ML20133L664

Insp Rept 50-483/96-14 on 961124-970104.Violations Noted. Major Areas Inspected:Operations,Maint & Plant Support

ML20133L664
Person / Time
Site:	Callaway
Issue date:	01/16/1997
From:	NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION IV)
To:
Shared Package
ML20133K956	List: ML20133K953 ML20133K962 ML20133L664
References
50-483-96-14, NUDOCS 9701220099
Download: ML20133L664 (16)

See also: IR 05000483/1996014

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ENCLOSURE 2 I

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U.S. NUCLEAR REGULATORY COMMISSION i

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l Docket No.: 50-483

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j License No.: NPF-30 i

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Report No.: 50-483/96-14 '

Licensee: Union Electric Company

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l Facility: Callaway Plant t

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Location: Junction Highway CC and Highway O

Fulton, Missouri

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l* Dates: November 24,1996, through January 4,1997

i inspectors: D. G. Passehl, Senior Resident inspector i

j F. L. Brush, Resident inspector

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H. F. Bundy, Reactor Engineer

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G. M. Good, Senior Emergency Preparedness Analyst

i Approved By: W. D. Johnson, Chief, Project Branch B

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ATTACHMENT: Supplemental Information  :

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9701220099 970116

PDR ADOCK 05000483

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EXECUTIVE SUMMARY

Callaway Plant

NRC Inspection Report 50-483/96-14

Operations

• The license's decision to shutdown the plant to repair a feedwater isolation valve

actuator was appropriate (Section 01,1).

• The control room staff response to a turbine trip during reactor startup was good

(Section 01.2). There were no problems during the subsequent startup

(Section 01.3).

• An equipment operator was thorough during rounds. The plant material condition

was good (Section O2.1).

• An equipment operator inadvertently pulled the wrong fuses on a bus in the main

circulating water and service water pump house. This resulted in a partialloss of

circulating water flow to the main condenser and required the operators to reduce

plant power. This was a violation caused by a personnel error (Section 04.1).

Maintenance

• The licensee's actions to determine the reason for the main feed water isolation

valve hydraulic actuator leaks were thorough. The licensee installed incorrect

0-rings due to inadequate material control which was a noncited violation

(Section M1.3).

"iant Suncort

• The commitment to perform onshif t dose assessments was clearly described in the

emergency plan and implementing procedures (Section P3.1).

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Report Details

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Summary of Plant Status

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The plant was at 100 percent power at the beginning of the report period.

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On December 1,1996, due to hydraulic oilleaks on the actuator for feedwater isolation

Valve D, the licensee shut down the unit. At 12:48 p.m. on December 5,1996, the plant

was brought back online. However, the turbine tripped a few minutes later due to a hi-hi

steam generator water level. At 8:25 p.m. on December 5,1996, the license returned the

unit online. The unit reached full power on December 6,1996.

At 4:41 p.m. on December 18,1996, the licensee reduced plant power to 92 percent

when an equipment operator inadvertently tripped a main circulating water pump. The

plant was returned to full power approximately four hours later and operated near

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100 percent power for the remainder of the report period.

I. Operations

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01 Conduct of Operations

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01.1 Plant Shutdown <

a. Inspection Scone (71707) i

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On December 1,1996, the inspectors observed control room operations during l

portions of the plant shutdown for a forced outage. l

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b. Observations and Findinas l

The licensee shut down the unit due to hydraulic fluid leaks on the actuator for main

feedwater isolation Valve AEFV0042. The actuator repair effort is discussed in

paragraph M1.2. The licensee's decision to shut down the unit was appropriate.

The licensee would have been required to enter and exit facdwater isolation valve

Technical Specification action statement 3.7.1.6 repeatediy in order to repair the

valve.

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The shift supervisor held good briefings prior to starting the power reduction and

removing major equipment from service. Licensee management was present in the

control room and ensured personnel were aware of expectations. There was good

communication between the control room operators. The shift supervisor exhibited

good command and control. Operators did self-checking prior to manipulating plant

components. The inspectors did not note any problems.

In addition, the inspectors verified compliance to the Technical Specifications and

Final Safety Analysis Report requirements by reviewing logs, touring main control

boards and reviewing status boards.

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01.2 Plant Startuo with Turbine Trio, Feedwater System isolation and Motor-Driven

Auxiliary Feedwater System Actuation

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a. Insoection Scoce (71707,93702) l

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On December 5,1996, the inspectors observed portions of the plant startup l

following the forced outage discussed in Section 01.1. i

During the startup, a hi-hi water levelin Steam Generator B resulted in a main l

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turbine trip, feedwater system isolation, and motor-driven auxiliary feedwater

actuation. The inspectors observed the control room operator response to the trip. ,

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b. Observations and Findinos

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During the startup prior to entering Mode 2, the control room supervisor held good :l

briefings. There was good communication among operations personnel. Licensee

management was in the control room and discussed their expectations with onshift

personnel.

At approximately 18 percent power, while transferring feed flow control from the

feedwater flow bypass valves to the main feedwater regulating valves, the steam

generator water levels began to oscillate. A main turbine trip and engineered safety

features actuations occurred when the level in Steam Generator B reached the hi-hi

setpoint of 78 percent. The magnitude of the level oscillations in the steam

generators were exacerbated by the positive moderator temperature coefficient

present at low power levels during this early stage in core life.

Operator response following the turbine trip and feedwater isolation was good. In

order to rapidly establish normal steam generator level, the operators manually

started the turbine-driven auxiliary feedwater pump and used control rods to rapidly

reduce power. This prevented a reactor trip on low steam generator level due to

the isolation of the main feedwater system. The shift supervisor exhibited good

command and control.

c. Conclusions

The control room staff's response to the turbine trip was good. Operator

communications were good during the startup and subsequent trip. The shif t

supervisor exhibited good command and control. Licensee management ensured

that plant personnel followed expectations.

01.3 Second Plant Startuo on December 5,1996(71707)

Following the trip noted in paragraph 01.2, the licensee reviewed the methods of

starting up and increasing power with a positive temperature coefficient. For the

second startup on December 5,1996, the licensee changed the method for

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transferring from the main feedwater bypass valves to the main feedwater

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regulating valves.

Rather than continuing to increase main generator load just after synchronizing to

the grid, the licensee held the main generator output to approximately 60 MWe. I

When steam generator water levels had stabilized and the feedwater bypass valves

were approximately 90 percent open, using the steam dumps, the licensee

increased the main generator output at approximately one half percent per minute.  ;

This allowed a smooth transition from the feedwater bypass to the main feedwater

regulating valves. There were no steam generator level deviation alarms during this

startup. The inspectors did not identify any significant issues.

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O2 Operational Status of Facilities and Equipment 1

02.1 Plant Tours

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a. Inspection Scope (71707)

The inspectors accompanied an equipment operator during rounds of the auxiliary

and fuel buildings. This was to determine the thoroughness of his inspections and

his sensitivity to equipment and plant housekeeping problems. l

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b. Observations and Findinas

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The operator was appropriately sensitive to the condition and operating status of all 1

equipment inspected. The inspectors noted that the operator wiped oil l

accumulatior, from safeguards pumps, which was considered a good practice. The I

inspectors also noted that any leaks were appropriately identified with work request

tags.

The operator noted that chemical and volume control system to centrifugal charging ,

Pump A discharge to reactor coolant pump seals throttle Valve BGHV8357A,had l

an accumulation of boric acid crystals. The operator stated that this did not meet  ;

expectations from both housekeeping and corrosion control standpoints. The I

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inspectors followed up and found that the valve is being tracked by the licensee's

boric acid leak tracking program iad will be worked at an appropriate time. The

inspectors observed that the operator was thorough in his inspections and was ,

particularly sensitive to determining the status of previously identified fluid leaks. )

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The inspectors observed that material, tools, and equipment were properly stored.

With the exception of clutter in the hot tool and radwaste staging areas, the

buildings were clean and free of debris. The clutter observed in the noted areas

was not unexpected in that refueling outage cleanup was still in progress.

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c. _ Conclusions

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The equiprnent operator was thorough in his inspections and particularly sensitive to

determining the status of existing fluid leaks. The plant material condition was

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02.2 Cold Weather Preparations

a. Inspection Scone (71707)

The inspectors reviewed the licensee's cold wcather preparations,

b. Observations and Findinas

The licensee performed a plant walkdown using Procedure OTS-ZZ-00007, i

Revision 3, " Plant Cold Weather," to ensure that equipment required during cold I

weather was operational. During the walkdown, the licensee identified a few

deficiencies which were corrected. The inspectors did not note any problems

during subsequent cold weather conditions.

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04.1 Worker Protection Tao Placed on the Wrona Component which Trioned Main i

j Circulatina Water Pumo B and Service Water Pumo B j

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a. Insoection Scope (71707)  !

The inspectors reviewed a December 18,1996, event, which occurred when an

equipment operator inadvertently pulled the metering and relay fuses for electrical  ;

Bus PB122. The bus supplied power fo, main circulating water Pump B and service i

water Pump B. When the fuses were pulled, the pump undervoltage protective i

circuits tripped the two pumps. The equipment operator was supposed to pull the l

instrument potential transformer secondary fuses for electrical Bus PB121.

b. Observations and Findinas

While intending to place a worker protection tag on an instrument potential

transformer secondary fuses for electrical Bus PB121, an equipment operator

! incorrectly placed the worker protection tag on the metering and relay fuses for

electrical Bus PB122. This action caused main circulating water Pump B and

l service water Pump B to trip. Main circulating water Pump A and service water

l Pump A were already secured to allow maintenance on Bus PB121. This left only

service water Pump C and main circulating water Pump C in service.

When the equipment operator pulled the metering and relay fuses, the control room

operators received a number of indications alerting them that the pumps had

tripped. Control room personnel immediately commenced reducing power to

prevent a turbine trip on loss of main condenser vacuum. Condenser pressure

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increased and stabilized at approximately 4.5 inches Hg after reactor power was

reduced to 92 percent. The condenser pressure turbine trip setpoint was 7.5 inches

Hg. The operators started essential service water Pump A to provide an adequate

service water supply.

After determining that the fuses were inadvertently pulled, the licensee restored

both Bus PB121 and Bus PB122 and restarted main circulating water Pump B.

Service water Pump A was also started and essential service water Pump A was

secured. The plant was returned to 100 percent power.

The licensee initiated an investigation of the event using the corrective action

process.

The licensee identified the following major causes:

• Failure to perform self-checking of the worker protection tag against the

component labeling.

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• Many of the fuses outside the power block were not consistently labeled.

The licensee's corrective actions included reviewing proper tcgout techniques with 1

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equipment operators. This includes the expectation that field supervisors resolve

any discrepancies between tagout sheet nomenclature and component labels in the

field. The licensee was also reviewing the adequacy of fuse labeling for

components outside the power block. Fuse labeling problems inside the power

block were identified and corrected at an earlier time.

The inspectors agreed with the licensee's findings.

Administrative Procedure ODP-ZZ-00310,"Workmac.'s Protection Assurance

Tagging", Revision 2, Step 4.1.10.3, required that the method and order specified

on the tagout control sheet be followed when hanging tags.

The tagout control sheet for Workman's Protection Assurance 21672, Tag 10,

specified that a tag be hung on the potential transformer secondary fuses for

Bus PB121. Failure to adhere to this requirement is considered a violation of the

licensee's administrative procedure.

NRC Inspection Report 50-483/9611 identified a similar occurrence when an

equipment operator pulled incorrect fuses and rendered centrifugal charging Pump A

inoperable. This licensee-identified and corrected violation is being treated as a

cited violation due to a repeat occurrence of a recent event (483/9614-01).

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c. Conclusions

The inspectors concluded that the failure to pull the correct fuses was due to

personnel error.

08 Miscellaneous Operations issues

08.1 Technical Specification interpretations (71707)

During a review of Callaway Technical Specification Interpretations, the inspectors

noted that NRC personnel were identified as giving concurrence for the positions

taken in two of them:

Technical Specification interpretation 1 - Emergency Core Cooling System

Accumulators, and

• Technical Specification Interpretation 4 - Turbine Overspeed Protection.

The inspectors informed the licensee that this form of NRC involvement is not

recognized by the Commission and is not an acceptable practice. However, the

referencing of official NRC correspondence in a licensee Technical Specification

Interpretation is acceptable. The inspectors requested that the licensee remove any

informal references to NRC review and/or approval from their Technical

Specification Interpretations. The licensee's Onsite Review Committee had already

approved removing these interpretations from the Technical Specifications.

II. Maintenance

l- M1 Conduct of Maintenance

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M 1.1 General Comments - Maintenance

a, inspection Scope (62707)

The inspectors observed or reviewed portions of the following work activities:

• Work Activity P541890- Centrifugal Charging Pump A Motor Bearing Oil

Sight Glass Leaks,

• Work Activity W175769- Rebuild Spare Feedwater Isolation Valve Actuator,

• Work Activity P548345- Clean and inspect Feeder Circuit Breaker to Motor-

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Driven Auxiliary Feedwater Pump A,

• Work Activity P548864- Calibrate Auxiliary Feedwater Flow to Steam

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Generator B Feed Flow Transmitter, and

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• Work Activity P576360- Cold Weather Preparations.

b. Observations and Findinas

Except as noted in paragraph M1.3, the inspectors found no concerns with the

maintenance observed. All work observed was performed with the work packages

present and in active use. The inspectors frequently observed supervisors and

system engineers monitoring job progress, and quality control personnel were

present when required. Housekeeping and foreign material exclusion controls were

satisfactory.

M1.2 General Comments - Surveillance

a. Inspection Scope (61726)

The inspectors observed all or portions of the following test activities:

• Surveillance Procedure OSP-EF-P001 A- Emergency Service Water Train A

Operability,

• Surveillance Procedure OSP-NE-0001 A- Standby Diesel Generator A Periodic

Tests, and

• Surveillance Procedure OSP-SA-0017A- Train A Safety injection System -

Containment Spray Actuation System Slave Relay Test.

b. Observations and Findinas

Surveillance testing observed during this inspection period was conducted

satisfactorily in accordance with the licensee's approved programs and the

Technical Specifications.

M 1.3 Feedwater Isolation Valve Actuator Hydraulic Leaks

a. Insnection Scooe (62707)

On November 29,1996, the actuator on feedwater isolation Valve AEFV0042 for

Steam Generator D, developed a hydraulic leak on both hydraulic system trains.

Each train is capable of independently closing the feedwater isolation valve upon

receiving a feedwater system isolation signal. The inspectors reviewed the

licensee's efforts to repair the actuator and determine the root cause of the leaks.

b. Observations and Findinas

The licensee discovered that the wrong size O-rings had been installed on both

hydraulic system trains for the actuator on Valve AEFV0042. Although the inside

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diameter of the O-rings was correct, the thickness was incorrect. As the hydraulic  ;

pressure'in the actuator cycled during normal operation, the O-ring material wore '

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away which established a leak path outside the valve.  ;

The licensee ' determined the root cause to be a maintenance error during

refurbishment of a spare hydraulic actuator for Valve AEFV0042. Workers

refurbished the spare actuator just prior to the recent refueling outage. This

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refurbishment included installing new O-rings on the hydraulic trains on October 8,

1996. However, some of the O-rings were the incorrect size. The licensee later- i

replaced the existing actuator on AEFV0042 with the newly refurbished spare (with l

the iicorrect 0-rings) during the refueling outage as part of an overall preventive i

maintenance task. l

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In December 1996, during the licensee's followup investigation after the leak was

discovered, the licensee inspected several dozen 0-rings and found a total of 17

incorrect 0-rings that had been installed in both hydraulic trains in Valve

AEHVOO42. The licensee replaced these with the correct 0-rings.

The licensee held a multidisciplinary review to determine the root cause of and '

corrective actions for this event. As a result, the licensee initiated a case study of

this event due to the broad scope of potential corrective actions.

The licensee's short term corrective actions included successfully repairing the valve

and testing a representative sample of O-rings in stock to ensure no other O-ring

problems existed. No incorrect 0-rings were identified.

The licensee's long term corrective actions include the case study, which

addresses:

Ensuring correct drawings are specified and available in work packages,

• Reviewing material control wording to clear up confusing nomenclature on I

parts sizing,

• Ensuring adequate work planning and coordination for complex maintenance

efforts, and i

• Conducting training on the results of the case study for the various

disciplines involved in maintenance activities.

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The inspectors reviewed the work package used to refurbish the actuator on

AEFV0042 just prior to the refueling outage. The inspectors found that the

i supervisor in charge of the job did not thoroughly review the work package for

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information on replacement 0-rings. Information on replacement 0-rings of the

correct size and material was available in the work package.

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Criterion V of Appendix B to 10 CFR Part 50 requires, in part, that activities  ;

affecting quality shall be prescribed by documented instructions, procedures, and i

drawings appropriate to the circumstances and shall be accomplished in accordance

with these instructions, procedures, or drawings. The failure to adhere to this l

requirement is considered a violation of Criterion V of Appendix B to 10 CFR r

Part 50. This licensee-identified and corrected violation is being treated as a ,

noncited violation, consistent with Section Vll.B.1 of the NRC Enforcement Policy

(483/9614-02).

i c. Conclusions

The inspectors concluded that the licensee's actions to determine the reason for the

leak were thorough. The inspectors also found the licensee's repair of the leaking

hydraulic components to be satisf actory. The licensee's control of O-ring material

for rebuilding the feedwater isolation valve actuator was lacking.

Ill. Enaineerina

E1 Conduct of Engineering

E1.1 fnaineerina Involvement in Plant Activities (37551)-

The inspectors noted that engineering was appropriately involved in plant activities

during this inspection period. The inspectors noted that system engineers

conducted plant walkdowns of assigned systems for cold weather preparations as

discussed in Section O2.2 of this report. Expectations were included on a

management policy entitled " System Walkdowns," NE-System Walkdown-01,

Revision 1. In addition, plant engineers participated in the multidisciplinary case

study team and root cause evaluation for the failure of feedwater isolation Valve l

AEFV0042 (Section M1.3). The inspectors had no concerns, j

E2 Engineering Support of Facilities and Equipment

E2.1 Review of Facility Conformance to Uodated Final Safety Analvsis Report

Commitments j

A recent discovery of a licensee operating their f acility in a manner contrary to the

Final Safety Analysis Report description highlighted the need for a special focused

review that compares plant practices, procedures, and/or parameters to the Final

Safety Analysis Report description. While performing the inspections discussed in

this report, the inspectors reviewed the applicable portions of the Final Safety

Analysis Report that related to the areas inspected. No inconsistencies were noted

between the wording of the Updated Safety Analysis Report and the plant practices,

procedures, and/or parameters observed by the inspectors,

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IV. Plant SuDDort

R1 Radiological Protection and Chemistry (RP&C) Controls

R 1.1 Radioloaical Protection Proaram Observations

The inspectors toured various areas of the radiologically controlled areas of the

plant. Health physics personnel were observed routinely touring the radiologically

controlled areas. Licensee personnel observed performing work in radiological

control areas exhibited good radiation worker practices. Contaminated areas and

high radiation areas were properly posted. Area surveys posted outside rooms in

the auxiliary building were current.

P3.1 Licensee Onshift Dose Assessment Capabilities

a. Insoection Scoce (Tl 2515/134)

Using Temporary Instruction 2515/134,the inspectors gathered information

regarding:

• Dose assessment commitment in emergency plan,

• Onshift dose assessment emergency plan implementing procedure, and

• Onshift dose assessment training.

b. Observations and Findinas

On December 17,1996, the inspectors conducted an inoffice review of the

emergency plan and implementing procedures to obtain the information requested

by the temporary instruction. The inspectors also conducted a telephone interview

with the licensee on December 17,1996, to verify the results of the review. Based

on the documentation review and the licensee interview, the inspectors determined

that the licensee had the capability to perform onshift dose assessments using real-

time effluent monitor and meteorological data and that the commitment was clearly

described in the emergency plan and implementing procedures.

c. Conclusion

The commitment to perform onshift dose assessments was clearly described in the

emergency plan and implementing procedures. Further evaluation of the information

obtained using the temporary instruction will be conducted by NRC Headquarters

personnel.

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I V. Manaaement Meetinas

X1 Exit Meeting Summary

The exit meeting was conducted on January 3,1997. The licensee expressed a

position on the subject of the violation in this report.

During the discussion of the equipment operator inadvertently pulling the wrong

fuse which caused operators to reduce plant power (Section 04.1), the licensee

stated that the event was not significant enough to merit a violation for the

following reasons:

• The licensee disagreed that a procedure violation occurred given a literal

interpretation of the equipment control tagging procedure,

• The licensee stated that 10 CFR 50, Appendix B, did not apply to the non-

safety related fuse, and

• The licensee stated that the equipment control tagging procedure was a

reference-use procedure.

The inspectors asked the licensee whether any materials examined during the

inspection shou!d be considered proprietary. No proprietary information was

identified.

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ATTACHMENT

SUPPLEMENTAL INFORMATION

PARTIAL LIST OF PERSONS CONTACTED

Licensee

J. D. Blosser, Manager, Operations Support

H. D. Bono, Supervising Engineer, Licensing Fuels and Site Licensing

D. G. Cornwell, General Supervisor, Maintenance

R. T. Lamb, Superintendent, Operations

l J. V. Laux, Manager, Quality Assurance

D. W. Neterer, Shif t Supervisor

J. R. Peevy, Manager, Emergency Preparedness and

Organizational Support  :

G. L. Randolph, Vice President, Nuclear Operations

M. A. Reidmeyer, Engineer, Quality Assurance

R. R. Roselius, Superintendent, Chemistry and Rad Waste

J. D. Schnack, Engineer, Quality Assurance

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T. P. Sharkey, Supervising Engineer, Nuclear Operations

INSP_fCTION PROCEDURES USED

IP 37551: Onsite Engineering

IP 61726: Surveillance Observations

IP 62707: Maintenance Observations

i IP 71707: Plant Operations

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IP 93702: Prompt Onsite Response to Events at Operating Power Reactors

Tl 2515/134 Licensee Onshift Dose Assessment Capabilities

ITEMS OPENED CLOSED, AND DISCUSSED

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9614-01 VIO Equipment Operator Pulled Incorrect Fuse (Section 04.1)

9614-02 NCV Leaking 0-Rings On Feedwater isolation Valve AEFV0042

For Steam Generator D (Section M1.3)

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l 9614-02 NCV Leaking O-Rings On Feedwater Isolation Valve AEFV0042

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For Steam Generator D (Section M1.3)

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LIST OF DOCUMENTS REVIEWED

Emeroency Plan imolementina Procedures

EIP-ZZ-00101 Classification of Emergencies Revision 19

ElP-ZZ-00102 Emergency implementing Actions Revision 15

EIP-ZZ-01211 Management Action Guides for Revision 18

Nuclear Emergencies

Other Documents

Callaway Radiological Emergency Response Plan Revision 20

CN 96-02

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