IR 05000352/1989001

Insp Rept 50-352/89-01 on 890117-20.No Violations Noted. Major Areas Inspected:Implementation of post-accident Monitoring Instrumentation in Accordance W/Reg Guide 1.97, Rev 2

ML20247K864
Person / Time
Site:	Limerick
Issue date:	02/22/1989
From:	Anderson C, Cheung L, Della Grecca A NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION I)
To:
Shared Package
ML20247K856	List: IR 05000352/1989001 ML20247K851
References
RTR-REGGD-01.097, RTR-REGGD-1.097 50-352-89-01, 50-352-89-1, GL-82-33, NUDOCS 8904050340
Download: ML20247K864 (15)

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i U.S. NUCLEAR REGULATORY COMMISSION I REGIGN I i'

Report N /89-01

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Docket N i l

License No. NPF-39 Licensee: Philadelphia Electric Company 2301. Market Street Philadelphia, Pennsylvania 19101 {

Facility Name: Limerick Generating Station, Unit 1 Inspection At: Limerick, Pennsylvania Inspection Conducted: January 17-20, 1989 Inspectors: . A -

Leonard Cheung, Senior Re or Engineer ' d a te'

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A.DellaGre(fa,ReactorEngineer 2AJn datd (

Other participant and contributor to this report include:

M. Yost, Engineer, I a National Engineering Lab Approved by: ,

2 2 f C. J.vAnderson, Chief, Plant System date Section, EB/DRS  ;

Inspection Summary: Inspection of January 17-20, 1989 (Inspection Report I No. 50-352/89-01) '

l Areas Inspected: Special, announced inspection to review the licensee's implementation of the post accident monitoring instrumentation in accordance with Regulatory Guidance 1.97, Revision Results: Based on this inspection, the inspectors determined that the licensee.

had implemented a program to meet the recommendations of RG 1.9 The inspectors l

also reviewed the licensee's corrective actions for previously identified

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Environmental Qualification items. As a result, five violations were closed l (50-352/88-02-01 through 50-352/88-02-05).

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Details 1.0 Persons Contacted 1.1 Philadelphia Electric Company (PECo)

M. Caldwell, Engineer, Nuclear Engineering

• E. Callon, I&C Engineer W. Clune, Nuclear Engineering R. Dubiel, Superintendent, Plant Service C. Engriss, Regulatory Engineer G. Foust, Nuclear Support Licensing

-*R. George, Engineer, Nuclear Engineering

• R. Lynch, Nuclear Engineering A. MacAinsh, Manager, Quality Assurance

• W. Malfaro, I&C Test Engineer M. McCormick, Jr., Plant Manager, Limerick

• R. Ogitis, Engineer, RG .1.97 Coordinator L. Robinson, I&C Maintenance Coordinator J. Rubert, QA Engineer D. Sandt, Manager, Nuclear Engineering

• J. Spencer, Superintendent, I&C Maintenance

• V. Warren, Test Engineer, Licensing 1.2 Bechtel Power Corporation R. Murrin, Engineering Supervisor R. Salgado, Group Leader, Control System D. Warren, Senior Engineer, Control System U.S. Nuclear Regulatory Commission T. Kenny, Senior Resident Inspector L. Scholl, Resident Inspector

• Denotes those present at the exit meeting on January 20, 1989,

2.0 Background The purpose of this inspection was to review instrumentation systems for assessing plant conditions during and following the course of an accident based on the criteria specified in Regulatory Guide (RG) 1.97,. Revision These systems were inspected to determine if they were installed in ac-cordance with Generic Letter number 82-33 " Requirements for Emergency Response Capability" (Supplement I to NUREG-0737). This letter specifies those requirements regarding emergency response capabilities that have been approved by the NRC for implementation. This supplement also discusses, in part, the application of RG 1.97 to the emergency response facilities, including the control room, the technical support center (TSC) and the.

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I emergency response facility. Regulatory Guide 1.97 identifies the plant variables to be measured and the instrumentation criteria for assuring acceptable emergency response capability during and following the course of an acciden l Regulatory Guide 1.97 divides Post Accident Instrumentation into 3 categories and 5 types. The three design categories are noted as 1, 2 )

and 3. Category 1 has the most stringent design requirements and category l 3 has the least stringent. The five types of instrumentation identified  ;

in the Regulatory Guide are types A, B, C, D, and E. Type A variables i are plant specific and classified by the licensee. Type B variables {

provide information to indicate that plant ufety functions are being 1 accomplishe Type C variables provide information regarding the breach of barriers for fission product release. Type D variables indicate the operation of individual safety system Type E variables are those that indicate and determine the magnitude of the release of radioactive materials. Each variable type can be any design category. However, type A variables must meet Category 1 design requirement .0 Sc, ope The NRC inspection scope included: equipment qualification (Seismic and Environmental), redundancy of power supplies, measured variables, display and recording methods used, independence ind separation of electrical circuits, range and overlapping features of multiple instrument indicators, equipment identification for R31.97 instruments, service, test and surveillance frequency, direct and indirect measurement of parameters of interes The safety related (Q) and EQ master equipment lists were reviewed for the instruments selected to ascertain whether they had been evaluated and tested to the appropriate environmental, quality assurance (QA) and seismic qualification requirement .0 Inspection Details The inspectors held discussions with various members of the licensee's staf f, reviewed drawings (see Appendix A) and procedures, and selected variables for system walkdown. Walkdowns were performed for the sensing instruments (transmitters and 02 and H2 analyzers) at various locations of the reactor building and the display instruments in the control room to assess the implementation of RG 1.97, Rev. Instrument variables reviewed for Limerick Unit 1 included reactor coolant level, reactor pressure, drywell pressure, containment hydrogen / oxygen concentration, suppression pool water level and suppression pool water temperature.

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Characteristics examined for each variable include identity, location, function, separation (physical / electrical), isolation, seismic, power source, environmental qualification status and instrument rang The following instrumentation was examined:

4.1 Reactor Water Level The licensee determined reactor water level to be a 'ype A variabl Four instrument channels were provided to cover the required water level- range as follows:

Power Transmitter Division Recorder Indicator Range LT42-115A (I) XR42-IR623 " to +60" LT42-115B (II) XR42-IR6238 -

-150" to +60" LT42-IN085A (I) LR42-IR615 -

-350" to -100" LT42-IN0858 (II) -

LI42-IR610 -350" to -100" The licensee has taken exception to RC 1.97 for the reactor water level measurement range. RG 1.97 specifies that the range should be from the bottom of the core support plate to the lesser of the ton of the vessel or the centerline of the main steam -lines. The range provided by the licensee for the pper limit of water level is 60",

which is less than that recommended by RG 1.97. This " deviation" was justified by the licensee and accepted by the NRC as documented in the Limerick Safety Evaluation Report (SER).

The display instruments (indicator and recorder) are located on the main control board, and are specifically marked with yellow transparent mylar strips for easy identification after an acciden All of the above instrument loops were found to be in calibration as evidenced by the calibration records. The inspector reviewed the associated drawings and procedures as. identified in Appendix A, and did not identify any deficiencie .2 Reactor Coolant Pressure The licensee determined reactor coolant pressure to be a Type A variable. The following two instrument channels were provided t monitor this variable after an accident:

Power Transmitter Division Recorder Indicator Range PT42-103A (I) XR42-IR623A -

0 to 1500 psig PT42-103B (II) XR42-IR5238 -

0 to 1500 psig

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These two instrument channels share recorders with the reactor water J level. The recorders are two pen recorders located-on the main l control board and are specifically marked with yellow mylar strips I for easy. identification after an acciden The transmitters are in the EQ master. list. All instruments in these two instrument channels are'in the seisc.f c qualification list. - They were found to be in calibration as evidenced by the calibration record The' inspector reviewed the associated drawings.and procedures identified in Appendix A and did not identify any deficiencie .3 Drywell Pressure The licensec determined drywell pressure to be a Type A variabl The following two instrument channels were provided to monitor this >

variable after an accident:

Power Transmitter Division Recorder Indicator Range PT57-101 (I) PR57-101 -

-5 to +165 psig PT42-101 (II) -

PI42-101 -5 to +165 psig The p essure tap of the first transmitter (PT57-101) is in the I suppression pool atmosphere while the pressure tap of the second transmitter (.PT42-101) is in the drywell area. The indicator and recorder are located on the main control board and are marked with yellow mylar strips for easy identification after an accident. The instrument ranges enveloped those recommended by RG 1.9 The two transmitters are included in the Limerick EQ Master List. All of the instruments for these two-instrument channels are in calibratio The inspector reviewed the associated drawings and precedures as identified in Appendix A and did not identify any deficiencie .4 Containment and Drywell H2 [02 Concentration The licensee determined that containment and drywell hydrogen and oxygen concentration are Type A variables. Accordingly, they l furnished category I sampling, process and display instrumentation.

l The monitoring of these variables is performed by the following l redundant instrument channels: Hydrogen Concentration <

Sensing Power Elements Transmitter Division Recorder Indicator Range AE57-151 AIT57-151 (IV) -

A157-151 'O - 30%

AE57-188 AIT57-188 (III) -

AI57-188 0 - 30%-

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O 6 Oxygen Concentration Sensing Power Elements Transmitter Division Recorder Indicator Range AE57-150 AIT57-150 (IV) -

AI57-150 0-10% & 0-25%

AE57-187 AIT57-187 (III) -

AI57-187 0-10% & 0-25%

The hydrogen and oxygen concentration indicators are located on the main control board and are marked with yellow mylar strips for distinction and ease of recognition as post-accident monitoring instrumentation. All instrument loops were found to be properly calibrated as evidenced by the calibration record Review of the associated documents as listed in Appendix A revealed no deficiencie .5 Suppression Pool Water Level The licensee classified suppression pool water level as a Type A variable. The monitoring of this variable after an accident is accomplished b' 'he following two instrument charnels:

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Power Transmitter Division Recorder Indicator Range LT52-140A I -

LI52-140A 0 - 50" LT52-1408 II -

LI52-140B 0 - 50" The display instruments (indicators) are located on the main control

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board and are marked with yellow mylar strips for ease of recognition as post-accident instrumentatio The above instrument loops were found to be properly calibrated as evidenced by the calibration records. The inspector reviewed the associated documents identified in Appendix A and did not identify any deficiencies. Table 7.5-3 shows the instrument range to be 0 - 30" versus the actual instru-ments range of 0 - 50" The licensee expla.ined that the discrepancy is the result of a recent modification which increased the range from 0 - 30" to 0 - 50". The FSAR will be updated accordingl .6 Suppression Pool Water Temperature Regulatory Guide 1.97 classifies the suppression pool water temperature as a Category 2 va ':ble. However, the licensee has specified it to be a Type A variable. Therefore, the instrumentation is required to conform to the Category 1 criteria. The monitoring of this variable is performed by the following two channels of instrumentation, each comprising eight (8) temperature sensing elements:

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l Power Sensor Division Recorder Indicator Range TI41-101A/H I -

TI41-101 30 F-230*F-TI41-103A/H II -

TI41-103 30 F-230 F

, The temperature indicato'rs are located on the main control board

) and are marked with yellow mylar strips' for ease of identification as

!. post-accident instrumentation. They are digital type and receive their input from electronic units (TIX41-101 & 103).which are capable of providing the average temperature of the suppression pool as well as the individual temperature of each suppression pool zone monitore The instrument loops were found to be properly calibrated'as evidenced by the calibration records. The inspector reviewed the. associated documents listed in Appendix A and did not identify any deficiencie .7 Isolation Devices Where a Category 1 signal is used as input to a non-Category 1 system, Regulatory Guide 1.97 specifies the use of isolation devices which are fully qualified for use in ' Category 1 circuit The inspector examined the circuits involved and found that the isolation as well as the separation criteria had been properly l implemented. In particular, the inspection revealed that: All of the above loops provide an input to a non-safety-related plant computer. In this case the. isolation function is l performed by a Category 1 multiplexe The hydrogen / oxygen analyzers and the suppression pool tempera- )

ture monitoring system provide inputs to the non-safety-related annunciator system as well as the computer. The input to the annunciator is isolated from the safety-related signal using a coil to contact separation with Category 1 relays. The' relays used in the hydrogen and oxygen analyzing equipment are Potter-Brumfield Model KRP. The relays in the suppression' pool ]

temperature monitoring equipment are circuit board type supplied by Simmonds Precision. -These two types of relays are considered to be acceptable devices for signal isolatio .0 Physical Inspection The inspector performed a physical inspection of display instruments located in the cont ol room, and local instruments located in various areas of the Reactor Building. For the display instruments (indicators and recorders), the inspector verified instrument function, instrument range and the yellow marker identificatio For the local mounted instru- ;

ments, the inspector verified instrument mounting and supports, separation of cable routing and instrument tubing for redundant instrument channel .I

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I During this physical inspection while in room 118 in the Reactor 1 Building, the inspector noticed that: 1) the high pressure impulse lines !

of the two redundant suppression pool level transmitters (LT52-140A an LT52-1408) share the same pressure tap (1" pipe) from the suppression pool clean-up suction line; and, 2) all four impulse lines of these two transmitters were routed together.along a wall.' RG 1.97, Revision 2, paragraph 1.3.lb states in part that "no single failure within either the -

accident monitoring instrumentation, its auxiliary supporting features...

should prevent the operators from being presented the information neces-sary for them to determine the safety status of the plant..." The inspector questioned the ability of these transmitters to meet the single failure criterion. The inspector reised a third concern that debris or I sediment may build up in the suppression pool cleanup suction line (elevation below the bottom of suppression pool) and clog the transmitter pressure ta Following the completion of this inspection, on January 27 and January 30, 1989, the licensee transmitted to the NRC their response to the above issues. The licensee responses are discussed as follows:

l 1) Only One Tap For Both Instrument Channe The licensee stated that

' the 6-inch and 1-inch piping between the containment penetration and the isolation valves is ASME B&pV Code Section III, Class 2 piping, designed to seismic Category I criteria. This piping is designed to the "no break" stress criteria of FSAR section 3.6.1.2, such that cracks in the piping need not be assume The containment boundary is considered to be extended to the isolation valves for the two transmitters. The inspector has no further questions regarding this issu ) Instrument Impulse Lines Of Both Channels Routed Together. The licensee stated that the room where these instrument lines are located was identified as a non-hostile area. Therefore, protection against high energy line breaks, missiles, and load handling hazards, is not required. The licensee defined hostile areas as those areas th. t are subject to the effects of missiles (from certain !

rotating equipment or load handling devices) or high energy line I breaks. In addition, nothing is installed above the redundant instrument piping / tubing which would'present a hazard to i The j inspector has no further questions regarding this issu ) possible Clogging Of Instrument Tap Due To Debris or Sediment Accumulatio The licensee stated that they had surveyed the quality of water taken from the Limerick 1 suppression pool. The results indicated the presence of ionic (dissolved) impurities, rather than suspended material. Therefore, no significant buildup of solid matter is expected in the lines connecting to the level l

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transmitter Furthermore, the 1-inch instrument piping connection ,

to.the 6-inch cleanup line is on the side of the pipe;at 90 . There -

fore, solid material is not expected to accumulate in the 6-inch line in sufficient quantity to plug the branch connection.to the level instruments. While there may be some accumulation of insulatio debris in the suppression pool post-accident, most of the heavier

material wil! settle out on the drywell floor and.not be carried over l to the suppression' pool. Because the' remaining material.is light and because of the. turbulence in the pool post-accident, most of the l material will tend to float or remain in suspension. Therefore, blockage of the line to the extent that the differential pressure

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transmitters could be affected is not deemed credible.

( The inspector has no further question regarding this issue,.

l 6.0 Surveillance, Testing and Calibration Limerick Unit 1 employes a computerized data base for instrument calibratio Part of the function of this data base is to generate the repetitive main-tenance task orders for recalibration-of instruments and-to provide a historical record of instrument calibratio The inspectors reviewed the data base for the instruments inspected, the frequency of calibration, and the date that calibration is next du Verification was made to determine that procedures are in place for the performance of the calibration. The maintenance and calibration data for Limerick Generating Station, Unit No.1 instrumentation for the inspected variables are found in Appendix B. No abnormalities were note .0 Status of Previr.usly Identified Items

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(Closed) Violetion 50-352/88-02-02 pertaining to 10 CFR 30 Part 21 requirements r t being specified in EQ p mcurement documents. The licensee's corrective action for this viulation was to revise procec:ure E-1415, " Field procurement of Q listed components for field' modification and replacement," to require AMP PIDG terminal and butt' splice procure- i ments to include the requirements of 10 CFR Part 21. Implementation of the revised requirements for the applicable procurement will. prevent future non-compliance. The inspector reviewed the revised procurement procedure .

E-1415 (dated August 1988) and verified the inclusion of Part 21 require- i ments. This item is close (Closed) Violation 50-352/88-02-03 pertaining to the environmental qualification of Rockbestos Coaxial Cable and Special Multiconductor

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Cable. This violation was a result of certain technical documentation not being included in the controlled EQ package at the time of the inspection. PECo procedure II-6.2 " Procedure for the Control of Environ- i mental Qualification Documentation for Nuclear Plant Class IE Equipment" t

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did not adequately address the review of vendor test reports and the subsequent up-date of environmental qualification packages. As a result, the Rockbestos test which addressed the concerns of NRC Information Notice IN-84-44 were not included in the EQ packag PEco's corrective action for this violation was to include Rockbestos test reports QR-5804 in'their'EQ package No. 22. QR-5804 constitutes a valid equipment qualification test report. This test report was included-in the revised EQ package in July,198 To avoid future non-compliance, PECo Procedure EE-6.2 was revised and issued on June 22, 1988. The revised procedure addresses the review and inclusion of updated vendor test reports in EQ packages. The revision of EE-6.2 and the inclusion of the Rockbestos test reports in the EQ package achieves full compliance. Therefore, this item is considered close (Closed) Violation 50-352/88-02-04 pertaining to the environmental qualification of Rockbestos 600V cable This item is similar to violation 88-02-03 above. The licensee revised procedure EE-6.2 and included Rockbestos test report QR-5805 which constitutes a valid test report in their EQ package No. 24. The inspector considered these cor-rective actions adequate and this item is close [_ Closed) Violation 50-352/88-02-05 pertaining to the environmental qualification of Rockbestos thermocouple extension cables. This item is similar to violation 88-02-03 above. The licensee revised procedure EE-6.2 and included Rockbestos test report QR-6802 which constitutes a valid test report in their EQ package No. 25. The inspector considered these corrective actions adequate and this item is close { Closed) Violation 50-352/88-02-01 regarding the environmental quali-fication of unidentified cable splices in the Standby Gas Treatment System area. In response to NRC's findings, the licensee addressed in his letter dated February 29, 1988, that the subject splices were not splices for.the conductors, rather splices for the drain wire only. This issue is no longer considered to be a violation. No corrective actions were require This item is close {0 pen) Violation 50-352/88-02-06 regarding the environmental. qualification of AMP butt splices. At the time of the close out inspection, the AMP splice EQ package # 194 was not yet complete. The EQ package was still under reviewed by Bechtel for PEco. PECo stated that EQ package No. 194 will be completed in early April 1989. Because this EQ package was not yet complete this item remains open until the EQ package has been completed by the licensee and reviewed by the NRC,

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l 8.0 Exit Meeting The inspector met with licensee representatives (denoted in Details, paragraph 1.0) at the conclusion of the inspection on January 20, 198 j The inspector summarized the scope of the inspection, the inspection findings and confirmed with the licensee that the documents reviewed by the inspectors did not contain any proprietary information. The licensee agreed that the inspection report may be placed in the Public Document Room without prior licensee review for proprietary informatio I i

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Appendix A Documents Reviewed During This Inspection DOCUMENT N DOCUMENT TITLE Reactor Water Level 8031-M-42 SH 1 of 4 Nuclear Boiler P&ID 8031-QAD-M-42 Sh 1 QAD Es31-M-888 SH6, 7, 9 & 10 Loop Diagram 8031-M-1-H12-1090-E00 Loop Diagram Power Dist. Sy M-1-821-1090-E-15.12 NSSS System 8031-M-1-821-1090-E-005.20 NSSS System 8031-M-1-E11-1040-E-012.24 RHR System 8031-M-1-E11-1040-E-013.32 RHR' System 8031-M-1-E32-1050-E-7.12 MSIV Leakage Control 8031-E-15~ Single Line Diag - 4KV Power Sy E-28 Single Line Diag Load Ctrs, 8031-E-30 Sh. 3 of 3 Single Line Instr. AC Sys V8031-E-33 Sh1 & 2 of 3 Single Line Diag-125 VDC ST-2-042-463-1 Calibration / Functional Test Pro ST-2-042-464-1 Calibration / Functional Test Pro MRF#8780972 Maintenance Request Form MRF#8780973 Maintenance Request Form- Reactor Coolant Pressure 8L41-M-42 Sh. 1 of 4 Nuclear Boiler P&ID 8031-QAD-M-42 Sh I QAD 8031-M-888 Sh 6, 7, 9&10 Loop Diagram 8031-M-1-H12-1090-E-003.14 Loop Diagram Power Dist. Sy M-1-821-1090-E-005.20 NSSS System 8031-M-1-B21-1090-E-15.12 NSSS System 8031-M-1-E21-1040-E-015.13 Core Spray System 8031-M-1-E32-1050-E-7.12 MSIV Leakage Control 8031-E-15 Single Line Diag. - 4KV Pwr Sy E-28 Single Line Diag. - Load Ctrs, 440V 8031-E-30 Sh 3 of 3 -Single Line Diag. - AC System 8031-E-33 Sh 1 of 3 Single Line Diag. - 125 VDC ST-2-042-461-1 Calibration / Functional Test Pro ST-2-042-462-1 Calibration / Functional Test Pro C. Primary Containment & Drywell Pressure 8031-M-42 Sh 1 of 4 Nuclear Boiler P&ID 8031-QAD-M-42 Sh 1 QAD 8031-M-1-H12-2040-E-25 Nuclear Boiler Vessel Inst M-888 Sh 24 Loop Diag. Misc. Core Spray 8031-M-1-H12-1090-E-003.14 Loop Diag. Power Dist. Sy M-57 Sh 1 & 2 of 6 P&ID 8031-QAD-M-57 Sh 1&2 QAD M-1-E12-2040-E-9 Containment Atm. Control 8031-M-1-E32-1050-E-7.12 MSIV Leakage Control

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Appendix A 2 DOCUMENT N DOCUMENT TITLE 8031-E-15 Single Lin'e Diag. - 4KV Pwr Sys 8031-E-28 Single Line Diag. - Load Ctrs, 440V l 8031-E-30 Sh 3 of 3 Single Line Diag. - AC System '

8031-E-33 Sh 1 of 3 Single Line Diag. - 125 VDC Containment & Drywell H2/02 Concentration 8031-M-57 Sh 1, 2 &3 of 6 Containment Atmosphere Control P&ID 8031-QAD-M-57 Sh 1, 2, & 3 QAD 8031-M-235-26 Sh 1 thru 10 Delphi Industries Wiring. Dia E-386 Sh I & 2 of 2 Schem. Diag.-H2/02 Analyzer Pk E-28 Single Line Diag. - Load Ctr, 440V 8031-E-15 Single Line Diag. - 4KV Pwr System 8031-E-26 Single Line Dia VAC Pwr Supply ST-2-057-403-1 Qualibration Test Procedure Suppression Pool Water Level 8031-M-52 Sh 1 of 4 Core Spray P&ID-8031-M-55 Sh 1 of 2 High Pressure Coolant In,1ection P&ID 8031-M-57 Sh 1 of 6 Containment Atmosphere P&ID 8031-QAD-M-52 Sh I QAD 8031-QAD-M-55 Sh 1 QAD 8031-QAD-M-57 Sh 1 QAD 8031-M-888 Sh 7, 23&24 Loop' Diag - Misc Core Spray 8031-E-684 Sh 1 of 2 Schem. Diag - NSSS Syst Mis !

8031-M-1-H12-1090-E-003.14 Loop Diag. Power Dist. System 8031-M-1-E-21-1040-E-015.30 Core Spray System 8031-M-1-E32-1050-E-7.12 MSIV Leakage Control 8031-E-15 Single Line Diag. - 4KV Pwr Sys 8031-E-28 Single Line Diag. - Load Ctrs, 440V 8031-E-30 Sh 3 of 3 Single Line Diag. - AC System 8031-E-33 Sh 1 of 3 Single Line Diag. -.125VDC ST-2-052-400-1 Div I, Channel A Calibration Procedure ST-2-052-401-1 Div II, Channel B Calibration Procedure Suppression Pool Water Temperature l 8031-M-41 Sh 2 of 6 Nuclear Boiler P&ID 8031-QAD-M-41 Sh 2 QAD '

8031-M-888 Sh 29 & 30 Loop Diag. - Misc. Nuclear Boiler 8031-E-694 Schem. Diag. - Suppr. Pool Temp 8031-E-15 Single Line Diag - 4KV Pwr Syst 8031-E-28 Single Line Diag - Load Ctrs. 440V 8031-E-30 Sh 3 of 3 Single Line Diag - AC System 8031-M-263-2-1 Simmonds Prec. - Regts for SPOTMOS 8031-M-263-11-6 Simmonds Prec. - User's Manual for SPOTMOS ST-2-041-400-1 Calibration / Functional Test Procedure ST-2-041-401-1 Calibration / Functional Test Procedure L_ __ _ _ _ _ _ _ _

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Appendix A 3 Miscellaneous Surveillance Test Master File Dump - Unit 1, dated 1/16/89 EQ Master List & SCEW Sheets QA Master List EQPT Qualif Package Status Summary, dated 10/28/88 List of Devices Assoc. with RG 1.97, dated 1/18/89 Seismic Qual. Reevaluation for CR Panel H12-P60-FSAR Tables 7.5 , -2, -3, -4 & -5 FSAR Question 421.26 Response Page 421.26-1 & -2 l

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Appendix B Maintenance & Calibration Data Last Next Calibration Calibration Instruments Frequency Date Date Reactor Water Level LT-42-115A 18M 11/19/88 6/20/90 LT-42-1158 18M 12/15/88 6/16/90 LT-42-IN085A 18M 5/21/87 LT-42-IN0858 18M 5/21/87 Reactor Coolant Pressure PT-42-103A 18M 11/20/88 5/22/90 PT-42-103B 18M 12/19/88 6/20/90 Containment and Drywell Press PT-42-101 18M 12/01/88 4/12/90 PT-57-101 IBM 12/6/88 4/20/90 Containment and Drywell H2/02 Analyzers AIT-57-151 3M 12/1/88 2/21/89 AIT-57-188 3M 11/29/88 3/01/89 AIT-57-150 3M 12/1/88 2/21/89 AIT-57-187 3M 11/29/88 3/01/89 Suppression Pool Water Level LT-52-140A 18M 9/7/88 3/5/90 ;

LT-52-140B 18M 9/12/88 3/8/90 )

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TIX-41-101 18M 1/7/89 7/9/90 TIX-41-103 18M 1/8/89 7/10/90 i

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