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IR 05000219-12-005, 10/01/2012 - 12/31/2012; Oyster Creek Generating Station - NRC Integrated Inspection Report; Operability Determinations and Functionality Assessments, Other Activities
	ML13031A540
Person / Time
Site:	Oyster Creek
Issue date:	01/31/2013
From:	Hunegs G K; NRC/RGN-I/DRP/PB6
To:	Pacilio M J; Exelon Generation Co
	Hunegs G K
References
	G20130037 IR-12-005
	Download: ML13031A540 (52)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION REGION I 2100 RENAISSANCE BOULEVARD, SUITE 100 KING OF PRUSSIA, PENNSYLVANIA 19406-2713 January 31, 2013

Mr. Michael Senior Vice President, Exelon Generation Company, LLC President and Chief Nuclear Officer, Exelon Nuclear

4300 Winfield Road

Warrenville, IL 60555

SUBJECT: OYSTER CREEK GENERATING STATION - NRC INTEGRATED INSPECTION REPORT 05000219/2012005

Dear Mr. Pacilio:

On December 31, 2012, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at your Oyster Creek Generating Station. The enclosed inspection report documents the inspection results, which were discussed on January 22, 2013 with Russell Peak, Oyster Creek Plant Manager, and other members of your staff.

The inspection examined activities conducted under your license as they relate to safety and compliance with the Commission's rules and regulations 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 and one self-revealing finding of very low safety significance (Green). These findings were determined to involve violations of NRC requirements. 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 (NCVs), consistent with Section 2.3.2 of the NRC Enforcement Policy. If you contest any NCVs 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 Generating Station. In addition, if you disagree with the cross-cutting aspect assigned to any 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 Inspector at Oyster Creek Generating Station.

In accordance with 10 CFR 2.390 of the NRCs "Rules of Practice," a copy of this letter, its enclosure, and your response (if any) will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records (PARS) component of the NRC's document 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 05000219/2012005

w/Attachment:

Supplementary Information cc w/encl: Distribution via ListServ

ML13031A540 SUNSI Review Non-Sensitive Sensitive Publicly Available Non-Publicly Available OFFICE mmt RI/DRP RI/DRP RI/DRP NAME JKulp/GKH for SBarber/GKH for GHunegs/GKH DATE 01/31/13 01/31/13 01/31/13

1 Enclosure U.S. NUCLEAR REGULATORY COMMISSION REGION I

Docket No.: 50-219

License No.: DPR-16

Report No.: 05000219/2012005

Licensee: Exelon Nuclear

Facility: Oyster Creek Generating Station

Location: Forked River, New Jersey

Dates: October 1, 2012 - December 31, 2012

Inspectors: J. Kulp, Senior Resident Inspector A. Patel, Resident Inspector J. Schoppy, Senior Reactor Inspector

T. Hedigan, Operations Engineer S. Hammann, Senior Health Physicist J. Rady, Reactor Inspector B. Dionne, Health Physicist C. Crisden, Reactor Inspector C. Newport, Operations Engineer P. Kaufman, Senior Reactor Inspector T. O'Hara, Reactor Inspector T. Fish, Senior Operations Engineer

Approved By: Gordon Hunegs, Chief Reactor Projects Branch 6 Division of Reactor Projects

2 Enclosure

SUMMARY OF FINDINGS

IR 05000219/2012005, 10/01/2012 - 12/31/2012; Exelon Energy Company, LLC, Oyster Creek

Generating Station; Operability Determinations and Functionality Assessments, Other Activities.

This report covered a three-month period of inspection by resident inspectors and announced inspections performed by regional inspectors. This report documents one inspector-identified and one self-revealing finding of very low safety significance (Green), both of which are non-cited violations (NCV). The significance of most findings is indicated by their color (Green, White, Yellow, Red) using Inspection Manual Chapter (IMC) 0609, "Significance Determination Process" (SDP). The cross-cutting aspects for the findings were determined using IMC 0310,

"Components Within Cross-Cutting Areas." Findings for which the SDP does not apply may be Green, or be assigned a severity level after NRC management review. The NRC's program for overseeing the safe operation of commercial nuclear power reactors is described in NUREG-1649, "Reactor Oversight Process," Revision 4, dated December 2006.

Cornerstone: Mitigating Systems

Green.

The inspectors identified a Green non-cited violation (NCV) of 10 CFR 50, Appendix B, Criterion V, "Instructions, Procedures, and Drawings," because Exelon did not properly implement procedural cont rols to ensure adequate thread engagement for standby liquid control (SLC) squib valve spool piece flanges. Specifically, SLC squib valve flanges were installed with inadequate thread engagement (stud was not flush with the nut), as required by Exelon's maintenance procedures. Exelon's corrective actions included declaring the system inoperable, entering the issue into the corrective action program (IR 1444861 and 1444862) and immediately replacing the existing bolts with bolts of an appropriate length such that projection through the nut was at least flush.

The performance deficiency was more than minor because if left uncorrected the inadequate thread engagement would have the potential to lead to a more significant safety concern. Specifically, Exelon's evaluation stated that the SLC squib valve spool piece flanges would not have been able to perform their design function under all seismic conditions when the system was required to be operable. In consultation with the Region I senior reactor analyst, the inspectors reviewed this condition using IMC 0609, Attachment G, "Shutdown Operations Significance Determination Process." As the condition occurred during the refueling outage and was identified and corrected before Exelon started up the Oyster Creek reactor, and only existed during the outage when SLC was not required to be operable (November 16 - 27, 2012), the issue screened to very low safety significance (Green). This finding has a cross-cutting aspect in the area of Problem Identification and Resolution, Corrective Action Program, because Exelon did not take appropriate corrective actions to address safety issues and adverse trends in a timely manner, commensurate with their safety significance and complexity. Specifically, Exelon did not take appropriate corrective actions, such as replacing bolts during the refueling outage with longer bolts, after the NRC identified a similar concern on the same SLC squib valve spool piece flanges in September 2012 (IR 1417726). (P.1(d)) (Section 1R15)

Cornerstone: Barrier Integrity

Green.

A self-revealing NCV of 10 CFR 50, Appendix B, Criterion V, "Instructions, Procedures, and Drawings," was identified because Exelon procedures and work orders were not effective in preventing refueling cavity leakage from overflowing onto the exterior surface of the drywell liner during the refueling outage (1R24) in November 2012. The performance deficiencies that contributed to the finding were inadequate oversight of the contractors applying a strippable coating to the reactor cavity liner and a valve configuration control error on a temporarily installed leak age collection system. Upon discovery, Exelon took immediate corrective actions to open the leakage collection system filter inlet valve and restore reactor cavity liner leakage flow to the reactor building equipment drain tank.

This finding is associated with the barrier integrity cornerstone and is more than minor because, if left uncorrected, this condition would have the potential to lead to a more significant safety concern. Specifically, the continued wetting of the metallic drywell liner surface could provide an environment conducive to corrosion. This finding is not more than very low safety significance because Exelon performs periodic inspections of drywell liner and exterior surface coating to ensure that liner corrosion is monitored and controlled. The inspectors completed the Phase 1 Initial Screening and Characterization of Findings, of Attachment 0609.04 of Inspection Manual Chapter (IMC) 0609, and screened the finding to Green, very low safety significance. Exelon has entered this condition into the corrective action process under IR 1440116. This finding has a cross-cutting aspect in the area of Human Performance, Work Practices, for not ensuring supervisory and management oversight of work activities, including contractors and plant personnel, such that nuclear safety is supported regarding the application of the strippable coating on the reactor cavity liner. (H.4(c)) (Section 1R08)

REPORT DETAILS

Summary of Plant Status

Oyster Creek began the inspection period at 100 percent power and operated at full power until October 22 when operators commenced a shutdown for a planned refueling and maintenance outage (1R24). Following the completion of refueling and maintenance activities, operators commenced a reactor startup on November 29. Operators returned the unit to 100 percent power on December 4, and remained at or near 100 percent power for the remainder of the inspection period.

REACTOR SAFETY

Cornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity

1R01 Adverse Weather Protection

Main article: IP 71111.01

.1 Readiness for Seasonal Extreme Weather Conditions

a. Inspection Scope

The inspectors performed a review of Exelon's readiness for the onset of seasonal cold temperatures. The review focused on the intake structure and the emergency diesel generators (EDGs). The inspectors reviewed the Updated Final Safety Analysis Report (UFSAR), technical specifications, control room logs, and the corrective action program to determine what temperatures or other seasonal weather could challenge these systems, and to ensure Exelon's personnel had adequately prepared for these challenges. The inspectors reviewed station procedures, including Exelon's seasonal weather preparation procedure and applicable operating procedures. The inspectors performed walkdowns of the selected systems to ensure station personnel identified issues that could challenge the operability of the systems during cold weather conditions.

b. Findings

No findings were identified.

.2 Readiness for Impending Adverse Weather Conditions

a. Inspection Scope

The inspectors completed one impending adverse weather preparation sample. The inspectors reviewed Exelon's preparations for the onset of Superstorm Sandy on October 28, 2012. The inspectors reviewed the implementation of adverse weather preparation procedures before the onset of and during adverse weather conditions.

The inspectors walked down the emergency diesel generators and the intake structure to ensure system availability. The inspectors verified that operator actions defined in Exelon's adverse weather procedure maintained the readiness of essential systems. The inspectors discussed readiness and staff availability for adverse weather response with operations and work control personnel.

b. Findings

No findings were identified.

1R04 Equipment Alignment

.1 Partial System Walkdowns

Main article: IP 71111.04Q

a. Inspection Scope

The inspectors performed partial walkdowns of the following systems:

Standby gas treatment system (SBGTS) #2 while SBGTS #1 was inoperable for corrective maintenance on October 4, 2012 Emergency service water (ESW) pump 1-1 while ESW pump 1-3 was inoperable for planned maintenance on October 10, 2012 Service water (SW) and ESW systems during Superstorm Sandy on October 29, 2012 Emergency diesel generator (EDG) #1 and EDG #2 during Superstorm Sandy on October 29, 2012 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 t he 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

Main article: IP 71111.04S

a. Inspection Scope

From October 10-12, 2012, the inspectors performed a complete system walkdown of accessible portions of the "A" control rod drive 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 t he 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

Main article: IP 71111.05Q

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.

Condenser Bay (TB-FZ-11E) on October 23, 2012 Torus Room (RB-FA-2) on November 8, 2012 Drywell (RB-FA-2) on November 20, 2012

b. Findings

No findings were identified.

1R06 Flood Protection Measures

Main article: IP 71111.06

.1 Internal Flooding Review

a. Inspection Scope

The inspectors reviewed the updated final safety analysis report, the site flooding analysis, and plant procedures to assess susceptibilities involving internal flooding. The inspectors also reviewed the corrective action program to determine if Exelon identified and corrected flooding problems and whether operator actions for coping with flooding were adequate. The inspectors also focused on the control rod drive, core spray and containment spray pump areas to verify the adequacy of internal flooding mitigating strategies and barriers.

b. Findings

No findings were identified.

1R08 In-service Inspection - Oyster Creek

Main article: IP 71111.08

a. Inspection Scope

From November 5, 2012 to November 9, 2012, from November 13, 2012 to November 15, 2012 and from December 11, 2012 to December 13, 2012, the inspectors conducted a review of Exelon's implementation of in-service inspection (ISI) program activities for monitoring degradation of the reactor coolant system pressure boundary, risk significant piping and components, and containment systems for the Oyster Greek Generating Station. The sample selection was based on the inspection procedure objectives and risk priority of those pressure retaining components in these systems where degradation would result in a significant increase in risk. The inspectors observed in-process non-destructive examinations (NDE), reviewed documentation, and inter-viewed inspection personnel to verify that the non-destructive examination activities performed as part of Interval 4, Period 3 of the Oyster Creek In-service Inspection during the 1R24 outage were conducted in accordance with the requirements of the American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel Code Section XI, 2005 Edition, 2006 Addenda.

Nondestructive Examination and Welding Activities (02.01)

The inspectors performed direct observations of NDE activities in process and reviewed records of nondestructive examinations listed below:

ASME Code Required Examinations Direct field observation of visual examination (VT) of drywell sand bed bay #11 for epoxy coating anomalies and for corrosion. This inspection is part of the IWE containment inspection requirements and is performed to meet a license renewal aging management license requirement.

Inspection documentation review of VT in sand bed bays #1, #3, #5, #7, #9, #13, #15, #17, and #19.

Additionally, the inspectors reviewed the results of the ultrasonic (UT) thickness measurements taken in the sand bed bays to determine the extent of corrosion of the drywell wall. The inspectors also reviewed the sand bed coating repair records for repairs carried out during the 1R24 outage inspections.

Record review of NDE examination records of tests performed on reactor vessel nozzle N9 safe-end weld during repair. (See Repair/Replacement Activities below.)

Record review of NDE examination records of tests performed on a leak on reactor head penetration N7B flange weld during repair. (See Repair/Replacement Activities below.) The inspectors reviewed a sample of certifications for NDE technicians performing examinations and verified that the inspections were performed in accordance with approved procedures and that the results were reviewed and evaluated by certified Level III NDE personnel.

Other Augmented or Industry Initiative Examinations The inspectors reviewed inspection records of visual inspections conducted on reactor vessel internals components. These inspections were carried out in accordance with the industry initiative under the Boiling Water Reactor Vessel and Internals Project (BWRVIP), In Vessel Visual Inspection (IVVI) Program. These inspections monitor and record the condition of the reactor vessel internal components. Specifically, the inspectors reviewed VT examination data records and reviewed the disposition of indications noted by the inspectors. The inspectors verified that the activities were

performed in accordance with applicable examination procedures and industry guidance. All recorded indications were dispositioned by the NDE examiner and Exelon as acceptable for further service.

Review of Originally Rejectable Indications Accepted by Evaluation

There were no samples available for review during this inspection that involved examinations with recordable indications that had been accepted for continued service from the previous Oyster Creek outage 1R23.

Repair/Replacement Activities Including Welding Activities

During an in-service liquid penetrant (LP) inspection of the nozzle to safe-end weld on reactor vessel control rod drive injection nozzle N9, Exelon identified rejectable surface indications. The inspectors reviewed the LP inspection record and subsequent ultrasonic (UT) examination records conducted on the N9 nozzle to safe-end weld indications. The UT inspection verified that the surface indications were not connected to the inside diameter of the nozzle. Exelon decided to repair the surface indications by installing a full structural weld overlay in accordance with the requirements of ASME Code Case N504-4. The inspectors reviewed the engineering evaluation of the overlay design and the ASME,Section XI repair/replacement plan for the weld overlay. The

inspectors reviewed the weld traveler for the overlay and reviewed the pre-service, phased array ultrasonic examination of the completed overlay. Also, the inspectors verified the acceptability of the completed overlay from the successful plant operational pressure test of the nozzle-to safe-end weld. The inspectors verified that the repair, the welding activities and applicable NDE activities were completed successfully in accordance with ASME Code requirements.

During plant startup preparations at the end of the 1R24 outage, a small leak was observed from reactor head penetration N7B flange during the plant operational pressure test. Exelon determined that the leak was the result of a weld defect in a flange to pipe socket weld on the reactor head spray connection. Exelon initiated an ASME,Section XI repair of the defect. The inspectors reviewed the repair replacement program plan, the welding documentation of the repair, the in-process NDE, and the documentation of the final, successful plant operational pressure test of the repair. The leak was repaired in accordance with the ASME Code requirements.

Identification and Resolution of Problems The inspectors reviewed a sample of Oyster Creek action reports (ARs), which identified NDE indications, deficiencies and other nonconforming conditions since the previous 1R23 outage and during the present 1R24 outage. The inspectors verified that nonconforming conditions were properly identified, characterized, evaluated, corrective actions identified and dispositioned, and appropriately entered into the Oyster Creek corrective action program.

The inspectors specifically focused on several corrective action reports written in response to the leakage of reactor refueling cavity (pool) water into the drywell sand bed

area.

b. Findings

Introduction:

A self-revealing non-cited violation of 10 CFR 50, Appendix B, Criterion V, Instructions, Procedures and Drawings, was identified when reactor refueling cavity leakage was not adequately controlled (incorrect strippable coating application and failure to control the position of valve V-18-131) allowing water to contact the exterior surface of the drywell shell in the sand bed areas.

Description:

During the refueling outage (1R24), a strippable coating was applied to the refueling cavity liner as a radiological contamination prevention measure which had a secondary benefit of minimizing reactor pool leakage. During installation of the coating, the contractor did not properly follow the work order instructions, resulting in parts of the pool liner not being properly coated. This deficiency of not coating the liner contributed to an increase in the refueling pool leakage when the refuel pool was filled for refueling operations on November 2, 2012. The increased pool leakage continued until November 20, 2012 when refueling operations were completed and the refuel pool was drained.

A temporary system had been installed to capture the refueling pool leakage and direct it to the reactor building equipment drain tank (RBEDT) for processing. The leakage was directed via an overflow drain trough, through a filt er with isolation valves, to the RBEDT. After a short period of operation, the filter became clogged, reducing the flow to the RBEDT. The clogged filter caused the refuel pool drain trough to overflow and water flowed over the exterior surface of the drywell shell into the sand beds and onto the torus room floor. The leakage on the torus room floor was diverted to the reactor building drain system and collected in the normal plant liquid radiological waste disposal system.

To address the clogged filter, Exelon revised work order R2076388, to close the filter inlet valve and removed the filter cartridge. However, the work order failed to appropriately direct operators to return the filter inlet valve (V-18-131) to the open position. As a result, for a period of approximately 11 hours1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br />, the leakage continued.

Analysis:

Exelon did not provide adequate instructions, procedures and drawings to properly apply the strippable coating to the refueling cavity liner to minimize known liner leakage and to control the position of the leakage collection system filter inlet valve. The

two issues are being grouped together in accordance with the guidance provided in NRC IMC 0612, Appendix B, Block 2, Item (3). These issues are performance deficiencies because providing appropriate instructions was within Exelon's ability to foresee and correct and should have prevented water leakage onto the exterior of the drywell liner. This finding is more than minor because, if left uncorrected, this condition would have the potential to lead to a more significant safety concern. Specifically, the continued wetting of the metallic drywell liner surface could provide an environment conducive to corrosion in the sand bed areas.

This finding affects the barrier integrity cornerstone and the inspectors completed the Phase 1 Initial Screening and Characterization of Findings, of Table 2 and Table 3 of Attachment 0609.04 of Inspection Manual Chapter (IMC) 0609. The inspectors completed the screening of Exhibit 3, of IMC 0609, Appendix A and screened the finding to Green, very low safety significance, because "- the finding does not represent an actual open pathway in the physical integrity of the reactor containment -", and, "... the finding does not involve an actual reduction in function of hydrogen igniters in the reactor containment". This finding is not more than very low safety significance because Exelon removed the sand from the sand bed areas and coated the liner exterior with an epoxy coating in 1992, to further reduce the likelihood of liner corrosion. Additionally, Exelon performs periodic inspections of the drywell liner and exterior surface coating to ensure that liner corrosion is monitored and controlled.

This issue is of very low safety significance because Exelon completed significant corrective actions to reduce the corrosion of the drywell liner in the sand bed bays in 1992 when the sand was removed from the sand beds. Also, the drywell liner in the sand bed bays was coated with an epoxy coating in 1992, to further prevent the likelihood of corrosion.

The inspectors determined that the finding has a cross-cutting aspect in the area of Human Performance, Work Practices, H.4(c) for not ensuring supervisory and management oversight of work activities, including contractors and plant personnel, such that nuclear safety is supported regarding the application of the strippable coating on the reactor cavity liner.

Enforcement:

10 CFR 50, Appendix B, Criterion V, "Instructions, Procedures and Drawings" requires, in part, that, "Activities affecting quality shall be prescribed by documented instructions, procedures and drawings, of a type appropriate to the circumstances and shall be accomplished in accordance with these instructions, procedures or drawings. Instructions, procedures, or drawings shall include appropriate quantitative or qualitative acceptance criteria for determining that important activities have been satisfactorily accomplished."

Contrary to the above, Exelon did not implement effective instructions, procedures, or drawings to ensure that leaking portions of the refueling cavity liner were coated with a strippable coating to minimize leakage and did not provide effective procedures to preclude water from contacting the exterior surface for the drywell liner during refueling outage 1R24, in November 2012. This condition resulted in an environment that was conducive to an increased potential for drywell liner corrosion. Upon discovery, Exelon took immediate corrective actions to open the filter inlet valve and restore reactor cavity liner leakage flow to the reactor building equipment drain tank and entered this condition into the corrective action process under IR 1440116. This violation is being treated as an NCV, consistent with Section 2.3.2. of the Enforcement Policy because it was of very low significance and was documented in Exelon's corrective action program. (NCV 05000219/2012005-02, Inadequate Application of Strippable Coating to the Refueling Cavity Liner and the Failure to Configure a Valve in the Leakage Collection System Resulting in Increased Potential for Corrosion on the Exterior of the Drywell Liner Surface in the Sand Beds)

1R11 Licensed Operator Requalification Program

Main article: IP 71111.11

.1 Quarterly Review of Licensed Operator Requalification Testing and Training

a. Inspection Scope

The inspectors observed licensed operator simulator on October 3, 2012 and just in time training for unit startup on December 3, 2012. 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, implemen-tation 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

On October 21, 2012, the inspectors observed the control room operators shutdown the unit for refueling outage 24 and turbine overspeed trip test. The inspectors observed the pre-evolution brief and reviewed the post-evolution critique to ensure that the crew was ready to perform the evolution and were self-critical in their appraisal of their perfor-mance. Additionally, the inspectors observed the crew during the evolution to verify that procedure use, crew communications, and coordination of activities in the control room met established expectations and standards.

b. Findings

No findings were identified.

.3 Licensed Operator Requalification Program

a. Inspection Scope

On August 2, 2012, region-based inspectors conducted an in-office review of results of the licensee-administered annual operating tests (comprehensive written exams were previously administered in May and June 2011). The inspection assessed whether pass rates were consistent with the guidance of NRC Manual Chapter 0609, Appendix I, "Operator Requalification Human Performance Significance Determination Process (SDP)". The inspectors verified that:

Main article: IP 71111.15

a. Inspection Scope

The inspectors reviewed operability determinations for the following degraded or non-conforming conditions:

Service water system operability during high intake water levels on October 29, 2012 Emergency service water system operability during high intake water levels on October 30, 2012 Standby liquid control pump operability due to inadequate thread engagement on pump discharge flanges on November 28, 2012 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 Exelon's 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

Introduction:

The inspectors identified a Green, non-cited violation of 10 CFR 50, Appendix B, Criterion V, "Instructions, Procedures, and Drawings," because Exelon did not properly implement procedural controls to ensure adequate threaded fastener engagement when reinstalling the standby liquid control (SLC) squib valve spool piece following squib valve replacement. Specifical ly, the SLC squib valve spool pieces were installed with inadequate thread engagement (studs were not flush with the nuts), as required by station maintenance procedures.

Description:

On November 27, 2012, during a walkdown of the SLC system, the inspectors identified that following the replacement of both squib valves, all the fasteners securing the squib valve spool pieces to the system piping were two to three threads short of being flush with the nut and were not in compliance with Exelon procedure 2400-GMM-3900.52, "Inspection and Torquing of Bolted Connections." Specifically, 2400-GMM-3900.52, precaution step 3.1.2 states, in part, "minimum projection of a bolt through a nut shall be flush." Contrary to this procedure, the inspectors identified the spool piece flange fasteners for both SLC systems, each having four studs per flange, did not project any stud flush with the fastening nuts.

Exelon reviewed the as-found condition and determined that there was not a reasonable assurance that the fasteners for the spool pieces would be able to perform their design function under all seismic conditions, and determined SLC to be inoperable. At the time of identification, technical specification actions did not apply because SLC was not required to operable because Oyster Creek was in a refueling outage (reactor temperature < 212 F). Additionally, Exelon determined that the condition concerning the flange fasteners that were installed did not exist when SLC was required to operable because the spool pieces were removed and reinstalled during the refueling outage on November 16, 2012. Exelon's corrective actions included entering the issue into the corrective action program (IR 1444861 and 1444862) and immediately replacing the inadequate studs with studs of an appropriate length, such that projection through the nut was at least flush.

a. Inspection Scope

(71114.02 - 1 Sample)

An onsite review was conducted to assess the maintenance and testing of the Alert and Notification System (ANS). During this inspection, the inspectors conducted a review of the ANS testing and maintenance programs. The inspectors reviewed the associated ANS procedure and the Federal Emergency Management Agency (FEMA) approved ANS Design Report to ensure compliance with design report commitments for system maintenance and testing. The inspection was conducted in accordance with NRC Inspection Procedure 71114, Attachment 2. Title 10 of the Code of Federal Regulations (10 CFR) 50.47(b)(5) and the related requirements of 10 CFR Part 50, Appendix E, were used as reference criteria.

b. Findings

No findings were identified.

1EP3 Emergency Response Organization Staffing and Augmentation System

a. Inspection Scope

(71114.03 - 1 Sample)

The inspectors conducted a review of the Oyster Creek Emergency Response Organization (ERO) augmentation staffing requirements and the process for notifying and augmenting the ERO. The review was performed to verify the readiness of key Exelon staff to respond to an emergency event and to verify Exelon's ability to activate their emergency response facilities (ERF) in a timely manner. The inspectors reviewed the Exelon Nuclear Standardized Emergency Plan and the Oyster Creek Emergency Plan Annex for ERF activation and ERO staffing requirements, the ERO duty roster, applicable station procedures, augmentation test reports, the most recent drive-in drill report, and condition reports (CR) related to this inspection area. The inspectors also reviewed a sample of ERO responder training records to verify training and qualifications were up to date. The inspection was conducted in accordance with NRC Inspection Procedure 71114, Attachment 3. Title 10 CFR 50.47(b)(2) and related requirements of 10 CFR Part 50, Appendix E, were used as reference criteria.

b. Findings

No findings were identified.

1EP5 Maintaining Emergency Preparedness

a. Inspection Scope

(71114.05 - 1 Sample)

The inspectors reviewed a number of activities to evaluate the efficacy of Exelon's efforts to maintain the Oyster Creek emergency preparedness program. The inspectors reviewed: Letters of Agreement and/or Memorandums of Understanding with offsite agencies; the 10 CFR 50.54(q) Emergency Plan change process and practice; licensee maintenance of equipment important to EP; records of evacuation time estimate population evaluation; and provisions for, and implementation of, primary, backup, and alternate emergency response facility (ERF) maintenance. The inspectors also verified Exelon's compliance at Oyster Creek with new NRC EP regulations regarding:

emergency action levels for hostile action events and protective actions for on-site personnel during events.

The inspectors further evaluated Exelon's ability to maintain their EP program through their identification and correction of EP weaknesses, by reviewing a sample of drill reports, actual event reports, self-assessments, 10 CFR 50.54(t) audits, and EP-related CRs. The inspectors reviewed a sample of EP-related CRs initiated at Oyster Creek from July 2010 through October 2012. The inspection was conducted in accordance with NRC Inspection Procedure 71114.05. Title 10 CFR 50.47(b) and the related requirements of 10 CFR Part 50, Appendix E, were used as reference criteria.

b. Findings

No findings were identified.

Cornerstones: Public Radiation Safety and Occupational Radiation Safety

2RS1 Radiological Hazard Assessment and Exposure Controls

Main article: IP 71124.01

a. Inspection Scope

The inspectors reviewed radiation measurement devices, area radiation surveys, radiation work permits, contamination and radiation material controls, high and very high radiation areas, radiation worker performance, and radiation protection personnel qualifications. These areas were inspected to review and evaluate Exelon's performance in assessing the radiological hazards in the workplace associated with licensed activities and the implementation of appropriate radiation monitoring and

exposure control measures for both individual and collective exposures. The inspectors evaluated whether problems associated with radiation monitoring and exposure control were being identified by Exelon at an appropriate threshold and were properly addressed for resolution in Exelon's corrective action program.

b. Findings

No findings were identified.

2RS2 Occupational ALARA Planning and Controls

Main article: IP 71124.02

a. Inspection Scope

The inspectors reviewed the as low as is reasonable achievable (ALARA) work activity evaluations, exposure estimates, exposure reduction requirements and measures taken by Exelon to track, trend and reduce occupational doses for ongoing work activities to assess performance with respect to maintaining individual and collective radiation exposures ALARA. The inspectors also reviewed Exelon's records to determine the historical trends and current status of plant source term known to contribute to elevated facility collective exposure. The inspectors observed the performance of radiation workers and radiation protection technicians during refueling outage activities in radiation areas, airborne radioactivity areas, and high radiation areas. The inspectors verified Exelon's ALARA program, including administrative, operational, and engineering controls, is effectively maintaining occupational exposure ALARA. The inspectors evaluated whether problems associated with ALARA planning and controls are being identified by Exelon at an appropriate threshold and were properly addressed for resolution in Exelon's corrective action program.

b. Findings

No findings were identified.

2RS3 In-Plant Airborne Radioactivity Control and Mitigation

Main article: IP 71124.03

a. Inspection Scope

The inspectors reviewed the updated final safety analysis report, technical specification, air sample test results, equipment maintenance and test records, inspection and maintenance procedures, and system operational procedures. The inspectors reviewed procedural guidance for use of installed plant systems to reduce dose and assessed whether the systems are used, to the extent practicable, during high-risk activities. The inspectors reviewed instrument setpoints to verify that in-plant airborne concentrations are being controlled consistent with ALARA to the extent necessary to validate plant operations as reported by the performance indicators and to verify that the practices and use of respiratory protection devices on site do not pose an undue risk to the wearer.

The inspectors reviewed a sample of training and medical records to verify that employees were properly qualified to use respiratory protection devices. The inspectors monitored several employees as they demonstrated the use of respiratory protection devices. The inspectors spot check several respiratory protection devices and verified that they were in acceptable material condition and maintained properly.

b. Findings

No findings were identified.

2RS4 Occupational Dose Assessment

Main article: IP 71124.04

a. Inspection Scope

The inspectors reviewed Exelon's procedures associated with dosimetry operations, including issuance/use of external dosimetry, assessment of internal dose, and evaluation of and dose assessment for radiological incidents. The inspectors evaluated whether Exelon had established procedural requirements for determining when external dosimetry and internal dose assessments are required. The inspectors walked down and evaluated the onsite storage of dosimeters before issuance, during use, and before processing/reading. The inspectors also reviewed the guidance provided to radiation workers with respect to care and storage of dosimeters. The inspectors reviewed dosimetry occurrence reports or corrective action program documents for adverse trends related to electronic pocket dosimeters. The inspectors reviewed procedures used to assess the dose from internally deposited radionuclides using whole body counting equipment. The inspectors reviewed the documentation for two individuals who had declared pregnancy during the current assessment period and evaluated whether Exelon's radiological monitoring program (internal and external) for declared pregnant workers is technically adequate to assess the dose to the embryo/fetus. The inspectors reviewed exposure results and monitoring controls implemented by Exelon. The inspectors evaluated Exelon's neutron dosimetry program, including dosimeter types and/or radiation survey instrumentation.

b. Findings

No findings were identified.

OTHER ACTIVITIES

4OA1 Performance Indicator Verification

Main article: IP 71151

.1 Mitigating Systems Performance Index (5 samples)

a. Inspection Scope

The inspectors reviewed Exelon's submittal of the Mitigating Systems Performance Index for the following systems for the period of October 1, 2011 through September 30, 2012: Emergency AC Power System High Pressure Injection System Heat Removal - Isolation Condensers RHR - Containment Spray Cooling Water System To determine the accuracy of the performance indicator data reported during those periods, the inspectors used definitions and guidance contained in Nuclear Energy Institute (NEI) Document 99-02, "Regulatory Assessment Performance Indicator Guideline," Revision 6. The inspectors also reviewed Exelon's operator narrative logs, condition reports, mitigating systems perfo rmance index derivation reports, event reports, and NRC integrated inspection reports to validate the accuracy of the submittals.

b. Findings

No findings were identified.

.2 EP Performance Indicators (PI) (3 samples)

a. Inspection Scope

The inspectors reviewed data for the three EP Performance Indicators (PI), which are:

(1) Drill and Exercise Performance;

(2) ERO Drill Participation; and,

(3) ANS Reliability. The last NRC EP inspection at Oyster Creek was conducted in the third calendar quarter of 2011. Therefore, the inspectors reviewed supporting documentation from EP drills and equipment tests from the third calendar quarter of 2011 through the third calendar

quarter of 2012 to verify the accuracy of the reported PI data. The review of the PIs was conducted in accordance with NRC Inspection Procedure 71151. The acceptance criteria documented in NEI 99-02, "Regulatory Assessment Performance Indicator Guidelines," Revision 6, was used as reference criteria.

b. Findings

No findings were identified.

.3 Occupational Exposure Control Effectiveness (1 - sample)

a. Inspection Scope

The inspectors reviewed implementation of the Occupational Exposure Control Effectiveness PI Program. The inspectors reviewed corrective action program records for occurrences involving high radiation areas, very high radiation areas, and unplanned personnel radiation exposures since the last inspection in this area. The review was against the applicable criteria specified in NEI 99-02, Regulatory Assessment Performance Indicator Guideline, Rev. 6. The purpose of this review was to verify that occurrences that met NEI criteria were recognized and identified as Performance Indicators.

b. Findings

No findings were identified.

.4 RETS/ODCM Radiological Effluent Occurrences (1 - sample)

a. Inspection Scope

The inspectors reviewed the implementation of the Radiological Effluents Technical Specification/Offsite Dose Calculation Manual (RETS/ODCM) PI program. The inspectors reviewed corrective action program records and projected monthly and quarterly dose assessment results due to radioactive liquid and gaseous effluent releases for the past four complete quarters. The review was against the applicable criteria specified in NEI 99-02, Regulatory Assessment Performance Indicator Guideline, Rev. 6. The purpose of this review was to verify that occurrences that met NEI criteria were recognized and identified as Performance Indicators.

As part of this review, the inspectors also reviewed Exelon's evaluations and public dose assessments associated with identification of localized ground water contamination within the restricted area.

b. Findings

No findings were identified.

4OA2 Problem Identification and Resolution

Main article: IP 71152

.1 Routine Review of Problem Identification and Resolution Activities

a. Inspection Scope

As required by Inspection Procedure 71152, "Problem Identification and Resolution," 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 attent ion 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 Semi-Annual Trend Review

a. Inspection Scope

The inspectors performed a semi-annual review of site issues, as required by Inspection Procedure 71152, "Problem Identification and Resolution," to identify trends that might indicate the existence of more significant safety issues. In this review, the inspectors included repetitive or closely-related issues that may have been documented by Exelon outside of the corrective action program, such as trend reports, performance indicators, major equipment problem lists, system health reports, maintenance rule assessments, and maintenance or corrective action program backlogs. The inspectors also reviewed Exelon's corrective action program database for the first and second quarters of 2012 to assess condition reports written in various subject areas (equipment problems, human performance issues, etc.), as well as indivi dual issues identified during the NRCs daily condition report review (Section 4OA2.1).

a. Findings and Observations

No findings were identified.

The inspectors evaluated a sample of equipment material condition improvement lists.

This review included a sample of condition reports of those systems on the list to determine equipment availability, reliability and operability. The inspectors also verified the appropriate disposition of equipment material condition trends and that they were addressed within the scope of the corrective action program and documented in condition reports.

Examples of systems in Exelon's equipment material condition improvement list include electrical penetrations, fuel pool cooling heat exchangers, and standby gas treatment systems. The inspectors determined that Exelon appropriately identified equipment material conditions improvements and appropriately documented those systems in the corrective action program. The inspectors concluded that Exelon was implementing appropriate actions to address any adverse trend in equipment material condition.

.3 Annual Sample: Review of the Operator Workaround Program

a. Inspection Scope

The inspectors reviewed the cumulative effects of the existing operator workarounds, operator burdens, existing operator aids and disabled alarms, and open main control room deficiencies to identify any effect on emergency operating procedure operator actions, and any impact on possible initiating events and mitigating systems. The inspectors evaluated whether station personnel had identified, assessed, and reviewed operator workarounds as specified in Exelon procedure OP-AA-102-103, Operator Work-Around Program.

The inspectors reviewed Exelon's process to identify, prioritize and resolve main control room distractions to minimize operator burdens. The inspectors reviewed the system used to track these operator workarounds and recent Exelon self assessments of the program. The inspectors also toured the control room and discussed the current operator workarounds with the operators to ensure the items were being addressed on a schedule consistent with their relative safety significance.

b. Findings and Observations

No findings were identified.

The inspectors determined that the issues reviewed did not adversely affect the capability of the operators to implement abnormal or emergency operating procedures. The inspectors also verified that Exelon entered operator workarounds and burdens into the corrective action program at an appropriate threshold and planned or implemented corrective actions commensurate with their safety significance.

.4 Annual Sample:

Failure of Agastat Relays in the Isolation Condenser System (ICS)

a. Inspection Scope

The inspectors performed an in-depth review of Exelon's failure analysis and corrective actions associated with condition report CR 01350115 that documented occurrences where Agastat electro-pneumatic time delay relay contacts within the isolation condenser system (ICS) failed to change state when the relay de-energized. The relay de-energized as expected during the surveillance testing procedure when the direct current (DC) circuit was opened by simulating a high Reactor Pressure Vessel (RPV)pressure condition. However, relay contacts did not actuate to reposition the 'B' isolation condenser condensate return valves. There has been a high frequency of failures of these Agastat electro-pneumatic time delay relays within the ICS. Most of the failures have been identified during surveillance activities that simulated high RPV pressure or low-low RPV water level conditions into the ICS logic to verify that the ICS actuation signals initiated.

The inspectors assessed Exelon's problem identification threshold, causal analyses, extent of condition reviews, compensatory actions, and the prioritization and timeliness of corrective actions to determine whether Exelon was appropriately identifying, characterizing, and correcting problems associated with this issue. The inspectors compared the actions taken to the requirements of Exelon's corrective action program and Title 10 of the Code of Federal Regulations (10 CFR) Part 50, Appendix B, Criterion XVI, Corrective Action. In addition, the inspectors reviewed documentation associated with this issue, including condition and failure analysis reports, and interviewed engineering personnel to assess the effectiveness of the implemented corrective actions and the actions planned to complete full resolution of the issue.

b. Findings and Observations

No findings were identified.

Because of repetitive failures of the Agastat electro-pneumatic time delay relays over the last several years within the ICS, Exelon implemented ECR OC 12-00438 to replace the existing Agastat relays with Allen-Bradley electronic time delay relays. Exelon also uses this type of Allen-Bradley relay within the ICS High Energy Line Break circuitry and these relays have been very reliable. Also, an Electric Power Research Institute (EPRI)

Control Relays Aging Management Guideline Technical Report was published in 2011 that acknowledged the high failure frequency for this type of Agastat relay and provided a suitable replacement relay. Exelon used this guidance to install the recommended replacement relay into the ICS during their 2012 refueling outage.

The inspectors determined that Exelon's overall response to the issue was commensurate with the safety significance, was timely, and the actions taken and planned were reasonable to resolve the relay failures within the ICS.

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

Main article: IP 71153

.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 contained in IMC 0309, "Reactive Inspection Decision Basis for Reactors," for consideration of potential reactive inspection activities. The inspectors verified that Exelon properly reported the event in accordance with 10 CFR Parts 50.72 and 50.73. The inspectors reviewed Exelon's follow-up actions related to the event to assure that Exelon implemented appropriate corrective actions commensurate with their safety significance.

Oyster Creek declared alert due to high intake level during Superstorm Sandy on October 29, 2012

Inspectors were stationed onsite for Superstorm Sandy from Sunday, October 28, 2012 through Tuesday, October 30, 2012. While onsite, inspectors provided continuous monitoring and evaluation of environmental conditions and Exelon's actions in response to the storm. The inspectors responded to the control room as warranted to provide event response and to monitor operator response to rising intake levels and restoration of equipment following a loss of offsite power. During the loss of offsite power, both of Exelon's self-contained air cooled emergency diesel generators, which are not cooled by service water, started as designed and provided power to vital equipment. At the height of the storm, a total of 39 of Oyster Creek's 42 emergency sirens were rendered inoperable due to power outages and storm damage. During the time that the sirens were not available, the route alerting method of emergency notification was available, if necessary. The inspectors noted that Exelon has committed to the State of New Jersey, to install new sirens with battery backup capability by June 1, 2013. Following testing and acceptance by the Federal Emergency Management Agency (FEMA), the sirens will be placed in service and the old sirens will be removed. Located at approximately 23 feet above sea level, the independent spent fuel storage facility was unaffected by the 7.4 foot storm surge. Reports and observations from the inspectors were a factor in the decision to dispatch a special inspection team to review Exelon's response to Superstorm Sandy. The special inspection was conducted from November 13 to 27, 2012. The results of the inspection are documented in Inspection Report

05000219/2012009 (ML13010A47).

b. Findings

No findings were identified.

4OA5 Other Activities

.1 Temporary Instruction 2515/187 - Inspection of Near-Term Task Force Recommendation 2.3 - Flooding Walkdowns

a. Inspection Scope

The inspectors verified that Exelon's walkdown packages contained the elements as specified in NEI 12-07 Walkdown Guidance document:

The inspectors accompanied Exelon on their walkdown of the turbine building basement and condenser bay and verified that Exelon confirmed the following flood protection features:

Visual inspection of the wall penetrations Available Physical margin Flood protection feature functionality was determined using visual observation The inspectors independently performed their walkdown and verified that the following flood protection feature was in place:

Emergency diesel generator building asphalt dike The inspectors verified that noncompliances with current licensing requirements, and issues identified in accordance with the 10 CFR 50.54(f) letter, Item 2.g of Enclosure 4, were entered into Exelon's corrective action program. In addition issues identified in response to Item 2.g that could challenge risk significant equipment and Exelon's ability to mitigate the consequences will be subject to additional NRC evaluation.

b. Findings

No findings or self-revealing findings were identified.

.2 Temporary Instruction 2515/188 - Inspection of Near-Term Task Force Recommendation 2.3 - Seismic Walkdowns

a. Inspection Scope

The inspectors accompanied Exelon on their seismic walkdowns of the 23 ft and 45 ft level of the Drywell on November 5, 2012 and verified that Exelon confirmed that the following seismic features associated with the inboard main steam isolation valve (V-1-7)and A, C, and E electromatic relief valves were free of potential adverse seismic

conditions (list the applicable seismic features which were verified):

Anchorage was free of bent, broken, missing or loose hardware Anchorage was free of corrosion that is more than mild surface oxidation Anchorage was free of visible cracks in the concrete near the anchors Anchorage configuration was consistent with plant documentation SSCs will not be damaged from impact by nearby equipment or structures Overhead equipment, distribution systems, ceiling tiles and lighting, and masonry block walls are secure and not likely to collapse onto the equipment Attached lines have adequate flexibility to avoid damage The area appears to be free of potentially adverse seismic interactions that could cause flooding or spray in the area The area appears to be free of potentially adverse seismic interactions that could cause a fire in the area The area appears to be free of potentially adverse seismic interactions associated with housekeeping practices, storage of portable equipment, and temporary installations (e.g., scaffolding, lead shielding)

The inspectors independently performed their walkdown and verified that the following SSCs were free of potential adverse seismic conditions:

"A" isolation condenser on August 22, 2012 Standby liquid control tank on August 22, 2012 Observations made during the walkdown that could not be determined to be acceptable were entered into Exelon's corrective action program for evaluation.

Additionally, inspectors verified that items that could allow the spent fuel pool to drain down rapidly were added to the seismic walkdown equipment list (SWEL) and these items were walked down by Exelon.

b. Findings

No findings were identified.

.3 Followup Inspection for Three or More Severity Level IV Traditional Enforcement Violations in the Same Area in a 12-Month Period (IP 92723)

a. Inspection Scope

The inspectors performed a follow-up inspection for three Severity Level (SL) IV Traditional Enforcement violations in the area of Impeding Regulatory Process that occurred in 2011. Two of the violations involved Operator Licensing medical issues and the third violation involved improper implementation of an Emergency Action Level bases change.

The objectives of the inspection were to determine whether Exelon:

Provided assurance that the causes of the SL IV Traditional Enforcement violations were understood; Provided assurance that the extent of condition and extent of cause of the SL IV Traditional Enforcement violations were identified; and Provided assurance that corrective actions for the SL IV Traditional Enforcement violations were sufficient to address the causes.

The inspectors reviewed Exelon's collective Common Cause Analysis evaluation for the violations, related condition reports, procedures, and relevant references. The inspectors also interviewed management and staff personnel who were familiar with the violations and participated in the evaluation or corrective actions.

Documents reviewed during the inspection are listed in the Attachment.

b. Findings and Observations

No findings were identified.

The inspectors concluded that Exelon completed an adequate Common Cause Analysis that used a systematic method to identify the causes of the Traditional Enforcement violations. Exelon considered the primary common cause to be inadequate individual accountability and questioning attitude associated with regulatory sensitive issues. Exelon's evaluation also considered two additional Traditional Enforcement violations that occurred outside of the 12-month period assessed by the inspection.

The inspectors determined that the station adequately assessed the extent of condition and extent of cause of the violations. The inspectors concluded that Exelon's corrective actions were sufficient to address the identified common cause and that the completed and planned corrective actions addressed the causes described in the evaluation.

.4 Operation of an ISFSI at Operating Plants (IP 60855)

a. Inspection Scope

The inspectors evaluated Exelon's activities related to long-term operation and monitoring of their Independent Spent Fuel Storage Installation (ISFSI), and verified that activities were being performed in accordance with the Certificate of Compliance (CoC), technical specifications (TS), regulations, and Exelon procedures.

The inspectors performed tours of the ISFSI pad to assess the material condition of the pad and the loaded horizontal storage modules (HSMs). The inspectors also verified that transient combustibles were not being stored on the ISFSI pad or in the vicinity of the HSMs. The inspectors confirmed vehicle entry onto the ISFSI pad was controlled in accordance with Exelon's procedures and verified that Exelon was appropriately performing daily HSM surveillances in accordance with TS requirements.

The inspectors interviewed reactor engineering personnel and reviewed Exelon's program associated with fuel characterization and selection for storage from the last ISFSI loading campaign in April/May 2012. The inspectors verified that the criteria meets the conditions for cask and canister use as specified in the CoC. The inspectors also confirmed that physical inventories were conducted annually and were maintained as required by the regulations.

The inspectors reviewed radiological records from the last ISFSI loading campaign to confirm that radiation and contamination levels measured on the casks were within limits specified by TS and consistent with values specified in the updated final safety analysis report (UFSAR). The inspectors reviewed radiation protection procedures and radiation work permits (RWPs) associated with ISFSI operations. The inspectors also reviewed annual environmental reports to verify that areas around the ISFSI pad and the ISFSI site boundary were within limits specified in 10 CFR Part 20 and 10 CFR Part 72.104.

The inspectors reviewed corrective action program condition reports (ARs), and the associated follow-up actions that were generated since Exelon's last loading campaign to ensure that issues were entered into the corrective action program, prioritized, and evaluated commensurate with their safety significance. The inspectors also reviewed Exelon's 10 CFR 72.48 screenings.

b. Findings

No findings were identified.

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

a. Inspection Scope

The inspectors reviewed the final report for the INPO plant assessment of Oyster Creek Nuclear Generating Station conducted in March 2012. The inspectors reviewed these

reports to ensure that any issues identified were consistent with NRC perspectives of Exelon performance and to determine if INPO identified any significant safety issues that required further NRC follow-up.

b. Findings

No findings were identified.

4OA6 Meetings, Including Exit

On January 22, 2013, the inspectors presented the inspection results to Russell Peak, Oyster Creek Plant Manager, and other members of the Oyster Creek Nuclear Generating Station staff. The inspectors verified that no proprietary information was retained by the inspectors or documented in this report.

4OA7 Licensee-Identified Violations

None ATTACHMENT:

SUPPLEMENTARY INFORMATION

KEY POINTS OF CONTACT

Licensee Personnel

G. Stathes, Site Vice-President

M. Massaro, Site Vice-President

R. Peak, Plant Manager

M. Ford, Director, Operations

B. Baker, Site Manager Reactor Services, Limerick

G. Young, Operations Training

G. Busch, ISFSI Project Manager

C. Holtzapple, SNM Coordinator

G. Malone, Director, Engineering

J. Dostal, Director, Maintenance

C. Symonds, Director, Training

D. DiCello, Director, Work Management

J. Barstow, Manager, Regulatory Assurance

T. Farenga, Radiation Protection Manager

R. Larzo, Engineering Manager

V. Samlal, DSC Engineer

J. Murphy, Rad Engineering Manager

J. McCarthy, Senior Radiation Protection Analyst

D. Chernesky, Manager, Environmental/Chemistry

T. Keenan, Manager, Site Security

W. Trombley, Senior Manager, Plant Engineering

H. Ray, Senior Manager, Design Engineering

G. Flesher, Shift Operations Superintendent

J. Chrisley, Regulatory Assurance Specialist

D. Moore, Regulatory Assurance Specialist

J. Kerr, Regulatory Assurance Specialist

K. Wolf, RP Technical Manager

S. Schwartz, Senior Staff Engineer

P. Procacci, Electrical Design Engineer

C. Coyle, HVAC Design Engineer

I. Abelev, HVAC System Engineer

LIST OF ITEMS OPENED, CLOSED, DISCUSSED, AND UPDATED

Opened/Closed

05000219/2012005-01 NCV Failure to Follow Inspection and Torquing of Bolted Connection Procedure (Section 1R15)

05000219/2012005-02 NCV Inadequate Application of Strippable Coating to the Refueling Cavity Liner and the Failure to

Configure a Valve in the Leakage Collection System Resulting in Increased Potential for

Corrosion on the Exterior of the Drywell Liner

Surface in the Sand Beds (Section 1R08)

A- 2 Attachment

LIST OF DOCUMENTS REVIEWED

Section 1R01: Adverse Weather Protection

Procedures

OP-OC-108-109-1001, Preparation for Severe Weather T&RM for Oyster Creek, Revision 16

OP-AA-108-111-1001, Severe Weather and Natural Disaster Guidelines, Revision 9

WC-AA-107, Seasonal Readiness, Revision 11

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

ABN-31, High Winds, Revision 18

ABN-32, Abnormal Intake Level, Revision 19

Condition Reports

1366669

1447243

1446831

1441562

1439194

1425728

1373418

Maintenance Orders/Work Orders

A2291958 A2291428 A2291836 A2291956 A2299647 A2292220

A2292281 A2291037 A2277901

Miscellaneous

Oyster Creek Winter Execution Morning Plant Status Report, dated December 14, 2012

Oyster Creek Certification of 2012-2013 Winter Readiness, dated November 15, 2012

Section 1R04: Equipment Alignment

Procedures

330, Standby Gas Treatment System, Revision 54

2, Service Water Service, Revision 80

341, EDG Operation, Revision 99 302.1, Control Rod Drive System, Revision 111

OP-OC-108-103-1003, Oyster Creek Locked Equipment and Key Control, Revision 20

Drawings

GE 237E487, Control Rod Drive System Flow Diagram, Revision 63 GU 3E-822-21-1000, Standby Gas Treatment, Revision 10

Maintenance Orders/Work Orders

C2027733

Section 1R05: Fire Protection

Procedures

OP-OC-201-008-1012, Reactor Building (Drywell and Torus) (RB-FA-2), Revision 1

OP-OC-201-008-1030, Turbine Building (Condenser Bay) (TB-FZ-11E), Revision 0

OP-OC-201-008, Oyster Creek Pre-Fire Plans, Revision 13

Section 1R06: Flood Protection Measures

Procedures

ABN-18, Service Water Failure, Revision 16

A- 3

Attachment

ABN-20, TBCCW Failure Response, Revision 11

ABN-32, Abnormal Intake Level, Revision 19

OP-OC-201-008-1010, Reactor Building (CRD and Core Spray) (RB-FZ-1F3), Revision 0

OP-OC-201-008-1011, Reactor Building (Containment Spray) (RB-FZ-1F4), Revision 0

Miscellaneous

Internal Flood Evaluation Summary and Notebook: Oyster Creek Nuclear Generating Station, dated April 17, 2008 White Paper 28063-005, Design and Licensing Bases for Flooding at OCGS, dated August 29, 2007 Information Notice 2005-30, Safe Shutdown Potentially Challenged by Unanalyzed Internal Flooding Events and Inadequate Design

Section 1R08: In-Service Inspection

Procedures

205.95.0, Reactor Flood-up/Drain Down, Revision 20

205.94.0, RPV Flood-up Using Core Spray, Revision 12

RP-OC-6006, Reactor Cavity and Equipment Pit Leak Mitigation and Decontamination, Revision 2

ER-AA-335-002, Procedure Liquid Penetrant Examination, Revision 6

ER-AA-335-003, Procedure Magnetic Particle Examination, Revision 5

ER-AA-335-004, Ultrasonic Measurement Of Material Thickness and Interfering Conditions, Revision 16

ER-AA-335-014, Procedure

VT-1 Visual Examination, Revision 7

ER-AA-335-016, Procedure

VT-3 Visual Examination of Component Supports, Attachments and Interiors of Reactor Vessels, Revision 8

ER-AA-335-018, Visual Examination of ASME, Revision 8

IWE Class MC and Metallic Liners of IWL Class CC Components

ER-AA-335-002, Procedure Eddy Current Surface Examinations, Revision 1

GEH-PDI-UT-2, GE Hitachi Nuclear Energy PDI Generic Procedure for the Ultrasonic Examination of Austenitic Pipes, Revision 6

GEH-UT-601, GE Hitachi Nuclear Energy Pr ocedure For Ultrasonic Thickness Measurements for Flow Accelerated Corrosion (FAC), Version 6

Drawings

& Sketches Oyster Creek RPV MAP, 7/1/99

Dwg. E 232-565-5, Nozzle Details For General Electric Inc. Jersey Central - Reactor Vessel Structural Integrity Associates drawing 1200118.510, 11/12/12; N-9 Control Rod Drive Return

Nozzle Safe End, Pipe, And Elbow Full Structural Weld Overlay design (4 sheets), 11/14/12 (Nozzle N-9)

GE Dwg. 4066-4, 3/8/66, Reactor Building; Building Cross-section Details Exelon Nuclear Drawing, GE JC147434, Sheet 2 of 3, Revision 57; Sumps And Waste

Collection System, Flow Diagram

Exelon Nuclear Drawing,

GE 237E756, Sheet 1, Revision 53, Spent Fuel Pool Cooling,

Flow Diagram

Dwg 1200118.510 SIA dwg. Revision 4, 11/14/12

Final WSI Construction dwg. Contours

A- 4

Attachment

Condition Reports

(*NRC-identified)

1437583

1437716*

1437583

1388492

1144359

1436892

1437169

1436360

1436340

1141202

1137564

1279515

1286188

1241899

1155454

1145290

1451886*

1437716

25902

1388192

1418745

1418700

1435047

1431606

21211

1273404

1347421

1315262

1440116*

1437583

1301435

1417576

1403174

1435742

1433984

1432528

1432713

1432684

1432671

1430947

1435740

1145290

21211

1440116

1436892*

1440116*

1433984

1439117*

1438651

1438414

1438578

1436892 1444414

Maintenance Orders/Work Orders

R2076388 R2087028 R2046983 R2134869

C2023712

C2028889

C2028760

Miscellaneous

ASME Code, Appendix VIII, Supplement 10: Qualification Requirements For Dissimilar Metal Piping Welds Performance Demonstration Initiative (PDI), Guideline for Ultrasonic Examination of Corrosion Resistant Cladding (CRC),

PDI-GL-002, Revision B, 1/29/03 Exelon Nuclear Letter

RA-09-011, March 9, 2009; Subject: Submittal of Analytical Evaluation in Accordance with

IWB-3134(b) Electric Power Research Institute Report

IR-2008-340; Evaluation of Dissimilar Metal Weld Examinations Performed at Oyster Creek during Refueling Outage 22 (1R22) BWR Feedwater Nozzle And Control Rod Drive Return Line Nozzle Cracking: Resolution Of Generic Technical Activity A-10 (Technical Report) ASME Boiler and Pressure Vessel Code Case N-504-4, Alternative Rules for Repair of Classes 1, 2 and 3 Austenitic Stainless Steel Piping,Section XI, Division 1 Material Safety Data Sheet, Supermend Hardener, 3/4/11 (9 pages)

NRC Information Notice 2012-19: License Renewal Post-Approval Site Inspection Issues, October 23, 2012

ECR

OC 12-00540, N-9 Safe End and Pipe Weld Overlay (rejectable PT indications)

Specifications Specification

IS-328227-004, Specification for Oyster Creek, Functional Requirements for Drywell Containment Vessel Thickne ss Examinations, Revision 14A, 2009

Engineering Calculations & Evaluations Structural Integrity Associates, Inc. Calculation Package, File No.:1200118.310; Title: Weld Overlay Sizing for CRD Nozzle Safe End, Safe End-to-Pipe Weld, Pipe, and Pipe-to-Elbow Weld; Revision 1, 11/14/12 Structural Integrity Associates, Inc. Calculation Package, File No.:1200118.310; Title: Weld Overlay Sizing for CRD Nozzle Safe End, Safe End-to-Pipe Weld, Pipe, and Pipe-to-Elbow Weld; Revision 1, 11/14/12; Attachment 1; Assessment to Justify Startup

for N9 Nozzle, Safe End, Pipe and Elbow Weld Overlay Structural Integrity Associates, Inc. Calculation Package, File No.:1200118.310; Title: Weld Overlay Sizing for CRD Nozzle Safe End, Safe End-to-Pipe Weld, Pipe, and Pipe-to-Elbow Weld; Revision 1, 11/14/12; Attachment 2: Crack Growth Rate Evaluation for Stainless Steel Weld Overlay at Oyster Creek Engineering Evaluation for AR A2318125, Repair of N7B Flange, 11/26/12 Technical Evaluation 01432528.02, Evaluation of the Degradation of Coating found in Sandbed Attachment Bays - 2012, 12/19/12, 19 pages Technical Evaluation

01435740-04, Evaluation of 2012 Drywell Sandbed UT Data - External Data, 11/18/12, 4 pages

NDE Inspection Reports & Data Sheets Sand Bed Bay #1, Report 1R24-LRA-043, ASME IWE (CLASS MC) Containment and IWL (CLASS CC) Metallic Liner Visual Exam and NDE Report, 11/17/12 (25 pages), (VT, UT) Sand Bed Bay #3, Report 1R24-LRA-050, ASME IWE (CLASS MC) Containment and IWL (CLASS CC) Metallic Liner Visual Exam and NDE Report, 11/17/12 (64 pages), (VT, UT) Sand Bed Bay #5, Report 1R24-LRA-037, ASME IWE (CLASS MC) Containment and IWL (CLASS CC) Metallic Liner Visual Exam and NDE Report, 11/17/12 (8 pages), (VT, UT) Sand Bed Bay #7, Report 1R24-LRA-040, ASME IWE (CLASS MC) Containment and IWL (CLASS CC) Metallic Liner Visual Exam and NDE Report, 11/17/12 (50 pages), (VT, UT) Sand Bed Bay #9, Report 1R24-LRA-032, ASME IWE (CLASS MC) Containment and IWL (CLASS CC) Metallic Liner Visual Exam and NDE Report, 11/17/12 (22 pages), (VT, UT) Sand Bed Bay #11, Report 1R24-LRA-030, ASME IWE (CLASS MC) Containment and IWL (CLASS CC) Metallic Liner Visual Exam and NDE Report, 11/19/12 (85 pages), (VT, UT) Sand Bed Bay #13, Report 1R24-LRA-009, ASME IWE (CLASS MC) Containment and IWL (CLASS CC) Metallic Liner Visual Exam and NDE Report, 11/18/12 (64 pages), (VT, UT) Sand Bed Bay #15, Report 1R24-LRA-066, ASME IWE (CLASS MC) Containment and IWL (CLASS CC) Metallic Liner Visual Exam and NDE Report, 11/17/12 (23 pages), (VT, UT) Sand Bed Bay #17, Report 1R24-LRA-048, ASME IWE (CLASS MC) Containment and IWL (CLASS CC) Metallic Liner Visual Exam and NDE Report, 11/17/12 (22 pages), (VT, UT) Sand Bed Bay #19, Report 1R24-LRA-046, ASME IWE (CLASS MC) Containment and IWL (CLASS CC) Metallic Liner Visual Exam and NDE Report, 11/17/12 (32 pages), (VT, UT) Report 1R24-047, Examination Summary Sheet, Component ID: 422-1013, Support (RF-2-28), VT, 11/7/12 (VT) Report 1R24-128, Examination Summary Sheet, Component ID: NR02 4-565A (N1A), N1A Recirc Outlet Nozzle Safe End, 11/4/12 (No change from 2008, rejectable indication in

2008) (UT) GE Hitachi, Indication Notification Report (INR) OC1R24

IVVI-12-01 SD Bank 1 Horizontal H04

ID, 5 pages, 10/26/12 (VT) GE Hitachi, INR OC1R24

IVVI-12-02 SD Drain Channel Weld V19 ID, 3 pages, 10/26/12 (VT)

GE Hitachi, INR OC1R24

IVVI-12-03 SD Drain Channel Weld V07 ID, 5 pages, 10/27/12 (VT)

GE Hitachi, INR OC1R24

IVVI-12-04 SD Drain Channel Weld V03 ID, 2 pages, 10/27/12 (VT)

GE Hitachi, INR OC1R24

IVVI-12-05 SD Center Baffle Plate, 4 pages, 10/26/12 (VT) GE Hitachi, INR OC1R24

IVVI-12-06

SD 50 degree HAD Swing Bar Stop Block, 4 pages, 10/26/12 (VT) GE Hitachi, INR OC1R24

IVVI-12-07

SD 135 degree Lifting Rod Lock Collar, 3 pages, 10/26/12 (VT) GE Hitachi, INR OC1R24

IVVI-12-08

SD 130 degree HAD Swing Bar Stop Block & Jacking Bolt,

4 pages, 10/26/12 (VT) GE Hitachi, INR OC1R24

IVVI-12-09 SD Tie Bar N-1 Lower, 4 pages, 10/26/12 (VT)

GE Hitachi, INR OC1R24

IVVI-12-10 SD Tie Bar K-1 Lower, 2 pages, 10/26/12 (VT)

GE Hitachi, INR OC1R24

IVVI-12-11 SD Tie Bar N, 6 pages, 10/26/12 (VT)

GE Hitachi, INR OC1R24

IVVI-12-12 SD Tie Bar C-1 Lower, 4 pages, 10/27/12 (VT)

GE Hitachi, INR OC1R24

IVVI-12-13 SD Tie Bar B-1 Lower, 2 pages, 10/27/12 (VT) GE Hitachi, INR OC1R24

IVVI-12-14

SD 310 degree HAD Swing Bar Stop Block, 2 pages, 10/27/12 (VT) GE Hitachi, INR OC1R24

IVVI-12-15

SD 45 degree Lifting Rod Lock Collar, 3 pages, 10/27/12 (VT)

Attachment GE Hitachi, INR OC1R24

IVVI-12-16 SD Drain Channel Weld V15 ID, 4 pages, 10/27/12 (VT) GE Hitachi, INR OC1R24

IVVI-12-17 SD Drain Channel Weld V08 ID, 3 pages, 10/27/12 (VT)

GE Hitachi, INR OC1R24

IVVI-12-18 SD Drain Channel Weld V16 ID, 4 pages, 10/27/12 (VT) GE Hitachi, INR OC1R24

IVVI-12-19 Fuel Support Casting 34-35 FME, 4 pages, 11/05/12 (VT)

VT-2 Visual Examination NDE Sheet, Report No. R2143786, N7B flange, Post Repair Test During Plant Operational Pressure Test, 12/4/12 (VT) GE Hitachi, Examination Summary Sheet, Report No.: 1R24-209, Component ID: NC-4-

0001AR1, N9 Weld Overlay, 11/29/12, 70 pages

GE Hitachi, Austenitic Piping 1.0T Flaw Ev aluation Sheet, Oyster Creek, Weld ID:

NC-4-0001AR1, Indication 11 WSI Nonconformance Report 12-151, 11/20/12, 16 pages

WSI Nonconformance Report 12-152, 11/20/12, 15 pages

WSI Nonconformance Report 12-152, Attachment 1, 11/20/12

Liquid Penetrant Inspection Report No.: N9-PT-08, 11/25/12 (LP)

Program Health Reports

OYSTER CREEK Inservice Inspection (ISI) Program Health Report, 3

rd Quarter 2012

NDE Inspector Certifications

25 0977 1079

Section 1R11: Licensed Operator Requalification Program

Procedures

2612.885.0.0911A, Oyster Creek Station Licensed Operator Requal Training Simulator Exercise

Guide, Revision 2 201, Plant Startup, Revision 82

2.1, Power Operations, Revision 132

203, Plant Shutdown, Revision 66

25.4.001, Turbine Over Speed Test and Calibration, Revision 18

OP-AB-300-1001, BWR Control Rod Movement Requirements, Revision 7

OP-AB-300-1003, BWR Reactivity Maneuver Guidance, Revision 8

OP-AA-108-108, Unit Restart Review, Revision 12

OP-AA-108-110, Evaluation of Special Tests or Evolutions, Revision 2

OP-AA-106-101, Significant Event Notification and Reporting, Revision 15

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-310-1002, Maintenance Rule Functions - Safety Significance Classification, Revision 3

ER-AA-310-1006, Maintenance Rule Expert Panel Roles and Responsibilities, Revision 4

330, Standby Gas Treatment System, Revision 54

117.3, Alternate AC System Reliability Monitoring, Revision 4

Drawings

BR 2011, Reactor Building Ventilation Flow Diagram, Revision 62 GU 3E-822-21-1000, Standby Gas Treatment, Revision 10

Attachment

Calculations

C-1302-822-5350-030, OC Reactor Building Diff Press System Alarm Setpoint Calculation, Revision 0

Condition Reports

25935

1397342

1139347

1143867

1155922

1439089

1433118

1386338

1425712

Miscellaneous

OCMM-408808-001, Reactor Building Differential Pressure Indication System Modification, Revision 0 Maintenance Rule Scope and Performance Monitoring Document, System 743 - Station Blackout (SBO) CT and Support System System 743 Station Blackout (SBO) CT and Suppor

t System Failure Report dated December 1, 2010 through December 17, 2012 NUMARC 93-01, Industry Guideline for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants, Revision 2 System 743 - Station Blackout (SBO) CT monthly report, July 2012

System 743 - Station Blackout (SBO) CT monthly report, August 2012 System 743 - Station Blackout (SBO) CT monthly report, September 2012 System 743 - Station Blackout (SBO) CT monthly report, October 2012

System 743 - Station Blackout (SBO) CT monthly report, November 2012

System 743 - Station Blackout (SBO) CT monthly report, March 2011

Scoping/Risk Significance Detailed Report for System 743 Station Blackout (SBO) CT and Support System Oyster Creek Operations Logs, September 1, 2010 through December 17, 2012

Section 1R13: Maintenance Risk Assessments and Emergent Work Control

Procedures

WC-OC-101-1001, Online Risk Management and Assessment, Revision 9

OP-AA-108-117, Protected Equipment Program, Revision 2

ER-AA-600-1042, On-Line Risk Management, Revision 7

OU-OC-103-1001, Shutdown Safety Management Program, Revision 7

OP-OC-108-109-1001, Severe Weather Preparation, Revision 16

Condition Reports

1437620

1434584

1432438

Maintenance Orders/Work Orders

R2190214

Section 1R15: Operability Determinations and Functionality Assessments

Procedures

LS-AA-120, Issue Identification and Screening Process, Revision 10

OP-AA-108-115, Operability Determinations (CM-1), Revision 10

2, Service Water Service, Revision 80

ABN-31, High Winds, Revision 18

ABN-32, Abnormal Intake Level, Revision 19

2400-GMM-3900.52, Inspection and Torquing of Bolted Connections, Revision 7 2400-SMM-3219.02, Liquid Poison System Explosive Valve Maintenance, Revision 8

Attachment

Drawings

GE 148F723, Liquid Poison System Flow Diagram, Revision 39

Condition Reports

(*NRC-identified)

1069881

1444862*

1444861*

1417726*

1418103*

1442876

1186333

1176569

1431888

Maintenance Orders/Work Orders

R2190214 A2318262 R2179400

Section 1R18: Plant Modifications

Procedures

ABN-32, Abnormal Intake Level, Revision 18

ABN-32, Abnormal Intake Level, Revision 19

Condition Reports

(IRs)

1434076

Maintenance Orders/Work Orders

A2316198

Miscellaneous

Oyster Creek Nuclear Generating Station UFSAR Section 9.2.1.1, "Service Water Systems", Revision 17

OC-2012-S-0105, 50.59 Review, "Revision of

ABN-32 for shutdown of service water pumps when the water reaches 0.5 feet below the service water pump motors", Revision 0

ABN-32-IP-10/29/1012-01, Document Site Approval Form: "Abnormal Intake Level", dated October 29, 2012

EP-AA-1010, Table OCGS 3-2 OCGS EAL Technical Basis, Section HA4, "Natural or destructive phenomena affecting Vital Areas", Revision 6

EP-AA-1010, Table OCGS 3-2 OCGS EAL Technical Basis, Section HU4, "Natural or destructive phenomena affecting Protected Area", Revision 6

Section 1R19: Post-Maintenance Testing

Procedures

OP-MA-109-101, Clearance and Tagging, Revision 13

MA-AA-716-012, Post Maintenance Testing, Revision 17

607.4.017, Containment Spray and Emergency Service Water Pump System 2 Operability and Quarterly Inservice Test, Revision 31 2400-SMM-3900.04, System Pressure Test Procedure (ASME XI), Revision 9 665.5.003, Main Steam Isolation Valve Leak rate Test, Revision 43

ER-AA-380, Primary Containment Leakrate Testing Program, Revision 9

MA-AA-716-012, Post Maintenance Testing, Revision 17

Industry Guideline For Implementing Performance-Based Option of 10 CFR Part 50, Appendix

J,

NEI 94-01, Revision 2 2400-GMM-3921.52, Removal, Inspection and Installation of Mechanical Snubbers, Revision 12

SP-1302-52-045, Oyster Creek Specification for Requirements for Functional Testing of Snubbers, Revision 6

Attachment

Condition Reports

(*NRC-identified)

26259 *1431388

1439150

1438491

1438308

1440422

1442086

1429613

1432256

1437828

1439774

Maintenance Orders/Work Orders

C2027733

C2028734 R2179230 R2173669

C2028595

C2027126

R2116444 R2208902 R2136093 C2026522

Section 1R20: Refueling and Other Outage Activities

Procedures

201, Plant Start-up, Revision 82

205.95.0, Reactor Flood-up/Drain-down, Revision 20

233, Drywell Access and Control, Revision 70 302.2, Control Rod Drive Manual Control System, Revision 53 604.1.005, Torus to Drywell Vacuum Breaker, Mechanical Surveillance and Limit Switch Calibration, Revision 24

401.2, Nuclear Instrumentation SRM Channels Operation during Start-up, Revision 13

2.2, IRM Operation During Start-up, Revision 26 602.4.001, Nuclear Steam Supply System (NSSS) Leak Test, Revision 50 602.4.001, Nuclear Steam Supply System (NSSS) Leak Test, Revision 51

2.1, Power Operations, Revision 132

203, Plant Shutdown, Revision 66

25.4.001, Turbine Over Speed Test and Calibration, Revision 18

OP-AB-300-1001, BWR Control Rod Movement Requirements, Revision 7

OP-AB-300-1003, BWR Reactivity Maneuver Guidance, Revision 8

OP-AA-108-108, Unit Restart Review, Revision 12

OP-AA-108-110, Evaluation of Special Tests or Evolutions, Revision 2

OP-AA-106-101, Significant Event Notification and Reporting, Revision 15

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

Condition Reports

1437620

1444589

1444592

1445022

1445121

1445358

1445373

1445484

1445803

1445806

1445894

1445954

1446816

1446719

1446272

1445954

1445936

1444388

1441833

1441836

1441910

1441771

1433982

1434196

1438948

1441036

1441023

1441009

1441008

1440925

1440882

1440870

1439768

1440127

1439416

1439292

1439493

1439625

1439646

1439723

1439743

1439814

1440329

1440278

1440076

1440047

1440021

1427547

1438368

1438577

1437155

1430779

1430829

1430832

1430835

1430849

1430924

1430985

1431024

1431095

1431098

1431101

1431115

1437317

1437368

1435924

1435959

1435842

1433621

1433368

1429145

1435249

1435039

1434828

1434404

1433122

1434235

1434322

1434924

1432271

1432320

1432158

1434070

1431229

1431141

1431241

1431350

1431430

1431690

1431700

1431689

1431536

1431502

1430624

1430787

1430299

1430495

1430519

1430487

1429882

1429651

1429647

29643

1429641

1429640

1429638

1429637

1429634

29632

1429623

1429618

1429948

1430092

1430074

Attachment

1430006

1429973

1429471

1429399

1429447

1429275

29118

1431388

1439150

1438491

1438308

1440422

1447378

1434655

1440895

1445358

1445121

1444987

1444589

1444592

1442335

1442086

1442614

1442335

1442341

1442346

1441613

1441543

1441927

1441856

1440794

1440895

1440878

1439813

1439814

1438760

1430624

1328300

1436679

1436683

1436698

1436713

1437138

1437063

1436794

1436123

1436794

1432374

1434070

1431895

1430438

1430415

1430349

1430503

1430489

1430432

1430492

1429964

1429571

1429612

1431735

1431229

1431264

1430051

1430059

1429613

1430096

1431674

1431601

1431105

1431586

1431232

1432146

1431965

Maintenance Orders/Work Orders

C2026522

Miscellaneous

2.4.002, MSIV Closure and IST Test, performed 11/29/12 Clearance No.

12501578

NF-AB-720-F-1, Control Rod Sequence Review and Approval Sheet, dated 11/24/12

Section 1R22: Surveillance Testing

Procedure

602.4.002, MSIV Closure and IST Test, Revision 39 602.3.005, ADS Actuation Circuit Test and Calibration, Revision 31

636.4.002, Diesel Generator No. 2 Automatic Actuation Test, Revision 10

Condition Report

29613

1439748

1440804

1440808

1440820

1440828

1440837

Maintenance Orders/Work Orders

R2174290

Section 1EP2: Alert and Notification System Evaluation

Procedures

EP-MA-121-1002, Exelon East Alert Notification System (ANS) Program, Revision 8

EP-MA-121-1003, Exelon East ANS Siren Monitoring, Troubleshooting, and Testing ASC ANS

System, Revision 0

EP-MA-121-1004, Exelon East ANS Corrective Maintenance, Revision 5

EP-MA-121-1005, Exelon East ANS Preventive Maintenance Program, Revision 4

Miscellaneous

Oyster Creek Nuclear Plant Upgraded Public Alert and Notification System Report, dated March

2005 Consolidated Technical Review of Exelon East Updated Design Reports for Three Mile Island,

Peach Bottom, Limerick and Oyster Creek Stations

Attachment

Section 1EP3: Emergency Response Organization Staffing and Augmentation System

Procedures

EP-AA-100, Exelon Nuclear Standardized Radiological Emergency Plan, 6/20/2012

EP-AA-1010, Exelon Nuclear Radiological Em ergency Plan Annex for Oyster Creek

Station, Revision 4

EP-AA-1102, ERO Fundamentals, Revision 5

TQ-AA-113, ERO Training and Qualifications, Revision 20

Miscellaneous

Oyster Creek 2012 Station Off-hours Drive-in Augmentation Drill Report (2012-08), dated October 11, 2012 Oyster Creek Generating Station EP Full Scale Integrated Drill and Semi- Annual Health Physics (HP) Drill Report, Revision 1, dated August 17, 2012 Oyster Creek Generating Station Emergency Preparedness Full Scale Integrated Drill Report

(2011-02), dated March 23, 2011 ERO Call-in Augmentation Drill Results (2012-02), dated June 26, 2012

ERO Call-in Augmentation Drill Results (2012-04), dated March 20, 2012 ERO Call-in Augmentation Drill Results (2011-13), dated December 20, 2011 ERO Call-in Augmentation Drill Results (2011-07), dated September 24, 2011

ERO Call-in Augmentation Drill Results (2011-04), dated June 23, 2011

ERO Call-in Augmentation Drill Results (2010-11), dated December 7, 2010

ERO Call-in Augmentation Drill Results (2010-05), dated September 23, 2010 ERO Team Roster, dated 11/03/2012

ERO B-1 Table

Section 1EP5: Correction of Emergency Preparedness Weaknesses

Condition Reports

1012042

1308050

1159509

1328578

1433589

1257675

1305572

1268265

1382684

1343871

1408679

1433277

1054741

1048234

1012048

Miscellaneous

EP-MA-124-1001-F-02, TSC/OSC Equipment Test Software and Reference Document Inventory, Revision G, dated August 27, 2012

EP-MA-124-1001-F-04, Technical Support Center Inventory, Revision E, dated August 22, 2012

EP-MA-124-1001-F-04, Operations Support Center Inventory, Revision G, dated August 22, 2012

EP-MA-124-1001-F-10, Emergency Operations Facility Inventory, Revision G, dated August 23, 2012

EP-MA-124-1001-F-11, Emergency Operations Facility Equipment Test, Revision G, dated September 11, 2012

EP-MA-124-1001-F-02, TSC/OSC Equipment Test Software and Reference Document

Inventory, Revision F, dated May 30, 2012

EP-MA-124-1001-F-11, Emergency Facility Equipment Tests, Revision F, dated March 14, 2012

Event Summary Report of an Alert Declared at the Exelon Nuclear Oyster Creek Station, dated October 31, 2012 Oyster Creek Generating Station, 07/23/12, Notice of Unusual Event Report (2012-1), dated August 16, 2012 Oyster Creek Generating Station, 08/23/11, Notice of Unusual Event Report, Revision 1 (2011-1R1), dated September 21, 2011

Attachment Oyster Creek Generating Station, 12/01/10, Notice of Unusual Event Report (2010-1), dated December 29, 2010

NOSA-OYS-10-03, Emergency Preparedness Audit Report, Oyster Creek, April 19, 2010 - April

23, 2010

NOSA-OYS- 11-03, Emergency Preparedness Audit Report, Oyster Creek, April 18, 2011 - April 21, 2011

NOSA-OYS-12-03, Emergency Preparedness Audit Report, Oyster Creek, April 23, 2012 - April

27, 2012

NOSA-OYS-12-03, Emergency Preparedness NOS Objective Evidence Report, April 23, 2012 - April 27, 2012 Oyster Creek Station NRC Baseline Program Inspection Readiness Assessment, dated August

31, 2012 Evacuation Time Estimates for the Oyster Creek Plume Exposure Pathway Emergency

Planning Zone, dated October 2012

Section 2RSO1:

Radiological Hazard Assessment and Exposure Controls

Procedures

RP-AA-350, Personnel Contamination Monitoring Decontamination and Reporting, Revision 10

RP-AA-18, Radiological Posting and Labeling Program Description, Revision 1

RP-AA-376, Radiological Posting and Labeling and Markings, Revision 6

RP-AA-376-1001, Radiological Posting and Labeling and Markings Standard, Revision 6

RP-AA-300, Radiological Survey Program, Revision 10

RP-AA-302, Determination of Alpha Levels and Monitoring, Revision 4

RP-AA-403, Administration of the Radiation Work Permit Program, Revision 3

RP-AA-460, Controls for High and Locked High Radiation Area, Revision 23

RP-AA-460-001, Controls for Very High Radiation Areas, Revision 4

RP-AA-460-002, Additional High Radiation Exposure Controls, Revision 1

RP-AA-460-003, Access to

HRAS-LHRA in Response to a Potential or Actual Emergency,

Revision 2

RP-AA-500, Radioactive Material Control, Revision 14

RP-AA-503, Unconditional Release Survey Method, Revision 5

RP-AA-4005, Conduct of Radiation Protection Outage Readiness Assessment, Revision 1

Oyster Creek Station Procedure 233, Drywell Access and Control, Revision 68

Condition Reports

1430591

1429810

1430067

Miscellaneous

LS-AA-126-1005 Attachment 1 Check In Self Assessment

1363513 - Nuclear Regulatory Commission Outage HP Inspection, dated May 25, 2012 OCGS Radiological Survey No.

IAA-12-6285, Drywell 13' General Area, dated October 22, 2012

OCGS Radiological Survey No.

IAC-12-6281, Drywell 13' Under Vessel, dated October 22, 2012 OCGS Radiological Survey No.

IAA-12-6286, DW C Recirc Loop, dated October 22, 2012 OCGS Radiological Survey No.

IAA-12-6287, DW E Recirc Loop, dated October 22, 2012 OCGS Radiological Survey No.

RH3-12-6481,

RB 119' During Refueling, dated October 25, 2012 OCGS Radiation Work Permit No. 12-00425 1R24

RB 119' Cavity Coating and Decon Activities, dated June 2, 2011 OCGS Radiation Work Permit No. 12-00508 1R24 Drywell Scaffolding, dated June 2, 2011

Attachment OCGS Radiation Work Permit No. 12-00519 1R24 Drywell

ISI-IGSCC-FAC Inspections, dated June 2, 2011 OCGS Radiation Work Permit No. 12-00511 1R24 Drywell CRD Exchange and CRD Support

Work, dated June 2, 2011 OCGS Radiation Work Permit No. 12-00505 1R24 Outage Drywell Observations, Inspection, Operations, Services and RP, dated June 2, 2011

TQ-AA-160 Attachment 10 Supplemental Radiation Protection Technician Qualification Card,

LMS

ID 952397, dated September 8, 2012

TQ-AA-160 Attachment 10 Supplemental Radiation Protection Technician Qualification Card,

LMS

ID 034205, dated September 7, 2012

TQ-AA-160 Attachment 10 Supplemental Radiation Protection Technician Qualification Card,

LMS ID034653, dated October 15, 2012

TQ-AA-160 Attachment 10 Supplemental Radiation Protection Technician Qualification Card,

LMS ID033202, dated September 10, 2012

TQ-AA-160 Attachment 10 Supplemental Radiation Protection Technician Qualification Card,

LMS ID033203, dated September 8, 2012

TQ-AA-160 Attachment 10 Supplemental Radiation Protection Technician Qualification Card, LMS

ID 024832, dated September 10, 2012

Section 2RSO2:

Occupational ALARA Planning and Controls

Procedures

RP-AA-16, ALARA Program Description, Revision 0

RP-AA-400, ALARA Program, Revision 9

RP-AA-400-1001, Establishing Collective Radiation Exposure Annual Business Plan, Revision

RP-AA-400-1002, Dose Equalization, Revision 1

RP-AA-400-1003, Work Group Exposure Reduction Plan, Revision 0

RP-AA-400-1004, Emergent Dose Control and Authorization, Revision 4

RP-AA-400-1005, ALARA Suggestion Program, Revision 0

RP-AA-400-1006, Outage Exposure Estimating and Tracking, Revision 3

RP-AA-400-1007, Elevated Dose Rate Response Planning, Revision 0

RP-AA-400-1008, Exposure Goal Recovery Plans, Revision 0

RP-AA-400-1009, Remote Monitoring System, Revision 0

RP-AA-400-2000, Department Dose Zealot, Revision 0

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

RP-OC-402, Use of Temporary Shielding, Revision 0

CY-AB-120-1000 BWR Strategic Water Chemistry Plan, Revision 11

Condition Reports

21348

Miscellaneous

2012 Collective Dose Goals and Actual by Department

LS-AA-126-1005 Attachment 1 - Check In Self Assessment

1363513 - Nuclear Regulatory Commission Outage HP Inspection, dated May 25, 2012 OC Generating Station Radiation Protection 01R23 - 2010 Refueling Outage Report, dated February 25, 2011

RP-AA-400, Attachment 2 - SAC Agenda, dated October 24, 2012

RP-AA-401, Attachment 2 - ALARA Plan 2012-508 for 1R24 Drywell Scaffolding, dated October

25, 2012

RP-AA-401, Attachment 2 - ALARA Plan 2012-503 for 1R24 Drywell Under-vessel Maintenance Attachment

Activities, dated October 25, 2012

RP-AA-401, Attachment 2 - ALARA Plan 2012-402 for 1R24 Reactor Disassembly, Refuel, Inspections and Reassembly, dated October 25, 2012

RP-AA-401, Attachment 2 - ALARA Plan 2012-506 for 1R24 for Drywell Insulation Removal -

Replacement, dated October 25, 2012

RP-AA-401, Attachment 2 - ALARA Plan 2012-507 for 1R24 Drywell Shielding, dated October

25, 2012

RP-AA-401, Attachment 2 - ALARA Plan 2012-511 for 1R24 Drywell CRD Exchange and CRD

Support Work, dated October 25, 2012

RP-AA-401, Attachment 2 - ALARA Plan 2012-519 for 1R24 Drywell

ISI-IGSCC-FAC

Inspections, dated October 25, 2012

RP-AA-401, Attachment 2 - ALARA Plan 2012-245 for 1R24 Cavity Coating and Decontamination, dated October 25, 2012

Section 2RSO3:

In-Plant Airborne Radioactivity Control and Mitigation

Procedures

RP-AA-301, Radiological Air Sampling Program, Revision 5

RP-AA-700-1301, Calibration, Source Check, Operation and Set-up of the Eberline Beta Air

Monitor Model

AMS-4, Revision 0

RP-AA-825, Maintenance Care and Inspection of Respiratory Protective Equipment, Revision 5

RP-AA-13, Respiratory Protection Program Description, Revision 0

RP-AA-870-1002, Use of Vacuum Cleaners in Radiological Controlled Areas, Revision 3

RP-AA-870-1003, Testing Portable HEPA Filter Units, Revision 0

RP-AA-870-1001 Set-up and Operation of Portable Air Filtration Equipment, Revision 2 Station Procedure 329, Reactor Building Heating, Cooling and Ventilation System, Revision 62

Condition Reports

(IRs)

1430035

Miscellaneous

System Health Report for System 822 - Rx Building Ventilation, Quarter 3, 2012

RP-AA-301, Attachment - 2 Airborne Radioactivity Calculation Sheet, Sample # 12-1187, Drywell Initial Entry, dated October 22, 2012

RP-AA-301, Attachment - 2 Airborne Radioactivity Calculation Sheet, Sample # 12- 1188, Drywell Initial Entry, dated October 22, 2012

RP-AA-301, Attachment 2 - Airborne Radioactivity Calculation Sheet, Sample # 12-1191,

Drywell General Area, dated October 22, 2012

RP-AA-301, Attachment 2 - Airborne Radioactivity Calculation Sheet, Sample # 12-1207, Reactor Building 119' Head Removal, dated October 23, 2012

RP-AA-301, Attachment 2 - Airborne Radioactivity Calculation Sheet, Sample # 12-1239,

Reactor Building Cavity, dated October 23, 2012

RP-AA-870-1001 Attachment 3 - Sample HEPA Issue and Return Log, dated October 19, 2012

RP-AA-870-1002 Attachment 1 - HEPA Vacuum Issue Log, dated October 24, 2012

RP-AA-825-1013 Attachment 2 - 3M Air Mate Inspection and issue Log, dated October 25, 2012

Section 2RSO4:

Occupational Dose Assessment

Procedures

RP-AA-210, Dosimetry Issue, Usage and Control, Revision 22

RP-AA-210-1001, Dosimetry Logs and Forms, Revision 0

Attachment

RP-AA-210-1003, REMs Access Control System, Revision 0

RP-AA-220, Bioassay Program, Revision 8

RP-AA-221, Whole Body Count Data Review, Revision 1

RP-AA-222, Methods for Estimating Internal Exposure from In Vivo and In Vitro Bioassay Data,

Revision 3

RP-AA-250, External Dose Assessment from Contamination, Revision 0

RP-AA-270, Prenatal Radiation Exposure, Revision 6

RP-AA-350, Personnel Contamination Monitoring, Decontamination and Reporting, Revision 10

Condition Reports

1430594

1430382

1430412

1430110

Miscellaneous

Exelon Nuclear,

RS-05-165, Application to Use Weighting Factors for External Exposure, dated December 14, 2005

RP-AA-210-1001 Attachment - 13 Multiple Dosimetry EDE Evaluation Sheet for 1R24 Drywell

Under-vessel Maintenance Activities on Carousel, dated October 19, 2012

RP-AA-210-1001 Attachment - 13 Multiple Dosimetry EDE Evaluation Sheet for Drywell CRD

Exchange and Support Work at Carousel Level, dated October 19, 2012

RP-AA-210-1001 Attachment 3 - Multiple Dosimetry Issue log (Single Entry) for CRD Exchange,

EID# 5673, dated October 24, 2012

RP-AA-210-1001 Attachment 3 - Multiple Dosimetry Issue log (Single Entry) for CRD Exchange,

EID# 5945, dated October 24, 2012

RP-AA-210-1001 Attachment 3 - Multiple Dosimetry Issue log (Single Entry) for CRD Exchange,

EID# 5751, dated October 24, 2012

RP-AA-210-1001 Attachment 3 - Multiple Dosimetry Issue log (Single Entry) for CRD Exchange,

EID# 2568, dated October 24, 2012

RP-AA-203, Attachment 1 - Dose Control Level Extension Form, J. Morel, dated October 15, 2012

RP-AA-203, Attachment 1 - Dose Control Level Extension Form, M. Wilson, dated October 11, 2012

RP-AA-203, Attachment 1 - Dose Control Level Extension Form, J. Burgan, dated October 10, 2012

RP-AA-270, Attachment 3 - Declaration of Pregnancy for DPW #1, dated October 24, 2011

RP-AA-270, Attachment 4 - Embryo/Fetus Dose Report for DPW #1, dated October 24, 2011

RP-AA-270, Attachment 5 - DPW Secondary/Primary Dose Log for DPW #1, dated October 24, 2011

RP-AA-270, Attachment 2 - Declaration of Intent to Become Pregnant for DPW #2, dated May 3, 2012

RP-AA-270, Attachment 5 - DPW Secondary/Primary Dose Log for DPW #2, dated May 5, 2012

Section 4OA1: Performance Indicator Verification

Procedures

LS-AA-2001, Collecting and Reporting of NRC Performance Indicator Data, Revision 14

LS-AA-2200, Mitigating System Performance Index Data Acquisition and Reporting, Revision 5

LS-AA-2140, Monthly Data Elements for NRC Occupational Exposure Control Effectiveness, Revision 5

LS-AA-2150, Monthly Data Elements for NRC RETS/ODCM Radiological Effluent Occurrence, Revision 2

CY-OC-170-201, Compliance with Technical Specification 6.8.4 Radioactive Effluent Control Program, Revision 2

Attachment

Condition Reports

0430565

1430560

1359080

Miscellaneous

NEI 99-02, Regulatory Assessment Performance Indicator Guideline, Revision 6

Oyster Creek MSPI Basis Document Oyster Creek Unit 1 - 4Q2011 - 3Q2012 MSPI Data, December 17, 2012

Performance Indicator Data - 2

nd quarter 2011 to 2

nd quarter 2012

Section 4OA2: Problem Identification and Resolution

Procedures

ABN-19, RBCCW Failure Response, Revision 10

C-2-C, RB CCW ISOL, Revision 3 E-7-d, CCW Flow Lo A, Revision 1 E-7-f, CCW Flow Lo BA, Revision 1

OP-AA-102-102, General Area Checks and Operator Field Rounds, Revision 12

OP-AA-102-103, Operator Work-Around Program, Revision 3

OP-AA-102-103-1001, Operator Burden and Plant Significant Decisions Impact Assessment Program, Revision 4

OP-AA-108-101, Control of Equipment and System Status, Revision 10

OP-AA-115-101, Operator Aid Postings, Revision 2

OP-OC-102-106-1001, Control of Time Critical O

perator Actions at Oyster Creek, Revision 0

CC-AA-309-1012, 10 CFR Part 21 Technical Evaluations, Revision 2

651.4.002, Standby Gas Treatment System 10-Hour Run, Revision 5

ER-AA20, Equipment Reliability Program Description, Revision 3

ER-AA-2001, Plant Health Committee, Revision 16

ER-AA-2100, Equipment Reliability Performance Review & Analysis, Revision 1

ER-AA-10, Equipment Reliability Process Description, Revision 7

ER-AA-30, Integrated Equipment Reliability Long Term Planning Process Description,

Revision 2

LS-AA-120, Issue Identification and Screening Process, Revision 14

LS-AA-125-1001, Root Cause Investigation Report Content and Format, Revision 9

Drawings

BR 3029, Sht. 2, Emergency Condenser System Electrical Elementary Diagram, Revision 26

BR 3029, Sht. 2A, Emergency Condenser System Electrical Elementary Diagram, Revision 24

GE 148F262, Sht. 1, Emergency Condenser Flow Diagram, Revision 54

GE 148F712, Sht. 1, Reactor Vessel Level, Pressure, and Temperature Instruments, Revision 47

Calculations/Engineering Evaluation Reports

C-1302-211-E320-130, Isolation Condenser Time Delay Relays 6K9/10/11/12 Setpoint Uncertainty, Revision 0 ECR

OC 12-00438, Isolation Condenser System Relay Replacement, Revision 4

Condition Reports

(*NRC-identified)

1165919

1181834

1207106

1243864

1288256

1334733

1347525

1375260

1375960

1398230

1431041

1445823

0849990

0932736

1145063

1178900

1350115

1441225

1444319*

1233058

Attachment Maintenance Orders/Work Orders

C2020983

C2028359 R2141941 R2152212 R2156115 R2160693

R2164665 R2171247 R2180585 A2284829 A2255281 A2255277

A2285969

Miscellaneous

609.3.003, Isolation Condenser Automatic Actuation Sensor Calibration and Test, Rev. 49, Performed 3/29/10 609.3.003, Isolation Condenser Automatic Actuation Sensor Calibration and Test, Rev. 51, Performed 4/6/11, 4/5/12, and 4/12/12 609.3.113, Isolation Condenser Automatic Actuation Bistable Calibration and Test, Rev. 20, Performed 1/6/10, 2/3/10, and 6/14/10 609.3.113, Isolation Condenser Automatic Actuation Bistable Calibration and Test, Rev. 21, Performed 9/3/10 and 11/27/10

AR 01281400-01, Recurring Quarterly Operations Burden Review, dated December 19, 2011

AR 01317603-01, Recurring Quarterly Operations Burden Review, dated April 2, 2012

AR 01357660-01, Recurring Quarterly Operations Burden Review, dated July 1, 2012

AR 01392631-01, Recurring Quarterly Operations Burden Review, dated October 2, 2012

Abnormal Component Position Notebook, dated November 28, 2012 Adverse Condition Monitoring and Contingency Plan Notebook, dated November 28, 2012 Control Room Degraded Components Database, dated November 28, 2012

Disabled Alarms Database, dated November 28, 2012

Main Control Room Deficiencies Database, dated November 28, 2012

Main Control Room Distractions Database, dated November 28, 2012

Operator Aids Notebook, dated November 28, 2012 Operator Challenge Database, dated November 28, 2012 Operational and Technical Decision Making Process Notebook, dated November 28, 2012

Operator Work-Around Database, dated November 28, 2012

Temporary Modifications Notebook, dated November 28, 2012

01350115-05, Equipment Apparent Cause Report, dated 5/30/12

1022972, EPRI Plant Engineering: Control Relay Aging Management Guideline, dated April

2011

OYS-34497, Failure Analysis of a Time Delay Relay, dated March 13, 2009

OYS-36241, Fault Analysis of an Isolation Condenser Relay, dated March 1, 2011

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

Procedures

OP-OC-108-109-1001, Preparation for Severe Weather T&RM for Oyster Creek, Revision 16

OP-AA-108-111-1001, Severe Weather and Natural Disaster Guidelines, Revision 9

WC-AA-107, Seasonal Readiness, Revision 11

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

ABN-31, High Winds, Revision 18

ABN-32, Abnormal Intake Level, Revision 19

Section 4OA5: Other Activities

Procedures

NF-AA-60, Fuel Selection For Dry Cask Storage Process Description, Revision 0

NF-AA-300, Special Nuclear Material Control and Accountability, Revision 15

NF-AA-309, Fuel Move Sheet Cask 23, Attachment 2

Attachment

NF-AA-330, Special Nuclear Material Physical Inventories, Revision 11

NF-AA-620-1000, Classification of Fuel Assemblies for Dry Storage/Transport, Revision 2

NF-AB-624, BWR Fuel Selection and Documentation for NUHOMS Dry Cask Loading, Revision 0

NF-OC-300, Special Nuclear Material Control-Oyster Creek, Revision 14

OU-AA-630, Dry Cask Storage Program Implementation, Revision 0

OU-OC-641, Transporting and Loading of Transport Cask and Dry Shielded Canister, Revision 2

OU-OC-642, Dry Shielded Canister Welding, Vacuum Drying, and Helium Backfill, Revision 3

RP-OC-1001-04-1, Radiation Protection Calculation, Doses On-Site and to Members of the Public as a Result of the Independent Spent Fuel Storage Installation, Revision 2

LS-AA-125-1002, Common Cause Analysis Manual, Revision 7

TQ-AA-150, Operator Licensing Training, Revision 7

Drawings

3179, Miscellaneous Outdoor Facilities, Revision 9

3180-12, Miscellaneous Outdoor Facilities Sheet 1, dated November 23, 1966

Condition Reports

1352824

1347055

1363636

1380764

1092319

1180107

1192432

1193110

1220428

1288468

1324011

1357538

1377128

1422582

1415778

1406841

1410069

1404344

1405765

1382255

1382254

1382251

1382250

1382248

1401219

1407010

1406952

1406823

1405765

653489

1406089

1402045

1402027

1402009

1422582

Miscellaneous

OEDO Procedure 220, Coordination with the Institute of Nuclear Power Operations, Revision 1

2.48 Screening No. OC02011-S-0117

2.48 Screening No. OC02012-S-0022

2.48 Screening No. OC02012-S-0052

OCGS Radiological Survey,

YFS-12-02531, HSM #21

Oyster Creek ISFSI Fence Dosimeters 2011-2012

RP-AA-401 Attachment 2, ALARA Plan, 2012 Dry Cask Storage Campaign, Revision 13

RWP 01021, Rev. 0, "ISFSI Project, All Areas" Technical Specification Log Sheet Number 681.4.004 Attachment 1, Dry Fuel Storage, Revision 24 N-OC-ILT-12ILTSY, License Maintenance Training Oyster Creek Nuclear Generating Station UFSAR Section 2.4.2, Floods, Revision 16

Oyster Creek Nuclear Generating Station UFSAR Section 2.3.1, Regional Climatology, Revision 16 Oyster Creek Nuclear Generating Station UFSAR Section 3.4, Water Level (Flood) Design, Revision 14

NEI 12-07, Guidelines for Performing Verification Walkdowns of Plant Flood Protection Features, Revision 0-A Exelon letter, "Exelon Generation Company, LLC's 180-day Response to NRC Request for Information Pursuant to 10

CFR 50.54(f) Regarding the Flooding Aspects of Recommendation 2.3 of the Near-Term Task Force Review of Insights from the Fukushima Dai-ichi Accident," dated November 19, 2012

Attachment