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Insp Rept 50-458/88-08 on 880216-0331.Violation Noted.Major Areas Inspected:Licensee Action on Previous Insp Findings, Status of Facility OL Conditions,Nrc Bulletin 80-70,10CFR21 Repts & Surveillance Test & Maint Observations
	ML20153C018
Person / Time
Site:	River Bend
Issue date:	04/29/1988
From:	Chamberlain D, Holler E, William Jones; NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION IV)
To:	;
Shared Package
ML20153C013	List: ML20153C009; ML20153C014; ML20153C018;
References
	50-458-88-08, 50-458-88-8, IEB-80-70, NUDOCS 8805060132
	Download: ML20153C018 (15)
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APPENDIX B

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U. S. NUCLEAR REGULATORY COMMISSION

REGION IV

NRC Inspection Report: 50-458/88-08

Docket: 50-458

Licensee: Gulf States Utilities Company (CSU)

P. O. Box 220

St. Francisville, Louisiana 70775

Facility Name: River Bend Station (RBS)

Inspection At: River Bend Station, St. Francisville, Louisiana

Inspection Conducted: February 16 through March 31, 1988

Inspectors: ,' 88

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D. D.VChamberlain, Senior Resident Inspector Date

Project Section C, Division of Reactor Projects

_M o k 3. b

W. B. Jones, ResidenthInspector

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Project Section C, bivision of Reactor Projects

Approved:

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E. J.' Holler, Chief, Project Section C Dite '

Division of Reactor Projects

8805060132 880502

PDR ADOCK 05000459

Q DCD

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Inspection deport

~ Inspection Conducted February 16 through March 31, 1988

(Report 50-458/88-08)

Areas Inspected: Routine, uncnnounced inspection of licensee action on

previous inspection findings, status of facility operating license conditions,

NRC Bulletin 80-70, 10 CFR Part 21 Reports, surveillance test observation,

maintenance observation and operational safety verification.

Results: Within the areas inspected, one violation was identified (inadequate

alarm response procedure, paragraph 8).

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DETAILS

1. Persons Contacted

D. L. Andrews, Director, Nuclear Training

W. J. Beck, Supervisor, Reactor Engineering

J. E. Booker, Manager, Oversight

E. M. Cargill, Supervisor, Radiation Programs

J. W. Cook, Lead Environmental Analyst, Nuclear

Licensing

T. C. Crouse, Manager, Quality Assurance

J. C. Deddens, Senior Vice President, River Bend

Nuclear Group

D. R. Derbonne, Assistant Plant Manager, Maintenance

L. A. England, Director, Nuclear Licensing

R. W. Frayer, Director, Projects

P. E. Freehill, Outage Manager

A. O. Fredieu, Supervisor, Operations

P. D. Graham, Assistant Plant Manager, Operations

J. R. Hamilton, Director, Design Engineering

G. K. Henry, Director, Quality Assurance Operations

B. E. Hey, Nuclear Engineer, Design Engineering

G. R. Kimmell, Director, Quality Services

R. J. King, Supervisor, Nuclear Licensing

A. D. Kowale;uk, Director, Oversight-

J. W. Leavines, Director, Field Engineering

I. M. Malik, Supervisor, Quality Systems

J. H. McQuirter, Licensing Engineer

T. G. Murphy, Supervisor, Planning and Scheduling

V. J. Normand, Supervisor, Administrative Services

W. H. Odell, Manager, Administration

T. F. Plunkett, Plant Manager

C. A. Rohrmann, Training Systems Coordinator

M. F. Sankovich, Manager, Engineering

J. P. Shippert, Operations Engineer

K. E. Suhrke, Manager, Project Management

R. J. Vachon, Senior Compliance Analyst

J. Venable, Assistant Operations Supervisor

T. L. Weir, Director

R. G. West, Supervisor, General Maintenance

NRC

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E. J. Holler, Chief, Project Section C, Division of Reactor Projects

D. D. Chamberlain, Senior Resident Inspector

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The NRC inspectors also interviewed additional licensee personnel during !

the inspection period.

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Denotes those persons that attended the exit interview conducted on

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April 6, 1988. l

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2. Licensee Action on Previous Inspection Findings

a. (Closed) Violation (450/8729-01): Failure to follow procedure for -

control of locked valves.

This violation resulted when'a nuclear equipment operator unlocked [

and closed a normally locked open valve using the emergency key t

without notifying the control room staff. The operator was !

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transferring the control rod drive (CRD) pump suction path from the s

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condensate storaga tank to the condenser, utilizing the station

operating procedure, when he misunderstood the directiens provided

and closed the condensate storage tank suction line. The Assistant

Plant Manager-Operations issued a memorandum reiterating the

licensee's policy for adherence to all procedures and to ensure that !

all individuals involved in an evolution understand the task to be

performed. Station Operating Procedure (50P) SOP-0002, "Control Rod :

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Drive Hydraulics," was revised to add a caution statement for the

transfer of the CRD pump suction path. The remaining SOPS were also !

reviewed to detertaine if additional instructions or cautions were ;

needed for other plant evolutions. Finally, licensee management ;

personnel reviewed the precedures for controlling locked valves with ;

each shift crew. The resident inspector attended three of these r

discussions and found the review to be adequate.

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This violation is closed. l

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(Closed) Violation (458/8531-01): Failure to identify all valves in

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the valve lineup check sheet, required to conduct the integrated leak

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rate test. i

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The licensee has revised Surveillance Test Procedure STP-057-3703,

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"Primary Containment Integrated Leak Rate Test," to include the six

differential pressure instruments and the one motor operated valve .

l that were omitted from the original valve lineup in i

L preoperational/ acceptance test procedure 1-PT-57-1. These valves !

i have been added to the valve lineup in STP-057-3703, utilizing f

Temporary Change Notice 87-1748. [

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! This violation is closed. :

l c. (Closed) Violation (458/8727-02): Failure to initiate hot work ;

' permit for grinding activity. '

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This violation involved the failure to secure a valid Hot Work Permit i

! and to establish a designated fire watch for grinding activities on l

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the Inboard Main Steam Isolation Valve 1821*A0V022B, The Assistant

Plant Manager-Maintenance issued Memorandum Number APM-M-87-342 which

promulgates the licensee's requirement for adherence to procedures.

The NRC inspectors have observed similar activities requiring a Hot

Work Permit and establishment of a designated fire watch since the

issuance of the above memorandum,- No further problems in this area

have been identified.

This violation is closed,

d. (Closed) Violation (458/8716-01): Failure of followup action by the

licensee to assure that specified corrective action for an NRC

violation and a deviation had been completed.

The specified corrective actions have now oeen ccmpleted and

verified. The licensee established a task force to review all

previously identified corrective actions for NRC findings. Overdue

items identified by the task force have all been completed. Field

engineering has implemented a work tracking system which includes

corrective actions for NRC items. Individual departments have

assigned department coordinators to assure prompt attention and high

priority to corrective actions for NRC items and other items.

Monthly trend information is provided to senior management. The

additional tracking and management attention should prevent

recurrence of this problem.

This violation is closed.

e. (Closed) Violation (458/8720-05): Failure to verify diesel fuel oil

properties within 31 days as required by Technical Specifications.

Subsequent verification by the licensee revealed that all required TS

fuel oil properties were met. The licensee has entered TS fuel oil

analysis requirements in the River Cend Surveillance Test Procedure

Tracking Program to prevent future occurrences of this nature. TS

training has been completed for the chemistry supervisor and

applicable staff members.

This violation is closed.

f. (Closed) Unresolved Item (458/8720-07): Two instances of misaligned

instrument valves identified by the licensee.

Both of these instances of misaligned instrument valves were

evaluated by the NRC to determine enforcement action for a subsequent

case of misaligned instrument valves. This is documented in NRC

Inspection Report 458/8728. Violation 8728-01 was issued for this

subsequent case. Licensee corrective actions will be documented in

response to this violation.

This unresolved item is closed.

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g. (Closed) Violation (458/8724-02): Failure to utilize the proper

revision of a surveillance test procedure for daily fire door

position checks.

The licensee has performed the surveillance test to the correct

procedure and a review of past surveillance tests conducted revealed

that no other tests had been conducted to the incorrect revision.

Security personnel have received additional training to provide

instruction on obtaining the correct procedure. Plant security has

also been placed on distribution for procedure changes to the daily

fire door position' surveillance test.

This violation is closed,

b. (Closed) Violation (458/8724-01): Inadequate 50P for the fuel pool

cooling and cleanup system.

This procedure allowed a siphen path of the upper fuel pool to be

established to the condensate storage tank. The problem was

compounded with inadequate controls on anti-siphon devices. The fuel

pool siphon event and licensee corrective actions are fully described

in NRC Inspection Report 458/8724. The licensee has completed all

corrective actions which included drilling redundant anti-siphon

holes in the upper and lower fuel storage pools.

This violation is closed,

i. (Closed) Unresolved Item (458/8640-03): Reactor core isolation

cooling (RCIC)/ residual heat removal (RHR) steam lina break

instrument setpoint.

The licensee had experienced problems with water formation in the

instrument lines for the RCIC/RHR steam line break instrument. This

water formation caused an instrument offset of negative 110 inches of

water during RCIC system operation. During the first refueling

outage in 1987, the licensee implemented a design modification to

correct the problem. Testing conducted during plant startup in 1988

revealed that the water column formation condition has been corrected

by the design modification.

This unresolved item is closed.

J. (Closed) Violation (458/8636-01): Inadequate safety evaluation for a

temporary modification to the control building ventilation system.

The licensee identified that the safety evaluation for the temporary

modification which removed a low air flow trip was inadequate. The

evaluation failed to recognize that the automatic start of the

redundant division of control building ventilation was also affected

under certain conditions. The licensee took immediate action to

restore the temporary alterations to the original uesign

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configuration. The licensee also performed an engineering evaluation

which verified that manual operator actuation of the redundant system

after 20 minutes would have prevented any room temperatures from

exceeding the design basis temperatures. A review of other temporary

alterations and prompt design changes revealed no other problems with

safety evaluations. The temporary alteration program has been

discontinued at River Bend. Additional procedural controls and

training have been implemented to strengthen the safety evaluation ,

process for design modifications.

This violaticn is closed,

k. (Closed) Violation (458/8620-02): Engineering piping and instrument

drawing (P&ID) differences between the actual system configuration

and procedures. ,

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The licensee has corrected the specific differences identified by the

NRC inspector. Additional procedural controls to ensure replacement

of vent and drain line pipe caps have been implemented. Locked valve

criteria have been examined and consistency with procedures and i

drawings have been established. A 100 percent review of 220 P& ids

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have been completed and any discrepancies identified have been

incorporated into design modifications to update the drawings.

This violation is closed. ;

1. (Closed) Open Item (458/8040-04): Monitor licensee corrective

actions for turning vane failures in ventilation system ductwork.

The licensee's corrective action for this problem included repair of i

cracked dampers and removal of certain dampers of the annulus mixing

system. The licensee also inspected other high velocity systems and

no other turning vane problems were found. The dampers that were ,

repaired in the annulus mixing system were replaced with a heavy duty ;

assembly designed to withstand the inherent high velocity and i

turbulent flow conditions of this system. These repairs have

performed satisfactorily for about 2 years. Based on the repairs and ,

inspections performed to date, the licensee has determined that the i

turning vane problems were limited to the initial failures discovered <

in the annulus mixirg system. No further corrective actions or !

inspections are deeued necessary.

This open item is closed.

m. (Closed) Violation (458/8720-06): Failure to include necessary

quality assurance (QA) controls in a procurement document for

analysis of emergency diesel generator fuel oil.

The existing vendor supplying laboratory analysis services did not

have a program to implement applicable 10 CFR Part 50, Appendix B,

requirements for services provided. The licensee has recently

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contracted with E. W. Saybolt & Company, Inc. for diesel generator

fuel oil analysis. This vendor has recently implemented a QA program

which was surveyed and evaluated by Gulf States Utilities. A

Contract for services has been released based on this preaward survey '

and resolution of outstanding issues.

This violation is closed.

3. Status of Facility License Condition

(Closed) License Condition (?.C.7): "Prior to startup following the first

refueling outage, GSV shall implement design modifications to improve the

capabilities of existing bypassed and inoperable status indication used to -

monitor the status of safety-related systems. The specific design changes '

to be implemented are identified in a GSU letter dated December 3,1984, j

as clarified in a GSU letter dated March 5,1985." 1

The licensee has installed an additional plant alarm panel in the main

control room to implement the additional bypass / inoperable status

indications defined in USAR Table 7.5-12. This new alarm panel

supplemented existing control room alarms. These alarm indications were

tested and placed in operation following the first refueling outage at

River Bend. ,

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License Condition 2.C.7 is closed.

4. Licensee Action on NRC Bulletin 80-70

This area of the inspection was conducted to review licensee actions

relative to NRC Bulletin No. 80-70, "Cracking and Failure of Jet Pump Hold I

Down Beam Assemblies." The licensee's action on this bulletin was

addressed in NRC Inspectior Report 458/85-54, paragraph 4. This bulletin

remained open pending issuance of the inservice inspection (ISI) plan. '

The resident inspector reviewed Appendix J of the licensee's ISI Plan

issued May 19, 1987. This appendix establishes the frequency for reactor

vessel exams which includes the entire jet pump exam, jet pump sensing

lines, jet pump riser brace, jet pump hold down beam, jet pump bolt and

weld assembly, and reactor pressure vessel weld.

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j This NRC bulletin is closed,

i 5. 10 CFR Part 21 Reports

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The resident inspector was provided copies of selected 10 CFR Part 21 I

reports by NRC Region IV, which may be applicable to equipment or services ,

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supplied to River Bend. These reports were provided to the licensee, who

verified that the reports either had been or were being evaluated for

applicability at River Bend. Any reports that were not already entered

into the licensee tracking system were immediately entered. A listing of

j reports by date, manufacturer, and subject is provided below:

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September 16, 1986 - General Electric Company - Potential defect with

solenoid valve rebuild kits for control rod drive hydraulic control

units.

January 19, 1988 - Limitorque Corporation - Improperly sized terminal

lugs to motor leads. (Report submitted by Gulf States Utilities)

The resident inspector will continue to provide copies of potentially

applicable 10 CFR Part 21 reports for licensee evaluation and a followup

of licensee action on selected 10 CFR Part 21 reports will be conducted

during future NRC inspections.

No violations or deviations were identified in this area of the

inspection.

6. Surveillance Test Observation

During this inspection period, the resident inspector observed the

performance of Surveillance Test Procedures STP-505-4503, "RPS/ Control Rod

B'ock-APRM Weekly CHFUNCT, Weekly CHCAL (C51*K6050) and 18 Month LSFT,"

6TP-508-4514, "Turbine Stop Valve Closure Monthly CHFUNCT (C71-N006

Channels A thru H," STP-110-0101, "Turbine Overspeed Protection System

Weekly Operability Test," STP-051-0201 "RPS-Main Steam Isolation

Valve-Closure Monthly CHFUNCT," and STP-509-0101, "Main Turbine Bypass

System Valve Cycle Test." The following observations were made during the

performances of the above surveillance tests:

STP-505-4503 - This surveillance procedure was performed on March 25,

1988, with the reactor in operational condition 1, to satisfy the

weekly channel functional tests required by River Bend Station (RBS)

Technical Specification (TS) for the reactor protection system (RPS)

- average power range monitor (APRM) and control rod block-APRM

instrument (CSI-APRM C). The APRMs are required to be operable when

the reactor is in operational condition 1, 2, 3, 4 or 5. The

instrumentation and control (I & C) technicians obtained permission

from the control operating foreman (C0F) prior to initiating this

STP. Communications were established between the two I&C technicians

located at the instrument and the H13-P680 control panel. The

at-the-controls (ATC) operator was notified prior to a RPS half-scram

being inserted and was immediately notified when the RPS half-scram

could be reset. The required jumpers were controlled in accordance

with General Maintenance Procedure GMP-042, "Circuit Testing and

Lifted Leads and Jumpers." During restoration, a 75 percent

indicated power swing was observed on local power range

monitor (LPRM) 4-C-30-15. After approximately 10 minutes, the LPRM

returned to the expected indicated power. Maintenance Work

Request (MWR) 115028 was initiated to investigate the cause for the

erratic power swings. '

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STP-508-4514 - This surveillance procedure was performed on March 26, ,

1988, with the reactor at 79 percent power. This STP is required to I

be performed monthly with the reactor in operational condition 1, to

meet the TS requirements for channel fuxtional testing of the RPS ,

t turbine stop valve closure and the end of cycle recirculation pump t

trip system turbine stop salve closure (C71-N006) Channels A !

through H. Thissurveillancetestwasperformedinconjunctionwith

STP-110-0101, "Turbine Overspeed Protection System Weekly Operability

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, Test." Direct communications were maintained between the I&C :

technicians and ATC operator to minimize the time the turbine stop

valves remained closed. The licensee determined that all the

acceptance criteria was met and the test results were properly

reviewed by the C0F. [

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STP-110-0101 - This STP was performed on March 26, 1988, with the :

reactor at 79 percent thermal power. This surveillance was performed !

to test each high pressure turbine stop valve, high pressure turbine !

control valve, low pressure turbine intermediate stup valve and low

pressure turbine intercept valve. This surveillance is required to

! be performed every 7 days when the plant is in operational

condition 1 or 2 to satisfy TS 4.3.8.2.a. This activity was closely

supervised by the shift supervisor and plant parameters were allowed ,

to steady out prior to cycling the next valve. The expected RPS !

half-scrams were received when the turbine control valves were l

cycled. All test acceptance criteria were met and the test results !

reviewed and accepted by the C0F, :

STP-509-0101 - This STP was performed on March 26, 1988, with the

reactor aT79 percent thermal power. This surveillance test

demonstrates the operability of each of the two turbine bypass valves

by cycling each valve through one complete cycle. This surveillance

must be performed at least once every 7 days with the reactor in !

1 operational condition 1 as specified in TS 4.7.9.a. Full valve '

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travel was verified through indication of bypass valve position and a t

decrease in megawatt electri'c output. Each valve was observed to ;

perform as expected. !

STP-051-0201 This surveillance was performed on March 26, 1988,

with the reacIor at 79 percent rated thermal power. This monthly STP

implements the requirement of TS Section 4.3.1.1 Table 4.3.1.1-1.6 to

4 perform a channel functional test of the RPS main steam line

isolation valve (MSIV) closure instrumentation. The MSIVs were

tested individually using the slow closure feature. The RPS

half-scram was observed to actuate prior to the MSIV indicating ,

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mid position, which actuates at approximately 10 percent closed, as !

expected. The MSIV was immediately allowed to reopen once the ,

intermediate position was indicated. The ATC operator closely !

, monitored main steam line flow instrumentation to ensure that the [

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MSIV was not traveling fully closed. Communications were maintained

5etween the ATC operator and the operator during the performaace of *

the MSIV channel functional surveillance.

No violations or deviations were identified in this area of_the

inspection.

7. Maintenance Observation

On March 30, 1988, the licensee placed the Division II diesel generator in

the maintenance mode to perform required preventive maintenance. The

plant entered a 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months limiting condition of operation (LCO) as required

by the RBS TS 3.8.1. All of the Division I and III emergency core cooling

systems and support systems remained operable during this LC0 period. The ~

resident inspector verified that the required clearance had been initiated

in accordance with Admini*:rative Procedure ADM-0027,"Protective Tagging."

Each of the valves and breakers identified on the clearance (88-0338) were

observed to be in their correct positions as specified by the clearance

order. After completion of the preventive maintenance activities, the

clearance was released and a post-maintenance test performed to verify i

diesel generator operability. No problems were identified during the

performance of the maintenance activities that could have resulted in the

diesel generator not being able to fulfill its safety function. The

a following preventive maintenance work activities were observed and/or

f maintenance packages reviewed:

i P516420 - This maintenance activity involved inspection of the

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governor linkages for wear and loose parts. The licensee found the

j linkage mechanism to be acceptable.

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P516738 - This maintenance activity involved inspection of the ring

oilers. No problems were identified by the licensee during the

inspection.

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P516538 - Lubrication and inspection of fuel oil pump coupling. The

puap coupling was cleaned, reassembled and greased in accordance with

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the lubrication manual. No problems were identified during the

inspection.

P516266 - The starting air manifold was inspected as required by this

maintenance work order. No problems were identified during the

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inspection.

No violations or deviations were identified in this area of the

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inspection. I

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8. Operational Safety Verification

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The resident inspectors observed operational activities throughout the

inspection period and closely monitored operational events. Control room

activities and conduct were generally observed to be well controlled.

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Proper control room staffing was maintained and access to the control room

operational areas was controlled. Selected shift turnover meetings were ;

observed and it was found that information concerning plant status was

l being covered in each of these meetings. System walkdowns of the "B" low

pressure coolant injection system and low pressure core spray system were

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conducted to verify major flow path and proper breaker alignment for ,

system operability. Plant tours were conducted, and overall plant

cleanliness was good.

General radiation protection practices were observed and no problems were

noted. Personnel exiting the radiation control area were observed and

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radiation monitors were being properly utilized to check for '

contamination.

Prompt security officer response to door alarms was observed and

compensatory posts were established where required. Protected and vital

area barriers were found to be intact, t

l The resident inspectors also reviewed licensee actions on operational

events and potential problems. The results of reviews of selected items i

are described below: l

a. Emergency Exercise: The resident inspectors participated in the

j licensee conducted emergency exercise on February 24, 1988. This

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exercise included local, state and federal participation. The NRC

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participation included NRC Region IV management personnel on site and

activation of the Region IV emergency response facility. An NRC

inspection team was also on site to evaluate the licensee's emergency

response capability. The evaluation results are documented in NRC

Inspection Report 50-458/88-07. While participating in the exercise, !

the resident inspectors monitored the licensee actions to control and i

mitigate the consequences of the simulated emergency. These i

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observations were made in the control room, technical support center, i

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and emergency operating facility. Licensee actions were deemed to be

1 controlled and proper to control and siitigate the simulated

emergency. ;

' b. Inadvertent Activation of Emergency Sirens: At 7:31 p.m. CST on

March 29, 1988, an emergency stren activated in West Feliciana Parish

for approximately 3 minutes. The siren activation was caused by

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lightning striking the siren. The Louisiana Office of Emergency

Preparedness and the local radio station were notified of the

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inadvertent siren activation. A message was transmitted over the

emergency broadcast system at 7:49 p.m. CST stating that no actual ;

emergency existed. ;

c. Reactor Shutdown: During this inspection period, the licensee

initiated a manual reactor shutdown as required by RBS T5s and !

received an automatic reactor scram during the subsequent reactor [

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startup. These reactor shutdowns are described below:

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Manual Reactor Shutdown Required by TSs: During full power

operation on February 19, 1988, the "A" reactor recirculation

pump tripped on an over-current condition. Reactor thermal

power was reduced to within the limits specified in RBS

TS Figure 3.4.1.1-1 within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and placed in Hot Shutdown :

within the subsequent 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The licensee later determined

that moisture had entered the pump motor conduit, which is i

located in the drywell, resulting in the indicated ground at the i

pump motor. The pump motor cable conduit was subsequently t

cleaned and sealed and a reactor startup initiated on [

February 21, 1988.

Automatic Reactor Scram: During a reactor startup on

February 21, 1988, with the reactor at approximately 4 percent

thermal power, the reactor scram resulted from a main turbine

trip signal. The reactor scram occurred during shell warming of '

the main turbine. Turbine first stage pressure was allowed to

exceed the equivalent of 40 percent power and with the turbine

stop valves closed, an automatic scram was initiated. The

licensee has added a caution statement to the turbine shell

warming procedure stating that a reactor scram will occur if (

turbine first stage pressure is allowed to exceed 40 percent

indicated power. However, sufficient guidance was given in '

SOPS 50D-0080, "Turbine Generator Operation," Revision 4, to

maintain turbine first stage pressure below 173 psig (40 percent

power) and thus have prevented this reactor scram.

d. Reactor Core Isolation Cooling System: During this inspection

period, the licensee experienced three events involving the reactor

core isolation cooling (RCIC) system during surveillance testing. ;

Two of these events involved repositioning of the RCIC suction line '

from the condensate storage tank (CST) to the suppression pool. The ;

third event involved an isolation of the RCIC system. These three ,

events are described below: ,i

STP-500-4550 - On March 8,1988, instrumentation and control

(I&C) technicians were performing Surveillance Test

Procedure STP-500-4550, "RPCS High and Low Power Setpoint

Functional Test (C11-N654 A, D, C and D and C11-N655 A and B),"

when an unexpected actuation of relay E51-K79 energized, causing

the RCIC suction path to transfer from the CST to the

suppression pool. Similar occurrences have been identified in

Condition Reports 86-1365, 86-1437, 87-0029, 87-0435, 87-0625, !

87-1715, 88-0043, 88-0052, 88-0143 and 88-0218, where spurious

transients in Panel H13*P629 have caused trips in Rosemount trip i

units. A field review of Panel H13*P629 panel wiring from the !

power supply to the rack identified several discrepancies with !

the signal ground and chassis ground. Modification ;

Request (MR) 88-0118 has been issued to correct the wiring i

discrepancies and a log is to be maintained identifying any

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further spurious trips. The above identified panel wiring

discrepancies will be an unresolved item pending further review

by the NRC inspector (458/8808-02). ,

STP-209-4206 - On March 10, 1988, I&C technicians were -

performing STP-209-4206, "RCIC-Suppression Pool Water Level High

Monthly CHFUNCT, 18 Month CHCAL, 18 Month LSFT (E51-N036A,

E51-N636A) " when an incorrect lead was lifted from the adjacent

panelspecIfiedintheSTP. This resulted in an unexpected

switch of the RCIC '.uction path from the CST to the suppression

pool. The licensee's corrective actions to preclude

reoccurrence will be to require the I&C technicians to give

in-shop training on the event and the importance of ensuring

actions required by the STP are first considered then correctly

performed.

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STP-207-4538 - On February 23, 1988, during the performance of

STP-207-4538, "RCIC Isolation-RCIC Steam Supply Pressure Low

Monthly CHFUNCT," a lifted lead was relanded prior to the RCIC

isolation being reset. This resulted in a RCIC turbine

isolation and turbine trip. This CTP had been revised per a

temporary change notice (TCN) to identify a new lead to be

lifted which is more readily accessible and will still prevent

the turbine trip and isolation. Previous isolations have

occurred because of shorting leads that were not easily

accessible. However, the TCN required the I&C technicians to

reland the lead prior to resetting the isolation signal. A

complete review of other applicable STPs was performed and no

other instances where the lead was to be relanded prior to

resetting the isolation logic were identified,

e. Alarm Response Procedures - On March 10, 1988, the senior resident

inspector was notified by the Office of Nu: lear Reactor Regulation

that the setpoints given in Alarm Response Procedure [

(ARP) ARP-601-19, "P601-19 Alarm Responses," Revision 2, were

incorrect for alarms 2403 and 20 9. This discovery was made during a

review of a RBS TS change for main steam tunnel temprature

isolations. Alarm numbers 2403 and 2409 are for main steam tunnel

ambient temperature high and main steam tunnel ventilation

differential temperature high. The immediate and long range actions

to prevent the main steam isolation valves (MSIVs) from closing on

high ambient temperature were reviewed by the resident inspectors,

lhe immediate and long range actions were found to be inadequate for

alarm 2403. The temperature at which the main steam tunnel ambient

temperature should be maintained below was given as 180*F rather than

the correct value of 130 F. A MSIV isolation will occur at 135*F. ;

In the event the main steam tunnel cooling systems can not maintain

the ambient temperature from approaching the MSIV isolation setpoint,

no additional operator actions are specified to prevent a full MSIV

isolation. This failure to provide adequate ARPs for high main steam ;

tunnel temperature and differential temperature was identified by the

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resident inspectors as an apparent violation (458/8808-01). The ,

licensee is presently reviewing the remaining ARPs for correct

setpoint values. A condition report will be initiated by the

licensee to identify and correct the identified deficiencies.

9. Unresolved Item

An unresolved item is an item about which additional information is

required in order to determine if it is acceptable, a deviation, or a

violation. There is one unresolved item in this report.

Paragraph Item No. Subject

8 458/8808-02 Panel Wiring Descrepancies I

10. Exit Intervfew

An exit interview was conducted with licensee representatives identified i

in paragraph 1 of this report. During this interview, the senior resident

inspector reviewed the scope and findings of the inspection.

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ML20153C018

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