IR 05000312/1988027

Insp Rept 50-312/88-27 on 880912-16.No Violations Noted. Major Areas Inspected:Licensee Conformance W/Rev 3 to Reg Guide 1.97.Rept Addresses & Closes Sims Issue Number 67.3.3

ML20207L155
Person / Time
Site:	Rancho Seco
Issue date:	09/30/1988
From:	Jim Melfi, Richards S NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION V)
To:
Shared Package
ML20207L150	List: IR 05000312/1988027 ML20207L148
References
RTR-REGGD-01.097, RTR-REGGD-1.097 50-312-88-27, GL-82-33, NUDOCS 8810170213
Download: ML20207L155 (15)

Text

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U. S. NUCLEAR REGULATORY COMMISSION t

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Report N /88-27 P Docket N i

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License N DPR-54 Licensee Sacramento Municipal Utility District P. O. Box 15380 Sacramento, /:alifornia 95813  !

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Facility Name Rancho Le eo Nuclear Generating Station j Inspection Conducted

September 12-16, 1988 i Inspector , e 7. /N[M' / 9 [ !

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. F. Melfi, Reackdr ,3dspector >

D(eSpned Other a s panying personnel:

Alan C. Udy. NRC Contractor, INEL Approved By: 89 __9 OS Daf.e signed S. A. Richards, Chief. Engineering Section [

Inspection Sumunary: l t

, , Inspection During the Period of September 12 - September 16, 1988 (Inspection {

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Report 50-312/88-27J [

i Areas Inspected: A special, announced inspection by a regional based l inspector and a NRC contractor, to assess the licensee's conformance to l Regulatory Guide .97, revision The inspection procedures used were 30703 i and 2558 l

Safety Issue Management System (SIMS) Items:  !

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• - This report addresses and closes SIMS issue number 67.3.3, "Improved i Accident Monitoring". t

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-2-Results:

- General Conclusions arid _ Specific Findings The licensee was found to meet the requirements of Regulatory Guide 1.97 .

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and commitments made to the NRC fer Regulatory Guide 1.97. Items still to be implemented were in the licensee's tracking system, and were on schedule er be complete Significant Safety Matters: None

- Summary of Violations: None

- Open Items Summary:

There are three items that will be followed up or are unresolve ,

(1) The licensee had not explicitly identified the instruments used to monitor the status of standby power. The licensee will identify the specific instruments and the inspection will be completed for this i variabl l (2) The licensee monitored the 2 class 1E indications of Condensate '

Storage Tank level with 2 different units of measurement (Kilo gallons and feet). The licensee agreed to change the readout to be consisten :

(3) The steam generator pressure instruments were found to be within the Technical Specification calibration interval of 18 months, but certain licensee cciculations for these instruments implied that a calibration interval of 12 months was needed to account for instrument drif If the 12 month calibration interval is correct, the instruments were out of calibration by approximately 3 months and the technical specification needs to be change !

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I DETAILS Persons Contacted

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Licensee Personnel

• B. Croley, AGM, Technical Services  !

• G. Legner, NRC Inspection Coordinator

'*D. Proach, I&C Engineer

• H. Heckert, Quality Assurance Auditor

• D. Tipton, Supervisor of Projects and Procedures

• R. Dobson, I&C Maintenance Deputy Superintendent

• Delenzenski, Regulatory Coordination Supervisor

• Williams, I&C Supervisor

• C, Linkhart, I&C Maintenance Supervisor C. Guico, I&C Engineer R. Pate, I&C Engineer i l P. Johnson, Electrical Engineer j

USNRC

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• C. Myers, Resident Inspector

• Denotes those attending the final exit meeting on September 12, 1988.

The inspectors alsc contacted licensee operators, engineers, technicians, and other personnel during the course of the inspectio . Introduction L

The purpose of this inspection was to compare the installed plant instrumentation with the licensee's commitments to the NRC, as contained in correspondence related to Post-Accident instrumentation and as described in the NRC Safety Evaluation Report (SER). This inspection also assessed if r the instrumentation meets the criteria specified in Regulatory Guide 1.97, revision 3. Some of the' references used to assess the licensee's conformance to Regulatory Guide 1.97 were Regulatory Guide 1.97, Revision 3, "Instrumentation for Light Water Cooled Nuclear Power Plants to Assess Plant and Environs Conditions i During and Following an Accident."

Safety Evaluation Report as noted in a letter dated September 17, 1987, Kalman to Andognini with Technical Evaluation Report (TER)

prepared for the NRC by EG&G Idaho Inc. , "Conformaace to Regulatory .

Guide 1.97 Rancho Seco, Rev. 2," Harch 1987, EGG-EA694 NUREG 1286, "Safety Evaluation Report related to the restart of l Rancho Seco Nuclear Generation Station, Unit 1, following the event i

t of December 26, 1985," October 1987.

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NUREG 1286, Supplement Number 1 "Safet/ Evaluation Report related to I the restart of Rancho Seco Nuclear Generation Station, Unit 1, [

following the event of December 26, 1985," March 198 The Code of Federal Regulations (CFR) contains requirements for ,

post-accident instrumentation at Nuclear Power Plants. The General Design a Criteria (GDC) f rom appendix A of 10 CFR 50 which are most applicable to  !

post-accident instrumentation are GDC 13 "Instrumentation and Control",  !

GDC 19, "Control Room", and GDC 64, "Monitoring Radioactivity Releases."

GDC 13 includes a requirement that instrumentation be provided to monitor variables and systems over their anticipated ranges for accident conditions [

to ensure adequate safet GDC 19 includes a requirement that a control room be provided to maintain the nuclear power unit in a s.nfe condition ,

under accident conditions, including a Loss-of-Coolant Accident (LOCA), and  !

that necessary instrumentation be provided at appropriate locations outside i the control room with a design capability for prompt hot shutdown of the *

reactor. GDC 64 includes a requirement that a means be provided for .

monitoring the reactor containment atmosphere, spaces containing components I for recirculation of LOCA fluid, effluent discharge paths and the plant i environs, for radioactivity that may be released from postulated accident [

t l Additionally, the NRC issued Generic Letter 82-33, which contained  !

supplement I to NUREG-0737 and specified requirements regarding emergency ,

response capability. This supplement discuss-d in part, the application of l

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l Regulatory Guide (RG) 1.97 to the emergency response facilities, including I the Control Room (CR), Technical Support Center (TSC), and the Emergency  ;

Operations Facility (EOF) at nuclear power plant The licensee's response to RG 1.97 was provided to the NRC in letters dated September 14,  !

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1983, July 13, 1984, September 14, 1984 July 9, 1985, September 30, 1985,  !

l October 31, 1985 January 13, 1986, March 30, 1987, December 23, 1987, and i March 31, 198 !

l The NRC issued an order dated February 21, 1984 to implement Regulatory f Guide 1.97 as based on a submittal to be provided by September 15, 198 l This schedule was provided by the licensee on September 14, 1984. The NRC  !

also requested additional information on 11 items from the licensee in a f letter dated August 19, 1985, Stolz to Rodriguez. The licensee responded to this request for additional information (RAI) in their October 31, 1985  :

lette The licensee does not have many meters or recorders for instrumentation  !

displayed in the control room. The licensee relies on the Cafety Parameter Display System (SPDS) for most of the indication of post-acc. der' . [

instrumentation. The SPDS redundancy, isolation, power sources en- i qualification were reviewed by the NRC technical staff and docume .cd ip  ;

NUREG-1286 and NUREG 1286, Supplement 1. The technical staff , apted the  ;

SPDS in these reports as fully qualified to class 1E requir' , ants. The j SPDS also can trend, record, and display the informatio to the operator l The class 1 and 2 ir Heations displayed on the SPDS at Rancho Seco for  !

Regulatory Guide 1.97 variables is considered an acceptable method for l display of the variable (

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In general, the inspection verified that the licensee had documentation l onsite that showed the redundancy, physical and electrical separation,  ;

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power sources and interfaces for the instrumentation. The equipment lists were reviewed for the variables selected, to ascertain whether the instrumentation had been evaluated and tested to the appropriate environmental, seismic, and quality assurance (QA) requirements. The environmental qualification (EQ) requirements are tabled below for the instruments by showing the EQ listing or the environment that the component is located in. A mild environment does not need any special qualification. The seismic file listing shown in the tables notes the seismic class I file that the instrument was qualified by. Instruments classified as category 2 do not need any special seismic qualificatio Regulatory Guide 1.97 divides post-accident instrumentation into three categories and five types. The three categories are noted as 1, 2, and Category I requirements for instrumentation are essentially class IE, and include full separation, qualification, redundancy, and power from class IE buses. Category 2 instra Station needs some qualification, but does not need full qualification. Category 3 requirements are the least stringent, essentially commercial grade. The five types of instrumentation identified in RG 1.97 are types A, B, C, D, and E. Type A are plant specific and classified by the licensee; type B variables provide information to indicate that plant safety functions are being accomplished; type C variables provide information on the breach of barriers for fission product release; type D variables indicate the operation of individual safety systems; and type E variables are those that indicate and determine the magnitude of the release of radioactive materials. Each variable type can be of any category, except for type A, which can only be category The specific information on the instrumentation inspected is discussed in section This inspection focused on category 1 and 2 variables, without any radiation monitoring instrumentation reviewed. Except as noted, the requirements for this instrumentation were me . Inspection _ Details The inspectors held discussions with various members of the licensee's staf f, examined drawings, performed selected system walkdowns, and toured the control room, to assess the implementation of the commitments delineated in the Itcensee's response to RG 1.97, revision The following instrumentation was examine .1 Auxiliary Feedwater Flow Regulatory Guide 1.97 classifies this as a Category 1 variable. In addition, the licensee classifies this variable as Type A. This instrumentation is used to monitor the availability of the auxiliary feedwater system as a heat sink. There are two transuitters and two square root converters per channel. The composite signals are recorded on the qualified Safety Parameter Display System (SPDS). The low-range transmitters are an expanded scale (for greater accuracy). The comparator passes the greater accuracy signal at low flows and passes the hi-range signal beyond 7.07 milliamps. The transition between these two signals is said to be bumples Information on the auxiliary feedwater flow instrumentation is as follow _ - . _ _ - -

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Tag EQ Seismic Power Instrument Number Function Listed Listed Circuit Range FT-31802 Transmitter (hi) E-0255 SQ-075 S1B -- '

FY-31802 Square Root Mild SQ-027 SIP --

FT-20504 Transmitter (low ) E-0255 SQ-075 SIB -- I FY-20504 Square Root Mild SQ-027 SIB --

FY-20504A Comparator Hild SQ-027 S1B SPDS 0 to 1300 gpm FI-31802 Indicator Hild SQ-062 SIB 2 0 to 1300 gpm

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FT-31902 Transmitter thi) E-0255 SQ-075 SIB --

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FY-31902 Square Root Mild SQ-027 SIB --

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FT-20502 Transmitter (low) E-0255 SQ-075 S1B --

FY-20502 Square Root Mild SQ-027 S1B -- '

FY-20502A Comparator Hild SQ-027 SIB SPDS 0 to 1300 gpm ,

FI-31902 Indicator Mild SQ-062 S1B2 0 to 1300 gpm PT-31803 Tratsmitter (hi) E-0255 SQ-075 SIA --

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FY-31803 Square Root Mild SQ-027 SIA --

FT-20501 Transmitter (low) E-0255 SQ-075 SIA -- l FY-20501 Square Root Mild SQ-027 SIA --

FY-20501A Comparator Hild SQ-027 SIA SPDS 0 to 1300 gpm FI-31803 Indicator Hild SQ-062 S1A2 0 to 1300 gpm FT-31903 Transmitter (hi) E-0255 SQ-075 SIA --

FY-31903 Square Root Hild SQ-027 SIA --

FT-20503 Transmitter (low) E-0255 SQ *,15 SIA --

FY-20503 Square Root Hild SQ-027 SIA --

FY-20503A Comparator Mild SQ-027 SIA SPDS 0 to 1300 gpm FI-31903 Indicator Mild SQ-062 SIA2 0 to 1300 gpm Inspe_ tion Findings  ;

The inspectors found that the instrumentation supplied for this variable meets the Category I recommendations specified in Regulatory Guide 1.97 and is, therefore, acceptabl i Condensate Storage Tank Level I f

Regulatory Guide 1.97 classifies this as a Category 1 variable. In i addition, the ifcensee classifies this variable as Type This instrumentation is used to ensure the availability of the primary water  !

supply for auxiliary feedwater. The signals are indicated and recorded on  !

the SPDS. Information on the condensate storage tank level transmittera '

is as follow ;

Tag EQ Seismic Power Instrument Number Function Listed Listed Circuit Range *

LT-35809 Transmitter Mild SQ-075 SIA SPDS 0 to 450,000 ga LT-35810 Transmitter Mild SQ-075 SIB SPDS 0 to 50 f Inspection Findings l

The inspectors found that the instrumentation supplied for this variable l meets the Category 1 recommendations specified in r.cgulatory Guide 1.97 -

and is, therefore, acceptable. The inspector. nr.ced that channel 35809  ;

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. s displayed in gallons while redundant channel 35810 displayed in :tee This could cause confusion should one channel of the two redundant channels (as recommended for Category 1 Type A variables) become inoperative. This is discussed further in paragraph .3 Containment Sump _ Water Level Regulatory Guide 1.97 recommends Category I wide-range instrumentation and Category 2 narrow-range instrumentation for this variable. In addition, the licensee classifies the wide-range instrumentation as Type A. The narrow-range signals are displayed and recorded on the SPDS, and alarmed  ;

at the three foot level. The wide-range instruments measure over the range of zero (containment floor) to ten feet in the containment. The narrow-range instruments measure f rom zero (sump bottom) *.o 5 feet. The narrow-range and wide-range instrument ranges do not overlap. The wide-range signals are also displayed and recorded on the SPD Information on the containment sump water level instrumentation is as follow Tag EQ Seismic Power Instrument Number Function Listed Listed Circuit Range LE-20509A/B Sensor (wide) E-0263 SQ-091 -- --

LIT-20509 Transmitter Mild SQ-091 S1A2 SPDS 0 to 10 f LE-26112C Sensor (narrow) E-0263 N/A -- --

LSH-26112C Comparator Hild N/A SIA2 Alarm 0 3 f SPDS 0 to 5 f '

LE-20510A/B Sensor (wide) E-0263 SQ-091 -- --

LIT-20510 Transmitter Hild SQ-091 S182 SPDS 0 to 10 f LE-26112D Sensor (narrow) E-0263 N/A -- -- l

, LSH-26112D Comparator Hild N/A SIB 2 Ala rm @ 3 f !

SPDS 0 to 5 f Inspection Findings i

The inspectors found that the instrumentation supplied for the wide-range i sump level meets the Category I recommendations specified in Regulatory Guide 1.97 and that the instrumentation supplied for the narrow-range sump ,

Icvel instrumentation meets the Category 2 recommendations specified in Regulatory Guide 1.97. Therefore, the instrumentation supplied for this variable is seceptabl .4 Containment Hydrogen Concentration L

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Regulatory Guide 1.97 recommends Category 1 instrumentation for this variabl In addition, the licensee classifies this variable as Type This instrumentation provides long-term surveillance of the containment ,

for potentially explosive concentrations of hydrogen and aids in the  ;

determination that accident mitigation is being successfully accomplishe ,

The signals are indicated and recorded on the SPDS. Information on the I containment hydrogen concentration instrumantstion is as follow F i

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Tag EQ Seismic Power Instrument Number Function Listed Listed Circuit Range

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AE-53811 Sensor E-0271 SQ-073 -- --

'AT-53811 A/B Analyzer Mild SQ-073 S2A1 SPDS 0 to 10% +

AE-53812 Sensor E-0271 SQ-073 -- --

AT-53812 A/B Analyzer Mild SQ-073 S2B1 SPDS 0 to 10%

Inspection Findings The inspectors found that the instrumentation supplied for this variable meets th= Category 1 recommendations specified in Regulatory Guide 1.97 p

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and is, therefore, acceptabl !

3.5 Containment Pressure ,

Regulatory Guide 1.97 recommends Category 1 instrumentation for this variabl In addition, the licensee classifies this variable as Type The licensee uses this instrumentation to determine the need to terminate or to re-initiate safety features that affect containment conditions. The signals are indicated and recorded on the SPD Information on the containment pressure instrumentation is as follow Tag EQ Seismic Power Ins t rument Number Function Listed Listed Circuit Range l PT-53621 Transmitter E-0253 SQ-075 SIA SPDS -5 to 180 psig ,

l PT-53622 Transmitter E-0255 SQ-075 CIB SPDS -5 to 180 psig 1 i Inspection Findings l l The ir.spectors found that the instrumentation supplied for this variable I meets the Category I recommendations specified in Regulatory Guide 1.97 and is, therefore, acceptabl .6 Pressurizer Level

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Regulatory Guide 1.97 reccamends Category 1 instrumentation for this i variabi In addition, the licensee classifies this variable as Type The licersee uses this instrumentation to determine the need to terminate ,

[ or to re-initiate safety injection and to determine the emergency  ;

I procedures to be used. The level is also indicated and recorded on the (

i SPD Information on the pressurizer level is as follow l t

l Tag EQ Seismic Power Instrument Number Function Lister Listed Circuit Range LT-21503A Transmitter E-0256 SQ-075 SIA SPDS 0 to 320 in, j LY-21503A !solator Hild SQ-040 SIA --

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LT-21503B Transmitter E-0256 SQ-075 S1A SPDS 0 to 320 i l LY-21503B Isolator Mild SQ-040 SIA --

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LT-21503C Transmitter E-0256 SQ-075 SIB SPDS 0 to ?20 i LY~21503C Isolator Mild SQ-040 SIB --

LI-21503F Indicator * lilld SQ-062 -- O to 320 i l

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LR-21503 Recorder * Mild SQ-062 SlJ 0 to 320 i s i Manually switched to display / record one output of the three isolator !

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Inspection Findings ,

The inspectors found that the instrumentation supplied for this variable meets the Category I recommendations specified in Regulatory Guide 1.97 and is, therefare, acceptabl .7 Reactor Coolant, System Hot Leg Water Temperature _

Regulatory Guide 1.97 recommends Category 1 instrumentation for this variabl In addition, the licensee classifies this variable as Type The licensee uses this instrumentation, in part, to ensure the proper cooldown rate and to monitor system temperature. The signals are indicated and recorded on the SPDS. Information on the RCS hot leg water temperature instrumentation is as follow Tag EQ Seismic Power Instrument Number Function Listed Listed Circuit Range TE-21030 RTD E-0252 SQ-092 SIB SPDS 120 to 920 F TE-21033 RTD E-0252 SQ-092 SIA SPDS 120 to 920 F Inspection Findings The insnectors found that the instrumentation supplied for this variable meets the Category I recommendations specified in Regulatory Guide 1.97 and is, therefore acceptabl .8 Reactor Coolant System Pressure Regulatory Guide 1.97 recommends Category 1 instrumentation for this variabl In addition, the licensee classifies this variable as Type This instrumentation is used, in part, to verify the correct relation between system pressure and temperature. The signals are indicated and recorded on the SPD Information on the RCS pressure instrumentation is as follow Tag EQ Seismic Power Instrument Number Function Listed Listed Circuit Range PT-21050 Transmitter E-0285 SQ-075 --

SPDS 0 to 3000 psig PY-21050 Isolator Mild SQ-040 S I B." --

PI-21050 Indleator Hild Isolated SIB 2 0 to 3000 psig PT-21051 Transmitter E-0285 SQ-075 --

SPDS 0 to 3000 psig PY-21051 Isolator Mild SQ-040 SIA2 --

PI-21051 Indicator Mild Isolated SIA2 0 to 3000 psig

_ Inspection Findings The inspectors found that the instrumentation supplied for this variabli meets the Category I recommendations specified in Regulatory Cuide 1.97 and is, therefore, acceptabl _ - - .. - - - _ __ - . - - - - - - - . ..

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Steam Generator Level

{ Regulatory Guide 1.97 recommends Category 1 instrumentation for this variabl In addition, the licensee classifies this variable as Type A.

< The licensee uses this wide range instrum-ntation to determine the availability of the steam generators as heat sinks, to '.erify the adequacy of auxiliary feedwater flow, and to identify steam generator tube rupture event In addition to the control panel indicators, each steam generator level signal is indicated and recorded on the SPDS. Information on the i wide range steam generator level instrumentation is as follow Tag EQ Seismic Power Instrument i Number Function Listed Listed Circuit Range ,

LT-20507A Transmitter OTSGA E-0250 SQ-021 SIA2 SPDS 6 to 619 i !

l L1-20507A Indicator OTSGA Mild SQ-062 SIA2 6 to 619 i ,

LT-20507B Transmitter OTSGA E-0250 SQ-021 S1B2 SPDS 6 to 619 i LI-20507B Indicator OTSGA Mild SQ-062 SIB 2 6 to 619 i !

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LT-20508A Transmitter OTSGB E-0250 SQ-021 SIA2 SPDS 6 to 619 i LI-20508A Indicator OTSGB Mild SQ-062 SIAg 6 to 619 in.

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LT-20508B Transmitter OTSGB E-0250 SQ-021 SIB 2 SPDS 6 to 619 i !

LI-pr;38B Indicator OTSCC Mild SQ-062 S1B2 6 to 619 i i i Inspection Findings 4 The inspectors found that the instrumentation supplied for this variable  ;

i meets the Category I recommendations specified in Regulatory Guide 1.97 i and is, therefore, acceptabl j

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variable; however, the licensee has classified this as a Type A variabl Therefore, the instrumentation provided should be Category 1. The  !

licensee uses this instrumentation to verify the correct pressure in the

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steam generator that is not af fected by a steam generator tube rupture q event and to diagnose the loss of secondary coolant in a tube rupture .

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even In addition to the control panel indicators, the signals are  !

indicated and recorded on the SPD Information on the steam generator

. pressure instrumentation is as follow I a i

) Tag EQ Seismic Power Instrument  ;

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Nunibe r Function Listed Listed Circuit Range i PT-20545A Transmitter OTSGA E-0255 SQ-075 SIA2 SPDS 0 to 1200 psig  :

PI-20545A Indicator MilJ SQ-062 SIA2 0 to 1200 psig  !

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j PT-20545B Transmitter OTSGA E-0255 SQ-075 31B2 SPDS 0 to 1200 psig l PI-20545B Indicator Mild SQ-062 SIB 2 0 to 1200 psig l l i

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PT-20546A Transmitter OTSGB E-0255 SQ-075 S1A2 SPDS 0 to 1200 psig l

PI-20546A Indicator Mild SQ-062 SIA2 0 to 1200 psig l I [

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Tag EQ Seismic Power Instrument Number Function Listed Listed Circuit Range PT-20546B Transmitter OT3GB E-0255 SQ-075 SIB 2 SPDS 0 to 1200 psig PI-20546B Indicator Hild SQ-062 SIB 2 0 to 1200 psig Inspection Findings The inspectors found that the instrumentation supplied for this variable meets the Category 1 secomeendations specified in Regulatory Guide 1.97 and is, therefore, acceptabl .11 Degrees Subcooled Regulatory Guide 1.97 recommendr, Category 2 instrumentation for this varsable. The indication is a computed signal, using the RCS hot leg water temperature and the RCS pressure. In addition to the control panel indicators, the signals are indicated and recorded on the SPD Information on the degrees of subcooling instrumentation is as follow Tag EQ Power Instrument Number Function Listed Circuit Range TE-21029 Hot Leg RTD Tran E-0252 SIA --

TE-21033 Hot Leg RTD Tran E-0252 SIA --

PT-21092 RCS Pressure Trans. E-0267 SIA --

UY-21031 Calculation Module Hild S1A2 SPDS 0 to 200 F UI-21031 Indicator Mild S2A1 0 to 200 F TE-21030 Hot 1.eg RTD Tran E-0252 SIB --

TE-21034 Hot Leg RTD Tran E-0252 SIB --

PT-21042 RCS Pressure Trans. E-0267 SIB --

UY-21032 Calculation Module Hild SIB 2 SPDS 0 to 200 F UI-21032 Indicator Hild S2B1 0 to 200 F Inspection Findings The inspectors found that the instrumentation supplied for this variable meets the Category 2 recommendations specified in Regulatocy Guide 1.97 and is, therefore, acceptabl .12 High Pressure Safety Injection Flow Regulatory Guide 1.97 recommends Category 2 flow instrumentation to i l

monitor the operation of the high pressure injection (HPI) syste Information on the !!PI flow instrumentation is as follow Tag EQ Pcwer Instrument Number Function Lieted Circuit Range FT-23805 Transmitter E-0255 SIA --

FY-23805A Square Root Hild SIA SPD9 0 to 600 gpm FI-23805 Indicator Mild --

O to 500 gpm PT-23806 Transmitter E-0255 SIB --

FY-23806A Square Root Mild SIB SPDS 0 to 600 gpa ,

FI-23806 Indicator Mild -- O to 600 gpm I

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N_ umber Function Listed Circuit Range FT-23807 Trannmitter E-0255 SIA --

FY-23807A Square Root Mild S1A SPDS 0 to 600 gpm i FI-23807 Indicator Mild -- O to 600 gpm i FT-23808 Transmitter E-0255 SIB --

FY-23808A Square Root Mild SIB SPDS 0 to 600 gpm FI-23808 Indicator Mild -- O to 600 gpm l

Inspection Findings  !

i The instrumentation supplied for this variable meets the Category 2 !

l recommendations specified in Regulatory Guide 1.97 and is, therefore, '

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3.14 Law Pressure Safety Injection Flow Flow in Residual (Decay) Heat Removal System  ;

Regulatory Guide 1.97 recommends Category 2 flow inrtrumentation to *

monitor the operation of the low pressure injection (LPI) and the residual (decay) heat removal (DHR) systems. At Raacho Seco, low pressure l

injection is a function of the DHR system, and the same instrumentation is I

applicable to both of these variables. Information on the DHR flow l instrumentation is as follow !

i Tag EQ Power Instrument 1 Ntunbe r Function Listed Circuit Range FT-26003 Transmitter E-0255 S1A --

FY-26003 Square Root Mild SIA SPDS 0 to 5000 gpm [

FI-26003 Indicator Mild --

O to 5000 gpm !

FT-26004 Transmitter E-0255 SIB --

i FY-26004 Square Root Mild SIB SPDS 0 to 5000 gpm l FI-26004 Indicator Mild --

O to 5000 gpm i Inspection Findings  !

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i recosm.endations specified in Regulatory Guide 1.97 and is, therefore, i l acceptable.

l 3.14 Primary System Safety Relief Valve Position

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I Regulatory Guide 1.97 recommends Category 2 instrumentation to monitor the position of these valves for the possible loss of primary coolant. The i

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licensee's instrumentation monitors flow through the valve tailpipes by l

) way of accelerometers. There are two channels of instrumentation for each !

i of the three valves. Both channels are indicated and recorded on the :

j SPDS. One channel for each valve is also indicated on the control panel l in volt Information on the primar" system ssfety relief valve position !

.' instrumentation is as follow j l Tag EQ Power Instrument Number Function Listed Circuit Range t

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AE-21520 Accelerometer E-0258 -- --

I XY-21520 Charge Amplifier E-0258 SIB 3 SPDS 0 to 100% flow f i

XI-21506 Indicator Mild SIB Volts l

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Tag EQ Power Instrument Number Function Listed Circuit Range XE-21521 Accelerometer E-0258 -- --

XY-21521 Charge Amplifier E-0253 S1A3 SPDS G to 100% flow XE-21522 Accelerometer E-0258 -- -~

XY-21522 Charge Amplifier E-0258 S1B3 3PDS 0 to 100% flow XI-21507 Indicator Mild SIB Volt 3 XE-21523 Accelerometer E-0258 -- --

XY-21523 Charge Amplifier E-0258 SIA3 SPDS 0 to 100% flow XE-21524 Accelerometer E-0258 -- --

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XY-21524 Charge Amplifier E-0258 SIB 3 SPDS 0 to 100% flow XI-21511 Indicator Mild S1B Volts XE-21525 Accelerometer E 0258 -- --

XY-21525 Charge Amplifier E-0258 S1A3 SPDS 0 to 100% flow i

l Inspection Findings  ;

The inspectors found that the instrumentation supplied for this variable meets the Category 2 recommendations in Regulatory Guide 1.97 and is, therefore, acceptabl .15 Status of Standby Power Regulatory Guide 1.97 recommends plant specific Category 2 instrumentation for this variable. This lastrumentation is used to monitor the operation  ;

of emergency power sources (AC and DC electric, pneumatic, etc.). The '

licensee has not specifically identified which instrumentation it intends f

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to use. This is further discussed in paragraph . Service Testing and Calibration r For the variables selected, the inspectors reviewed the licettee's ,

calibration records to verify that the instrumentation was in calibratio !

The inspectors note that the licensee's program for maintaining this -

calibration is being reorganized. The previous licensee calibration of [

instruments was generally done under generic procedures. The licensee is now generating specific surveillance procedures for many of these  !

instrument Some of the most recent calibrations of these instruments i were done under a generic procedure, and some were under the new l surveillance procedures. The irmpectors found that the instrumentation t selected for review was in calibratio [

t There is a question as to the frequency of calibration for the steam  ;

generator pressure instruments, and this is further discussed in [

paragraph l

! Inspector Observations .

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There are three items that were identified during the inspection that will f require further revie i

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. During the inspection, the inspectors asked to .see the drawings, QA

records and qualification for the instruments used to monitor the i status of standby power variable. This variable provides information to the operator to determine if the emergency AC, DC, air, etc. power sources are available and to monitor these power sources. The

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licensee responded by asking which instruments the NRC wanted to see ,

the drawings and records for. The inspectors responded tnat the '

instrumerts to monitor this variable should have been identified by the license It became apparent that the licensee had not explicitly

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identified the instruments used to monitor the status of standby power variabl t

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The licensee's original submittal to the NRC stated that they cr.mplied with the NRC recommendations for this variable. The inspectors asked ,

the licensee to provide the documentation showing how they complied l with the recommendations of the Regulatory Guide for this variabl i ,

The licensee then provided historical documentation which was a l

summary of all the instrumentation available for monitoring the status of standby power. This document was an internal licensee scoping

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study, which stated that they had the indications available in the

control room, and then listed essentially all the indications i available on the electrical panel. This document concluded that they  ;

I did have adequate instrumentation in the control room. This document 0 did not specifically identify the instruments to be used to monitor

! standby power, although it did have some of the typical instruments j

! used to monitor this variabl P

The licensee had committed to provide Category 2 instrumentation for this variabl The inspectors observed suitable instrumentation in  !

j the control room for the four diesel generators (currents, voltages,  ;

and frequencies). We vere unable to verify that the instrumentation l

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for this variable was included in calibratior and surveillance procedures. The inspectort did not identify any instrumentation in  ;

i the control room to monitor the de power system (battery current,  ;

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battery charger current, and bus voltsge) other than annunciator These annunciators do not appear to meet the intsut of the Regulatory s

Guide to have meters to monitor the status of Standby Power. The use  !

j of these annunciators should be documented in a submittal to NRR to i determine the adequacy of using annunciators for thie purpos .

] The inspectors discussed the identification of instruments for this  !

variable with the licensee. The licensee agreed to identify and I

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document the specific instruments for this variable in a submittal to  !

j NR This documentation will include any commitments to upgrade o i j add instrumentation and verification of calibration and surveillance ,

j procedures. After these specific instruments have been identified,  !

I the calibration records, drawings, and ranges for these instruments  !

will be inspected in a future inspection to determine Regulatory Guide 1.97 compliance (50-312/88-27-01).

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, . The class lE indication of Condensate Storage Tank (CST) level is on 4 the SPDS. There are only 2 class lE readouts of CST level on the SPDS, with different units of measurement (gallons and feet). One measurement is used during certain Emergency Operating Inr.tructions, and the other is used to verify technical specification complianc The regulatory guide human factors section states that, "the d

monitoring instrumentation design should minimize the development of *

i con 61tions that would cause meters, annunciators, recorders , ala rms ,

l etc., to give anomalous indications potentially confusing to the ope ra t o r. " The inspectors discussed this with the operators, who did not regard this dual indication as confusing. This issue was

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discussei at length with the licensee's staf f. The licensee agreed that the inconsistency should be eliminated and will inform the office of Nuclear Reactor Regulation (NRR) of their plans to change the  ;

readout of one channel and the corresponding procedures. The change t

of the CST level indication to one consistent unit of measurement and the procedural changes reflecting this will be followed up during a i future inspection (50-312/88-27-02). ' The inspectors verified that the instruments were in calibration for t

the variables inspected. A concern became apparent regarding the J

Steam Generator Pressure Transmiiters. The steam generator pressure  !

j instruments were found to be within the Technical Specificatian i calibration interval of 18 months, but certain licensee calculations >

(EFIC Setpointn and Accura.'ies, Z-EFI-IO146) for these instruments  ;

impiled that a calibration interval of 12 months is needed to account -

for instrument drift. The inspectors were informed that the licensee had initially set up their preventative maintenance program for recalibration of these instruments on a 12 month cycle. At the time  :

of the inspection, the calibration on 3 of the 4 instruments had been  ;

changed to 18 month >

If the 12 month calibration interval is correct, the instruments were }

out of calibration by approximately 3 months and the technical l

specification needs to be reviewed to reflect the licensee's [

calculatio i The licensee was informed of this problem and agreed to resolve this i concern. This item remains unresolved and will be followed up in a  !

future inspection report (50-312/88-27-03).  !

6. Exit Int e rview The results of the inspectiop were summarized on September 16, 1985 with those persons indicated in paragraph 1. The inspector described the scope i of the inspection and the findings up to that date, j f

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