: All positions from auxiliary power to plant operator Dates: July 1973 to July 1978 Location: Arkansas Power and Light Company Arkansas Nuclear One Unit One A 1025 MW B & W design power and as plant operator on Unit 2, a 980 MWCE design pwr.

Plant Status:

Job

Description:

Responsible for all phases of equipment operatian and startup testing including obtaining senior reactor operator certification (1978), a reactor operator license (1976), and a high pressure boiler operator license (1973).

Position: Machinist Mate Dates: May 1965 to April 1973 Location: United States Navy Plant Status:

Job

Description:

Responsible for operation and maintenance of naval nuclear power plants and for training new navy operators in safe and correct operation and maintenance procedures.

e

, -- c-- .-. - - - - - . _ - - - - - -

RESUME NAME: John D. Hopkins DATE OF BIRTH: April 29,1957 DATE EMPLOYED: July 5,1977 TITLE: Shift Supervisor EDUCATION: 11/3 years Augusta College LICENSE / CERTIFICATIONS: Senior Reactor Operator Certification 8/84, Vogtle Project Reactor Operator License received 4/82 for Hatch 1 & 2 WORK EXPERIENCE:

SUMMARY

61/2 yers as operator at BWR 1984 to present operator / supervisor at PWR NUCLEAR (CPC) Position: Shift Supervisor Dates: August 1984 - Present Location: Plant Vogtle, Burke Co., GA Plant Status: Under construction & startup Job

Description:

Direct operators on shift during CAT, and startup. Assigned to C/R Design Modifications / Human Factor Group, Work Planning Group, and Ops representative in Primary Hydro planning.

Position: Shift Foreman-in-Training Dates: March 17,1984 - August 1984 Location: Plant Vogtle, Burke Co., CA Plant Status: Under construction and startup Job

Description:

Attending SRO certification school and assigned to C/R Design Modifica-tions / Human Factors group.

l Position: Plant Operator i Dates: January 1984 - March 17,1984 Location: Plant Vogtle, Burke Co., CA I Plant Status: Under construction & startup Job

Description:

Attend SRO Certification School Position: Assistant Plant Operator Reactor Operator License Dates: April 1982 to December 1983 Plant Status: Commercial Operation Job

Description:

Duties consi:;t of Control Room

. Operation cf 2 Unit BWR under norm ! and transit conditions, normal startup, shutdown and refueling operations, the refueling flow and in Control Room.

Resume John D. Hopkins Page 2 NUCLEAR (CPC) Position: Assistant Plant Operator CONT'D Dates: October 1979 to April 1982 Location: Plant Hatch Plant Status: Commercial Operation Job

Description:

Duties consist of operation of rad-waste facilities including liquid and solid waste processing. During this time I attended the Hatch RO license school for RO license preparation.

Position: Plant Equipment Operator Dates: July 1977 to October 1979 Location: Plant Hatch Plant Status: Commercial Operation Job

Description:

Daily check of remote equipment and remote equipment operation.

TRAINING NUCLEAR Course

Title:

Substation Operation Dates: January 1980 Total Course Hrs.: 40 Vendor: CPC

Description:

Design and operation of 230/500 kv switchyard Course

Title:

Turbine Generator Operation Dates: November 1982 Total Course Hrs;: 40 Vendor: Spectrum Technical Training

Description:

Design, operation and construction of Turbine Generator and auxillary systems required for T-C startup, shutdown and operation.

Course

Title:

Preparation for Reactor Operator License Dates: August 80 Thru February 82 Total Course Hrs.: Approx.18 months.

Vendor: GPC, General Physics, General Electric

Description:

Training for NRC exam at E. l. Hatch (BWR) including theory, systems,

{ simulator and on-the-job training.

R:sume ' ' .

John D. Hopkins '

Page 3 -

s, TRAINING -

NUCLEAR (CONT'D) Course

Title:

. Reactor Startup Qualification Dates: , January 1982 Total Course Hrs.: 40 hrs.

Vendor: General Electric Corp. -

Description:

(C.E. hot license certification)

Course

Title:

SRO Certification Program Plant Vogtle Dates: January 1984 to July 1984 Total Course Hrs.: 1120 hrs.

Vendor: CPC; General Physics

Description:

Prepare SRO candidates for certification.

Basic PWR Theory, Design, and Operations with 8 weeks of Simulator

. Training.

Course

Title:

TechnicalCommunications Dates: August 1984 Total Course Hrs.: 40 hrs.

Vendor: Nilsson Corp.

Description:

Instruction in verbal and writteri technical communications.

Course

Title:

Control Room Management Dates: April 1985 Total Course Hrs.: 40 hrs.

Vendor: General Electric

Description:

Study of decision making and nproblem solving techniques withemphasis on stressful situations.

Course

Title:

Hot Participation Experience Dates: September 1985-October 1985

. Total Course Hrs.: 6 weeks l Vendor: NA

Description:

Self study /cbservation of McGuire l Operations Dept. during normal l operation of units 1 and 2.

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