IR 05000219/2013004

IR 05000219-13-004, July 1, 2013 - September 30, 2013, Oyster Creek, Integrated

ML13318A298
Person / Time
Site:	Oyster Creek
Issue date:	11/14/2013
From:	Hunegs G K NRC/RGN-I/DRP/PB6
To:	Pacilio M J Exelon Generation Co, Exelon Nuclear
HUNEGS, GK
References
IR-13-004
Download: ML13318A298 (28)

Text

November 14, 2013

Mr. Michael Senior Vice President, Exelon Generation President and Chief Nuclear Officer, Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555

SUBJECT: OYSTER CREEK NUCLEAR GENERATING STATION - NRC INTEGRATED INSPECTION REPORT 05000219/2013004

Dear Mr. Pacilio:

On September 30, 2013, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at your Oyster Creek Nuclear Generating Station. The enclosed inspection report documents the inspection results, which were discussed on November 7, 2013 with Mr. G. Stathes, Site Vice President, and other members of your staff. The inspection examined activities conducted under your license as they relate to safety and with the conditions of your license. The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel. This report documents one NRC-identified finding of very low safety significance (Green). This finding was determined to involve a violation of NRC requirements. However, because of the very low safety significance, and because it was entered into your corrective action program, the NRC is treating this finding as a non-cited violation (NCV), consistent with Section 2.3.2 of the NRC Enforcement Policy. If you contest the NCV in this report, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the Nuclear Regulatory Commission, ATTN.: Document Control Desk, Washington, DC 20555-0001; with copies to the Regional Administrator, Region I; the Director, Office of Enforcement, United States Nuclear Regulatory Commission, Washington, DC 20555-0001; and the NRC Resident Inspectors at Oyster Creek. In addition, if you disagree with the cross-cutting aspect assigned to the finding 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 I, and the NRC Resident Inspectors at Oyster Creek. enclosure, and your response (if any) will be available electronically for public inspection in the NRC Agencywide Documents Access Management System (ADAMS). ADAMS is accessible from the NRC website at http://www.nrc.gov/reading-rm/adams.htmL (the Public Electronic Reading Room).

Sincerely,/RA/ Gordon K. Hunegs, Chief Reactor Projects Branch 6 Division of Reactor Projects Docket Nos.: 50-219 License Nos.: DPR-16

Enclosure:

Inspection Report 05000219/2013004

w/Attachment:

Supplementary Information cc w/encl: Distribution via ListServ

ML13318A298 SUNSI Review Non-Sensitive Sensitive Publicly Available Non-Publicly Available OFFICE RI/DRP RI/DRP RI/DRP NAME mmt JKulp/ GKH for BBickett/ GKH for GHunegs/ GKH DATE 11/12 /13 11/12/13 11/13/13 1 Enclosure U.S. NUCLEAR REGULATORY COMMISSION REGION I Docket Nos.: 50-219 License Nos.: DPR-16 Report No.: 05000219/2013004 Exelon: Exelon Nuclear Facility: Oyster Creek Nuclear Generating Station Location: Forked River, New Jersey Dates: July 1, 2013 September 30, 2013 Inspectors: J. Kulp, Senior Resident Inspector A. Patel, Resident Inspector J. DeMarshall, Operations Engineer B. Dionne, Health Physicist E. Burkett, Emergency Preparedness Inspector J. Laughlin, Emergency Preparedness Inspector Approved By: Gordon K. Hunegs, Chief Reactor Projects Branch 6 Division of Reactor Projects 2 Enclosure

SUMMARY OF FINDINGS

IR 05000219/2013004; 07/01/2013 09/30/2013; Exelon Energy Company, LLC, Oyster Creek Generating Station; Adverse weather protection. This report covered a three-month period of inspection by resident inspectors and announced inspections performed by regional inspectors. Inspectors identified one finding of very low safety significance (Green), which was an NCV. The significance of most findings is indicated by their color (Green, White, Yellow, Red) using Inspection Manual Chapter (IMC) 0609, -cutting aspect for the finding was - for which the SDP does not apply may be Green, or be assigned a severity level after NRC management reactors is described in NUREG-Revision 4, dated December 2006.

Cornerstone: Mitigating Systems

Green.

The inspectors identified a Green, non-cited violation (NCV) of 10 CFR 50, regulatory requirements and design basis for the emergency diesel generators were correctly translated into instructions. Specifically, the inspectors determined that Exelon did not ensure that the design basis for flood control features was maintained and correctly translated into specifications, drawings, procedures and instructions for the installation of a security wall modification around the emergency diesel generator building which affected the probable maximum precipitation flood protection features of the building. Exelon entered this issue into the corrective action program for resolution as IR 1546148 and implemented corrective actions which included removing soil and re-grading the area adjacent to the building to improve the storm water runoff flow patterns. The performance deficiency was more than minor because the finding affected the protection against external factors attribute of the mitigating systems cornerstone objective of ensuring the availability, reliability and capability of systems that respond to initiating events to prevent undesirable consequences. The inspectors determined this finding involved the loss or degradation of equipment or function specifically designed to mitigate a seismic, flooding or severe weather initiating event; however, it did not involve the assumption that the protected equipment or safety function was completely failed or unavailable, and did not involve the total loss of any safety function, identified by Exelon through a PRA, IPEEE or similar analysis that contributes to external event initiated core damage accident sequences. Therefore, the inspectors determined the finding to be of very low safety significance (Green). This finding has a cross-cutting aspect in the area of Problem Identification and Resolution, because Exelon, beginning in 2009 and as recent as September 2012, did not thoroughly evaluate the problem such that the resolution addressed the cause of an issue that potentially impacted nuclear safety P.1(c). (Section 1R01)

Other Findings

None.

REPORT DETAILS

Summary of Plant Status Oyster Creek began the inspection period at 100 percent power. Oyster Creek reduced power periodically from July 2, 2013 to July 22, 2013 to comply with New Jersey Department of Environmental Protection thermal discharge permit limitations. On September 1, 2013, operators reduced power to 80% to perform a rod pattern adjustment and returned the reactor to 100% power on September 2, 2013. On September 6, 2013, operators lowered power to 95% to perform repairs on the level controls for a high pressure feed heater and returned the reactor to 100% power. On September 29, 2013, operators reduced power to approximately 25% to perform troubleshooting on the turbine speed control system. On September 30, 2013, operators commenced a planned reactor shutdown and entered the 1M30 planned maintenance outage to perform corrective maintenance on the turbine speed control system.

REACTOR SAFETY

Cornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity

1R01 Adverse Weather Protection

.1 External Flooding

a. Inspection Scope

During the week of July 24, 2013 and on August 13, 2013, the inspectors performed an inspection of the external flood protection measures for the Oyster Creek Nuclear Generating Station. The inspectors reviewed the UFSAR, Chapter 2.4.2, which depicted the design flood levels and protection areas containing safety-related equipment to identify areas that may be affected by external flooding. The inspectors conducted a general site walkdown of the emergency diesel generator building to ensure that Exelon erected flood protection measures in accordance with design specifications. The inspectors also reviewed operating procedures for mitigating external flooding during severe weather to determine if Exelon planned or established adequate measures to protect against external flooding events.

b. Findings

Introduction.

The inspectors identified a Green, non-cited violation (NCV) of 10 CFR 50, regulatory requirements and design basis for the emergency diesel generators were correctly translated into instructions. Specifically, Exelon did not ensure the design basis for the emergency diesel generator building probable maximum precipitation flood control features was maintained and correctly translated into instructions for installation of a security wall around the emergency diesel generator building.

Description.

As described in the update final safety analysis report (UFSAR), Section 2.4.2.3, the probable maximum precipitation level is 23.5 feet above mean sea level (MSL). As stated in the Oyster Creek Individual Plant Examination for External Events (IPEEE), section 5.2.3, the emergency diesel generator building is at an elevation of 23.0 feet above MSL, therefore a six inch high asphalt dike was constructed to prevent water entry into the emergency diesel generator building. Additionally, AmerGen

, ground surface is even with the top of the ramp at the Emergency Diesel Generator Building at Elevation 23.5 feet, and slopes down to the road at the north end of the building and the south side of the site to the south of the building. Precipitation will thus On August 13, 2013, the inspectors performed a walk down of the emergency diesel generator building during a heavy rainstorm to determine if the flood protection features listed in the UFSAR for protection against external flooding of the building during a probable maximum precipitation event were adequate. The inspectors observed that rainwater was accumulating and flowing over the flood protection features into the emergency diesel generator building. The inspectors determined that the design features were not protecting the building against external flooding. Exelon entered the issue into their corrective action program as IR 1546148. As an immediate temporary corrective action, Exelon installed sandbags at the entrance of the emergency diesel generator building to mitigate the amount of water that would enter the building during a PMP event. Long term corrective actions were completed to re-grade the area such that water would not accumulate and enter the emergency diesel generator building.

The inspectors noted that in 2009, Exelon made several modifications throughout the site to improve security. One of the modifications was to install a solid security wall around the emergency diesel generator building. Modification design package, OC 09-00549, for the security wall was generated using Exelon procedure CC-AA-CC-AA-103, step 4.1.4, from a flooding perspective especially any change to the topography and assure that all affected analyses are updated and the impacts understood before allowing installation to -AA-103 directs the use of procedure CC-AA-and Configuration Change Impact Screening,pplicable design considerations and impacts of the modification. CC-AA-102 provides a comprehensive listing of configuration change considerations that could impact the design basis of the system, structures and components.

CC-AA-102, step 4.1.38, identifies civil and structural requirements that must be addressed during the configuration change process. Sub-step 4.1.38.6 determines if the configuration change adversely affects the external and internal flooding analysis.

.38 addressed other effects concerning civil and structural considerations but did not identify any effects on the flooding analysis.

Further, CC-AA-102, step 4.1.14, determines changes to environmental conditions and resultant adverse environmental impacts of the modification. Environmental conditions include 4.1.14 identified that the installed security wall had the potential to increase water retention in the area between the wall and the emergency diesel generator building. Exelon reviewed the potential to increase water retention and determined the wall will not exacerbate the problem and may serve to limit water retention because the configuration of the wall is expected to redirect the rainfall runoff around and/or away from the emergency diesel generator building. As a result, the inspectors observed that no instructions were provided to the installation crew to grade the ground or to provide any improvements to address the interruption of stormwater runoff patterns described in licensing basis documents caused by installation of the solid security wall.

The inspectors determined evaluations to assess impacts on the emergency diesel generator as a result of the security modification were inadequate as evidenced when heavy rainstorm water entered the emergency diesel generator building. The inspectors also identified continuing opportunities for Exelon to re-evaluate or affirm the design of the security wall installation and its potential impact on the emergency diesel generators. In September 2012, the inspectors questioned the effect of the installation of the security wall and the apparent grading of the ground on the stormwater runoff patterns in the vicinity of the emergency diesel generator building. Specifically, the inspectors questioned the impact of not having the grading around the emergency diesel generator building sloped away from the emergency diesel generator building. Exelon entered this question into the corrective action program as IR 1410069.

response to IR 1410069 stated, in part, the ground around the emergency diesel generator consists of a thin layer of coarse gravel and sand, which allow for faster infiltration of water into the ground therefore this should mitigate the effects of water retention. No additional action, further evaluations or design reviews of the wall installation were performed.

Analysis.

The inspectors determined that Exelon did not ensure the design basis for flood control features were correctly translated into instructions for the installation of a security wall around the emergency diesel generator building. The performance deficiency was more than minor because the finding affected the protection against external factors attribute of the mitigating systems cornerstone objective of ensuring the availability, reliability and capability of systems that respond to initiating events to prevent undesirable consequences. Specifically, installation of the security wall changed the surface water runoff patterns and the grade of the ground which affected the flood protection of the emergency diesel generator during a probable maximum precipitation event.

The inspectors determined that this finding affected the external event mitigation systems portion of the Mitigating Systems cornerstone through the use of Table 2 of finding using - The inspectors determined this finding involved the loss or degradation of equipment or function specifically designed to mitigate a seismic, flooding or severe weather initiating event; however, it did not involve the assumption that the protected equipment or safety function was completely failed or unavailable, and did not involve the total loss of any safety function, identified by Exelon through a PRA, IPEEE or similar analysis that contributes to external event initiated core damage accident sequences. Therefore, the inspectors determined the finding to be of very low safety significance (Green). This finding has a cross-cutting aspect in the area of Problem Identification and Resolution, because Exelon did not thoroughly evaluate a problem such that the resolution addressed the cause of an issue that potentially impacted nuclear safety. Specifically, since 2009 and as recent as September 2012, was not adequate to evaluate the potential adverse impact of the security wall on the flood protection features of the emergency diesel generator building. (P.1(c))

Enforcement.

10 CFR 50 Appendix B, Criterion III, be established to assure that applicable regulatory requirements and the design basis, as defined in § 50.2 and as specified in the license application, for those structures, systems, and components to which this appendix applies are correctly translated into September 2009 and August 2013, Exelon did not properly translate the regulatory requirements of flood control measures into instructions for installation of a security wall which resulted in the flood control features of the emergency diesel generator building during a PMP to be inadequate. Because this violation was of very low safety significanthis violation is being treated as an NCV, consistent with the Enforcement Policy. (NCV 05000219/2013004-01, Physical Change To Security Feature Causes Flood Control Feature To Be Ineffective).

1R04 Equipment Alignment

.1 Partial System Walkdowns

a. Inspection Scope

The inspectors performed partial walkdowns of the following systems: Containment spray system II while containment spray system I was out-of-service on July 8, 2013 Emergency diesel generator I while emergency diesel generator II was out-of-service on September 9, 2013 A isolation condenser while B isolation condenser was out-of-service on September 24, 2013 The inspectors selected these systems based on their risk-significance relative to the reactor safety cornerstones at the time they were inspected. The inspectors reviewed applicable operating procedures, system diagrams, the UFSAR, technical specifications, work orders, condition reports, and the impact of ongoing work activities on redundant trains of equipment in order to identify conditions that could have impacted system performance of their intended safety functions. The inspectors also performed field walkdowns of accessible portions of the systems to verify system components and support equipment were aligned correctly and were operable. The inspectors examined the material condition of the components and observed operating parameters of equipment to verify that there were no deficiencies. The inspectors also reviewed whether Exelon staff had properly identified equipment issues and entered them into the corrective action program for resolution with the appropriate significance characterization.

b. Findings

No findings were identified.

1R05 Fire Protection

.1 Resident Inspectors Quarterly Walkdowns

a. Inspection Scope

The inspectors conducted tours of the areas listed below to assess the material condition and operational status of fire protection features. The inspectors verified that Exelon controlled combustible materials and ignition sources in accordance with administrative procedures. The inspectors verified that fire protection and suppression equipment was available for use as specified in the area pre-fire plan, and passive fire barriers were maintained in good material condition. The inspectors also verified that station personnel implemented compensatory measures for out of service, degraded, or inoperable fire protection equipment, as applicable, in accordance with procedures.

Turbine building basement south (TB-FZ-11D) on July 18, 2013 Feed pump room (TB-FZ-11F) on July 18, 2013 Reactor building southeast corner room (RB-FZ-1F1) on July 19, 2013 Reactor building (RB-FZ-1D) on July 19, 2013 Reactor building (RB-FZ-1C) on July 19, 2013 Fire water House (FW-FA-18) on August 8, 2013

b. Findings

No findings were identified.

.2 Fire Protection Drill Observation

a. Inspection Scope

The inspectors observed a fire brigade drill scenario conducted on September 10, 2013, that involved a fire in the A/B battery room. The inspectors evaluated the readiness of the plant fire brigade to fight fires. The inspectors verified that Exelon personnel identified deficiencies, openly discussed them in a self-critical manner at the debrief, and took appropriate corrective actions as required. The inspectors evaluated specific attributes as follows: Proper wearing of turnout gear and self-contained breathing apparatus Proper use and layout of fire hoses Employment of appropriate fire-fighting techniques Sufficient fire-fighting equipment brought to the scene Effectiveness of command and control Search for victims and propagation of the fire into other plant areas Smoke removal operations Utilization of pre-planned strategies Adherence to the pre-planned drill scenario Drill objectives met The inspectors also evaluated the fire brigade actions to determine whether these actions were in accordance with fire-fighting strategies.

b. Findings

No findings were identified.

1R11 Licensed Operator Requalification Program

.1 Quarterly Review of Licensed Operator Requalification Testing and Training

a. Inspection Scope

The inspectors observed licensed operator simulator training on July 10, 2013, which included inadvertent initiation of the A isolation condenser coincident with an anticipated transient without scram and subsequent large break loss of coolant accident. The inspectors also observed licensed operator simulator training on July 30, 2013, which included a small break loss of coolant accident with an anticipated transient without a scram. The inspectors evaluated operator performance during the simulated event and verified completion of risk significant operator actions, including the use of abnormal and emergency operating procedures. The inspectors assessed the clarity and effectiveness of communications, implementation of actions in response to alarms and degrading plant conditions, and the oversight and direction provided by the control room supervisor. The inspectors verified the accuracy and timeliness of the emergency classification made by the shift manager and the technical specification action statements entered by the shift technical advisor. Additionally, the inspectors assessed the ability of the crew and training staff to identify and document crew performance problems.

b. Findings

No findings were identified.

===.2 Quarterly Review of Licensed Operator Performance in the Main Control Room

a. Inspection Scope

The inspectors observed the containment spray and emergency service water pump system 2 operability testing on August 1, 2013. The inspectors observed the pre-shift brief to verify that the briefing met the criteria specified in Exelon briefing and human performance procedures. Additionally, the inspectors observed crew performance to verify that procedure use, communications, and coordination of activities met established expectations and standards.

b. Findings

No findings were identified.

=

a. Inspection Scope

The inspectors reviewed the samples listed below to assess the effectiveness of maintenance activities on SSC performance and reliability. The inspectors reviewed system health reports, corrective action program documents, maintenance work orders, and maintenance rule basis documents to ensure that Exelon was identifying and properly evaluating performance problems within the scope of the maintenance rule. For each sample selected, the inspectors verified that the SSC was properly scoped into the maintenance rule in accordance with 10 CFR 50.65 and verified that the (a)(2) performance criteria established by Exelon staff was reasonable. As applicable, for SSCs classified as (a)(1), the inspectors assessed the adequacy of goals and corrective actions to return these SSCs to (a)(2). Additionally, the inspectors ensured that Exelon staff was identifying and addressing common cause failures that occurred within and across maintenance rule system boundaries.

Main feedwater system a(1) determination (IR 1520128) on July 31, 2013 C reactor recirculation pump 1st stage seal leakage (IR 1538141) on August 1, 2013 A emergency service water pump degraded breaker (IR 1511787) on September 5, 2013

b. Findings

No findings were identified.

1R13 Maintenance Risk Assessments and Emergent Work Control

a. Inspection Scope

The inspectors reviewed station evaluation and management of plant risk for the maintenance and emergent work activities listed below to verify that Exelon performed the appropriate risk assessments prior to removing equipment for work. The inspectors selected these activities based on potential risk significance relative to the reactor safety cornerstones. As applicable for each activity, the inspectors verified that Exelon personnel performed risk assessments as required by 10 CFR 50.65(a)(4) and that the assessments were accurate and complete. When Exelon performed emergent work, the inspectors verified that operations personnel promptly assessed and managed plant risk. The inspectors reviewed the scope of maintenance work and discussed the results of consistent with the risk assessment. The inspectors also reviewed the technical specification requirements and inspected portions of redundant safety systems, when applicable, to verify risk analysis assumptions were valid and applicable requirements were met.

Containment spray system I out of service for planned maintenance on July 8, 2013 Containment spray system II out of service for surveillance testing and a maximum emergency generation alert on July 16, 2013 Reactor protection system I and main steam line temperature unexpected alarms on August 25, 2013 Emergency diesel generator II and B control rod drive pump out of service for planned maintenance on September 9, 2013 B isolation condenser and remote shutdown panel out of service for planned surveillance testing on September 25, 2013

b. Findings

No findings were identified.

1R15 Operability Determinations and Functionality Assessments

a. Inspection Scope

The inspectors reviewed operability determinations for the following degraded or non-conforming conditions: Increase in drywell temperature on July 17, 2013 Turbine bypass #4 valve inoperable on July 23, 2013 Increase in trunnion room temperature on July 25, 2013 The inspectors selected these issues based on the risk significance of the associated components and systems. The inspectors evaluated the technical adequacy of the operability determinations to assess whether technical specification operability was properly justified and the subject component or system remained available such that no unrecognized increase in risk occurred. The inspectors compared the operability and design criteria in the appropriate sections of the technical specifications and UFSAR to evaluations to determine whether the components or systems were operable. Where compensatory measures were required to maintain operability, the inspectors determined whether the measures in place would function as intended and were properly controlled by Exelon. The inspectors determined, where appropriate, compliance with bounding limitations associated with the evaluations.

b. Findings

No findings were identified.

1R18 Plant Modifications

.1 Temporary Modifications

a. Inspection Scope

The inspectors reviewed the temporary modifications listed below to determine whether the modifications affected the safety functions of systems that are important to safety. The inspectors reviewed 10 CFR 50.59 documentation and post-modification testing results, and conducted field walkdowns of the modifications to verify that the temporary modifications did not degrade the design bases, licensing bases, and performance capability of the affected systems.

Engineering Change Package OC-13-00226 Temporary change to jumper out the M1B transformer thermal detector trouble alarm Engineering Change Package OC-13-00304 Temporary change to modify the drywell equipment drain tank control logic Engineering Change Package OC-13-00378 Temporary change for main steal line tunnel temperature sensors

b. Findings

No findings were identified.

1R19 Post-Maintenance Testing

a. Inspection Scope

The inspectors reviewed the post-maintenance tests for the maintenance activities listed below to verify that procedures and test activities ensured system operability and functional capability. The inspectors reviewed the test procedure to verify that the procedure adequately tested the safety functions that may have been affected by the maintenance activity, that the acceptance criteria in the procedure was consistent with the information in the applicable licensing basis and/or design basis documents, and that the procedure had been properly reviewed and approved. The inspectors also witnessed the test or reviewed test data to verify that the test results adequately demonstrated restoration of the affected safety functions.

Standby gas treatment system 2 after corrective maintenance (M2330598) on July 25, 2013 Diesel fire pump 1 after biennial preventive maintenance (R2187093) on August 8, 2013 4160v fire panel after corrective maintenance (M2335952) on August 15, 2013 Average power range monitor #7 after corrective maintenance (C2030489) on August 19, 2013 B isolation condenser after preventive maintenance (R2119252) on September 24, 2013

b. Findings

No findings were identified.

1R20 Refueling and Other Outage Activities

a. Inspection Scope

1M30 maintenance outage, which started on September 29, 2013. The inspectors reviewed development and implementation of outage plans and schedules to verify that risk, industry experience, previous site-specific problems, and defense-in-depth were considered. The startup from this outage will be documented in inspection report 05000219/2013005. During the outage, the inspectors observed portions of the shutdown and cooldown processes and monitored controls associated with the following outage activities: Configuration management, including maintenance of defense-in-depth, commensurate with the outage plan for the key safety functions and compliance with the applicable technical specifications when taking equipment out of service Implementation of clearance activities and confirmation that tags were properly hung and that equipment was appropriately configured to safely support the associated work or testing Status and configuration of electrical systems and switchyard activities to ensure that technical specifications were met Monitoring of decay heat removal operations Reactor water inventory controls, including flow paths, configurations, alternative means for inventory additions, and controls to prevent inventory loss Activities that could affect reactivity Maintenance of secondary containment as required by technical specifications Identification and resolution of problems related to outage activities

b. Findings

No findings were identified.

1R22 Surveillance Testing

a. Inspection Scope

The inspectors observed performance of surveillance tests and/or reviewed test data of selected risk-significant SSCs to assess whether test results satisfied technical specifications, the UFSAR, and Exelon procedure requirements. The inspectors verified that test acceptance criteria were clear, tests demonstrated operational readiness and were consistent with design documentation, test instrumentation had current calibrations and the range and accuracy for the application, tests were performed as written, and applicable test prerequisites were satisfied. Upon test completion, the inspectors considered whether the test results supported that equipment was capable of performing the required safety functions. The inspectors reviewed the following surveillance tests: 646.4.036, Fire pump #2 operability test on July 2, 2013 609.4.007, Fire water makeup to isolation condensers in-service test on July 3, 2013 651.4.003, Standby gas treatment system #2 10 hour1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> operability test on August 19, 2013 610.3.215, Core spray system #2 operability test on September 13, 2013

b. Findings

No findings were identified. Cornerstone: Emergency Preparedness

==1EP4 Emergency Action Level and Emergency Plan Changes (IP 71114.04 1 sample)

a. Inspection Scope

Nuclear Security and Incident Response (NSIR) staff performed an in-office review of the latest revisions of various Emergency Plan Implementing Procedures (EPIPs) and the emergency plan located under ADAMS accession numbers ML13162A199 and ML13200A124 as listed in the Attachment. Exelon determined that in accordance with 10 CFR 50.54(q), the changes made in the revisions resulted in no reduction in the effectiveness of the emergency plan, and that the revised emergency plan continued to meet the requirements of 10 CFR 50.47(b) and Appendix E to 10 CFR Part 50. The NRC review was not documented in a safety evaluation report and did not constitute approval of Exelon generated changes; therefore, this revision is subject to future inspection. The specific documents reviewed during this inspection are listed in the attachment.

b. Findings

No findings were identified. 1EP6 Drill Evaluation==

.1 Emergency Preparedness Drill Observation

a. Inspection Scope

The inspectors evaluated the conduct of routine Exelon emergency drills on July 10, 2013 and on July 24, 2013 to identify any weaknesses and deficiencies in the classification, notification, and protective action recommendation development activities. The inspectors observed emergency response operations in the simulator and emergency operations facility to determine whether the event classification, notifications, and protective action recommendations were performed in accordance with procedures. The inspectors also reviewed the station drill critique to compare inspectors observations with those identified by Exelon staff in order to evaluate critique and to verify whether the Exelon staff was properly identifying weaknesses and entering them into the corrective action program.

b. Findings

No findings were identified.

a. Inspection Scope

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b. Findings

No findings were identified.

4OA1 Performance Indicator Verification

.1 Reactor Coolant System (RCS) Specific Activity and RCS Leak Rate (2 samples)

a. Inspection Scope

The inspectors reviewed submittal for the RCS specific activity and RCS leak rate performance indicators for both Unit 1 and Unit 2 for the period of July 1, 2012 through June 30, 2013. To determine the accuracy of the performance indicator data reported during those periods, the inspectors used definitions and guidance contained in NEI Document 99-Revision 6. The inspectors also reviewed RCS sample analysis and control room logs of daily measurements for RCS leakage, and compared that information to the data reported by the performance indicator.

b. Inspection Findings No findings were identified.

4OA6 Meetings, Including Exit

On November 7, 2013, the inspectors presented the inspection results to Mr. G. Stathes, Site Vice President, and other members of the Oyster Creek staff. The inspectors verified that no proprietary information was retained by the inspectors or documented in this report.

ATTACHMENT:

SUPPLEMENTARY INFORMATION

KEY POINTS OF CONTACT

Exelon Personnel

G. Stathes, Site Vice-President

R. Peak, Plant Manager

M. Ford, Director, Operations

G. Malone, Director, Engineering

J. Dostal, Director, Maintenance

C. Symonds, Director, Training

D. DiCello, Director, Work Management

M. McKenna, Manager, Regulatory Assurance

T. Farenga, Radiation Protection Manager

J. Renda, Manager, Environmental/Chemistry

T. Keenan, Manager, Site Security

P. Bloss, Senior Manager, Plant Engineering

H. Ray, Senior Manager, Design Engineering

E. Swain, Shift Operations Superintendent

J. Chrisley, Regulatory Assurance Specialist

D. Moore, Regulatory Assurance Specialist

K. Paez, Regulatory Assurance Specialist

LIST OF ITEMS OPENED, CLOSED, DISCUSSED, AND UPDATED

Opened/Closed

05000219/2013004-01 NCV Physical Change To Security Feature Causes Flood Control Feature To Be Ineffective (Section 1R01)

Section 1R01: Adverse Weather Protection

Procedures

CC-AA-103, Configuration Change Control For Permanent Physical Plant Changes, Revision 25

EN-AA-103, Environmental Review, Revision 4

CC-AA-102, Design Input and Configuration Change Impact Screening, Revision 27

Condition Reports

1543148

1560629

1434344

1546148

1548260

1410069

1404344

Work Orders

A2228056 A2336218

C2021630 M2336218 A2024731 A2222266

Attachment

Drawings

06-121-203, As-Built Survey Diesel Generator Building Security, Revision 0 4020-1, Emergency Diesel Generator Vault Plans, Sections & Details, dated August 1, 1967

GE 207A6068, Section View Emergency Diesel Generator (EDG) No 2 Switchgear U-3, Revision 0 -- Revision 4 3E-121-31-1000, Diesel Generator Bldg. Yard Fl. Drain Shutoff Valve & Storm Drain Piping Sys, Plan, Sections, Details, Revision 1

Miscellaneous

-219, SEP Topic No.

II-3- Enersys Ironclad Diesel Starting Batteries Specifications, Revision F, dated April 2007 Oyster Creek Individual Plant Examination for External Events (IPEEE), dated December 1, 1995 Component History Work Order Closure Remarks Report for System 157, dated October 15, 2013 NUREG 0822, Supplement 1, Integrated Plant Safety Assessment, Systematic Evaluation Program, Oyster Creek Nuclear Generating Station, dated July, 1988 AmerGen Letter-219, Reply to RAI on IPEEE), dated August 17, 2000 Oyster Creek Nuclear Generating Station Updated Final Safety Analysis Report section 2.4.8,

Component History Work Order Closure Remarks Report for System 157, dated September 18, 2013

OC-09-00549, ECR:

Security Force-On-Force Changes for EDG Bldg Protection, Revision 1

OC-06-00316, ECR:

EDG Building East Entrance Water Retention, Revision 2

OC-CCD-328384-001, Configuration Change Documentation, Diesel Generator Floor Drain Shutoff Valve and Storm Drain Piping System, Revision 0

Section 1R04: Equipment Alignment

Procedures

310, Containment Spray System Operation, Revision 104 307, Isolation Condenser System, Revision 123 341, Emergency Diesel Generator Operation, Revision 105

Drawings

GE 148F740, Sheet 1, Containment Spray System Flow Diagram, Revision 43

Section 1R05: Fire Protection

Procedures

OP-OC-201-008, Oyster Creek Pre-Fire Plans, Revision 16

OP-AA-201-009, Control of Transient Combustible Material, Revision 12

OP-OC-201-008-1027, -ision 2

OP-OC-201-008--- Elevations), Revision 1

OP-OC-201-008-1008, Reactor Building (-

OP-OC-201-008-1008, Reactor B1

OP-OC-201-008-1003, Reactor Building (- 1

OP-OC-201-008-1038, Fire Water House (Pond Area), Revision 1

Attachment

Miscellaneous

Fire Drill Scenario for A/B Battery Room, dated September 10, 2013 Fire Drill Record Sheet for A/B Battery Room, Crew D, dated September 10, 2013

Section 1R11: Licensed Operator Requalification Program

Procedures

607.4.017, Containment Spray and Emergency Service Water Pump System 2 Operability and

Quarterly Inservice Test, Revision 33

Condition Reports

1539216

1539184

1538800

1538777

Work Orders

R2222971

Miscellaneous

Oyster Creek July 10, 2013 DEP Training Drill, 7/10/2013 Oyster Creek Station License Operator Requalification Training Simulator Exercise Guide

Scenario 13-5.1, Revision 1

Section 1R12: Maintenance Effectiveness

Procedures

ER-AA-310, Implementation of the Maintenance Rule, Revision 8

ER-AA-310-1001, Maintenance Rule Scoping, Revision 4

ER-AA-310-1003, Maintenance Rule

Performance Criteria Selection, Revision 4

ER-AA-310-1005, Maintenance Rule

Dispositioning between (A1) and (A2), Revision 6

ABN-17, Feedwater System Abnormal Conditions, Revision 15

Condition Reports

1538141

1530337

1520128

1518353

1518638

1518661 1518824

Section 1R13: Maintenance Risk Assessments and Emergent Work Control

Procedures

OP-AA-108-117, Rev 003, Protected Equipment Program, Revision 3

WC-AA-104, Integrated Risk Management, Revision 18

WC-OC-101-1001, On-line Risk Management and Assessment, Revision 14 310, Containment Spray System Operation, Revision 104

ABN-60, Grid Emergency, Revision 13

WC-AA-101, On-Line Work Control Process, Revision 19

Drawings

GE 148F740, Sheet 1, Containment Spray System Flow Diagram, Revision 43

GE 237E566, Sheet 2, Reactor Protection System Electrical Elementary Diagram, Revision 46

Condition Reports

1550576

1550330

1551775

1550224

Attachment

Maintenance Orders/Work Orders A2334405

Miscellaneous

Operations Department Compensatory Action Report, dated August 29, 2013 Operations Department Protected Equipment Report, dated August 29, 2013

Section 1R15: Operability Determinations and Functionality Assessments

Procedures

OP-AA-108-115, Operability Evaluation, Revision 11 625.4.002, Main Turbine Surveillances, Revision 90 651.4.003, Standby Gas Treatment System 10-Hour Run

System 2, Revision 6

RAP-C8h, DW Temp Hi, Revision 1

EMG-SP26, Support Procedure 26 Determining Bulk Drywell Temperature, Revision 1 681.4.004, Technical Specification Log Sheet, Revision 26

EMG-3200.02, Primary Containment Control, Revision 19A

Condition Reports

1536776

1532601

1532592

1538924

1538685

1533116

1538925

Miscellaneous

Adverse Condition Monitoring and Contingency Plan, DW Bulk Temperature, Revision 1

OC-2013-OE-0008, Turbine Bypass Valve #4, Revision 0

Section 1R18: Plant Modifications

Procedures

101.2, Fire Protection Program, Revision 69

LS-AA-104-1003, 50.59 Screening Form, Revision 3 619.3.010, Main Steam Line Tunnel High Temperature Sensor Functional Test, Revision 13

Drawings

GE 237E566, Sheet 2, Reactor Protection System Electrical Elementary Diagram, Revision 46

Condition Reports

1514818

1529347

1535290

1440929

1441114

1549410

1550576

1550330

1551775

1550224

Work Orders

A2329696

C2030444 A2334405

Miscellaneous

OC-13-00226, TCCP at

FD-665-700 for M1B Thermal Detector Trouble Alarm, Revision 2

OC-13-00304, TCCP for Drywell Equipment Drain Tank Control Logic, Revision 0 Oyster Creek Nuclear Generating Station UFSAR, Section 7.3.1.1.1, Reactor Protection System, Revision 15 Oyster Creek Nuclear Generating Station UFSAR, Section 15.1.5, Steam System Piping Failures Outside Containment, Revision 17

Attachment

C-1302-6411-5320-001, O.C. Main Steam Tunnel Temperature Detector Modification, dated April 10, 1984

OC-641-A, Division System Design Description for Main Steam Line Tunnel Temperature Detectors Modification

Oyster Creek, Revision 0

LP 2621.828.0.0037, Lesson Plan

Reactor Protection System, Revision 12 2611-PGD-2621, Lesson Plan - Reactor Protection System, Revision 12 Oyster Creek Nuclear Generating Station Technical Specification 3.1, Protective Instrumentation, Amendment 235

OC-2013-E-0002, 50.59 Evaluation: TCCP to Jumper Out

TS-IB0010E and

TS-IB0010F, Revision 2

OC-2013-S-0061, 50.59 Screening: TCCP to Jumper Out

TS-IB0010E and

TS-IB0010F, Revision 0

OC-13-00378, Engineering Change Request: TCP to Jumper Out

TS-IB-0010E and

TS-IB-0010F, Revision 2

Section 1R19: Post-Maintenance Testing

Procedures

MA-AA-716-012, Post Maintenance Testing, Revision 17 651.4.003, Standby Gas Treatment System 10-Hour Run

System 2, Revision 6 645.4.001, Fire Pump #1 Operability Test, Revision 69 645.4.018, Fire Pump Monitoring Test, Revision 65

Condition Reports

(*NRC-identified)

1527568*

1513444

1022923

1545030*

1546038

Maintenance Orders/Work Orders R2222981 A2330598 M2330598 R2187093 R2167460

C2030168 R2212816 R2215511 M2335952

C2030489 A2330883

Section 1R20: Refueling and Other Outage Activities

Procedures

201, Plant Startup, Revision 85

ER-AA-600-1043, Shutdown Risk Management, Revision 5 203, Plant Shutdown, Revision 70 305, Shutdown Cooling System Operation, Revision 116

Section 1R22: Surveillance Testing

Procedures

609.4.007, Fire Water Makeup to Isolation Condensers IST, Revision 20 316.1, Condensate Transfer System, Revision 57 645.4.036, Fire Pump #2 Operability Test, Revision 22 651.4.003, Standby Gas Treatment System 10-Hour Run

System 2, Revision 8

Condition Reports

1548092

Work Orders

R2221801 R2214836 R2225393

Attachment

Section 1EP4: Emergency Action Level and Emergency Plan Changes

EP-AA-110-

EP-AA-110- EP-AA-

Section 1EP6: Drill Evaluation

Procedures

EP-AA-112-1 00-F-01, Shift Emergency Director Check List, Revision S

EP-AA-114-F-02, BWR Release in Progress Determination Guidance, Revision A

EP-AA-114-100-F-03, State/Local Notification Form, Revision G

EP-AA-122-1002-F-02, Drill & Exercise Objective Evaluation Data Tables, Revision B

Condition Reports

1534870

1535086

1539216

1539184

1538777

1538800

1538795

1549555

Miscellaneous

Oyster Creek July 10, 2013 DEP Training Drill, 7/10/2013 Oyster Creek Nuclear Generating Station, July 10, 2013 & July 24, 2013 Emergency Preparedness Integrate Drills Combined Report (2013-05), dated August 22, 2013 -- -- -- -- --- -- -- -- -- --- --- -- --- --- --- -- --- ---- ---- ----

Attachment ----- -- -- --- -- ----- - -- -- - - - - --- --- -- ---- -- ---- ---- -------

Attachment -- ---

Section 4OA1: Performance Indicator Verification

Miscellaneous

-