Text

Insp Repts 50-361/88-18 & 50-362/88-19 on 880627-0701. Violation Noted.Major Areas Inspected:Representative Subsystems of post-accident Monitoring Sys at Facility, Plant Conformance W/Rev 2 to Reg Guide 1.97
	ML20151S951
Person / Time
Site:	San Onofre
Issue date:	07/20/1988
From:	Jim Melfi, Richards S; NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION V)
To:	;
Shared Package
ML20151S942	List: ML20151S938; ML20151S944; ML20151S951;
References
	RTR-REGGD-01.097, RTR-REGGD-1.097 50-361-88-18, 50-362-88-19, NUDOCS 8808160179
	Download: ML20151S951 (16)
	v • d • e

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U. S. NUCLEAR REGULATORY COMMISSION

REGION V

Reports Nos:

50-361/88-18,50-362/88-19

Docket Nos.

50-361, 50-362

License Nos.

NPF-10, NPF-15

Licensee:

Southern California Edison Company

P. O. Box 800

2244 Walnut Grove Avenue.

Rosemead, California,

91770

Facility Name:

San Onofre Units 2 and 3

Inspection at:

San Onofre Nuclear Generating Station Units 2 and 3.

Inspection Conducted:

June 27 - July 1, 1988

Inspectors:

/

/ ,umfb M ,

7MMg

~

D(te Mfjned

elfT, React

In' spec tor

Other Accompanying Personnel

M. W. Yost, NRC Contractor, INEL

J. P. Joyce, Inspector, ICSB, NRR

Approyed By: [

m/#f7;

ef

7/.,:ro,d7f

Richards,

16f,~Eng i n rfng Tection

Date StynEd

Summary:

Inspection on June 27, 1988 - July 1, 1988 (Report 50-361/88-18,50-529/88-19)

Areas Inspected:

A special announced inspection of representative subsystems

of the post-accident monitoring system at the San Onofre Nuclear Generating

Station (SONGS), Units 2 and 3.

This inspection assessed the conformance of

the SONGS with Regulatory Guide 1.97, Revision 2.

Inspection procedures 30703

and 25587 were used during this inspection. This inspection addresses Safety

Issue Management System (SIMS) item number 67.3.3.

,

Results: Of the area inspected,1 violation was identified dealing with the

i

separation of electrical cables in a control room cabinet.

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DETAILS

1.

Persons Contacted

San Onofre Nuclear Generating Station

D. Mercurio, Sr. Licensing Engineer

D. Schone, QA Director

C. Couser, Compliance Engineer

K. O'Connor, Retrofit Manager

J. Ibarra, Nuclear Systems Engineer

M. Zenker, Compliance Engineer

T. Vogt, Asst. Plant Operations Superintendent

C

Hays, Retrofit Engineer

D. Daek, QA Engineer

R. Reiss, QA Supervisor

S. McMahan, Assistant Maintenance Manager

R. Plappert, Compliance Engineer

R. L. Baker, Unit 2/3 Project Engineer

R. Baker, Compliance Engineer

R. Waldo, Engineer

E. Bennet, QA Engineer

B. Bas, Engineer

Other NRC Personnel

C. Trammel, NRC Project Manager

Attended Exit Meeting, July 1,1988.

The inspectors also held discussions with other licensee and contractor

personnel during the inspection. This included plant staff engineers,

technicians, administrative and clerical assistants.

2.

Introduction

The purpose of this inspection was to compare the installed plant

instrumentation with the commitments contained in correspondence related

to Post-Accident Instrumentation as described in the Safety Evaluation

Report (SER). This inspection also assessed if the instrumentation meets

the criteria specified in Regulatory Guide 1.97.

Some of the references

used to assess the licensee conformance to Regulatory Guide 1.97 were:

Regulatory Guide 1.97, Revision 2, "Instrumentation for Light

Water-Cooled Nuclear Power Plants to Assess Project and Environs

Conditions During and Following an Accident."

San Onofre Nuclear Generating Station (SONGS) Final Safety Analysis

Report (FSAR), Chapters 3 and 7.

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2

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Safety Evaluation Report, as discussed in memorandum from

R. W. Houston to T. M. Novak, Februsry 13, 1985, with Technical

Evaluation Report (TER) prepared.for the NRC by EG&G Idaho Inc.,

"Conformance to Regulatory Guide 1.97, San Onofre Nuclear Generating

Station, Unit Nos. 2 and 3", October 1984, EGG-EA-6525.

Generic Letter 82-33 issued supplement 1 to NUREG-0737, which specified

those requirements regarding emergency' response capability that had been

approved by the NRC. This supplement also discussed in part the

application of Regulatory Guide (RG) 1.97 to the emergency response

' facilities, including the Control Room (CR), Technical Support Center

(TSC) and Emergency Operations Facility (E0F) at power plants. The

response by the licensee to RG 1.97 was provided in letters to the NRC

dated May 13 1982, and July 26, 1984.

.

The inspectors verified that the licensee had documentation available

onsite that showed the redundancy, physical and electrical separation,

power sources and interfaces for the instrumentation. The Q and EQ

master equipment lists showed that for the instruments selected,

they had been evaluated and tested to the appropriate environmental,

quality assurance and seismic qualification requirements. The

Environmental Qualification (EQ) tests are labled with either a statement

affirming that the instrument is EQ qualified, or gives the environment

,

that the component is located in. A mild environment does not need any

special qualification.

The seismic listing also notes if the instrument

is appropriately qualified. The QA procurement of these instruments was

also reviewed. No problems were identified with their procurement.

Regulatory Guide 1.97 divides Post-Accident instrumentation into three

categories and five types. The three categories are noted as 1, 2, and 3.

Category 1 has the most stringent requirements and category 3 the least

stringent. The five types of instrumentation identified in the Regulatory

Guide 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 1.

The specific information on the instrumentation inspected is discussed in

paragraph 3.

Except as noted, the requirements for the Category 1 and 2

instruments were met.

3.

Inspection Details

The inspectors held discussions with various members of the licensee's

staff, examined drawings, and walked through the control room to assess

the implementation of the requirements delineated in Regulatory Guide 1.97, Revision 2.

The Control Rooms for Units 2 and 3 are coninon, and

were inspected. Both of these units employ the same design and similar

instrument numbers.

For Category 1 instrumentation, the power is supplied

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by Class-1E instrument buses. The licensee has installed a Qualified

Safety Parameter Display System (QSPDS) which is a fully qualified data

acquisition, display, and recording system. . Several of the instruments

inspected had recordings of the QSPDS, instead of on separate, qualified

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recorders. The use of the QSPDS is an acceptable means for recording of

the variables.

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The following variables and instrumentation were examined.

3.1 Neutron Flux

Regulatory Guide 1.97 classifies this as a Category 1. variable.

In.

addition, the licensee classifies this as a Type A variable.

The

currently documented range is 1 E-8 percent to 125 percent of full power.

The actual range displayed goes up to 200 percent of full power. This is

displayed on log-scale indicators, recorded on a Category 2 two-pen

recorder (one pen per neutron flux channel), and recorded on the Qualified

Safety Parameter Display System (QSPDS). The non-seismically qualified

recorder is optically isolated from both Category 1 instrument loops by

fully qualified Foxboro isolators.

Information on the neutron flux

instrumentation is as follows.

Tag

.

EQ

Seismic

Power

Instrument

Number

Function

Listed

Division

Range

JE-0006-1

Detector

Yes

A/MCC2BY

-8

JI-00582

Indicator

Mild

Yes

10 8 to 200%

--

JR-0006

Recorder

Mild

Yes

10- to 200%

'

--

JE-0005-2

Detector

Yes

B/MCC2BZ

--

JI-00681

Indicator

Mild

Yes'

10

to 200%

--

JR-0005

Recorder

Mild

Yes

10' to 200%

--

Note: JR-0005 and 0006 are two scales within a common recorder.

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Inspection Findings

The inspectors found that the instrumentation for this variable meets the

Category 1 recommendations specified in Regulatory Guide 1.97.

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3.2 Reactor Coolant System Hot and Cold Leg Water Temperature

The licensee has determined that these variables are Type A.

This

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Category 1 instrumentation is used, in part, to ensure the proper cooldown

rate and to monitor system temperature.

Each of the two hot legs and four

cold legs of the reactor is monitored by a 200-ohm resistance temperature

detectors (RTDs). Category 2 two-pen recorders (one pen per channel) are

used. The recorder is optically isolated from both Category 1 instrument

loops by fully qualified Foxboro isolators.

Infonnation on the cold leg

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water temperature instrumentation was typical of all four loops. Information

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on the Reactor Coolant System (RCS) hot and cold leg water temperature

instrumentation was as follows:

-

- - .. -

-

- --

-

- -

-

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Tag

.EQ

Seismic

Power.

Instrument

Number

Function

Listed

Division

Range

Hot Leg Water Temperature

TE-911-1

Detector

Yes

A/Y01

--

TE-921-2

Detector

Yes

B/Y02

--

TR-911-1

Recorder

Mild

Yes

A/Y01

0-710*F

Cold Leg Water Temperature.

TE-925-1

Detector

Yes

A/Y01

--

TE-915-2

Detector

Yes

B/Y02

--

TR-915-2

Recorder

Mild

Yes

B/Y02

0-710 F

Inspection Findings

The inspectors found that the instrumentation for this variable meets the-

-

,

Category 1 recommendations specified in Regulatory Guide 1.97.

However,

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the SONGS Unit 2/3 FSAR states that the range of the cold leg water

temperature instrumentation is 0-600 F.

The installed instrumentation has

a greater range of 0-710 F.

The licensee agreed to modify their FSAR to

show the correct range.

3.3 RCS Pressure

The licensee has determined that this is a Type A variable. This Category

1 instrumentation is used, in part, to verify the correct relation between

system pressure and temperature. Regulatory Guide 1.97 recomends a range

of 0-4000 psig for these Combustion Engineering units.

Information on the

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RCS pressure transmitters and recorders were as follows:

Tag

EQ

Seismic

Power

Instrument

Number

Function

Listed

_ Division

Range

PT-0102-1

Detector

Yes

A/ Vital Bus 1

--

PT-0102-2

Detector

Yes

B/ Vital Bus 2

--

PT-0102-3

Detector.

Yes

C/ Vital Bus 3

--

PT-0102-4

Detector

Yes

0/ Vital Bus 4

--

PR-0102-1

Recorder

Mild

Yes

A/ Vital Bus 1

0 - 3000 psig

PI-0102-Al

Indicator

Mild

Yes

A-

0 - 3000 psig

PI-0102-A2

Indicator

Mild

Yes

B

0 - 3000 psig

PI-0102-B1

Indicator

Mild

Yes

C

0 - 3000 psig

PI-0102-B2

Indicator

Mild

Yes

0

0 - 3000 psig

Inspection Findings

The SER for Regulatory Guide 1.97 accepted the 0 - 3000 psig range

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pending the resolution of the Anticipated Transient Without Scram (ATWS)

issue. An SCE letter (M. O. Medford) to the NRC (G. W. Knighton), dated

June 6, 1986, proposed resolving the ATWS issue with the addition of a

diverse scram system at Units 2&3. As NRR has not resolved the ATWS issue

for San Onofre-2/-3, the inspectors conclude that the 0 - 3000 psig

range is still acceptable in the interim pending NRR completing action on

the ATWS issue for San Onofre-2/-3. The inspectors found the RCS pressure

instrumentation to meet Regulatory Guide 1.97 requirements.

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- , _ -

_ . - -

- - . _ - . . _ - - - . - _ .

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3.4 Refueling Water Storage Tank Level

The licensee has defined this as a Type A variable.

The Refueling Water

Storage Tank (RWST) provides a supply of borated water.during normal plant

operation.

It also supplies water to the safety injection pumps following

an accident. Type A variables impose Category 1 recommendations. All

instrumentation for this variable is located in a mild post-accident

environment.

Information on the RWST level transmitters and recorders were

as follows:

Tag

EQ

Seismic

Power

Instrument

Number

Function

Listed

Division

Range *

LT-305-1

Transmitter

Mild

Yes

A/ Vital Bus 1

--

LT-305-2

Transmitter

Mild

Yes

B/ Vital Bus 2

--

LT-305-3

Transmitter

Mild

Yes

C/ Vital Bus 3

--

LT-305-4

Transmitter

Mild

Yes

D/ Vital Bus 4

--

LR-305-1

Recorder

Mild

Yes

A/ Vital Bus 1

0 to 100%

LI-305-1

Indicator

Mild

Yes

A

(0 to 384.5 in.)

LI-305-2

Indicator

Mild

Yes

B

0 - 100%

LI-305-3

Indicator

Mild

Yes

C

0 - 100%

LI-305-4

Indicator

Mild

Yes

0

0 - 100%

Inspection Findings

The inspectors found that the instrumentation for this variable meets the

Category 1 recommendations specified in Regulatory Guide 1.97,

3.5 Containment Pressure

The licensee has determined that this is a Type A variable. This Category

1 instrumentation is used to monitor post-accident containment conditions

and the performance of those engineered safety features designed to

control the post-accident containment environment.

There are four

channels of wide range (-4 psig to 85 psig) instrumentation and two

channels of wide-wide range instrumentation.

Information on this

instrumentation were as follows:

Tag

EQ

Seismic

Power

Instrument

Number

Function

Listed

Division

Range

PT-0352-1

Transmitter

Yes

A/ Vital Bus 1

--

PR-0352-1

Recorder

Mild

Yes

A/ Vital Bus 1

-4 to 85 psig

j

PI-0352-1

Indicator

Mild

Yes

-4 to 85 psig

'

--

PT-0352-2

Transmitter

Yes

B/ Vital Bus 2

--

PI-0352-2

Indicator

Mild

Yes

-4 to 85 psig

--

PT-0352-3

Transmitter

Yes

C/ Vital Bus 3

--

PI-0352-3

Indicator

Mild

Yes

-4 to 85 psig

--

PPT-0352-4 Transmitter

Yes

D/ Vital Bus 4

--

PI-0352-4

Indicator

Mild

Yes

-4 to 85 psig

--

PT-0353-1

Transmitter

Yes

A/ Vital Bus 1

--

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m

Tag

EQ

Seismic

Power

Instrument

Number

Function

Listed

Division

Range

PR-0353-1

Recorder

Mild

Yes

A/ Vital Bus 1

0 to 180 psig

PI-0353-1

Indicator

Mild

Yes

--

0 to 200 psig

PT-0354-2

Transmitter

Yes

B/ Vital Bus 2

--

0 to 200 psig

PI-0354-2

Indicator

Mild

Yes

--

Inspection Findings

The inspectors found that the instrumentation for this variable meets the

Category 1 recommendations specified in Regulatory Guide 1.97.

3.6 Containment Sump Water Level

The licensee has determined that this is a Type A variable. The

instrumentation for this variable consists of three sets of two channels.

The ranges of these three sets of instrumentation overlap to cover a total

range of from 11 feet, 11 inches, to 30 feet, 2 inches. This

instrumentation is used .in part, to assess. containment conditions prior

to switching to the recirculation mode, and to monitor the water level in

containment. Each set of instrumentation uses a separate dual-pen recorder.

Each channel of instrumentation is optically isolated from the recorder by

fully qualified Foxboro isolators. Information on the containment sump

water level transmitters and recorders were as follows:

Tag

EQ

Seismic

Power

Instrument

Number

Function

Listed

Division

Range

Normal Range

LT-5853-1 Transmitter

Yes

A/ Vital Bus 1

--

LT-5853-2 Transmitter

Yes

B/ Vital Bus 2

--

LR-5853-2 Recorder

Mild

Yes

B/ Vital Bus 2

11' 11" to 16' 6"

'

Emergency Range

LT-9386-1 Transmitter

Yes

A/ Vital Bus 1

--

LT-9386-2 Transmitter

Yes

B/ Vital Bus 2

--

t

LR-9386-1 Recorder

Mild

Yes

B/ Vital Bus 2

12' to 19' 9"

Wide Range

LT-9387-1 Transmitter

Yes

A/ Vital Bus 1

--

LT-9388-2 Transmitter

Yes

B/ Vital Bus 2

--

LR-9387-1 Recorder

Hild

Yes

A/Vitai Bus 1

18' 2" to 30' 2"

Inspection Findings

The range on these instruments is greater than the range specified in the

Regulatory Guide (0 to 600,000 gallons).

The inspectors found that the

instrumentation for this variable meets the Category 1 recommendations

specified in Regulatory Guide 1.97.

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3.7 Containment Hydrogen Concentration

The licensee has determined that this is a Type A variable.

Regulatory

Guide 1.97 recommends Category 1 instrumentation for this variable. Some of

the uses for this instrumentation include long-term surveillance of the

containment for potentially explosive concentrations of hydrogen, and to

determine that accident mitigation is being successfully accomplished.

Information on the containment hydrogen concentration instrumentation were

as follows:

Tag

EQ

Seismic

Power

Instrument

Number

Function

Listed

Division

Range

AET-8100-1

Sensor /Trans.

Yes

A/MCC BY

--

,

AI-8108A

Indicator

Mild

Yes

A/MCC BY

0 to 10%

'

AET-8111-2

Sensor /Trans.

Yes

B/MCC BZ

--

Al-8118A2

Indicator

Mild

Yes

B/MCC BZ

0 to 10%

AR-8118A2

Recorder

Mild

Yes

B/MCC BZ

0 to 10%

Inspection Findings

The inspectors found that the instrumentation for this variable meets the

Category 1 recommendations specified in Regulatory Guide 1.97.

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3.8 Coolant Level in Reactor

The licensee has classified this as a Type A variable.

Regulatory Guide 1.97 recomends Category 1 instrumentation for this variable.

The

instrumentation is a dual channel heated-junction thermocouple system.

.

Each thermocouple probe assembly consists of eight discrete thermocouples

that are surrounded by resistance heating wire and eight nearby unheated

thermocouples. The thermocouples are shielded from spla< ag, flow

changes, and turbulence. The eight thermocouple pairs are distributed

along the length of the probe. The presence of liquid coolant is

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indicated by the same temperature at each thermocouple of the pair.

Vapor

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is indicated at a pair location by a temperature differential being

observed (by computer and by the QSPDS) between the two thermocouples cf

the pair. The probe assembly, seals, and electrical connections are

environmentally qualified. Other components of the system are located in

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a mild environment. All portions of this system are seismically

qualified. Each channel is supplied with divisionally independent vital

bus power.

Inspections Findings

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The inspectors found that the instrumentation for this variable meets the

Category 1 recommendations specified in Regulatory Guide 1.97.

3.9 High Pressure Safety Injection Flow

,

The licensee has defined the High Pressure Safety Injection (HPSI) flow as

a Type A variable. This instrumentation should therefore be Category 1.

The flow orifices and transmitters are located in a harsh post-accident

environment.

The square root extractors are located in a mild environment

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and otherwise meet the same design requirements'. Recording is provided by

the Critical Function Monitoring System.(CFMS).- The CFMS is not Category

1; however, fully qualified Foxboro-optical isolators: isolate the CFMS'

from both the Category 1 instrumentation and the QSPDS.

Information on.

the HPSI flow transmitters were as-follows:

Tag

EQ

Seismic

Power

Instrument.

Number

Function

Listed

Division

Range

FT-311-2

Transmitter-

Yes

B/ Vital Bus 2

Header Flow:

0 - 500 gpm

FI-311-2

Indicator

Mild

'Yes

--

FT-321-1

Transmitter

Yes

A/ Vital Bus 1

Header Flow

FI-321-1

Indicator

Mild

Yes

'

0 - 500 gpm

!

--

FT-331-1

Transmitter

Yes

A/ Vital Bus 1.

Header Flow

--

,

0 - 500 gpm

F1-331-1

Indicator

Mild

Yes

FT-341-2

Transmitter

Yes

Yes-

B/ Vital-Bus 2

Header Flow

]

FI-341-2

Indicator

Mild

Yes

0 - 500 gpm'

--

FT-9435-2

Transmitter

Yes

B/ Vital Bus 2

Header to Hot Leg

Flow

0 - 500 gpm

FI-9435-2

Indicator

Mild

Yes

--

J

FT-9421-1

Transmitter

Yes

A/ Vital-Bus 1

Header to Hot Leg

!

Flow

.

1

FI-9421-1

Indicator

Mild

Yes'

0 - 500 gpm

--

Inspection Findings

i

The inspectors found that the instrumentation for this variable meets the

Category 1 recomendations specified in Regulatory Guide 1.97.

3.10 Core Exit Temperature

The licensee has classified this variable.as Type'A. Regulatory Guide 1.97 recommends Category 1 instrumentation for this variable. The core

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exit temperature instrumentation consists of:two' channels composed of 28

chromel-alumel thermocouples each. .The thermocouple wires use guide tubes

-

and seal assemblies to penetrate.the reactor vessel head. These

thermocouples have divisional reference junctions that provide the signal

to the QSPDS. The QSPOS displays and records the temperature of all-

thermocouple locations. The' average core exit temperature is also

displayed on demand.

Information on typical- thermocouples were as follows:

i

Tag

EQ

Seismic

Power

Instrument

Number

Function

Listed

Division

Range

'

N0ZZ95-1TC

Ch A TC~

Yes

A/Y01

32 to 2300'F

N0ZZ100-1TC

Ch B TC

Yes

B/Y02

32 to 2300*F

.

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Inspection Findings

,

The inspectors found tlc 1.he all of the instrumentation for this variable ~

'

meets the Category 1 recomendations specified in Regulatory Guide 1.97.

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- - , - , - , . . - - . , , - . , . - - , - - ,

.-,----,.,-,,....w..,-,,,-,.

. . , . , , ,

-.,--,..-,,n-,n

.

. - . - - - . - , . - - - . - - - . . ,

e

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3.11 Steam Generator Level

The licensee has classified this as a Type A variable.- The

. instrumentation is used, in part, to detect steam generator tube ruptures,

to monitor the steam generator level following a feedwater line break, and

to ensure a usable reactor heat sink. Regulatory Guide 1.97 recomends

that this instrumentation be Category 1 with a range from the tube sheet

to the separators.

There are two steam generator at each unit (2&3) at

San Onofre. The transmitters are located in a harsh post-accident

environment.

Information on the steam generator wide range level

transmitters and recorders were as follows:

Tag

EQ

Seismic

Number

Function

Listed

Power Division /SG

LT-1115-1

Transmitter

Yes

A/ Vital Bus 1/SG89

LT-1115-2

Transmitter

Yes

'Yes

B/ Vital Bus 2/SG89

LR-1115-1

Recorder

Mild

Yes

A/ Vital Bus 1/SG89

LT-1125-1

Transmitter

Yes

A/ Vital Bus 1/SG88

LT-1125-2

Transmitter

Yes

B/ Vital Bus 2/SG88

LR-1125-2

Recorder

Mild

Yes

B/ Vital Bus 2/SG88

Inspection Findings

The Regulatory Guide 1.97 range for this variable is from the tube sheet to

the separator. The range on the instruments is 0 to 100%. The inspectors

had questioned the range of this variable.

The information provided by

the licensee showed that the tube sheet is located at 135.25 inches and

the bottom of the seperator is at 631.375 inches. The taps for the wide

range level are shown at 148.2S and 786 inches. The licensee's

instrumentation is 13 inches above the tube sheet. At 13 inches above the

tube sheet, the steam generator is essentially empty. The upper tap is

156.625 inches more than what is specified in the Regulatory Guide.

Therefore, this range would be adequate to monitor this variable during

accident and post-accident conditions. The inspectors found that the

instrumentation for this variable meets the Category 1 recommendations

specified for this variable.

3.12 Steam Generator Pressure

The licensee classifies this as a Type A variable; as such, the

instrumentation supplied should be Category 1.

Each steam generator has

four associated pressure channels. This instrumentation is used to

)

monitor the secondary steam pressure following a steam generator tube

rupture or steamline break. The transmitters are located in a harsh

post-accident environment.

Information on the steam generator pressure

instrumentation were as follows:

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Tag

EQ

Seismic

Power

Instrument

Number

Function

Listed

Division

Range

PT-1013-1

Transmitter

Yes

A/ Vital Bus 1

--

O ta 1.2K psia

PI-1013-1

Indicator

Mild

Yes

---

PR-1013-1

Recorder

Mild

Yes

A/ Vital Bus.1

0 to 1.2K psia

PT-1013-P.

Transmitter

Yes

B/ Vital Bus 2

--

PT-1013-2

Indicator

Mild

Yes

O to 1.2K psia

--

PT-1013-3

Transmitter

Yes

C/ Vital Bus 3

--

0 to 1.2K psia

PI-1013-3

Indicator

Mild

Yes

--

PT-1013-4

Transmitter

Yes

D/ Vital Bus 4

--

0 to 1.2K psia

PI-1013-4

Indicator

Mild

Yes

--

PT-1023-1

Transmitter

Yes

A/ Vital Bus 1

--

PI-1023-1

Indicator

Mild

Yes

0 to 1.2K psia

--

PR-1023-1

Recorder

Mild

Yes

A/ Vital Bus 1

0 to 1.2K psia

PT-1023-2

Transmitter

Yes

B/ Vital Bus 2

--

PI-1023-2

Indicator

Mild-

Yes

O to 1.2K psia

--

PT-1023-3

Transmitter

Yes

C/ Vital Bus 3-

--

PI-1023-3

Indicator

Mild

Yes

0 to 1.2K psia

.--

PT-1023-4

Transmitter

Yes

D/ Vital Bus 4

--

PI-1023-4

Indicator

Mild

Yes

0 to 1.2K psia

--

Inspection Findings

,

The inspectors found that this instrumentation meets the Category 1

!

recommendations specified in Regulatory Guide 1.97

'

3.13 Pressurizer Heater Current

Regulatory Guide 1.97 recomend3 that the current used by the pressurizer

heaters be monitored by Category 2 instrumentation.

The licensee has

provided current monitoring for the two pressurizer heater banks that are

!

backed by diesel generator Class 1E power. All heaters are provided by

i

480 VAC. All instrumentation is located in a mild environment,

t

Information on this instrumentation were as follows:

Tag

EQ

Seismic

Power

Instrument

Number

Function

Listed

Division

Range

IT-0100A

Transmitter

Mild

Yes

A

--

II-0100A

Indicator

Mild

Yes

A

0 to 300A

IT-01000

Transmitter

Mild

Yes

B

--

II-0100D

Indicator

Mild

Yes

B

0 to 300A

Inspection Findings

The inspectors found that the instrumentation for this variable meets the

Category 2 recomendations specified in Regulatory Guide 1.97.

l

.

b

i

.

,

i. - '

,

-

11

~ .

.

,

3.14 Status of Standby Power

Regulatory Guide 1.97 recommends plant specific Category 2 instrumentation

-

for this variable.

The licensee has instrumentation to monitor the

standby power sources for availability and usage. All of this

instrumentation is located in a mild environment with readouts in the

control room.

Instrumentation observed in the control room is marked in

that column. The licensee comitted to provide the following instrumentation

for this variable:

Power Source

Observed Ranges

4K VAC Buses

Volts

0 to 5.25 KV

'

Current

0 to 3 KA

Frequency

55 to 65 HZ

,

'

480 VAC Buses

Volts

0 to 600V

125 VOC Buses

Volts

0 to 150V

'

Current

0 to 1200A

120 VAC Inverter

i

Voltage Alarm

Yes

Power Source

Observed Ranges

Emergency Diesel Generator

Volts

0 to 5.25KV

l

Current

0 to 1KA

>

Non-Class 1E uninterruptable power. system

r

Voltage Alarm

Yes

Main Steam to Auxiliary Feedwater Turbine

Steam Generator Pressure

See Section 3.12

Isolation Valve Position

Yes/Yes

4

]

HV 8200/HV 8201

[

]

Inspection Findings

s

The inspectors found that the instrumentation for this variable meets the

'

Category 2 recomendations specified in Regulatory Guide 1.97.

,

'

3.15 Pressurizer Level

l

.

Regulatory Guide 1.97 recomends Category 1 instrumentation for this

l

variable with a range from the bottom to the top of the pressurizer

vessel. The pressurizer level instrumentation is an aid to the operator

-

>

l

in the proper operation of the pressurizer and the reactor coolant system.

Information on the pressurizer level transmitters, indicators, and

!

recorder were as follows:

'

i

a

u

i

?

.

. .

.

-

.

12

.

,

Tag

EQ

Seismic

Power

Instrument

Number

Function

Listed

Division

Range

LT-0110-1

Transmitter

Yes

A/ Vital Bus 1

--

O to 100%

LI-0110-1

Indicator

Mild

Yes

--

LR-0110-1

Recorder

Mild

Yes

A/ Vital Bus 1

0 to 100%

LT-0110-2

Transmitter

Yes

B/ Vital Bus 2

--

LI-0110-E

Indicator

Mild

Yes

0 to 100%

--

Inspection Findings'

The inspectors found that the instrumentation for this variable meets the

Category I reconaendations specified in Regulatory Guide 1.97.

3.16 Containment Atmosphere Temperature

Regulatory Guide 1.97 recommends Category 2 instrumentation for

n

+

variable to indicate the accomplishment of containment cooling.

,

Information on the containment atmosphere. temperature instrumentation

!

were as follows:

Equipment

EQ

Seismic

Number

Function

Listed

Li s te,d_

Power

Display

!

.

TE-9903-1

Element

Yes

A/ Vital Bus 1

--

4

TI-9903-1

Indicator

Mild

Yes

0 - 400*F

--

TR-9903-1

Recorder

Mild

Yes

A/ Vital Bus 1

0 - 400*F

TE-9911-2

Element

Yes

B/ Vital Bus 2

Computer

Display Only

Inspection Findings

,

The inspectors found that the instrumentation for this variable meets the

,

Category 2 recommendations specified in Regulatory Guide 1.97.

-

3.17 Condensate Storane Tank Water Level

'

Regulatory Guide 1.97 recomends Cat 2 gory 1 instrumentation to ensure the

availability of the primary water supply for auxiliary feedwater. The

'

licensee identified tank T-121 as the primary source of auxiliary

<

feedwater. Thus, level instrumentation for this tank should be

i

l

Category 1.

Instrumentation for backup sources of auxiliary feedwater

(identified as tank T-120) are specifically allowed to be Category 3 by

the regulatory guide.

Instrumentation for T-120 therefore, was not

,

examined as part of this audit.

Isolation between the Category 1

1

instrumentation for T-121 and the non-Category 1 computer display is

provided by fully qualified Foxboro optical isolators. Call up displays

,

'

ca a computer are specifically allowed for Category 1 instre antation by

Revision 3 of Regulatory Guide 1.97.

Information on the level instrumentation

'

for T-121 were at follows:

i

'

i

1

,

I

!

-

__ _

.

-,___,__ . ,.

_.,_..._-..._m

,-

,=

.

,-

'.

13

.-

.

Equipment

EQ

Seismic

Number

Function

L i s t_e_d_

Listed

Power

Display

'

LT-3204-1

Detector

Yes

A/ Vital Bus 1

4

--

LR-3204-1

Recorder

Mild

Yes

A/ Vital Bus 1

0 to 100%*

LT-3204-2

Detector

Yes

B/ Vital Bus 2

Computer-

Display Only

100% is equal to 144,000 gallons

Inspection Findings

The inspectors found that the instrumentation for this variable meets the

i

Category I recomendations specified in Regulatory Guide 1.97.

4.

Surveillance, Testing, and Calibration

The licensee uses a computerized data base, the San Onofre Maintenance

ManagementSystem(SOMMS). Part of the function of this system is to

i

generate the maintenance orders for recalibration of instruments as a

repetitive maintenance task and provide a historical record of

instrument calibrations.

)

Tha inspectors asked for the calibration records for the instruments

!

inspected, the frequency of calibration, and the next due date for

recalibration. The licensee was maintaining all of the instruments

-

inspected in calibration.

There were several variables for which the surveillance, testing, and

calibration data was not verified.

These variables are Pressurizer Heater

Current, Core Exit Thermocouples, and Status of Standby Power. The

surveillance, testing, and calibration data will be followed up at a later

i

inspection (50-361/88-18-01).

t

5.

Inspector Observations

During the course of the inspection, the inspectors made the following

observations:

'

A.

The licensee does not have official instrument loop drawings.

The

tracing of the instrument wiring from transmitter to recorder using

the licensee's official electrical drawings was a time consuming and

laborious process. At several times during the inspection, the

inspectors felt that the inspection would not be completed at the end

!

of the week, since it was even difficult for licensee personnel to

trace the wiring path.

The inspectors then determined that the

,

stationInstrumentationandControl(I&C)personnelhadunofficial

3

loop diagrams. The inspectors used these unofficial loop drawings

made by the I&C technicians as a guide to help trace the instrument

,

loop. The licensee stated that they have a program to eventually

'

update these drawings to loop diagrams.

l

'

i

,

6-

J

d*

,

i

-

14

.

B.

The inspectors notad some discrepancies with the FSAR listing of

these variables. These discrepancies did not involve any safety

significant concerns. The licensee committed to make updates to the

i

FSAR to correctly reflect installed plant equipment as noted in

tables 7.5-1 and 7.5-2.

,

C.

On 6/29/88, during the tour of the control room, the inspectors

viewed the back of control raom panel 59-for Unit- 2.

This panel has

both trains of many of the post accident monitoring variables. The

inspectors noted that these instruments were separated by barriers

where the recorders and indicators are placed in the panel. The

in'.pectors also noted that the wiring for the train A and train B

wires were in coils, and that the train A and train B wires were

touching at the bottom of the cabinet. There was also a

non-associated (X train) wire with the A train, which was in contact

,

with the B train.

The separation criteria for safety related wiring is described in

IEEE 384-1974, "IEEE Trial-Use Standard Criteria for Separation of

'

Class IF Equipment and Circuits", which requires 6 inches of air or a

barrier between wires of different Class IE trains. The licensee's

program for separating wires is described in Chapter 8 of the FSAR

and in Construction Specification (CS) E03 "Safety Related and

Non-Safety Related Electrical Construction Specification for Cable

Splicing, Termination and Supports". As described in the FSAR and CS

E03, the licensee has certain exceptions to the separation criteria

of 6 inches.

For example, the wires can tcuch each other if

both trains of wires are low energy. The non-associated train is

allowed by the licensee's program to touch 1 train, but is not

allowed to touch two trains. However, the recorders in this panel

'

were running off of class IE power, which was not low ener01

,

Additionally, Train A had a non-associated train (X) wire associated

'

with it, which was in proximity to both trains at that time. The

failure to maintain these wires separate is an apparent violation of

theconstructionspecification(50-361/88-18-02).

The licensee evaluated this situation and declared the panel

inoperable several hours later, entered a 48 hour5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> action statement

and generated Nonconformance Report (NCR) 2-2245. The licensee

separated the wires under Maintenance Order 88062608000, which was

completed 6/30/88.

i

After this lack of separation was initially discovered, the licensee

realized the possible generic concerns with separation of wiring in

other panels. The licensee then trained several groups of people to

inspect and verify that the wiring was in accordance with their

construction specification for different panels.

j

On 7/1/88, after the exit meeting, the inspector talked to the groups

of people verifying the separation in the other panels. The licensee

j

had started examining the cabinets for Unit 3, which was shut down.

<

The licensee informed the inspector that they would do an evaluation

i

after their Unit 3 inspection, to determine if the problem was

'

significant enough to do an imediate inspection of the Unit 2

cabinets,

)

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