IR 05000321/2016004

NRC Integrated Inspection Report 05000321/2016004 and 05000366/2016004

ML17031A284
Person / Time
Site:	Hatch
Issue date:	01/31/2017
From:	Shane Sandal NRC/RGN-II/DRP/RPB2
To:	Vineyard D Southern Nuclear Operating Co
References
IR 2016004
Download: ML17031A284 (24)

Text

UNITED STATES NUCLEAR REGULATORY COMMISSION ary 31, 2017

SUBJECT:

EDWIN I. HATCH NUCLEAR PLANT - NRC INTEGRATED INSPECTION REPORT 05000321/2016004 AND 05000366/2016004

Dear Mr. Vineyard:

On December 31, 2016, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at your Edwin I. Hatch Nuclear Plant, Units 1 and 2. On January 27, 2017, the NRC inspectors discussed the results of this inspection with Mr. Richard Spring and other members of your staff. Inspectors documented the results of this inspection in the enclosed inspection report.

NRC inspectors documented one finding of very low safety significance (Green) in this report which also involved a violation of NRC requirements. If you contest the violation or significance of the NCV, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the U.S. Nuclear Regulatory Commission, ATTN: Document Control Desk, Washington DC 20555-0001; with copies to the Regional Administrator, Region II; the Director, Office of Enforcement, U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001; and the NRC resident inspector at the Hatch Nuclear Plant.

If you disagree with a cross-cutting aspect assignment in this report, 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 Hatch Nuclear Plant. In accordance with Title 10 of the Code of Federal Regulations 2.390, Public Inspections, Exemptions, Requests for Withholding, of the NRC's Rules of Practice, a copy of this letter, its enclosure, and your response (if any) will be available electronically for public inspection in the NRCs Public Document Room or from the Publicly Available Records (PARS) component of the NRC's Agencywide Documents 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/

Shane R. Sandal, Chief Reactor Projects Branch 2 Division of Reactor Projects Docket Nos.: 05000321, 05000366 License Nos.: DPR-57, NPF-5

Enclosure:

IR 05000321/2016004, 05000366/2016004 w/Attachment: Supplemental Information

REGION II==

Docket Nos.: 50-321, 50-366 License Nos.: DPR-57 and NPF-5 Report No.: 05000321/2016004; and 05000366/2016004 Licensee: Southern Nuclear Operating Company, Inc.

Facility: Edwin I. Hatch Nuclear Plant Location: Baxley, Georgia Dates: October 1, 2016 through December 31, 2016 Inspectors: D. Hardage, Senior Resident Inspector D. Retterer, Resident Inspector B. Caballero, Senior Operations Engineer (1R11)

S. Sanchez, Senior Emergency Preparedness Inspector (1EP2, 1EP3, 1EP4, 1EP5, 4OA1)

J. Hickman, Emergency Preparedness Inspector (1EP2, 1EP3, 1EP4, 1EP5, 4OA1)

Approved by: Shane R. Sandal, Chief Reactor Projects Branch 2 Division of Reactor Projects Enclosure

SUMMARY

IR 05000321/2016004; and 05000366/2016004; October 1, 2016, through December 31, 2016;

Edwin I. Hatch Nuclear Plant, Units 1 and 2; Operability Determinations and Functionality Assessments The report covered a 3-month period of inspection by resident and regional inspectors. There was one NRC-identified violation documented in this report. The significance of inspection findings are indicated by their color (i.e., greater than Green, or Green, White, Yellow, Red) and determined using Inspection Manual Chapter (IMC) 0609, Significance Determination Process, (SDP) dated April 29, 2015. The cross-cutting aspects are determined using IMC 0310,

Aspects within the Cross-Cutting Areas, dated December 4, 2014. All violations of NRC requirements are dispositioned in accordance with the NRCs Enforcement Policy dated November 1, 2016. The NRCs program for overseeing the safe operations of commercial nuclear power reactors is described in NUREG-1649, Reactor Oversight Process, Revision 6.

Documents reviewed by the inspectors, not identified in the Report Details, are identified in the List of Documents Reviewed section of the Attachment.

Cornerstone: Mitigating Systems

Green.

An NRC-identified non-cited violation (NCV) of Hatch Unit 1 Technical Specification 5.4, Procedures, was identified when procedures did not include inspection criteria for ice buildup of the Unit 1 nitrogen storage tank piping. The licensees failure to establish controls to ensure that ice buildup on the Unit 1 Containment Atmospheric Dilution (CAD) subsystem piping did not exceed ten inches was a performance deficiency. The licensee entered the condition into their corrective action plan as CR10296584, and performed de-icing activities to remove the ice buildup.

This performance deficiency was more than minor, because ice buildup on the CAD system may lead to CAD subsystem inoperability if left uncorrected. The finding screened as Green because the CAD subsystem remained operable. The inspectors determined that this finding had a cross-cutting aspect in the Initiation aspect of the problem identification and resolution area, because the licensee did not initiate a condition report upon initially identifying the issue. [P.1] (Section 1R15)

REPORT DETAILS

Summary of Plant Status

Unit 1: Unit 1 began the inspection period at or near 100 percent rated thermal power (RTP).

On November 22, unit power was briefly reduced to 60 percent RTP to swap steam jet air ejectors. The unit was returned to 100 percent RTP and operated at or near 100 percent RTP through the remainder of the inspection period.

Unit 2: Unit 2 began the inspection period at 100 percent rated thermal power (RTP). On December 9, the unit entered end-of-cycle coast down and remained in coast down throughout the remainder of the inspection period.

REACTOR SAFETY

Cornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity

1R01 Adverse Weather Protection

a. Inspection Scope

Seasonal Extreme Weather Conditions: The inspectors conducted a detailed review of the stations adverse weather procedures for extreme low temperatures. The inspectors verified that weather-related equipment deficiencies identified during the previous year had been placed into the work control process and/or corrected before the onset of seasonal extremes. The inspectors evaluated the licensees implementation of adverse weather preparation procedures and compensatory measures before the onset of seasonal extreme weather conditions. The inspectors evaluated the following risk-significant systems:

• Unit 1 intake area

• Unit 2 intake area Impending Adverse Weather Conditions: The inspectors reviewed the licensees preparations to protect risk-significant systems from Hurricane Matthew expected October 7, 2016. The inspectors evaluated the licensees implementation of adverse weather preparation procedures and compensatory measures, including operator staffing, before the onset of the adverse weather conditions. The inspectors reviewed the licensees plans to address the ramifications of potentially lasting effects that may result from hurricane 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 that the licensee implemented periodic equipment walkdowns or other measures to ensure that the condition of plant equipment met operability requirements.

b. Findings

No findings were identified.

1R04 Equipment Alignment

a. Inspection Scope

Partial Walkdown: The inspectors verified that critical portions of the following systems were correctly aligned by performing partial walkdowns. The inspectors determined the correct system lineup by reviewing plant procedures and drawings listed in the

.

• Unit 1 B emergency diesel generator alignment to Unit 2 during the Unit 2 A emergency diesel generator planned system maintenance outage

• Unit 2 B train RHR while the opposite train was out of service for planned system maintenance outage

• Unit 2 reactor core isolation cooling system while high pressure coolant injection was out of service for a planned maintenance outage

• Unit 1 A and C emergency diesel generator while the B emergency diesel generator was out of service for inspection of the flexible drive gear assembly.

b. Findings

No findings were identified.

1R05 Fire Protection

a. Inspection Scope

Quarterly Inspection: The inspectors evaluated the adequacy of fire plans by comparing the fire plans to the defined hazards and defense-in-depth features specified in the fire protection program the following five fire areas.

• Unit 1 & 2, service water valve pits, fire zones 1602, 1602, 2601, and 2602

• Unit 2, reactor building elevation 203 working floor and stack monitoring room, fire zones 2205X and 2205Y

• Unit 1 & 2, condensate storage tank area, fire zones 1603 and 2603

• Unit 1, railroad airlock, fire zone 1604

• Unit 2, EDG Switchgear Rooms, fire zones 2404, 2408 and 2409 The inspectors assessed the following:

• 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

• material condition and operational status of fire protection equipment

b. Findings

No findings were identified.

1R06 Flood Protection Measures

a. Inspection Scope

Underground Cables: The inspectors reviewed related flood analysis documents and inspected the areas listed below containing cables whose failure could disable risk-significant equipment. The inspector directly observed the condition of cables and cable support structures and, as applicable, verified that dewatering devices and drainage systems were functioning properly. In addition, the inspectors verified the licensee was identifying and properly addressing issues using the corrective action program.

• Unit 1, PB1-DO

• Unit 1, PB1-DP

b. Findings

No findings were identified.

1R11 Licensed Operator Requalification Program and Licensed Operator Performance

a. Inspection Scope

Resident Inspector Quarterly Review of Licensed Operator Requalification: The inspectors observed classroom training of an operating crew for an upcoming refueling outage.

Resident Inspector Quarterly Review of Licensed Operator Performance: The inspectors observed licensed operator performance in the main control room during an emergent down power to 60 percent RTP due to a malfunctioning steam jet air ejector.

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 Annual Review of Licensee Requalification Examination Results: On December 7, 2016, the licensee completed the annual requalification operating examinations required to be administered to all licensed operators in accordance with Title 10 of the Code of Federal Regulations 55.59(a)(2), Requalification Requirements, of the NRCs Operators Licenses. The inspectors performed an in-office review of the overall pass/fail results of the individual operating examinations and the crew simulator operating examinations in accordance with Inspection Procedure (IP) 71111.11, Licensed Operator Requalification Program. These results were compared to the thresholds established in Section 3.02, Requalification Examination Results, of IP 71111.11.

b. Findings

No findings were identified.

1R12 Maintenance Effectiveness

a. Inspection Scope

The inspectors assessed the licensees treatment of the three issues listed below 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 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.

• Unit 1, Main Condenser tube leak

• Unit 1, Diesel Emergency Power, Cross drive replacements - quality control verifications were properly specified and were implemented as specified.

• Unit 1, Generator stator cooling inlet filter high differential pressure

b. Findings

No findings were identified.

1R13 Maintenance Risk Assessments and Emergent Work Control

a. Inspection Scope

The inspectors reviewed the four maintenance activities listed below to verify that 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.

• Unit 1 and 2, October 2 - October 9, 2016 including 2A EDG planned maintenance outage and preparation for Hurricane Matthew.

• Unit 1 and 2, October 23 - October 30, 2016 including 1A plant service water pump, 2C residual heat removal pump, and 2A standby gas treatment system planned maintenance outages.

• Unit 2, November 6 - November 13, 2016 including Unit 2 HPCI planned maintenance outage.

• Unit 1 and 2, November 27 - December 3, 2016, including 1A and 1B EDG flexible drive inspections and emergent replacement of the 1A EDG flexible drive assembly.

b. Findings

No findings were identified.

1R15 Operability Determinations and Functionality Assessments

a. Inspection Scope

Operability Determinations and Functionality Assessments Review: The inspectors selected the five 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.

• CR 10287561 Thru wall plant service water leak near valve 2P41F1176

• CR 10293453 PSW tornado missile protection vulnerability

• CR 10296368 Icing buildup on nitrogen storage tanks

• CR 10308478 Drywell High Press ATTS card 2E11-N694D gross fail indication

• CR 10310460 2A EDG Pilot line air flange bolting loose

b. Findings

Introduction:

An NRC-identified Green NCV of Hatch Unit 1 Technical Specification 5.4, Procedures, was identified on November 8, 2016, when procedures did not include inspection criteria for ice buildup of the Unit 1 nitrogen storage tank piping.

Description:

On November 8, 2016, the inspectors identified ice buildup of eight inches in diameter on the Unit 1 nitrogen storage tank piping and six inches on the Unit 2 piping to the ambient vaporizer. The licensee determined the Unit 2 containment atmospheric dilution (CAD) subsystem was operable. However, the licensee did not initiate a condition report or perform an operability determination for Unit 1. On November 14, 2016, inspectors identified an accumulation of ice on the Unit 1 nitrogen storage tank piping of approximately ten inches. The licensee entered the issue into the corrective action program and performed de-icing activities. The licensee determined the Unit 1 subsystem was operable.

Procedure 34SO-T48-002, Containment Atmospheric Control and Dilution Systems, stated Ice formation on the piping at the Nitrogen Storage Tank greater than ten inches will cause excess stress on the piping and per engineering will require periodic de-icing.

The limitation on CAD system piping icing ensures piping/ice interactions during a postulated seismic event do not result in loss of function. However, only Unit 2 operator rounds procedure OPS-1822, U2 Inside Rounds Reactor BLDG, contained the guidance to confirm ice buildup less than eight inches and provided direction to declare the CAD subsystem inoperable if buildup was greater than ten inches in diameter. The licensee had not established similar controls for Unit 1 to ensure that de-icing activities would occur prior to buildup greater than ten inches for the Unit 1 CAD system. On November 9, 2016, the licensee entered the lack of icing inspections and limitations for Unit 1 into the corrective action program.

Analysis:

The failure to establish controls to ensure that ice buildup on the Unit 1 CAD subsystem piping did not exceed ten inches was a performance deficiency. This performance deficiency was more-than-minor, because ice buildup on the CAD system may lead to CAD subsystem inoperability if left uncorrected. The inspectors screened this finding using IMC 0609, Appendix A, The Significant Determination Process (SDP)

For Findings At-Power, dated June 19, 2012. The finding screened as Green per Section A of Exhibit 2, Mitigating Systems Screening Questions, because the CAD subsystem remained operable. The inspectors determined that this finding had a cross-cutting aspect in the Initiation aspect of the problem identification and resolution area, because the licensee did not initiate a condition report upon initially identifying the issue.

[P.1]

Enforcement:

Hatch Unit 1 Technical Specification 5.4.1 required, in part, that procedures shall be established, implemented, and maintained covering the applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978. Regulatory Guide 1.33, Appendix A, Section 1.h required, in part, that log entries be established for the operation of safety-related activities. Contrary to the above, the licensee did not establish log entry requirements for the operation of the Unit 1 CAD subsystem. Specifically, log entry requirements were not established in the Unit 1 operator rounds procedure to ensure that the buildup of excessive ice on the nitrogen storage tank piping would not occur. The condition existed from November 8, 2016 until November 14, 2016. The condition was entered into the licensees corrective action program as CR10296584. This violation was treated as an NCV, consistent with the Enforcement Policy: NCV 05000321/2016004-01; Failure to Establish Icing Controls on CAD Subsystem.

1R18 Plant Modifications

a. Inspection Scope

For plant modification SNC539300, Unit 1 Reliable Hardened Containment Vent Design, the inspectors:

• verified that the modifications did not affect the safety functions of important safety systems.

• confirmed the modifications did not degrade the design bases, licensing bases, and performance capability of risk significant structures, systems and components.

• verified modifications performed during plant configurations involving increased risk did not place the plant in an unsafe condition.

• 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.

• reviewed a sample of related corrective action documents to verify the licensee was identifying and correcting any deficiencies associated with modifications.

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.

• SNC 520109, 2D RHR pump meggar and oil change, October 12, 2016

• SNC 778365, HCU 1807 scram valve diaphragm replacement, October 22, 2016

• SNC 457072, 2C RHR pump meggar and oil change, October 25, 2016

• SNC 781254, Adjust Packing on MOV 1E21F004B, November 16, 2016

• SNC 812013, Perform inspection and repair/replace 1B EDG crossdrive assembly, November 28, 2016

• SNC 832959, 2E11N694D gross fail indication, December 15, 2016 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.

b. Findings

No findings were identified.

1R22 Surveillance Testing

a. Inspection Scope

The inspectors reviewed the four surveillance tests listed below. The surveillance test was either observed directly or test results were reviewed to verify testing activities and results provide objective evidence that the affected equipment remain capable of performing their intended safety functions and maintain their operational readiness consistent with the facilitys current licensing basis. The inspectors evaluated the test activities to assess for:

• preconditioning of equipment,

• appropriate acceptance criteria,

• calibration and appropriateness of measuring and test equipment,

• procedure adherence, and

• equipment alignment following completion of the surveillance.

Additionally, the inspectors reviewed a sample of significant surveillance testing problems documented in the licensees corrective action program to verify the licensee was identifying and correcting any testing problems associated with surveillance testing.

Routine Surveillance Tests

• 34SV-E41-002-1, HPCI Pump Operability, Ver. 31.5

• 34SV-T22-001-0, Secondary Containment Test, Ver. 17.0

• 34SV-R43-006-1, Diesel Generator 1C Semi-Annual Test, Ver.14.1

• 34SV-R43-001-1, Diesel Generator 1A Monthly Test, Ver. 24.3

b. Findings

No findings were identified.

1EP2 Alert and Notification System Evaluation

a. Inspection Scope

The inspectors evaluated the adequacy of the licensees methods for testing and maintaining the alert and notification system in accordance with NRC Inspection Procedure 71114, Attachment 02, Alert and Notification System Evaluation. The applicable planning standard, 10 CFR Part 50.47 (b) (5), and its related 10 CFR Part 50, Appendix E requirements were used as reference criteria. The criteria contained in NUREG-0654, Criteria for Preparation and Evaluation of Radiological Emergency Response Plans and Preparedness in Support of Nuclear Power Plants, Revision 1, were also used as a reference.

The inspectors reviewed various documents which are listed in the Attachment and interviewed personnel responsible for system performance. This inspection activity satisfied one inspection sample for the alert and notification system on a biennial basis.

b. Findings

No findings were identified.

1EP3 Emergency Response Organization Staffing and Augmentation System

a. Inspection Scope

The inspectors reviewed the licensees Emergency Response Organization (ERO)augmentation staffing requirements and process for notifying the ERO to ensure the readiness of key staff for responding to an event and timely facility activation. The qualification records of key position ERO personnel were reviewed to ensure all ERO qualifications were current. A sample of problems identified from augmentation drills or system tests performed since the last inspection was reviewed to assess the effectiveness of corrective actions. The inspection was conducted in accordance with NRC Inspection Procedure 71114, Attachment 03, Emergency Response Organization Staffing and Augmentation System. The applicable planning standard, 10 CFR 50.47(b)

(2), and its related 10 CFR 50, Appendix E requirements were used as reference criteria.

The inspectors reviewed various documents which are listed in the Attachment. This inspection activity satisfied one inspection sample for the ERO staffing and augmentation system on a biennial basis.

b. Findings

No findings were identified.

1EP4 Emergency Action Level and Emergency Plan Changes

a. Inspection Scope

Since the last NRC inspection of this program area, one change was made to the Radiological Emergency Plan and two changes were made to the emergency action levels, along with changes to several implementing procedures. The licensee determined that, in accordance with 10 CFR 50.54(q), the Plan continued to meet the requirements of 10 CFR 50.47(b) and Appendix E to 10 CFR Part 50. The inspectors reviewed these changes to evaluate for potential reductions in the effectiveness of the Plan. However, this review was not documented in a Safety Evaluation Report and does not constitute formal NRC approval of the changes. Therefore, these changes remain subject to future NRC inspection in their entirety.

The inspection was conducted in accordance with NRC Inspection Procedure 71114, 04, Emergency Action Level and Emergency Plan Changes. The applicable planning standards of 10 CFR 50.47(b), and its related requirements in 10 CFR 50, Appendix E were used as reference criteria. The inspectors reviewed various documents that are listed in the Attachment to this report. This inspection activity satisfied one inspection sample for the emergency action level and emergency plan changes on an annual basis.

b. Findings

No findings were identified.

1EP5 Maintenance of Emergency Preparedness

a. Inspection Scope

The inspectors reviewed the corrective actions identified through the Emergency Preparedness program to determine the significance of the issues, the completeness and effectiveness of corrective actions, and to determine if issues were recurring. The licensees post-event after action reports, self-assessments, and audits were reviewed to assess the licensees ability to be self-critical, thus avoiding complacency and degradation of their emergency preparedness program. Inspectors reviewed the licensees 10 CFR 50.54(q) change process, personnel training, and selected screenings and evaluations to assess adequacy. The inspectors toured facilities and reviewed equipment and facility maintenance records to assess licensees adequacy in maintaining them. The inspectors evaluated the capabilities of selected radiation monitoring instrumentation to adequately support Emergency Action Level (EAL)declarations.

The inspection was conducted in accordance with NRC Inspection Procedure 71114, 05, and Maintenance of Emergency Preparedness. The applicable planning standards, related 10 CFR 50, Appendix E requirements, and 10 CFR 50.54(q) and (t)were used as reference criteria. The inspectors reviewed various documents which are listed in the Attachment. This inspection activity satisfied one inspection sample for the maintenance of emergency preparedness on a biennial basis.

b. Findings

No findings were identified.

1EP6 Drill Evaluation

a. Inspection Scope

The inspectors observed the emergency preparedness drill conducted on October 12, 2016. The inspectors observed licensee activities in the simulator and/or technical support center to evaluate implementation of the emergency plan, including event classification, notification, dose assessment, 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, submitted by the licensee, for the Unit 1 and Unit 2 PIs listed below. The inspectors reviewed plant records compiled between October 2015 and October 2016 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 verified the accuracy of reported data that were used to calculate the value of each PI.

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.

Cornerstone: Mitigating Systems

• safety system functional failures

• heat removal system

• cooling water system The inspectors sampled licensee submittals relative to the PIs listed below for the period October 1, 2015, through September 30, 2016. To verify the accuracy of the PI data reported during that period, PI definitions and guidance contained in NEI 99-02, Regulatory Assessment Performance Indicator Guideline, Revision 7, was used to confirm the reporting basis for each data element.

Cornerstone: Emergency Preparedness

• Drill/Exercise Performance (DEP)

• Emergency Response Organization (ERO) Readiness

• Alert and Notification System (ANS) Reliability For the specified review period, the inspectors examined data reported to the NRC, procedural guidance for reporting PI information, and records used by the licensee to identify potential PI occurrences. The inspectors verified the accuracy of the PI for ERO drill and exercise performance through review of a sample of drill and event records.

The inspectors reviewed selected training records to verify the accuracy of the PI for ERO drill participation for personnel assigned to key positions in the ERO. The inspectors verified the accuracy of the PI for alert and notification system reliability through review of a sample of the licensees records of periodic system tests. The inspectors also interviewed the licensee personnel who were responsible for collecting and evaluating the PI data. Licensee procedures, records, and other documents reviewed within this inspection area are listed in the Attachment. This inspection satisfied three inspection samples for PI verification on an annual basis.

b. Findings

No findings were identified.

4OA2 Problem Identification and Resolution

.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 Semi-Annual Trend Review

a. Inspection Scope

The inspectors reviewed issues entered in the licensees corrective action program and associated documents to identify trends that could indicate the existence of a more significant safety issue. The inspectors focused their review on repetitive equipment issues, but also considered the results of inspector daily condition report screenings, licensee trending efforts, and licensee human performance results. The review nominally considered the 6-month period of July 2016 thru December 2016 although some examples extended beyond those dates when the scope of the trend warranted.

The inspectors compared their results with the licensees analysis of trends.

Additionally, the inspectors reviewed the adequacy of corrective actions associated with a sample of the issues identified in the licensees trend reports. The inspectors also reviewed corrective action documents that were processed by the licensee to identify potential adverse trends in the condition of structures, systems, and/or components as evidenced by acceptance of long-standing non-conforming or degraded conditions.

b. Findings and Observations

No findings were identified.

.3 Annual Follow-up of Selected Issues

a. Inspection Scope

The inspectors conducted a detailed review of condition report 10299111, B HVAC Unit Tripping Trend Identified.

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

b. Findings

No findings were identified.

4OA6 Meetings, Including Exit

On January 27, 2017, the resident inspectors presented the inspection results to Mr.

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

ATTACHMENT:

SUPPLEMENTAL INFORMATION

KEY POINTS OF CONTACT

Licensee Personnel

B. Anderson, Radiation Protection Manager

J. Bailey, Licensing Engineer

H. Betsill, Emergency Preparedness Specialist

G. Brinson, Maintenance Director

D. Coffin, Corporate Emergency Preparedness Manager

J. Collins, Licensing Supervisor

B. Deen, Training Director

B. Duvall, Chemistry Manager

B. Hulett, Engineering Director

G. Johnson, Regulatory Affairs Manager

R. Lewis, Operations Support Manager

K. Long, Operations Director

A. Manning, Work Management Director

L. Mansfield, Fleet Emergency Preparedness Director

J. Merritt, Security Manager

D. Moore, Emergency Preparedness Specialist

R. Outler, Emergency Preparedness Supervisor

C. Rush, Nuclear Oversight Manager

R. Spring, Plant Manager

D. Vineyard, Site Vice President

B. Wainwright, Operations Training Manager

LIST OF REPORT ITEMS

Opened and Closed

NCV

05000321/2016004-01, Failure to Establish Icing Controls on CAD Subsystem (Section 1R15)