ML20215N523

Forwards Response to Request for Addl Info Re SER Open Item 14a on Crdr,Following Preimplementation Audit on 860918-19. Updated Control Room Inventory of Instrumentation Identified in Iccr Also Encl

ML20215N523
Person / Time
Site:	Vogtle
Issue date:	10/31/1986
From:	Bailey J GEORGIA POWER CO.
To:	Youngblood B Office of Nuclear Reactor Regulation
References
GN-1153, NUDOCS 8611060183
Download: ML20215N523 (25)

Text

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.- '* Georgis Power Company Post Office Box 282 Waynssboro, Georgia 30830 Telephone 404 554-99S1 404 724-8114 Southern Company Services, Inc.

Post Office Box 2625 Birmingham, Alabama 35202 Telephone 205 870-6011 Vogtie Project October 31, 1986 Director of Nuclear Reactor Regulation File: X7BC35 Attention: Mr. B. J. Youngblood Log: GN-ll53 PWR Project Directorate #4 Division of PWR Licensing A U. S. Nuclear Regulatory Commission Washington, D.C. 20555 NRC DOCKET NUMBERS 50-424 AND 50-425 CONSTRUCTION PERMIT NUMBERS CPPR-108 AND CPPR-109 V0GTLE ELECTRIC GENERATING PIANT - UNITS 1 AND 2 SER OPEN ITEM 14a: ' CONTROL ROOM DESIGN REVIEW (CRDR)

Dear Mr. Denton:

During the exit meeting, alminating your staff's CRDR preimplementation audit of September 18-19, 1986, your staff requested additional information.

Attached are responses to the items identified by your staff during the exit '

meeting.

If your staff requires any additional information, please do not hesitate to contact me.

n:e rely, J. A. Bailey Project Licensing Manager JAB /sm i Attachment xc: R. E. Conway NRC Regional Administrator )

j R. A. Thomas NRC Resident Inspector J. E. Joiner, Esquire D. Feig l B. W. Churchill, Esquire R. W. McManus '

M. A. Miller (2) L. T. Gucwa B. Jones, Esquire Vogtle Project File G. Bockhold, Jr.

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GEOR3IA POGER COMPANY VOGTLE wrRCTRIC GENERATING PLANT UNIT ONE NUCLEAR OPERATIONS CONTROL ROOM DESIGN REVIEW NRC PREIMPLEMENTATION AUDIT

RESPONSE

OCTOBER 24, 1986

TABLE OF CONTENTS

1.0 INTRODUCTION

........................................ 1 1.1 SYSTEMS FUNCTION AND TASK ANALYSIS.................. 1 1.1.1 System Operating Procedures invoked by EOPs.... 2 1.1.2 EOP Caution Statements......................... 2 1.1.3 Task Analysis of revisions to the EOPs......... 2 1.1.4 Control Panels referenced in the EOPs.......... 4 1.1.5 Instrument Response Time Capabilities.......... 4 1.1.6 Control And Display Type Comparison............ 6 l'. 2 CRDR TEAM DISCUSSIONS CONCERNING RESOLUTION OF HEDS. 6 1.3 COORDINATION OF CRDR WITH TRAINING.................. 8 1.4 HED CATEGORY ASSESSMENT PROCESS..................... 8 APPENDIX A Control Room Inventory...................... 12 APPENDIX B Mini Survey................................. 21 l

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. GEORGIA POWER COMPANY Page 1 VOGTLE ELECTRIC GENERATING PLANT UNIT ONE CONTROL ROOM DESIGN REVIEW NRC PREIMPLEMENTATION AUDIT RESPONSE

1.0 INTRODUCTION

On September 18 and 19, 1986 the Vogtle Unit One Control Room Design Review (CRDR) Preimplementation Audit and Mini Survey (Appendix B) was conducted by the Nuclear Regulatory Commission (NRC) and Lawrence Livermore National Laboratory (LLNL), acting as a consultant to the NRC. The audit was held at the Vogtle site to ' discuss and resolve questions resulting from the NRC/LLNL review of the Vogtle Unit One CRDR Summary Report. The audit discussed all aspects of the CRDR process. This report is submitted to the NRC as a preliminary response to some of the open iteus.

presented to Georgia Power Corporation (GPC) during the NRC exit meeting'on September 19, 1986. i 1.1 SYSTEMS FUNCTION AND TASK ANALYSIS The Vogtle Systems Function and Task Analysis process was reviewed by the NRC staff and LLNL. The NRC Audit Team stepped through the task analysis for a portion of the Steam Generator Tube Rupture procedure with the GPC CRDR Team. The NRC Audit Team identified several potential shortcomings in the Task Analysis process as a result of this review:

O System Operating Procedures (SOP) invoked by the Emergency Operating Procedures (EOP) were not Task Analyzed.

4 O EOP caution statements may not have been task analyzed.

O A formal mechanism for verifying Control Room displays and controls are suitable to support new or revised operator tasks resulting from EOP revisions does not exist.

O The EOPs may reference control panels in the control room outside the scope of the CRDR Program Plan.

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GEORGIA POWER COMPANY Page 2 O A comparison of needed instrument response time versus instrument response time capability was not performed. j O A comparison of the needed display and control types versus display and control types provided was not documented.

1.1.1 System Operating Procedures invoked by EOPs Each procedure in the EOP set was reviewed to identify the SOPS that are referenced. The review identified .

fifteen Unit One System Operating Procedures called for l in the EOP set. A Task Analysis was performed on control room equipment for each of the identified SOPS according to the process discussed in the VEGP CRDR-Summary Report. No additional Human Engineering Discrepancies (HED) were identified.

1.1.2 EOP Caution Statements l

All EOP caution statements were extracted from the EOP l set and duplicates were eliminated. The caution ~

statements were evaluated to identify the displays and controls needed to assess plant conditions. A computer search was conducted on the EOP Task Analysis data base for the identified displays and controls. The search l revealed that each EOP caution had been addressed in another procedure step during .the original Task Analysis. No additional HEDs were identified.

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1.1.3 Task Analysis of revisions to the EOPs The following elements of a task analysis are being added to the EOP revision process to provide some i

assurance that control room displays and controls are suitable to support new or revised operator tasks resulting from proposed EOP changes:

i INFORMATION CHARACTERISTICS UNITS: The parameter identified in the EOP step (s) agrees with the units on the specified control room instrument

, (examples: psig; %; gpm; etc.).

s.

, GEORGIA POWER COMPANY Page 3 RANGE: The interval over which the parameter  !

(EOP step) may vary does not exceed the  !

range of the installed instrument (examples: 0 to 3000 psig; 250 to 500 deg. F; O to 100%; etc.).

RESOLUTION: The EOP step (s) does not require the l determination of a parameter's value in l excess of the installed instrument resolution (example: greater than 1837

. psig on an instrument with a resolution of 50 psig).

TYPE: The EOP step (s) does not require visual information that the installed instrumentation cannot support, and classified as one of the following:

a) discrete or instantaneous (single value or alarm setpoint) b) continuous (multiple values within a ,

range) I c) trending (changing values within a range over a time period)

CONTROL CAPABILITY CHARACTERISTICS POSITIONS: The EOP step (s) does not require identification of control status unavailable in the control room (example: open; closed; throttled; on; off; etc.).

TYPE: The EOP step (s) does not require control actions that the installed controls can not support, classified as one of the following:

a) continuous (variable control; b) discrete (individual position (s) control) l l

GEORGIA POWER COMPANY Page 4 1.1.4 Control Panels referenced in the EOPs The NRC Audit Team requested that GPC conduct a review of the EOPs to ensure any referenced Control Room.back panels are included in the Unit One CRDR effort.

The review was conducted by the EOP procedure group.

This review confirmed that panels outside the scope of the Unit One CRDR Program Plan were not referenced.

1.1.5 Instrument Response Time Capabilities The comparison of needed instrument response times versus instrument response time capabilities was evaluated. In evaluating the response times for VEGP installed instrument loops, three factors were considered:

0 Response time of the transmitter O Response time of the process racks O Response time of the indicators l

Industry experience dictates that transmitter response <

times are in the range of a couple of seconds, process )

racks response times are in the range of milliseconds and indicator response times are insignificant compared 1 to the other two. This provides a typical response time l of less than 5 seconds. The exceptions to this  !

statement are temperature elements (RTD's) where the

, heat transfer characteristics of the thermowell may result in response times longer than direct immersion detectors.

Due to the present state of plant construction and testing, it is impractical to verify all actual instrument loop response times. The response times provided in the Control Room Inventory data base (Appendix A) were derived from the following sources:

a) Actual instrument rack response time measurements (35 to 60 milliseconds) for some but not all primary process rack inputs, b) Quality Assurance and Design Specification documents for Differential Pressure and Pressure transmitters used in Westinghouse Nuclear Steam Supply System.

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, GEORGIA POWER COMPANY Page 5 Step response times were required to be demonstrated as part of the supplier's type testing program. Each of the following was demonstrated:

1) Time to reach 50% output from an input step from 45% to 55%

2) Time to reach 50% output from i an input step from 5% to 95%

Neither value to exceed .4 seconds and for filled systems neither value to exceed I second independent of capillary length, size or fill fluid.

c) Quality Assurance and Design Specification documents for Resistance Temperature Detectors (RTD's) used in Westinghouse Nuclear Steam Supply System.

Step response times were required to be demonstrated as part of the supplier's type testing program. Each of the following was demonstrated:

1) The direct immersion RTD time response shall be 2.5 seconds for a 63.2% response to a step change in the media.

2) Well mounted RTD's shall have a time response of 4 seconds for a 63.2% response to a step change in the media.

In lieu of actual instrument loop time measurements the specification times were at least doubled to provide l some conservatism in determining the response time capabilities used in the comparison to the Westinghouse Instrument and Control Characteristics Review (ICCR) requirements'.

The Control Room Inventory of Instruments Identified in the ICCR was updated and compared to the requirements.

No HEDs were identified during this evaluation.

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, GEORGIA POWER COMPANY Page 6 1.1.6 Control And Display Type Comparison The comparison of the needed display and control types versus the actual installed display and control types was performed. The . Control Room Inventory of Instruments Identified in the ICCR (Appendix A) was updated and compared to the requirements. No HEDs were identified during this evaluation.

1.2 CRDR TEAM DISCUSSIONS CONCERNING RESOLUTION OF HEDS The NRC Audit Team had a concern that important Team discussions relevant to the resolution of HEDs will not i be preserved for future reference (ie. Unit Two CRDR).

4 To aid in the preservation of relevant comments, the  !

HED Form has been modified to include Team Member i discussions (Figure 1). l l

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, - . - - - . . _ . . ,-, - ,..... . - , - .,n_n-.. . - - , ,

GEORGIA POWER COMPANY Page 7 REV: 1 DATE: 10/17/86 VOGTLE ELECTRIC GENERATING PLANT HUMAN ENGINEERING DISCREPANCY (HED)

HED Number:

Item (s) involved:

Origin:

HED

Description:

Originator: /

Signature Date Team Menber Discussions:

T/M 1 T/M 2 T/M 3 T/M 4 FR--:*3 Resolution: Category:

CRIR Team Approval /

(Team Imader Signature) Date Pages Attached (Figure 1)

GEORGIA POWER COMPANY Page 8 1.3 COORDINATION OF CRDR WITH TRAINING The CRDR process described in VEGP CRDR Summary Report

! was coordinated with other post-TMI activities. The CRDR Summary Report details the mechanisms for coordination of control room improvements with other programs. In addition, the CRDR was coordinated with the Training Program as follows:

1) The Team Captain and one other team member attended a Senior Reactor Operator License Training Program during the Unit One CRDR effort. This improved the CRDR Team Members knowledge of operations and plant design, allowing them to more effectively identify design problems later in the CRDR process.

2) Where appropriate, HED resolutions identified training needs which were incorporated in formal lesson plans by the Training Department.

3) Both students and instructors in the Simulator Training Program were surveyed to=

identify Human Engineering Discrepancies which were noted during simulator exercises.

This was an especially valuable technique since new operators problems with the controls reveal design problems that more experienced operators have learned to compensate for.

j 4) Control room modifications that resulted from the Emergency Operating Procedures Validation Program and/or CRDR Survey Instruments were first installed in the Training simulator (when practicable) in order to gain operator feedback regarding the suitability of the improvement. The formal feedback mechanisms were the Operator Questionnaires and Problem Reports as presented in the CRDR Summary Report.

1.4 HED CATEGORY ASSESSMENT PROCESS

, As discussed in the VEGP CRDR Summary Report, the last aspect of the Assessment Phase was an independent HED category review. This HED category review was conducted to provide assurance that each HED identified during the Execution Phase of the CRDR wcs in fact properly categorized.

. GEORGIA POWER COMPANY Page 9 During the NRC Preimplementation Audit, the Audit Team noted that a potential existed for HEDs with safety significance and high error probability to be assigned a category that would not require correction if they were not identified during the EOP Validation Exercise.

The review of the HED data base conducted by the CRDR Team during the Audit determined that no HEDs of safety significance and high error probability would be left uncorrected. However, to provide assurance that HEDs of safety significance and high error probability would be properly categorized, the algorithm was modified to permit HEDs to be categorized as Category 1 without reference to the EOP Validation Exercise and before the Category 2 decision point.

All HEDs identified in the future will be subjected to the following modified algorithm (Figures 2 and 3) to determine their significance and effects on plant safety.

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-n.- , - ,-- , . - , -- - , ,..--,..-,---r , - - . - - - - , - , . , e - - - - , , , - - - - - , - . , - - - , , - - ,---- ~.-- - . , - - , ,- a.n --

i CRDR DISCREPANCIES IDENTIFIED SURVEYS CHECKLISTS Fig u re 2 TASK ANALYSIS hff g E EE

! IDENTIFIED HED'sk o

YES E

HED CATEGORIZED ITEM >

7 NO l

1 2 3 >l CATEGORY 1 l V 8

4 4 >l CATEGORY 2 l

! 3 CATEGORY 3 l l n 9 CATEGORY 4 l D suu 6 5

ALGORITHM ATTRIBUTES ITEM 1 ITEM 2 HED's experienced or assessed as having a hig h probability of HED's associated with ESF contributing to operator e rro r. System s.

e e

S ITEM 3 ITEM 4

• HED's that could result in HED's idenlified through the unsafe operation or violation Operat,ing Experience Review of a Techn.ical Specif.icat. ion. or actual problems identified o in the Operator Questionnaire.  %

ITEM 5 ITEM 6 HED's determined to be easily HED's determined to contribute correctable with point, tape, labels, to Operator mental work load engraving changes or work space (cumulative effects) resulting in environment improvements. fatigue, confusion or discomfort.

Fig u re 3 g 11

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., GEORGIA POWER COMPANY Page 12 1

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l APPENDIX A i 1

CONTROL ROOM INVENTORY OF INSTRUMENTATION IDENTIFIED IN THE VEGP ICCR l i

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CEOR2IA POWER COMPANY Paga 13 CONIROL ROCH INVENIORY OF INSTHJMENTATION IDENTIFIED IN THE VEGP ICCR MST INSTRUMNIATION INSTRUM!NTATION (MITS MIN MAX RESOLUTION ACCtRACY RESPONSE TYPE NO. NUM ER NAME TIME 001 TSIE-3 SI ACIUATED N/A N/A N/A N/A N/A N/A D  !

BPIB WDOCH l l

002 ALBO9-A4 SI ANNUNCIATORS N/A N/A N/A N/A N/A N/A D 003 AIB GROUP 1 & 4 CMT ISO PHASE N/A N/A N/A N/A N/A N/A D A PONITOR LIGifrS 004 Car ISO PH B NO ISO OCCURS N/A N/A N/A N/A N/A N/A ON PHASE B 005 TSIB-4 CONTAIMENT N/A N/A N/A N/A N/A N/A D SPRAY STATUS 006 TSLB-1 IDW STMLINE N/A N/A N/A N/A N/A N/A. D PRESS SI SIGNAL STATUS 007 TSIB-3 LOW PRZR PRESS N/A N/A N/A N/A N/A N/A D SI SIGNAL STATUS 008 1-LI-0990A REFUELING WATER % 0 100 2 3.7 3 SEC. D,C STORAGE TANK 009 ALB06-E5 RHST I!MPTY N/A N/A N/A N/A N/A N/A D AIARM 010 1-FI-0918 SAFE INJ PU W GPM O 800 20 3.6 3 SEC. D,C P6003 DISCH 011 1-FI-0917A CVCS CIE319F TO GPM O 1000 20 3.7 3 SEC. D,C BGt INJ TK V6 012 1-PI-0947 BOR N INJECT PSIG 0 2800 50 3.0 3 SEC. D,C TANK 013 1-PI-0919 sAPE INJ PUDP PSIG 0 2000 50 3.0 3 SEC. D,C P6003 DISCH 014 1-NI-OO41B POMR RAN3E- 1 % FULL 0- 120 2 5.2 1 SEC. D,C,T 1-NR-0045  % PULL POMR POMR 015 1-NI-0036B INTEREDIATE AMPS 10E-11 10E-3' 1 10.2 1 SEC. D,C,T 1-NR-0045 RANGE-2

1 GEOR3IA POWER COMPANY Pcga 14 CONTROL ROCN INVENTORY OF INSTRUMENTATION IDENTIFIED IN THE VEGP ICCR E ST INSTRUMENTATION INSTRUMENTATION IMITS MIN MAX RESOLITIION ACCtRACY RESPONSE TYPE NO. NUPEER NAME TIME 016 1-NI-0035D INTERMEDIATE DPM .-5 5 .1 N AVAIL N/A D,C RANGE-1 STRT UP 016 1-NI-0036D INIEREDIATE DPM .-5 5 .1 N AVAIL N/A D,C RANGE-2 STRT UP 017 1-NI-0032B SOURCE RANGE-2 CPS 10E0 10E6 1 11.0 1 SEC. D,C,T 1-NR-0045 CCUNE RATE 018 1-NI-0032D SOUICE RANGE-2 DPM .5 5 .1 N AVAIL N/A D,C STRr UP RATE 019 N/A RCD BOT 1tN N/A N/A N/A N/A N/A N/A D LIGRTS 020 1-RE-0002 AREA 60N M/h 10E-1 10E4 DIGITAL >20.0 N AVAIL D,C CONTAIN OP LEVEL 020 1-RE-0005 AREA M]N M/h 10E-3 10E11 DIGITAL >20.0 N AVAIL D,C CONTAIN OP LEVEL 021 1-RE-OO19 STEAM GENERATOR UCI/cm3 4E-7 4E-2 DIGITAL >20.0 N AVAIL D,C LIQUID 022 1-RE-0021 STM GEN BIh0N UCI/cm3 4E-7 4E-2 DIGITAL >20.0 N AVAIL D,C TO CONIENSER 023 1-RE-12839A SJAE & STM PEG N/A N N AVAIL DIGITAL >20.0 N AVAIL D,C EXH RAD MRI*1TR AV.~ . L 023 1-RE-12839B SJAE & SIM PNG N/A N N AVAIL DIGITAL >20.0 N AVAIL D,C EXH RAD M3fITTR AVAIL 023 1-RE-12839C SL7AE & SIM PNG N/A N N AVAIL DIGITAL >20.0 N AVAIL D,C EXH RAD 60NITOR AVAIL 024 1-RE-0024A SEtaCT CCMP UCI/an3 1E-10 1E-5 DIGITAL >20.0 N AVAIL D,C CUBICIE 024 1-RE-0024B SELECT CCMP UCI/an3 5E-7 5E-2 DIGITAL >20.0 N AVAIL D,C CUBICLE O25 1-RE-13119 MAIN STEAM LINE N/A N N AVAIL DIGITAL >20.0 N AVAIL D,C MON AVAIL

, GEOR2IA POWER COMPANY Paga 15 CONIROL ROCN INVENIORY OF INSTRUMENTATION IDENTIFIED IN THE VEGP ICCR E ST INSTRUMENTATION INSTRUMENTATION INITS MIN MAX RESOLUTION ACCGtACY RESPONSE TWZ NO. NUBBER NAME TIME 026 1-RE-12442A PIANI VENT UCI/cm3 1E-11 1E-6 DIGITAL >20.0 N AVAIL D,C 026 1-RE-12442B PLANT VENT UCI/cm3 1E-11 1E-6 DIGITAL >20.0 N AVAIL D,C 026 1-RE-12442C PLANT VENT UCI/cm3 5E-7 SE-2 DIGITAL >20.0 N AVAIL D,C 027 1-AI-12979 CONTAIN H2  % 0 10 .1 N AVAIL N AVAIL D,C MONITUR TRN A 027 1-AR-12979 CONTAIN H2  % 0 10 .1 N AVAIL N AVAIL D,C PONITOR TRN A 028 1-PI-0934 CONTAIPM!NT PSIG 0 75 1 3.0 3 SEC. D,C,T 1-PR-0934 029 1-LI-0764 CONIAIN !!MERG  % 0 100 2 3.7 3 SEC. D,C FLOOR DRNS LEVEL 030 1-FI-0930 SPRAY AIDITIVE GEN O 300 5 3.2 3 SEC. D,C TANK IN 031 1-LI-0931A SPRAY AIDIT TK % 0 100 2 3.7 3 SEC. D,C T6001 LEVEL 032 1-PI-0408 REAC COOLANT PSIG 0 3000 50 3.0 3 SEC. D,C,T 1-PR-0428 LOCP 1 }OT LEG 033 1-TI-0412 REAC 000 IDCP 1 DEGREE F 530 630 2 3.6 8 SEC. D,C.T 1-TR-0412 TilDF AVERAGE 034 CORE EXIT T/C T/C's DEGREE F 0 2400 .1 N AVAIL 5 SEC. D,C,T l 1-XR-400053  !

l 035 1-UI-13134A RCS SUBCOOLING DEGREE F N N AVAIL N AVAIL N AVAIL N AVAIL D,C i BONITOR AVAIL l 036 1-TI-0413A REAC IOOP 1 DEGREE F 0 700 10 3.7 8 SEC. D,C,T 1-TR-0433A WIDE RANGE HCfr 037 1-TI-0413B REAC IDOP 1 DEGREE F 0 700 10 3.7 8 SEC. D,C,T 1-TR-0433B WIDE FANGE COID i

038, 1-LR-1310 REACTOR VPmvr. % 60/0 120 1/2 3.3 3 SEC. D,C,T 39, WATER LEVELS 40 1

GEORGIA POWER COMPANY Paga 16 4

CONIROL ROOM INVENIORY OF INSTRUMENTATION IDENTIFIED IN THE VEGP ICCR 1

l MST INSIMM!NTATION INSTRUMNTATION (NITS MIN MAX RESOLUTION ACCCRACY RESPONSE TYPE NO. !GSER NAM TIM 1

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041 1-TE-173 RCP #1 SEAL DEGREE F N N AVAIL N/A N AVAIL N AVAIL l T!!MP AVAIL l 042 1-FI-0414 REAC COOLANT  % 0 120 2 3.0 3 SEC. D,C LOOP 1

! 042 1-FI-0444 REAC COOLANT  % 0 120 2 3.0 3 SEC. D,C j

043 1-PI-0455A PRESSURIZER PSIG 1700 2500 10 2.5 3 SEC. D,C,T 1-PR-0455A VAPOR l 044 1-TI-0453 PRESSURIZER DEGREE F 100 700 10 3.7 8 SEC. D,C i LIQUID l

045 1-LI-0459A PRESSURIZER  % 0 100 2 3.6 3 SEC- D,C,T 1-IR-0459 1

046 1-TI-0468 PRESSURIZER DEGREE F 50 350 5 3.7 8 SEC. D,C RELIEF TANK

047 1-LI-0470 PRESSURIZER  % 0 100 2 3.7 3 SEC. D,C RELIEF TANK 048 1-PI-0469 PRESSURIZER PSIG 0 100 2 3.0 3 SEC. D,C RELIEF TA M l 049 1-TI-0449 PRESSURIZER oe n F 50 400 10 3.7 8 SEC. D,C poler RELIEF 4 050 1-TI-0464 PRESSURIZER DEM EE F 50 400 10 3.7 8 SEC. D,C SAFETY VALVE j DISCH 051 1-FI-0618A RESID NT RBOV @M 0 5000 100 3.6 3 SEC. D,C IP RET BYPASS A t

052 1-PI-0614 RESID HT RB OV PSIG 0 800 20 3.0 3 SEC. D,C l PLMP 1 DISCH 053 ALB06-Al & B1 RIE PUW DISCH N/A N/A N/A N/A N/A N/A D l HIGH PRESS ALAM

i 054 1-FI-0183A EMRG B0 RATION @M O 150 2 3.2 3 SEC. D,C 055, 1-FR-0110 BCRIC ACID 0 160/40 2/1 4  % 2.8/3.4 3 SEC. D,C,T 67 BLEND 00N m0L l

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00NTROL ROCH INVENIORY OF INSTRUMDrIATION IDENTIFIED IN THE VEGP ICCR Mt31' INSTRUMENTATION INSTRUMENTATION LMITS MIN MAX RESOLUTION ACCLRACY RESPONSE TYPE NO. IG BER NADE TDE 056 1-TI-0103 BORIC ACID TANK DEGREE F 50 150 2 3.7 8 SEC. D,C T4003 057 1-FI-0121C CHARGING LINE GPM O 200 10 3.7 3 SEC. D,C j 058 1-FI-0142A REAC COOLANT GPM 0 20 0.5 3.7 3 SEC. D,C PLMP 4 SEAL WATER 059 1-FI-0132C IRID 06N FLOW GPM O 200 5 3.7 3 SEC. D,C 060 1-FI-0406A REACIOR HEAD GPM O 80 1 3.7 3 SEC. D,C LETD9M LINE 061 1-ER-0156 REAC COOL ENP gal 0 1.0 .02 3.4 3 SEC. D,C,T 1AND2 L RANGE IJC 062 1-FR-0158 REAC COOL PMP GPM O 6.0 .2 3.4 3 SEC. D,C,T 3AND4 H RANGE IJC 063 1-PDI-0150 REAC COOLANT PSID 0 400 10 3.0 3 SEC. D,C PlNP 4 NO 1 SEAL 064 N AVAIL RCP SEAL N/A N/A N/A N/A N/A N/A INJECTION SUPPLY TBF 065 1-PI-0120A CHARGING HEAIER PSIG O 3500 50 3.0 3 SEC. D,C 066 1-LI-0185 VOL CGfTROL  % 0 100 2 3.7 3 SEC. D,C TANK 068 1-PI-0131A ID PRES LETDPH PSIG 0 600 10 3.0 3 SEC. D,C 069 1-PI-0124 EXCES LEID6M PSIG 0 250 5 3.0 3 SEC. D,C HEATEXCH DISCH 070 ZIB-12,13,614 AB BREAK DETECT N/A N/A N/A N/A N/A N/A D SYS STATUS LIGfr I

071 1-FT-19052 RCP CCW THERMAL N/A N/A N/A N/A N/A N/A D l BARRIER FIDW

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, GEERGIA POWER COMPANY PXgia 18 CONIROL ROOM INVENIORY OF INS'IBUMENTATION IDENTIFIED IN THE l VEGP ICCR MST INS"1PUM!lNTATION INSTRUMENTATION . IMITS MIN MAX RESOLUTION ACCtRACY RESPONSE TYPE NO. NUM ER NAME TIME i

072 1-FE-1929 CCW FIIN 'IO RHR N/A N/A N/A N/A N/A N/A D HK's j 073 1-PI-1874 COMPO CW PUW PSIG O 200 5 3.0 3 SEC. D,C TRAIN A DISCH 074 1-PI-1977 AIR C(NPO CW PSIG O 200 5 3.0 3 SEC. D,C PMPS DISCH 075 1-FI-1876 CCEPO CW PUW GPM x 10E2 0 150 2 3.6 3 SEC. D,C TRAIN A DISCH 076 1-TE-1967 AOCW SUPPLY DEGREE F N N AVAIL N/A N AVAIL N AVAIL D T!!MP AVAIL 077 AIBO4-B3,4,5,&6 ACCW RCP COOLER N/A N/A N/A N/A N/A N/A D FIDW ANNINCIA'ICR 078 1-PI-9361 INSIR AIR DRYER PSIG O 150 2 3.0 3 SEC. D,C

'ID SCS EQUIP 079 1-PI-1636 NUC SERV CW PMP PSIG O 200 5 3.0 3 SEC. D,C 7 RAIN A DISCH 080 1-FI-1640A NUC SERV TRAIN GEN X10E3 0 25 .5 3.6 3 SEC. D,C 1 A RETURN FIDW 081 1-PI-0514A STM GEN LOOP 1 PSIG O 1300 20 3.0 3 SEC. D,C,T l 1-PR-0514 STM 082 AIa13-F1 STEAM PRESSURE N/A N/A N/A N/A N/A N/A D l RATE AIARM

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083 1-LI-0517 SIM GEN LOCP 1 % 0 100 2 3.6 3 SEC. D,C,T 1-FR-0510 084 1-LI-0501 STM GEN IDOP 1 % 0 100 2 3.6 3 SEC. D WIDE RANGE 085 1-SI-5316 SGFPI A SPEED R1H X10E3 0 8 .2 N AVAIL N AVAIL D,C TACH DO RMr N

086 1-PI-0508 FEEDWIR PUW PSIG 200 1500 20 3.0 3 SEC. D,C l DISCE

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, GE3R3IA POWER COMPANY Pcga 10 COMm0L ROCN INVENIORY OF INSTRUMENTATION IDENTIFIED IN THE VEGP ICCR MST INSTRUMENTATION INSTRUMENTATION (MITS MIN MAX RESOLUTION ACCCRACY RESPONSE TYPE NO. NUMER NAME TIME

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087 1-FI-0510A SIM GEN IDOP 1 WPH 0 5 .1 4.0 3 SEC. D,C FEEDfrR 088 1-PR-6292 LPI A & B PSIG 0 30 0.5 2.6 3 SEC. D,C,T ExxAuST N0ao PRESS N 089 1-FI-5150A AIN FEEDWrR GPM 0 600 10 3.6 3 SEC. D,C SUPP TO SIM GEN 4

090 1-SI-15109A ALE FW TURB RPM x10E3 0 6 .1 N AVAIL N AVAIL D,C SPEED 091 1-PI-5107A AIN FEED PMP TD PSIG X10 0 200 5 3.0 3 SEC. D,C P4001 IM DISCH 092 1-LI-5101 CONDENSATE  % 0 100 2 3.7 3 SEC. D,C SICRAGE TANK 1 i 093 1-JI-40132 GENERATOR A-C MGA 0 1500 20 1.0 INST D,C JI-Gl>N 094 1-PI-6338 HYDRAULIC FLUID PSIG x10E3 0 2 .5 N AVAIL N AVAIL D,C PRESSURE 095 1-JI-40113 DG1A WAIT KIIDDETTS O 10E4 200 1.0 INST D,C OUIPUT 095 1-JI-40114 DG1B WATT KIIO9ATTS O 10E4 200 1.0 INST D,C OUTPUT 096 1-EI-40137B DG1A 001PUT AC VOLTS 0 5000 100 1.0 INST D,C VOLTAGE 096 1-EI-40138B DG1B OUIPUT AC VOLTS 0 5000 100 1.0 INST D,C VOLTAGE

, 097 N/A 13.8KV BUS VOLTS O 18000 200 1 INST D,C 1 VOLTAGE 098 N/A 13.8KV BUS HZ 57 61 .5 1 INST D,C FREQUENCY 099 N/A 4.16KV BUS VOLTS O 5000 10 1 INST D,C VOLTAGE i

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CEORGIA POWER COMPANY Pcga 20 CON 1 POL ROOM INVENIDRY OF INSTRUMENTATION IDENTIFIED IN 'INE VEGP ICCR M ST INSTRUMENTATION INSTRUMENTATION UNITS MIN MAX RESOLITTION ACCT. RACY RESPONSE TYPE NO. NUMER NAME TIME 100 N/A 480 VOLT BUS N/A N/A N/A N/A N/A INST D POTENTIAL LIGHTS 101 N/A AC EM!RGENCY VOLTS O 5000 10 1 INST D BUS VOLTAGE 102 1-LSHL-0625 SPENT FUEL N/A N/A N/A N/A N/A N/A D LEVEL 103 1-FI-0631 SFPCPS FLOW N/A N/A N/A N/A N/A N/A D 104 N/A CONTROL ROCN MIN /HR 00:01 24:00 00:01 N AVAIL INST D,C CLOCK l

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GEORGIA POWER COMPANY Page 21 l

APPENDIE B l

! VOGTLE PREIMPLEMENTATION AUDIT l CONTROL ROOM MINI SURVEY RESULTS SEPTEMBER 18, 1986 NRC MINI AUDIT HEDS Plant VOGTLE position j

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1) The meter face non-glare VEGP HEDS 1288 I coating or other damage impairs the readability of the meter  !

scales.

2) No reflash capability for VEGP BED # 1211 & 1281 multiple input annunciators, l

3) Annunciator group labels The current label referring to are misleading or incomplete MFW and steam generators is (e.g. AFW annunciators located inclusive of the AFW systema. i in a group of Main Feedwater) This level of labeling meets the guidelines of NUREG 0700.

Revisions to these labels were-already planned to standmedize nomenclature and has been installed, it now reads 'MFW, AFW and STEAM GENERATORS'.

4) Inconsistent channel VEGP HEDS 1012, 1013 & 1139 terminology used on the AFW pumps and controls (e.g. A,B,C versus 1,2,3).

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5) Vibration monitor controls VEGP EED# 1068, 1251 & 1253, appear to be out of reach for

, the 5th percentile female.

6) Steam / Feed Flow / Level blue Refer to RED # 1149 & 1285 and and green recorder pointers are their resolution, but no obscured by the recorder scale. problems have been identified in the Simulator or the Operator Experience Reports. The operatore do not normally stand at attention, pressed to the rail to read this instrument.

Normal flexure to operate the l controls makes the pens visible.

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- . GEORGIA POWER COMPANY Page 22

7) The normal range of the VEGP HEDS 1048 displayed parameters are not indicated

8) The meaning of the amber VEGP HED# 1099 lights associated with the hand switches are not clear

9) The labels for the steam HED resulted from a modification generator flow element inputs to correct a previous HED. This are obscured from tall operators item has not been subjected to by the recorder covers. the Verification Program at this time.

10) TDI-15215 (Delta "T" The parameter is also identified indicators) parameter indication in the Hierarchical label above located on meter scales instead the indicator (1TI for temp.

of device labels. indicator and 1DTI for Delta temp. indicator).

11) Parameter units are not This panel was not subject to provided on the digital Rad the Unit One CRDR, but it was Monitor displays. our intention to add the units to the Rad Monitor displays on this panel and the local read outs via the Supplemental Label Program.

12) Annunciators are located VEGP HED# 1067 & 1070 too high for continued viewing, especially by shorter operators.

13) Labeling on many "J" handle VEGP HEDS 1295 switches is obscured by the "J" handle itself.

14) One set of labels (Hotwell This control room item was level control) is placed midway previously identified by the between two sets of functionally CRDR Team and is now corrected.

distinct displays. Operator misreads will result.

15) The Load Limit Set Dial This specific problem was not readings are not readable, need addressed in 0700,.but the dials l contrast from background, need cleaning, and will be j addressed under our house cleaning procedure.

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16) The height of lower "J" and We plan to perform a second "T" handles and associated Anthropometric Survey of the controls on panel PSDA are too Shutdown Panels to ensure no low. other errors exist.

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