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| {{Adams|number = ML091170613}} | | {{Adams |
| | | number = ML091170613 |
| | | issue date = 04/27/2009 |
| | | title = IR 05000354-09-002 on 01/01/09 - 03/31/09 for Hope Creek |
| | | author name = Burritt A |
| | | author affiliation = NRC/RGN-I/DRP/PB3 |
| | | addressee name = Joyce T |
| | | addressee affiliation = PSEG Nuclear, LLC |
| | | docket = 05000354 |
| | | license number = NPF-057 |
| | | contact person = burritt al |
| | | case reference number = FOIA/PA-2010-0209 |
| | | document report number = IR-09-002 |
| | | document type = Inspection Report, Letter |
| | | page count = 27 |
| | }} |
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| {{IR-Nav| site = 05000354 | year = 2009 | report number = 002 }} | | {{IR-Nav| site = 05000354 | year = 2009 | report number = 002 }} |
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| =Text= | | =Text= |
| {{#Wiki_filter: | | {{#Wiki_filter:UNITED STATES NUCLEAR REGULATORY COMMISSION ril 27, 2009 |
| [[Issue date::April 27, 2009]]
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| Mr. Thomas Joyce President and Chief Nuclear Officer PSEG Nuclear LLC - N09 P. O. Box 236 Hancocks Bridge, NJ 08038
| | ==SUBJECT:== |
| | HOPE CREEK GENERATING STATION - NRC INTEGRATED INSPECTION REPORT 05000354/2009002 |
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| SUBJECT: HOPE CREEK GENERATING STATION - NRC INTEGRATED INSPECTION REPORT 05000354/2009002
| | ==Dear Mr. Joyce:== |
| | On March 31, 2009, the U. S. Nuclear Regulatory Commission (NRC) completed an integrated inspection at the Hope Creek Generating Station. The enclosed inspection report documents the inspection results discussed on April 8, 2009, with Mr. George Barnes and other members of your staff. |
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| ==Dear Mr. Joyce:==
| | The inspections examined activities conducted under your license as they relate to safety and compliance with the Commissions rules and regulations and with the conditions of your license. |
| On March 31, 2009, the U. S. Nuclear Regulatory Commission (NRC) completed an integrated inspection at the Hope Creek Generating Station. The enclosed inspection report documents the inspection results discussed on April 8, 2009, with Mr. George Barnes and other members of your staff. The inspections 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. Based on the results of this inspection, no findings of significance were identified.
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| | The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel. |
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| | Based on the results of this inspection, no findings of significance were identified. |
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| In accordance with 10 CFR 2.390 of the NRC's "Rules of Practice," a copy of this letter, its enclosure, and your response (if any) will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records (PARS) component of NRC's document system (ADAMS), accessible from the NRC Web site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room). | | In accordance with 10 CFR 2.390 of the NRC's "Rules of Practice," a copy of this letter, its enclosure, and your response (if any) will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records (PARS) component of NRC's document system (ADAMS), accessible from the NRC Web site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room). |
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| Sincerely,/RA/ | | Sincerely, |
| Arthur L. Burritt, Chief Projects Branch 3 Division of Reactor Projects Docket No: 50-354 License No: NPF-57 | | /RA/ |
| | Arthur L. Burritt, Chief Projects Branch 3 Division of Reactor Projects Docket No: 50-354 License No: NPF-57 Enclosure: Inspection Report 05000354/2009002 w/Attachment: Supplemental Information |
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| ===Enclosure:=== | | =SUMMARY OF FINDINGS= |
| Inspection Report 05000354/2009002
| | IR 05000354/2009002; 01/01/2009 - 03/31/2009; Hope Creek Generating Station; Routine |
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| | Integrated Inspection Report. |
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| ===w/Attachment:===
| | This report covers a three-month period of inspection by resident inspectors and announced inspections by regional specialist inspectors. The NRCs program for overseeing the safe operation of commercial nuclear power reactors is described in NUREG-1649, Reactor Oversight Process, Revision 4, dated December 2006. |
| Supplemental Information
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| =SUMMARY OF FINDINGS=
| | No findings of significance were identified. |
| ......................................................................................................... 3 | |
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| =REPORT DETAILS= | | =REPORT DETAILS= |
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| | ===Summary of Plant Status=== |
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| | The Hope Creek Generating Station operated at or near full power for the duration of the inspection period with the following exceptions. On January 9, operators reduced power to approximately 76 percent for planned testing and maintenance. The unit was restored to full power on January 10. On January 17, operators performed a manual scram in response to a turbine runback caused by a loss of stator cooling to the main generator. The unit was restarted on January 18, and reached full power on January 19. Additionally, on February 28, operators reduced power to approximately 81 percent to repair a condenser tube leak. The unit was restored to full power on March 1. On March 23, the unit entered end-of-cycle coastdown. The unit was operating at approximately 97 percent power at the end of the inspection period. |
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| ==REACTOR SAFETY== | | ==REACTOR SAFETY== |
| .............................................................................................................. 4 1R01 Adverse Weather Protection .................................................................................... 4 1R04 Equipment Alignment .............................................................................................. 4 1R05 Fire Protection ......................................................................................................... 5 1R06 Flood Protection Measures ...................................................................................... 6 1R11 Licensed Operator Requalification Program ............................................................ 6 1R12 Maintenance Effectiveness ...................................................................................... 7 1R13 Maintenance Risk Assessments and Emergent Work Control ................................. 7 1R15 Operability Evaluations ............................................................................................ 8 1R18 Plant Modifications .................................................................................................. 8 1R19 Post-Maintenance Testing ....................................................................................... 9 1R22 Surveillance Testing ................................................................................................ 9 1EP2 Alert and Notification System (ANS) Evaluation .................................................... 10 1EP3 Emergency Response Organization (ERO) Staffing and Augmentation System .... 10 1EP4 Emergency Action Level (EAL) and Emergency Plan Changes ............................. 10 1EP5 Correction of Emergency Preparedness Weaknesses ........................................... 11 1EP6 Drill Evaluation
| | Cornerstones: Initiating Events, Mitigating Systems, Barrier Integrity, and Emergency Preparedness |
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| | {{a|1R01}} |
| | ==1R01 Adverse Weather Protection== |
| | {{IP sample|IP=IP 71111.01|count=1}} |
| | |
| | ===.1 Evaluate Readiness for Impending Adverse Weather Conditions=== |
| | |
| | ====a. Inspection Scope==== |
| | The inspectors completed one adverse weather preparation sample. The inspectors reviewed PSEGs preparation activities for river grass intrusion conditions that may impact the station service water system. Inspectors assessed implementation of PSEGs grassing readiness plan through service water system walkdowns, corrective action program review, and discussions with cognizant managers and engineers. |
| | |
| | Documents reviewed are listed in the Attachment. |
| | |
| | ====b. Findings==== |
| | No findings of significance were identified. {{a|1R04}} |
| | ==1R04 Equipment Alignment (71111.04 - 3 samples,== |
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| | ==71111.04S - 1 sample) |
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| | ===.1 Partial Walkdown=== |
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| | ====a. Inspection Scope==== |
| | == |
| | The inspectors completed three partial system walkdown inspection samples. For the systems listed below the inspectors verified the operability of redundant or diverse trains and components when the listed safety equipment was unavailable. The inspectors completed walkdowns to determine whether there were discrepancies in the systems alignment that could impact the function of the system, and therefore, potentially increase risk. The inspectors reviewed applicable operating procedures, walked down control system components, and verified that selected breakers, valves, and support equipment were in the correct position to support system operation. The inspectors also verified that PSEG had properly identified and resolved equipment alignment problems that could cause initiating events or impact the capability of mitigating systems or barriers and entered them into the corrective action program. Documents reviewed are listed in the Attachment. |
| | * A emergency diesel generator (EDG) during B EDG maintenance on February 9, 2009 |
| | * A, B, and D service water (SW) system with C SW system out of service on March 9, 2009 |
| | * B safety auxiliary cooling system (SACS) loop with A SACS loop 2522 C valve maintenance on March 23, 2009 |
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| | ===.2 Complete Walkdown=== |
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| | ====a. Inspection Scope==== |
| | The inspectors completed one complete walkdown inspection of accessible portions of the standby liquid control system. The inspectors used PSEG procedures and other documents listed in the Attachment to verify proper system alignment and functional capability. The inspectors independently verified the alignment and status of standby liquid control system valves, labeling, hangers and supports, and associated support systems. The walkdown also included checks that oil reservoir levels were normal, pump rooms and pipe chases were adequately ventilated, system parameters were within established ranges, and equipment deficiencies were appropriately identified. |
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| | ====b. Findings==== |
| | No findings of significance were identified. |
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| | {{a|1R05}} |
| | ==1R05 Fire Protection== |
| | {{IP sample|IP=IP 71111.05Q|count=6}} |
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| | ===.1 Fire Protection - Tours=== |
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| | ====a. Inspection Scope==== |
| | The inspectors completed six quarterly fire protection inspection samples. 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 combustibles and ignition sources were controlled in accordance with PSEGs administrative procedures; fire detection and suppression equipment was available for use; that passive fire barriers were maintained in good material condition; and that compensatory measures for out-of-service, degraded, or inoperable fire protection equipment were implemented in accordance with PSEGs fire plan. The six areas toured are listed below with their associated pre-fire plan designator. Other documents reviewed are listed in the Attachment. |
| | * FRH-II-713, A/C SW Bay |
| | * FRH-II-713, B/D SW Bay |
| | * FRH-II-713, SW Intake Screen Room |
| | * FRH-II-434, Reactor Building MCC Area |
| | * FRH-II-542, Lower Control Equipment Area |
| | * FRH-II-541, 1E Switchgear 130 |
| | |
| | ====b. Findings==== |
| | No findings of significance were identified. |
| | |
| | {{a|1R06}} |
| | ==1R06 Flood Protection Measures== |
| | {{IP sample|IP=IP 71111.06|count=1}} |
| | |
| | ====a. Inspection Scope==== |
| | The inspectors completed one flood protection measure inspection sample. The inspectors reviewed selected risk-important plant design features and PSEG procedures intended to protect the plant and its safety-related equipment from internal flooding events. Specifically, the inspectors focused on internal flood mitigation features for the 54 elevation of the reactor building that contains significant portions of the core spray, residual heat removal, high pressure coolant injection, reactor core isolation cooling, and reactor building sump systems. The inspectors reviewed flood analysis and design documents, including the Updated Final Safety Analysis Report (UFSAR), engineering calculations, and abnormal operating procedures. The inspectors observed the condition of wall penetrations, watertight doors, flood alarm switches, and drains to assess their readiness to contain flow from an internal flood in accordance with the design basis. |
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| | ====b. Findings==== |
| | No findings of significance were identified. |
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| | {{a|1R11}} |
| | ==1R11 Licensed Operator Requalification Program== |
| | {{IP sample|IP=IP 71111.11Q|count=1}} |
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| | ===.1 Requalification Activities Review By Resident Staff=== |
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| | ====a. Inspection Scope==== |
| | The inspectors observed a licensed operator annual requalification simulator scenario on February 10, 2009, to assess operator performance and training effectiveness. The scenario involved a safety relief valve failing open, a loss of primary condensate pumps, a mode switch failure, a failure of the high pressure coolant injection system to initiate, and event classification. The inspectors verified that control room staff correctly identified and declared emergency action levels in a timely manner. The inspectors assessed simulator fidelity and observed the simulator instructors critique of operator performance. The inspectors also observed control room activities with emphasis on simulator-identified areas for improvement. Finally, the inspectors reviewed applicable documents associated with licensed operator requalification as listed in the Attachment. |
| | |
| | ====b. Findings==== |
| | No findings of significance were identified. |
| | |
| | {{a|1R12}} |
| | ==1R12 Maintenance Effectiveness== |
| | {{IP sample|IP=IP 71111.12|count=3}} |
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| | ====a. Inspection Scope==== |
| | The inspectors completed three maintenance effectiveness inspection samples. For the systems listed below the inspectors evaluated items such as: appropriate work practices; identifying and addressing common cause failures; scoping in accordance with 10 CFR 50.65(b) of the maintenance rule (MR); characterizing reliability issues for performance; trending key parameters for condition monitoring; charging unavailability for performance; classification and reclassification in accordance with 10 CFR 50.65(a)(1) or (a)(2); and appropriateness of performance criteria for structures, systems, and components (SSCs) functions classified as (a)(2) and/or appropriateness and adequacy of goals and corrective actions for SSCs/functions classified as (a)(1). |
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| | Documents reviewed are listed in the Attachment. |
| | * Feedwater system |
| | * High pressure coolant injection (HPCI) pump |
| | * Service water pumps |
| | |
| | ====b. Findings==== |
| | No findings of significance were identified. |
| | |
| | {{a|1R13}} |
| | ==1R13 Maintenance Risk Assessments and Emergent Work Control== |
| | {{IP sample|IP=IP 71111.13|count=4}} |
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| | ====a. Inspection Scope==== |
| | The inspectors completed four maintenance risk assessment and emergent work control inspection samples. The inspectors reviewed on-line risk management evaluations through direct observation and document reviews for the following four configurations: |
| | * A control rod drive pump and C SACS pump out of service on January 6, 2009; |
| | * B EDG and one offsite line out of service on February 10, 2009; |
| | * C EDG and B reactor building ventilation system out of service on February 3, 2009; and |
| | * B reactor protection system motor generator set and one of two supply breakers for the B 4kV bus out of service on March 10, 2009. |
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| | The inspectors reviewed the applicable risk evaluations, work schedules and control room logs for these configurations to verify that concurrent planned and emergent maintenance and test activities did not adversely affect the plant risk already incurred with these configurations. PSEGs risk management actions were reviewed during shift turnover meetings, control room tours, and plant walkdowns. The inspectors also used PSEGs on-line risk monitor (Equipment Out-Of-Service workstation) to gain insights into the risk associated with these plant configurations. Finally, the inspectors reviewed notifications documenting problems associated with risk assessments and emergent work evaluations. Documents reviewed are listed in the Attachment. |
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| | ====b. Findings==== |
| | No findings of significance were identified. |
| | |
| | {{a|1R15}} |
| | ==1R15 Operability Evaluations== |
| | {{IP sample|IP=IP 71111.15|count=6}} |
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| | ====a. Inspection Scope==== |
| | The inspectors completed six operability evaluation inspection samples. The inspectors reviewed the operability determinations for degraded or non-conforming conditions associated with: |
| | * Degraded control rods due to channel distortion; |
| | * HPCI booster pump wear particles in oil; |
| | * SW strainer differential pressure increase; |
| | * B EDG jacket water leak; |
| | * Condensate storage tank to torus swapover for high pressure coolant injection/reactor core isolation cooling; and |
| | * EDG fuel oil transfer pump cross-connect flow path. |
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| | The inspectors reviewed the technical adequacy of the operability determinations to ensure the conclusions were justified. The inspectors also walked down accessible equipment to corroborate the adequacy of PSEGs operability determinations. |
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| | Additionally, the inspectors reviewed other PSEG identified safety-related equipment deficiencies during this report period and assessed the adequacy of their operability screenings. Documents reviewed are listed in the Attachment. |
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| | ====b. Findings==== |
| | No findings of significance were identified. |
| | |
| | {{a|1R18}} |
| | ==1R18 Plant Modifications== |
| | {{IP sample|IP=IP 71111.18|count=1}} |
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| | ===.1 Temporary Modifications=== |
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| | ====a. Inspection Scope==== |
| | The inspectors completed one plant modification inspection sample. The inspectors reviewed the temporary plant modification package for temporary power feeds from offsite power supply substation #9. This review verified that the design bases, licensing bases, and performance capability of the system was not degraded by the modification. |
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| | The inspectors verified the new configuration was accurately reflected in the design documentation, and the post-modification testing was adequate to ensure the structures, systems, and components would function properly. The inspectors interviewed plant staff, and reviewed issues that had been entered into the corrective action program to determine whether PSEG had been effective in identifying and resolving problems associated with temporary modifications. The 10 CFR 50.59 evaluation associated with this temporary modification was also reviewed. Documents reviewed are listed in the |
| | . |
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| | ====b. Findings==== |
| | No findings of significance were identified. |
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| | {{a|1R19}} |
| | ==1R19 Post-Maintenance Testing== |
| | {{IP sample|IP=IP 71111.19|count=6}} |
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| | ====a. Inspection Scope==== |
| | The inspectors completed six post-maintenance testing inspection samples. The inspectors reviewed the post-maintenance tests for the maintenance items listed below to verify that test activities confirmed system operability and functional capability following completion of maintenance. The inspectors reviewed applicable test procedures to verify that they tested all safety functions potentially affected by the associated maintenance activities. The inspectors verified that for each potentially affected safety function the acceptance criteria stated in the procedure was consistent with the UFSAR and other design documentation. The inspectors also witnessed completion of the testing or reviewed the completed test results to verify satisfactory restoration of all safety functions affected by the maintenance activities. Documents reviewed are listed in the Attachment. |
| | * A control rod drive pump motor replacement on January 8, 2009 |
| | * CD482 inverter card replacement on January 5, 2009 |
| | * D EDG SACS cooling water valve 2395 D relay replacement on January 12, 2009 |
| | * C EDG scheduled maintenance on March 9, 2009 |
| | * B, C, and D EDG day tank level switch calibrations on March 11, 2009 |
| | * B control room chiller scheduled maintenance on March 19, 2009 |
| | |
| | ====b. Findings==== |
| | No findings of significance were identified. |
| | |
| | {{a|1R22}} |
| | ==1R22 Surveillance Testing== |
| | {{IP sample|IP=IP 71111.22|count=6}} |
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| | ====a. Inspection Scope==== |
| | The inspectors completed six surveillance testing (ST) inspection samples. The inspectors witnessed performance of and/or reviewed test data for the risk-significant STs listed below to assess whether the SSCs tested satisfied technical specification, UFSAR, and procedure requirements. The inspectors verified that test acceptance criteria were clear, demonstrated operational readiness and were consistent with design documentation; that test instrumentation had current calibrations and the range and accuracy for the application; and that tests were performed, as written, with applicable prerequisites satisfied. Upon ST completion, the inspectors verified that equipment was returned to the status required to perform its safety function. Documents reviewed are listed in the Attachment. |
| | * Nuclear instrumentation intermediate range monitor testing on January 18, 2009 |
| | * B EDG monthly operability test on February 11, 2009 |
| | * D EDG 24-hour surveillance test on February 18, 2009 |
| | * Control room envelope filtration surveillance test on February 19, 2009 |
| | * Reactor core isolation cooling surveillance test on February 19, 2009 |
| | * High pressure coolant injection in-service test on February 24, 2009 |
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| | ====b. Findings==== |
| | No findings of significance were identified. |
| | |
| | {{a|1EP2}} |
| | ==1EP2 Alert and Notification System (ANS) Evaluation== |
| | {{IP sample|IP=IP 71114.02|count=1}} |
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| | ====a. Inspection Scope==== |
| | An onsite review was conducted to assess the maintenance and testing of the Salem and Hope Creek ANS. During this inspection, the inspectors interviewed Emergency Preparedness (EP) staff responsible for implementation of the ANS testing and maintenance and reviewed corrective action program notifications pertaining to the ANS for causes, trends, and PSEGs corrective actions. The inspector reviewed the ANS procedures and the ANS design report to ensure PSEGs compliance with system maintenance and testing commitments. The inspection was conducted in accordance with NRC Inspection Procedure 71114, Attachment |
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| | ===.02. Planning Standard, 10 CFR=== |
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| | 50.47(b) |
| | : (5) and the related requirements of 10 CFR 50, Appendix E, were used as reference criteria. |
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| | ====b. Findings==== |
| | No findings of significance were identified. |
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| | {{a|1EP3}} |
| | ==1EP3 Emergency Response Organization (ERO) Staffing and Augmentation System== |
| | {{IP sample|IP=IP 71114.03|count=1}} |
| | |
| | ====a. Inspection Scope==== |
| | The inspectors conducted a review of Salem/Hope Creeks ERO augmentation staffing requirements and the process for notifying and augmenting the ERO. This was performed to ensure the readiness of key staff for responding to an event and to ensure timely facility activation. The inspectors reviewed the ERO roster, training records, applicable procedures, drill reports for augmentation, quarterly EP drills and corrective action program notifications related to the ERO staffing augmentation system. The inspectors also reviewed the implementation of the change in the ERO augmentation time from 60 to 90 minutes. The inspection was conducted in accordance with NRC Inspection Procedure 71114, Attachment |
| | |
| | ===.03. Planning Standard, 10 CFR 50.47(b)(2)=== |
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| | and related requirements of 10 CFR 50, Appendix E, were used as reference criteria. |
| | |
| | ====b. Findings==== |
| | No findings of significance were identified. |
| | |
| | {{a|1EP4}} |
| | ==1EP4 Emergency Action Level (EAL) and Emergency Plan Changes== |
| | {{IP sample|IP=IP 71114.04|count=1}} |
| | |
| | ====a. Inspection Scope==== |
| | Prior to this inspection, the NRC had received and acknowledged changes made to the Salem/Hope Creek Emergency Plan and its implementing procedures. PSEG developed these changes in accordance with 10 CFR 50.54(q), and determined that the changes did not result in a decrease in effectiveness of the Plan. PSEG also determined that the Plan continued to meet the requirements of 10 CFR 50.47(b) and Appendix E to 10 CFR 50. During this inspection, the inspectors conducted a review of Salems and Hope Creeks 10 CFR 50.54(q) screenings for all changes made to the EALs, and for a sample of the changes made to the Plan, from May 2008 through March 2009, that could have potentially resulted in a decrease in effectiveness. This review of the EAL, Plan, and EPIP changes did not constitute NRC approval of the changes and, as such, the changes remain subject to future NRC inspection. In addition, the inspectors reviewed notifications written related to this area. The inspection was conducted in accordance with NRC Inspection Procedure 71114, Attachment |
| | |
| | ===.04. The requirements in 10 CFR 50.54(q) were used as reference criteria.=== |
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| | ====b. Findings==== |
| | No findings of significance were identified. |
| | |
| | {{a|1EP5}} |
| | ==1EP5 Correction of Emergency Preparedness Weaknesses== |
| | {{IP sample|IP=IP 71114.05|count=1}} |
| | |
| | ====a. Inspection Scope==== |
| | The inspectors reviewed a sampling of self-assessment procedures and reports to assess PSEG=s ability to evaluate their EP performance and programs. The inspectors reviewed a sampling of notifications written between January 2008 and March 2009 that were initiated by PSEG at Salem and Hope Creek for issues identified during drills, self-assessments and audits. Additionally, the inspectors reviewed: Nuclear Oversight audits; the event report for the August 2008 Unusual Event declaration at Hope Creek; and, the 2007 and 2008 50.54(t) audit reports. This inspection was conducted in accordance with NRC Inspection Procedure 71114, Attachment |
| | |
| | ===.05. Planning Standard,=== |
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| | 10 CFR 50.47(b) |
| | : (14) and the related requirements of 10 CFR 50 Appendix E were used as reference criteria. |
| | |
| | ====b. Findings==== |
| | No findings of significance were identified. |
| | |
| | {{a|1EP6}} |
| | ==1EP6 Drill Evaluation== |
| | {{IP sample|IP=IP 71114.06|count=1}} |
| | |
| | ====a. Inspection Scope==== |
| | The inspectors completed one drill evaluation inspection sample. The inspectors observed control room operator emergency plan response actions during a licensed operator requalification training scenario on February 10, 2009. The inspectors verified that emergency classification declarations and notifications were completed in accordance with 10 CFR 50.72, 10 CFR 50, Appendix E, and the Hope Creek emergency plan implementing procedures. Documents reviewed for this inspection are listed in the Attachment. |
| | |
| | ====b. Findings==== |
| | No findings of significance were identified. |
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| ==OTHER ACTIVITIES== | | ==OTHER ACTIVITIES== |
| ............................................................................................................ 12
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| {{a|4OA1}} | | {{a|4OA1}} |
| ==4OA1 Performance Indicator Verification ......................................................................... 12 4OA2 Identification and Resolution of Problems .............................................................. 12 4OA3 Event Followup ...................................................................................................... 13 4OA5 Other Activities ...................................................................................................... 13 4OA6 Meetings, Including Exit......................................................................................... 15== | | ==4OA1 Performance Indicator Verification== |
| ATTACHMENT: | | {{IP sample|IP=IP 71151|count=6}} |
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| | ====a. Inspection Scope==== |
| | The inspectors reviewed PSEGs program for gathering, evaluating and reporting information for the performance indicators (PIs) listed below. The inspectors used the definitions and guidance contained in NEI (Nuclear Energy Institute) 99-02, Regulatory Assessment Performance Indicator Guideline, Revision 5, to assess the accuracy of PSEGs collection and reporting of PI data. The documents reviewed by the inspectors are listed in the Attachment. |
| | |
| | ===Cornerstone: Initiating Events=== |
| | * Unplanned Scrams per 7000 Critical Hours |
| | * Unplanned Scrams with Complications |
| | * Unplanned Power Changes per 7000 Critical Hours The inspectors reviewed the data reported for these PIs for the period January 1 through December 31, 2008. The records reviewed included PI data summary reports, licensee event reports, monthly operating reports, and operator narrative logs. The inspectors verified the accuracy of the number of critical hours reported, and interviewed the system engineers responsible for data collection and evaluation. |
| | |
| | ===Cornerstone: Emergency Preparedness=== |
| | * Drill and Exercise Performance |
| | * ERO Drill Participation |
| | * ANS Reliability For the PIs listed above, to verify the accuracy of the reported data, the inspectors reviewed the PI data, supporting documentation and the information PSEG reported, from the second quarter through the fourth quarter of 2008 |
| | |
| | ====b. Findings==== |
| | No findings of significance were identified. {{a|4OA2}} |
| | ==4OA2 Identification and Resolution of Problems== |
| | {{IP sample|IP=IP 71152}} |
| | ===.1 Review of Items Entered into the Corrective Action Program:=== |
| | |
| | As required by Inspection Procedure 71152, Identification and Resolution of Problems, and in order to help identify repetitive equipment failures or specific human performance issues for follow-up, the inspectors performed a daily screening of all items entered into PSEG's corrective action program. This was accomplished by reviewing the description of each new notification and attending daily management review committee meetings. |
| | |
| | {{a|4OA3}} |
| | ==4OA3 Event Followup== |
| | {{IP sample|IP=IP 71153|count=1}} |
| | |
| | ===.1 (Closed) LER 05000354/2009-001, Reactor Manual Scram Due to Turbine Runback=== |
| | |
| | On January 17, 2009, operators initiated a manual reactor scram in response to a main turbine runback caused by a loss of main generator stator cooling. The loss of stator cooling occurred due to a turbine auxiliary cooling system isolation valve that failed shut. |
| | |
| | The solenoid for the valve was determined to have a detached lead. This lead had been replaced approximately one week prior to the event. This condition was not caused by a performance deficiency associated with the maintenance activity. |
| | |
| | The resident inspectors responded to the site and verified that plant systems responded as designed to the transient and operator response was consistent with plant procedures. The inspectors reviewed control board indications, plant logs, computer alarm data, and other post-transient records and data. The inspectors also reviewed PSEGs prompt investigation, apparent cause evaluation, and root cause evaluation for this event. |
| | |
| | The inspectors reviewed LER 05000354/2009-001 and determined that the direct cause, the solenoid failure, was not within PSEG's ability to foresee and correct, and therefore would not meet the screening criteria for a finding. The inspectors identified no findings of significance and determined there was no violation of NRC requirements. This LER is closed. |
| | |
| | {{a|4OA5}} |
| | ==4OA5 Other Activities== |
| | |
| | ===.1 Quarterly Resident Inspector Observations of Security Personnel and Activities=== |
| | |
| | ====a. Inspection Scope==== |
| | During the inspection period, the inspectors conducted observations of security force personnel and activities to ensure that the activities were consistent with PSEG security procedures and regulatory requirements relating to nuclear plant security. These observations took place during both normal and off-normal plant working hours. These quarterly resident inspector observations of security force personnel and activities did not constitute any additional inspection samples. Rather, they were considered an integral part of the inspectors normal plant status review and inspection activities. |
| | |
| | ====b. Findings==== |
| | No findings of significance were identified. |
| | |
| | ===.2 TI 2515/173, Review of the Implementation of the Industry Ground Water Protection=== |
| | |
| | Voluntary Initiative |
| | |
| | ====a. Inspection Scope==== |
| | On March 9-13, 2009, the inspectors assessed PSEGs ground water protection program to verify that PSEG implemented the voluntary industry Ground Water Protection Initiative (GPI). The GPI was unanimously approved by a formal vote of the Nuclear Energy Institute (NEI) member utility chief nuclear officers. This established the industrys commitment to implement the initiative. The GPI identifies the actions the industry deemed necessary for implementation of a timely and effective ground water protection program. |
| | |
| | The inspectors verified that the following objectives for the GPI were contained in PSEG's program: |
| | 1.1 Site Hydrology and Geology 1.2 Site Risk Management 1.3 On-Site Ground Water Monitoring 1.4 Remediation Process 1.5 Record Keeping 2.1 Stakeholder Briefing 2.2 Voluntary Communication 2.3 Thirty-Day Reports 2.4 Annual Reporting 3.1 Perform a Self-Assessment 3.2 Review the Program Under the Auspices of NEI Unit 2 Emergency Sump The inspectors reviewed documentation and PSEG actions related to the identification of tritium in the Unit 2 emergency sump, located below the 54 elevation in the turbine building. The inspectors discussed with PSEG the testing and reviews conducted to determine the source of the tritium. PSEG's investigation determined that the source of the tritium was condensation from the turbine building administrative area heating ventilation and air conditioning (HVAC) unit, and that the tritium from the condensation came from the Technical Specification/Offsite Dose Calculation Manual authorized effluent releases from the plant vents being drawn into the HVAC intake. The inspectors confirmed that the information developed from PSEG's investigation, including various system testing and data collection, supported this conclusion. |
| | |
| | The inspectors also reviewed PSEG's investigation efforts and actions taken to determine the cause of frequent makeup of water volume to the condensate storage tank. While investigation is still continuing, PSEG's efforts did provide basis to conclude that there were no leaks to ground water in associated underground piping, valving, or the tank. |
| | |
| | ====b. Findings==== |
| | No findings of significance were identified. |
| | |
| | ===.3 Correction to NRC Cross-Cutting Aspect Coding of NRC Finding NCV=== |
| | |
| | 05000354/2009006-03, Failure to Follow Procedures Contributes to Emergency Diesel Generator Inoperability NRC Inspection Report 05000354/2009006 dated March 16, 2009, documented a Green finding associated with PSEGs failure to follow a surveillance test procedure. The finding had a cross-cutting aspect in the area of human performance and the aspect of work practices, procedural compliance, because PSEG personnel did not follow procedures. However, the finding documentation in Inspection Report 05000354/2009006 contained a typographical error. Specifically, in analysis section for the finding and the summary of findings section for the report the cross-cutting aspect code for this finding was incorrectly listed as H.2(b). The correct cross-cutting aspect code for this finding was H.4(b). |
| | |
| | ===.4 TI 2515/175, Emergency Response Organization, Drill/Exercise Performance Indicator=== |
| | |
| | Program Review The inspectors performed TI 2515/175, ensured the completeness of PSEGs completed 1 from the TI, and then forwarded the data to NRC, HQ. |
| | |
| | {{a|4OA6}} |
| | ==4OA6 Meetings, Including Exit== |
| | |
| | The resident inspectors presented the inspection results to Mr. George Barnes and other members of PSEG staff on April 8, 2009. The inspectors verified that proprietary material reviewed by the inspectors during this period was properly controlled and the content of the report includes no proprietary information. |
| | |
| | ATTACHMENT: |
|
| |
|
| =SUPPLEMENTAL INFORMATION= | | =SUPPLEMENTAL INFORMATION= |
|
| |
|
| ==KEY POINTS OF CONTACT== | | ==KEY POINTS OF CONTACT== |
| .................................................................................................. A-1
| | |
| | ===Licensee Personnel=== |
| | : [[contact::G. Barnes]], Site Vice President |
| | : [[contact::B. Booth]], Operations Director |
| | : [[contact::D. Burgin]], Corporate Emergency Preparedness Manager |
| | : [[contact::R. Canziani]], Maintenance Director |
| | : [[contact::E. Casulli]], Shift Operations Superintendent |
| | : [[contact::K. Chambliss]], Assistant Plant Manager |
| | : [[contact::P. Duca]], Senior Engineer, Regulatory Assurance |
| | : [[contact::K. Knaide]], Engineering Director |
| | : [[contact::M. Gaffney]], Regulatory Assurance Manager |
| | : [[contact::J. Perry]], Plant Manager |
| | : [[contact::J. Sears]], Chemistry Manager |
| | : [[contact::H. Trimble]], Radiation Protection Manager |
| | |
| ==LIST OF ITEMS OPENED, CLOSED, AND DISCUSSED== | | ==LIST OF ITEMS OPENED, CLOSED, AND DISCUSSED== |
| ....................................................... A-1
| |
| ==LIST OF DOCUMENTS REVIEWED==
| |
| ...................................................................................... A-1
| |
| ==LIST OF ACRONYMS==
| |
| : [[......]] [[...................................................................................................... A-9]]
| |
| : [[3SUMMAR]] [[Y]]
| |
| : [[OF]] [[]]
| |
| : [[FINDIN]] [[]]
| |
| GS
| |
| IR 05000354/2009002; 01/01/2009 - 03/31/2009; Hope Creek Generating Station; Routine
| |
| Integrated Inspection Report. This report covers a three-month period of inspection by resident inspectors and announced
| |
| inspections by regional specialist inspectors. 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.
| |
| No findings of significance were identified.
| |
| : [[4REPORT]] [[]]
| |
| DETAILS Summary of Plant Status The Hope Creek Generating Station operated at or near full power for the duration of the
| |
| inspection period with the following exceptions. On January 9, operators reduced power to approximately 76 percent for planned testing and maintenance. The unit was restored to full power on January 10. On January 17, operators performed a manual scram in response to a turbine runback caused by a loss of stator cooling to the main generator. The unit was restarted on January 18, and reached full power on January 19. Additionally, on February 28, operators
| |
| reduced power to approximately 81 percent to repair a condenser tube leak. The unit was restored to full power on March 1. On March 23, the unit entered end-of-cycle coastdown. The unit was operating at approximately 97 percent power at the end of the inspection period. 1.
| |
| : [[REACTO]] [[R]]
| |
| : [[SAFETY]] [[Cornerstones: Initiating Events, Mitigating Systems, Barrier Integrity, and Emergency Preparedness 1R01 Adverse Weather Protection (71111.01 - 1 sample) .1 Evaluate Readiness for Impending Adverse Weather Conditions a. Inspection Scope The inspectors completed one adverse weather preparation sample. The inspectors reviewed]]
| |
| : [[PS]] [[]]
| |
| : [[EG]] [['s preparation activities for river grass intrusion conditions that may impact the station service water system. Inspectors assessed implementation of]]
| |
| : [[PS]] [[]]
| |
| EG's grassing readiness plan through service water system walkdowns, corrective action program review, and discussions with cognizant managers and engineers. Documents reviewed are listed in the Attachment. b. Findings No findings of significance were identified. 1R04 Equipment Alignment (71111.04 - 3 samples, 71111.04S - 1 sample)
| |
| .1 Partial Walkdown a. Inspection Scope The inspectors completed three partial system walkdown inspection samples. For the systems listed below the inspectors verified the operability of redundant or diverse trains and components when the listed safety equipment was unavailable. The inspectors
| |
| completed walkdowns to determine whether there were discrepancies in the system's alignment that could impact the function of the system, and therefore, potentially increase risk. The inspectors reviewed applicable operating procedures, walked down control system components, and verified that selected breakers, valves, and support
| |
| 5equipment were in the correct position to support system operation. The inspectors also verified that
| |
| : [[PSEG]] [[had properly identified and resolved equipment alignment problems that could cause initiating events or impact the capability of mitigating systems or barriers and entered them into the corrective action program. Documents reviewed are listed in the Attachment. * A emergency diesel generator (]]
| |
| : [[EDG]] [[) during B]]
| |
| : [[EDG]] [[maintenance on February 9, 2009 * A, B, and D service water (]]
| |
| : [[SW]] [[) system with C]]
| |
| : [[SW]] [[system out of service on March 9, 2009 * B safety auxiliary cooling system (]]
| |
| : [[SACS]] [[) loop with A]]
| |
| : [[SACS]] [[loop 2522 C valve maintenance on March 23, 2009 .2 Complete Walkdown a. Inspection Scope The inspectors completed one complete walkdown inspection of accessible portions of the standby liquid control system. The inspectors used]]
| |
| PSEG procedures and other documents listed in the Attachment to verify proper system alignment and functional capability. The inspectors independently verified the alignment and status of standby liquid control system valves, labeling, hangers and supports, and associated support systems. The walkdown also included checks that oil reservoir levels were normal, pump rooms and pipe chases were adequately ventilated, system parameters were
| |
| within established ranges, and equipment deficiencies were appropriately identified. b. Findings No findings of significance were identified. 1R05 Fire Protection (71111.05Q - 6 samples) .1 Fire Protection - Tours a. Inspection Scope The inspectors completed six quarterly fire protection inspection samples. 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 combustibles
| |
| and ignition sources were controlled in accordance with
| |
| : [[PSEG]] [['s administrative procedures; fire detection and suppression equipment was available for use; that passive fire barriers were maintained in good material condition; and that compensatory measures for out-of-service, degraded, or inoperable fire protection equipment were implemented in accordance with]]
| |
| PSEG's fire plan. The six areas toured are listed below
| |
| with their associated pre-fire plan designator. Other documents reviewed are listed in the Attachment. *
| |
| : [[FRH]] [[-]]
| |
| : [[II]] [[-713, A/C]]
| |
| : [[SW]] [[Bay *]]
| |
| : [[FRH]] [[-II-713, B/D]]
| |
| : [[SW]] [[Bay *]]
| |
| FRH-II-713, SW Intake Screen Room
| |
| 6*
| |
| : [[FRH]] [[-]]
| |
| : [[II]] [[-434, Reactor Building]]
| |
| : [[MCC]] [[Area *]]
| |
| : [[FRH]] [[-II-542, Lower Control Equipment Area *]]
| |
| : [[FRH]] [[-]]
| |
| : [[II]] [[-541, 1E Switchgear 130' b. Findings No findings of significance were identified. 1R06 Flood Protection Measures (71111.06 - 1 sample) a. Inspection Scope The inspectors completed one flood protection measure inspection sample. The inspectors reviewed selected risk-important plant design features and]]
| |
| : [[PS]] [[]]
| |
| EG procedures intended to protect the plant and its safety-related equipment from internal flooding events. Specifically, the inspectors focused on internal flood mitigation features for the 54' elevation of the reactor building that contains significant portions of the core spray,
| |
| residual heat removal, high pressure coolant injection, reactor core isolation cooling, and reactor building sump systems. The inspectors reviewed flood analysis and design documents, including the Updated Final Safety Analysis Report (UFSAR), engineering calculations, and abnormal operating procedures. The inspectors observed the condition of wall penetrations, watertight doors, flood alarm switches, and drains to assess their readiness to contain flow from an internal flood in accordance with the design basis.
| |
| b. Findings No findings of significance were identified.
| |
| 1R11 Licensed Operator Requalification Program (71111.11Q - 1 sample) .1 Requalification Activities Review By Resident Staff a. Inspection Scope The inspectors observed a licensed operator annual requalification simulator scenario on February 10, 2009, to assess operator performance and training effectiveness. The scenario involved a safety relief valve failing open, a loss of primary condensate pumps, a mode switch failure, a failure of the high pressure coolant injection system to initiate,
| |
| and event classification. The inspectors verified that control room staff correctly identified and declared emergency action levels in a timely manner. The inspectors assessed simulator fidelity and observed the simulator instructor's critique of operator performance. The inspectors also observed control room activities with emphasis on simulator-identified areas for improvement. Finally, the inspectors reviewed applicable
| |
| documents associated with licensed operator requalification as listed in the Attachment. b. Findings No findings of significance were identified.
| |
| 71R12 Maintenance Effectiveness (71111.12 - 3 samples) a. Inspection Scope The inspectors completed three maintenance effectiveness inspection samples. For the systems listed below the inspectors evaluated items such as: appropriate work
| |
| practices; identifying and addressing common cause failures; scoping in accordance with
| |
| : [[10 CFR]] [[50.65(b) of the maintenance rule (]]
| |
| MR); characterizing reliability issues for performance; trending key parameters for condition monitoring; charging unavailability for performance; classification and reclassification in accordance with 10 CFR 50.65(a)(1) or (a)(2); and appropriateness of performance criteria for structures,
| |
| systems, and components (SSCs) functions classified as (a)(2) and/or appropriateness and adequacy of goals and corrective actions for
| |
| : [[SSC]] [[s/functions classified as (a)(1). Documents reviewed are listed in the Attachment. * Feedwater system * High pressure coolant injection (]]
| |
| HPCI) pump * Service water pumps b. Findings No findings of significance were identified. 1R13 Maintenance Risk Assessments and Emergent Work Control (71111.13 - 4 samples) a. Inspection Scope The inspectors completed four maintenance risk assessment and emergent work control inspection samples. The inspectors reviewed on-line risk management evaluations
| |
| through direct observation and document reviews for the following four configurations: * A control rod drive pump and C
| |
| : [[SACS]] [[pump out of service on January 6, 2009; * B]]
| |
| : [[EDG]] [[and one offsite line out of service on February 10, 2009; * C]]
| |
| : [[EDG]] [[and B reactor building ventilation system out of service on February 3, 2009; and * B reactor protection system motor generator set and one of two supply breakers for the B 4kV bus out of service on March 10, 2009. The inspectors reviewed the applicable risk evaluations, work schedules and control room logs for these configurations to verify that concurrent planned and emergent maintenance and test activities did not adversely affect the plant risk already incurred with these configurations.]]
| |
| PSEG's risk management actions were reviewed during shift
| |
| turnover meetings, control room tours, and plant walkdowns. The inspectors also used
| |
| : [[PS]] [[]]
| |
| EG's on-line risk monitor (Equipment Out-Of-Service workstation) to gain insights into the risk associated with these plant configurations. Finally, the inspectors reviewed notifications documenting problems associated with risk assessments and emergent work evaluations. Documents reviewed are listed in the Attachment.
| |
| b. Findings No findings of significance were identified. 1R15 Operability Evaluations (71111.15 - 6 samples)
| |
| a. Inspection Scope The inspectors completed six operability evaluation inspection samples. The inspectors reviewed the operability determinations for degraded or non-conforming conditions associated with: * Degraded control rods due to channel distortion; *
| |
| : [[HPCI]] [[booster pump wear particles in oil; *]]
| |
| : [[SW]] [[strainer differential pressure increase; * B]]
| |
| : [[EDG]] [[jacket water leak; * Condensate storage tank to torus swapover for high pressure coolant injection/reactor core isolation cooling; and *]]
| |
| : [[EDG]] [[fuel oil transfer pump cross-connect flow path. The inspectors reviewed the technical adequacy of the operability determinations to ensure the conclusions were justified. The inspectors also walked down accessible equipment to corroborate the adequacy of]]
| |
| : [[PS]] [[]]
| |
| EG's operability determinations.
| |
| Additionally, the inspectors reviewed other
| |
| : [[PS]] [[]]
| |
| EG identified safety-related equipment deficiencies during this report period and assessed the adequacy of their operability screenings. Documents reviewed are listed in the Attachment. b. Findings No findings of significance were identified. 1R18 Plant Modifications (71111.18 - 1 sample) .1 Temporary Modifications
| |
| a. Inspection Scope The inspectors completed one plant modification inspection sample. The inspectors reviewed the temporary plant modification package for temporary power feeds from offsite power supply substation #9. This review verified that the design bases, licensing
| |
| bases, and performance capability of the system was not degraded by the modification. The inspectors verified the new configuration was accurately reflected in the design documentation, and the post-modification testing was adequate to ensure the structures, systems, and components would function properly. The inspectors interviewed plant staff, and reviewed issues that had been entered into the corrective action program to
| |
| determine whether
| |
| : [[PSEG]] [[had been effective in identifying and resolving problems associated with temporary modifications. The 10]]
| |
| CFR 50.59 evaluation associated with this temporary modification was also reviewed. Documents reviewed are listed in the Attachment.
| |
| b. Findings No findings of significance were identified. 1R19 Post-Maintenance Testing (71111.19 - 6 samples)
| |
| a. Inspection Scope The inspectors completed six post-maintenance testing inspection samples. The inspectors reviewed the post-maintenance tests for the maintenance items listed below to verify that test activities confirmed system operability and functional capability
| |
| following completion of maintenance. The inspectors reviewed applicable test procedures to verify that they tested all safety functions potentially affected by the associated maintenance activities. The inspectors verified that for each potentially affected safety function the acceptance criteria stated in the procedure was consistent with the
| |
| : [[UFS]] [[]]
| |
| AR and other design documentation. The inspectors also witnessed completion of the testing or reviewed the completed test results to verify satisfactory restoration of all safety functions affected by the maintenance activities. Documents
| |
| reviewed are listed in the Attachment. * A control rod drive pump motor replacement on January 8, 2009 *
| |
| : [[CD]] [[482 inverter card replacement on January 5, 2009 * D]]
| |
| : [[EDG]] [[]]
| |
| : [[SACS]] [[cooling water valve 2395 D relay replacement on January 12, 2009 * C]]
| |
| : [[EDG]] [[scheduled maintenance on March 9, 2009 * B, C, and D]]
| |
| : [[EDG]] [[day tank level switch calibrations on March 11, 2009 * B control room chiller scheduled maintenance on March 19, 2009 b. Findings No findings of significance were identified. 1R22 Surveillance Testing (71111.22 - 6 samples) a. Inspection Scope The inspectors completed six surveillance testing (]]
| |
| : [[ST]] [[) inspection samples. The inspectors witnessed performance of and/or reviewed test data for the risk-significant]]
| |
| : [[ST]] [[s listed below to assess whether the]]
| |
| : [[SSC]] [[s tested satisfied technical specification,]]
| |
| : [[UFS]] [[]]
| |
| AR, and procedure requirements. The inspectors verified that test acceptance
| |
| criteria were clear, demonstrated operational readiness and were consistent with design documentation; that test instrumentation had current calibrations and the range and accuracy for the application; and that tests were performed, as written, with applicable prerequisites satisfied. Upon ST completion, the inspectors verified that equipment was returned to the status required to perform its safety function. Documents reviewed are
| |
| listed in the Attachment. * Nuclear instrumentation intermediate range monitor testing on January 18, 2009 * B
| |
| : [[EDG]] [[monthly operability test on February 11, 2009 * D]]
| |
| EDG 24-hour surveillance test on February 18, 2009
| |
| 10* Control room envelope filtration surveillance test on February 19, 2009 * Reactor core isolation cooling surveillance test on February 19, 2009 * High pressure coolant injection in-service test on February 24, 2009 b. Findings No findings of significance were identified.
| |
| : [[1EP]] [[2 Alert and Notification System (]]
| |
| : [[ANS]] [[) Evaluation (71114.02 - 1 sample) a. Inspection Scope An onsite review was conducted to assess the maintenance and testing of the Salem and Hope Creek]]
| |
| : [[ANS.]] [[During this inspection, the inspectors interviewed Emergency Preparedness (]]
| |
| : [[EP]] [[) staff responsible for implementation of the]]
| |
| : [[ANS]] [[testing and maintenance and reviewed corrective action program notifications pertaining to the]]
| |
| : [[ANS]] [[for causes, trends, and]]
| |
| : [[PSEG]] [['s corrective actions. The inspector reviewed the]]
| |
| : [[ANS]] [[procedures and the]]
| |
| : [[ANS]] [[design report to ensure]]
| |
| : [[PSEG]] [['s compliance with system maintenance and testing commitments. The inspection was conducted in accordance with]]
| |
| : [[NRC]] [[Inspection Procedure 71114, Attachment .02. Planning Standard, 10]]
| |
| : [[CFR]] [[50.47(b) (5) and the related requirements of]]
| |
| : [[10 CFR]] [[50, Appendix E, were used as reference criteria. b. Findings No findings of significance were identified. 1]]
| |
| : [[EP]] [[3 Emergency Response Organization (ERO) Staffing and Augmentation System (71114.03 - 1 sample) a. Inspection Scope The inspectors conducted a review of Salem/Hope Creeks']]
| |
| : [[ERO]] [[augmentation staffing requirements and the process for notifying and augmenting the]]
| |
| ERO. This was
| |
| performed to ensure the readiness of key staff for responding to an event and to ensure timely facility activation. The inspectors reviewed the
| |
| : [[ERO]] [[roster, training records, applicable procedures, drill reports for augmentation, quarterly]]
| |
| : [[EP]] [[drills and corrective action program notifications related to the]]
| |
| : [[ERO]] [[staffing augmentation system. The inspectors also reviewed the implementation of the change in the]]
| |
| ERO augmentation
| |
| time from 60 to 90 minutes. The inspection was conducted in accordance with
| |
| : [[NRC]] [[Inspection Procedure 71114, Attachment .03. Planning Standard, 10]]
| |
| : [[CFR]] [[50.47(b)(2) and related requirements of]]
| |
| : [[10 CFR]] [[50, Appendix E, were used as reference criteria. b. Findings No findings of significance were identified. 1]]
| |
| EP4 Emergency Action Level (EAL) and Emergency Plan Changes (71114.04 - 1 sample) a. Inspection Scope
| |
| 11Prior to this inspection, the
| |
| : [[NRC]] [[had received and acknowledged changes made to the Salem/Hope Creek Emergency Plan and its implementing procedures.]]
| |
| : [[PSEG]] [[developed these changes in accordance with]]
| |
| : [[10 CFR]] [[50.54(q), and determined that the changes did not result in a decrease in effectiveness of the Plan.]]
| |
| : [[PSEG]] [[also determined that the Plan continued to meet the requirements of]]
| |
| : [[10 CFR]] [[50.47(b) and Appendix E to 10]]
| |
| CFR 50. During this inspection, the inspectors conducted a review of
| |
| Salem's and Hope Creek's
| |
| : [[10 CFR]] [[50.54(q) screenings for all changes made to the]]
| |
| : [[EAL]] [[s, and for a sample of the changes made to the Plan, from May 2008 through March 2009, that could have potentially resulted in a decrease in effectiveness. This review of the]]
| |
| : [[EAL]] [[, Plan, and]]
| |
| : [[EPIP]] [[changes did not constitute]]
| |
| : [[NRC]] [[approval of the changes and, as such, the changes remain subject to future]]
| |
| NRC inspection. In addition, the
| |
| inspectors reviewed notifications written related to this area. The inspection was conducted in accordance with
| |
| : [[NRC]] [[Inspection Procedure 71114, Attachment .04. The requirements in 10]]
| |
| : [[CFR]] [[50.54(q) were used as reference criteria. b. Findings No findings of significance were identified.]]
| |
| : [[1EP]] [[5 Correction of Emergency Preparedness Weaknesses (71114.05 - 1 sample) a. Inspection Scope The inspectors reviewed a sampling of self-assessment procedures and reports to assess]]
| |
| PSEG=s ability to evaluate their EP performance and programs. The inspectors reviewed a sampling of notifications written between January 2008 and March 2009 that
| |
| were initiated by
| |
| : [[PSEG]] [[at Salem and Hope Creek for issues identified during drills, self-assessments and audits. Additionally, the inspectors reviewed: Nuclear Oversight audits; the event report for the August 2008 Unusual Event declaration at Hope Creek; and, the 2007 and 2008 50.54(t) audit reports. This inspection was conducted in accordance with]]
| |
| : [[NRC]] [[Inspection Procedure 71114, Attachment .05. Planning Standard,]]
| |
| : [[10 CFR]] [[50.47(b) (14) and the related requirements of 10]]
| |
| CFR 50 Appendix E were used
| |
| as reference criteria. b. Findings No findings of significance were identified.
| |
| : [[1EP]] [[6 Drill Evaluation (71114.06 - 1 sample) a. Inspection Scope The inspectors completed one drill evaluation inspection sample. The inspectors observed control room operator emergency plan response actions during a licensed operator requalification training scenario on February 10, 2009. The inspectors verified that emergency classification declarations and notifications were completed in accordance with 10]]
| |
| CFR 50.72, 10 CFR 50, Appendix E, and the Hope Creek
| |
| emergency plan implementing procedures. Documents reviewed for this inspection are listed in the Attachment.
| |
| 2 b. Findings No findings of significance were identified.
| |
| 4.
| |
| : [[OTHER]] [[]]
| |
| : [[ACTIVI]] [[TIES]]
| |
| : [[4OA]] [[1 Performance Indicator Verification (71151 - 6 samples) a. Inspection Scope The inspectors reviewed]]
| |
| PSEG's program for gathering, evaluating and reporting
| |
| information for the performance indicators (PIs) listed below. The inspectors used the definitions and guidance contained in
| |
| : [[NEI]] [[(Nuclear Energy Institute) 99-02, "Regulatory Assessment Performance Indicator Guideline," Revision 5, to assess the accuracy of]]
| |
| : [[PSEG]] [['s collection and reporting of]]
| |
| : [[PI]] [[data. The documents reviewed by the inspectors are listed in the Attachment. Cornerstone: Initiating Events * Unplanned Scrams per 7000 Critical Hours * Unplanned Scrams with Complications * Unplanned Power Changes per 7000 Critical Hours The inspectors reviewed the data reported for these]]
| |
| PIs for the period January 1 through
| |
| December 31, 2008. The records reviewed included
| |
| : [[PI]] [[data summary reports, licensee event reports, monthly operating reports, and operator narrative logs. The inspectors verified the accuracy of the number of critical hours reported, and interviewed the system engineers responsible for data collection and evaluation. Cornerstone: Emergency Preparedness * Drill and Exercise Performance *]]
| |
| : [[ERO]] [[Drill Participation *]]
| |
| : [[ANS]] [[Reliability For the]]
| |
| : [[PI]] [[s listed above, to verify the accuracy of the reported data, the inspectors reviewed the]]
| |
| : [[PI]] [[data, supporting documentation and the information]]
| |
| PSEG reported, from the second quarter through the fourth quarter of 2008 b. Findings No findings of significance were identified. 4OA2 Identification and Resolution of Problems (71152)
| |
| .1 Review of Items Entered into the Corrective Action Program: As required by Inspection Procedure 71152, "Identification and Resolution of Problems," and in order to help identify repetitive equipment failures or specific human performance issues for follow-up, the inspectors performed a daily screening of all items entered into
| |
| : [[13PSEG]] [['s corrective action program. This was accomplished by reviewing the description of each new notification and attending daily management review committee meetings. 4]]
| |
| OA3 Event Followup (71153 - 1 sample) .1 (Closed) LER 05000354/2009-001, Reactor Manual Scram Due to Turbine Runback On January 17, 2009, operators initiated a manual reactor scram in response to a main turbine runback caused by a loss of main generator stator cooling. The loss of stator cooling occurred due to a turbine auxiliary cooling system isolation valve that failed shut. The solenoid for the valve was determined to have a detached lead. This lead had been
| |
| replaced approximately one week prior to the event. This condition was not caused by a performance deficiency associated with the maintenance activity. The resident inspectors responded to the site and verified that plant systems responded as designed to the transient and operator response was consistent with plant procedures. The inspectors reviewed control board indications, plant logs, computer alarm data, and other post-transient records and data. The inspectors also reviewed
| |
| : [[PSEG]] [['s prompt investigation, apparent cause evaluation, and root cause evaluation for this event. The inspectors reviewed]]
| |
| : [[LER]] [[05000354/2009-001 and determined that the direct cause, the solenoid failure, was not within]]
| |
| : [[PS]] [[]]
| |
| EG's ability to foresee and correct, and therefore
| |
| would not meet the screening criteria for a finding. The inspectors identified no findings of significance and determined there was no violation of
| |
| : [[NRC]] [[requirements. This]]
| |
| LER is closed. 4OA5 Other Activities .1 Quarterly Resident Inspector Observations of Security Personnel and Activities a. Inspection Scope During the inspection period, the inspectors conducted observations of security force
| |
| personnel and activities to ensure that the activities were consistent with
| |
| : [[PS]] [[]]
| |
| EG security procedures and regulatory requirements relating to nuclear plant security. These observations took place during both normal and off-normal plant working hours. These quarterly resident inspector observations of security force personnel and activities did not constitute any additional inspection samples. Rather, they were considered an
| |
| integral part of the inspectors' normal plant status review and inspection activities. b. Findings No findings of significance were identified. .2 TI 2515/173, Review of the Implementation of the Industry Ground Water Protection Voluntary Initiative a. Inspection Scope
| |
| 14On March 9-13, 2009, the inspectors assessed
| |
| : [[PSEG]] [['s ground water protection program to verify that]]
| |
| : [[PSEG]] [[implemented the voluntary industry Ground Water Protection Initiative (GPI). The]]
| |
| : [[GPI]] [[was unanimously approved by a formal vote of the Nuclear Energy Institute (]]
| |
| NEI) member utility chief nuclear officers. This established the industry's commitment to implement the initiative. The GPI identifies the actions the industry deemed necessary for implementation of a timely and effective ground water
| |
| protection program. The inspectors verified that the following objectives for the
| |
| : [[GPI]] [[were contained in]]
| |
| PSEG's program: 1.1 Site Hydrology and Geology 1.2 Site Risk Management 1.3 On-Site Ground Water Monitoring 1.4 Remediation Process 1.5 Record Keeping 2.1 Stakeholder Briefing 2.2 Voluntary Communication
| |
| 2.3 Thirty-Day Reports 2.4 Annual Reporting 3.1 Perform a Self-Assessment 3.2 Review the Program Under the Auspices of
| |
| : [[NEI]] [[Unit 2 Emergency Sump The inspectors reviewed documentation and]]
| |
| : [[PSEG]] [[actions related to the identification of tritium in the Unit 2 emergency sump, located below the 54' elevation in the turbine building. The inspectors discussed with]]
| |
| : [[PS]] [[]]
| |
| EG the testing and reviews conducted to
| |
| determine the source of the tritium.
| |
| : [[PSEG]] [['s investigation determined that the source of the tritium was condensation from the turbine building administrative area heating ventilation and air conditioning (]]
| |
| : [[HVAC]] [[) unit, and that the tritium from the condensation came from the Technical Specification/Offsite Dose Calculation Manual authorized effluent releases from the plant vents being drawn into the]]
| |
| : [[HV]] [[]]
| |
| AC intake. The inspectors
| |
| confirmed that the information developed from
| |
| : [[PSEG]] [['s investigation, including various system testing and data collection, supported this conclusion. The inspectors also reviewed]]
| |
| PSEG's investigation efforts and actions taken to determine the cause of frequent makeup of water volume to the condensate storage
| |
| tank. While investigation is still continuing,
| |
| : [[PS]] [[]]
| |
| EG's efforts did provide basis to conclude that there were no leaks to ground water in associated underground piping, valving, or the tank. b. Findings No findings of significance were identified.
| |
| .3 Correction to
| |
| : [[NRC]] [[Cross-Cutting Aspect Coding of]]
| |
| : [[NRC]] [[Finding NCV 05000354/2009006-03, Failure to Follow Procedures Contributes to Emergency Diesel Generator Inoperability]]
| |
| : [[15NRC]] [[Inspection Report 05000354/2009006 dated March 16, 2009, documented a Green finding associated with]]
| |
| : [[PSEG]] [['s failure to follow a surveillance test procedure. The finding had a cross-cutting aspect in the area of human performance and the aspect of work practices, procedural compliance, because]]
| |
| : [[PS]] [[]]
| |
| EG personnel did not follow procedures. However, the finding documentation in Inspection Report 05000354/2009006 contained a typographical error. Specifically, in analysis section for
| |
| the finding and the summary of findings section for the report the cross-cutting aspect code for this finding was incorrectly listed as
| |
| : [[H.]] [[2(b). The correct cross-cutting aspect code for this finding was H.4(b). .4]]
| |
| : [[TI]] [[2515/175, Emergency Response Organization, Drill/Exercise Performance Indicator Program Review The inspectors performed]]
| |
| : [[TI]] [[2515/175, ensured the completeness of]]
| |
| : [[PSEG]] [['s completed Attachment 1 from the]]
| |
| : [[TI]] [[, and then forwarded the data to]]
| |
| : [[NRC]] [[,]]
| |
| : [[HQ.]] [[4]]
| |
| : [[OA]] [[6 Meetings, Including Exit The resident inspectors presented the inspection results to Mr. George Barnes and other members of]]
| |
| : [[PSEG]] [[staff on April 8, 2009. The inspectors verified that proprietary material reviewed by the inspectors during this period was properly controlled and the content of the report includes no proprietary information.]]
| |
| : [[ATTACH]] [[MENT:]]
| |
| : [[SUPPLE]] [[]]
| |
| : [[MENTAL]] [[]]
| |
| : [[INFORM]] [[]]
| |
| : [[ATION]] [[Attachment]]
| |
| : [[SUPPLE]] [[]]
| |
| : [[MENTAL]] [[]]
| |
| : [[INFORM]] [[]]
| |
| : [[ATION]] [[]]
| |
| : [[KEY]] [[]]
| |
| : [[POINTS]] [[]]
| |
| : [[OF]] [[]]
| |
| CONTACT
| |
| Licensee Personnel G. Barnes, Site Vice President B. Booth, Operations Director D. Burgin, Corporate Emergency Preparedness Manager R. Canziani, Maintenance Director
| |
| : [[E.]] [[Casulli, Shift Operations Superintendent K. Chambliss, Assistant Plant Manager P. Duca, Senior Engineer, Regulatory Assurance K. Knaide, Engineering Director M. Gaffney, Regulatory Assurance Manager J. Perry, Plant Manager J. Sears, Chemistry Manager]]
| |
| : [[H.]] [[Trimble, Radiation Protection Manager]]
| |
| : [[LIST]] [[]]
| |
| : [[OF]] [[]]
| |
| : [[ITEMS]] [[]]
| |
| : [[OPENED]] [[,]]
| |
| : [[CLOSED]] [[,]]
| |
| : [[AND]] [[]]
| |
| : [[DISCUS]] [[SED Closed 05000354/2009-001]]
| |
| : [[LER]] [[Reactor Manual Scram Due to Turbine Runback (Section 4]]
| |
| OA3.1)
| |
| Discussed 05000354/2009006-03
| |
| : [[NCV]] [[Failure to Follow Procedures Contributes to Emergency Diesel Generator Inoperability (Section 4]]
| |
| : [[OA]] [[5.3)]]
| |
| : [[LIST]] [[]]
| |
| : [[OF]] [[]]
| |
| : [[DOCUME]] [[]]
| |
| : [[NTS]] [[]]
| |
| : [[REVIEW]] [[]]
| |
| : [[ED]] [[In addition to the documents identified in the body of this report, the inspectors reviewed the following documents and records: Hope Creek Generating Station (HCGS) Updated Final Safety Analysis Report Technical Specification Action Statement Log (SH.OP-AP.ZZ-108)]]
| |
| : [[HCGS]] [[]]
| |
| : [[NCO]] [[Narrative Logs]]
| |
| : [[HC]] [[]]
| |
| GS Plant Status Reports
| |
| Weekly Reactor Engineering Guidance to Hope Creek Operations Hope Creek Operations Night Orders and Temporary Standing Orders
| |
| Attachment Section 1R01: Adverse Weather Protection Procedures
| |
| : [[WC]] [[-]]
| |
| AA-107, Seasonal Readiness, Revision 8 Notifications *NRC identified 20319618 20319616 20346435 20329266 *20403377 *20403912
| |
| Other Documents
| |
| : [[HWM]] [[-08-0013, 2008 Site Winter/Grassing Readiness - Hope Creek Generating Station, 10/31/2008 Hope Creek Winter/Grassing Readiness Report and Weekly Information Update Section 1R04: Equipment Alignment Procedures]]
| |
| : [[HC.OP]] [[-SO.KJ-0001, Emergency Diesel Generators Operation, Revision]]
| |
| : [[46 HC.OP]] [[-]]
| |
| : [[SO.EA]] [[-0001, Service Water System Operation, Revision]]
| |
| : [[34 HC.OP]] [[-]]
| |
| : [[SO.EG]] [[-0001, Safety and Turbine Auxiliaries Cooling Water System Operation, Revision]]
| |
| : [[40 HC.OP]] [[-]]
| |
| : [[IS.BH]] [[-0001, Standby Liquid Control Valve Operability Test - Monthly, Revision]]
| |
| : [[42 HC.OP]] [[-]]
| |
| : [[IS.BH]] [[-0101, Standby Liquid Control System Valves - Inservice Test, Revision]]
| |
| : [[9 HC.OP]] [[-]]
| |
| : [[ST.BH]] [[-0002, Standby Liquid Control Flow Test - 18 Months, Revision]]
| |
| : [[25 HC.OP]] [[-]]
| |
| SO.BH-0001, Standby Liquid Control System Operation, Revision 10 Drawings M-11-1, Safety Auxiliaries Cooling Reactor Building, Revision 40
| |
| M-48-1, Standby Liquid Control, Revision 15 Section 1R05: Fire Protection Procedures
| |
| : [[NC.FP]] [[-]]
| |
| : [[AP.ZZ]] [[-0005, Fire Protection Surveillance and Periodic Test Program, Revision]]
| |
| : [[14 NC.FP]] [[-]]
| |
| : [[AP.ZZ]] [[-0025, Operational Fire Protection Program, Revision 7]]
| |
| : [[OP]] [[-]]
| |
| : [[AA]] [[-201-009, Control of Transient Combustible Material, Revision]]
| |
| : [[1 HC.FP]] [[-]]
| |
| : [[SV.ZZ]] [[-0026(F), Flood and Fire Barrier Penetration Seal Inspection, Revision]]
| |
| : [[4 NC.FP]] [[-]]
| |
| : [[AP.ZZ]] [[-0009, Fire Protection Training Program, Revision 5 Notifications *NRC-identified *20406254 Other Documents]]
| |
| : [[FRH]] [[-]]
| |
| : [[II]] [[-541, 1E Switchgear, Revision]]
| |
| : [[7 FRH]] [[-]]
| |
| : [[II]] [[-542, Control Equipment Mezzanine Area, Revision]]
| |
| : [[9 FRH]] [[-]]
| |
| : [[II]] [[-713, Service Water Intake Structure, Revision]]
| |
| : [[4 FRH]] [[-]]
| |
| II-434, MCC Area, Revision 3
| |
|
| |
|
| Attachment Section 1R06: Flood Protection Measures
| | ===Closed=== |
| Procedures
| | : 05000354/2009-001 LER Reactor Manual Scram Due to Turbine Runback (Section 4OA3.1) |
| : [[OP]] [[-]] | |
| HC-103-102-1005, High Energy and Internal Flooding Barrier Control Program, Revision 0 Drawings A-4641-1, Reactor Building Unit 1 Floor Plan at Elevation 54'
| |
| 2-1, Reactor Building Unit 1 Floor Plan at Elevation 77' Other Documents Calculation 11-92, Reactor Building Flooding - El. 54' and 77', Revision 5 Section 1R11: Licensed Operator Requalification Program Procedures
| |
| : [[HC.OP]] [[-]]
| |
| : [[AB.ZZ]] [[-0001, Transient Plant Conditions, Revision 16]]
| |
| : [[HC.OP]] [[-]]
| |
| : [[AB.RPV]] [[-0006, Safety Relief Valve, Revision]]
| |
| : [[3 HC.OP]] [[-]]
| |
| : [[AB.RPV]] [[-0004, Reactor Level Control, Revision]]
| |
| : [[6 HC.OP]] [[-]]
| |
| : [[AB.ZZ]] [[-0000, Reactor Scram, Revision 3 Other Documents Hope Creek Generating Station Emergency Classification Guide Simulator Scenario Guide]]
| |
| : [[SG]] [[-654,]]
| |
| : [[SRV]] [[fails open / Loss of Primary Condensate Pumps / Mode Switch Failure / Failure of]]
| |
| : [[HPCI]] [[to Auto-initiate Section 1R12: Maintenance Effectiveness Procedures]]
| |
| : [[HC.OP]] [[-AB.COOL-001, Station Service Water, Revision]]
| |
| : [[17 HC.OP]] [[-]]
| |
| : [[SO.EA]] [[-0001, Service Water System Operation, Revision 34]]
| |
| : [[HC.OP]] [[-]]
| |
| : [[SO.BJ]] [[-0001, High Pressure Coolant Injection Operation, Revision]]
| |
| : [[37 WC]] [[-]]
| |
| : [[AA]] [[-101, On-line Work Management Process, Revision]]
| |
| : [[16 ER]] [[-]]
| |
| : [[AA]] [[-310, Implementation of the Maintenance Rule, Revision]]
| |
| : [[6 ER]] [[-]]
| |
| : [[AA]] [[-310-1001, Maintenance Rule - Scoping, Revision]]
| |
| : [[3 ER]] [[-]]
| |
| : [[AA]] [[-310-1003, Maintenance Rule - Performance Criteria Selection, Revision 3]]
| |
| : [[ER]] [[-]]
| |
| : [[AA]] [[-310-1004, Performance Monitoring, Revision 7 Drawings]]
| |
| : [[PN]] [[1-E41-C002-0050, Oil Piping Diagram, Revision 0 M-55-1,]]
| |
| : [[HPCI]] [[]]
| |
| : [[P&]] [[]]
| |
| ID Mech/Cont, Revision 39
| |
| Notifications 20373393 20383071 20382963 20389013 20356470 20402660 20402671 20402908 20402662 20402661 20402653 20401726
| |
| Orders 70086290 70070456
| |
|
| |
|
| Attachment Other Documents Hope Creek Maintenance Rule Status and Projections, dated February 5, 2009 Hope Creek
| | ===Discussed=== |
| : [[SHIP]] [[System Summary Report, 4th Quarter 2008 System Function Level Maintenance Rule Scoping Information Maintenance Rule System Function and Risk Information Section 1R13: Maintenance Risk Assessments and Emergent Work Control Procedures]] | | : 05000354/2009006-03 NCV Failure to Follow Procedures Contributes to Emergency Diesel Generator Inoperability (Section 4OA5.3) |
| : [[OP]] [[-AA-101-112-1002, On-Line Risk Assessment, Revision 2]]
| |
| : [[WC]] [[-]]
| |
| AA-101, On-Line Work Management Process, Revision 16 Notifications *NRC-identified *20400675 20403118
| |
| Orders 70094278 Section 1R15: Operability Evaluations Procedures
| |
| : [[HC.OP]] [[-]]
| |
| : [[SO.BJ]] [[-0001, High Pressure Coolant Injection Operation, Revision]]
| |
| : [[37 HC.OP]] [[-]]
| |
| : [[IS.BJ]] [[-0001,]]
| |
| : [[HPCI]] [[Main and Booster Pump Set - In-service Test, Revision 51]]
| |
| : [[HC.OP]] [[-AR.ZZ-0023,]]
| |
| : [[CRIDS]] [[Computer Points Book 4, Revision 6]]
| |
| : [[HC.OP]] [[-AR.ZZ-0022,]]
| |
| : [[CRIDS]] [[Computer Points Book 3, Revision 5]]
| |
| : [[HC.OP]] [[-AR.AP-0001, Condensate and Refuel Storage and Transfer Local Panel, Revision]]
| |
| : [[8 OP]] [[-]]
| |
| : [[AA]] [[-108-115, Operability Determinations, Revision]]
| |
| : [[1 HC.OP]] [[-]]
| |
| : [[AB.COO]] [[L-001, Station Service Water, Revision 17]]
| |
| : [[HC.OP]] [[-]]
| |
| : [[SO.EA]] [[-0001, Service Water System Operation, Revision]]
| |
| : [[34 HC.RE]] [[-]]
| |
| : [[RA.BF]] [[-0002, Channel Distortion Testing, Revision 5 Calculations]]
| |
| : [[SC]] [[-]]
| |
| : [[AP]] [[-0001, Condensate Storage Tank Low Level Switch to]]
| |
| : [[HPCI]] [[& Tank 135,000 Gal Reserve, Revision 6]]
| |
| : [[SC]] [[-AP-0003, Condensate Storage Tank Low Level to]]
| |
| : [[RCIC]] [[, Revision 7]]
| |
| : [[AP]] [[-0004, Condensate Storage Tank Level Set Points -]]
| |
| : [[EPU]] [[, Revision 7]]
| |
| PN0-E41-4010-0072, High Pressure Coolant Injection, Revision 10 22A6237, High Pressure Coolant Injection
| |
| Drawings M-55-1,
| |
| : [[HPCI]] [[P&]]
| |
| ID Mech/Cont, Revision 39 M-30-1, Diesel Engine Auxiliary Systems Fuel Oil, Revision 26
| |
| Notifications *NRC-identified *20405785 *20406260 *20405617 *20407300 20396692 20198545 20400785 20401222 20400174 20399809 20399810 20400121 20406048 20404376 20399912 20367624
| |
| Orders 50097446 50104249 50106733 50093625 70093928
| |
| Attachment Other Documents Hope Creek Generating Station Human Reliability Analysis, Revision
| |
| : [[3 GE]] [[/Hitachi 10]]
| |
| : [[CFR]] [[21 Communication]]
| |
| : [[SC]] [[08-05, Updated Surveillance Program for Channel - Control Blade Interference Monitoring, Revision 1 Section 1R18: Plant Modifications Procedures]]
| |
| : [[CC]] [[-AA-112, Temporary Configuration Changes, Revision]]
| |
| : [[11 CC]] [[-]]
| |
| : [[AA]] [[-112-1001, Temporary Configuration Change Implementation]]
| |
| : [[T&]] [[]]
| |
| : [[RM]] [[, Revision 1]]
| |
| : [[LS]] [[-]]
| |
| : [[AA]] [[-104-1001, 50.59 Review Coversheet Form, Revision]]
| |
| : [[2 LS]] [[-]]
| |
| : [[AA]] [[-104-1002, 50.59 Applicability Review Form, Revision]]
| |
| : [[2 LS]] [[-]]
| |
| : [[AA]] [[-104-1003, 50.59 Screening Form, Revision 1 Orders 80097753 Other Documents]]
| |
| : [[4HT]] [[-09-001, Temporary Power Feeds From Substation #9, Revision 1 Section 1R19: Post-Maintenance Testing Procedures]]
| |
| : [[HC.IC]] [[-FT.JE-0003, Emergency Diesel Generator C Day Tank Level Switches, Revision]]
| |
| : [[3 HC.IC]] [[-]]
| |
| : [[GP.ZZ]] [[-0067, General Instrument Calibration, Revision]]
| |
| : [[13 HC.MD]] [[-]]
| |
| : [[GP.ZZ]] [[-0055, Magnetrol Liquid Level Detector]]
| |
| : [[P.M.]] [[and Calibration, Revision 7]]
| |
| : [[MA]] [[-AA-716-012, Post Maintenance Testing, Revision]]
| |
| : [[12 HC.OP]] [[-]]
| |
| ST.KJ-0003, Emergency Diesel Generator Operability Test - Monthly, Revision 66
| |
| Calculations
| |
| : [[SC]] [[-]]
| |
| : [[JE]] [[-0059, Diesel Fuel Oil Day Tank Level, Revision 6 10855-JE-13, Volume of Diesel Fuel Oil in Diesel Fuel Oil Day Tank at Setpoints, Revision 3 Drawings]]
| |
| : [[PM]] [[018Q-0087, Tank 550 Gallon Fuel Oil Day]]
| |
| : [[ASME]] [[]]
| |
| : [[III]] [[, 8/31/94 Notifications *]]
| |
| NRC-identified *20404345 *20397661 *20397987 *20402772 *20402389 *20407000 20393065 20403928 20088715 20379530
| |
| Orders 30134833 50120642 70035038 60078265 60080169 60080750 70093493 70091844 50120642 Section 1R22: Surveillance Testing Procedures
| |
| : [[OP]] [[-]]
| |
| HC-103-102-1005, High Energy and Internal Flooding Barrier Control Program, Revision 0
| |
| Completed Surveillances
| |
| : [[HC.IC]] [[-]]
| |
| : [[FT.SE]] [[-0006, Nuclear Instrumentation Intermediate Range Monitor Test, 1/19/09]]
| |
| : [[HC.OP]] [[-]]
| |
| ST.KJ-0002, Emergency Diesel Generator 1BG400 Operability Test, 2/11/09
| |
| Attachment
| |
| : [[HC.OP]] [[-]]
| |
| : [[IS.BJ]] [[-0001,]]
| |
| : [[HPCI]] [[Main and Booster Pump Set - In-service Test, 2/24/09]]
| |
| : [[HC.OP]] [[-ST.KJ.0017, Emergency Diesel Generator]]
| |
| : [[1DG]] [[400 - 24 Hour Operability Run and Hot Restart Test, 2/18/09]]
| |
| : [[HC.OP]] [[-IS.BD-0001, Reactor Core Isolation Cooling Pump, 2/19/09]]
| |
| : [[HC.OP]] [[-]]
| |
| ST.GK-0005, Control Room Emergency Air Supply Fan Operability Test, 3/19/09
| |
| Orders 50120468 Notifications 20406899
| |
|
| |
|
| Section
| | ==LIST OF DOCUMENTS REVIEWED== |
| : [[1EP]] [[2: Alert and Notification System (]]
| |
| ANS) Evaluation
| |
| American Signal Corporation Final
| |
| : [[REP]] [[-10 Design Review Report,]]
| |
| : [[PSEG]] [[Salem and Hope Creek Generating Stations]]
| |
| : [[EP]] [[-]]
| |
| : [[AA]] [[-121, Emergency Response Facilities and Equipment Readiness, Revision]]
| |
| : [[0 EP]] [[-]]
| |
| : [[AA]] [[-121-1002,]]
| |
| : [[PSEG]] [[Alert Notification System (]]
| |
| : [[ANS]] [[) Program, Revision 0]]
| |
| : [[EP]] [[-]]
| |
| : [[AA]] [[-121-1004,]]
| |
| : [[PSEG]] [[]]
| |
| : [[ANS]] [[Corrective Maintenance, Revision]]
| |
| : [[0 EP]] [[-]]
| |
| : [[AA]] [[-121-1005,]]
| |
| : [[PSEG]] [[]]
| |
| : [[ANS]] [[Preventive Maintenance Program, Revision]]
| |
| : [[1 EP]] [[-]]
| |
| : [[AA]] [[-121-1006,]]
| |
| : [[PSEG]] [[]]
| |
| : [[ANS]] [[Siren Monitoring, Troubleshooting, and Testing, Revision]]
| |
| : [[0 ANS]] [[-related Condition Reports, dated January 2008 - March 2009 Section 1]]
| |
| : [[EP]] [[3: Emergency Response Organization (ERO) Staffing and Augmentation System]]
| |
| : [[PSEG]] [[Nuclear]]
| |
| : [[LLC]] [[Emergency Plan, Revision]]
| |
| : [[62 EP]] [[-]]
| |
| : [[AA]] [[-121-1001, Automated Call-Out System Maintenance]]
| |
| : [[NC.EP]] [[-]]
| |
| : [[AP.ZZ]] [[-1011 (Z), Maintenance of Emergency Response Organization, Revision]]
| |
| : [[9 EPIP]] [[204S, Emergency Response Callout/Personnel Recall, Revision 70]]
| |
| : [[EPIP]] [[204H, Emergency Response Callout/Personnel Recall, Revision 70 January Monthly Callout Check (pagers) February Monthly Callout Check (pagers)]]
| |
| : [[ERO]] [[Roster]]
| |
| : [[ERO]] [[Assignment]]
| |
| : [[ERO]] [[Qualifications Section 1]]
| |
| : [[EP]] [[4: Emergency Action Level (EAL) and Emergency Plan Changes]]
| |
| : [[PSEG]] [[Nuclear]]
| |
| : [[LLC]] [[Emergency Plan, Revision]]
| |
| : [[62 EP]] [[-]]
| |
| : [[AA]] [[-120, Emergency Plan Administration, Revision]]
| |
| : [[0 EP]] [[-]]
| |
| : [[AA]] [[-120-1001,]]
| |
| : [[10CFR]] [[50.54(q) Change Evaluation, Revision 0]]
| |
| : [[EP]] [[-AA-120-1003, Emergency Preparedness Document Processing, Revision]]
| |
| : [[0 EP]] [[-]]
| |
| : [[AA]] [[-120-1005, Emergency Plan and Event Classification Guide Content/Format, Revision]]
| |
| : [[1 EP]] [[-]]
| |
| : [[AA]] [[-124, Inventories and Surveillances, Revision 0]]
| |
| : [[EP]] [[-]]
| |
| : [[AA]] [[-124-1001, Facilities Inventories and Equipment Tests, Revision]]
| |
| : [[0 LS]] [[-]]
| |
| : [[AA]] [[-104, Exelon 50.59 Review Process, Revision]]
| |
| : [[5 LS]] [[-]]
| |
| : [[AA]] [[-104-1000, 50.59 Resource Manual, Revision]]
| |
| : [[4 LS]] [[-]]
| |
| AA-104-1007, Emergency Plan Guidance for Salem and Hope Creek Stations, Revision 0 Emergency Preparedness 10CFR50.54(q) screenings performed between May 2008 - March
| |
| 2009
| |
| Attachment Section
| |
| : [[1EP]] [[5: Correction of Emergency Preparedness Weaknesses]]
| |
| : [[LS]] [[-AA-120, Issue Identification and Screening Process, Revision]]
| |
| : [[8 LS]] [[-]]
| |
| : [[AA]] [[-125, Corrective Action Program (CAP) Procedure, Revision]]
| |
| : [[12 EP]] [[-]]
| |
| : [[AA]] [[-122, Drills and Exercises, Revision 0]]
| |
| : [[EP]] [[-]]
| |
| : [[AA]] [[-122-1001-F10, Drill and Exercise Post Event Critique and Report Development Guidance, Revision]]
| |
| : [[0 EP]] [[-]]
| |
| : [[AA]] [[-121-1001, Automated Call-Out System Maintenance, Revision 0 Nuclear Oversight Audits:]]
| |
| : [[NOSA]] [[-]]
| |
| : [[HPC]] [[-08-02]]
| |
| : [[NOSA]] [[-]]
| |
| : [[HPC]] [[-07-04]]
| |
| : [[NOSA]] [[-]]
| |
| : [[HPC]] [[-06-03 Event Follow-up Report for the Hope Creek August 2008 Unusual Event Declaration]]
| |
| : [[ERO]] [[Common Cause Analysis Report]]
| |
| ERO Common Cause Analysis Report, Revision 1 Emergency Preparedness Drill Reports, dated January 2008 - March 2009 Emergency Preparedness-related Condition Reports, dated January 2008 - March 2009
| |
|
| |
|
| Section
| |
| : [[1EP]] [[6: Drill Evaluation Procedures]]
| |
| : [[HC.OP]] [[-AB.ZZ-0001, Transient Plant Conditions, Revision]]
| |
| : [[16 HC.OP]] [[-]]
| |
| : [[AB.RPV]] [[-0006, Safety Relief Valve, Revision]]
| |
| : [[3 HC.OP]] [[-]]
| |
| : [[AB.RPV]] [[-0004, Reactor Level Control, Revision 6]]
| |
| : [[HC.OP]] [[-]]
| |
| : [[AB.ZZ]] [[-0000, Reactor Scram, Revision 3 Other Documents Hope Creek Generating Station Emergency Classification Guide Section]]
| |
| : [[4OA]] [[1: Performance Indicator Verification Procedures]]
| |
| : [[LS]] [[-AA-2001, Collecting and Reporting of NRC Performance Indicator Data, Revision 10]]
| |
| : [[LS]] [[-]]
| |
| : [[AA]] [[-2010, Monthly Data Elements for]]
| |
| : [[NRC]] [[/]]
| |
| : [[WANO]] [[Unit/Reactor Shutdown Occurrences, Revision]]
| |
| : [[6 LS]] [[-]]
| |
| : [[AA]] [[-2030, Monthly Data Elements for]]
| |
| : [[NRC]] [[Unplanned Power Changes per 7000 Critical Hours, Revision 6]]
| |
| : [[EP]] [[-AA-125-1001, EP Performance Indicator Guidance, Revision 0]]
| |
| : [[DEP]] [[]]
| |
| : [[PI]] [[data, April 2008 - December]]
| |
| : [[2008 ERO]] [[Drill Participation]]
| |
| : [[PI]] [[data, April 2008 - December]]
| |
| : [[2008 ANS]] [[Reliability]]
| |
| : [[PI]] [[data, April 2008 - December 2008 Other Documents Hope Creek Integrated Inspection Reports 2008002 , 2008003, 2008004,]]
| |
| : [[2008005 NRC]] [[Performance Indicators for 1st quarter, 2nd quarter, 3rd quarter, and 4th quarter]]
| |
| : [[NEI]] [[99-02, Regulatory Assessment Performance Indicator Guideline, Revision 5 Section]]
| |
| : [[4OA]] [[3: Event Followup Procedures]]
| |
| OP-AA-108-114, Post Transient Review, Revision 3
| |
| Attachment
| |
| : [[OP]] [[-]]
| |
| HC-108-114-1001, Hope Creek Post-Trip Data Collection Guidelines, Revision 2 Notifications 20398232 20398234 20308825 20402784 Orders 70093613 70064952 Other Documents Prompt Investigation for 20398232 LER 05000354/2009001, dated 3/16/2009
| |
| Training diagram 080-01, Safety and Turbine Auxiliaries Cooling System Post-transient alarm data Section
| |
| : [[4OA]] [[5: Other Activities Procedures]]
| |
| : [[CY]] [[-AA-170-400, Revision 3, Radiological Ground Water Protection Program]]
| |
| : [[ER]] [[-]]
| |
| : [[AA]] [[-5400, Revision 1, Buried Piping Program Guide]]
| |
| : [[ER]] [[-]]
| |
| : [[AA]] [[-5400-1002, Revision 1, Buried Piping Examination Guide]]
| |
| : [[SH.RA]] [[-]]
| |
| : [[IS.ZZ]] [[-0109(Q), Revision 4, Storage Tank Integrity Testing]]
| |
| : [[OP]] [[-]]
| |
| : [[SH]] [[-111-101-1001, Revision 1, Use and Development of Operating Logs]]
| |
| : [[LS]] [[-]]
| |
| : [[AA]] [[-125, Revision 12, Corrective Action Program Procedure]]
| |
| : [[HC.MD]] [[-]]
| |
| : [[DG.ZZ]] [[-0091(Z), Revision 1, Desktop Guide Leak Management Coordination]]
| |
| : [[CY]] [[-]]
| |
| : [[AA]] [[-170-4000, Revision 6, Radiological Ground Water Protection Program Implementation]]
| |
| : [[CY]] [[-]]
| |
| : [[AA]] [[-170-4160, Revision 1, Station]]
| |
| : [[RGPP]] [[Controlled Sample Point Parameters]]
| |
| : [[CY]] [[-AA-170-000, Revision 3, Radioactive Effluent and Environmental Monitoring Programs]]
| |
| : [[RP]] [[-]]
| |
| : [[AA]] [[-228, Revision 0,]]
| |
| : [[10CFR]] [[50.75(G) and 10]]
| |
| : [[CFR]] [[72.30(D) Documentation Requirements]]
| |
| : [[NC.CH]] [[-]]
| |
| : [[AP.ZZ]] [[-8011(Q), Revision 1, Unplanned Radiological Effluent Releases]]
| |
| : [[CY]] [[-]]
| |
| : [[AA]] [[-170-100, Revision 2, Radiological Environmental Monitoring Program]]
| |
| : [[LA]] [[-]]
| |
| AA-126-1005, Revision 3, Check-In Self-Assessment Other Documents Preliminary Assessment and Site Investigation Work Plan - Hope Creek Generating Station, April 2006 Site Investigation Report, Hope Creek Generating Station, July 2006 Updated Final Safety Analysis Report, Section 2.4 - Hydrology
| |
| American Nuclear Insurers Nuclear Liability Insurance Inspection - Report L071108.230, Salem/Hope Creek Nuclear Power Plant, July 23, 2008 Memorandum from
| |
| : [[E.]] [[Keating to J. Shelton, March 6, 2009, Subject:]]
| |
| : [[NEI]] [[07-07 Objective 2.1.a and 2.1.b Maplewood Testing Services, Work Instruction]]
| |
| : [[HB]] [[]]
| |
| LF-68, Groundwater Sampling Procedure
| |
| Off-Site Dose Calculation Manual, Revision 22 Check-In Self-Assessment, Tritium Ground Water, SAP Order 70087553
| |
| Attachment
| |
| : [[LIST]] [[]]
| |
| : [[OF]] [[]]
| |
| : [[ACRONY]] [[]]
| |
| : [[MS]] [[]]
| |
| : [[ANS]] [[Alert and Notification System]]
| |
| : [[CFR]] [[Code of Federal Regulations]]
| |
| : [[DEP]] [[Drill and Exercise Performance]]
| |
| : [[EAL]] [[Emergency Action Level]]
| |
| : [[EDG]] [[Emergency Diesel Generator]]
| |
| : [[EP]] [[Emergency Preparedness]]
| |
| : [[EPIP]] [[Emergency Plan Implementing Procedure]]
| |
| : [[ERO]] [[Emergency Response Organization GPI Ground Water Protection Initiative]]
| |
| : [[HCGS]] [[Hope Creek Generating Station]]
| |
| : [[HPCI]] [[High Pressure Coolant Injection]]
| |
| : [[HVAC]] [[Heating Ventilation and Air Conditioning]]
| |
| : [[MCC]] [[Motor Control Center]]
| |
| : [[MR]] [[Maintenance Rule]]
| |
| : [[NCV]] [[Non-cited Violation NEI Nuclear Energy Institute]]
| |
| : [[NRC]] [[Nuclear Regulatory Commission]]
| |
| : [[PI]] [[s Performance Indicators]]
| |
| : [[PS]] [[Planning Standard]]
| |
| : [[PSEG]] [[Public Service Enterprise Group Nuclear]]
| |
| : [[LLC]] [[]]
| |
| : [[PSID]] [[Pounds per Square Inch Differential]]
| |
| : [[SACS]] [[Safety Auxiliaries Cooling System]]
| |
| : [[SSC]] [[Structures, Systems, and Components]]
| |
| : [[ST]] [[Surveillance Testing]]
| |
| : [[SW]] [[Service Water TI Temporary Instruction]]
| |
| : [[UFS]] [[]]
| |
| : [[AR]] [[Updated Final Safety Analysis Report]]
| |
| }} | | }} |
|
---|
Category:Inspection Report
MONTHYEARIR 05000354/20230042024-02-0101 February 2024 Integrated Inspection Report 05000354/2023004 IR 05000354/20234012024-01-22022 January 2024 Material Control and Accounting Program Inspection Report 05000354/2023401 IR 05000354/20230032023-11-0707 November 2023 Integrated Inspection Report 05000354/2023003 IR 05000272/20234022023-10-12012 October 2023 and Salem Nuclear Generating Station, Units 1 and 2 - Security Baseline Inspection Report 05000354/2023402, 05000272/2023402 and 05000311/2023402 (Cover Letter Only) IR 05000354/20230052023-08-31031 August 2023 Updated Inspection Plan for Hope Creek Generating Station (Report 05000354/2023005) IR 05000354/20230022023-08-0303 August 2023 Integrated Inspection Report 05000354/2023002 and Independent Spent Fuel Storage Installation Inspection Report 07200048/2023001 IR 05000354/20230102023-08-0303 August 2023 Biennial Problem Identification and Resolution Inspection Report 05000354/2023010 IR 05000354/20230112023-05-0101 May 2023 Commercial Grade Dedication Report 05000354/2023011 IR 05000354/20230012023-04-26026 April 2023 Integrated Inspection Report 05000354/2023001 IR 05000354/20220062023-03-0101 March 2023 Annual Assessment Letter for Hope Creek Generating Station (Report 05000354/2022006) IR 05000354/20220042023-01-24024 January 2023 Integrated Inspection Report 05000354/2022004 ML22335A0412022-12-0101 December 2022 Notification of Commercial Grade Dedication Inspection (05000354/2023011) and Request for Information IR 05000354/20220032022-11-0303 November 2022 Integrated Inspection Report 05000354/2022003 IR 05000354/20223012022-10-24024 October 2022 Initial Operator Licensing Examination Report 05000354/2022301 IR 05000354/20224022022-10-14014 October 2022 Cyber Security Inspection Report 05000354/2022402 - Cover Letter Only IR 05000354/20220122022-09-0808 September 2022 Design Basis Assurance Inspection (Programs) Inspection Report 05000354/2022012 IR 05000354/20220052022-08-31031 August 2022 Updated Inspection Plan for Hope Creek Generating Station (Report 05000354/2022005) IR 05000354/20220022022-08-10010 August 2022 Integrated Inspection Report 05000354/2022002 IR 05000272/20224012022-07-21021 July 2022 and Salem Nuclear Generating Station, Units 1 and 2 - Security Baseline Inspection Report 05000354/2022401, 05000272/2022401, and 05000311/2022401 (Cover Letter Only) IR 05000272/20225012022-06-14014 June 2022 and Salem Nuclear Generating Station, Units 1 and 2 - Emergency Preparedness Biennial Exercise Inspection Report 05000354/2022501, 05000272/2022501, and 05000311/2022501 IR 05000354/20220012022-05-0202 May 2022 Integrated Inspection Report 05000354/2022001 IR 05000354/20220102022-03-16016 March 2022 Triennial Fire Protection Inspection Report 05000354/2022010 IR 05000272/20210132022-03-10010 March 2022 Evaluation of Changes, Tests, and Experiments Baseline IR 05000354/2021013, 05000272/2021013 and 05000311/2021013 & ISFSI IR 07200048/2021001 Related to PSEG Evals of Stations & Planned Wind Port Manufacturing Facility IR 05000354/20210062022-03-0202 March 2022 Annual Assessment Letter for Hope Creek Generating Station (Report 05000354/2021006) IR 05000354/20210042022-02-0707 February 2022 Integrated Inspection Report 05000354/2021004 IR 05000272/20215012021-11-30030 November 2021 and Salem Nuclear Generating Station, Units 1 and 2 - Emergency Preparedness Biennial Exercise Inspection Report 05000354/2021501, 05000272/2021501 and 05000311/2021501 IR 05000272/20214022021-11-19019 November 2021 and Salem Nuclear Generating Station, Units 1 and 2 - Security Baseline Inspection Report 05000354/2021402, 05000272/2021402 and 05000311/2021402 IR 05000354/20210032021-11-0202 November 2021 Integrated Inspection Report 05000354/2021003 IR 05000272/20210122021-10-28028 October 2021 and Salem Nuclear Generating Station, Units 1 and 2 - Biennial Problem Identification and Resolution Inspection Report 05000354/2021012, 05000272/2021012 and 05000311/2021012 IR 05000272/20214032021-10-28028 October 2021 and Salem Nuclear Generating Station, Units 1 and 2 - Biennial Problem Identification and Resolution Inspection Report (Security-Related Information) 05000354/2021403, 05000272/2021403 and 05000311/2021403 (Cover Letter Only IR 05000354/20210112021-09-30030 September 2021 Temporary Instruction 2515/194 Inspection Report 05000354/2021011 IR 05000354/20210102021-09-16016 September 2021 Design Bases Assurance Inspection (Teams) Inspection Report 05000354/2021010 IR 05000354/20210052021-09-0101 September 2021 Updated Inspection Plan for the Hope Creek Nuclear Generating Station (Report 05000354/2021005) IR 05000354/20210022021-08-10010 August 2021 Integrated Inspection Report 05000354/2021002 IR 05000354/20210012021-05-0404 May 2021 Integrated Inspection Report 05000354/2021001 IR 05000354/20213012021-04-0101 April 2021 Initial Operator Licensing Examination Report 05000354/2021301 IR 05000354/20200062021-03-0303 March 2021 Annual Assessment Letter for Hope Creek Generating Station Unit 1 (Report 05000354/2020006) IR 05000272/20214012021-02-23023 February 2021 and Salem Nuclear Generating Station, Units 1 and 2: Security Baseline Inspection Report 05000354/2021401, 05000272/2021401 and 05000311/2021401 (Letter Only) IR 05000354/20200042021-02-0909 February 2021 Integrated Inspection Report 05000354/2020004 ML21008A5092021-01-21021 January 2021 Inspection Report IR 05000354/20200032020-11-0404 November 2020 Integrated Inspection Report 05000354/2020003 IR 05000354/20200052020-08-31031 August 2020 Updated Inspection Plan (Inspection Report 05000354/2020005) IR 05000272/20204012020-07-23023 July 2020 Nuclear Generating Station, Units 1 and 2 and Hope Creek Generating Station: Security Baseline Inspection Report 05000272/2020401, 05000311/2020401, and 05000354/2020401 (Letter Only) IR 05000354/20200012020-05-0606 May 2020 Integrated Inspection Report 05000354/2020001 IR 05000354/20200102020-04-0808 April 2020 Reissued, Temporary Instruction 2515/194 Report 05000354/2020010 ML20077M1872020-03-20020 March 2020 Temporary Instruction 2515/194 Report 05000354/2020010 IR 05000354/20190062020-03-0303 March 2020 Annual Assessment Letter for Hope Creek Generating Station, Unit 1 (Report 05000354/2019006) IR 05000354/20190042020-02-10010 February 2020 Integrated Inspection Report 05000354/2019004 IR 05000354/20190032019-11-0707 November 2019 Integrated Inspection Report 05000354/2019003 IR 05000354/20193012019-10-17017 October 2019 Initial Operator Licensing Examination Report 05000354/2019301 2024-02-01
[Table view] Category:Letter
MONTHYEARIR 05000354/20230042024-02-0101 February 2024 Integrated Inspection Report 05000354/2023004 ML24030A8752024-02-0101 February 2024 Operator Licensing Examination Approval ML24009A1022024-01-26026 January 2024 Exemption from Select Requirements of 10 CF Part 73 (EPID L-2023-LLE-0045 (Security Notifications, Reports, and Recordkeeping and Suspicious Activity Reporting)) IR 05000354/20234012024-01-22022 January 2024 Material Control and Accounting Program Inspection Report 05000354/2023401 ML23341A1372024-01-16016 January 2024 Issuance of Amendment No. 235 Revise Trip and Standby Auto-Start Logic Associated with Safety Related Heating, Ventilation and Air Conditioning ML23335A1122023-12-15015 December 2023 Retest Schedule for Drywell to Suppression Chamber Vacuum Breakers ML23307A1532023-12-15015 December 2023 NRC Investigation Report No. 1-2023-001 ML23270C0072023-11-29029 November 2023 Notice of Proposed Amendment to Decommissioning Trust Agreement ML23324A3072023-11-17017 November 2023 Request for Exemption from Enhanced Weapons, Firearms Background Checks, and Security Event Notifications Implementation IR 05000354/20230032023-11-0707 November 2023 Integrated Inspection Report 05000354/2023003 IR 05000272/20234022023-10-12012 October 2023 and Salem Nuclear Generating Station, Units 1 and 2 - Security Baseline Inspection Report 05000354/2023402, 05000272/2023402 and 05000311/2023402 (Cover Letter Only) LR-N23-0065, Submittal of 2023 Annual 10 CFR 50.46 Report2023-10-0202 October 2023 Submittal of 2023 Annual 10 CFR 50.46 Report LR-N23-0045, and Peach Bottom Atomic Power Station, Units 2 and 3 - Notice of Proposed Amendment to Decommissioning Trust Agreement2023-09-0808 September 2023 and Peach Bottom Atomic Power Station, Units 2 and 3 - Notice of Proposed Amendment to Decommissioning Trust Agreement ML23249A2612023-09-0606 September 2023 License Amendment Request to Modify the Salem and Hope Creek Exclusion Area Boundary IR 05000354/20230052023-08-31031 August 2023 Updated Inspection Plan for Hope Creek Generating Station (Report 05000354/2023005) ML23192A8212023-08-14014 August 2023 and Salem Nuclear Generating Station, Unit Nos. 1 and 2 - Issuance of Amendment Nos. 234, 347, and 329 Revise Technical Specifications to Delete Meteorological Tower Location IR 05000354/20230022023-08-0303 August 2023 Integrated Inspection Report 05000354/2023002 and Independent Spent Fuel Storage Installation Inspection Report 07200048/2023001 IR 05000354/20230102023-08-0303 August 2023 Biennial Problem Identification and Resolution Inspection Report 05000354/2023010 LR-N23-0052, Retest Schedule for Drywell to Suppression Chamber Vacuum Breakers Per Technical Specification 4.6.2.12023-07-31031 July 2023 Retest Schedule for Drywell to Suppression Chamber Vacuum Breakers Per Technical Specification 4.6.2.1 LR-N23-0042, Spent Fuel Cask Registration2023-07-12012 July 2023 Spent Fuel Cask Registration LR-N23-0046, Emergency Plan Document Revisions Implemented June 28, 20232023-07-10010 July 2023 Emergency Plan Document Revisions Implemented June 28, 2023 IR 05000354/20230112023-05-0101 May 2023 Commercial Grade Dedication Report 05000354/2023011 ML23121A1412023-05-0101 May 2023 Senior Reactor and Reactor Operator Initial License Examinations LR-N23-0034, 2022 Annual Radiological Environmental Operating Report (AREOR) - Salem Nuclear Generating Station, Unit Nos. 1 and 2 and Hope Creek Generating Station2023-04-27027 April 2023 2022 Annual Radiological Environmental Operating Report (AREOR) - Salem Nuclear Generating Station, Unit Nos. 1 and 2 and Hope Creek Generating Station LR-N23-0035, 2022 Annual Radioactive Effluent Release Report (ARERR)2023-04-27027 April 2023 2022 Annual Radioactive Effluent Release Report (ARERR) IR 05000354/20230012023-04-26026 April 2023 Integrated Inspection Report 05000354/2023001 LR-N23-0010, License Amendment Request Revision of Technical Specification (TS) to Delete TS Section 5.5 - Meteorological Tower Location2023-04-21021 April 2023 License Amendment Request Revision of Technical Specification (TS) to Delete TS Section 5.5 - Meteorological Tower Location LR-N23-0009, License Amendment Request (LAR) to Revise the Hope Creek Trip and Standby Auto-start Logic Associated with Safety Related Heating, Ventilation and Air Conditioning (HVAC) Trains2023-04-18018 April 2023 License Amendment Request (LAR) to Revise the Hope Creek Trip and Standby Auto-start Logic Associated with Safety Related Heating, Ventilation and Air Conditioning (HVAC) Trains ML23087A1492023-04-17017 April 2023 NRC to PSEG Salem, Transmittal of the National Marine Fisheries Service'S March 24, 2023, Biological Opinion GAR-2020-02842 Concerning Salem and Hope Creek ML23089A0942023-04-17017 April 2023 NRC to PSEG Hope Creek, Transmittal of the National Marine Fisheries Service'S March 24, 2023, Biological Opinion GAR-2020-02842 Concerning Salem and Hope Creek ML23103A3232023-04-13013 April 2023 Submittal of Updated Final Safety Analysis Report, Rev. 26, Summary of Revised Regulatory Commitments for Hope Creek, Summary of Changes to PSEG Nuclear LLC, Quality Assurance Topical Report, NO-AA-10, Rev. 89 ML23095A3682023-04-12012 April 2023 and Salem Nuclear Generating Station, Unit Nos. 1 and 2 - Threshold Determination for Proposed Transfer of Land Ownership LR-N23-0024, Submittal of Hope Creek Generating Station Technical Specification Bases Changes2023-03-29029 March 2023 Submittal of Hope Creek Generating Station Technical Specification Bases Changes LR-N23-0006, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2023-03-24024 March 2023 Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations ML23086A0912023-03-24024 March 2023 NMFS to NRC, Transmittal of Biological Opinion for Continued Operations of Salem and Hope Creek Nuclear Generating Stations LR-N23-0019, and Salem Generating Station, Units 1 and 2 - Guarantees of Payment of Deferred Premiums2023-03-21021 March 2023 and Salem Generating Station, Units 1 and 2 - Guarantees of Payment of Deferred Premiums ML23037A9712023-03-0909 March 2023 and Salem Nuclear, Unit Nos. 1 and 2 Issuance of Amendment Nos. 233, 344, and 325 Relocate Technical Specification Staff Qualification Requirements to the PSEG Quality Assurance Topical Report IR 05000354/20220062023-03-0101 March 2023 Annual Assessment Letter for Hope Creek Generating Station (Report 05000354/2022006) LR-N23-0016, and Salem Generating Station, Units 1 and 2 - Report of Changes, Tests, and Experiments2023-02-28028 February 2023 and Salem Generating Station, Units 1 and 2 - Report of Changes, Tests, and Experiments LR-N23-0018, Technical Specification 6.9.1.5.b - 2022 Annual Report of SRV Challenges2023-02-27027 February 2023 Technical Specification 6.9.1.5.b - 2022 Annual Report of SRV Challenges LR-N23-0012, Annual Property Insurance Status Report2023-02-24024 February 2023 Annual Property Insurance Status Report LR-N23-0014, Stations Submittal of 2022 Annual Report of Fitness for Duty Performance Data Per 10 CFR 26.203(e) and 10 CFR 26.7172023-02-23023 February 2023 Stations Submittal of 2022 Annual Report of Fitness for Duty Performance Data Per 10 CFR 26.203(e) and 10 CFR 26.717 IR 05000354/20220042023-01-24024 January 2023 Integrated Inspection Report 05000354/2022004 LR-N23-0011, In-Service Inspection Activities - 90 Day Report: Twenty-Fourth Refueling Outage2023-01-19019 January 2023 In-Service Inspection Activities - 90 Day Report: Twenty-Fourth Refueling Outage LR-N22-0096, and Salem Generating Station, Units 1 and 2 - Request for Threshold Determination2023-01-0505 January 2023 and Salem Generating Station, Units 1 and 2 - Request for Threshold Determination LR-N22-0094, Emergency Plan Document Revisions Implemented November 21, 20222022-12-14014 December 2022 Emergency Plan Document Revisions Implemented November 21, 2022 LR-N22-0091, Independent Spent Fuel Storage Installation, Report of 10 CFR 72.48 Changes, Tests, and Experiments2022-12-0202 December 2022 Independent Spent Fuel Storage Installation, Report of 10 CFR 72.48 Changes, Tests, and Experiments ML22335A0412022-12-0101 December 2022 Notification of Commercial Grade Dedication Inspection (05000354/2023011) and Request for Information IR 05000354/20220032022-11-0303 November 2022 Integrated Inspection Report 05000354/2022003 2024-02-01
[Table view] |
Text
UNITED STATES NUCLEAR REGULATORY COMMISSION ril 27, 2009
SUBJECT:
HOPE CREEK GENERATING STATION - NRC INTEGRATED INSPECTION REPORT 05000354/2009002
Dear Mr. Joyce:
On March 31, 2009, the U. S. Nuclear Regulatory Commission (NRC) completed an integrated inspection at the Hope Creek Generating Station. The enclosed inspection report documents the inspection results discussed on April 8, 2009, with Mr. George Barnes and other members of your staff.
The inspections examined activities conducted under your license as they relate to safety and compliance with the Commissions rules and regulations and with the conditions of your license.
The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel.
Based on the results of this inspection, no findings of significance were identified.
In accordance with 10 CFR 2.390 of the NRC's "Rules of Practice," a copy of this letter, its enclosure, and your response (if any) will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records (PARS) component of NRC's document system (ADAMS), accessible from the NRC Web site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).
Sincerely,
/RA/
Arthur L. Burritt, Chief Projects Branch 3 Division of Reactor Projects Docket No: 50-354 License No: NPF-57 Enclosure: Inspection Report 05000354/2009002 w/Attachment: Supplemental Information
SUMMARY OF FINDINGS
IR 05000354/2009002; 01/01/2009 - 03/31/2009; Hope Creek Generating Station; Routine
Integrated Inspection Report.
This report covers a three-month period of inspection by resident inspectors and announced inspections by regional specialist inspectors. The NRCs program for overseeing the safe operation of commercial nuclear power reactors is described in NUREG-1649, Reactor Oversight Process, Revision 4, dated December 2006.
No findings of significance were identified.
REPORT DETAILS
Summary of Plant Status
The Hope Creek Generating Station operated at or near full power for the duration of the inspection period with the following exceptions. On January 9, operators reduced power to approximately 76 percent for planned testing and maintenance. The unit was restored to full power on January 10. On January 17, operators performed a manual scram in response to a turbine runback caused by a loss of stator cooling to the main generator. The unit was restarted on January 18, and reached full power on January 19. Additionally, on February 28, operators reduced power to approximately 81 percent to repair a condenser tube leak. The unit was restored to full power on March 1. On March 23, the unit entered end-of-cycle coastdown. The unit was operating at approximately 97 percent power at the end of the inspection period.
REACTOR SAFETY
Cornerstones: Initiating Events, Mitigating Systems, Barrier Integrity, and Emergency Preparedness
1R01 Adverse Weather Protection
Main article: IP 71111.01
.1 Evaluate Readiness for Impending Adverse Weather Conditions
a. Inspection Scope
The inspectors completed one adverse weather preparation sample. The inspectors reviewed PSEGs preparation activities for river grass intrusion conditions that may impact the station service water system. Inspectors assessed implementation of PSEGs grassing readiness plan through service water system walkdowns, corrective action program review, and discussions with cognizant managers and engineers.
Documents reviewed are listed in the Attachment.
b. Findings
No findings of significance were identified.
1R04 Equipment Alignment (71111.04 - 3 samples,
==71111.04S - 1 sample)
.1 Partial Walkdown
a. Inspection Scope
==
The inspectors completed three partial system walkdown inspection samples. For the systems listed below the inspectors verified the operability of redundant or diverse trains and components when the listed safety equipment was unavailable. The inspectors completed walkdowns to determine whether there were discrepancies in the systems alignment that could impact the function of the system, and therefore, potentially increase risk. The inspectors reviewed applicable operating procedures, walked down control system components, and verified that selected breakers, valves, and support equipment were in the correct position to support system operation. The inspectors also verified that PSEG had properly identified and resolved equipment alignment problems that could cause initiating events or impact the capability of mitigating systems or barriers and entered them into the corrective action program. Documents reviewed are listed in the Attachment.
- A, B, and D service water (SW) system with C SW system out of service on March 9, 2009
- B safety auxiliary cooling system (SACS) loop with A SACS loop 2522 C valve maintenance on March 23, 2009
.2 Complete Walkdown
a. Inspection Scope
The inspectors completed one complete walkdown inspection of accessible portions of the standby liquid control system. The inspectors used PSEG procedures and other documents listed in the Attachment to verify proper system alignment and functional capability. The inspectors independently verified the alignment and status of standby liquid control system valves, labeling, hangers and supports, and associated support systems. The walkdown also included checks that oil reservoir levels were normal, pump rooms and pipe chases were adequately ventilated, system parameters were within established ranges, and equipment deficiencies were appropriately identified.
b. Findings
No findings of significance were identified.
1R05 Fire Protection
Main article: IP 71111.05Q
.1 Fire Protection - Tours
a. Inspection Scope
The inspectors completed six quarterly fire protection inspection samples. 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 combustibles and ignition sources were controlled in accordance with PSEGs administrative procedures; fire detection and suppression equipment was available for use; that passive fire barriers were maintained in good material condition; and that compensatory measures for out-of-service, degraded, or inoperable fire protection equipment were implemented in accordance with PSEGs fire plan. The six areas toured are listed below with their associated pre-fire plan designator. Other documents reviewed are listed in the Attachment.
- FRH-II-713, SW Intake Screen Room
- FRH-II-434, Reactor Building MCC Area
- FRH-II-542, Lower Control Equipment Area
- FRH-II-541, 1E Switchgear 130
b. Findings
No findings of significance were identified.
1R06 Flood Protection Measures
Main article: IP 71111.06
a. Inspection Scope
The inspectors completed one flood protection measure inspection sample. The inspectors reviewed selected risk-important plant design features and PSEG procedures intended to protect the plant and its safety-related equipment from internal flooding events. Specifically, the inspectors focused on internal flood mitigation features for the 54 elevation of the reactor building that contains significant portions of the core spray, residual heat removal, high pressure coolant injection, reactor core isolation cooling, and reactor building sump systems. The inspectors reviewed flood analysis and design documents, including the Updated Final Safety Analysis Report (UFSAR), engineering calculations, and abnormal operating procedures. The inspectors observed the condition of wall penetrations, watertight doors, flood alarm switches, and drains to assess their readiness to contain flow from an internal flood in accordance with the design basis.
b. Findings
No findings of significance were identified.
1R11 Licensed Operator Requalification Program
Main article: IP 71111.11Q
.1 Requalification Activities Review By Resident Staff
a. Inspection Scope
The inspectors observed a licensed operator annual requalification simulator scenario on February 10, 2009, to assess operator performance and training effectiveness. The scenario involved a safety relief valve failing open, a loss of primary condensate pumps, a mode switch failure, a failure of the high pressure coolant injection system to initiate, and event classification. The inspectors verified that control room staff correctly identified and declared emergency action levels in a timely manner. The inspectors assessed simulator fidelity and observed the simulator instructors critique of operator performance. The inspectors also observed control room activities with emphasis on simulator-identified areas for improvement. Finally, the inspectors reviewed applicable documents associated with licensed operator requalification as listed in the Attachment.
b. Findings
No findings of significance were identified.
1R12 Maintenance Effectiveness
Main article: IP 71111.12
a. Inspection Scope
The inspectors completed three maintenance effectiveness inspection samples. For the systems listed below the inspectors evaluated items such as: appropriate work practices; identifying and addressing common cause failures; scoping in accordance with 10 CFR 50.65(b) of the maintenance rule (MR); characterizing reliability issues for performance; trending key parameters for condition monitoring; charging unavailability for performance; classification and reclassification in accordance with 10 CFR 50.65(a)(1) or (a)(2); and appropriateness of performance criteria for structures, systems, and components (SSCs) functions classified as (a)(2) and/or appropriateness and adequacy of goals and corrective actions for SSCs/functions classified as (a)(1).
Documents reviewed are listed in the Attachment.
b. Findings
No findings of significance were identified.
1R13 Maintenance Risk Assessments and Emergent Work Control
Main article: IP 71111.13
a. Inspection Scope
The inspectors completed four maintenance risk assessment and emergent work control inspection samples. The inspectors reviewed on-line risk management evaluations through direct observation and document reviews for the following four configurations:
- A control rod drive pump and C SACS pump out of service on January 6, 2009;
- B EDG and one offsite line out of service on February 10, 2009;
The inspectors reviewed the applicable risk evaluations, work schedules and control room logs for these configurations to verify that concurrent planned and emergent maintenance and test activities did not adversely affect the plant risk already incurred with these configurations. PSEGs risk management actions were reviewed during shift turnover meetings, control room tours, and plant walkdowns. The inspectors also used PSEGs on-line risk monitor (Equipment Out-Of-Service workstation) to gain insights into the risk associated with these plant configurations. Finally, the inspectors reviewed notifications documenting problems associated with risk assessments and emergent work evaluations. Documents reviewed are listed in the Attachment.
b. Findings
No findings of significance were identified.
1R15 Operability Evaluations
Main article: IP 71111.15
a. Inspection Scope
The inspectors completed six operability evaluation inspection samples. The inspectors reviewed the operability determinations for degraded or non-conforming conditions associated with:
- HPCI booster pump wear particles in oil;
- SW strainer differential pressure increase;
- Condensate storage tank to torus swapover for high pressure coolant injection/reactor core isolation cooling; and
- EDG fuel oil transfer pump cross-connect flow path.
The inspectors reviewed the technical adequacy of the operability determinations to ensure the conclusions were justified. The inspectors also walked down accessible equipment to corroborate the adequacy of PSEGs operability determinations.
Additionally, the inspectors reviewed other PSEG identified safety-related equipment deficiencies during this report period and assessed the adequacy of their operability screenings. Documents reviewed are listed in the Attachment.
b. Findings
No findings of significance were identified.
1R18 Plant Modifications
Main article: IP 71111.18
a. Inspection Scope
The inspectors completed one plant modification inspection sample. The inspectors reviewed the temporary plant modification package for temporary power feeds from offsite power supply substation #9. This review verified that the design bases, licensing bases, and performance capability of the system was not degraded by the modification.
The inspectors verified the new configuration was accurately reflected in the design documentation, and the post-modification testing was adequate to ensure the structures, systems, and components would function properly. The inspectors interviewed plant staff, and reviewed issues that had been entered into the corrective action program to determine whether PSEG had been effective in identifying and resolving problems associated with temporary modifications. The 10 CFR 50.59 evaluation associated with this temporary modification was also reviewed. Documents reviewed are listed in the
.
b. Findings
No findings of significance were identified.
1R19 Post-Maintenance Testing
Main article: IP 71111.19
a. Inspection Scope
The inspectors completed six post-maintenance testing inspection samples. The inspectors reviewed the post-maintenance tests for the maintenance items listed below to verify that test activities confirmed system operability and functional capability following completion of maintenance. The inspectors reviewed applicable test procedures to verify that they tested all safety functions potentially affected by the associated maintenance activities. The inspectors verified that for each potentially affected safety function the acceptance criteria stated in the procedure was consistent with the UFSAR and other design documentation. The inspectors also witnessed completion of the testing or reviewed the completed test results to verify satisfactory restoration of all safety functions affected by the maintenance activities. Documents reviewed are listed in the Attachment.
- A control rod drive pump motor replacement on January 8, 2009
- CD482 inverter card replacement on January 5, 2009
- D EDG SACS cooling water valve 2395 D relay replacement on January 12, 2009
- C EDG scheduled maintenance on March 9, 2009
- B, C, and D EDG day tank level switch calibrations on March 11, 2009
- B control room chiller scheduled maintenance on March 19, 2009
b. Findings
No findings of significance were identified.
1R22 Surveillance Testing
Main article: IP 71111.22
a. Inspection Scope
The inspectors completed six surveillance testing (ST) inspection samples. The inspectors witnessed performance of and/or reviewed test data for the risk-significant STs listed below to assess whether the SSCs tested satisfied technical specification, UFSAR, and procedure requirements. The inspectors verified that test acceptance criteria were clear, demonstrated operational readiness and were consistent with design documentation; that test instrumentation had current calibrations and the range and accuracy for the application; and that tests were performed, as written, with applicable prerequisites satisfied. Upon ST completion, the inspectors verified that equipment was returned to the status required to perform its safety function. Documents reviewed are listed in the Attachment.
- B EDG monthly operability test on February 11, 2009
- D EDG 24-hour surveillance test on February 18, 2009
b. Findings
No findings of significance were identified.
1EP2 Alert and Notification System (ANS) Evaluation
Main article: IP 71114.02
a. Inspection Scope
An onsite review was conducted to assess the maintenance and testing of the Salem and Hope Creek ANS. During this inspection, the inspectors interviewed Emergency Preparedness (EP) staff responsible for implementation of the ANS testing and maintenance and reviewed corrective action program notifications pertaining to the ANS for causes, trends, and PSEGs corrective actions. The inspector reviewed the ANS procedures and the ANS design report to ensure PSEGs compliance with system maintenance and testing commitments. The inspection was conducted in accordance with NRC Inspection Procedure 71114, Attachment
.02. Planning Standard, 10 CFR
50.47(b)
- (5) and the related requirements of 10 CFR 50, Appendix E, were used as reference criteria.
b. Findings
No findings of significance were identified.
1EP3 Emergency Response Organization (ERO) Staffing and Augmentation System
Main article: IP 71114.03
a. Inspection Scope
The inspectors conducted a review of Salem/Hope Creeks ERO augmentation staffing requirements and the process for notifying and augmenting the ERO. This was performed to ensure the readiness of key staff for responding to an event and to ensure timely facility activation. The inspectors reviewed the ERO roster, training records, applicable procedures, drill reports for augmentation, quarterly EP drills and corrective action program notifications related to the ERO staffing augmentation system. The inspectors also reviewed the implementation of the change in the ERO augmentation time from 60 to 90 minutes. The inspection was conducted in accordance with NRC Inspection Procedure 71114, Attachment
and related requirements of 10 CFR 50, Appendix E, were used as reference criteria.
b. Findings
No findings of significance were identified.
1EP4 Emergency Action Level (EAL) and Emergency Plan Changes
Main article: IP 71114.04
a. Inspection Scope
Prior to this inspection, the NRC had received and acknowledged changes made to the Salem/Hope Creek Emergency Plan and its implementing procedures. PSEG developed these changes in accordance with 10 CFR 50.54(q), and determined that the changes did not result in a decrease in effectiveness of the Plan. PSEG also determined that the Plan continued to meet the requirements of 10 CFR 50.47(b) and Appendix E to 10 CFR 50. During this inspection, the inspectors conducted a review of Salems and Hope Creeks 10 CFR 50.54(q) screenings for all changes made to the EALs, and for a sample of the changes made to the Plan, from May 2008 through March 2009, that could have potentially resulted in a decrease in effectiveness. This review of the EAL, Plan, and EPIP changes did not constitute NRC approval of the changes and, as such, the changes remain subject to future NRC inspection. In addition, the inspectors reviewed notifications written related to this area. The inspection was conducted in accordance with NRC Inspection Procedure 71114, Attachment
.04. The requirements in 10 CFR 50.54(q) were used as reference criteria.
b. Findings
No findings of significance were identified.
Main article: IP 71114.05
a. Inspection Scope
The inspectors reviewed a sampling of self-assessment procedures and reports to assess PSEG=s ability to evaluate their EP performance and programs. The inspectors reviewed a sampling of notifications written between January 2008 and March 2009 that were initiated by PSEG at Salem and Hope Creek for issues identified during drills, self-assessments and audits. Additionally, the inspectors reviewed: Nuclear Oversight audits; the event report for the August 2008 Unusual Event declaration at Hope Creek; and, the 2007 and 2008 50.54(t) audit reports. This inspection was conducted in accordance with NRC Inspection Procedure 71114, Attachment
.05. Planning Standard,
10 CFR 50.47(b)
- (14) and the related requirements of 10 CFR 50 Appendix E were used as reference criteria.
b. Findings
No findings of significance were identified.
1EP6 Drill Evaluation
Main article: IP 71114.06
a. Inspection Scope
The inspectors completed one drill evaluation inspection sample. The inspectors observed control room operator emergency plan response actions during a licensed operator requalification training scenario on February 10, 2009. The inspectors verified that emergency classification declarations and notifications were completed in accordance with 10 CFR 50.72, 10 CFR 50, Appendix E, and the Hope Creek emergency plan implementing procedures. Documents reviewed for this inspection are listed in the Attachment.
b. Findings
No findings of significance were identified.
OTHER ACTIVITIES
4OA1 Performance Indicator Verification
a. Inspection Scope
The inspectors reviewed PSEGs program for gathering, evaluating and reporting information for the performance indicators (PIs) listed below. The inspectors used the definitions and guidance contained in NEI (Nuclear Energy Institute) 99-02, Regulatory Assessment Performance Indicator Guideline, Revision 5, to assess the accuracy of PSEGs collection and reporting of PI data. The documents reviewed by the inspectors are listed in the Attachment.
Cornerstone: Initiating Events
- Unplanned Scrams per 7000 Critical Hours
- Unplanned Scrams with Complications
- Unplanned Power Changes per 7000 Critical Hours The inspectors reviewed the data reported for these PIs for the period January 1 through December 31, 2008. The records reviewed included PI data summary reports, licensee event reports, monthly operating reports, and operator narrative logs. The inspectors verified the accuracy of the number of critical hours reported, and interviewed the system engineers responsible for data collection and evaluation.
Cornerstone: Emergency Preparedness
- Drill and Exercise Performance
- ANS Reliability For the PIs listed above, to verify the accuracy of the reported data, the inspectors reviewed the PI data, supporting documentation and the information PSEG reported, from the second quarter through the fourth quarter of 2008
b. Findings
No findings of significance were identified.
4OA2 Identification and Resolution of Problems
.1 Review of Items Entered into the Corrective Action Program:
As required by Inspection Procedure 71152, Identification and Resolution of Problems, and in order to help identify repetitive equipment failures or specific human performance issues for follow-up, the inspectors performed a daily screening of all items entered into PSEG's corrective action program. This was accomplished by reviewing the description of each new notification and attending daily management review committee meetings.
4OA3 Event Followup
On January 17, 2009, operators initiated a manual reactor scram in response to a main turbine runback caused by a loss of main generator stator cooling. The loss of stator cooling occurred due to a turbine auxiliary cooling system isolation valve that failed shut.
The solenoid for the valve was determined to have a detached lead. This lead had been replaced approximately one week prior to the event. This condition was not caused by a performance deficiency associated with the maintenance activity.
The resident inspectors responded to the site and verified that plant systems responded as designed to the transient and operator response was consistent with plant procedures. The inspectors reviewed control board indications, plant logs, computer alarm data, and other post-transient records and data. The inspectors also reviewed PSEGs prompt investigation, apparent cause evaluation, and root cause evaluation for this event.
The inspectors reviewed LER 05000354/2009-001 and determined that the direct cause, the solenoid failure, was not within PSEG's ability to foresee and correct, and therefore would not meet the screening criteria for a finding. The inspectors identified no findings of significance and determined there was no violation of NRC requirements. This LER is closed.
4OA5 Other Activities
.1 Quarterly Resident Inspector Observations of Security Personnel and Activities
a. Inspection Scope
During the inspection period, the inspectors conducted observations of security force personnel and activities to ensure that the activities were consistent with PSEG security procedures and regulatory requirements relating to nuclear plant security. These observations took place during both normal and off-normal plant working hours. These quarterly resident inspector observations of security force personnel and activities did not constitute any additional inspection samples. Rather, they were considered an integral part of the inspectors normal plant status review and inspection activities.
b. Findings
No findings of significance were identified.
.2 TI 2515/173, Review of the Implementation of the Industry Ground Water Protection
Voluntary Initiative
a. Inspection Scope
On March 9-13, 2009, the inspectors assessed PSEGs ground water protection program to verify that PSEG implemented the voluntary industry Ground Water Protection Initiative (GPI). The GPI was unanimously approved by a formal vote of the Nuclear Energy Institute (NEI) member utility chief nuclear officers. This established the industrys commitment to implement the initiative. The GPI identifies the actions the industry deemed necessary for implementation of a timely and effective ground water protection program.
The inspectors verified that the following objectives for the GPI were contained in PSEG's program:
1.1 Site Hydrology and Geology 1.2 Site Risk Management 1.3 On-Site Ground Water Monitoring 1.4 Remediation Process 1.5 Record Keeping 2.1 Stakeholder Briefing 2.2 Voluntary Communication 2.3 Thirty-Day Reports 2.4 Annual Reporting 3.1 Perform a Self-Assessment 3.2 Review the Program Under the Auspices of NEI Unit 2 Emergency Sump The inspectors reviewed documentation and PSEG actions related to the identification of tritium in the Unit 2 emergency sump, located below the 54 elevation in the turbine building. The inspectors discussed with PSEG the testing and reviews conducted to determine the source of the tritium. PSEG's investigation determined that the source of the tritium was condensation from the turbine building administrative area heating ventilation and air conditioning (HVAC) unit, and that the tritium from the condensation came from the Technical Specification/Offsite Dose Calculation Manual authorized effluent releases from the plant vents being drawn into the HVAC intake. The inspectors confirmed that the information developed from PSEG's investigation, including various system testing and data collection, supported this conclusion.
The inspectors also reviewed PSEG's investigation efforts and actions taken to determine the cause of frequent makeup of water volume to the condensate storage tank. While investigation is still continuing, PSEG's efforts did provide basis to conclude that there were no leaks to ground water in associated underground piping, valving, or the tank.
b. Findings
No findings of significance were identified.
.3 Correction to NRC Cross-Cutting Aspect Coding of NRC Finding NCV
05000354/2009006-03, Failure to Follow Procedures Contributes to Emergency Diesel Generator Inoperability NRC Inspection Report 05000354/2009006 dated March 16, 2009, documented a Green finding associated with PSEGs failure to follow a surveillance test procedure. The finding had a cross-cutting aspect in the area of human performance and the aspect of work practices, procedural compliance, because PSEG personnel did not follow procedures. However, the finding documentation in Inspection Report 05000354/2009006 contained a typographical error. Specifically, in analysis section for the finding and the summary of findings section for the report the cross-cutting aspect code for this finding was incorrectly listed as H.2(b). The correct cross-cutting aspect code for this finding was H.4(b).
.4 TI 2515/175, Emergency Response Organization, Drill/Exercise Performance Indicator
Program Review The inspectors performed TI 2515/175, ensured the completeness of PSEGs completed 1 from the TI, and then forwarded the data to NRC, HQ.
4OA6 Meetings, Including Exit
The resident inspectors presented the inspection results to Mr. George Barnes and other members of PSEG staff on April 8, 2009. The inspectors verified that proprietary material reviewed by the inspectors during this period was properly controlled and the content of the report includes no proprietary information.
ATTACHMENT:
SUPPLEMENTAL INFORMATION
KEY POINTS OF CONTACT
Licensee Personnel
- G. Barnes, Site Vice President
- B. Booth, Operations Director
- D. Burgin, Corporate Emergency Preparedness Manager
- R. Canziani, Maintenance Director
- E. Casulli, Shift Operations Superintendent
- K. Chambliss, Assistant Plant Manager
- P. Duca, Senior Engineer, Regulatory Assurance
- K. Knaide, Engineering Director
- M. Gaffney, Regulatory Assurance Manager
- J. Perry, Plant Manager
- J. Sears, Chemistry Manager
- H. Trimble, Radiation Protection Manager
LIST OF ITEMS OPENED, CLOSED, AND DISCUSSED
Closed
- 05000354/2009-001 LER Reactor Manual Scram Due to Turbine Runback (Section 4OA3.1)
Discussed
- 05000354/2009006-03 NCV Failure to Follow Procedures Contributes to Emergency Diesel Generator Inoperability (Section 4OA5.3)
LIST OF DOCUMENTS REVIEWED