IR 05000424/2014002

IR 05000424-14-002, 05000425-14-002; on 01/01/2014 - 03/31/2014; Vogtle Electric Generating Plant, Units 1 and 2, Integrated Inspection Report

ML14119A418
Person / Time
Site:	Vogtle
Issue date:	04/29/2014
From:	Frank Ehrhardt NRC/RGN-II/DRP/RPB2
To:	Tynan T Southern Nuclear Operating Co
References
IR-14-002
Download: ML14119A418 (30)

Text

UNITED STATES NUCLEAR REGULATORY COMMISSION ril 29, 2014

SUBJECT:

VOGTLE ELECTRIC GENERATING PLANT - NRC INTEGRATED INSPECTION REPORT 05000424/2014002 AND 05000425/2014002

Dear Mr. Tynan:

On March 31, 2014, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at your Vogtle Electric Generating Plant, Units 1 and 2. The enclosed integrated inspection report documents the inspection findings, which were discussed on April 22, 2014, with you and other members of your staff.

The inspection(s) examined activities conducted under your license as they relate to safety and compliance with the Commissions rules and regulations and with the conditions of your license.

The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel.

Based on the results of this inspection, no findings of significance were identified. As we informed you in the most recent NRC integrated inspection report, cross-cutting aspects identified in the last six months of 2013 using the previous terminology were being converted in accordance with the cross-reference in Inspection Manual Chapter (IMC) 0310. Section 4OA5 of the enclosed report documents the conversion of these cross-cutting aspects which will be evaluated for cross-cutting themes and potential substantive cross-cutting issues in accordance with IMC 0305 starting with the 2014 mid-cycle assessment review. If you disagree with the cross cutting aspect assigned, you should provide a response within 30 days of the date of this inspection report, with the basis for your disagreement, to the Regional Administrator, Region II, and the NRC Resident Inspector at the Vogtle Plant. In accordance with the 10 CFR 2.390 of the NRCs Rules of Practice, a copy of this letter, its enclosures, and your response (if any) will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records (PARS) component of the NRCs Agencywide Document Access and Management System (ADAMS). ADAMS is accessible from the NRC Web site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).

Sincerely,

/RA/

Frank Ehrhardt, Chief Reactor Projects Branch 2 Division of Reactor Projects Docket Nos.: 05000424, 05000425 License Nos.: NPF-68 and NPF-81

Enclosures:

Inspection Report 05000424/2014002 and 05000425/2014002 w/Attachment: Supplemental Information

REGION II==

Docket Nos.: 50-424, 50-425 License Nos.: NPF-68, NPF-81 Report Nos.: 05000424/2014002 and 05000425/2014002 Licensee: Southern Nuclear Operating Company, Inc. (SNC)

Facility: Vogtle Electric Generating Plant, Units 1 and 2 Location: Waynesboro, GA 30830 Dates: January 1, 2014, through March 31, 2014 Inspectors: M. Cain, Senior Resident Inspector T. Chandler, Resident Inspector R. Carrion, Senior Reactor Inspector (Section 1R08)

A. Vargas, Reactor Inspector (Section 1R08)

Approved by: Frank Ehrhardt, Chief Reactor Projects Branch 2 Division of Reactor Projects Enclosure

SUMMARY OF FINDINGS

IR 05000424/2014002, 05000425/2014002; 01/01/2014 - 03/31/2014; Vogtle Electric

Generating Plant, Units 1 and 2, Integrated Inspection Report The report covered a three-month period of inspection by the resident and regional inspectors. No findings of significance were identified. The NRCs program for overseeing the safe operation of commercial nuclear power reactors is described in NUREG-1649, Reactor Oversight Process Revision 5.

REPORT DETAILS

Summary of Plant Status

Unit 1 started the report period at full rated thermal power (RTP) and was shut down for a planned refueling outage on March 16, 2014. The unit remained shutdown for the remainder of the report period.

Unit 2 operated at essentially RTP for the entire inspection period.

REACTOR SAFETY

Cornerstones: Initiating Events, Mitigating Systems, Barrier Integrity

1R01 Adverse Weather Protection

a. Inspection Scope

Impending Adverse Weather Conditions The inspectors reviewed the licensees preparations to protect risk-significant systems from severe cold weather conditions expected on January 7, 2014. The inspectors evaluated the licensees implementation of adverse weather preparation procedures and compensatory measures, including operator staffing, before the onset of and during the adverse weather conditions. The inspectors reviewed the licensees plans to address the ramifications of potentially lasting effects that may result from cold weather conditions.

The inspectors verified that operator actions specified in the licensees adverse weather procedure maintain readiness of essential systems. The inspectors verified that required surveillances were current, or were scheduled and completed, if practical, before the onset of anticipated adverse weather conditions. The inspectors also verified the licensee implemented periodic equipment walkdowns or other measures to ensure that the condition of plant equipment met operability requirements. Documents reviewed are listed in the Attachment.

b. Findings

No findings were identified.

1R04 Equipment Alignment

a. Inspection Scope

Partial Walkdown The inspectors verified that critical portions of selected systems were correctly aligned by performing partial walkdowns. The inspectors selected systems for assessment because they were a redundant or backup system or train, were important for mitigating risk for the current plant conditions, had been recently realigned, or were a single-train system.

The inspectors determined the correct system lineup by reviewing plant procedures and drawings. Documents reviewed are listed in the Attachment.

The inspectors selected the following three systems or trains to inspect:

• Unit 2 A train residual heat removal (RHR) system while the B train RHR pump was out of service for maintenance

• Unit 1 A and C train auxiliary feedwater (AFW) systems while the B train AFW system was out of service for planned maintenance

• Unit 2 A train nuclear service cooling water (NSCW) transfer system while the B train NSCW transfer system was out of service for planned maintenance Complete Walkdown The inspectors verified the alignment of the Unit 1 containment spray (CS) system. The inspectors selected this system for assessment because it is a risk-significant mitigating system. The inspectors determined the correct system lineup by reviewing plant procedures, drawings, the updated final safety analysis report, and other documents. To identify any deficiencies that could affect the ability of the system to perform its function(s), the inspectors reviewed records related to outstanding design issues and maintenance work requests. The inspectors verified that the selected system was correctly aligned by performing a complete walkdown of accessible components.

To verify the licensee was identifying and resolving equipment alignment discrepancies, the inspectors reviewed corrective action documents, including condition reports and outstanding work orders. The inspectors also reviewed periodic reports containing information on the status of risk-significant systems, including maintenance rule reports and system health reports. Documents reviewed are listed in the Attachment.

b. Findings

No findings were identified.

1R05 Fire Protection

a. Inspection Scope

Quarterly Inspection The inspectors evaluated the adequacy of selected fire plans by comparing the fire plans to the defined hazards and defense-in-depth features specified in the fire protection program. In evaluating the fire plans, the inspectors assessed the following items:

• control of transient combustibles and ignition sources

• fire detection systems

• water-based fire suppression systems

• gaseous fire suppression systems

• manual firefighting equipment and capability

• passive fire protection features

• compensatory measures and fire watches

• issues related to fire protection contained in the licensees corrective action program The inspectors toured the following five fire areas to assess material condition and operational status of fire protection equipment. Documents reviewed are listed in the

.

• Unit 1, level A east and west penetration areas, fire zones 89, 90, 159, 87, 88, 93, 120, and 158

• Unit 2, CS and RHR pump rooms, fire zones 4, 5, 9 and 10

• Unit 2, 4.16 kV switchgear and remote shutdown rooms, fire zones 91, 92, 98, 103, and 97

• Unit 2, B train emergency diesel generator (EDG) building, fire zones 162 and 164

• Unit 1 containment building Annual Inspection The inspectors evaluated the licensees fire brigade performance during a drill on February 10, 2014, and assessed the brigades capability to meet fire protection licensing basis requirements. The inspectors observed the following aspects of fire brigade performance:

• capability of fire brigade members

• leadership ability of the brigade leader

• use of turnout gear and firefighting equipment

• team effectiveness

• compliance with site procedures The inspectors also assessed the ability of control room operators to combat potential fires, including identifying the location of the fire, dispatching the fire brigade, and sounding alarms. The inspectors evaluated the licensees ability to declare the appropriate emergency action level and make required notifications in accordance with NUREG 0654, Criteria for Preparation and Evaluation of Radiological Emergency Response Plans and Preparedness in Support of Nuclear Power Plants (FEMA-REP-1)and Title 10 of the Code of Federal Regulations (10 CFR) Part 50, Domestic Licensing of Production and Utilization Facilities. Documents reviewed are listed in the

.

b. Findings

No findings were identified.

1R07 Heat Sink Performance

a. Inspection Scope

Annual Review The inspectors verified the readiness and availability of the Unit 1 B train centrifugal charging pump (CCP) motor heat exchanger to perform its design function by observing performance tests or reviewing reports of those tests, verifying the licensee uses the periodic maintenance method outlined in Generic Letter 89-13, Service Water System Problems Affecting Safety Related Equipment, dated July 18, 1989, observing the licensees heat exchanger inspections, and verifying critical operating parameters through direct observation or by reviewing operating data. Additionally, the inspectors verified that the licensee had entered any significant heat exchanger performance problems into their corrective action program and that the corrective actions were appropriate. Documents reviewed are listed in the Attachment.

b. Findings

No findings were identified.

1R08 Inservice Inspection (ISI) Activities (IP 71111.08P, Unit 1)

a. Inspection Scope

Non-Destructive Examination Activities and Welding Activities: From March 24, 2014, through April 1, 2014, the inspectors conducted an on-site review of the implementation of the licensees ISI Program for monitoring degradation of the reactor coolant system, emergency feedwater systems, risk-significant piping and components, and containment systems in Unit 1. The inspectors activities included a review of non-destructive examinations (NDEs) to evaluate compliance with the applicable edition of the American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel Code (BPVC),

Section XI (Code of Record: 2001 Edition with 2003 Addenda; 3rd Interval, 2nd Period, 3rd Outage), and to verify that indications and defects (if present) were appropriately evaluated and dispositioned in accordance with the requirements of the ASME Code,Section XI, acceptance standards.

The inspectors directly observed the following NDE mandated by the ASME Code to evaluate compliance with the ASME Code Section XI and Section V requirements and, if any indications and defects were detected, to evaluate if they were dispositioned in accordance with the ASME Code or an NRC-approved alternative requirement.

• Ultrasonic test of component 1-1204-021-19-RB. 6 Elbow to Pipe Weld, Class 2

• VT-3 of component 1-1202-030-H003, Pipe Support The inspectors reviewed records of the following NDEs mandated by the ASME Code Section XI to evaluate compliance with the ASME Code Section XI and Section V requirements and, if any indications and defects were detected, to evaluate if they were dispositioned in accordance with the ASME Code or an NRC-approved alternative requirement.

• PT of control rod drive (CRD) housing weld, component number 1-1201-V6-001-W184

• PT of CRD housing weld, component number 1-1201-V6-001-W188 The inspectors observed the welding activities referenced below and reviewed associated documents in order to evaluate compliance with procedures and the ASME Code. The inspectors reviewed the work order, including the weld data sheets, welding procedures, procedure qualification records, and welder performance qualification records.

• Check valve 1-1204-U4-145 replacement on safety injection system line 1-1204-030-2, valve is an ASME Class 1 and 2 break In addition, the inspectors reviewed the following work orders for the weld packages, including weld data sheets, welding procedures, procedure qualification records, and welder performance qualification records.

• Work order SNC 495226, Seal Weld in the Chemical and Volume Control System Line 1-1208-008-3, ASME Class 1

• Work order SNC 555148, Chemical and Volume Control System Line 1-1208-012-2, ASME Class 1 During non-destructive surface and volumetric examinations performed since the previous refueling outage, the licensee did not identify any relevant indications that were analytically evaluated and accepted for continued service. Therefore, no NRC review was completed for this inspection procedure attribute.

PWR Vessel Upper Head Penetration (VUHP) Inspection Activities: For the Unit 1 vessel head, a bare metal visual examination was not required this outage pursuant to 10 CFR 50.55a as it had been performed during the last refueling outage. Therefore, no NRC review was done for this inspection procedure attribute.

Boric Acid Corrosion Control (BACC) Inspection Activities: The inspectors reviewed the licensees BACC program activities to ensure implementation with commitments made in response to NRC Generic Letter 88-05, Boric Acid Corrosion of Carbon Steel Reactor Pressure Boundary, and applicable industry guidance documents. Specifically, the inspectors performed an on-site record review of procedures and the results of the licensees containment walk-down inspections performed during the current spring refueling outage (1R18). The inspectors also interviewed the BACC program owner, conducted an independent walkdown of containment to evaluate compliance with licensees BACC program requirements, and verified that degraded or non-conforming conditions, such as boric acid leaks, were properly identified and corrected in accordance with the licensees BACC and corrective action programs.

The inspectors reviewed the following condition reports and associated corrective actions related to evidence of boric acid leakage to evaluate if the corrective actions completed were consistent with the requirements of the ASME Code Section XI and 10 CFR Part 50, Appendix B, Criterion XVI.

• CR 533081, Leak of valve 1HV3565

• CR 537487, Active boric acid leak on 1-1208-U4-A11

• CR 547269, Active boric acid leak on 1-1204-U4-137

• CR 738478, Flange downstream of valve 1-1204-U4-009 has active boric acid leak The inspectors reviewed the following engineering evaluations completed for evidence of boric acid leakage to determine if degraded components were documented in the corrective action program. The inspectors also evaluated corrective actions for any degraded components to determine if they met the ASME Section XI Code.

• Technical Evaluation (TE) 547817, associated with CR 547269 and includes Corrosion Assessment (CA) 1204-2013-006

• TE 556248, associated with CR 537487 and includes CA 1208-2012-002 Steam Generator (SG) Tube Inspection Activities: The inspectors observed the following activities and/or reviewed the following documentation and evaluated them against the licensees technical specifications, commitments made to the NRC, ASME Section XI, and Nuclear Energy Institute 97-06 (Steam Generator Program Guidelines):

• Reviewed the licensees in-situ SG tube pressure testing screening criteria. In particular, the inspectors assessed whether assumed NDE flaw sizing accuracy was consistent with data from the EPRI examination technique specification sheets (ETSS) or other applicable performance demonstrations.

• Compared the numbers and sizes of SG tube flaws/degradation identified against the licensees previous outage operational assessment.

• Reviewed the SG tube eddy current testing (ET) examination scope and expansion criteria.

• Evaluated if the licensees SG tube ET examination scope included potential areas of tube degradation identified in prior outage SG tube inspections and/or as identified in NRC generic industry operating experience applicable to the licensees SG tubes.

• Reviewed the licensees implementation of their extent of condition inspection scope and repairs for new SG tube degradation mechanism(s).

• Reviewed the licensees repair criteria and processes.

• Verified that primary-to-secondary leakage (e.g., SG tube leakage) was below three gallons per day, or the detection threshold, during the previous operating cycle according to licensee procedures.

• Evaluated if the ET equipment and techniques used by the licensee to acquire data from the SG tubes were qualified or validated to detect the known/expected types of SG tube degradation in accordance with Appendix H, Performance Demonstration for Eddy Current Examination, of EPRI Pressurized Water Reactor Steam Generator Examination Guidelines, Revision 7.

• Reviewed the licensees secondary side SG foreign object search and removal activities.

• Reviewed ET personnel qualifications.

Identification and Resolution of Problems: The inspectors performed a review of a sample of ISI-related problems which were identified by the licensee and entered into the corrective action program as CRs. The inspectors reviewed the CRs to confirm that the licensee had appropriately described the scope of the problem, and had initiated corrective actions. The review also included the licensees consideration and assessment of operating experience events applicable to the plant. The inspectors performed this review to ensure compliance with 10 CFR Part 50, Appendix B, Criterion XVI, Corrective Action, requirements. Documents reviewed are listed in the

.

b. Findings

No findings were identified.

1R11 Licensed Operator Requalification Program

.1 Resident Inspector Quarterly Review of Licensed Operator Requalification

The inspectors observed an evaluated simulator scenario administered to an operating crew conducted in accordance with the licensees accredited requalification training program.

The inspectors assessed the following:

• licensed operator performance

• the ability of the licensee to administer the scenario and evaluate the operators

• the quality of the post-scenario critique

• simulator performance Documents reviewed are listed in the Attachment.

.2 Resident Inspector Quarterly Review of Licensed Operator Performance

The inspectors observed licensed operator performance in the main control room on February 4, 2014, during the performance of in-service testing.

The inspectors assessed the following:

• use of plant procedures

• control board manipulations

• communications between crew members

• use and interpretation of instruments, indications, and alarms

• use of human error prevention techniques

• documentation of activities

• management and supervision Documents reviewed are listed in the Attachment.

b. Findings

No findings were identified.

1R12 Maintenance Effectiveness

a. Inspection Scope

The inspectors assessed the licensees treatment of the two issues listed below in order to verify the licensee appropriately addressed equipment problems within the scope of the maintenance rule (10 CFR 50.65, Requirements for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants). The inspectors reviewed procedures and records in order to evaluate the licensees identification, assessment, and characterization of the problems as well as their corrective actions for returning the equipment to a satisfactory condition. The inspectors also interviewed system engineers and the maintenance rule coordinator to assess the accuracy of performance deficiencies and extent of condition. Documents reviewed are listed in the Attachment.

• CR 351658 - Unplanned limiting condition of operation (LCO): Intermediate Range nuclear instrument (NI) 2N-36 failure

• CR 664671 and CR 681079 - Unit 2, Chemical and volume control system (CVCS)1208 taken to maintenance rule a(1) status

b. Findings

No findings were identified.

1R13 Maintenance Risk Assessments and Emergent Work Control

a. Inspection Scope

The inspectors reviewed the five maintenance activities listed below to verify the licensee assessed and managed plant risk as required by 10 CFR 50.65(a)(4) and licensee procedures. The inspectors assessed the adequacy of the licensees risk assessments and implementation of risk management actions. The inspectors also verified that the licensee was identifying and resolving problems with assessing and managing maintenance-related risk using the corrective action program. Additionally, for maintenance resulting from unforeseen situations, the inspectors assessed the effectiveness of the licensees planning and control of emergent work activities.

Documents reviewed are listed in the Attachment.

• Units 1 and 2, week of January 6, 2014, elevated Green risk condition associated with high-risk work in the high-voltage switchyard concurrent with the grid being in alert level 1A due to extreme low temperatures

• Unit 2, week of January 20, 2014, Yellow risk condition associated with the unplanned inoperability of Unit 2 A EDG concurrent with the high-risk work being performed in the high-voltage switchyard

• Unit 1, week of February 24, 2014, Yellow risk condition due to Unit 1 A NSCW pump #1 out of service (OOS) concurrent with Unit 1 B RHR pump OOS for scheduled maintenance outage

• Unit 1, week of March 3, 2014, Yellow risk condition due to Unit 1 B motor-driven AFW pump out of service for maintenance concurrent with Unit 1 A NSCW pump

1. 1 out of service for motor replacement

• Unit 1, week of March 24, 2014, outage risk assessment monitoring (ORAM) Yellow outage risk condition for reactor coolant system (RCS) at mid-loop level

b. Findings

No findings were identified.

1R15 Operability Evaluations

a. Inspection Scope

The inspectors selected the six operability determinations or functionality evaluations listed below for review based on the risk-significance of the associated components and systems. The inspectors reviewed the technical adequacy of the determinations to ensure that technical specification operability was properly justified and the components or systems remained capable of performing their design functions. To verify whether components or systems were operable, the inspectors compared the operability and design criteria in the appropriate sections of the technical specification and updated final safety analysis report to the licensees evaluations. Where compensatory measures were required to maintain operability, the inspectors determined whether the measures in place would function as intended and were properly controlled. Additionally, the inspectors reviewed a sample of corrective action documents to verify the licensee was identifying and correcting any deficiencies associated with operability evaluations.

Documents reviewed are listed in the Attachment.

• CR 760774, Failure of EDG 2A Over Speed Trip Test

• CR 757479, Void detected on pipeline 1-1204-032-2

• CR 769409, Increase of active leak on casing flange connection of jacket water keep warm pump

• CR 757018, EQPM 11201R5074 for 1PV0455A not performed within required frequency

• CR 774835, ATC Nuclear Part 21 Notification for Moore Industries 535 Single Loop Controllers

• CR 775371, 2AA02-07 Closing springs slow to close

b. Findings

No findings were identified.

1R18 Plant Modifications

a. Inspection Scope

The inspectors verified that the two plant modifications listed below did not affect the safety functions of important safety systems. The inspectors confirmed the modifications did not degrade the design bases, licensing bases, and performance capability of risk significant structures, systems, and components. The inspectors also verified modifications performed during plant configurations involving increased risk did not place the plant in an unsafe condition. Additionally, the inspectors evaluated whether system operability and availability, configuration control, post-installation test activities, and changes to documents, such as drawings, procedures, and operator training materials, complied with licensee standards and NRC requirements. In addition, the inspectors reviewed a sample of related corrective action documents to verify the licensee was identifying and correcting any deficiencies associated with modifications.

Documents reviewed are listed in the Attachment.

• SNC451183, Temporary modification to restore functionality of annunciator ALB07A01, BA Tank 1 Hi/Lo Level

• SNC517148, Unit 1 replacement of seal injector filter system with sub-micron filter system

b. Findings

No findings were identified.

1R19 Post-Maintenance Testing

a. Inspection Scope

The inspectors either observed post-maintenance testing or reviewed the test results for the six maintenance activities listed below to verify the work performed was completed correctly and the test activities were adequate to verify system operability and functional capability.

• Maintenance Work Order (MWO) SNC418749, A train NSCW pump 3 rebuild, and MWO SNC407844, A train NSCW pump 3 motor refurbish

• MWO SNC532915, - 21205P6002M01 (2B RHR pump motor) - Change oil in lower motor bearing

• MWO SNC408063, - (1A 1204SIP) - A train safety injection (SI) pump 3 motor 11204P6003M01 preventive maintenance (PM) and MWO SNC407988, - (1A 1204SIP) - 1HV8814 motor-operated mini-flow isolation MOV PM

• MWO SNC535924, Unit 2 accumulator tank 1 pressure channel failure

• MWO SNC557853, Unit 2 A motor-driven AFW pump tripped while taking to pull-to-lock

• MWO SNC560682, Unit 1 pressurizer backup heater A will not operate from control room The inspectors evaluated these activities for the following:

• acceptance criteria were clear and demonstrated operational readiness

• effects of testing on the plant were adequately addressed

• test instrumentation was appropriate

• tests were performed in accordance with approved procedures

• equipment was returned to its operational status following testing

• test documentation was properly evaluated Additionally, the inspectors reviewed a sample of corrective action documents to verify the licensee was identifying and correcting any deficiencies associated with post-maintenance testing. Documents reviewed are listed in the Attachment.

b. Findings

No findings were identified.

1R20 Refueling and Other Outage Activities

a. Inspection Scope

For the Unit 1 refueling outage beginning March 16, 2014, through the remainder of the report period, the inspectors evaluated the following outage activities:

• outage planning

• shutdown, cooldown, and refueling

• reactor coolant system instrumentation and electrical power configuration

• reactivity and inventory control

• decay heat removal and spent fuel pool cooling system operation The inspectors verified that the licensee:

• considered risk in developing the outage schedule

• controlled plant configuration in accordance with administrative risk reduction methodologies

• developed work schedules to manage fatigue

• developed mitigation strategies for loss of key safety functions

• adhered to operating license and technical specification requirements Additionally, inspectors verified that safety-related and risk-significant structures, systems, and components not accessible during power operations were maintained in an operable condition. The inspectors also reviewed a sample of related corrective action documents to verify the licensee was identifying and correcting any deficiencies associated with outage activities. Documents reviewed are listed in the Attachment.

b. Findings

No findings were identified.

1R22 Surveillance Testing

a. Inspection Scope

The inspectors reviewed the six surveillance tests listed below and either observed the test or reviewed test results to verify testing adequately demonstrated equipment operability and met technical specification and licensee procedural requirements. The inspectors evaluated the test activities to assess for preconditioning of equipment, procedure adherence, and equipment alignment following completion of the surveillance.

Additionally, the inspectors reviewed a sample of related corrective action documents to verify the licensee was identifying and correcting any deficiencies associated with surveillance testing. Documents reviewed are listed in the Attachment.

Routine Surveillance Tests

• 14658-2 Rev. 8, SSPS Slave Relay K740 and K741 A Train Test Semi-automatic Switchover to Containment Sump

• 14454A-1 Rev. 1.1, Motor-driven AFW pump A operability test

• 14808B-1 Rev. 4, Train B Centrifugal Charging Pump and Check Valve IST and Response Time Test

• 14850-1 Rev. 54.1, Cold Shutdown Valve Inservice Test Containment Isolation Valve

• 24349-1 Rev. 9.0, Containment Penetration No. 49 Excess Letdown and Seal Water Leakoff Local Leak Rate Test In-Service Tests (IST)

• 14806C-1 Rev. 4, Containment Spray Pump and Check Valve Refueling Comprehensive Full Flow Inservice Test

b. Findings

No findings were identified.

1EP6 Drill Evaluation

a. Inspection Scope

The inspectors observed the emergency preparedness drill conducted on March 12, 2014. The inspectors observed licensee activities in the Burke County Office Complex during a hostile action based tabletop exercise that included several local and state agencies from both Georgia and South Carolina. The inspectors evaluated implementation of the emergency plan, including event classification, notification, and protective action recommendations. The inspectors evaluated the licensees performance against criteria established in the licensees procedures. Additionally, the inspectors attended the post-exercise critique to assess the licensees effectiveness in identifying emergency preparedness weaknesses and verified the identified weaknesses were entered in the corrective action program.

b. Findings

No findings were identified.

4OA1 Performance Indicator Verification

a. Inspection Scope

The inspectors reviewed a sample of the performance indicator (PI) data for Unit 1 and Unit 2, submitted by the licensee, for the PIs listed below. The inspectors reviewed plant records compiled between January 2013, and December 2013 to verify the accuracy and completeness of the data reported for the station. The inspectors verified that the PI data complied with guidance contained in Nuclear Energy Institute 99-02, Regulatory Assessment Performance Indicator Guideline, and licensee procedures. The inspectors also confirmed the PIs were calculated correctly. In addition, the inspectors reviewed a sample of related corrective action documents to verify the licensee was identifying and correcting any deficiencies associated with PI data. Documents reviewed are listed in the Attachment.

Cornerstone: Initiating Events

• unplanned scrams per 7000 critical hours

• unplanned power changes per 7000 critical hours

• unplanned scrams with complications

b. Findings

No findings were identified.

4OA2 Identification and Resolution of Problems

.1 Routine Review

The inspectors screened items entered into the licensees corrective action program in order to identify repetitive equipment failures or specific human performance issues for follow-up. The inspectors reviewed condition reports, attended screening meetings, or accessed the licensees computerized corrective action database.

.2 Annual Follow-up of Selected Issues

a. Inspection Scope

The inspectors conducted a detailed review of condition reports CR 737334, Unit 2 safety injection accumulator tank #1 pressure channel failed high, and CR 783219, Motor-driven AFW pump A tripped while taking to pull-to-lock. The inspectors evaluated the following attributes of the licensees actions:

• complete and accurate identification of the problem in a timely manner

• evaluation and disposition of operability and reportability issues

• consideration of extent of condition, generic implications, common cause, and previous occurrences

• classification and prioritization of the problem

• identification of root and contributing causes of the problem

• identification of any additional condition reports

• completion of corrective actions in a timely manner Documents reviewed are listed in the Attachment.

b. Findings and Observations

No findings were identified.

4OA3 Event Follow-up

.1 (Closed) Licensee Event Report (LER) 05000424/2012-005-00: Main Steam Isolation

Valve Failures On October 8, 2013, with Unit 1 in Mode 2, the operators began preparations for power ascension. At 1616, as a main feedwater pump was being placed online, the control room operators noted a divergence in the RCS loop differential temperatures (Ts),steam pressures, and steam flows between loops 1 & 4 and loops 2 & 3. Loops 1 & 4 showed increasing loop Ts, lowering steam pressure, and some minimal steam flow, while loops 2 and 3 showed no loop T, increasing steam pressures (to the point of lifting the loop 2 and 3 atmospheric relief valves), and no steam flow. The Main Control Board hand switches indicated that all MSIVs and associated bypass valves were open.

The operators identified the potential impact to the core neutron flux and stopped power ascension. Following discussions with plant management and engineering, the operators placed the plant in a safe condition by inserting a manual trip of the reactor at 2155. The licensee subsequently assembled an issue response team (IRT) and a root cause team to investigate the cause of the diverging indications and to determine the required corrective actions. The root cause team determined that the root cause of the MSIV stem failures was due to temperature aging embrittlement of the stem material.

The enforcement aspects associated with this event were documented in NRC integrated inspection report 05000424,425/2012005 (Section 4OA2). No other findings were identified. This LER is closed.

.2 (Closed) Licensee Event Report 05000424/2013-001-00: Failure to Comply with

Technical Specification LCO 3.8.4 On November 27, 2013, an internal wiring discrepancy was discovered on the Unit 1 Class 1E battery charger 1AD1CB (one of two redundant battery chargers on A train)following the trip of the battery charger input breaker. The wiring discrepancy prevented the charger from performing all required functions of Technical Specification LCO 3.8.4, DC Sources - Operating, and rendered it inoperable. The LCO requires, in part, one of two redundant battery chargers to be operable. Subsequent review of battery charger maintenance activities determined that on September 30, 2013 the remaining redundant A train battery charger (1AD1CA) was removed from service for maintenance activities for approximately 14.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />. This resulted in both train A battery chargers being inoperable simultaneously, which is condition that requires restoration of the inoperable direct-current (DC) source (i.e. train) within two hours (LCO 3.8.4 Condition C).

Although the degraded charger (1AD1CB) was able to maintain battery terminal voltage within limits under minimal loading condition, the DC source was inoperable for a time greater than allowed by technical specification. The inspectors reviewed the LER, the associated condition report and apparent cause determination, and subsequent action items. The enforcement aspects associated with this event were documented in NRC integrated inspection report 05000424/2013005 (Section 1R19). No other findings were identified. This LER is closed.

.3 (Closed) Licensee Event Report 05000425/2013-002: Automatic Unit 2 Reactor Trip

due to loss of Generator Excitation On October 19, 2013, while Unit 2 was operating in Mode 1 at 100 percent power, the main generator excitation system experienced a failure that tripped the main generator and subsequently tripped the turbine and reactor. The reactor trip system, the engineered safety features actuation system, feedwater and auxiliary feedwater systems actuated as designed and the plant was stabilized in Mode 3. The inspectors reviewed the LER, the associated condition report and apparent cause determination, and subsequent action items. No findings or violations of NRC requirements were identified.

This LER is closed.

.4 (Closed) Licensee Event Report 05000425/2013-003: Manual Reactor Trip due to

Lowering Condenser Vacuum On October 22, 2013, while Unit 2 was operating in Mode 1 at 25 percent power, the unit was manually tripped due to lowering condenser vacuum. At the time of the reactor trip, maintenance activities were in progress on the B main feedwater pump turbine. Prior to the work commencing, the operators discussed how the maintenance work on the turbine could potentially impact condenser pressure. As a precaution, the operators established operating limits in case condenser vacuum was lost. As the lift of the turbine steam chest was initiated, condenser vacuum began lowering and maintenance personnel were directed to lower the steam chest back on the turbine. However, condenser vacuum continued to decrease, and as it approached the pre-determined operational limit of 23 inches of mercury, the shift supervisor directed a manual reactor trip. The reactor trip system, feedwater and auxiliary feedwater systems actuated as designed and the plant was stabilized in Mode 3. The inspectors reviewed the LER, the associated condition report and apparent cause determination, and subsequent action items. No findings or violations of NRC requirements were identified. This LER is closed.

4OA5 Other Activities

.1 Institute of Nuclear Power Operations (INPO) Report Review

In accordance with Executive Director of Operations Procedure 0220, Coordination with the Institute of Nuclear Power Operations, the inspectors reviewed the most recent INPO evaluation and accreditation reports dated February 10, 2014, to determine if those reports identified safety or training issues not previously identified by NRC evaluations. The report contained no safety issues that were not already known by the NRC.

b. Findings and Observations

No findings were identified.

.2 Cross-Cutting Aspect Common Language Initiative Transition

The table below provides a cross-reference from the 2013 and earlier findings and associated cross-cutting aspects to the new cross-cutting aspects resulting from the common language initiative. These aspects and any others identified since January 2014 will be evaluated for cross-cutting themes and potential substantive cross-cutting issues in accordance with IMC 0305 starting with the 2014 mid-cycle assessment review.

Finding Old Cross-Cutting Aspect New Cross-Cutting Aspect 05000424/2013005-01 P.1(c) P.2 05000424,425/2013007-01 P.1(c) P.2 05000424,425/2013403-01 P.1(a) P.1 05000424,425/2013403-02 P.1(d) P.3

4OA6 Meetings, Including Exit

.1 Exit Meeting

On April 22, 2014 the resident inspectors presented the inspection results to Mr. T.

Tynan and other members of the licensees staff. The inspectors confirmed that proprietary information was not provided or examined during the inspection.

ATTACHMENT:

SUPPLEMENTAL INFORMATION

KEY POINTS OF CONTACT

Licensee personnel

R. Barringer, Security Manager

R. Collins, Chemistry Manager

G. Gunn, Licensing Supervisor

R. Hons, Training Manager

M. Johnson, Health Physics Manager

F. Pournia, Engineering Director

J. Robinson, Engineering Programs Manager

G. Saxon, Plant Manager

J. Thomas, Operations Director

T. Thompson, Systems Engineering Manager

T. Tynan, Site Vice-President

K. Walden, Licensing Engineer

S. Waldrup, Licensing Director

NRC personnel

M. Cain, Senior Resident Inspector

T. Chandler, Resident Inspector

F. Ehrhardt, Chief, Region II Reactor Projects Branch 2

LIST OF ITEMS

OPENED AND CLOSED

Closed

05000424/2012-005-00 LER Main Steam Isolation Valve Failures (Section 4OA3.1)

05000424/2013-001-00 LER Failure to Comply with Technical Specification LCO 3.8.4 (Section 4OA3.2)

05000425/2013-002-00 LER Automatic Unit 2 Reactor Trip due to loss of Generator Excitation (Section 4OA3.3)

05000425/2013-003-00 LER Manual Reactor Trip due to Lowering Condenser Vacuum (Section 4OA3.4)