IR 05000219/2015001

IR 05000219/2015001, January 1, 2015 March 31, 2015, Oyster Creek Nuclear Generating Station - NRC Integrated Report

ML15133A235
Person / Time
Site:	Oyster Creek
Issue date:	05/14/2015
From:	Kennedy S R NRC/RGN-I/DRP/PB6
To:	Bryan Hanson Exelon Nuclear
KENNEDY, SR
References
IR 2015001
Download: ML15133A235 (46)

Text

May 14, 2015 Mr. Bryan Hanson 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 05000219/2015001

Dear Mr. Hanson:

On March 31, 2015, 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 April 17, 2015, with Garey Stathes, Site Vice President, and other members of your staff. The inspection examined activities conducted under your license as they relate to safety and The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel. This report documents three violations of NRC requirements, all of which were of very low safety significance (Green and/or Severity Level IV). Additionally, two licensee-identified violations, which were determined to be of very low safety significance, are listed in this report. However, because of the very low safety significance, and because they are entered into your corrective action program, the NRC is treating these findings as non-cited violations, consistent with Section 2.3.2.a of the NRC Enforcement Policy. If you contest the non-cited violations 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 Inspector at Oyster Creek Nuclear Generating Station. In addition, if you disagree with the cross-cutting aspect assigned to any finding 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 Inspector at Oyster Creek Nuclear Generating Station. In accordance with Title 10 of the Code of Federal Regulations any) will be 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/ Silas R. Kennedy, Chief Reactor Projects Branch 6 Division of Reactor Projects Docket Nos. 50-219 License Nos. DPR-16

Enclosure:

Inspection Report 05000219/2015001

w/Attachment:

Supplementary Information cc w/encl: Distribution via ListServ

ML15133A235 SUNSI Review Non-Sensitive Sensitive Publicly Available Non-Publicly Available OFFICE RI/DRP RI/DRP RI/DRP NAME APatel/ SRK for CBickett/ SRK for SKennedy/ SRK DATE 05/13/15 0513 /15 05/13/15 1 Enclosure U.S. NUCLEAR REGULATORY COMMISSION REGION I Docket Nos.: 50-219 License Nos.: DPR-16 Report No.: 05000219/2015001 Licensee: Exelon Nuclear Facility: Oyster Creek Nuclear Generating Station Location: Forked River, New Jersey Dates: January 1, 2015 March 31, 2015 Inspectors: A. Patel, Senior Resident Inspector J. Kulp, Senior Resident Inspector E. Andrews, Resident Inspector B. Bollinger, Project Engineer E. Burket, Emergency Preparedness Inspector N. Floyd, Reactor Inspector P. Kaufman, Senior Reactor Inspector M. Orr, Reactor Inspector J. Patel, Reactor Inspector Approved By: Silas R. Kennedy, Chief Reactor Projects Branch 6 Division of Reactor Projects 2 Enclosure

SUMMARY

IR 05000219/2015001; 01/01/2015 03/31/2015; Exelon Energy Company, LLC, Oyster Creek Generating Station; Post Maintenance Testing, Problem Identification and Resolution, Follow-Up of Events This report covered a three-month period of inspection by resident inspectors and announced inspections performed by regional inspectors. Inspectors identified one Severity Level IV non-cited violation (NCV) and two findings of very low safety significance (Green), which were NCVs. The significance of most findings are indicated by their color (i.e., greater than Green, or Green, White, Yellow, Red) and determined using Inspection Manual Chapter (IMC) 0609, -cutting aspects are -All viocommercial nuclear power reactors is described in NUREG-Revision 5.

Cornerstone: Barrier Integrity

Greentest requirements had been satisfied. Specifically, Exelon did not perform the proper post maintenance test procedure to assure that the requirements of Technical Specification 4.5.G.3 were satisfied following installation of a temporary modification to secondary containment. Exelon entered this issue into the corrective action program for resolution as issue report (IR) 2440643. Corrective actions include revising the process to perform the correct post maintenance test to ensure Technical Specification 4.5.G.3 is met. This finding is more than minor because it is associated with the configuration control (Standby Gas Trains) attribute of the Barrier Integrity cornerstone and adversely affected the cornerstone objective of providing reasonable assurance that physical design barriers protect the public from radionuclide releases caused by accidents or events. The inspectors June 19, 2012, and IMC 0609, Appendix G, Attachment 1, Significance Determination Process: Phase 1 Initial Screening and Characterization of secondary containment, the inspectors were required to further assess the finding using May 6, 2004. The inspectors determined that this finding is of very low safety significance (Green) because the decay heat values were low, given that the unit had been shut down for approximately three days, and reactor water level was greater than that required for movement of irradiated fuel assemblies within the reactor pressure vessel. This finding has a cross-cutting aspect in the area of Human Performance, Procedure Adherence, because Exelon personnel did not perform the post maintenance test specified by the work order. [H.8] (Section 1R19) Severitv Level lV. The inspectors identified a Severity Level IV NCV of 10 CFR 50.9(a) in that Exelon did not provide complete information in reports submitted per 10 CFR 50.72 and 10 CFR 50.73. Specifically, a licensee event report (LER) submitted on November 18, 2014, did not discuss a separate, partially opened secondary containment door that was discovered during the same time frame, which could have prevented the fulfillment of the safety function of secondary containment, and therefore was required to be discussed in the original LER. Exelon entered this issue into their corrective action program as IR 2440641. Planned corrective actions include revising the original LER to add a discussion of the partially opened secondary containment door. The inspectors determined that not providing a complete report in accordance with 10 CFR 5and correct and should have been prevented. Because the issue had the potential to affect ors evaluated this performance deficiency in accordance with the traditional enforcement process. In accordance with Section 2.2.2.d of the NRC Enforcement Policy, the inspectors determined that the performance deficiency identified with the reporting aspect of the event is a Severity Level IV violation because it is of more than minor concern with relatively inappreciable potential safety significance and is related to findings that were determined to be more than minor issues. In accordance with IMC 0612, Appendix B, this issue was not assigned a cross-cutting aspect. (Section 4OA3)

Cornerstone: Mitigating Systems

Green.

The inspectors identified an NCV of 10 CFR 50, Appendix B, Criterion V, lure to develop an adequate post Specifically, the corrective maintenance work performed on April 16, 2013, did not correct the cause of the failure and Exelon did not perform an adequate post maintenance test to verify conditions had been corrected. As a result, the emergency service water system was returned to service even though it did not meet all the requirements for operability. The issue was not identified and resolved until a subsequent surveillance test on April 17, 2013, which identified a failed breaker. Exelon entered this issue into their corrective action program (IR 2471069). Planned corrective actions include revising work order activities to specify the correct post maintenance test. This performance deficiency is more than minor because it is associated with the Equipment Performance attribute of the Mitigating Systems cornerstone, and adversely affected its objective to ensure the availability and reliability of the systems that respond failing to perform its function during the subsequent surveillance testing on April 17, 2013. Significance Determination Process (SDP) for Findings At-concluded that this finding did not represent an actual loss of function of the emergency service water system for greater than its technical specification allowed outage time (15 days). Therefore, the inspectors determined that this finding is of very low safety significance (Green). The inspectors determined that this finding had a cross-cutting aspect executing of work activities did not include documented instructions for performing an adequate post maintenance test. [H.5] (Section 4OA2)

Other Findings

Two violations of very low safety significance that were identified by Exelon were reviewed by the inspectors. Corrective actions taken or planned by Exelon have been entered into Exeare listed in Section 4OA7 of this report.

REPORT DETAILS

Summary of Plant Status Oyster Creek began the inspection period at 100 percent power. On March 22, 2015, an automatic reactor scram occurred due to high average power range monitor flux caused by an electronic pressure regulator failure. After repairs to the electronic pressure regulator, operators commenced plant startup on March 25, 2015, and returned to full power operation on March 28, 2015.

REACTOR SAFETY

Cornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity

1R01 Adverse Weather Protection

===.1 Readiness for Impending Adverse Weather Conditions

a. Inspection Scope

Weather Service for the period of January 26 27, 2015, and to the declaration of a cold weather alert by the grid operator on February 15 16, 2015. The inspectors verified that Exelon implemented its adverse weather procedures and that operators reviewed applicable emergency procedures and performed procedural briefs for the expected adverse weather conditions. The inspectors performed independent walkdowns of the site to verify the site was ready for the onset of adverse weather. Documents reviewed for each section of this inspection report are listed in the Attachment.

b. Findings

No findings were identified.

=

a. Inspection Scope

The inspectors performed partial walkdowns of the following systems: 2015 Containment spray system II while containment spray system I was out of service on January 20, 2015 Emergency diesel generator No. 2 while emergency diesel generator No. 1 was out of service on March 2, 2015 Reactor building closed cooling water system II while reactor building closed cooling water heat exchanger 1-1 was out of service on March 18, 2015 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 Updated Final Safety Analysis Report (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.

.2 Full System Walkdown

a. Inspection Scope

On February 9, 2015, the inspectors performed a complete system walkdown of accessible portions of the reactor building to torus vacuum breaker system to verify the existing equipment lineup was correct. The inspectors reviewed operating procedures, surveillance tests, drawings, equipment line-up check-off lists, and the UFSAR to verify the system was aligned to perform its required safety functions. The inspectors also reviewed electrical power availability; component lubrication and equipment cooling; hangar and support functionality; and operability of support systems. The inspectors performed field walkdowns of accessible portions of the systems to verify system components and support equipment were aligned correctly and operable. The inspectors examined the material condition of the components and observed operating parameters of equipment to verify that there were no deficiencies. Additionally, the inspectors reviewed a sample of related condition reports and work orders to ensure Exelon appropriately evaluated and resolved any deficiencies.

b. Findings

No findings were identified.

1R05 Fire Protection

.1 Resident Inspector 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.

New cable spreading room on January 20, 2015 Turbine lube oil storage area on January 20, 2015 Turbine operating floor on January 20, 2015 Motor-generator set room on March 11, 2015

b. Findings

No findings were identified.

1R07 Heat Sink Performance

.1 a.

- ---- ----------

- - - ---

b.

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 January 7, 2015, which included a seismic event with a loss of offsite power and failure of installed safety systems. 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 control room operator performance during a containment spray surveillance on February 20, 2015. The inspectors also observed control room operator performance during a scheduled downpower evolution to bring the D recirculation loop back in service following maintenance on February 27, 2015. The inspectors also observed control room operator performance during plant startup from forced outage 36 (1F36) on March 26, 2015. The inspectors observed infrequently performed test or evolution briefings, shift turnover briefings, alarm response, and operator control during performance of surveillance and post maintenance testing. Additionally, the inspectors observed operators to verify that procedure use, crew communications, and coordination of activities between work groups similarly met established expectations and standards.

b. Findings

No findings were identified.

1R12 Maintenance Effectiveness

a. Inspection Scope

The inspectors reviewed the samples listed below to assess the effectiveness of maintenance activities on structure, system or component 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 structure, system or component 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 a structure, system or component classified as (a)(1), the inspectors assessed the adequacy of goals and corrective actions to return the structure, system or component 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.

125 volt breaker maintenance on January 30, 2015 Reactor building to torus vacuum breakers on February 5, 2015 Drywell purge and vent valves on February 12, 2015 Hardened torus vent valve accumulators on February 19, 2015

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 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.

planned maintenance on January 5, 2015 Containment spray system I and emergency service water system I out of service for planned maintenance on January 20, 2015 Core spray system II out of service for planned maintenance on February 10, 2015 Emergency diesel generator No. 1 out of service for planned maintenance on March 2, 2015 Reactor building closed cooling water heat exchanger 1-1 out of service for planned maintenance on March 18, 2015

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: Reactor head flange area temperature monitor degraded on January 5, 2015 temperature on January 6, 2015 Hardened torus vent low accumulator pressure on February 12, 2015 pump motor lower bearing oil sample results on March 3, 2015 Emergency diesel generator No. 2 circulating lube oil pump degraded on March 12, 2015 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 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 Permanent Modifications

a. Inspection Scope

The inspectors reviewed the temporary modification listed below to determine whether the modification 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 Request 15-00064 Abandon Old Cable and Replace with New Cable for Turbine Acceleration Relay Pressure Switch (PSL-A) on February 7, 2015

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.

30 and V-14-31) and condensate return valve (V-14-34) preventive maintenance on January 6, 2015 -19-43) replacement on January 8, 2015 Containment spray system I following containment spray system I heat exchanger cleaning on January 23, 2015 Turbine acceleration relay pressure switch (PSL-A) following cable replacement on February 9, 2015 2015 Secondary containment following installation of trunnion room temporary modification on March 8, 2015 Electronic pressure regulator following electronic pressure regulator cable replacement on March 26, 2015

b. Findings

Introduction.

The inspectors identified a Green NCV of 10 CFR Part 50, Appendix B, quately evaluate test results to assure that test requirements had been satisfied. Specifically, Exelon did not perform the proper post maintenance test procedure to assure that the requirements of Technical Specification 4.5.G.3 were satisfied following installation of a temporary modification to secondary containment.

Description.

On September 16, 2014, Exelon installed a temporary modification to the trunnion room in accordance with work order R2211902. The purpose of the temporary modification was to move the secondary containment boundary from the trunnion room door to the temporary fittings on drain lines and ventilation ducts in the trunnion room. refueling outages to allow technicians to keep the trunnion room door open to run temporary services required for conducting maintenance. To ensure that the temporary modification maintains the integrity of the secondary containment boundary, Technical Specification 4.5.G.3 requires that testing be performed as stated: door open after the secondary containment boundary has been moved to the penetrations inside the trunnion room and the trunnion room is isolated from the secondary containment in support of outage activities, Standby Gas Treatment System testing shall be performed to demonstrate the capability to maintain a 1/4 inch of water vacuum under calm wind conditions with a Standby Gas Treatment System Filter train On September 18, 2014, Exelon personnel recorded the completion of the post maintenance test for the installation of the temporary modification completed under work order R2211902. R2211902, activity 7, specified performing Exelon procedure temporary modification was installed correctly and met the requirements of Technical Specification 4.5.G.3.

Also, scheduled for completion on September 18, 2014, was work order R2244647, -Minute Run System by testing the mechanical response of the system fans and valves. This test does not set conditions or record data to verify proper differential pressure or system flow rates as required by Technical Specification 4.5.G.3. The inspectors determined operators should have performed procedure 651.4.001, which would have satisfied Technical Specification 4.5.G.3.

The inspectors reviewed work orders, as well as the operations and the outage control center logs for September 18, 2014. The inspectors determined that Exelon only completed procedure 651.4.002, and that reactor building ventilation had not been secured on September 18, 2014, as required by Surveillance Procedure 651.4.001 (R2211902). The inspectors noted that documentation in work order R2211902 only indicated that the door to the trunnion room was opened while the standby gas treatment system was operating, and that reactor building differential pressure remained negative. Exelon did not record actual values for reactor building differential pressure and standby gas treatment system flow rate, which would have been used to satisfy the requirements of Technical Specification 4.5.G.3. Exelon entered the issue into their corrective action program as IR 2440643. Corrective actions include revising the process to perform the correct post maintenance test to ensure Technical Specification 4.5.G.3 is met.

Analysis.

The inspectors determined that not documenting and adequately evaluating test results to assure that test requirements have been satisfied in accordance with because it is associated with the configuration control (Standby Gas Trains) attribute of the Barrier Integrity Cornerstone and adversely affected the cornerstone objective of providing reasonable assurance that physical design barriers protect the public from radionuclide releases caused by accidents or events. Specifically, the post maintenance test conducted did not assure that the standby gas treatment system could have drawn 0.25 inch of water vacuum as required by Technical Specification 4.5.G.3.

of Operations Significance Determination Process: Phase 1 Initial Screening and ability to close or isolate secondary containment, the inspectors further assessed the safety significance (Green) because the decay heat values were low, given that the unit had been shut down for approximately 3 days, and reactor water level was greater than that required for movement of irradiated fuel assemblies within the reactor pressure vessel. This finding has a cross-cutting aspect in the area of Human Performance, Procedure Adherence because Exelon personnel did not perform the post maintenance test specified by the work order. [H.8]

Enforcement.

10 CFR Part 50, Appendix B, Criterthat test results shall be documented and evaluated to assure that test requirements have been satisfied. Contrary to the above, on September 18, 2014, Exelon did not adequately document and evaluate the results of the post maintenance test data for the temporary modification in the trunnion room to assure that the test requirements satisfied Technical Specification requirement 4.5.G.3. Specifically, Exelon did not perform the required post maintenance test specified by the work order for installation of a temporary modification to the secondary containment and the post maintenance test that was performed did not demonstrate that the test results met the requirements of Technical Specification 4.5.G.3. Because this issue is of very low safety significance (Green) and Exelon entered this issue into their corrective action program as IR 2440643, this finding is being treated as an NCV consistent with Section 2.3.2 of the NRC Enforcement Policy. (NCV 05000219/2015001-01, Post Maintenance Test Results were not Evaluated to Assure that Technical Specifications Requirements were Satisfied)

1R20 Refueling and Other Outage Activities

a. Inspection Scope

dule and outage risk plan for Oyster Creek forced outage (1F36), which was conducted March 22 through March 27, 2015. schedules to verify that risk, industry experience, previous site-specific problems, and defense-in-depth were considered. 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 Installation and configuration of reactor coolant pressure, level, and temperature instruments to provide accurate indication and instrument error accounting Status and configuration of electrical systems and switchyard activities to ensure that technical specifications were met Monitoring of decay heat removal operations Impact of outage work on the ability of the operators to operate the spent fuel pool cooling system 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 Fatigue management 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 structures, systems, and components 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: -service test on January 6, 2015 Emergency diesel generator No. 1 battery surveillance test on January 12, 2015 Emergency diesel generator No. 2 load test on January 29, 2015 Transverse in core probe ball valve primary containment isolation valve test on February 3, 2015 Reactor building to torus vacuum breaker test on February 18, 2015 Diesel driven fire pump No. 2 operability test on February 26, 2015 Emergency diesel generator No. 1 load test on March 2, 2015 Main steam isolation valve closure tests on March 24, 2015

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

Exelon implemented various changes to the Oyster Creek Emergency Action Levels (EALs), Emergency Plan, and implementing procedures. Exelon had determined that, in accordance with 10 CFR 50.54(q)(3), any change made to the EALs, Emergency Plan, and its lower-tier implementing procedures, had not resulted in any reduction in effectiveness of the Plan, and that the revised Plan continued to meet the standards in 10 CFR 50.47(b) and the requirements of 10 CFR 50 Appendix E.

The inspectors performed an in-office review of all EAL and Emergency Plan changes submitted by Exelon as required by 10 CFR 50.54(q)(5), including the changes to lower-tier emergency plan implementing procedures, to evaluate for any potential reductions in effectiveness of the Emergency Plan. This review by the inspectors was not documented in an NRC 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 requirements in 10 CFR 50.54(q) were used as reference criteria.

b. Findings

No findings were identified.

1EP6 Drill Evaluation

.1 Training Observations

a. Inspection Scope

The inspectors observed a simulator training evolution for licensed operators on January 7, 2015, which required emergency plan implementation by an operations crew. Exelon planned for this evolution to be evaluated and included in performance indicator data regarding drill and exercise performance. The inspectors observed event classification and notification activities performed by the crew. The inspectors also attended the post-activities was to note any weaknesses and deficieand ensure that Exelon evaluators noted the same issues and entered them into the corrective action program.

b. Findings

No findings were identified.

During the period January 26 performance in assessing and controlling radiological hazards in the workplace. The review was against criteria contained in 10 CFR Part 20, technical specifications, applicable Regulatory Guides, and Exelon procedures.

a. Inspection Scope

Inspection Planning

The inspector reviewed 2013 and 2014 performance indicators for the occupational radiation safety cornerstone, radiation protection program audits, and reports of operational occurrences in occupational radiation safety since the last inspection. Radiological Hazard Assessment The inspector conducted this inspection and reviewed the following hazard assessment aspects and associated documentation: reviewed changes in radiological hazards for onsite workers or members of the public and potential impact of the changes; and conducted walk-downs and made independent radiation measurements and reviewed survey documentation to determine thoroughness and frequency of the surveys. Instructions to Workers The inspector conducted inspection and reviewed available occurrences where a and workers response. Contamination and Radioactive Material Control The inspector conducted inspection and reviewed the recent transactions involving nationally tracked category 2 radioactive sources.

Radiological Hazards Control and Work Coverage The inspector evaluated that radiation dosimeters were worn in location of maximum dose and for areas with significant dose gradients verified that multi-badging and effective dose equivalents are being measured properly.

b. Findings

No findings were identified.

4OA2 Problem Identification and Resolution

.1 Routine Review of Problem Identification and Resolution Activities

a. Inspection Scope

the inspectors routinely reviewed issues during baseline inspection activities and plant status reviews to verify that Exelon entered issues into the corrective action program at an appropriate threshold, gave adequate attention to timely corrective actions, and identified and addressed adverse trends. In order to assist with the identification of repetitive equipment failures and specific human performance issues for follow-up, the inspectors performed a daily screening of items entered into the corrective action program and periodically attended condition report screening meetings.

b. Findings

No findings were identified.

.2 Failures

a. Inspection Scope

The inspectors performed an in-evaluations and corrective actions associated with IR 1511787 and IR 1614019, regarding the failure of the emergency service water pump breakers to close. IR 1511787 documented the Spray/Emergency Service Water Operability and In- service water pump breaker failure to close immediate corrective actions included initiating work orders to troubleshoot the issues and understand the cause of the failures.

actions to determine whether Exelon was appropriately identifying, characterizing, and correcting problems associated with these issues and whether the planned or completed corrective actions were appropriate. The inspectors compared the actions taken to the x B. In addition, the inspectors reviewed documentation associated with this issue, interviewed engineering and maintenance personnel, and performed a visual inspection of the breaker.

b. Findings

Introduction.

The inspectors identified a Green NCV of 10 CFR 50, Appendix B, emergency service water pump breaker.

Description.

On April 15, 2013, the experienced mechanical binding while the breaker was being racked out in support of a tagging clearance for work on emergency service water system. IR 1502012 was written, which documented that the breaker closing spring did not discharge as it was being racked out of the cubicle, as expected. It was noted that the breaker trip latch crank pin was slightly bent and the breaker spring discharge linkage assembly appeared to be bound. The breaker was subsequently repaired under a corrective maintenance work order (C2020132). Exelon performed post maintenance testing on April 16, 2013, by starting and stopping the pump from the control room. The post maintenance testing did not include inspection of the breaker by racking it in and out to verify that the closing coil would properly de-energize. On April 17, 2013, during performance of the monthly in-service test surveillance and emergency service water system pump operability test, the control room operator atte service water pump breaker did not close on demand. IR1503270 was written, which documented that the breaker closing spring was found in a discharge state. Further visual inspection identified that the breaker was mechanically bound and the pivot arm was raised such that the breaker could not be removed from the switchgear cubicle. The failed breaker was replaced with a spare, and sent for forensic analysis. Exelon performed an equipment apparent cause evaluation for the April 17, 2013 failure, after receiving the results from the forensic analysis. The analysis revealed that: 1. The breaker spring discharge linkage assembly was binding 2. The discharge crank pin was deformed, and 3. The anti-pump relay coil was found to be fully degraded as the coil was burned up and the relay would not function As a result, the inspectors identified that Exelon did not correct the failure that occurred ance testing for the corrective maintenance work order was inadequate because it did not verify whether the breaker would experience further mechanical binding during its functional operations. The purpose of a post maintenance test is to provide assurance that a component and its associated subsystems are functional after completion of maintenance. The level of post maintenance testing performed should be appropriate for the scope of maintenance work performed. The post maintenance test performed for the corrective maintenance work order on April 16, 2013, only cycled the breaker and did not verify whether the breaker spring discharge linkage assembly was binding. The binding did not allow the closing coil to properly charge. It also appears from the forensic analysis that the anti-pump relay coil failed when the breaker closing spring charging motor failed to charge the closing spring following the breaker operation. This placed the emergency service water pump in an inoperable condition. The inspectors determined that the breaker failure on April 17, 2013, could have been prevented if adequate post-maintenance testing had been performed following the corrective maintenance activities. Though Exelon identified the failure as a result of subsequent surveillance testing on April 17, 2013, the inspectors considered this finding to be NRC-equipment apparent cause evaluation did not address these organizational or human performance weaknesses in the cause evaluation.

The inspectors determined that prior to the failure on April 15, 2013, the breaker would have performed its safety function because on April 15, the breaker was found with the closing spring in a fully charged state. In this condition, the closing spring would have been able to close the breaker on demand. Exelon entered the issue into their corrective action program as IR 2471069. Planned corrective actions include revising work order activities to specify the correct post maintenance test.

Analysismaintenance test for the emergency service water pump in accordance with 10 CFR 50, Appeability to foresee and prevent. The performance deficiency is more than minor because it is associated with the Equipment Performance attribute of the Mitigating Systems Cornerstone and adversely affected its objective to ensure the availability and reliability of systems that respond to initiating events. Specifically, the inadequate post led to the emergency service water pump failing to perform its function during subsequent surveillance testing on April 17, 2013. The inspectors assessed this finding (SDP) for Findings At-finding does not represent an actual loss of function of the emergency service water system for greater than its technical specification allowed outage time (15 days). Therefore, the finding is of very low safety significance (Green). This finding has a cross-cutting aspect in the area of Human Performance, Work include documented instructions for performing an adequate post maintenance test [H.5].

Enforcement.

10 CFR 50, Appendix B, Criterion documented instructions, procedures, or drawings, of a type appropriate to the circumstances and shall be accomplished in accordance with these instructions, procedures, or drawings. Contrary to above, on April 16, 2013, following corrective er pump breaker, Exelon failed to prescribe appropriate documented instructions and proper acceptance criteria for performing an adequate post-water pump failed to start on April 17, 2013, which appeared to be caused by the same defective breaker mechanism that the corrective maintenance was intended to repair. Because this violation was of very low safety-significance and was entered into 2471069, this violation is being treated as an NCV, consistent with Section 2.3.2 of the NRC Enforcement Policy. (NCV 05000219/2015001-02, Inadequate Post-Maintenance Testing for Emergency Service Water Pump Breaker) c. Observations The inspectors concluded that Exelon took appropriate actions to identify the cause of the breaker failures on April 17, 2013, and January 29, 2014. The inspectors concluded that each breaker failure was not a common issue. However, the inspectors did determine that the April 17, 2013 breaker failure was caused by inadequate corrective maintenance and post maintenance testing performed on April 16, 2013. For the breaker failure on April 27, 2013, Exelon determined the apparent cause to be misalignment of the breaker to the switchgear cubicequipment apparent cause evaluation, the breaker spring discharge crank pin mechanically interfered with the spring discharge cam that is mounted in the switchgear cubicle. This interfering condition was sufficient to reposition the adjusting clevis and spring release crank. This condition degraded the spring release interlocking design feature, which is provided to discharge the closing and opening springs when the breaker is inserted into or withdrawn from the metal-clad switchgear. As stated in the report, this condition would not allow the spring discharge crank to move. Exelon determined that this may have prevented the breaker closing spring from recharging after the breaker was operated. Exelon promptly replaced the failed breaker and updated preventive maintenance procedure, 2400-SME-3915.03, to include steps to check alignment of the spring discharge cam and the spring discharge crank. Exelon also performed an extent of condition review and determined that there were no other breakers that were experiencing a similar issue. The inspectors determined that the failure was related to inadequate corrective maintenance performed on April 16, 2013, and an inadequate post maintenance test as discussed in Section 4OA2.2b. For the breaker failure on January 29, 2014, Exelon performed an equipment apparent cause evaluation and determined the apparent cause of this failure was degradation of the 52HH switch from wear and dirty contacts. The 52HH switch is a SBM-type switch that is mounted inside the switchgear cubicle. The switch is actuated by the breaker elevator when the breaker is in the fully raised position. When the breaker is fully raised up, the switch contacts are closed, which provides a permissive to close the breaker from the control room or locally at the breaker. Exelon determined that the 52HH switch degradation could have been identified if steps were added to the preventive maintenance procedure 2400-SME-3915.03. Exelon took prompt corrective action to replace the switch. In addition, Exelon completed an extent of condition review and created corrective actions to perform continuity checks on 52HH switch in other similar breakers. The inspectors determined that adding steps to the preventive maintenance procedure was an enhancement. se to breaker failure issues was commensurate with safety significance, and the actions taken and planned were reasonable to restore the nonconforming conditions.

.3 Annual Sample:

No. 2 Emergency Diesel Generator Cylinder No. 15 Degraded Piston Wrist Pin Bearing

a. Inspection Scope

The inspectors performed an in-actions associated with the emergency diesel generator No. 2 degraded piston wrist pin bearing. Specifically, during the performance of a 24-month preventive maintenance lubricating oil system inspection on emergency diesel generator No. 2 on October 21, 2013, foreign material in the form of silver metal shavings was found in the main lubricating oil filter housing. Subsequent inspection activities revealed silver metal shavings in the engine sump below cylinder No. 15 and indications of a degraded wrist pin bearing, which necessitated replacement of the power pack assembly. Exelon entered the issue into the corrective action program as IR prompt investigation and performed an equipment apparent cause evaluation and mitigating system performance indicator failure determination evaluation to address the degraded conditions and past operability of emergency diesel generator No. 2. cause analyses and evaluations; extent of condition reviews; and the prioritization and timeliness of actions to evaluate whether Exelon was appropriately identifying, characterizing, and correcting problems associated with this issue and whether the planned or completed corrective actions were appropriate and met the requirements of their corrective action process. The inspectors reviewed the applicable condition reports and associated documents, work orders, maintenance procedures, engine log readings, and as-actions to address other possible or contributing causes. The inspectors compared the actions taken to the Additionally, the inspectors interviewed engineering and maintenance personnel to assess the effectiveness of the implemented corrective actions and performed field walkdowns to assess the material condition of the emergency diesel generator No. 2. b. Observations Oyster Creek is equipped with two identical General Motors Corporation, Electromotive Division Model EMD 20-645E4, 20 cylinder, emergency diesel generator units. The function of these emergency diesel generators is to provide safety-related alternating current power to the class 1E busses upon a loss of off-site power while the reactor is critical, including during post-accident conditions. Upon demand, the emergency diesel generator must be able to start, achieve rated speed and voltage, and provide power to the Class 1E busses within 10 seconds. Further, the emergency diesel generator must be able to sustain power production for a minimum of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

The emergency diesel generators were modified in 1986 to include prelubricating/ prewarm oil systems which operate continuously to maintain the diesels in a standby condition to reduce engine wear during fast starts. The prelubricating/prewarm system provides direct lubrication to the crankshaft surfaces and turbocharger bearings during standby conditions, but does not provide direct application to the wristpin bearings. However, the time to initiation of wristpin lubrication has been minimized by maintaining the lubricating oil headers full via the prelubricating system. Additionally, procedural enhancements were instituted to reduce the number of fast starts on the emergency diesel generators during testing to enhance bearing and other component life. The inspectors concluded that Exelon staff generally conducted a thorough and appropriate technical review as documented in their equipment apparent cause evaluation and corrective action reports. Past operability of emergency diesel generator No. 2 was addressed in the mitigating system performance indicator failure determination evaluation. The inspectors noted that the mitigating system performance indicator evaluation included detailed discussions on operability of the emergency diesel generator with the degraded bearing. The inspectors determined that the maintenance metal flakes were commensurate with their programs and procedures as well as vendor and Electromotive Division oinspectors further noted that Exelon used relevant operating experience in their response to the issue and determination regarding operability. Exelon was not able to identify a specific factor that led to the wrist pin bearing failure. However, Exelon noted that operating history and industry experience suggested that the most likely cause of the bearing damage involved the wrist pin bearing and lubrication delivery system coupled with a combination of factors including multiple starts and excessive high or low cause for this occurrence could be found was reasonable.

Additionally, the inspectors determined that Exelon staff appropriately identified latent organizational weaknesses as contributors to the event. Lubricating oil analysis is a major indicator of machinery degradation; however, the vendor contracted by Exelon to perform the oil analysis did not possess the capability of measuring silver content to the 0.1 parts per million (ppm) tolerance required. Silver is a layered element within the diesel engine piston wrist pin bearings and as the wrist pin bearing degrades, the silver content in the lubricating oil system increases. Exelon further identified that engineering staff failed to review analysis results in a timely manner and did not take the required actions following receipt of ten oil analysis reports indicating silver content exceeding the procedural guidance as described in maintenance procedure MA-AA-716-230-1001, These issues have been entered into 1575045. This performance deficiency and violation of regulatory requirements is dispositioned in Section

4OA7 of this report.

The failure to identify the high out-of-specification silver content readings at 1.0 ppm in the lubricating oil results occurred on ten occasions over thirteen months between samples taken from two separate emergency diesel generator No. 2 locations. 1.0 ppm of silver should have triggered additional actions for levels above 0.3 and 0.7 ppm per the procedure including, but not limited to: resampling immediately to verify abnormal results; performing confirmatory testing using more accurate methods if required; reviewing all vibration and thermography data immediately for adverse trends; and contacting the equipment manufacturer for additional assistance. The inspectors noted that the original vendor had retained an oil sample taken before the October 21, 2013 two year overhaul. This sample was sent to a new vendor who possessed the required analysis accuracy and resulted in an actual silver content of 0.5 ppm.

additional observations regarding corrective actions. First, while Exelon considered other emergency diesel generator results relative to required action levels, Exelon did not look further to other components to see if the same extent-of-cause issue existed in other safety-related systems. For instance, various safety-related closed loop cooling systems at the station have routine analyses to verify that the vendor was performing the tests to the required accuracy. Second, from a procedural point of view, the only individual required to review emergency diesel generator oil analysis results was an engineer in the Component Maintenance Optimization group. The inspectors observed that no second check or peer check was procedurally in-place to minimize any delays in identifying out-of-action process as IR 2486351. Regarding operability of the 2B emergency diesel generator with a silver content of 0.5 ppm in the lubricating oil, the inspectors reviewed operating experience with the same make and model emergency diesel generator in other nuclear applications. The inspectors found two instances where other emergency diesel generators were able to perform the intended safety function with elevated silver contents at 2.0 and 1.3 ppm emergency diesel generator cylinder No. 15 removed wrist pin bearing demonstrated that although the bearing had been degraded, some material remained in place which was capable of carrying the applied loads. Furthermore, pressure/volume combustion chamber diagnostics from 2011 and 2013, as well as engine log reviews, revealed no issues that would impact the ability to perform the intended safety function. commensurate with the safety significance, was timely, and generally included appropriate follow-up actions.

.4 Annual Sample:

Sand Bed Water Intrusion a.

--

b.

---

4OA3 Follow-Up of Events and Notices of Enforcement Discretion

.1 Plant Events

a. Inspection Scope

For the plant events listed below, the inspectors reviewed and/or observed plant parameters, reviewed personnel performance, and evaluated performance of mitigating systems. The inspectors communicated the plant events to appropriate regional personnel, and compared the event details with criteria activities. As applicable, the inspectors verified that Exelon made appropriate emergency classification assessments and properly reported the event in accordance -up actions related to the events to assure that Exelon implemented appropriate corrective actions commensurate with their safety significance.

Augmented offgas isolation due to deflagration on March 4, 2015 Reactor scram caused by electronic pressure regulator failure on March 22, 2015

b. Findings

No findings were identified.

.2 (Closed) Exelon LER 05000219/2014-005-00:

Secondary Containment Declared Inoperable On September 19, 2014, during refueling outage 1R25 with the unit in cold shutdown, a technician discovered that a previously authorized and installed temporary modification had been removed from a penetration in the outboard main steam isolation valve room (trunnion room). The purpose of the temporary modification is to isolate the penetration from the reactor building to the trunnion room to allow the reactor building trunnion room door to be maintained open during refueling outages. Per Technical Specifications 3.5.B and 4.5.G, in order to maintain secondary containment integrity with the trunnion room door open, four penetrations connecting the trunnion room to the reactor building must be sealed. The trunnion room door was open when the plug was found removed from a six inch equipment drain hub. The plug was immediately reinstalled, restoring the safety function of the secondary containment. Exelon performed an engineering analysis, which determined that the secondary containment system was capable of performing its safety function with the plug removed.

The apparent cause of the event was determined to be inadequate signage on the trunnion room door, with a contributing cause that the individual who removed the temporary modification to use the equipment drain hub did not understand the importance of the temporary modification. Exelon has revised the temporary modification to require signage not only on the trunnion room door, but to all the plugs installed as part of the temporary modification.

The inspectors determined that the technical specification violation was minor because it was not a precursor to a significant event; did not have the potential to lead to a more significant safety concern; did not relate to a performance indicator that would have exceeded a threshold; and did not adversely affect any of the cornerstone objectives. The inspectors identified other issues concerning the adequacy of the post-maintenance test utilized after the initial temporary modification installation (see Section 1R19); a concurrent loss of secondary containment safety function (see Section 4OA7); and the completeness of the LER and emergency notification system report (see below). This LER is closed. Findings

Introduction.

The inspectors identified a Severity Level IV NCV of 10 CFR 50.9(a) in that Exelon did not provide complete information in reports submitted per 10 CFR 50.72 and 10 CFR 50.73. Specifically, an LER submitted on November 18, 2014, did not discuss a separate, partially-opened secondary containment door that was discovered during the same time frame, which could have prevented the fulfillment of the safety function of secondary containment, and therefore was required to be discussed in the original LER.

Description.

At approximately 2200 on September 19, 2014, while the reactor was in cold shutdown for the 1R25 refueling outage, an Oyster Creek technician discovered that a previously installed temporary modification was removed from a penetration that was required to maintain secondary containment in the trunnion room. The purpose of the temporary modification is to isolate the penetration opening from the reactor building and allow the trunnion room door to be maintained open during refueling outages. Technical Specification 3.5 allows this temporary modification to serve as a secondary containment boundary while work activities are occurring in the trunnion room. The technician immediately reinstalled the temporary modification and entered the issue into the corrective action program as IR 2383820.

At approximately 0630 on September 20, 2014, the shift manager reviewed the IR report, declared secondary containment inoperable and made an 8-hour report (ENS 50476) per 10 CFR 50.72(b)(3), which described the partially-removed temporary modification. The shift manager then set plant conditions to show that secondary containment was operable following reinstallation of the temporary modification. However, the standby gas treatment system could only achieve a differential pressure of negative 0.20 inches of water, which did not meet the Technical Specification 4.5.G.3 criterion of negative 0.25 inches of water. The shift manager entered this issue into the corrective action program as IR 2383852 and commenced troubleshooting efforts to determine why the technical specification could not be met. The troubleshooting efforts identified that a personnel access door embedded in the railroad airlock outer door was not fully closed, and allowed enough air to leak into secondary containment to prevent achieving a negative 0.25 inches of water differential pressure. Technicians shut the personnel access door and secondary containment differential pressure returned to the value required by technical specifications.

Oyster Creek submitted LER 2014-005-modification and concluded that the safety function of secondary containment was not lost as the cross sectional area of the penetration was bounded by a design calculation that showed it was not large enough to prevent the standby gas treatment system from drawing negative 0.25 inches of water differential pressure.

The inspectors reviewed the LER and ENS and determined that neither report documented the inability of the standby gas treatment system to achieve the technical specification surveillance requirement on September 20, and did not document the discovery of the partially opened personnel access door. Exelon entered the issue into their corrective action program as IR 2440641. Planned corrective actions include revising the original LER to add a discussion of the partially opened secondary containment door.

Analysis.

The inspectors determined that not providing a complete report in accordance ability to foresee and correct and should have been prevented. Specifically, Exelon did not describe the effectiveness of response measures taken and major occurrences during the event, including all component or system failures that contributed to the event. oversight function, the inspectors evaluated this performance deficiency in accordance with the traditional enforcement process. The inspectors documented findings related to this event in Section 1R19 and section

4OA7 of this report, which were determined to be of very low safety significance.

In accordance with Section 2.2.2.d of the NRC Enforcement Policy, the inspectors determined that the performance deficiency identified with the reporting aspect of the event is a Severity Level IV violation, because it is of more than minor concern, with relatively inappreciable potential safety significance and is related to findings that were determined to be more than minor issues. In accordance with IMC 0612, Appendix B, this issue is not assigned a cross-cutting aspect.

Enforcement.

applicant for a license or by a licensee or information required by statute or by the or the licen the above, on November 18, 2014, information provided by Exelon in accordance with 10 CFR 50.72 and 10 CFR 50.73 was not complete in all material aspects because Exelon did not describe the effectiveness of response measures taken and all component or system failures that contributed to the event. The inspectors determined that submission of incomplete reports required by 10 CFR 50.72 and 10 CRF 50.73 is characterized as a Severity Level lV violation. However, because the violation was of (IR 2440641), this violation is being treated as an NCV consistent with Section 2.3.2 of the Enforcement Policy, (NCV 05000219/2015001-03, Incomplete 50.72 and 50.73 Reports Associated with Secondary Containment Integrity)

4OA6 Meetings, Including Exit

On April 17, 2015, the inspectors presented the inspection results to Garey Stathes, Site Vice President, and other members of the Exelon staff. The inspectors verified that no proprietary information was retained by the inspectors or documented in this report.

4OA7 Licensee-Identified Violations

The following violations of very low safety significance (Green) were identified by Exelon and were a violation of NRC requirements which meets the criteria of the NRC Enforcement Policy for being dispositioned as an NCV.

secondary containment integrity be maintained at all times when the reactor vessel head and the drywell head are in not in place. Technical Specification 1.14, system is operable. Technical Specification 4.5.G.3 specifies that with the trunnion room door open and the trunnion room is isolated from secondary containment in support of outage activities, testing of the standby gas treatment system to be performed to demonstrate the capability to maintain 1/4 inch of water vacuum under calm wind conditions and a standby gas treatment system filter train flow rate of not more than 4000 cfm. Contrary to Technical Specification 3.5.B, on September 20, 2014, with the reactor vessel head and drywell head removed for the refueling outage, Exelon determined that they did not have secondary containment integrity when performing testing to demonstrate standby gas treatment system capability in accordance with Technical Specification 4.5.G.3 and subsequently found that the outer railroad air lock personnel access hatch had not been closed properly, which prevented a proper vacuum from being achieved. Exelon entered this issue into the corrective action program as IR 2383852. Using guidance in IMC 0609, Appendices G and H, the inspectors determined that this finding was of very low safety significance (Green) because the decay heat values were low and the reactor water level inventory was above that required to move irradiated fuel.

Technical Specificatiimplemented, and maintained covering surveillance and test activities of equipment Contrary to the above, from August 2012 through September 2013, Exelon took no action following receipt of ten lubricating oil analysis report results taken from two emergency diesel generator No. 2 sample locations which indicated silver content at 1.0 ppm, which exceeded procedural action levels. Specifically, Exelon maintenance procedure MA-AA-716-230-governs safety system oil analyses and describes actions to be taken when equipment wear metals exceed specific thresholds, as obtained through monthly oil analysis. Section 3 of procedure MA-AA-716-230-1001 lists potential actions to be taken when oil analysis results indicate silver content above 0.3 and 0.7 ppm respectively. These actions include resampling immediately to verify abnormal results, performing confirmatory testing using more accurate methods if required, reviewing all vibration and thermography data immediately for adverse trends, and contacting the equipment manufacturer for additional assistance. Exelon identified this issue on October 21, 2013, during the performance of a 24-month lubricating oil system inspection on the emergency diesel generator No. 2 when silver metal shavings were found in the main lubricating oil filter housing and in the sump below cylinder #15. The inspectors determined that the failure to identify an out-of-specification lubricating oil sample result on numerous occasions was a performance determined that the issue adversely impacted the reliability of the safety-related emergency diesel generator in that the wrist pin bearing was degraded and had partially failed. The inspectors determined that the issue was of very low safety significance (Green) because it did not: affect design or qualification; represent a loss of system or function; exceed technical speciation allowed outage times; and involve external events. Exelon entered this issue into the corrective action program as IR 1575045.

ATTACHMENT:

SUPPLEMENTARY INFORMATION

KEY POINTS OF CONTACT

Exelon Personnel

G. Stathes, Site Vice-President

J. Dostal, Plant Manager

P. Bloss, Senior Manager, Plant Engineering

M. Chanda, Emergency Preparedness Manager

D. DiCello, Director, Work Management

D. Chernoky, Director, Maintenance

T. Farenga, Radiation Protection Manager

M. Ford, Director, Operations

T. Keenan, Manager, Site Security

G. Malone, Director, Engineering

M. McKenna, Manager, Regulatory Assurance

J. Parker, CMO Rotating Equipment

H. Ray, Senior Manager, Design Engineering

J. Renda, Manager, Environmental/Chemistry

C. Ricketts, Electrical Systems Manager

H. Tritt, Electrical Design and Systems Manager

E. Swain, Shift Operations Superintendent

C. Symonds, Director, Training

LIST OF ITEMS OPENED, CLOSED, DISCUSSED, AND UPDATED

Opened/Closed

05000219/2015001-01 NCV Post Maintenance Test Results Were Not Evaluated to Assure that Technical Specifications Requirements Were Satisfied (Section 1R19)

05000219/2015001-02 NCV Inadequate Post Maintenance Testing for Emergency Service Water Pump Breaker (Section 4OA2)

05000219/2015001-03 NCV Incomplete 50.72 and 50.73 Reports Associated with Secondary Containment Integrity (Section 4OA3)

Attachment

Closed

05000219/LER-2014-005-00 LER Secondary Containment Declared Inoperable (Section 4OA3)

Section 1R01: Adverse Weather Protection

Procedures

ABN-31, High Winds, Revision 19

ABN-32, Abnormal Intake Level, Revision 24

ABN-60, Grid Emergency, Revision 15

OP-AA-108-111-1001, Severe Weather and Natural Disaster Guidelines, Revision 12

OP-OC-108-109-1001, Severe Weather Preparation T&RM for Oyster Creek, Revision 30

OP-OC-108-109-1002, Cold Weather Freeze Inspections, Revision 4

RAP-K7e, Environ Water Mon, Revision 7

Drawings

3E-168-02-001, General Arrangement Intake Structure Plan and Sections, Revision 10

Condition Reports

2452526

2452534

2452890

2452956

2452957

2452969

2453101

2453131

2453147

2453176

2453177

Miscellaneous

Oyster Creek Nuclear Generating Station Operating Logs dated February 15

16, 2015 Oyster Creek Nuclear Generating Station Updated Final Safety Analysis Report, Section 10.4.5, Circulating Water System, Revision 18 Intake Level Recorder Data for February 15

16, 2015

EP-AA-1010 Addendum 3, Emergency Action Levels for Oyster Creek Station, Revision 0

Section 1R04: Equipment Alignment

Procedures

307, Isolation Condenser System, Revision 124

309.2, Reactor Building Closed Cooling Water System, Revision 93 310, Containment Spray System Operation, Revision 109 341, Emergency Diesel Generator Operation, Revision 108 604.3.001, Reactor Building to Torus Power Vacuum Breaker Test and Calibration, Revision 42 604.4.003, Reactor Building to Suppression Chamber Self Actuating Vacuum Breaker Surveillance Test and IST, Revision 22 604.4.015, Reactor Building to Torus Power Vacuum Breaker Check, Revision 20

OP-AA-108-117, Protected Equipment Program, Revision 4

RAP-C8e, RB/Torus Vac Brkr Opn, Revision 2

Attachment Calculations

C-1302-852-5360-003, Accumulator Sizing for V-27-1, 2, 3 and 4, Revision 1

C-1302-852-5360-008, Development of Accum Leakage Criteria, Revision 0A

C-1302-852-E310-018, Verification of AOV Accumulator Pressure Drop Criteria, Revision 0

C-1302-852-5322-014, Support Calc for Air Trip Valve V-26-16 & V-26-18, Revision 0

C-1302-622-5350-017, RB to Torus Vacuum Breaker Differential Pressure Switch Errors (DPS-0066A & B), Revision 4

C-1302-243-5310-B. To Suppression Chamber Vacuum Breaker

Verification of Test Procedure # 604.4.003, Revision 0

Drawings

BR 2005, Emergency Service Water System Flow Diagram, Revision 86 3E-243-21-1000, Drywell and Torus Vacuum Relief System, Revision 29

BR 2006 Sh.1, Reactor Building Closed Cooling Water System, Revision 79

Condition Reports

1636994

1644268

1645130

1650157

1662626

1666133

1689797

2060026

1692258

2387208

2390816

2471026

Maintenance Orders/Work Orders R2210607

Miscellaneous

SP-1302-12-307, Specification for Drywell Vent & Purge Valves, Revision 1

Section 1R05: Fire Protection

Procedures

OP-OC-201-008, Oyster Creek Pre-Fire Plans, Revision 18

OP-OC-201-012-1001, On-Line Fire Risk Management, Revision 2

OP-AA-201-012-1001, Operations On-Line Fire Risk Management, Revision 1

OP-AA-108-117, Protected Equipment Program, Revision 4

WC-AA-101-1006, On-Line Risk Management and Assessment, Revision 1

ER-AA-600-1069, High Risk Fire Area Identification, Revision 1

OP-OC-201-008-1019, New Cable Spreading Room, Revision 1

OP-OC-201-008-1031, Turbine Lube Oil Storage, Pumping Elevation, Revision 4

OP-OC-201-008-

OP-OC-201-008-1014, MG Set Room, Revision 0

OP-OC-201-008-oom, Revision 2

OP-OC-201-008-

Condition Reports

2439468

2443477 2441075

Section 1R07: Heat Sink Performance

-

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

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

Section 1R11: Licensed Operator Requalification Program

Miscellaneous

NF-AB-720-F-1, Control Rod Sequence Review and Approval Sheet

Section 1R12: Maintenance Effectiveness

Procedures

2400-SME-3915.01, Motor Control Center Preventive Maintenance, Revision 19 310, Containment Spray System Operation, Revision 109 604.3.001, Reactor Building to Torus Power Vacuum Breaker Test and Calibration, Revision 42 604.4.003, Reactor Building to Suppression Chamber Self Actuating Vacuum Breaker Surveillance Test and IST, Revision 22 604.4.015, Reactor Building to Torus Power Vacuum Breaker Check, Revision 20

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

ER-AA-310-1004, Maintenance Rule

Performance Monitoring, Revision 12

PI-AA-120, Issue Identification and Screening Process, Revision 1

PI-AA-125, Corrective Action Program (CAP) Procedure, Revision 0

RAP-C8e, RB/Torus Vac Brkr Opn, Revision 2

Calculations

C-1302-852-5360-003, Accumulator Sizing for V-27-1, 2, 3 and 4, Revision 1

C-1302-852-5360-008, Development of Accum Leakage Criteria, Revision 0A

C-1302-852-E310-018, Verification of AOV Accumulator Pressure Drop Criteria, Revision 0

C-1302-852-5322-014, Support Calc for Air Trip Valve V-26-16 & V-26-18, Revision 0

C-1302-622-5350-017, RB to Torus Vacuum Breaker Differential Pressure Switch Errors (DPS-0066A & B), Revision 4

C-1302-243-5310- Verification of Test Procedure # 604.4.003, Revision 0

Condition Reports

2442341

2437096

2438727

2433545

Attachment

Drawings

3E-243-21-1000, Drywell and Torus Vacuum Relief System, Revision 29

Maintenance Orders/Work Orders R2119318 C2007322

Section 1R13: Maintenance Risk Assessments and Emergent Work Control

Procedures

304, Standby Liquid Control, Revision 48

307, Isolation Condenser System, Revision 124 308, Emergency Core Cooling, Revision 95 310, Containment Spray System, Revision 109 341, Emergency Diesel Generator Operation, Revision 108

ER-AA-600-1042, Online Risk Management, Revision 9

OP-AA-108-117, Protected Equipment Program, Revision 4

WC-AA-101, On-Line Work Control Process, Revision 24

WC-OC-101-1001, Online Risk Management and Assessment, Revision 18

Miscellaneous

Oyster Creek Morning Report for March 18, 2014 Oyster Creek Paragon Results for March 18, 2014

Section 1R15: Operability Determinations and Functionality Assessments

Procedures

681.4.004, Technical Specification Log Sheet, Revision 30

EMG-SP26, Support Procedure 26 Determining Bulk Drywell Temperatures, Revision 1

OP-AA-108-115, Operability Determinations, Revision 15

OP-AA-108-115-1002, Supplemental Consideration for On-Shift Immediate Operability Determinations, Revision 3

MA-AA-716-230-1001, Oil Analysis Interpretation Guideline, Revision 17

Condition Reports

2424160

2425255

1649198

2394230

2432809

2433545

2461906

1564416

1564417

1492013

0799753

2467827

2443995

1667842

2465654

Maintenance Orders/Work Orders A2019430 R2200889

Drawings

3E-861-21-1002, Emergency Diesel Generator Lube Oil System, Sheet 1, Revision 12

Miscellaneous

Oyster Creek Nuclear Generating Station Technical Specifications Section 3.4, Containment Spray System and Emergency Service Water System, Amendment 247 Oyster Creek Nuclear Generating Station Updated Final Safety Analysis Report Section 6.2, Containment Systems, Revision 18

VM-OC-0137, Vertical Induction Motors, Revision 5

Attachment

VM-OC-0095, Diesel Generators, Revision 12 Oyster Creek Nuclear Generating Station Updated Final Safety Analysis Report Section 8.3, Onsite Power Systems, Revision 18

Section 1R18: Plant Modifications

Procedures

EP-059, Conduit Support Design and Installation, Revision 2

SP-9000-41-005, Installation Specification for Cables & Raceways at Oyster Creek Nuclear Generating Station, Revision 5

CC-AA-103, Configuration Change Control for Permanent Physical Plant changes, Revision 25

Drawings

GE 237E566, Reactor Protection System Electrical Elementary Diagram Channel 1, Sheet 1, Revision 45

GE 237E566, Reactor Protection System Electrical Elementary Diagram Channel 1, Sheet 3, Revision 15

Condition Reports

2448320

2451785

Maintenance Orders/Work Orders

C2033871

C2033863 A2373135

Miscellaneous

ECR 15-00064-000, Abandon Old Cable and Pull New Cable for

PSL-A, Revision 0000 Oyster Creek Nuclear Generating Station Technical Specifications Table 3.1.1

Protective Instrumentation Requirements, Amendment 208 Oyster Creek Nuclear Generating Station Updated Final Safety Analysis Report Section 7.2, Reactor Trip System, Revision 16

Section 1R19: Post-Maintenance Testing

Procedures

MA-AA-716-012, Post Maintenance Testing, Revision 19

WC-AA-101, On-Line Work Control Process, Revision 24 609.4.001, Isolation Condenser Valve Operability and In Service Test, Revision 79 651.4.001, Standby Gas Treatment System Auto Actuation Test, Revision 70 651.4.001, Standby Gas Treatment System Auto Actuation Test, Revision 71 651.4.002, Standby Gas Treatment System 15-Minute Run

System 1, Revision 14

MA-AA-716-011, Work Execution & Close Out, Revision 19

OP-AA-108-104, Technical Specification Compliance, Revision 1

WC-AA-111, Surveillance Program Requirements, Revision 4 602.3.004, Electromatic Relief Valve Pressure Sensor Test and Calibration, Revision 54 2400-SMM-3219.03, Removal Installation of Liquid Poison Relief Valves V-19-42 and V-19-43, Revision 8

Attachment Drawings

GE 237E566, Reactor Protection System Electrical Elementary Diagram Channel 1, Sheet 1, Revision 45

GE 237E566, Reactor Protection System Electrical Elementary Diagram Channel 1, Sheet 3, Revision 15 607.4.004, Containment Spray and Emergency Service Water Pump System 1 Operability and Comprehensive/Pre-Service/Post-Maintenance Inservice Test, Revision 93

Condition Reports

2448320

2448996

2451785

1484833

2440643

2060027

Maintenance Orders/Work Orders R2214807 R2213081 R2221719

C2033871

C2033863 A2373135 R2212850 R2211906 R2190413 R0800966 R2244647 R2211902 R2215497 R2208830

C2033158

Calculations

C-1302-622-E510-060,

PS-IA-0083 EMRV High Pressure Relief Calibration and Instrument Loop Error, Revision 0

Miscellaneous

VM-OC-0134, Anchor Darling Valves Operating & Maintenance Instruction Manual, Revision 13

ECR 15-00064, Abandon Old Cable and Pull New Cable for

PSL-A, Revision 0 Oyster Creek Nuclear Generating Station Technical Specifications Table 3.1.1

Protective Instrumentation Requirements, Amendment 208 Oyster Creek Nuclear Generating Station Updated Final Safety Analysis Report Section 7.2, Reactor Trip System, Revision 16

ECR 13-00238, Update

SP-1302-12-186 Test of Liquid Poison Relief Valves, Revision 0

SP-1302-12-186, Oyster Creek Specification for Test of Liquid Poison Relief Valves, Revision 2 Oyster Creek Nuclear Generating Station Outage Control Center Logs, dated September 18-20, 2014 Oyster Creek Nuclear Generating Station Control Room Logs, dated September 18-20, 2014 Oyster Creek Nuclear Generating Station Technical Specification 4.5, Containment System, Amendment 200 Oyster Creek Nuclear Generating Station Technical Specification 3.5, Containment, Amendment 196 Component History for System 822, Reactor Building Ventilation System, dated January 15, 2015 Oyster Creek Nuclear Generating Station Technical Specification 3.4, Emergency Cooling, Amendment 247 Oyster Creek Nuclear Generating Station Updated Final Safety Analysis Report Section 6.3, Emergency Core Cooling System, Revision 18 Complex Troubleshooting

2473044, MPR

Mechanical Pressure Regulator Complex Troubleshooting

2472372, EPR

Electronic Pressure Regulator

Section 1R20: Refueling and Other Outage Activities

Procedures

OP-AA-108-114, Post Transient Review, Revision 11

OP-AA-108-108, Unit Restart Review, Revision 16

ABN-9, Electric Pressure Regulator Malfunction, Revision 8

Attachment 203.4, Plant Cooldown Following Reactor Scram, Revision 55 201, Plant Startup, Revision 97

Condition Reports

(IRs)

2475725

2471342

2475432

2475114

2475561

2475574

2475641

2475747

2476834

2473561

2474409

2474403

2474385

2474379

2474359

2474338

2473834

2473656

2473641

2473580

2473159

2473665

2473100

2473287

2472230

2472176

2472427

2472415

2472372

2472063

Maintenance Orders/Work Orders

C2033216

C2034003

C2033572

C203330

C2033158

Miscellaneous

Complex Troubleshooting

2473044, MPR

Mechanical Pressure Regulator Complex Troubleshooting

2472372, EPR

Electronic Pressure Regulator

Section 1R22: Surveillance Testing

Procedures

636.4.013, Diesel Generator #2 Load Test, Revision 44 636.2.005, Diesel Generator #1 Weekly Battery Surveillance, Revision 25 678.4.001, Primary Containment Isolation Valve Operability and IST, Revision 45 612.4.001, Standby Liquid Control Pump and Valve Operability and IST, Revision 49 604.3.001, Reactor Building to Torus Power Vacuum Breaker Test and Calibration, Revision 42 645.4.036, Fire Pump #2 Operability Test, Revision 26 636.4.003, Diesel Generator #1 Load Test, Revision 101 602.4.002, MSIV Closure and IST Test, Revision 41

Calculations

C-1302-741-5350-009, Oyster Creek EDG Battery Sizing Calculation, Revision 1

Condition Reports

2435836

2435686

2435497

2435697

2473157

Maintenance Orders/Work Orders R2251418 R2250249 R2249566 R2253257 R2246844

Miscellaneous

In-service Testing Valve Trend Data for MSIV valve V-1-7, dated March 25, 2015

Section 1EP4: Emergency Action Level and Emergency Plan Changes

Miscellaneous

EP-AA-1000, Exelon Nuclear Standardized Radiological Emergency Plan, Revision 26

EP-AA-1010, Oyster Creek Station Radiological Emergency Plan Annex, Revision 9

Procedures

EP-AA-111, Emergency Classification and Protective Action Recommendations, Revision 19

Attachment

Section 1EP6: Drill Evaluation

Procedures

EP-AA-112-100, Control Room Operations, Revision 13

EP-AA-112-100-F-01, Shift Emergency Director Checklist, Revision U

EP-AA-112-100-F-06, ERO Notification or Augmentation, Revision Q

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

Section 2RS1: Radiological Hazard Assessment and Exposure Controls

RP-AA-210, Dosimetry Issue, Usage and Control, Revision 25

RP-AA-210-1001, Dosimetry Logs and Forms, Revision 9

RP-AA-300, Radiological Survey Program, Revision 12

RP-AA-401, Operational ALARA Planning and Controls, Revision 15

RP-AA-503, Unconditional Release Survey Method, Revision 8 -

NOSA-OYS-13-06, Radiation Protection Audit Report, August 28, 2013

NOSCPA-OC-14-17, Oyster Creek Radiation Protection Performance Report, December 2014

OC Radiation Protection O1R25 2014 Refueling Outage Report, November 21, 2014

OC-14-013 Radiation Position Paper Evaluation of Effective Dose Equivalent (EDEX) During

Refueling Outage 1R24 and 1R25, January 13, 2015 Michael Marshal (USNRC-NRR) letter to Christopher Crane (EXELON-CNO) dated

Exposure dated December 14, 2005 (TAC Nos. MC9247 through MC9263)

RP-AA-401 Attachment 5, ALARA Post Job Review 14-406 1R25 Reactor Disassembly, Refuel,

Inspection and Reassembly of Reactor, October 30, 2014 Teledyne Brown Engineering, Report of Analysis Batch # L61417 Samples

Received 12/17, 2014, January 20, 2015 OC Radiological Survey,

RH3-14-02920, Refuel Floor

Refuel Outage Routine,

October 3, 2014 OC Radiological Survey,

RH3-15-00075 Refuel Floor - Monthly Clean Area Routine,

January 11, 2015 OC Radiological Survey, 14-02907 Reactor Water Cleanup Regen Heat Exchanger,

October 2, 2014 OC Radiological Survey,

REO-14-02709 Reactor Water Cleanup Regen Heat Exchanger

Shielding Removal, September 26, 2014

OC-RP-AA-203-1001, Attachment 1 - Personnel Exposure Investigation,

PEI-14-114,

November 28, 2014

Attachment

Section 4OA2: Problem Identification and Resolution

--

2400-SME-3915.03, 4160 Volt Breaker Preventive Maintenance, Revision 11

PI-AA-125, Corrective Action Program (CAP) Procedure, Revision 2 636.4.002, Diesel Generator No. 2 Automatic Actuation Test, performed 11/17/12 636.4.013, Diesel Generator No. 2 Load Test, performed 9/22/13, 10/10/13, 10/25/13 and 11/04/13 636.4.016, Diesel Generator No. 2 Fast Start Test, performed 5/20/13

MA-AA-716-230-1001, Oil Analysis Interpretation Guideline, Revisions 16, 17 --- --- --

BR 3001C, 4160 System One Line Diagram, Revision 1

GE 223R0173, Sht. 16C, Emergency Service Water System Electrical Elementary Diagram, Revision 13

3E-861-21-1000, Sht. 1, EDG Air Cooling System Flow Diagram, Revision 11 3E-861-21-1001, Sht. 1, EDG Water Cooling System Flow Diagram, Revision 11 3E-861-21-1002, Sht. 1, EDG Lubricating Oil System Flow Diagram, Revision 12 - - - ----

ACIT

01575340-05, Submit Vendor FMS Trico Predict Labs for EDG Oil Analysis ACIT

01575340-08, CMO Lubricating Oil Program Owner to perform follow-up verification of new lab (Analysts Inc.) using appropriate Alarm Set and precision to meet Exelon Lubricating Oil Analysis Interpretation Guideline ACIT

01575340-11, CMO Lubricating Oil Program Owner to review wear metal alerts in

MA-AA-716-230-1001 for extremely low alert levels Apparent Cause Report (Equipment) for

AR 01575045,

EDG-2 Degraded Cylinder 15 Wrist Pin Found During Maintenance Inspection, event date 10/21/13

EA-01-235, Surry Nuclear Power Station

NRC Supplemental Inspection Report Nos. 50-280/02-08 and 50-281/02-08, dated 5/08/02

ER-AA-2008, MSPI Failure Determination Evaluation for

AR 01575045, dated 12/30/13

ESI-EMD Diesel Generator Owners Group Mechanical Maintenance Subcommittee

Impact of the 2001 Surry and Sequoyah Wrist Pin Bearing Failures on Other EMD Engine Users, Revision 0, dated 6/07/2003

Attachment

LER 01-01-00, 05000-280, Surry Power Station Unit 1 Inoperable EDG Results in Technical Specification Violation, dated 6/22/01

LER 86-001-01, 05000-313, Arkansas Nuclear One Unit 1 EDG Failure Due to Failure of Wrist Pin Bearings Results in Plant Shutdown Required By Technical Specifications, dated 10/31/88 M.I. 1760, GM ElectroMotive Maintenance Instruction, Lubricating Oil for EMD Engines

Marine, Power, and Drilling Rig, Revision H NRC Information Notice 2002-22: Degraded Bearing Surfaces in GM/EMD Emergency Diesel Generators, dated 6/28/02

OP-AA-101-113-1004, Attachment 2, Event/Issues Report Format, Equipment Issue (Oyster Creek), Revision 26 Surry Power Station

NRC Integrated Inspection Report 05000280/2012004, 05000281/2012004, 05000280/2012502, 05000281/2012502, dated 11/2/2012 Surry Power Station

NRC Integrated Inspection Report 05000280/2013002, 05000281/2013002, dated 4/30/2013

Windrock Inc. Letter, Bryan Blanchard to Exelon Oyster Creek Nuclear Station regarding EDG2 Oil Analysis, Cylinder Peak Firing Pressures and Vibration Analysis, dated 10/27/13

1511787, MSPI Failure Determination, dated 5/08/13

1575590-04, Apparent Cause Evaluation (Equipment)

ESW Pump 52A Failure to Start,

Breaker Failed to Close, dated 4/17/13

1614019, MSPI Failure Determination, dated 2/25/14 1614019-010, Apparent Cause Evaluation (Equipment)

ESW Pump 52C Failure to Start,

Breaker Failed to Close, dated 1/19/14

1664517-02, Maintenance Rule (a)(1) Determination, dated 5/27/14 2IQ9V2-001, Exelon/Oyster Creek Generation Station

AM-4.16-250-7H 1200 Amp Breaker,

S/N 0204A4764-001 Most Probable Cause of Failure Report, dated 10/17/13 Operator Rounds Log, Open/Closed Breakers Properly Charged, date range 4/04/13

4/18/13 PCM Template, Switches, dated 1/22/07 PCM Template, Medium Voltage Circuit Breakers, dated 4/19/14 System Health Report, 4160V AC Distribution System, Q4-2014

VM-OC-0008, Magne-Blast Circuit Breakers Types

AM-4.16-250-6, 7, 8, 9,

MC-13

Stored Energy Mechanism Instruction and Renewal Part, Revision 14

Section 4OA3: Follow-up of Events and Notices of Enforcement Discretion

Procedures

651.4.002, Standby Gas Treatment System 15-Minute Run

System 1, Revision 14

OP-AA-106-101, Significant Event Reporting, Revision 16

LS-AA-1110, Reportable Event SAF 1.8, Revision 21 312.2, Operation of the Reactor Building Railroad Air Lock Doors, Revision 16

EP-AA-1010, Emergency Action Levels for Oyster Creek Station, Revision 3

ABN-25, Off-Gas Deflagration, Revision 7

Attachment 203.4, Plant Cooldown Following Reactor Scram, Revision 55

ABN-1, Reactor Scram, Revision 13

Condition Reports

(IRs)

2383852

2383820

2440641

2060027

2463085

2463431

2463102

2475725

2471342

2475432

2475114

2475561

2475574

2475641

2475747

2476834

2473561

2474409

2474403

2474385

2474379

2474359

2474338

2473834

2473656

2473641

2473580

2473159

2473665

2473100

Maintenance Orders/Work Orders R2211902 A0700966 R0800966 R2244647

Miscellaneous

C-1302-822-E150-066, Secondary Containment Integrity Calculation, Revision 2 Oyster Creek Nuclear Generating Station Technical Specification 3.5, Containment, Amendment 196 Oyster Creek Nuclear Generating Station Technical Specification 4.5, Containment System, Amendment 200

LER 2014-005-00, Secondary Containment Declared Inoperable, dated November 18, 2014 10CFR50.9, Completeness and Accuracy of Information, dated July 10, 2014 10CFR 50.72, Immediate Notification Requirements for Operating Nuclear Power Reactors, dated July 10, 2014 10CFR 50.73, Licensee Event Report System, dated July 10, 2014

ENS 50476, Loss of Secondary Containment Integrity NRC Enforcement Policy, dated January 28, 2013, revised July 9, 2013 Oyster Creek Nuclear Generating Station Operating Logs, dated September 18-20, 2014

LIST OF ACRONYMS

ADAMS Agencywide Documents Access and Management System

CFR Code of Federal Regulations

EAL Emergency Action Level

IMC Inspection Manual Chapter

IR Issue Report

PPM Parts Per Million

LER Licensee Event Report

NCV Non-Cited Violation

NRC Nuclear Regulatory Commission

SDP Significance Determination Process UFSAR Updated Final Safety Analysis Report