IR 05000219/2014002
| ML14135A013 | |
| Person / Time | |
|---|---|
| Site: | Oyster Creek |
| Issue date: | 05/15/2014 |
| From: | Mangan K A NRC/RGN-I/DRP/PB6 |
| To: | Pacilio M J Exelon Generation Co, Exelon Nuclear |
| mangan, ka | |
| References | |
| IR-14-002 | |
| Download: ML14135A013 (34) | |
Text
May 15, 2014
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 NUCLEAR GENERATING STATION - NRC INTEGRATED INSPECTION REPORT 05000219/2014002
Dear Mr. Pacilio:
On March 31, 2014, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at your Oyster Creek Nuclear Generating Station. The enclosed inspection report documents the inspection results, which were discussed on April 24, 2014, with Mr. G. Stathes, Site Vice President, and other members of your staff. The inspection examined activities conducted under your license as they relate to safety and The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel. This report documents two violations of NRC requirements, both of which were of very low safety significance (Green). However, because of the very low safety significance, and because they are entered into your corrective action program, the NRC is treating these findings as non-cited violations, consistent with Section 2.3.2.a of the NRC Enforcement Policy. If you contest the non-cited violations in this report, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the Nuclear Regulatory Commission, ATTN.: Document Control Desk, Washington, DC 20555-0001; with copies to the Regional Administrator, Region I; the Director, Office of Enforcement, United States Nuclear Regulatory Commission, Washington, DC 20555-0001; and the NRC Resident Inspector at Oyster Creek Nuclear Generating Station. In addition, if you disagree with the cross-cutting aspect assigned to any finding, or a finding not associated with a regulatory requirement 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 Nuclear Generating Station. Additionally, as we informed you in the most recent NRC integrated inspection report, cross-cutting aspects identified in the last six months of 2013 using the previous terminology were being converted in accordance with the cross-reference in Inspection Manual Chapter 0310. Section 4OA5 of the enclosed report documents the conversion of these cross-cutting aspects which will be evaluated for cross-cutting themes and potential substantive cross-cutting issues in accordance with IMC 0305 starting with the 2014 mid-cycle assessment review. If you disagree with the cross-cutting aspect assigned, you should provide a response within 30 days of the date of this inspection report, with the basis for your disagreement, to the Regional Administrator, Region 1, and the NRC Resident Inspector at the Oyster Creek Nuclear Generating Station. In accordance with Title 10 of the Code of Federal Regulations s Access Management System (ADAMS). ADAMS is accessible from the NRC website at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).
Sincerely,
/RA/ Kevin A. Mangan, Acting Chief Reactor Projects Branch 6 Division of Reactor Projects Docket Nos.: 50-219 License Nos.: DPR-16 Enclosure: Inspection Report 05000219/2014002 w/Attachment: Supplementary Information cc w/encl: Distribution via ListServ
ML14135A013 SUNSI Review Non-Sensitive Sensitive Publicly Available Non-Publicly Available OFFICE RI/DRP RI/DRP RI/DRP NAME JKulp/via email LCline/LC KMangan/KAM DATE 05/14/14 05/14/14 05/14/14 1 Enclosure U.S. NUCLEAR REGULATORY COMMISSION REGION I Docket Nos.: 50-219 License Nos.: DPR-16 Report No.: 05000219/2014002 Licensee: Exelon Nuclear Facility: Oyster Creek Nuclear Generating Station Location: Forked River, New Jersey Dates: January 1 to March 31, 2014 Inspectors: J. Kulp, Senior Resident Inspector A. Patel, Resident Inspector B. Bollinger, Reactor Engineer (NSPDP) P. Kaufman, Senior Reactor Inspector T. Hedigan, Operations Engineer J. Furia, Senior Health Physicist S. Pindale, Senior Reactor Inspector E. Burket, Emergency Preparedness Inspector Approved By: K. Mangan, Acting Chief Reactor Projects Branch 6 Division of Reactor Projects 2 Enclosure
SUMMARY OF FINDINGS
IR 05000219/2014002; 01/01/2014 03/31/2014; Exelon Energy Company, LLC, Oyster Creek Generating Station; Risk Assessments, Problem Identification and Resolution This report covered a three-month period of inspection by resident inspectors and announced inspections performed by regional inspectors. Inspectors identified two findings of very low safety significance (Green), both of which are non-cited violations. The significance of most findings is indicated by their color (Green, White, Yellow, Red) using Inspection Manual Chapter -cutting aspects for the -for which the SDP does not apply may be Green, or be assigned a severity level after NRC nuclear power reactors is described in NUREG-5, dated February 2014.
Cornerstone: Initiating Events
- Green.
The inspectors identified a Green non-cited violation of 10 CFR Part 50.65(a)(4), because Exelon did not reassess and manage risk after the grid operator declared a maximum emergency generation action, prior to performing maintenance on the B control rod drive pump on January 30, 2014. The inspectors identified that Exelon assessment of risk was green; however, if the emergency generation action had been included in the assessment, the risk would have been yellow requiring Exelon to perform compensatory actions to limit the risk to the unit. Exelon entered this issue into their corrective action program as issue report 1614625. performing maintenance on the B control rod drive pump after the grid operator declared a maximum emergency generation was a performance deficiency that was reasonably it is associated with the configuration control attribute of the Mitigating Systems cornerstone and adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. The inspectors used NRC inspection manual chapter 0609, significance of this finding. The inspectors determined that the finding is of very low safety significance (Green). This finding has a cross-cutting aspect in the area of Human Performance because operators did not stop when faced with uncertain conditions and evaluate and manage risks before proceeding as scheduled. Specifically, the operators continued maintenance without reassessing risk after the inspectors questioned the rationale for not entering the grid emergency procedure [H.11]. (Section 1R13)
- Green.
A self-revealing Green non-cited violation of 10 CFR Part 50, Appendix B, Criterion XVI, "Corrective Action," was identified when the corrective action to prevent recurrence of a significant condition adverse to quality did not preclude repetition of the event. Specifically, Exelon generated a corrective action to prevent recurrence during a root cause evaluation for a reactor scram caused by spiking on intermediate range monitor nuclear instruments that occurred in May 2004. In October 2013 another scram caused by spiking on the intermediate range nuclear instrument occurred, which Exelon subsequently determined to be a repeat of the May 2004 event. Exelon entered this issue into their corrective action program as issue report 1567196. condition adverse to quality was a performance deficiency that was reasonably within iency is more than minor because it is associated with the equipment performance attribute of the Initiating Events cornerstone and adversely affected the cornerstone objective to limit the likelihood of events that upset plant stability and challenge critical safety functions during shutdown as well as power operations. The significance of this finding was determined using NRC IMC 0609, appendix A, exhibit 1. This finding screened as very low safety significance (Green), because the finding did not contribute to both the likelihood of a reactor trip and likelihood that mitigation equipment or functions would not be available. The finding does not have a cross cutting aspect as it is not reflective of current performance because the root cause and associated corrective actions to prevent reoccurrence were from 2004. (Section 4OA2)
Other Findings
None.
REPORT DETAILS
Summary of Plant Status Oyster Creek began the inspection period at 100 percent power and operated at full power throughout the inspection period.
REACTOR SAFETY
Cornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity
1R01 Adverse Weather Protection
.1 Readiness for Impending Adverse Weather Conditions
a. Inspection Scope
operator for the period January 3-4, 2014 and a winter storm warning issued by the National Weather Service for the period of January 2-3, 2014. The inspectors verified that Exelon implemented their cold weather procedures and that operators monitored plant equipment that could have been affected by the cold weather conditions. The inspectors performed walkdowns to verify that temperatures equipment and areas in the plant were maintained within procedural limits, and when necessary, compensatory actions were properly implemented in accordance with procedures. The inspectors also verified that Exelon properly implemented its adverse weather procedures and that operators reviewed applicable emergency procedure. The inspectors performed independent walkdowns of the site to verify the site was ready for the onset of adverse weather.
b. Findings
No findings were identified.
1R04 Equipment Alignment
.1 Partial System Walkdowns
a. Inspection Scope
The inspectors performed partial walkdowns of the following systems: B standby liquid control pump while A standby liquid control pump was out of service for planned maintenance on January 9, 2014 A, B, and D emergency service water pumps while C emergency service water pump was out of service for corrective maintenance on January 30, 2014 Core spray system I while core spray system II was out of service for surveillance testing on February 12, 2014 The inspectors selected these systems based on their risk-significance relative to the reactor safety cornerstones at the time they were inspected. The inspectors reviewed applicable operating procedures, system diagrams, the UFSAR, technical specifications, work orders, condition reports, and the impact of ongoing work activities on redundant trains of equipment in order to identify conditions that could have impacted system performance of their intended safety functions. The inspectors also performed field walkdowns of accessible portions of the systems to verify system components and support equipment were aligned correctly and were operable. The inspectors examined the material condition of the components and observed operating parameters of equipment to verify that there were no deficiencies. The inspectors also reviewed whether Exelon staff had properly identified equipment issues and entered them into the corrective action program for resolution with the appropriate significance characterization.
b. Findings
No findings were identified.
.2 Full System Walkdown
a. Inspection Scope
On March 27, 2014, the inspectors performed a complete system walkdown of accessible portions of the B isolation condenser 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, to assess the operability of support systems. The inspectors performed field walkdowns of accessible portions of the systems to verify system components and support equipment were aligned correctly and operable. The inspectors examined the material condition of the components and observed operating parameters of equipment to verify that there were no deficiencies. Additionally, the inspectors reviewed a sample of related condition reports and work orders to ensure Exelon appropriately evaluated and resolved any deficiencies.
b. Findings
No findings were identified.
1R05 Fire Protection
.1 Resident Inspector Quarterly Walkdowns
a. Inspection Scope
The inspectors conducted tours of the areas listed below to assess the material condition and operational status of fire protection features. The inspectors verified that Exelon controlled combustible materials and ignition sources in accordance with administrative procedures. The inspectors verified that fire protection and suppression equipment was available for use as specified in the area pre-fire plan, and passive fire barriers were maintained in good material condition. The inspectors also verified that station personnel implemented compensatory measures for out of service, degraded, or inoperable fire protection equipment, as applicable, in accordance with procedures.
Reactor building control rod drive pump room on January 27, 2014 Emergency diesel generator room 1 on January 27, 2014 A/B battery room on January 30, 2014 Intake structure on January 30, 3014 Reactor building northeast corner room on January 31, 2014
b. Findings
No findings were identified.
.2 Fire Protection Drill Observation
a. Inspection Scope
The inspectors observed a fire brigade drill scenario conducted on March 13, 2014, that involved a fire in the battery room of the Site Emergency Building. The inspectors evaluated the readiness of the plant fire brigade to fight fires. The inspectors verified that Exelon personnel identified deficiencies, openly discussed them in a self-critical manner at the debrief, and took appropriate corrective actions as required. The inspectors evaluated specific attributes as follows: Proper wearing of turnout gear and self-contained breathing apparatus Proper use and layout of fire hoses Employment of appropriate fire-fighting techniques Sufficient fire-fighting equipment brought to the scene Effectiveness of command and control Search for victims and propagation of the fire into other plant areas Smoke removal operations Utilization of pre-planned strategies Adherence to the pre-planned drill scenario Drill objectives met acti-fighting strategies.
b. Findings
No findings were identified.
1R07 Heat Sink Performance (711111.07A
1 sample)
a. Inspection Scope
The inspectors reviewed the containment spray system II heat exchangers to determine their readiness and availability to perform their safety functions. The inspectors reviewed the design basis for the components and verified Exelon maintained the commitments described in their NRC Generic Letter 89-13 response. The inspectors reviewed the results of previous inspections of the containment spray system II heat exchangers. The inspectors discussed the results of the most recent inspection with engineering staff and reviewed pictures of the as-found and as-left conditions. The inspectors verified that Exelon initiated appropriate corrective actions for identified deficiencies. The inspectors also verified that the number of tubes plugged within the heat exchanger did not exceed the maximum amount allowed by their analysis.
b. Findings
No findings were identified.
1R11 Licensed Operator Requalification Program
Quarterly Review of Licensed Operator Requalification Testing and Training
a. Inspection Scope
The inspectors observed licensed operator simulator training on March 4, 2014, which included a loss of B control rod drive pump and reactor building closed loop cooling water system and subsequent anticipated transient with a failure to scram.
The inspectors evaluated operator performance during the simulated event and verified completion of risk significant operator actions, including the use of abnormal and emergency operating procedures. The inspectors assessed the clarity and effectiveness of communications, implementation of actions in response to alarms and degrading plant conditions and the oversight and direction provided by the control room supervisor. The inspectors verified the accuracy and timeliness of the emergency classification made by the shift manager and the technical specification action statements entered by the shift technical advisor. Additionally, the inspectors assessed the ability of the crew and training staff to identify and document crew performance problems.
b. Findings
No findings were identified.
1R12 Maintenance Effectiveness
a. Inspection Scope
The inspectors reviewed the samples listed below to assess the effectiveness of maintenance activities on structure, system, or component performance and reliability. The inspectors reviewed system health reports, corrective action program documents, maintenance work orders, and maintenance rule basis documents to ensure that Exelon was identifying and properly evaluating performance problems within the scope of the maintenance rule. For each sample selected, the inspectors verified that the structure, system or, component was properly scoped into the maintenance rule in accordance with 10 CFR 50.65 and verified that the (a)(2) performance criteria established by Exelon staff was reasonable. As applicable, for a structure, system, or component classified as (a)(1), the inspectors assessed the adequacy of goals and corrective actions to return the structure, system, or component to (a)(2). Additionally, the inspectors ensured that Exelon staff was identifying and addressing common cause failures that occurred within and across maintenance rule system boundaries.
Average power range monitor power supply issues on January 30, 2014 Core monitoring system issues on February 18, 2014 Emergency service water pump breaker issues on March 17, 2014
c. Findings
No findings were identified.
1R13 Maintenance Risk Assessments and Emergent Work Control
a. Inspection Scope
The inspectors reviewed station evaluation and management of plant risk for the maintenance and emergent work activities listed below to verify that Exelon performed the appropriate risk assessments prior to removing equipment for work. The inspectors selected these activities based on potential risk significance relative to the reactor safety cornerstones. As applicable for each activity, the inspectors verified that Exelon personnel performed risk assessments as required by 10 CFR 50.65(a)(4) and that the assessments were accurate and complete. When Exelon performed emergent work, the inspectors verified that operations personnel promptly assessed and managed plant risk. The inspectors reviewed the scope of maintenance work and discussed the results of the risk assessment. The inspectors also reviewed the technical specification requirements and inspected portions of redundant safety systems, when applicable, to verify risk analysis assumptions were valid and applicable requirements were met.
A standby liquid control pump and A isolation condenser out of service for planned maintenance on January 9, 2014 Containment spray system II and reactor building closed cooling water pump 1-2 out of service for planned maintenance on January 16, 2014 B combustion turbine, B control rod pump, B battery charger, C emergency service water pump unavailable with declaration of a maximum emergency generation action on January 30, 2014 Reactor building closed cooling water system II and standby gas treatment system II out of service for planned maintenance on March 11, 2014
b. Findings
Introduction:
The inspectors identified a Green, non-cited violation of 10 CFR 50.65 (a)(resulted from proposed maintenance activities. Specifically, Exelon did not reassess and manage risk after the grid operator declared a maximum emergency generation action, prior to performing maintenance on the B control rod drive pump on January 30, 2014.
Description:
At 0551 on January 30, 2014, PJM Interconnection (PJM is the grid operator for Oyster Creek Generating Station) declared a maximum emergency generation action for the mid-Atlantic and Southern regions of the PJM Regional Transmission Organization. While performing their morning status review, the inspectors determined that the maximum emergency generation action was applicable to Oyster Creek. The inspectors subsequently asked the control room operators for the maximum emergency generation action declaration. Control room operators informed the inspectors that they were told by Exelon power team that the maximum emergency generation action was not applicable to Oyster Creek. The inspectors then asked the control room operators to determine the basis for that determination. Control room operators subsequently consulted with Exelon corporate personnel regarding the resident inspectors concern. At 0859, Exelon determined that maximum emergency generation action was applicable to the site and Oyster Creek entered their grid emergency procedure (ABN-60). Oyster Creek procedure ABN--AA-is performed for the emergent condition, and suspend maintenance, testing, and troubleshooting that may adversely affect electrical generation, or transmission system, and also requires that the risk of the scheduled on-line maintenance activities be continuously evaluated based on conditions such as power grid stability and weather forecast. Exelon risk analysis procedures consider a maximum emergency generation action to be a qualitative risk increase for a loss of offsite power (LOOP) caused by external events. The inspectors determined that Oyster Creek removed the B control rod drive pump from service at 0600 for planned maintenance and that risk for this maintenance had been assessed as part of the work management process. However, the inspectors found that the assessment did not take into account the maximum emergency generation action PJM declared at 0551. Therefore, Exelon did not assess the maintenance risk due to the emergent condition until 0859, three hours after the maximum emergency generation action was declared. Finally, the inspectors determined that the point of contact between the grid operator and the site control room is the Exelon power team. The Exelon power team is to inform the nuclear duty officer of any changes to the status of the grid who then informs the site control room of the change to grid conditions.
generation action but did not pass the information regarding the change in grid status to o perform an accurate risk assessment for the planned maintenance on the B control rod drive pump during a maximum emergency generation action. The inspectors noted that Oyster Creek exited the emergency generation action which resulted in plant risk being reduced to green and documented the late notification of a maximum emergency generation action in IR 1614625.
Analysisprior to performing maintenance on the B control rod drive pump after the grid operator declared a maximum emergency generation was a performance deficiency that was because it affected the configuration control attribute of the Mitigating Systems cornerstone and affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. Specifically, Exelon did not maximize the availability, reliability and capability mitigating systems prior to removing the control rod drive pump from service during a maximum emergency generation action grid emergency. Additionally, this issue is similar to example 7.f in inspection manual chapter 0612, appendix E, because the overall elevated plant risk placed the plant into a higher licensee-established risk category. cornerstones, attachment 4, table 3, paragraph 5.C, directs that if the finding affects the risk associated with performing maintenance activities under all plant operating or shutdown conditions in accordance with Baseline tion Manual Chapter 0609, Appendix K, the finding and calculated tool, and found the result to be less than 1E-6. The regional senior reactor analyst , SAPHIRE. The inspectors determined that because this finding is a 10 CFR 50.65(a)(4) performance issue associated with risk management actions only and the ICDP is not >1E-6, the finding is of very low safety significance (Green).
This finding has a cross-cutting aspect in the area of Human Performance because operators did not stop when faced with uncertain conditions and evaluate and manage risks before proceeding as scheduled. Specifically, the operators continued maintenance without reassessing risk after the inspectors questioned the rationale for not entering the grid emergency procedure [H.11]. Enforcementmanage the increase in risk that may result from the proposed Exelon procedure WC-AA-requirements of 10 CFR 50.65 (a)(4), requires Exelon to continuously evaluate the risk of the scheduled on-line maintenance activities based on conditions such as power grid stability. Contrary to the above, on January 30, 2014, between 0600 and 0906, Exelon did not adequately assess the increase in risk of scheduled on-line maintenance activities prior to proposed maintenance activities. Specifically, a risk assessment was not performed after the grid operator declared a maximum emergency generation action prior to removing the B control rod drive pump from service for maintenance. Compliance to the rule was restored when the action declaration ended. Because this action program as IR 1614625, this violation is being treated as a non-cited violation, consistent with the NRC Enforcement Policy. (NCV 05000219/2014002-01, 50.65 a(4) Risk Evaluation Not Promptly Performed during a Maximum Emergency Generation Action)
1R15 Operability Determinations and Functionality Assessments
a. Inspection Scope
The inspectors reviewed operability determinations for the following degraded or non-conforming conditions: B battery degraded due to low electrolyte cell temperature on January 10, 2014 Control rod 22-43 operability due to degraded control rod drive mechanism seal on January 20, 2014 C emergency service water pump operability after failure to start on January 29, 2014 B standby liquid control operability during low crankcase oil on February 11, 2014 B battery bus operability due to low voltage on February 21, 2014 B standby liquid control operability due to squib valve open alarm on March 6, 2014 Part 21 notification of degraded scram solenoid pilot valves on March 17, 2014 The inspectors selected these issues based on the risk significance of the associated components and systems. The inspectors evaluated the technical adequacy of the operability determinations to assess whether technical specification operability was properly justified and the subject component or system remained available such that no unrecognized increase in risk occurred. The inspectors compared the operability and design criteria in the appropriate sections of the technical specifications and UFSAR to Where compensatory measures were required to maintain operability, the inspectors determined whether the measures in place would function as intended and were properly controlled by Exelon. The inspectors determined, where appropriate, compliance with bounding limitations associated with the evaluations.
b. Findings
No findings were identified.
1R19 Post-Maintenance Testing
a. Inspection Scope
The inspectors reviewed the post-maintenance tests for the maintenance activities listed below to verify that procedures and test activities ensured system operability and functional capability. The inspectors reviewed the test procedure to verify that the procedure adequately tested the safety functions that may have been affected by the maintenance activity; that the acceptance criteria in the procedure was consistent with the information in the applicable licensing basis and/or design basis documents; and that the procedure had been properly reviewed and approved. The inspectors also witnessed the test or reviewed test data to verify that the test results adequately demonstrated restoration of the affected safety functions.
A standby liquid control system after planned maintenance on January 9, 2014 Containment spray system II after planned maintenance on January 14, 2014 D emergency service water pump after motor replacement on January 16, 2014 C emergency service water pump after internal breaker switch replacement on February 7, 2014 Standby gas treatments system I after planned maintenance on March 6, 2014 Reactor building closed loop cooling water heat exchanger 1-1 following cleaning on March 12, 2014
b. Findings
No findings were identified.
1R22 Surveillance Testing
a. Inspection Scope
The inspectors observed performance of surveillance tests and/or reviewed test data of selected risk-significant structures, systems, and components (SSCs) to assess whether test results satisfied technical specifications, the UFSAR, and Exelon procedure requirements. The inspectors verified that test acceptance criteria were clear; tests demonstrated operational readiness and were consistent with design documentation, test instrumentation had current calibrations and the range and accuracy for the application; tests were performed as written, and applicable test prerequisites were satisfied. Upon test completion, the inspectors considered whether the test results supported that equipment was capable of performing the required safety functions. The inspectors reviewed the following surveillance tests: Emergency diesel generator 1 load test on January 6, 2014 A isolation condenser valve operability and in-service test on January 6, 2014 Main steam isolation valve 10% closure test on January 16, 2014 Containment spray/emergency service water system II operability and in-service test on January 17, 2014 Unidentified leak rate verification on January 20, 2014 Core spray system II pump operability and quarterly in-service test on February 10, 2014 Reactor building to torus power vacuum breaker test and calibration on February 19, 2014 Electromatic relief valve pressure sensor test and calibration on February 19, 2014
b. Findings
No findings were identified. Cornerstone: Emergency Preparedness 1EP4 Emergency Action Level and Emergency Plan Changes (IP 71114.04 1 Sample)
a. Inspection Scope
Exelon implemented various changes to the Oyster Creek emergency action levels, emergency plan, and implementing procedures. Exelon had determined that, in accordance with 10 CFR 50.54(q)(3), any change made to the emergency action levels, emergency plan, and its lower-tier implementing procedures had not resulted in any reduction in effectiveness of the plan and the revised plan continued to meet the standards in 50.47(b) and the requirements of 10 CFR 50 Appendix E.
The inspectors performed an in-office review of all emergency action level and emergency plan changes submitted by Exelon as required by 10 CFR 50.54(q)(5), including the changes to lower-tier emergency plan implementing procedures, to evaluate for any potential reductions in effectiveness of the emergency plan. This review by the inspectors was not documented in an NRC safety evaluation report and does not constitute formal NRC approval of the changes. Therefore, these changes remain subject to future NRC inspection in their entirety. The requirements in 10 CFR 50.54(q) were used as reference criteria.
b. Findings
No findings were identified.
1EP6 Drill Evaluation
.1 Emergency Preparedness Drill Observation
a. Inspection Scope
The inspectors evaluated the conduct of a routine quarterly Exelon emergency drill on February 3, 2014 to identify any weaknesses or deficiencies in the classification, notification, and protective action recommendation development activities. The inspectors observed emergency response operations in the simulator and technical support center to determine whether the event classification, notifications and protective action recommendations were performed in accordance with procedures. The inspectors also attended the station drill critique to compare inspector observations whether the Exelon staff was properly identifying weaknesses and entering them into the corrective action program.
b. Findings
No findings were identified.
RADIATION SAFETY
===Cornerstone: Public Radiation Safety and Occupational Radiation Safety
2RS8 Radioactive Solid Waste Processing and Radioactive Material Handling, Storage, and Transportation
a. Inspection Scope
During the week of February 3-7, 2014, the inspectors verified the effectiveness of material. The inspectors used the requirements of 10 CFR Parts 20, 61, and 71; and licensee procedures required by the Technical Specifications/Process Control Program, as===
criteria for determining compliance. The inspectors reviewed the solid radioactive waste system description in the updated final safety analysis report, the process control program, and the recent radiological effluent release report for information on the types, amounts, and processing of radioactive waste. corrective actions of quality assurance audits performed for this area since the last inspection.
Radioactive Material Storage The inspectors inspected areas where containers of radioactive waste were stored to determine if the radioactive materials storage areas were controlled and posted as appropriate. The inspectors verified that the licensee had established a process for monitoring the impact of long-term storage (e.g., buildup of any gases produced by waste decomposition, chemical reactions, container deformation, loss of container integrity, or re-release of free-flowing water). The inspectors verified that there were no signs of swelling, leakage, or deformation. Radioactive Waste System Walkdown The inspectors walked down accessible portions of liquid and solid radioactive waste processing systems to verify and assess that the current system configuration and operation agree with the descriptions in the updated final safety analysis report, offsite dose calculation manual, and process control program. During the walkdown, the inspectors identified radioactive waste processing equipment that was not operational and/or was abandoned in place and verified that Exelon had established administrative and/or physical controls for the protection of personnel from unnecessary personnel exposure. The inspectors reviewed the adequacy of any changes made to the radioactive waste processing systems since the last inspection. The inspectors verified that changes from what was described in the updated final safety analysis report were reviewed and documented. The inspectors identified processes for transferring radioactive waste resin and/or sludge discharges into shipping/disposal containers. The inspectors verified that the waste stream mixing, sampling procedures and methodology for waste concentration averaging were consistent with the process control program and provided representative samples of the waste product for the purposes of waste classification. For those systems that provide tank recirculation, the inspectors verified that the tank recirculation procedure provided sufficient mixing. Finally, the inspectors verified that the Exelon process control program correctly described the current methods and procedures for dewatering waste.
Waste Characterization and Classification radiochemical sample analysis results were sufficient to support radioactive waste calculations to account for difficult-to-measure radionuclides was technically sound and based on current analyses. The inspectors assessed that changes to plant operational parameters were taken into account to maintain the validity of the waste stream composition data between the annual or biennial sample analysis update and when Exelon determined if waste shipments met applicable requirements. Finally, the inspectors verified that Exelon had established and maintained an adequate quality assurance program to ensure compliance with applicable waste classification and characterization requirements. Shipment Preparation The inspectors reviewed the records of shipment packaging, surveying, labeling, marking, placarding, vehicle checks, emergency instructions, disposal manifest, shipping papers provided to the driver, and Exelon documents for verification of shipment readiness to verify the requirements of any applicable transport cask certificate of compliance had been met. The inspectors assessed that the receiving licensee was authorized to receive the shipment packages. The inspectors evaluated if the shippers were knowledgeable of the shipping regulations and that shipping personnel demonstrated adequate skills to accomplish the package preparation requirements for training to personnel responsible for the conduct of radioactive waste processing and radioactive material shipment preparation activities. Shipping Records The inspectors identified non-excepted package shipment records and verified that the shipping documents indicate the proper shipper name; emergency response information; a 24-hour contact telephone number; accurate curie content and volume of material; and appropriate waste classification, transport index, and international shipping identification number. The inspectors verified that the shipment placarding was consistent with the information in the shipping documentation. Identification and Resolution of Problems The inspectors verified that problems associated with radioactive waste processing, handling, storage and transportation were being identified by Exelon at an appropriate threshold, were properly characterized and corrective actions for a selected sample of problems were appropriate.
b. Findings
No findings were identified.
OTHER ACTIVITIES
4OA2 Problem Identification and Resolution
.1 Routine Review of Problem Identification and Resolution Activities
a. Inspection Scope
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, performed 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.
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 indicate the existence of more significant safety issues. In this review, the inspectors reports written in the subject area as well completed surveillance frequency changes as permitted by the program. The inspectors also reviewed the specific condition reports to verify that Exelon was appropriately evaluating and trending potential adverse conditions itechnical specification surveillance frequency control program and associated implementing procedures to determine whether the program was consistent with industry standards.
b. Findings and Observations
No findings were identified. The inspectors reviewed a surveillance test interval change screening form associated with the control rod drive scram discharge instrument volume, which changed the scram discharge volume level instrument test from quarterly to annually. The inspectors noted the change properly considered prior test performance and associated results, vendor-specified maintenance, operating experience, and risk insights; and the inspectors concluded that the change was acceptable and in accordance with procedures. The inspectors also reviewed condition reports associated with surveillance frequencies and the governing administrative program and determined that there were no adverse trends in this area.
.3 Annual Sample: Loss of Vacuum Scram
a. Inspection Scope
A problem identification and resolution sample inspection was conducted for evaluation of an approximate one inch hole identifed on the B main condenser steam inlet stainless steel expansion joint bellows which caused a rapid loss of condenser vacuum during unit startup from a maintenance outage. Operators initiated the scram due to the rapid loss of condenser vacuum on October 6, 2013. The inspectors assessed problem identification threshold, apparent cause analyses, extent of condition reviews, and timeliness of corrective actions. The inspectors performed reviews of the documents listed in the Attachment to this report and interviewed engineering personnel to assess the effectiveness of the planned, scheduled, and completed corrective actions to resolve the identified component deficiency. Finally, the inspectors reviewed issue reports, system health reports, work orders, purchase orders, drawings, photographs, and procedures to determine if the nonconforming condition was appropriately identified, documented, characterized and Appendix B requirements.
b. Findings and Observations
No findings were identified. Exelon determined that the hole identifed on the B main condenser steam inlet expansion joint bellows was most likely caused by fatigue cracking of the stainless steel expansion bellows and also identified a contributing cause as impact damage at the hole location. The inspectors consider the cause to be plausible based on a review of photographs taken of the stainless steel steam inlet expansion bellows failure location. The inspectors determined that Exelon took acceptable immediate corrective action to perform a temporary leak repair of the expansion bellows to resolve the vacuum leak until a permanent replacement bellows could be procured and installed. Additionally Exelon, as part of the extent of condition reviews, inspected all similar expansion joint bellows with no deficiencies identified. The inspectors determined the planned program, refueling outage scope change request process, and work order process. The inspectors concluded that the corrective actions taken and planned should adequately resolve the main condenser expansion bellows issue.
.4 Annual Sample: Automatic Reactor Scram Caused By An Invalid Intermediate Range Monitor Signal
a. Inspection Scope
A problem identification and resolution sample inspection was conducted for evaluation of the root cause analysis that Exelon performed due to an automatic reactor scram on October 3, 2013. The scram was caused by an invalid intermediate range monitor scram signal.
The inspectors performed an in-depth review of the root cause evaluation and assessed the following attributes: operability of the intermediate range monitors, identification of the root and contributing causes, extent of condition reviews, and previous operating experience. The inspectors also assessed the timeliness of corrective actions and whether they will preclude repetition of the event. The inspectors performed reviews of the documents noted in the Attachment to this report and interviewed engineering personnel to assess the effectiveness of the planned, scheduled, and completed corrective actions to resolve the identified deficiencies.
b. Findings and Observations
Introduction.
A self-revealing Green non-cited violation of 10 CFR Part 50, Appendix B, Criterion XVI, "Corrective Action," was identified because corrective actions to prevent recurrence of a significant condition adverse to quality did not preclude repetition of the event. Specifically, Exelon generated corrective actions to prevent recurrence, following a root cause evaluation, for a May 2004 reactor scram that was caused by spiking on intermediate range monitor nuclear instruments. A similar event occurred in October 2013 which was determined to be a repeat of the May 2004 event.
Description.
The inspectors identified that in May 2004, Oyster Creek experienced a reactor scram during a planned plant shutdown at approximately 2 percent power. The scram occurred when the reactor protection system (RPS) processed a reactor scram signal from the intermediate range monitor channels. The scram signal occurred when operators moved the source range monitor detectors into the core. During subsequent troubleshooting activities, Exelon determined that excessive electrical noise spiking appeared on intermediate range monitor channels which caused the RPS scram signal.
Exelon performed a root cause evaluation of the event, documenting their conclusions in a root cause evaluation. The root cause of the event was determined to be spiking on the intermediate range monitor channels which was caused by electronic noise generated from the source range monitor center conductors. Exelon found that the noise was detected by the intermediate range monitors due to low insulation resistance to ground measurements on the intermediate range monitor cables. They determined this was caused by a combination of moisture intrusion and degradation of the cable connections. Exelon identified two corrective actions to prevent recurrence. The first corrective action was to provide training to electricians and instrument and control technicians on electrically induced noise. The second corrective action was to develop and perform a preventive maintenance action to test the nuclear instrument cabling for degradation prior to every controlled startup and shutdown. The inspectors determined that subsequent to the completion of the root cause evaluation, the system manager modified this corrective action by implementing a preventive maintenance action to test the nuclear instrument cabling only before shutting down for refueling outage and during start up after a refueling outage.
In NO-AA-echnical plant scram was reported to the NRC under 10 CFR Section 50.73(a)(2)(iv)(A) in Licensee Event Report (LER) ER 2004-003-00/01. The inspectors concluded that since the 2004 scram met the technical specification definition of a reportable event, it also ors then concluded that the corrective actions to prevent recurrence that were developed by the root cause analysis were meant to prevent recurrence of the root cause of the scram.
The inspectors noted that in October 2013 Oyster Creek experienced a reactor scram during a planned startup from maintenance outage 1M30. The reactor protection system processed a scram signal on intermediate range monitor channels while withdrawing the source range monitor detectors out of the core. During subsequent troubleshooting activities, Exelon determined that excessive electrical noise spiking appeared on intermediate range monitor channels when operators were moving source range monitor detector 22 into and out of the core. Exelon subsequently entered the issue into their corrective action program (Issue Report 1567196) and performed a root cause evaluation of the event which is documented in root cause evaluation 1567196-08, Start-up.corrective actions to address the noise susceptibility of the intermediate range monitor channels have been less than adequate. Exelon immediate corrective actions were to repair the source range instrument in order to remove the noise source. The inspectors reviewed the root cause evaluation and determined it to be reasonable.
Analysis.
The inspectors determined that not precluding repetition of a significant condition adverse to quability to foresee and correct. Specifically, the corrective actions to prevent recurrence of the May 2004 event were ineffective to preclude repetition of and resulted in a repeat event in October 2013. The inspectors determined that the performance deficiency is more than minor because it is associated with the equipment performance attribute of the initiating events cornerstone and adversely affected the cornerstone objective to limit the likelihood of events that upset plant stability and challenge critical safety functions Significance Determination Process for Findings At-Screeinitiator because it caused a reactor scram. Because the failure to properly ground the intermediate range monitors did not contribute to both the likelihood of a reactor trip and likelihood that mitigation equipment or functions would not be available, the violation screened as very low safety significance (Green), This finding does not have a cross cutting aspect due to it is not reflective of current performance. The decision to not test intermediate range monitors prior to every reactor startup was made in 2004. EnforcementIn the case of significant conditions adverse to quality, the measure shall assure that the cause of the condition is determined and corrective action taken to preclude repetition. event did not preclude repetition of the event as evidenced by a repeat event occurring in October 2013. Exelon immediate corrective actions were to repair the source range instrument in order to prevent recurrence. Because this issue is of very low safety significance (Green) and Exelon entered this issue into their corrective action program (Issue Report 1567196) this finding is being treated as an NCV consistent with the NRC Enforcement Policy. (NCV 05000336/2014002-02, Corrective Action to Prevent Recurrence Ineffective to Preclude Repetition of a Significant Condition Adverse to Quality) Observations The inspectors determined that the root cause evaluation for the October 2013 event was thorough and included considerations for extent of condition. The inspectors ermined that overall they were appropriate to adequately address the identified deficiencies. The inspectors noted the planned repairs of the intermediate range monitor cables are being appropriately tracked in management process and repair activities are planned during the 1R25 refueling outage.
4OA3 Follow-Up of Events and Notices of Enforcement Discretion
.1 (Closed) Licensee Event Report (LER) 05000219/2013-001-00/01: Automatic Reactor SCRAM due to an Invalid Intermediate Range Monitor (IRM) SCRAM Signal
On October 3, 2013, during a plant startup with the reactor critical and power in the intermediate range, an automatic reactor scram occurred due to an invalid (noise) intermediate range monitor scram signal processed on both reactor protection system trip systems. The scram was caused by both reactor protection system channels -13, 14, 17, and 18.
The root cause of the event was identified as the susceptibility of the intermediate range monitor channels to electrical noise due to low shield to ground insulation resistance. Contributing to the event was an internal fault of the source range monitor channel 22 detector which created a significant amount of noise which propagated onto the intermediate range monitor channels resulting in spiking. The source range monitor 22 detector was replaced in a subsequent maintenance outage on November 20, 2013. The root cause identified corrective actions to repair the intermediate range monitor insulation resistance. The inspectors did not identify any new issues during the review of the LER. One violation was identified and discussed in Section 4OA2.4 of this report. This LER is closed.
.2 (Closed) Licensee Event Report (LER) 05000219/2013-003-00: Secondary Containment Integrity Momentarily Declared Inoperable
On November 17, 2013, while transiting into the reactor building through the northwest air lock, an Exelon employee opened the outer door to enter the air lock before another employee, who was in the air lock, had finished closing the inner door. This resulted in both the inner and outer air lock doors being open at the same time during power operation. The employees reset the door interlock pin and shut the door, restoring secondary containment integrity after a period of approximately 10 seconds. Exelon entered this issue into their corrective action program and determined that secondary containment was inoperable. Exelon subsequently entered and exited the limiting condition for operation action statement for the period of time that both doors were open, as technical specification definition 1.14 and technical specification 3.5.B.1 require. Exelon subsequently replaced the door interlock mechanism and performed an extent of condition inspection on the other air lock doors.
The inspectors noted thaaccidental loss of secondary containment integrity, restore secondary containment doors in this scenario was accidental in nature and that secondary containment integrity was restored within the time restrictions imposed by technical specification 3.5.B.2. The inspectors determined that Exelon complied with their technical specifications and no violation of technical specification exists. The inspectors did not identify any violations new issues during the review of the LER. This LER is closed.
.3 (Closed) Licensee Event Report (LER) 05000219/2013-002-00: Manual Scram Due to Lowering Vacuum
On October 6, 2013, during a plant startup from maintenance outage and reactor power ascension at approximately 20% of rated thermal power, main condenser vacuum began to lower. As a result of degrading condenser vacuum operators inserted a manual reactor scram. Operations and maintenance personnel identified an approximate 1 inch hole on the B condenser steam inlet expansion joint bellows on the south side of B condenser. Exelon confirmed the hole to be an active leak and subsequently the source of condenser vacuum degradation. A temporary leak repair was performed on the expansion joint bellows. Exelon Power Labs determined that the hole was most likely caused by fatigue cracking of the stainless steel expansion joint bellows and a contributing cause was impact damage at the hole location. The inspectors did not identify any violations or new issues during the review of the LER. This LER is closed.
4OA5 Other Activities
.1 The table below provides a cross-reference from the 2013 and earlier findings and associated cross-cutting aspects to the new cross-cutting aspects resulting from the common language initiative.
These aspects and any others identified since January 2014 will be evaluated for cross-cutting themes and potential substantive cross-cutting issues in accordance with IMC 0305 starting with the 2014 mid-cycle assessment review. Finding Old Cross-Cutting Aspect New Cross-Cutting Aspect 05000219/2013004-01 P.1(c) P.2
.2 (Closed) URI 05000219/2013003-03, Difference In Interpretation Of Guidance Contained NEI 99-02 Submitted Into The Frequently Asked Question Process.
a. Inspection Scope
rd Quarter 2012) for Unplanned Power Changes per 7000 Critical Hours performance indicator excluded a downpower which the inspectors believed should have been reported as an Document 99-NEI 99-02, Chapter 1, General Reporting Guidance, states that if the NRC staff and the licensee cannot resolve an issue of interpretation or implementation of the guidance contained in NEI 99-02 the issue should be escalated to appropriate industry and NRC management using the frequently asked question (FAQ) process. As a result, the NRC opened an unresolved item (URI) to allow the issue to be addressed through the FAQ process and to determine whether a performance of the performance indicator data for Unplanned Power Changes per 7000 Critical Hours. On April 2, 2014, the FAQ was resolved by the NRC Reactor Oversight Process Working Group and Nuclear Energy Institute Reactor Oversight Process Task Force which determined that the downpower should have been reported under the Unplanned Power Changes per 7000 Critical Hours performance indicator for the 3rd quarter of 2012. The downpower is no longer relevant to the performance indicator calculation because the indicator only considers downpowers occurring in the previous four quarters. Additionally, the inspectors reviewed the relevant four quarters for which the downpower would have been considered and determined that counting this downpower would not have made the Unplanned Power Changes per 7000 Critical Hours performance indicator change from Green to White.
data for the 3rd However because this issue did not cause the Unplanned Power Changes per 7000 Critical Hours performance indicator to change from green to white, the violation is considered to be minor. This closes URI 05000219/2013003-03.
b. Findings
No findings were identified.
4OA6 Meetings, Including Exit
On April 24, 2014, the inspectors presented the inspection results to Mr. G. Stathes, Site Vice President, and other members of the Oyster Creek staff. The inspectors verified that no proprietary information was retained by the inspectors or documented in this report.
ATTACHMENT:
SUPPLEMENTARY INFORMATION
KEY POINTS OF CONTACT
Exelon Personnel
- G. Stathes, Site Vice-President
- R. Peak, Plant Manager
- M. Ford, Director, Operations
- G. Malone, Director, Engineering
- J. Dostal, Director, Maintenance
- C. Symonds, Director, Training
- M. Chanda, Emergency Preparedness Manager
- D. DiCello, Director, Work Management
- M. McKenna, Manager, Regulatory Assurance
- T. Farenga, Radiation Protection Manager
- J. Renda, Manager, Environmental/Chemistry
- T. Keenan, Manager, Site Security
- P. Bloss, Senior Manager, Plant Engineering
- H. Ray, Senior Manager, Design Engineering
- E. Swain, Shift Operations Superintendent
- J. Chrisley, Regulatory Assurance Specialist
- D. Moore, Regulatory Assurance Specialist
- K. Paez, Regulatory Assurance Specialist
LIST OF ITEMS OPENED, CLOSED, DISCUSSED, AND UPDATED
Opened/Closed
- 05000219/2014002-01 NCV Untimely Performance of a 50.65 a(4) Risk Evaluation during a Maximum Emergency Generation Action (Section 1R13)
- 05000219/2014002-02 NCV Corrective Action to Prevent Recurrence Ineffective to Preclude Repetition of a Significant Condition Adverse to Quality (Section 4OA2)
Closed
- 05000219/LER-2013-001-00/01 LER Automatic Reactor SCRAM due to an Invalid Intermediate Range Monitor (IRM) SCRAM Signal
- 05000219/LER-2013-002-00 LER Manual Scram Due to Lowering Vacuum (Section 4OA3)
- 05000219/LER-2013-003-00 LER Secondary Containment Integrity Momentarily Declared Inoperable (Section 4OA3)
- Attachment
- 05000219/FIN-2013003-03 URI Difference In Interpretation Of Guidance Contained NEI 99-02 Submitted Into The Frequently Asked Question Process (Section 4OA5)
LIST OF DOCUMENTS REVIEWED
Section 1R01: Adverse Weather Protection
Procedures
- OP-OC-108-109-1001, Severe Weather Preparation T&RM for Oyster Creek, Revision 24
- ABN-60, Grid Emergency, Revision 14
- OP-AA-108-111-1001, Severe Weather and Natural Disaster Guidelines, Revision 12
- OP-OC-108-109-1002, Cold Weather Freeze Inspections, Revision 4
Section 1R04: Equipment Alignment
Procedures
- 612.4.001, Standby Liquid Control Pump and Valve Operability and In-Service Test, Revision 45 607.4.014, Containment Spray and ESW System 1 Pump Operability, IST, and Containment Spray Pumps Trip, Revision 48 607.4.015, Containment Spray and ESW System 2 Pump Operability, IST, and Containment Spray Pumps Trip, Revision 42
- 308, Emergency Core Cooling System Operation, Revision 92 307, Isolation Condenser System, Revision 124
Condition Reports
- 1639421
- 1639050
Work Orders
- R2177069
Drawings
- GE 148F723, Liquid Poison System Flow Diagram, Revision 40
- BR 2005 Sheet 4, Emergency Service Water System Flow Diagram, Revision 86
- GE 148F262, Emergency Condenser Flow Diagram, Revision 55
- GE 885D781, Core Spray System Flow Diagram, Revision 73
Section 1R05: Fire Protection
Procedures
- OP-OC-201-008, Oyster Creek Pre-Fire Plans, Revision 17 101.2, Oyster Creek Site Fire Protection Program, Revision 70
- OP-OC-201-008-1010, Reactor Building CRD Pump Room, Revision 0
- OP-OC-201-008-1035, Emergency Diesel Generator Room #1, Revision 2
- OP-OC-201-008-
- OP-OC-201-008-1034, Intake Structure, Revision 1
- OP-OC-201-008-1011, Reactor Building Northeast Corner, Revision 0
- OP-OC-201-008-1043, Site Emergency Building, Revision 0
- OP-OC-201-008-1020, Cable Spreading Room, Revision 1
- Attachment
Condition Reports
- 1609107
- 1632800
- 1633052
- 1647143
Miscellaneous
- Doc No 990-1746, OCNGS Fire Hazard Analysis Report pages 7-21 to 7-23, Revision 17
- Doc No 990-1746, OCNGS Fire Hazard Analysis Report pages 7-113 to 7-116, Revision 17
- Fire Drill Record, dated March 13, 2014
Section 1R07: Heat Sink Performance
Procedures
- 607.4.017, Containment Spray and Emergency Service Water Pump System 2 Operability and
- Quarterly Inservice Test, Revision 36
- GL 89-13 Program Implementing Procedure, Revision 7
- ER-OC-340-1001, Oyster Creek Generic Letter 89-13 Program Basis Document, Revision 3
Calculations
- C-1302-241-E120-078, Containment Spray Heat Exchanger Performance Evaluation, Revision
- 0
- EXOC005-CALC-002, System Acceptance Criteria for Containment Spray and ESW Flow
- Rates, Revision 0
Work Orders
- R2229404
Drawings
- BR 2005, Sheet 4, Emergency Service Water System, Revision 86
- GE 148F740, Containment Spray System, Revision 44
Miscellaneous
- EPRI-NP-7552, Heat Exchanger Performance Monitoring Guidelines, dated December 1991
Section 1R11: Licensed Operator Requalification Program
Miscellaneous
- OBE 14-2.1, Oyster Creek Station Licensed Operator Requal Training Simulator Exercise
- Guide, Revision 0
Section 1R12: Maintenance Effectiveness
Procedures
- ER-AA-310, Implementation of the Maintenance Rule, Revision 9
- ER-AA-310-1001, Maintenance Rule Scoping, Revision 4
- ER-AA-310-1003, Maintenance Rule
- Performance Criteria Selection, Revision 4
- ER-AA-310-1005, Maintenance Rule
- Dispositioning between (A1) and (A2), Revision 6
Condition Reports
- 1568276
- 1511787
- 1588402
- 1561274
- 1567079
Miscellaneous
- Maintenance Rule Scoping Document, Revision 28
- Attachment
Section 1R13: Maintenance Risk Assessments and Emergent Work Control
Procedures
- ER-AA-600-1042, On-line Risk Management, Revision 8
- OP-AA-108-117, Protected Equipment Program, Revision 3
- WC-OC-101-1001, On-line Risk Management and Assessment, Revision 17
- OP-AA-108-107-1001, Station Response to Grid Capacity Conditions, Revision 4
- WC-AA-101, On-Line Work Control Process, Revision 20
- ABN-60, Grid Emergency, Revision 14 309.2, Reactor Building Closed Cooling Water System, Revision 91 330, Standby Gas Treatment System, Revision 56
Condition Reports
- 1391791
- 1390285
- 1389933
- 1422329
- 1557742
- 1557229
- 1614646
- 1390871
- 1614625
- 1614635
- 1615043
- 1615044
- 1537180
- 1537340
Miscellaneous
- Plant Status/Integrated Work Schedule for January 6, 2014 Plant Status/Integrated Work Schedule for January 13, 2014 Clearance tag log for January 16, 2014
- Oyster Creek Nuclear Generating Station Control Room Logs dated January 30, 2014 Oyster Creek Nuclear Generating Station Control Room Logs dated July 18, 2013
- Interconnect Emergency Message 85316 PJM Interconnect Emergency Message 77369 PJM Interconnect Emergency Message 88308 PJM Interconnect Emergency Message 84105 PJM Interconnect Emergency Message 84103 PJM Manual 13, Emergency Operations, Revision 55
Section 1R15: Operability Determinations and Functionality Assessments
Procedures
- 612.4.001, Standby Liquid Control Pump and Valve Operability and In-Service Test, Revision 46 RAP U7e, A-B Battery Room Airflo/Temp Lo, Revision 2 634.2.011, Main Station Battery Monthly Surveillance, Revision 11
- RAP-G2b, Squib Valve Open, Revision 0 2400-SMM-3219.02, Liquid Poison System Explosive Valve Maintenance, Revision 8
Condition Reports
- 1605236
- 1614019
- 1619313
- 1619800
- 1360867
- 1203285
- 1502012
- 1511787
- 1503270
- 1606613
- 1615414
- 1605236
- 1615373
- 1616903
- 1613679
- 1610198
- 1624571
- 1624338
- 1632773
- 1628754
Work Orders
- C2030884 R2233196
- Attachment
Miscellaneous
- VM-OC-5934, Instructions for Liquid Poison Pumps, Revision 3
Section 1R19: Post-Maintenance Testing
Procedures
- MA-AA-716-012, Post Maintenance Testing, Revision 19
- 612.4.011, Standby Liquid Control Pump and Valve Operability and In-service Test, Revision 45 607.4.017, Containment Spray and Emergency Service Water Pump System 2 Operability and
- Quarterly In-service Test, Revision 36 607.4.009, Containment Spray System 1 and System 2 IST Valve Position Check, Revision 8 310, Containment Spray System Operation, Revision 106
- 607.4.005, Containment Spray and Emergency Service Water Pump System 2 Operability and
- Comprehensive/Preservice/Post-Maintenance Inservice Test, Revision 76 330, Standby Gas Treatment System, Revision 56
- Issue Report
- 1614019
- 1614653
- 1614244
- 1360867
- 1203285
- 1502012
- 1511787
- 1503270
Work Orders
- R2177069 R2195669 R2196266 R2195670
- C2030884 R2233196
- C2031608 R2217953 R2114216
Section 1R22: Surveillance Testing
Procedures
- 609.4.001, Isolation Condenser Valve Operability and In Service Test, Revision 77 636.4.003, Diesel Generator #1 Load Test, Revision 97
- 602.4.004, Main Steam Isolation Valve 10% Closure Test, Revision 23
- 607.4.017, Containment Spray and Emergency Service Water Pump System 2 Operability and Quarterly In-Service Test, Revision 36
- 610.4.022, Core Spray System 2 Pump Operability and Quarterly In-Service Test, Revision 27 604.3.001, Reactor Building to Torus Power Vacuum Breaker Test and Calibration, Revision 42 602.3.004, Electromatic Relief Valve Pressure Sensor Test and Calibration, Revision 53 420, Instrumentation Setpoints, Revision 12
- ER-AB-331-1006, BWR Reactor Coolant System Leakage Monitoring and Action Plan, Revision 2
Calculations
- C-1302-153-5450-083, Evaluation of Isolation Condenser MOV Gear Modification Impact on
- C-1302-622-5350-017, RB to Torus Vacuum Breaker Differential Pressure Switch Errors (DPS-0066A & B), Revision 4
Work Orders
- R2232281 R2231611 R2232176 R2229404 R2233561 R2220103 R2234410
Condition Reports
- 1608808
- 1610198
- 1613679
- Attachment
Drawings
- GE 885D781, Core Spray System Flow Diagram, Revision 71
Miscellaneous
- OC 07-00647-000, Revise UFSAR to Add Reference to Table 6.3-1, Revision 0
- SE-328312-003,
- GL 89-10 Motor Operated Valve Modification, Revision 2
Section 1EP4: Emergency Action Level and Emergency Plan Changes
Procedures
- EP-AA-114, Notifications, Revision 12
- EP-MA-114-100, Mid-Atlantic State/Local Notifications, Revision 20
Section 1EP6: Drill Evaluation
Procedures
- EP-AA-1010, Emergency Plan Annex for Oyster Creek Station, Revision 7
Condition Reports
- 1617364
Miscellaneous
- Oyster Creek Station Simulation Guide 2-02-14, Revision 0
Section 2RS8: Radioactive Solid Waste Processing and Radioactive Material Handling, Storage, and Transportation
- Procedures:
- RP-AA-605, 10CFR61 Program, Revision 5 351.70, Process Control Plan for Biocide Injection, Revision 14
- RW-AA-100, Process Control Program for Radioactive Wastes, Revision 8
- Condition Reports:
- 1341459
- 1349637
- 1351695
- 1375369
- 1479385
- 1483910
- 1617534
- Shipments 0107-13 1003-13 3001-13 3002-13 4008-13
Miscellaneous
- Radiation Protection Calculation and Position Paper,
- OC-12-06, 2012-2013 10CFR61 Waste Stream Analysis Audit
- NOSA-OYS-12-04, Chemistry, Radwaste, Effluent and Environmental Monitoring Benchmark Assessment
- 1349598, RAM Containers Benchmark Assessment
- 1458171, Infield Wok Control and Radworker Practices Follow-up, Radwaste and Radioactive Material Handling, Storage and Transportation
- NRWSHP-1000, DOT/79-19 Training for Support of Radioactive and Asbestos Shipments HAZSEC, DOT Security Awareness and Transportation Security Plan Attachment
Section 4OA2: Problem Identification and Resolution
Procedures
- ER-AA-425, Implementation of the Technical Specification Surveillance Frequency Control Program, Revision 0
- ER-AA-425-1000, Selecting a Candidate to be Evaluated for a Proposed Surveillance Test Interval Change, Revision 0
- ER-AA-425-1001, Surveillance Test Interval Evaluation Form, Revision 0
- ER-AA-425-1002, Engineering Evaluation of Proposed Surveillance Test Interval Changes, Revision 0
- ER-AA-425-1003, Surveillance Frequency Control Program - Integrated Decision Making Panel Roles and Responsibility, Revision 0
- ER-AA-425-1004, Implementing an Approved Surveillance Frequency Change, Revision 0
- ER-AA-425-1005, Monitoring the Effects of Changes to the Surveillance Frequency Control Program, Revision 0 SFCP, OCNGS Surveillance Frequency Control Program - List of Surveillance Frequencies, Revision 1
- MA-AA-716-210, Performance Centered Maintenance Process Procedure, Revision 4
- LS-AA-125-1001, Root Cause Analysis Manual, Revision 4
- PI-AA-125-1001, Root Cause Analysis Manual, Revision 0
- LS-AA-125, Corrective Action Program, Revision 3
- PI-AA-125, Corrective Action Program, Revision 0
- PI-AA-120, Issue Identification and Screening Process, Revision 0
Drawings
Work Orders
- C2031016
- C2029085
Condition Reports
- 1539987
- 1453695
- 1560908
- 1586470
- 1586222
- 1568503
- 1605656
- 1605650
- 1605640
- 1605653 O2004-1314
Miscellaneous
- ER-AA-425-1000 Attachment 1, Surveillance Test Interval Change Screening Form
- Control Rod Drive Scram Discharge Instrument Volume, dated June 19, 2013
- NEI 04-10, Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies, Revision 1 Oyster Creek Nuclear Generating Station Outage Control Center Logs, dated November 17, 2013 and November 18, 2013 Purchase Order 80
- 055045, dated November 1, 2013 Scope Change Request Form #1R25-103, dated October 30, 2013 Reheat Steam System Health Report, 4th Quarter 2013 A2125872, PM to Inspect Expansion Joints in Subset 5 of Evaluation A2014243.66 Root Cause Report: IRM Erratic Behavior Causes Full Reactor Scram, Revision 0 Root Cause Report: Reactor Scram During Plant Shutdown May, 27 2004, Revision 0
- Attachment
- LER 2013-001-01, Automatic reactor scram due to an invalid intermediate range monitor scram signal
- LER 2004-003-01, Actuation of RPS system due to Spurious Hi-Hi trip signals on IRMs caused by electromagnetic Interference Event Notice 40778 Oyster Creek Generating Station - NRC Integrated Inspection Report 05000219/2004004 Oyster Creek Nuclear Generating Station Technical Specification 1.30, Amendment 271
Section 4OA3: Follow-up of Events and Notices of Enforcement Discretion
Miscellaneous
- LER 2013-003-00, Secondary Containment Integrity Momentarily Declared Inoperable, dated January 16, 2014
- LER 2013-002-00, Manual Scram Due to Lowering Vacuum, dated December 5, 2013
- LER 86-034, Manual Scram due to Inability to Maintain Condenser Vacuum Caused by Equipment Failure, dated January 30,1987