IR 05000321/1987029

Insp Repts 50-321/87-29 & 50-366/87-29 on 871027-1120.No Violation or Deviation Noted.Major Areas Inspected: Operational Safety Verification,Maint Observation,Plant Mod, Surveillance Observation,Esf Sys & Physical Security

ML20237D080
Person / Time
Site:	Hatch
Issue date:	12/10/1987
From:	Holmesray P, Menning J, Sinkule M NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II)
To:
Shared Package
ML20237D069	List: IR 05000321/1987029 ML20237D068
References
TASK-2.E.4.2, TASK-2.F.1, TASK-2.K.3.16, TASK-2.K.3.18, TASK-TM 50-321-87-29, 50-366-87-29, NUDOCS 8712230035
Download: ML20237D080 (9)

Text

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t u UMITED STATES l: . [pa Hro o NUCLEAR REGULATORY COMMISSIGF0

'g" [g REGloN il l

^ y 101 MARIETTA STREET, * * ATLANTA, GEORGI A 30323 p'*

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Report Nos.: 50-321/87-29 and 50-366/87-29 Licensee: Georgia Power Company P. D. Box 4545 Atlanta, GA 30302 Docket Nos.: 50-321 and 50-366 License Nos.: OPR-57 and NPF-5 Facility Name: Hatch I and 2 Inspection Conducted: October 27 - ifovember 20, 1987 Inspectors: } /Jd Abet [wtE g b 3 Peter Holmes-Ray, Senior Resident Inspector

/ 2r[10/97 Date Signed Y $ & /4 k ctb$+tO A - / 2[ic/l' 7 F*cJohn E. Menning, Resident Inspector Date Signed Accompanying Pers.onnel: Randall A. Musser Approved by: ~7.- Cid d /7/A7 7 Mrvin V. Sinkule, CL1Ay Projett Section 2C Date signed !

Division of Reactor Projects SUMMARY

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Scope: This routine inspection was conducted at the site in the areas of Operational Safety Verification, Maintenance Obserystion, Plant Modification, Surveillance Observation, ESF System Walkdown, Radiological Protection, Physical Securi ty , Reportable Occurrences, Reactor Events, Part 21 Report Followup and TMI Open Item Followu Results: No violations or deviations were identifie !

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I REPORT DETAILS

. Persons Contacted Licensee Employees l

T. Beckham, Vice President, Plant Hatch 'l

• H. C. Nix, Plant Manager ,

D. Read, Plant Support Manager H. L. Sumner, Operations Manager P. E. Fornel, Maintenance Manager

• T. R. Powers, Engineering Manager

• R. W. Zavadoski, Health I'hysics and Chemistry Manager

• C. Coggin, Training and Emergency Preparedness Manager M. Googe, Outages and Planning Manager

• 0. M. Fraser, Site Quality Assurance (QA) Manager

• S. 8. Tipps, Nuclear Safety and Compliance Manager Other licensee ' employees contacted included technicians, operators, mechanics, security force members and office personne * Attended exit interview Exit Interview (30703)

The inspection scope and findings were summarized on November 20, 1987, with those persons indicated in paragraph 1 above. The licensee did not identify as proprietary any of the material provided to or reviewed by the inspector (s) during this inspectio The licensee 3 acknowledged the findings and took no exceptio (0 pen) Unresolved Item 50-366/87-29-0 Review of DCR 84-14 (Paragraph 6). Unresolved Item *

i An sunresolved item (URI) was opened concerning a Design Change Request (DCR) that was implemented in Unit 2 during the 1985 refueling outag The licensee has reported that DCR 84-142 could possibly have resulted in overloading of the 2A and 2C diesel generators during certain accident conditions. The URI is addressed in paragraph 6 of this repor . Operational Safety Verification (71707)

The inspectors kept themselves informed on a daily basis of the overall plant status and any significe.nt safety matters related to plant i operations. Daily discussions were held with plant mancgement and various members of the plant operating staff. The inspectors made frequent visits to the control room. Observations included instrument readings, setpoints

• An Unresolved item is a matter about which more information is required to determine whether it is acceptable or may involve a violation or deviation.

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l and recordings, status of operating systems, tags and clearances on equipment, controls and switches, annunciator alarms, adherence to limiting conditions for operation, temporary alterations in effect, daily journals and data sheet entries, control room manning, and access controls. This inspection activity included numerous informal discussions with operators and their supervisors. Weekly, when on site, selected Engineering Safety Feature (ESF) systems were confirmed operable. The confirmation was made by verifying the following: accessible valve flow path alignment, power supply breaker and fuse status, instrumentation, major component leakage, lubrication, cooling, and general conditio General plant tours were conducted on at least a weekly basis. Portions of the control building, turbine building, reactor building, and outside area, were visite Observations included general plant / equipment conditions, safety related tagout verifications, shift turnover, sampling program, housekeeping and general plant conditions, fire protection equipment, control of activities in progress, radiation protection controls, physical security, problem identification systems, missile hazards, instrumentation and alarms in the control room, and containment isolatio '

The following discrepancies were noted by the inspectors during general plant tours end brought to the attention of licensee personnel:

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On November 5, 1987 wood scaffolding was observed it, an overhead'

area in the vicinity of the Unit 2 Standby Liquid Control system pumps. The scaffolding was not tagged to indicate that it was being used for ongoing maintenance wor It appeared that the materials had been left from previous wor While touring the diesel generator building on November 13, 1987, the inspector observed that the conditions of certain locked valves I were not in complete agreement with the related system valve lineup sheet More specifically, the inspector noted that valves 2R43-F034A and C, 2R43-F035A and C, and 2R43-F037A and C were all locked in the open position. These valves are all associated with the air start systems of the 2A and 2C diesel generators. The system valve lineup sheets contained in Data Package 2 of procedure l

3450-R43-001-25, " Diesel Generator Standby AC System Operating Instructions", specify that these valves are to be ope Licensee procedure 34G0-SUV-001-05, " Control and Surveillance of Locked I Valves", requires these valves to be locked open. Based upon an inqui ry by the inspector, a licensee representative agreed to investigate the need to modify the current system valve lineup sheets to specify that the valves are to be locked ope During this reporting period, the inspector reviewed the licensee's controls on overtime of personnel who perform safety-related function Section 6 2. of the Technical Specifications (TS) establishes requirements for the control of such overtime and Section 8.4 of licensee l

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procedure 30AC-0PS-003-0S, " Plant Operations," provides implementing instructions to support the technical specification requirement The inspector reviewed a Maintenance Department Overtime Report for the month of September and determined that the requirements of 30AC-0PS-003-0S and the technical specifications had been me No violations or deviations were identifie ; . Maintenance Observation (62703)

During the report period, the inspector (s) observed selected maintenance activities. The observations included a review of the work documents for adequacy, adherence to procedure, proper tagouts, adherence to technical specifications, radiological controls, observation of all or part of the actual work and/or retesting in progress, specified retest requirements, and adherence to the appropriate quality control The prima ry maintenance observations during this month are summarized below:

Maintenance Activity Date l Replacement of Unit 1 High Pressure 10/29/87 Coolant Injection barometric condenser vacuum switch'(1E41-N762) Preventive maintenance of Unit 2 Reactor 11/03/87 Core Isolation Cooling System Electrical troubleshooting on logic 11/04/87 energizing the solenoid actuat.or of valve 2P41-F339A in Unit 2 Electrical trouble shooting on Unit 1 1C 11/05/87 battery charger No violations or deviations were identifie . Plant Modification (37700)

The inspectors reviewed documentation packages for selected Design Change Requests (DCRs) that had been implemented and closed by the licensee. The review included verification that the design changes had been reviewed and approved in accordance with the Technical Specification and 10 CFR 50 59, controlled by approved procedures and verified by appropriate post installation testing. The review also included verification that plant procedures, operator training programs, as built drawings, preventive mainter.ence programs and in service testing and inspection programs were revised, as appropriate, prior to the modification being declared operable.

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The DCRs involved in tnis review are identified by the licensee as Nos.81-138, 83-167,84-200 and 86-20 The inspector reviewed the licensee's program for temporary modifications, lifted leads and jumpers. Program requirements are currently contained in procedure 30AC-OPS-005-05, Rev. O, '" Temporary Bypass, Jumper, and Lif ted Lead Control". The inspector verified that program controls require reviews and approvals in accordance with the Technical Specifications and 10 CFR 50.59, the use cf detailed approved procedure when performing temporary modifications, the maintenance of formal records, independent l verification of installation and removal, and periodic review of record The licensee implemented DCR 84-142 on Unit 2 during the 1985 refueling outage. This DCR provided a bypass switch to allow operators to restart l the drywell chillars under LOCA conditions. A clearance was placed on the I bypass switch soon after installation, making the switch ineffective. The reason that the clearance was placed on the switch is not absolutely clear at this tim As discussed later, the licensee is now attempting to establish the reason for the clearance as part of a broadsr investigatio On November 17, 1987, the licensee notified NRC that DCR 84-142 had the potential for creating an overload condition on the 2A and 2C diesel generators under LOCA/ Loss of Off site Power conditions. The licensee identified an accident scenario under which the failure of non-safety class timers could cause automatic loading of the drywell chillers onto the emergency 4160 volts busses and overloading of the diesel generator The licentee har formed a team to determine the safety significance of  ;

this matter and reconstruct the DCR review and approved, implementation, and clearance ;.rocess. This team intends to isste a report of finding by December 2, 198 Pending review of the licensee's findings, this matter is identified as Unresolved Item 366/87-29-01 - Review oi DCR 84-14 No violations or deviations were identifie . Surveillance Testing Observations (61726)

The inspector (s) observed the performance of selected surveillance. The observation included a review of the procedure for technical adequacy, conformance to Technical Specifications, verification of test instrument calibration, observation of all or part of the actual surveillance, removal from service and return to service of the system or components affected, and review of the data for acceptability based upon the acceptante criteria. The primary surveillance testing observations during this mov.th are summarized beicw:

Surveillance Testino Activity Date ATTS Panel 2H11-P925 Channel Functional 10/29/87 Test and Calibration in accordance with 575V-SUV-011-25 (Unit 2)

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l 5 Surveillance Testing Activity Date (cont'd) Manual Start of Diesel Generator 2C in 11/04/87 accordance with procedure 34SV-R43-001-2S Unit 2) Functional Test of GE NUMAC Main Steam 11/16/87 Line Logarithmic Radiation Monitor in accordance with procedure 57SV-D11-016-15 (Unit 1) High Pressure Coolant Injection Pump 11/19/87 Operability in accordance with procedure 345V-E41-002-2S (Unit 2)

During monthly operability testing of the Unit I torus to drywell vacuum breakers on November 11, 1987, vacuum breaker IT48-F323C failed to close after being opened. Technical Specification 3.7.A.4.a requires these vacuum breakers to be fully closed (except during testing). The licensee properly notified the NRC and reported that Unit I was in e condition requiring hot shutdown within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of the even Vacuum breaker IT48-F323C subsequently closed on its own approximately 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> after being opened. Preliminary investigation by the licensee suggested that a coil in a solenoid valve controlling air to the vacuum breaker's actuator may have failed, preventing closure by not allowing air to vent from the actuato During subsequent testing, vacuum breaker IT48-F323F would not open and was considered inoperative for opening. T.S. 3.7.A.4.a allows up to three vacuum breckers to be inoperable for opening provided that they are known to be in the closed position. Two redundant position indicating switches for each vacuum breaker indicated that IT48-F323C and F were both closed. The licensee has not yet conducted detailed trouble shooting on these vacuum breakers and detcrmined why they failed to perform properly during testin The resident inspectors will follow these maintenance l activitie I No violations or deviations were identifie . ESF System Walkdown (71710)

The inspectors routinely conducted partial walkdowns of ESF systems. Valve and breaker / switch lineups and equipment conditions were randomly verified both locally and in the control room to ensure that lineups were in accordance with operability requirements and that equipment material conditions were satisfactor The Unit-2 "A" core spray loop was walked down in detai No violations or deviations were note _ _ _ _ . _ _ __ ._ - ____-____--__- ___ _ ______________ _

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6 Radiological Protection (71709)

The resident inspectors reviewed aspects of the licensee's radiological protection program in the course of the monthly activitie The performance of health physics and other personnel was observed on various shifts to include: involvement of health physics supervision, use of radiation work permits, use of personnel monitoring equipment, control of high radiation areas, use of friskers and personal contamination monitors, and posting and labelin No violations or deviations were note . Physical Security (71881)

In the course of the monthly activities, the resident inspectors included a review of the licensee's physical security program. The perfor. nance of various shifts of the security force was observed in the conduct of daily activities to include: availability of supervision, availability of armed response personnel, protected and vital access controls, searching of personnel, packages and vehicles, badge issuance and retrieval, escorting of visitors, patrols and compensatory post The resident inspector verified the absence of obstructions in the isolation zone area on each side of the protected area (PA) fence that could conceal an unauthorized entry or interfere with the capability of the detection / assessment syste The adequacy of illumination in the PA was also verifie On November 12, 1987, the resident inspector visited the central and secondary alarm stations and determined that surveillance ,

equipment was functioning properl '

No violations or deviations were note i 1 Reportable Occurrences (90712 & 92700)

A number of Licensee Event Reports (LERs) were reviewed for potential I generic impact, to detect trends, and to determine whether corrective actions appeared appropriate. Events which were reported immediately were i also reviewed as they occurred to determine that Technical Specifications l were being met and the public health and safety were of utmost consideratio . Operating Reactor Events (93702)

At 1557 on November 10, 1987, the Unit 1 "B" recirculation pump tripped while the unit was operating at 100 percent of rated power. The reduction in recirculation flow resulted in a sudden power reduction from 100 to approximately 64 percent of rate Maintenance personnel had been changing out motor generator set generator and exciter brushos prior to this event. When changing the last exciter brush, the brush grounded against the exciter housing frame tripping the recirculation pump. The

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I inspector observed actions of control room personnel during recovery from the even The inspector noted in particular that personnel were continuing to reduce power to comply with the power-flow operating  ;

requirements of Figure 3.6-5 of the Technical Specifications. However, i since nuclear - instrumentation was not calibrated for single loop  !

recirculation loop operation at the time of the pump trip, TS 3.C. l'

required that Unit. I be placed in hot shutdown within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of the event. The licensee notified the NRC of the condition requiring shutdow In reviewing this matter, the inspector noted that, unlike the Unit 1 Technical Specifications, the Unit 2 Technical Specifications provide an allowance of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> for nuclear instrumentation on ioss of a recir-culation pump. The "B" recirculation pump was returned to service at 0220 ,

on Nevember 11, counteracting the requirement to shutdown Unit 1. Unit 1 again achieved 100 percent of rated power at approximately 2400 on November 1 Within the areas inspected, no violations or deviations were identifie . Part 21 Report followup (92716)

By letter dated January 20, 1987, Anchor / Darling advised Georgia Power Company that a DC motor irstalled in a Limitorque operator supplied to

'" ant Hatch was potentially defectiv The motor in question was fitted with Nomex-Kapton insulated leads that are susceptible to ir.sulation degradation and subsequent short circuit failure. The Nomex-Kupton leads were different than the leads which were tested and reported in Limitorque Qualification Report B-0009 dated April 30, 1976. Valves with these leads had failed to actuate on demand at several nuclear plant sites. Portland General Electric Company reported one such failure to the NRC pursuant to 10 CFR 21 on May 6, 1986. This matter was also the subject of IE Information Notice No. 87-08, " Degraded Motor Leads in Limitorque DC Motor Operators." The potentially defective DC motor supplied to Plant Hatch was determined to be installed in the operator of Unit 1 High Pressure Coolant Injection System Steam Inlet Valve 1E41-F00 The licensee has replaced the DC motor in question with a motor with environmentally qualified insulated leads. This work was performed per Maintenance Work Order (MWO) 1-87-02871 and completed on May 3, 1987. The inspector reviewed the MWO and the licensee's consideration of the matte This matter, tracked by Region II as item 321/P2186-04, is close General Electric informed the NRC of a defect reportable per 10 CFR 21 by letter dated April 13, 198 The defect related to the presence of Locktite-242, thread locking material, in the solenoid plungers of scram pilot solenoid valves of Control Rod Drive Hydraulic Control Units. The Locktite-242, which had been used to secure acorn cap nuts on the valves, had in some instances migrated to the plungers, resulting in slower then normal scram times. This matter was also the subject of IE Information Notice 84-53, "Information Concerning the Use of Locktite 242 and Other Anaerobic Adhesive / Sealants". The inspector reviewed the licensee's followup on this matter as documented in letter LR-REG-039-0987 dated September 28, 1987. The licensee determined that past practice had been

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l to tighten the acorn cap nuts to a torque of 100 inch pounds, without the use of. Locktite-242. To preclude p,ossible-use of- this material in this application in the future, QuaMfication' Data Packages 43 and 49 in the i Environmental Qualification files have been updated. The updating was completed on July 24, 1987. This matter, tracked by Region II as item 321/P2184-02 and 366/P2184-03, is close . Three Mile Island items (item numbers are from NUREG 0737)

Item II.E.4.2.7 concerns closure of the containment purge and vent lines on a high radiation signa DCR's83-167 and 83-168 for Units 1 and 2 modified the logic to provide closure of the 18" purge and vent vahes on i a high radiation signal. As discussed in NRC Inspection Report 321,  ;

366/87-07, this item remained open pending issue of amendments to the Technical Specifications that incorporate the closure logic into the T The Office of Nuclear Reactor Regulation issued the required amendments (Nos.143 and 78 for Units 1 and 2 respectively) on July 14, 1987. This item is closed for Units 1 and Item II.F.1.6 was reviewed for completion of the post accident hydrogen monitoring capability. Only equipment qualification (EQ) work remained outstanding to complete this item. Design Change Request (DCR)81-132 for i Unit 1 and DCR 81-165 for Unit 2 performed the EQ work. The licensee anticipates that DCR 81-132 will be closed in November, 1987 and that DCR 81-165 will be closed by April 1,1988. This item remains open pending review of the completed DCR package Item II.K.3.16.B included Lcw Low Set (LLS) relief valve logic, lowered Main Steam Isolation Valve (MSIV) water ievel setpoint, increased simmer margin (no change required at Hatch), Safety Relief Valve (SRV) preventive maintenance program, installation of the Analog Transmitter Trip System (ATTS) and improved SRV pneumatic supply. ATTS and LLS were installed by DCR 81-138 for Unit 1 and DCR 81-139 fer Ur.it 2. As discussed in NRC Inspection Report 321,366/87-07, this item remained open pending review of the completed package for DCR-138. This DCR was closed on October 19, 1987, and the package was subsequently reviewed by the inspecto This item is closed for Units 1 and !

Item II.K.3.18.C concerns modification of the Automatic Depressurization System ( ADS) to provide the capability of bypassing the High Drywell Pressure portion of the ADS initiation logic in the event of an Anticipated Transient Without Scram conditio Review of th4 s item was previously discussed in NRC Inspection Report 321,366/87-02. This item remained open pending the con.pletion of work and review of packages for DCR's84-200 and 87-87 for Units 1 and 2, respectivel DCR 84-200 was closed on August 4,1987, and subsequently reviewed by the inspector. DCR

87-87 is scheduled for implementation during the upcoming Unit 2 refueling outag The licensee anticipates that this DCR will be closed by May 1, 1988. This item remains open for Unit E perding review of the completed package for DCR.87-87. This Item is closed for Unit 1.

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