ML20154P639
| ML20154P639 | |
| Person / Time | |
|---|---|
| Site: | Trojan File:Portland General Electric icon.png |
| Issue date: | 09/16/1988 |
| From: | Jim Melfi, Richards S NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION V) |
| To: | |
| Shared Package | |
| ML20154P632 | List: |
| References | |
| RTR-REGGD-01.097, RTR-REGGD-1.097 50-344-88-36, NUDOCS 8810030130 | |
| Download: ML20154P639 (14) | |
See also: IR 05000344/1988036
Text
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U. S. NUCLEAR REGULATORY C069tISS10N
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REGION V
Report No.
50-344/88-36
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Docket No.
50-344
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License No.
Licensee:
Portland General Electric Company
121 S. W. Salmon Street
Portland, Oregon 97204
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Facility Name:
Trojan Nuclear Plant
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Inspection at:
Rainier, Oregon
(Trojan Site)
Inspection conducted:
August 8 - August 12, 1988
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Inspector:
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F. Melfi, Reac)6r )fispector
Date Sfgned
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Other accompanying personnel:
Alan C. Udy, NRC Contractor, INEL
C!/&f88
Approved By:
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S. A. Richards, Chief. Engineering Section
Date Signed
Inspection Summary:
Inspection During the Period of August 18 - August 22, 1988 (Inspection
Report 50-344/88-36)
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Areas Inspected:
A special, announced inspection by a regional based
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inspector and a hRC contractor, to assess the licensee's conformance to
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Regulatory Guide 1.97, revision 3.
The inspection procedures used were 30703
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and 25587.
This report addresses the Safety Issue Management System (SIMS)
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issue number 67.3.3.
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Results:
1 deviation was identified.
The deviation that was identified
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concerned the failure of the licensee to implement a coevaitment made to the
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NRC.
There was also an apparent lack of redundancy (single failure) for the
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power supplies to the Post Accident Wide Range Steam Generator Level, the RCS
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Cold Leg and Hot Leg Temperatures.
This lack of redundancy is an unresolved
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item.
These are discussed in paragraph 5 of this report.
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8910030130 000916
ADOCK 05000344
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OETAILS
1.
Persons Contacted
Licensee Personnel
- A. Olmstead, Trojan General Manager
- 0. Nordstrom, Compliance Engineer
- J. Reid Plant Services Manager
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- E.
Davis, Manager, Electrical Section
- J. Duclayan, NPE Electrical Engineer
- M. Stapelton, NPE Engineer
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"C. Brown, Quality Assurance Operations Branch Manager
- D.
Swanson, NSRD
- E.
Schmieman, PSE
- D. Benett, Maintenance Manager
"L. Erickson, QA Manager
- J.
Lentsch, PPD
- K. Bohlander, Nuclear Power and Engineering Engineer
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- M. Cooksey, Supervisor, !&C Maintenance
- B.
Kosmala, NPE Engineer
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R. Reinhart, I&C Supervisor
A. Roller, Nuclear Plant Engineering Manager
- 0. Swan, Technical Services Manager
R. Steele, Safety-Related List Project Manager
T. Walt. Nuclear Safety and Regulation Manager
0. Walters, Control and Electrical Supervisor
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- R. Barr, Senior Resident Inspector
- W. Wagner, Regional Inspector
- Denotes those attending the final exit meeting on August 12, 1988.
The inspectors also contacted licensee operators, engineers, technicians,
and other personnel during the course of the inspection.
2.
Introduction
The purpose of this inspection was to compare the installed plant
instrumentation with the licensee's commitments contained in
correspondence related to Post-Accident Monitoring Instrumentation as
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described in the NRC Safety Evaluation Report.
This inspection also
assessed if the instrumentation meets the criteria specified in
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Regulatory Guide 1.97 Revision 3.
Some of the references used to assess
the licensee's conformance to Regulatory Guide 1.97 were:
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Regulatory Guide 1.97, Revision 3. "Instrumentation for Light
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Water-Cooled Nuclear Power Plant to Assess Project and Environs
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Conditions During and Following an Accident"
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Trojan Updated Final Safety Analysis Report (FSAR), Chapters 3, 7,
and 8.
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Safety Evaluation Report as noted in Memorandum dated September 8,
1986, F. Rosa to J. Neighbors, with Technical Evaluation Report
prepared for the NRC by EG&G Idaho Inc., "Conformance to Regulatory
Guide 1.97, Trojan Nuclear Plant", August 1986, EGG-NTA-7076.
PGE-1043, "Accident Monitoring Instrumentation Review for the Trojan
Nuclear Power Plant", through amendment 1 September,1987.
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The Code of Federal Regulations (CFR) has requirements for post-accident
instrumentation at Nuclear Power Plants.
The General Design Criteria
(GDC) from appendix A of 10 CFR 50 most applicable to Post-Accident
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instrumentation are GDC 13 "Instrumentation and Control" GDC 19,
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"Control Room", and GOC 64, "Honitoring Radioactivity Releases".
GOC 13
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includes a requirement that instrumentation be provided to monitor
variables and systems over their anticipated ranges for accident
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conditions to ensure adequate safety.
GDC 19 includes d requirement that
a control room be provided to maintain the nuclear power unit in a safe
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condition under accident conditions, including Loss-of-Coolant Accidents
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(LOCA), and that necessary instrumentation be provided at appropriate
locations outside the control room with a design capability for prompt
hot shutdown of the reactor.
GDC 64 includes a requirement that a means
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be provided for monitoring the reactor containment atmosphere, spaces
containing components for recirculation of LOCA fluid, effluent discharge
paths, and the Plant environs
for radioactivity that may be released
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from postulated accidents.
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The NRC issued Generic Letter 82-33 which contained Supplement 1 to
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NUREG-0737 and specified requirements regarding emergency response
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capability.
This supplement discussed, in part, the application of
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Regulatory Guide 1.97 to the emergency response facil? ties, including the
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Control Room (CR), Technical Support Center (TSC) and Emergency
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Operations Facility (EOF) at nuclear power plants.
The licensee's
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response to RG 1.97 was provided in letters dated November 23, 1983, May
23, 1984, December 28, 1984, May 13, 1986, and January 26, 1987.
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The NRC issued an order on March 25, 1986, requiring the licensee to
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implement the requirements of Regulatory Guide 1.97, revision 3 by the
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end of the 1987 refueling outage.
The licensee met these requirements,
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except for Quench Tank Temperature and Neutron flux.
The licensee's
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letter dated January 26, 1987 proposed an alternate implementation
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schedule for these 2 variables.
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During a review of these documents, the inspector noted that the NRC SER
stated that the licensee conformed to or was justified in deviating from
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the guidance specified in RG 1.97 except for the variables of Quench Tank
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Temperature and Neutron Flux.
The Quench Tank Temperature had an
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inadequate range and the neutron flux variable h;d to be upgraded to
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class 1E requirements.
These variable are discussed in the inspection
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details section.
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In general, the inspection verified that the licensee had documentation
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onsite that showed the redundancy, physical and electrical separation,
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power sources and interfaces for the instrumentation.
The Q and EQ
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master lists were reviewed for the variables selected, to ascertain
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whether they had 9een evaluated and tested to the appropriate
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environmental, quality assurance (QA) and seismic qualification
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requirements.
The environmental qualification (EQ) requirements are
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tabled below for the instruments by showing the EQ listing er the
environment that that component is located in.
A mild environment does
not need any special qualification.
The seismic listing shown below
notes the class to which that equipment is qualified to, class 1 being
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the highest.
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Regulatory Guide 1.97 divides Post-Accident instrumentation into three
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categories and five types.
The three categories are noted as 1, 2, and
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3.
Category I requirements include full separation, qualification,
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redundancy, and power from class 1E buses.
Category 2 instrumentation
does not need full qualification.
Category 3 requirements are the least
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stringent, that is, commercial grade.
The five types of instrumentation
identified in the Regulatory Guide are types A, B, C. O, and E.
Type A
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are plant specific and classified by the licensee; type 8 variables
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provide information to indicate that plant safety functions are being
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accomplished; type C variables provide information on the breach of
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barriers for fission product release; type 0 variables indicate the
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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,
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which can only be category 1.
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The specific information on the instrumentation inspected is discussed in
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paragraph 3.
This inspectior, focused on variables classified as having
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the most safety significance (class 1 or 2).
Except as noted, the
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requirements for the Class 1 and Class 2 instruments were met.
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3.
Inspection Details
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The inspectors held discussions with various members of the licensee's
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staff, examined drawings, and walked through the control room to assess
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the implementation of the requirements delineated in Regulatory Guide
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1.97, revision 3.
For category 1 instrumentation, the power is supplied
by Class-1E buses.
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The following instrumentation was examined.
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3.1 Neutron Flux
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Regulatory Guide 1.97 classifies this as a Category 1 variable.
The
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licensee has installed a Category 1 channel and is committed to install a
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second (redundant) Category I channel during the 1990 refueling outage.
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The installation in 1990 will include a recorder and will bring Trojan
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into full compliance with the Regulatory Guide 1.97 requirements for this
variable.
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Tag
Seismic Power
Instrument
Number
Function
Listed
Listed
Circuit
Range
NE-48
Detector
72.4.2
Class I
--
--
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NM-48
Preamplifier
Mild
Class I' Y2415
--
NY-48
Sig. Cond.
Mild
class I Y2415
- ,0
N!-48A
Log Indicator.
Mild
Class I
10, to10p
--
NI-488
Count Rate Ind.
Mild
' Class I
10
to 10 cpm
--
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Inspection Findings
The inspectors found that the instrumentation supplied for this variable
does not presently meet the Category 1 recommendations specified in
Modifications are scheduled in 1990 to achieve
full compliance with the Category 1 recommendations for this variable.
3.2 Reactor Coolant System Hot-And Cold Leo Water Temperature
Regulatory Guide 1.97 classifies these as Category 1 variables.
In
addition, the licensee has classified them as Type A variables.
This
instrumentation is used for natural circulation and in preparation for
residual heat removal system operation.
There are four recorders in the
control room, one for each reactor loop.
Each recorder displays the hot
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leg temperature, the cold leg temperature, and the difference between
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them.
Information on the hot and cold leg water temperature
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instrumentation is as follows.
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Tag
Seismic Power
Instrument
Number
Function
Listed
Listed
Circuit
Range
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TE-413A
RTD Hot Leg
15.4.2
Class I
Y2203
--
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TE-413B
RTD Cold Leg
15.4.2
Class !
Y1103
--
0
TIR-413
Recorder
Hild
Class I
Y1114
0 to 700 F
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TE-423A
RTO Hot Leg
15.4.2
Class !
Y2203
--
TE-423B
RTD Cold Leg
15.4.2
Class !
Y1103
--
TIR-423
Recorder
Mild
Class !
Y2218
0 to 700 F
TE-433A
RTD Hot Leg
15.4.2
Class !
Y1103
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--
TE-4338
RTO Cold Leg
15.4.2
Class !
Y2203
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--
TIR-433
Recorder
Mild
Class !
Y1114
0 to 700 F
TE-443A
RfD Hot Leg
15.4.2
Class I
Y1103
--
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TE-443B
RTO Cold Leg
15.4.2
Class !
Y2203
--
TIR-443
Recorder
Mild
Class !
Y2218
0 to 700 F
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Inspection Findings
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The inspectors found that the instrumentation supplied for these
variables meets the Category I recommendations specified in Regulatory
Guide 1.97.
However, the instrument power sources for this
instrumentation are arranged so that the loss of a division of instrument
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power could cause the loss of three channels of hot leg temperature
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instrumentation, three channels of cold leg temperature instrumentation,
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dnd all differential temperature indication.
This is discussed further
in paragraph 5. of this report,
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3.3 Core Exit Temperature
Regulatory Guide 1.97 classifies this as a Category 1 variable.
In
addition, the licensee has classified this as a Type A variable.
There
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are 65 thermocouples separated into 2 divisions.
In each of the two
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divisions there are eight thermocouples that are input to the
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instrumentation for the variable subcooled margin monitor.
These sixteen
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thermocouples, reference junctions, and readout instrumentation are
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installed and mainta1ned as Category 1 instrumentation.
This arrangement
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was approved by the NRC in a safety evaluation report dated December 10,
1985.
Thermocouples RT-4, 5, 17, 19, 22, 29, 32, and 36 are connected
forming the A channel; RT-25, 37, 43, 45, 49, 52, 53, and 62 are
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connected forming the B channel.
Typical information on these
thermocouples is as follows.
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Tag
Seismic Power
Instrument
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Number
Function
Listed
Listed
Circuit
Range
RT-1 (Typical) Thermocouple
71.4.2
Class !
--
--
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JQ-3083
Reference Junction Mild
Class !
Y1111
--
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JQ-4908
Reference Junction Hild
Class !
Y2210
--
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UDIS-1013Al
Indicator
Mild
Class I
Y1313
0 to 2300'F
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UDIS-101381
Indicator
Mild
Class !
Y2413
0 to 2300 F
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Inspection Findings
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The inspectors found that the instrumentation supplied for this variable
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meets the Category 1 recommendations specified in Regulatory Guide 1.97.
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3.4 Reactor Coolant System Pressure
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Regulatory Guide 1.97 recommends Category 1 instrumentation for this
variable.
In addition, the ifcensee has classified this as a Type A
variable.
This instrumentation provides operator information during all
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phases of accident recovery and mitigation.
Information on this
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instrumentation is as follows.
Tag
Seismic
Power
Instrument
Nteber
Function
Listed
Listed
Circuit
Range
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PT-403
Transmitter
37.4.2
Class !
Y1103
--
O to 3000 psig
P!-403
Indicator
Mild
Class !
--
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PT-405
Transmitter
37.4.2
Class !
Y2203
--
O to 3000 psig
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PI-405
Ind.icator
Mild
Class !
--
PR-405
Recorder
Mild
Class !
Y2218
0 to 3000 psig
Inspection Findings
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The inspectors found that the instrumentation supplied for this variable
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meets the Category 1 recommendations specified in Regulatory Guide 1.97.
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_ _ _ _ - _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ __-
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3.' 5 Con +:.inment Pressure
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Regulatory Guide 1<.97 recommends Category 1 instrumentation for this
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variable.
In addition, the licensee has classified this as a Type A
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variable.
The licensee uses this instrumentation to determine the need
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to terminate or to re-initiate safety features that affect containment
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conditions.
Information on the containment pressure instrumentation is
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as follows.
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Tag
Seismic Power
Instrument
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Number
Function
Listed Listed
Circuit
Range
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PT-2087A
Transmitter 39.4.2 Class I Y1313
--
UR-2087A
Recorder
Mild
Class I Y1313
-10 to 190 psig
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PT-20878
Transmitter 39.4.2 Class ! Y2413
--
UR-20878
Recorder
Mild
Class I Y2413
-10 to 190 osig
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Inspection Findings
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The inspectors found that the instrumentation supplied for this variable
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meets the Category 1 recommendations specified in Regulatory Guide 1.97,
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3.6 Refueling Water Storage Tank Level
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Regulatory Guide 1.97 recommends Category 2 instrumentation for this
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variable; however, the licensee has classified this as a Type A variable.
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Therefore, the instrumentation provided should meet Category 1
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requirements.
The refueling water storage tank is the primary source of
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water for the emergency core cooling systems and containment spray.
The
operator observes the level in this tank to determine when to switch from
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the injection mode of operation to the recirculation mode.
The level is
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recorded by the plant computer.
Information on this instrumentation is
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as follows.
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Tag
Seismic
Power
Instrument
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Nurber
Function
Listed
Listed
Circuit
Range
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LT-1899
Transmitter
Mild
Class !
Y1305
--
O to 100%
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L1-1899
Indicator
Hild
Class !
--
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LT-1900
Transmitter
Hild
Class !
Y1107
--
O to 1001,
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L1-1900
Indicator
Hild
Class !
--
LT-1901
Transmitter
Mild
Class !
Y2210
--
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L1-1901
Indicator
Mild
Class !
O to 100%
--
InsnoltynFindings
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The tobcectors found that the instrumentation supplied for this variable
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meets the Category 1 recommendations specified in Regulatory Guide 1,97.
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3.7 Pressurizer Level
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Regulatory Guide 1.97 recomends Category 1 instrumentation for this
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variable.
In addition, the licensee classifies this as a Type A
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variable.
The licensee uses this instrumentation to determine the need
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to terminate or to re-initiate safety injection and to determine the
emergency procedures to be used.
Information on this instrumentation is
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as follows.
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Tag
Seismic Power
Instrument
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Number
Function
Listed Listed
Circuit
Range
__
LT-459
Transmitter
38.4.2 Class ! Y1103
--
LI-459A
Indication
Mild
Class I
O to 100%
--
LR-459
Recorder
Mild
Class I
O to 1004
--
LT-460
Transmitter
38.4.2 Class ! Y2203
--
LI-460A
Indicator
Mild
Class !
O to 100%
--
LT-461
Transmitter
38.4.2 Class ! Y1303
--
LT-461A
Indicator
Mild
Class I
O to 100%
--
Inspection Findinos
The inspectors found that the instrumentation supplied for this variable
meets the Category 1 recommendations specified in Regulatory Guide 1.97.
3.8 Pressurizer Heater Current
Regulatory Guide 1.97 recommends Category 2 instrumentation for this
variable.
This instrumentation is used to monitor the operation of the
pressurizer heate* banks.
Information on the pressurizer heater current
instrumentation is as follows.
Tag
Power
Instrument
Number
Function
Listed
Circuit
Range
C13-03M
Ammeter
Mild
80922
0 to 800 Amp
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C13-04H
Ammeter
Hild
B1022
0 to 800 Amp
C13 05M
Ammeter
Mild
80912/81031
0 to 800 Amp
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C13 06M
Ammeter
Hild
81012
0 to 800 Amp
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Inspection Findings
The inspectors found that the instrumentation supplied for this variable
meets th6 Category 2 recommendations specified in Regulatory Guide 1.97.
3.9 Steam Generator level
Regulatory Guide 1.97 recommends one Category 1 instrument channel per
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Steam generator for this va-table.
In addition, the Itcensee has
classified this as a Type A v. inble
The licensee uses this wide range
instrumentation to determine the availability of the steam generators as
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heat sinks, to verify the adequacy <f auxiliary feedwater flow, and to
identify steam generator tube rupture events.
Two dual-pen recorders
display the four wide range steam generator level channels.
Information
on the wide range steam generator le'.e1 instrumentation is as follows.
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Tag
Seismic
Power
Instrument
Number
f, unction
Listed
Listed
Circuit
Range
LT-501
Transmitter
38.4.2
Class !
Y2212/Y2414
l
--
LT-502
Transmitter
38.4.2
Class !
Y1112/Y1314
i
--
LR-501
Recorder for
Mild
Class !
Y2218
0 to 100%
,
LT-501 & 502
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LT-503
Transmitter
38.4.2
Class !
Y1112/Y1314
--
.
[
LT-504
Transmitter
38.4.2
Class !
Y2212/Y2414
--
LR-502
Recorder for
Mild
Class !
Y1114
0 to 100%
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LT-503 & 504
Inspection Findings
f
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 instrument power sources are arranged such that the loss of a
division of instrument power could cause the loss of three channels of
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this instrumentation.
Two steam generators are needed to assure safe
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shutdown capability.
This is discussed further in paragraph 5. of this
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report,
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3.10 Steam Generator Pressure
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Regulatory Guide 1.97 recommends Category 2 instrumentation for this
variable; however, the licensee has classified this as a Type A variable.
[
Therefore, the instrumentation provided should meet Category I
requirements.
The licensee uses this instrumentation to verify the
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correct pressure in the steam generators that are not affected by a steam
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generator tube rupture event and to diagnose the loss of secondary
coolant in a tube rupture event.
The plaat computer records the signals
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from this instrumentation.
Information on the steam generator pressure
instrumentation is as follows.
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Tag
Seismic
Power
Instrument
!
f
Number
Function
Listed
Listed _
Circuit
Range
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PT-514
Transmitter
40.4.2
Class !
Y1103
--
PI-514A
Indicttor
Mild
Class !
O to 1200 psig
--
,
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PT 515
Transmitter
40.4.2
Class !
Y2203
--
P!-515A
Indicator
Hild
Class !
O to 1200 psig
l
--
PT-516
Transmitter
40.4.2
Class !
Y2403
--
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P!-516A
Indicator
Mild
Class !
O to 1200 psig
--
PT-534
Transmitter
40.4.2
Class !
Y1103
--
P!-524A
Indicator
Mild
Class !
O to l'.00 psig
l
--
PT-525
Transmitter
40.4.2
Class !
Y2203
!
--
P!-525A
Indicator
flild
Class !
O to 1200 psig
--
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PT-526
Transmitter
40.4.2
Class !
Y1303
--
PI-526A
Indicator
Mild
Class !
O to 1200 psig
--
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- .
_- - - -_ _ __-
_
_ _ _ _ _ _ _ _
_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
_ _ _
_
---
-
_ _ _ _ ,
t
.
r
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'
9
.
7 -
.
Tag
Seismic
Power
Instrument
Number
Function
Listed
Listed
Circuit
Range
PT-534
Transmitter
40.4.2
Class !
Y1103
--
i
O to 1200 psig
.PI-53(A
Indicator
Mild
Class I
--
PT-535
Transmitter
40.4.2
Class !
Y2203
--
,
O to 1200 psig
PT-535A
Indicator
Mild
Class I
--
,
PT-536
Transmitter
40.4.2
Class I
Y1303
--
PT-M6A
Indicator
Hild
Class !
O to 1200 psig
--
PT-544
Transmitter
40.4.2
Class !
Y1103
--
0 to 1200 psig
PT-544A
Indicator
Mild
Class !
--
t
PT-545
Transmitter
40.4.2
Class I
Y2203
--
PT-545A
Indicator
Mild
Class !
O to 1200 psig
--
PT-546
Transmitter
40.4.2
Class I
Y2403
i
--
O to 1200 psig
PT-546A
Indicator
Hild
Class 1
--
Inspection Findings
.
The inspectors found that the instrumentation supplied for this variable
[
meets the Category I recommendations specified in Regulatory Guide 1.97.
,
3.11 Condensate Storage Tank level
Regulatory Guide 1.97 recommends Category 1 instrumentation for this
I
variable.
In addition, the licensee classifies this as a Type A
variable.
This instrumentation is used to determine the availability of
3
water for the auxiliary feedwater purps and to determine the need to
manually transfer the feedwater pump suction to the secondary source of
water (the service water system).
The plant cor.puter records the signals
!
from this instrumentation.
Information on the condensate storage tank
level instrumentation is as follows.
,
.
Tag
Seismic
Power
Instrument
Number
Function
Listed
Listed
Circuit
Range
l
l
./ LT-5201
Transmitter
Hild
Class !
Y1112
--
LI-5201
Indicator
Hild
O to 100%
--
'
'
'
LT-5265
Transmitter
Hild
Class !
Y2212
--
LI-5265
Indicator
Hild
O to 100%
--
a
Meets original plant seismic licensing criteria, but not class I.
l
Inspection Findings
i
The licensee comitted to upgrade the instrumentation for this variable
i
to include seismic qualification; however, the indicators have not been
[
replaced.
The licensee's comittment is discussed in the Inspector
i
Observations section.
The present indicators are in accordance with the
t
original plant licensing basis seismic criteria.
Except for the question
on seismic qualification, the inspectors find that the instrumentation
I
supplied for this variable meets the Category 1 recommendations specified
Seismic qualification of this instrumentation
f
is further discussed in paragraph 5. of this report.
[
!
!
'
_ _ _ _ _ _ _ _ _
_ _ . . - _ . .
_
_ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ ,
.
10
.
3.12 Status of Standby Power
Regulatory Guide 1.97 recommends plant specific Category 2 instrumentation for
this variable.
This instrumentation is used to monitor the operation of the
emergency power system.
Information on this instrumentation is as follows.
Tag
Power
Instrument
Number
Function
Listed
Monitor
Range
VAR-0G1
Mild
Diesel Generator 1
1000 to 3500 KVARS
VAR-DG2
Mild
Olesel Generator 2
1000 to 3500 KVAR$
W-0G 1/1
Watts
Hild
Diesel Generator 1
0 to 5000 KW
W-0G 2/1
Watts
Mild
Diesel Generator 2
0 to 5000 KW
V-A1/2
Volts
Mild
Bus A1
0 to 5250 V
V-A2/2
Volts
Mild
Bus A2
0 to 5250 V
V-A5/2
Volts
Hild
Bus A5
0 to 5250 V
V-A6/2
Volts
Mild
Bus A%
0 to 5250 V
RPM-0G1/
Speed
Mild
Diesel Generator 1
0 to 1200 rpm
F-0G1/1
Frequency
Mild
Diesel Generator 1
55 to 65 rpm
F-0G2/1
Frequency
Mild
Diesel Generator 2
55 to 65 rpm
A-A101/2
Current
Mild
Bus A1 Offsite Current 0 to 1200 A
A-A201/2
Current
Hild
Bus A2 Offsite Current 0 to 1200 A
A-A501/2
Current
Mild
Bus A5 Offsite Current 0 to 1200 A
A-A601/2
Current
Mild
Bus A6 Offsite Current 0 to 1200 A
A-A113/2
Current
Mild
480V Transformer 1
0 to 150 A
High Side Current
A-A207/2
Current
Hild
480V Transformer 2
0 to 150 A
Migh Side Current
A-A107/2
Current
Hild
480V Transformer 3
0 to 150 A
High Side Current
A-A213/2
Current
Hild
480V Transformer 4
0 to 150 A
High Side Current
inspection Findings
The inspectors found that the instrumentation supplied for this variable
meets the Category 2 recommendations specified in Regulatory Guide 1.97.
3.13 Quench Tank Temperature
This variable is classified as a category 3 variable, with no spectat
qualification required.
The NRC identified in its review of the
licensee's submittal that this variable had an inadequate range.
As
identified in the SER, the range had to be extended to where *,he rupture
g
disc would rupture (100 psi implies 338 F).
The new instrument was
installed under Plant Configuration Change (PCC)87-505.
This was
reviewed by the inspector and no problems were identified.
The inspectors verified that an instrument had been installed in the
control room to aget or exceed the range.
The range in the control room
is now 50 to 350
F.
_.
-_ _ ______ ___ -- _-____-_-____ _-_____ ____
_ _ ____-_-_-__ _ - _ __ _ -__ _ - ____
_-
.
.*
11
j
l
4.
Service, Testino, and Calibration
f
The ir,spectors reviewed the calibration data sheets to verify that the
instruments were in calibration.
For the instruments identified in the
!
report, all were found to be in calibration.
'
The inspectors noted that several of the calibration records for the
pressurizer heater current and status of standby power variables were
provided by the electrical shop (relay and breakers), instead of !&C.
[
The inspectors noted that the licensee did not have all the official
i
records available for pressurizer heater current.
Some unofficial
(
records were found that verified that the ammeters were in calibration,
r
The inspectors were informed that these were not quality records.
In
that Regulatory Guide 1.97 recommends that quality records of
calibrations of category !! instrumentation be maintained, the inspectors
asked the Itcensee to conduct an audit of how these records are
-
administrative 1y controlled.
The licensee committed to audit this
!
function.
This will be followed up in a future inspection
(50-344/88-36-01).
5.
Inspector conclusions
.
The inspectors verified that the licensee had documentation onsite that
i
showed the seismic and environmental qualification, redundancy,
separation, and calibration of the instruments reviewed.
The inspectors
i
toured the control room and remote shutdown panel to verify the ranges
l
l
and separation of the instruments.
The specified ranges were met and the
L
'
panels were appropriately separated.
!
,
e
The inspectors identified two problems at Trojan with respect to
(
'
]
These relate to a missed commitment on seismic
j
qualification of the Condensate Storage Tank level instruments and lack
t
j
of full redundancy on some instruments.
The specifics of these problems
l
are as follows:
[
l
{
J
A.
The Itcensee did not meet a commitment made to the NRC on the
$
Condensate Storage Tank (C5T).
The NRC reviewed the licensee's
4
j
submittal dated December 28, 1984 with respect to Regulatory Guide
j
1.97.
In a letter dated March 3, 1986, the NRC asked the licensee
1
to provide justification for 12 items which were different than RG
l
1.97 rec meendations.
One of the items identified by the NRC was
j
that the CST level was a category 1 variable, but did not have full
seisaic class ! qualification.
The NRC asked the licensee to
t
,
i
l
respond within 60 days providing additional justification on these
12 items.
j
The licensee responded to these items in a letter dated May 13,
]
1986.
In this letter, the licensee committed to provide full
{
Seismic Class 1 instrumentation for the CST 1evel indication by the
.
,
!
end of the 1986 refueling outage. The SER for Trojan accepted this
variable on the basis of this corvnitaent.
'
Ouring the inspection, it was identified that the commitment had not
i
been met, since the indication portion of the loop has not been
f
l
seismically qualified.
The licensee generated Non Conforming
-
j
Activity Report (NCAR) H88-86M on this missed comitment.
This is
[
.
,
i
- - . .
- -
i
_ _ _ _ _ _ _ _ _ .
- __ _ -____________- _ _- -.
_- -_ - -
__ _
. _ _ _
.
12
l
.
an apparent deviation (50-344/88-36-02).
The inspectors have a
concern with the licensee's commitment tracking system. The root
'
,
cause as to why the commitment was missed, the actions to prevent
!
,
reoccurrence and the licensee's action to meet the commitment will
.
j
be followed up as part of the NRC review of this deviation.
[
t
The CST is not a seismic category I structure, and is not the
'
>
seismic source of water to the steam generators.
The CST level
,
J
instrumentation is qualified to the original seismic licensing
!
"
basis.
Regulatory Guide 1.97 does not require seismic class !
instrumentation on tanks that are not required to be seismic class
!
~
I.
The inspectors recommended that the licensee discuss this issue
t
with NRR, or upgrade it to the commitment made.
!
!
l
B.
The inspectors identified that several class 1E post-accident
i
variables did not meet the full redundancy requirements as specified
!
j
in the Regulatory Guide.
These variables are the hot leg
i
temperature (Thot), the cold leg temperature (Tcold), and the wide
.
I
range steam generator level.
The hot leg and cold leg are also used
'
I
to give indication of the differential tempwature across the core.
l
These variables are discussed in sections 3.2 and 3.9.
,
<
?
'
l
The licensee provided the following rationale for how these
[
indications were installed not meeting full redundancy.
These
i
variables were originally installed as non-class IE.
These
variables were upgraded to class 1E requirements as a result of the
}
j
accident at Three Mile Island.
As part of the upgrades, the
J
licensee did a detailed control room design review (DCROR).
Part of
i
the OCRDR installed new recorders for the hot leg temperature, cold
[
'
j
leg temperature, and steam generator wide range level.
The Itcensee
I
had previously split the transmitters on the Reactor Coolant System
l
(RCS) hot leg and cold leg into different trains, with train A and
i
train 8 temperature indication on the same RCS loop.
Following the
i
DCRDR, each of the loops shows the hot leg, cold leg and
f
l
differential temperature on 1 recorder.
The licensee stated that
the indications were arranged this way to meet Human Factors
i
]
considerations of the OCRDR.
With the new recorders installed with
j
l
Class ! indication, the recorders were also powered off of class IE
!
power.
However, with these new recorders, a loss of power to the
l
'
!
recorder leads to loss of all indication on that recorder,
i
!
!
j
This can lead to the following situation involving a single failure,
f
If the loss of vital instrument bus Y11 is postulated, the licensee
I
r
I
i
will only have loop 2 Thot, loop 4 Tcold, Loop 1 wide range steam
generator level and no indication of differential temperature.
If
the loss of vital instrument bus Y22 is postulated, the licensee
i
will have loop 3 Thot loop 1 Tcold, no indication of differential
j
,
temperature and Loop 3 wide range steam generator level.
i
t
l
The inspectors discussed this problem with the licensee.
The
j
licensee agreed that there is a problem with this lack of full
,
redundancy.
The inspectors were informed by the licensee that this
t
,
'
arrangement was done purposely, as the space on the control board
j
was limited, to meet human factors considerations, and that the loss
!
-
i
-
t
.
.
- - -
- . -
- - ___
-
.-
..
-
- - -
-
g
-
.
-
.
13
.
.
.
I
of a vital bus was a very low probability event.
The licensee
stated in PGE 1043 that there were diverse variables that could holp
'
in giving indications of hot leg tempereture (Core Exit
^mperature), cold leg temperature (Steam Generator Pressure with
Tables), and backup indication for steam generator wide range
!
. (Narrow Range Level).
This diverse indicetion for these
)les does not eliminate the issue of single failure for the
mentation.
The backup variable is not recognized in the
,
atory Guide.
!
.. inspectors were informed that the licensee uses the differential
temperature to help in cooling down the plant.
The loss of 1
!
division of power now results in loss of all direct indication of
differential temperature.
This plant also requires two steam
generators to cool down (As noted in Tech. Spec Basis 3/4.4.5).
The
-
less of either vital bus will only leave one indication of wide
range level.
The licensee would have to rely on other indications
for the level in the other steam generators.
Regulatory Guide 1.97 states that for category 1 instrumentation,
"No single failure in the instrumentation, auxiliary supporting
featbres or power sources concurrent with the failures that are a
condition or result of a specific accident should prevent the
operators from being presenteu the information necessary to
determine the safety status of the plant and to bring the plant to
and maintain it in a safe shutdown condition." This one failure (of
either vital instrument bus) leaves the operator with minimal
information on these variables used in cooling down the plant unless
<
the operator relies on other diverse indication.
This lack of full
redundancy on the power sources and instrumentation for these 3
.
variables is an unresolved item, pending a review of the licensee's
actions to resolve the apparent conflict between the DCRDR and RG 1.97 requirements (50-344/88-36-03).
6.
Exit Meeting
I
I
On August 12, 1988, an exit meeting was held with the licensee
j
representatives identified in paragraph 1.
The inspector summarized the
inspection scope and findings as described in this report.
i
i
e
i
P
,
,
,
.1
4