IR 05000334/2014005
| ML15035A606 | |
| Person / Time | |
|---|---|
| Site: | Beaver Valley |
| Issue date: | 02/04/2015 |
| From: | Kennedy S R NRC/RGN-I/DRP/PB6 |
| To: | Larson E A FirstEnergy Nuclear Operating Co |
| KENNEDY, SR | |
| References | |
| 2014-04 ISFSI, IR 2014005 | |
| Download: ML15035A606 (34) | |
Text
February 4, 2015 Mr. Eric Site Vice President FirstEnergy Nuclear Operating Company Beaver Valley Power Station P. O. Box 4 Shippingport, PA 15077-0004
SUBJECT: BEAVER VALLEY POWER STATION NRC INTEGRATED INSPECTION REPORT 05000334/2014005 AND 05000412/2014005 AND INDEPENDENT SPENT FUEL STORAGE INSTALLATION REPORT NO. 07201043/2014004
Dear Mr. Larson:
On December 31, 2014, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at your Beaver Valley Power Station, Units 1 and 2. The enclosed inspection report documents the inspection results, which were discussed on January 29, 2015, with you and other members of your staff. The inspection examined activities conducted under your license as they relate to safety and compliance with the CommissThe inspectors reviewed selected procedures and records, observed activities, and interviewed personnel. This report documents two violations of NRC requirements, all of which were of very low safety significance (Green). However, because of the very low safety significance, and because they are entered into your corrective action program, the NRC is treating these findings as non-cited violations, consistent with Section 2.3.2.a of the NRC Enforcement Policy. If you contest the non-cited violations in this report, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the Nuclear Regulatory Commission, ATTN.: Document Control Desk, Washington, DC 20555-0001; with copies to the Regional Administrator, Region I; the Director, Office of Enforcement, United States Nuclear Regulatory Commission, Washington, DC 20555-0001; and the NRC Resident Inspector at Beaver Valley Power Station. In addition, if you disagree with the cross-cutting aspect assigned to any finding, you should provide a response within 30 days of the date of this inspection report, with the basis for your disagreement, to the Regional Administrator, Region I, and the NRC Resident Inspector at Beaver Valley Power Station. In accordance with Title 10 of the Code of Federal Regulations (CFR) 2.390 of the NRCs availabl Management System (ADAMS). ADAMS is accessible from the NRC website at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).
Sincerely,/RA/ Silas R. Kennedy, Chief Reactor Projects Branch 6 Division of Reactor Projects Docket Nos.: 50-334, 50-412 License Nos.: DPR-66, NPF-73
Enclosure:
Inspection Report 05000334/2014005 and 05000412/2014005 and 07201043/2014004,
w/Attachment:
Supplementary Information cc w/encl: Distribution via ListServ
ML15035A606 SUNSI Review Non-Sensitive Sensitive Publicly Available Non-Publicly Available OFFICE RI/DRP RI/DRP RI/DRP NAME JKrafty/BB for CBickett/ CAB SKennedy/ SRK DATE 02/04/15 02/03/15 02/04/15 1 Enclosure U.S. NUCLEAR REGULATORY COMMISSION REGION I Docket Nos.: 50-334, 50-412 License Nos.: DPR-66, NPF-73 Report No.: 05000334/2014005, 05000412/2014005, and 07201043/2014004 Licensee: FirstEnergy Nuclear Operating Company (FENOC) Facility: Beaver Valley Power Station (BVPS), Units 1 and 2 Location: Shippingport, PA 15077 Dates: October 1, 2014 to December 31, 2014 Inspectors: J. Krafty, Senior Resident Inspector B. Reyes, Resident Inspector A. Dugandzic, Reactor Inspector J. Furia, Senior Health Physicist S. Hammann, Senior Health Physicist C. Morell, Storage Safety & Transportation Inspector P. Presby Senior Operations Engineer R. Rolph, Health Physicist J. Trapp, Safety Inspector R. Temps, Senior Safety Inspector Approved By: Silas R. Kennedy, Chief Reactor Projects Branch 6 Division of Reactor Projects 2 Enclosure
SUMMARY
IR 05000334/2014005, 05000412/2014005, 07201043/2014004; 10/01/2014 12/31/2014; Beaver Valley Power Station, Units 1 and 2; Maintenance Risk Assessments and Emergent Work Control, Radioactive Solid Waste Processing and Radioactive Material Handling, Storage, and Transportation This report covered a three-month period of inspection by resident inspectors and announced inspections performed by regional inspectors. Inspectors identified two findings of very low safety significance (Green), which are non-cited violations (NCVs). The significance of most findings is indicated by their color (i.e., greater than Green, or Green, White, Yellow, Red) and (SDP), dated June 2, 2011. Cross-Aspects Within Cross-4, 2014. All violations of NRC requirements are described in NUREG-
Cornerstone: Mitigating Systems
- Green.
The inspectors identified an NCV of 10 CFR 50.65(a)(to implement adequate risk management actions (RMAs) associated with maintenance on Specifically, FENOC did not establish a contingency plan for the maintenance activity as required by FENOFENOC entered the issue into their corrective action program as CR 2015-00267. The performance deficiency is more than minor because it is associated with the Equipment Performance attribute of the Mitigating Systems cornerstone and adversely affected its objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. implement a contingency plan resulted in an increase in the duration of an elevated risk condition and unavailability of equipment relied upon to mitigate the consequences of a loss of the main intake structure. The finding was determined to be of very low safety significance (Green) because the incremental core damage probability (ICDP) for the event was less than 1.0 E-6. The inspectors determined that this finding had a cross-cutting aspect in the Human Performance, Work Management, because the FENOC work process failed to adequately manage the risk commensurate to the work [H.5]. (Section 1R13)
Cornerstone: Occupational/Public Radiation Safety
- Green.
The inspectors identified an Transportation of licensed personnel shipped a category 2 radioactive material of concern (RAM-QC) on public highways to a waste processor without adhering to a transpocorrective actions included revising procedure NOP-OP-Material shipment of Category 2 radioactive material. FENOC entered the issue into their corrective action program as CR 2014-17260.
The issue is more than minor because it is associated with the Program and Process attribute of the Public Radiation Safety cornerstone and adversely affected its objective to ensure the safe transport of radioactive material on public highways in accordance with regulations. The finding was determined to be of very low safety significance (Green) because FENOC had an issue involving transportation of radioactive material, but it did not involve: (1) a radiation limit that was exceeded; (2) a breach of package during transport; (3) a certificate of compliance issue; (4) a low level burial ground nonconformance; or (5) a failure to make notifications or provide emergency information. The inspectors determined that the finding did not have a cross-cutting aspect because the issue was not reflective of current plant performance. Specifically, FENOC implemented changes to the radioactive waste shipment procedure that addressed applicable requirements and implemented a formal process for reviewing pending regulatory changes for impacts to FENOC operations and support activities. (Section 2RS8)
REPORT DETAILS
Summary of Plant Status Unit 1 began the inspection period at 100 percent power. On October 10, 2014, Operators reduced Unit 1 to 13 percent power to reconnect the unit station service transformers to the main generator. Operators returned Unit 1 to 100 percent power on October 16, 2014, and the unit remained at or near 100 percent power for the remainder of the inspection period. Unit 2 began the inspection period at 100 percent power. On October 17, 2014, Operators reduced Unit 2 to 82 percent power to repair main condenser water box leakage. Operators returned Unit 2 to 100 percent power on October 20, 2014, and the unit remained at or near 100 percent power for the remainder of the inspection period.
REACTOR SAFETY
Cornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity
1R01 Adverse Weather Protection
.1 Readiness for Seasonal Extreme Weather Conditions
a. Inspection Scope
The inspectors performed a review of readiness for the onset of seasonal cold temperatures. The review focused on service and river water systems, Unit 2 emergency diesel generators, and heat tracing for the Unit 1 charging and quench spray systems. The inspectors reviewed the technical specifications, and the corrective action program to determine what temperatures or other seasonal weather could challenge these systems, and to ensure FENOC personnel had adequately prepared for these challenges. The inspectors reviewed station procedures, including seasonal weather preparation procedure and applicable operating procedures. The inspectors performed walkdowns of the selected systems to ensure station personnel identified issues that could challenge the operability of the systems during cold weather conditions. Documents reviewed for each section of this inspection report are listed in the Attachment.
b. Findings
No findings were identified.
.2 Readiness for Impending Adverse Weather Conditions
a. Inspection Scope
wind advisory and subsequent entry into abnormal operating procedure (AOP) 1/2OM-cts of Nature - on review of specific unit actions based on actual environmental conditions and adherence to mitigating procedures. The inspectors performed a walkdown of each ures, areas that could potentially impact safety related equipment, and emergency response facilities to verify the adequacy of protection from high winds. The inspectors verified completion of actions required by the AOP.
b. Findings
No findings were identified.
===.3 External Flooding
a. Inspection Scope
On December 30, 2014, the inspectors performed an inspection of the external flood protection measures for Beaver Valley Power Station. The inspectors reviewed technical specifications, procedures, design documents, and Updated Final Safety Analysis Report (UFSAR), Chapter 2, which depicted the design flood levels and protection areas containing safety-related equipment to identify areas that may be affected by external flooding. The inspectors conducted a general site walkdown of all external areas of the plant, including the turbine building, auxiliary building, and the main intake structure to ensure that FENOC erected flood protection measures in accordance with design specifications. The inspectors also reviewed operating procedures for mitigating external flooding during severe weather to determine if FENOC planned or established adequate measures to protect against external flooding events.
b. Findings
No findings were identified.
1R04 Equipment Alignment
Partial System Walkdowns===
a. Inspection Scope
The inspectors performed partial walkdowns of the following systems: quench spray and recirculation spray systems on October 21, 2014 maintenance on October 28, 2014 The inspectors selected these systems based on their risk-significance relative to the reactor safety cornerstones at the time they were inspected. The inspectors reviewed applicable operating procedures, system diagrams, the UFSAR, technical specifications, work orders, condition reports, and the impact of ongoing work activities on redundant trains of equipment in order to identify conditions that could have impacted system performance of their intended safety functions. The inspectors also performed field walkdowns of accessible portions of the systems to verify system components and support equipment were aligned correctly and were operable. The inspectors examined the material condition of the components and observed operating parameters of equipment to verify that there were no deficiencies. The inspectors also reviewed whether staff had properly identified equipment issues and entered them into the corrective action program for resolution with the appropriate significance characterization.
b. Findings
No findings were identified.
1R05 Fire Protection Resident Inspector Quarterly Walkdowns
a. Inspection Scope
The inspectors conducted tours of the areas listed below to assess the material condition and operational status of fire protection features. The inspectors verified that FENOC controlled combustible materials and ignition sources in accordance with administrative procedures. The inspectors verified that fire protection and suppression equipment was available for use as specified in the area pre-fire plan, and passive fire barriers were maintained in good material condition. The inspectors also verified that station personnel implemented compensatory measures for out of service, degraded, or inoperable fire protection equipment, as applicable, in accordance with procedures.
ble vault pipe tunnel, fire area PT-1 on October 7, 2014 Unit 2 primary auxiliary building, fire area PA-6 on November 11, 2014
b. Findings
No findings were identified.
1R11 Licensed Operator Requalification Program
.1 Quarterly Review of Licensed Operator Requalification Testing and Training
a. Inspection Scope
The inspectors observed licensed operator simulator training on October 20, 2014, which included a stuck open power-operated relief valve, a faulted steam generator, loss of emergency alternating current (AC) busses, and failure of select components to automatically start as required. The inspectors evaluated operator performance during the simulated event and verified completion of risk significant operator actions, including the use of abnormal and emergency operating procedures. The inspectors assessed the clarity and effectiveness of communications, implementation of actions in response to alarms and degrading plant conditions, and the oversight and direction provided by the control room supervisor. The inspectors verified the accuracy and timeliness of the emergency classification made by the shift manager and the technical specification action statements entered by the shift manager. Additionally, the inspectors assessed the ability of the crew and training staff to identify and document crew performance problems.
b. Findings
No findings were identified.
===.2 Quarterly Review of Licensed Operator Performance in the Main Control Room
a. Inspection Scope
The inspectors observed and reviewed a power reduction on Unit 1 which included securing of the second main feed pump to opening the main generator output breakers on October 10 and 11, 2014. The inspectors observed pre-job briefings, and reactivity control briefings to verify that the briefings met the criteria specified in station procedure NOP-OP-observed operator performance to verify that procedure use, crew communications, reactivity management, and coordination of activities between work groups similarly met established expectations and standards.
b. Findings
No findings were identified.
.3 Licensed Operator Requalification Program
=
a. Inspection Scope
On December 23, 2014, one NRC region-based inspector conducted an in-office review of the results of the Beaver Valley Station, Unit 2, licensee-administered annual operating tests and the biennial written exam for the year 2014. The results of the Beaver Valley Station, Unit 1 biennial written exam for the year 2013 were also reviewed. The inspection assessed whether pass rates were consistent with the inspector verified that: For Unit 2 Annual Operating Test in 2014: Individual pass rate on the dynamic simulator test was greater than 80 percent. (Pass rate was 88.3 percent.) Individual pass rate on the job performance measures of the operating exam was greater than 80 percent. (Pass rate was 100 percent.) More than 80 percent of the individuals passed all portions of the requalification exam. (Pass rate was 88.3 percent.) Crew pass rate was greater than 80 percent. (Pass rate was 100 percent.) For Unit 2 Biennial Written Exam in 2014: Individual pass rate on the written examination was greater than 80 percent. (The pass rate was 88 percent.)
For Unit 1 Biennial Written Exam in 2013: Individual pass rate on the written examination was greater than 80 percent. (The pass rate was 100 percent.)
b. Findings
No findings were identified.
1R12 Maintenance Effectiveness
a. Inspection Scope
The inspectors reviewed the Unit 1 480 Volt Station Service System during the week of November 4, 2014, to assess the effectiveness of maintenance activities on structure system, or component (SSC) performance and reliability. The inspectors reviewed system health reports, corrective action program documents, maintenance work orders, and maintenance rule basis documents to ensure that FENOC was identifying and properly evaluating performance problems within the scope of the maintenance rule. For each sample selected, the inspectors verified that the SSC was properly scoped into the maintenance rule in accordance with 10 CFR 50.65 and verified that the (a)(2) performance criteria established by FENOC staff was reasonable. As applicable, for SSCs classified as (a)(1), the inspectors assessed the adequacy of goals and corrective actions to return these SSCs to (a)(2). Additionally, the inspectors ensured that FENOC staff was identifying and addressing common cause failures that occurred within and across maintenance rule system boundaries.
b. Findings
No findings were identified.
1R13 Maintenance Risk Assessments and Emergent Work Control
a. Inspection Scope
The inspectors reviewed station evaluation and management of plant risk for the maintenance and emergent work activities listed below to verify that FENOC performed the appropriate risk assessments prior to removing equipment for work. The inspectors selected these activities based on potential risk significance relative to the reactor safety cornerstones. As applicable for each activity, the inspectors verified that FENOC personnel performed risk assessments as required by 10 CFR 50.65(a)(4) and that the assessments were accurate and complete. When FENOC performed emergent work, the inspectors verified that operations personnel promptly assessed and managed plant risk. The inspectors reviewed the scope of maintenance work and discussed the results nditions were consistent with the risk assessment. The inspectors also reviewed the technical specification requirements and inspected portions of redundant safety systems, when applicable, to verify risk analysis assumptions were valid and applicable requirements were met.
Yellow risk associated with placing degraded Unit 1 battery charger 1A in service for load testing of battery charger 1B on October 11, 2014 2014
b. Findings
Introductionfailure to implement adequate risk management actions (RMAs) associated with Specifically, FENOC did not management procedure.
Description.
During the week of October 13, 2014, FENOC was performing a silt check and bay cleaning of the alternatwater pumps for Unit 1 to mitigate the consequences of a loss of the main intake structure due to a postulated barge impact and subsequent explosion.
The submersible pump failed and FENOC deployed a team to repair the pump and rented a backup pump in the event that the repairs were unsuccessful. The inspectors plan prior to performing the maintenance activity. Repair of the failed submersible pump delayed the maintenance activity for over six hours, thus increasing the duration of an elevated risk condition. FENOC procedure NOP-OP-implemented, as feasible, to increase risk awareness and control, reduce the duration of activities and plant conditions associated with elevated risk, and minimize the magnitude 4 of NOP-OP-1007. The inspectors determined that it was reasonable for FENOC to establish a contingency plan for the elevated risk activity in order to minimize the increase in duration of the work due to potential equipment failures. FENOC entered the issue into their corrective action program (CAP) as CR 2015-00267
Analysis.
The inspectors determined that failure to implement a contingency plan for the purpose of managing risk pursuant to 10 CFR 50.65(a)(4) was a performance deficiency that was within the capability of FENOC to foresee and correct and should have been prevented. The performance deficiency was more than minor because it is associated with the Equipment Performance attribute of the Mitigating Systems cornerstone and adversely affected its objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. cy plan resulted in an increase of the duration of elevated risk condition and unavailability of equipment relied upon to mitigate the consequences of a loss of the main intake structure. An NRC senior reactor analyst calculated incremental core damage probability (ICDP) of the event to be 8.06 E-10 based on a six-hour exposure time. Using IMC 0609, is determined to be of very low safety significance (Green) because the ICDP for the event was less than 1.0 E-6.
The inspectors determined that this finding had a cross-cutting aspect in Human Performance, Work Management, because the FENOC work process failed to adequately manage the risk commensurate to the work. Specifically, the FENOC work processes did not appropriately incorporate contingency plans when performing mai
Enforcement.
10 CFR 50.65(a)(4) requires, in part, Contrary to the above, FENOC did not appropriately manage the increase in risk resulting from maintenance activities. Specifically, FENOC failed to implement a contingency plan during an elevated risk condition when performing maintenance in the low safety significance (Green) and was entered iprogram (CAP) as CR 2015-00267, this violation is being treated as an NCV, consistent with Section 2.3.2 of the NRC Enforcement Policy. (NCV 05000334/2014005-01, Failure to Adequately Implement Risk Management Actions)
1R15 Operability Determinations and Functionality Assessments
a. Inspection Scope
The inspectors reviewed operability determinations for the following degraded or non-conforming conditions: CR 2014-15436, Unit 2 48 Volt DC power supply to the reactor trip breakers low out of tolerance on October 17, 2014 CR 2014-bolt on October 21, 2014 CR 2014--leakage on October 22, 2014 CR 2014-15874, Unit 1 potential glycol leakage on 1A main feed regulating valve November 5, 2014 CR 2014-16599, 2MSS-SOV105E, steam supply isolation valve to the Unit 2 turbine driven auxiliary feed water pump exceeded its limiting closed stroke time on November 6, 2014 Engineering Evaluation Request 600931138, Evaluate data obtained per MSP-36.51A-E for margin in engineered safety features Time Response Beaver Valley Unit 1 test on November 10, 2014 CR 2014-spray heat exchangers on November 18, 2014 CR 2014-18292, Leak in Unit 2 four inch service water line in north safeguards room on December 15, 2014 The inspectors selected these issues based on the risk significance of the associated components and systems. The inspectors evaluated the technical adequacy of the operability determinations to assess whether technical specification operability was properly justified and the subject component or system remained available such that no unrecognized increase in risk occurred. The inspectors compared the operability and design criteria in the appropriate sections of the technical specifications and UFSAR to evaluations to determine whether the components or systems were operable. Where compensatory measures were required to maintain operability, the inspectors determined whether the measures in place would function as intended and were properly controlled by FENOC. The inspectors determined, where appropriate, compliance with bounding limitations associated with the evaluations.
b. Findings
No findings were identified.
1R19 Post-Maintenance Testing
a. Inspection Scope
The inspectors reviewed the post-maintenance tests for the maintenance activities listed below to verify that procedures and test activities ensured system operability and functional capability. The inspectors reviewed the test procedure to verify that the procedure adequately tested the safety functions that may have been affected by the maintenance activity, that the acceptance criteria in the procedure was consistent with the information in the applicable licensing basis and/or design basis documents, and that the procedure had been properly reviewed and approved. The inspectors also witnessed the test or reviewed test data to verify that the test results adequately demonstrated restoration of the affected safety functions.
Unit 1 emergency diesel generator header isolation valve breaker replacement on November 5, 2014 Unit 2 systeNovember 12, 2014 on December 1, 2014
b. Findings
No findings were identified.
1R22 Surveillance Testing
a. Inspection Scope
The inspectors observed performance of surveillance tests and/or reviewed test data of selected risk-significant SSCs to assess whether test results satisfied technical specifications, the UFSAR, and FENOC procedure requirements. The inspectors verified that test acceptance criteria were clear, tests demonstrated operational readiness and were consistent with design documentation, test instrumentation had current calibrations and the range and accuracy for the application, tests were performed as written, and applicable test prerequisites were satisfied. Upon test completion, the inspectors considered whether the test results supported that equipment was capable of performing the required safety functions. The inspectors reviewed the following surveillance tests:
2OST-1.12B, Safeguards Protection System Train B Safety Injection System Go Test, Revision 49, on October 30, 2014 1OST-24.2, Motor Driven Auxiliary Feed Pump Test (1FW-P-3A), Revision 50, on November 17, 2012 (In-service test) 2OST-11.2, Low Head Safety Injection Pump (2SIS*P21B) Test, Revision 31, on December 16, 2014 1OST-13.7B, 2B Recirculation Spray Pump Flow Test, Revision 12, on December 22, 2014
b. Findings
No findings were identified. Cornerstone: Emergency Preparedness
1EP6 Drill Evaluation
.1 Emergency Preparedness Drill Observation
a. Inspection Scope
The inspectors evaluated the conduct of a routine FENOC emergency drill on October 9, 2014, to identify any weaknesses and deficiencies in the classification, notification, and protective action recommendation development activities. The inspectors observed emergency response operations in the simulator, technical support center, and emergency operations facility to determine whether the event classification, notifications, and protective action recommendations were performed in accordance with procedures. The inspectors also attended the station drill critique to compare inspector observations with those identified by FENOC staff in order to evaluate critique and to verify whether the FENOC staff was properly identifying weaknesses and entering them into the corrective action program.
b. Findings
No findings were identified.
RADIATION SAFETY
Cornerstone:
Public Radiation Safety and Occupational Radiation Safety
2RS6 Radioactive Gaseous and Liquid Effluent Treatment
a Inspection Scope During the period November 3-in treatment, monitoring, and control of effluent releases including adequacy of public dose calculations and projections. The inspectors used the requirements in 10 CFR Part 20; 10 CFR 50, Appendix I; technical specifications; Offsite Dose Calculation Manual (ODCM); applicable industry standards; and procedures required by technical specifications as criteria for determining compliance.
Inspection Planning
The inspector conducted in-office preparation and review of FENOC submitted effluent and environmental program documents and reviewed associated UFSAR and the ODCM. Event Report and Effluent Report Reviews The inspectors reviewed the following: Annual radiological effluent and environmental reports for 2012 and 2013 including unexpected trends or abnormal releases Reported effluent monitor operability issues ODCM and UFSAR Reviews The inspectors reviewed the following: UFSAR changes associated with effluent monitoring and control Changes to ODCM including technical justifications Identification of any contaminated non-radioactive system and associated 10 CFR 50.59 evaluations Ground Water Protection Initiative The inspectors reviewed the following: Reported groundwater monitoring results and changes to the written program for identifying and controlling contaminated spills/leaks to groundwater Changes to the program since last inspection Procedures, Special Reports, and Other Documents The inspectors reviewed the following: Any Licensee Event Reports (LERs), and special reports related to the effluent program Effluent program implementing procedures, including those associated with effluent sampling, effluent monitor set-point determinations, and dose calculations Evaluation reports of the effluent monitoring program since the last inspection Walkdowns and Observations The inspectors reviewed the following: Walked down selected components of the gaseous effluent monitoring systems Potential unmonitored release points, building alterations which could impact airborne, or liquid, and effluent controls, and ventilation system leakage Effluent release system material condition surveillance records Changes to effluent release paths Routine processing and discharge of liquid waste 10 CFR 50.59 reviews for changes to effluent release points Sampling and Analyses The inspectors reviewed the following: Effluent sampling activities with respect to representative sampling Effluent discharges made with inoperable effluent radiation monitors Use of compensatory effluent sampling Results of the inter-laboratory and intra-laboratory comparison program, including hard-to-detect isotopes, to verify the quality of the radioactive effluent sample analyses Dose Calculations The inspectors reviewed the following: Significant changes in reported dose values compared to the previous radioactive effluent release reports Liquid and gaseous waste discharge permits Methods used to include hard-to-detect radionuclides in the effluent release reports Changes in the methodology for offsite dose calculations since the last inspection Meteorological dispersion and deposition factors used in offsite dose calculations Latest Land Use Census to verify that changes in land use have been factored into public dose projections and the environmental sampling program Dose calculations (monthly, quarterly, annual) Records of any abnormal gaseous or liquid discharges Discharges made with inoperable effluent radiation monitors Groundwater Protection Initiative (GPI) Implementation The inspectors reviewed the following: Groundwater monitoring results Changes made to the GPI program Anomalous results of groundwater samples Leakage or spill events and entries made into the decommissioning files (10 CFR50.75(g)) On-site contamination events involving contamination of groundwater Discharges from onsite surface water bodies Problem Identification and Resolution The inspectors evaluated whether problems associated with the effluent monitoring and control program were being identified at an appropriate threshold and were properly addressed for resolution in the licensee corrective action program. b Findings No findings were identified.
2RS8 Radioactive Solid Waste Processing and Radioactive Material Handling, Storage, and Transportation
a. Inspection Scope
During November 17-programs for processing, handling, storage, and transportation of radioactive material. The inspectors used the requirements of 49 CFR 170-177; 10 CFR 20, 61, and 71; applicable industry standards; and procedures required by TSs as criteria for determining compliance.
Inspection Planning
The inspectors conducted an in-office review of the solid radioactive waste system description in the UFSAR, the Process Control Program, and the recent radiological effluent release report for information on the types, amounts, and processing of radioactive waste disposed. The inspectors reviewed the scope of quality assurance audits performed for this area since the last inspection.
Radioactive Material Storage The inspectors inspected areas where containers of radioactive waste were stored. The inspectors verified that the licensee had established a process for monitoring the impact of long-term storage. Radioactive Waste System Walk-down The inspectors walked down areas of the plant, and reviewed: accessible portions of liquid and solid radioactive waste processing systems to verify current system alignment and material condition radioactive waste processing equipment that was abandoned in place, and reviewed the controls in place to ensure protection of personnel changes made to the radioactive waste processing systems since the last inspection processes for transferring radioactive waste resin and/or sludge discharges into shipping/disposal containers current methods and procedures for dewatering waste Waste Characterization and Classification The inspectors identified radioactive waste streams and reviewed radiochemical sample analysis results to support radioactive waste characterization. The inspectors reviewed the use of scaling factors and calculations to account for difficult-to-measure radionuclides.
Shipment Preparation The inspectors reviewed the records of shipment packaging, surveying, labeling, marking, placarding, vehicle checks, emergency instructions, disposal manifest, shipping papers provided to the driver, and licensee verification of shipment readiness. Shipping Records The inspectors reviewed selected non-excepted package shipment records. Identification and Resolution of Problems The inspectors reviewed problems associated with radioactive waste processing, handling, storage, and transportation, and were addressed for resolution in the licensee corrective action program.
b. Findings and Observations
IntroductionlicensFENOC personnel shipped a category 2 RAM-QC on public highways to a waste processor without adhering to a transportation security plan. Prior to shipment, FENOC staff failed to recognize that the quantity of radioactive material met the definition RAM-QC.
Description.
FENOC staff prepared a liner for shipment to a waste processor. The liner, containing spent resin, was determined to have a total activity of 1300 curies (including 40.9 curies of cobalt (Co-60) as indicated on the Uniform Low-Level Radioactive Waste Manifest (NRC Form 541) which FENOC had generated. The liner was shipped on May 21, 2013. The inspectors reviewed the shipment and determined that the shipment met the definition of category 2 RAM-QC since it contained more than 8.1 curies of Co-60. The liner was shipped without FENOC implementing the required transportation -OP-5 not identify category 2 RAM-QC material.
-OP-250Radioactive Material rtation requirements for shipment of Category 2 radioactive material.
Additionally, FENOC implemented a formal process for reviewing pending regulatory changes for impacts to FENOC operations and support activities.
Analysis.
The failure to ship the spent resin material as category 2 RAM-QC as required been prevented. The issue is more than minor because it is associated with the program and process attribute of the Public Radiation Safety cornerstone and affected the cornerstone objective to ensure the safe transport of radioactive material on public highways in accordance with regulations. In accordance with IMC 0609, Appendix D, "Public Radiation Safety Significance Determination Process," the finding was determined to be of very low safety significance (Green) because FENOC had an issue involving transportation of radioactive material, but it did not involve: (1) a radiation limit that was exceeded; (2) a breach of package during transport; (3) a certificate of compliance issue; (4) a low level burial ground nonconformance; or (5) a failure to make notifications or provide emergency information. The inspectors determined that the finding did not have a cross-cutting aspect because the issue was not reflective of current plant performance. Specifically, FENOC implemented changes to the radioactive waste shipment procedure that addressed applicable requirements and implemented a formal process for reviewing pending regulatory changes for impacts to FENOC operations and support activities. Enforcementwith the applicable requirements of Department of Transportation regulations in 49 CFR R 172.800(b)] requires that known radionuclides in forms listed as category 2 RAM-QC must adhere to a transportation security plan. Contrary to the above, FENOC made a category 2 shipment of radioactive material on May 21, 2013 (Shipment ID B-4247) withouactions included revising procedure NOP-OP-250 shipment of Category 2 radioactive material. Because this violation was of very low safety significance (Green) and FENOC entered this issue into their CAP as CR 2014-17260, this violation is being treated as an NCV, consistent with Section 2.3.2. of the NRC Enforcement Policy. (05000334/2014005-02; 05000412/2014005-02, Failure to Properly Ship Category 2 Radioactive Material)
OTHER ACTIVITIES
4OA1 Performance Indicator Verification
.1 Mitigating Systems Performance Index (4 samples)
a. Inspection Scope
The inspectors reviewed submittal of the Mitigating Systems Performance Index for the following systems for the period of October 1, 2013, through September 30, 2014: Unit 1 Emergency AC Power System Unit 2 Emergency AC Power System Unit 1 High Pressure Injection System Unit 2 High Pressure Injection System To determine the accuracy of the performance indicator data reported during those periods, the inspectors used definitions and guidance contained in Nuclear Energy Institute (NEI) Document 99-mitigating systems performance index derivation reports, event reports, and system health reports to validate the accuracy of the submittals.
b. Findings
No findings were identified.
.2 Radiological Effluent Technical Specifications/Offsite Dose Calculation Manual Radiological Effluent Occurrences (1 sample)
a. Inspection Scope
During Decemberthe inspector reviewed licensee submittals for the radiological effluent technical specifications/ODCM radiological effluent occurrences performance indicator (PI) for the period from the first quarter 2013 through the fourth quarter 2013. The inspector used PI definitions and guidance contained in NEI Document 99-7, dated August 31, 2013, to determine if the PI data was reported properly during this period.
The individual reports generated since this indicator was last reviewed to identify any potential occurrences that may impact offsite dose. The inspector reviewed gaseous and liquid effluent summary data and the results of associated offsite dose calculations between the first quarter 2013 and the fourth quarter 2013.
b. Findings
No findings were identified.
4OA2 Problem Identification and Resolution
.1 Routine Review of Problem Identification and Resolution Activities
a. Inspection Scope
As required by Inspection Procedure (IP) the inspectors routinely reviewed issues during baseline inspection activities and plant status reviews to verify that FENOC entered issues into the corrective action program at an appropriate threshold, gave adequate attention to timely corrective actions, and identified and addressed adverse trends. In order to assist with the identification of repetitive equipment failures and specific human performance issues for follow-up, the inspectors performed a daily screening of items entered into the corrective action program and periodically attended condition report screening meetings.
b. Findings
No findings were identified.
.2 Annual Sample: Fire Protection Challenges Corrective Actions
a. Inspection Scope
The inspectors performed an in-corrective actions associated with condition report CR-2013-16140, fire protection challenges. Specifically, the condition report documented challenges to fire protection equipment reliability, defensive strategies, and compensatory measures and to timely resolution of fire protection system reliability issues. FENOC was appropriately identifying, characterizing, and correcting problems associated with this issue and whether the planned or completed corrective actions were appropriate. The inspectors compared the actions taken to the requirements of B. In addition, the inspectors interviewed engineering personnel to assess the effectiveness of the implemented corrective actions.
b. Findings and Observations
No findings were identified.
FENOC determined the apparent cause was the failure of site management to reinforce standards and expectations of the fire protection program. Contributing causes included failure to effectively implement corrective actions and site wide lack of sensitivity to the importance of the fire protection program and systems.
FENOC implemented 13 corrective actions. Three of the corrective actions addressed the apparent cause which included changes to the form used in the management alignment and ownership meeting to highlight the status of fire protection equipment, providing periodic fire protection program updates to the management team, and allocating additional resources to support the fire protection program. The inspectors determined that this has been effective at raising the awareness of and addressing fire protection issues. Although fire protection program improvements have been made, the protection system health reports are both rated as yellow. Additionally, one of the corrective actions was to prioritize the items in the Fire Protection Improvement Plan. The inspectors noted that several items in the plan had been completed. The inspectors also noted that many of the items remaining to be completed have had their due dates extended. Some item due dates have been extended more than once. This is an indication that there are still some challenges with timely resolution of fire protection reliability issues. FENOC also performed four effectiveness reviews. Two of the four reviews were determined to be ineffective (control of transient combustibles and fire brigade drills) and transient combustible control is consistent with observations made by the inspectors.
4OA3 Follow-Up of Events and Notices of Enforcement Discretion
(Closed) LER 05000334/2014-005-00 and 05000412/2014-005-00: Containment Equipment Hatch Missile Shield Removal Results in Exceeding Technical Specification 3.6.1 Required Completion Times Between January 2003 and April 2014, FENOC improperly established and implemented procedures to remove the Unit 1 and Unit 2 containment equipment hatch missile barriers while in a Mode in which containment was required to be operable. The most recent occurrence was on April 18, 2014, when FENOC removed the Unit 2 equipment aspects of this issue were documented in inspection report 05000334/2014003 and 05000412/2014003. The inspectors did not identify any additional findings during the review of the LER. This LER is closed.
4OA5 Other Activities
Preoperational Testing of an Independent Spent Fuel Storage Installation (ISFSI) (IP 60854 and 60854.1), Review of 10 CFR 72.212 (b) Evaluations (IP 60856 and 60856.1)
a. Inspection Scope
The inspectors evaluated FENOC-operational dry run activities that were performed in order to fulfill requirements in the Certificate of Compliance (CoC) No. 1004, Amendment 13, Condition 8. The inspectors observed FENOC dry run activities on September 15-18, 2014, and were also on-site September 23-26, 2014, to review the BVPS 10 CFR 72.212 evaluation report.
During the dry run activities, the inspectors observed cask processing activities to determine whether the FENOC staff and contractors had developed the capability to properly process the dry shielded canister (DSC) to be used in storage of spent fuel at the BVPS site. The inspectors observed DSC activities including: blowdown, vacuum drying, helium backfilling, reflooding, welding, hydrogen monitoring, non-destructive examinations, and helium leak testing. The inspectors verified that the required vacuum pressure and helium backfill pressure could be achieved and maintained within the technical specification limits. The inspectors examined the DSC processing equipment and reviewed worker qualification records. During the dry run, the inspectors observed pre-job briefs and verified FENOC utilized adequate radiological controls and discussed relevant examples of operating experience. The inspectors verified that work instructions and procedures appropriately captured the commitments and requirements contained in the UFSAR, CoC, technical specifications, and 10 CFR Part 72.
The inspectors evaluated FENOC72.212. The inspectors verified FENOC10 CFR 72.212(b)(5) and confirmed: (1) the conditions set forth in the CoC had been met prior to use; (2) the ISFSI pad had been designed to support the load of stored casks; and (3) the radiological requirements of 72.104 had been met. The inspectors verified that applicable reactor site parameters, such as fire and explosions, tornadoes, wind-generated missile impacts, seismic qualifications, lightning, flooding and temperature, had been evaluated for acceptability with bounding values specified in the UFSAR and the NRC Safety Evaluation Report. The inspectors also verified that a 50.59 evaluation of the construction and operation of the ISFSI and plant interfaces was performed and that ISFSI related work activities would not require a change in the facility TS or require a license amendment for the facility.
The inspectors reviewed corrective action reports conditions reports associated with preparations for the ISFSI loading campaign to ensure that issues were being properly identified, prioritized, and evaluated commensurate with their safety significance.
b. Findings
No findings were identified.
4OA6 Meetings, Including Exit
On November 21, 2014, the inspectors presented the Occupation Radiation Safety inspection results to C. McFeaters, Director, Site Operations, and other members of the BVPS staff.
On December 18, 2014, the inspectors presented the ISFSI inspection results to B. Sepelak, BVPS Regulatory Compliance. On December 18, 2014, the inspector presented the public and occupational radiation Improvement, and other members of the BVPS staff.
On January 29, 2015, the inspectors presented the inspection results to Eric Larson, Site Vice President, and other members of the BVPS staff. The inspectors verified that no proprietary information was retained by the inspectors or documented in this report.
ATTACHMENT:
SUPPLEMENTARY INFORMATION
KEY POINTS OF CONTACT
Licensee Personnel
- E. Larson Site Vice President C. McFeaters Director, Site Operations
- D. Barth Radiation Protection Technician J. Belfiore Senior Consulting Engineer M. Benkowski ISFSI Project Manager W. Blazier Reactor Operator D. Bloom Engineer, Analysis engineering
- G. Cacciani 10 CFR 50.59 Engineer V. Carnevale Quality Control Oversight E. Crosby Radiation Protection Manager A. Crotty Supervisor, System Engineering
- J. DiCioccio System Engineer A. Doby Reactor Operator T. Dometrovich Licensing Consultant G. Ebeck Supervisor, Nuclear Civil/Structural Engineering
- K. Frederick Engineer, Analysis Engineering
- R. Gilchrist Nuclear Unit Supervisor K. Gillespie Nuclear Engineer II J. Gorman System Engineer J. Gross Radiation Protection Technician D. Gyms System Engineer E. Hall Staff Nuclear Specialist R. Hayward Mechanical/Structural Engineer D. Hoover Staff Nuclear Engineering Specialist S. Hovanec ManagerProperty "Contact" (as page type) with input value "R. Gilchrist Nuclear Unit Supervisor K. Gillespie Nuclear Engineer II J. Gorman System Engineer J. Gross Radiation Protection Technician D. Gyms System Engineer E. Hall Staff Nuclear Specialist R. Hayward Mechanical/Structural Engineer D. Hoover Staff Nuclear Engineering Specialist S. Hovanec Manager" contains invalid characters or is incomplete and therefore can cause unexpected results during a query or annotation process., Plant Engineering
- P. Logoyda Radiation Protection Superintendent J. Manning Radiation Protection Supervisor A. Matty Radiation Protection Technician D. McBride System Engineer J. Miller Fire Marshall R. Miller Performance Improvement Specialist K. Mitchell Nuclear Engineer R. Novak RETS/REMP Administrator D. Price SupervisorProperty "Contact" (as page type) with input value "P. Logoyda Radiation Protection Superintendent J. Manning Radiation Protection Supervisor A. Matty Radiation Protection Technician D. McBride System Engineer J. Miller Fire Marshall R. Miller Performance Improvement Specialist K. Mitchell Nuclear Engineer R. Novak RETS/REMP Administrator D. Price Supervisor" contains invalid characters or is incomplete and therefore can cause unexpected results during a query or annotation process., Mechanical/Structural Engineering
- B. Prinkey Supervisor, Nuclear Supply Systems Engineering R. Ruby Radwaste Shipper
Attachment
- D. Salera Chemistry Superintendent J. Saunders Radwaste Supervisor S. Sawtschenko Manager, Emergency Response
- D. Scheider Plant Operator J. Schwer Nuclear Shift Manager B. Sepelak Supervisor, Regulatory Compliance
- S. Snodgrass Reactor Operator B. Spiesman Fleet Regulatory Affairs J. Tolbert Supervisor, Licensed Operator Requalification Training
- T. White Quality Control Oversight D. Wilson Component Engineer T. Winfield Supervisor, Relays Areva TN E. Clendenning Welder M. Hunt PT Inspector M. Williams Director of Field Operations
LIST OF ITEMS OPENED, CLOSED, DISCUSSED, AND UPDATED
Opened/Closed
- 05000334/2014005-01 NCV Failure to Adequately Implement Risk Management Actions (Section 1R13)
- 05000412/2014005-02 NCV Failure to Properly Ship Category 2 Radioactive Material (Section 2RS8)
Closed
- 05000334/2014-005-
- 05000412/LER-2014-005-00 LER Containment Equipment Hatch Missile Shield Removal Inadvertently Results in Exceeding Technical Specification 3.6.1 Required Completion Times (Section 4OA3)
LIST OF DOCUMENTS REVIEWED
Section 1R01: Adverse Weather Protection
Procedures
- 1/2OST-30.21A, Group 1 Flood Door Seal System Operability Check, Revision 8 1/2OST-30.21B, Group 2 Flood Door Seal System Operability Check, Revision 8 1/2OST-45.1, Extreme Cold Weather Protection Verification, Revision 0 1/2OM-53C.4A.75.1, Acts of Nature - Tornado or High Winds, Revision 16 1/2OM-53C.4A.75.2, Acts of Nature - Flood, Revision 30 1OM-45.3.C.2, Power Supply and Control Switch List Heat Tracing System, Revision 21
- Attachment
- 1OST-45.11A, Cold Weather Protection Verification
- Performed in September and October, Revision 1 1OST-45.11B, Cold Weather Protection Verification
- Performed in November, Revision 0 2OST-45.11A, Cold Weather Protection Verification
- Performed in September and October, Revision 1 2OST-45.11B, Cold Weather Protection Verification
- Performed in November, Revision 0
Condition Reports
- 2014-03569 2014-10988 2014-13995 2014-15079 2014-15110 2014-15300 2014-16204 2014-16245 2014-16313 2014-16487 2014-16518 2014-16795 2014-17980
Section 1R04: Equipment Alignment
Procedures
- 1QS, Revision 15 2OM-7.3.B.1, Valve List
- 2CHS, Revision 27
Condition Reports
- 2014-15809 2014-15944
Drawings
- RM-0413-001 Containment Depressurization System, Revision 25 10080-RM-0407-002, Valve Oper No Diagram Charging System VCT and Make-up, Revision 19
Section 1R05: Fire Protection
Procedures
- 2PFP-MSCV-718-Pipe Tunnel Fire Area
- PT-1, Revision 0
Miscellaneous
- BVPS-2, Fire Protection Safe Shutdown Report, Addendum 38 2PFP-AXLB-755, Primary Auxiliary Building, Fire Areas Pa-4,
- PA-6, and
- PA-7, Revision 1
Section 1R11: Licensed Operator Requalification Program
Procedures
- NOP-OP-1002, Conduct of Operations, Revision 9
- NOP-LP-2601, Procedure/Work Instruction Use and Adherence, Revision 5
Section 1R12: Maintenance Effectiveness
Procedures
- BVPM-ER-3004, Maintenance Rule Program Supplemental Guidance, Revision 01
- NOP-ER-3004, FENOC Maintenance Rule Program, Revision 2 1/2CMP-75-MCB-IE, Testing of Westinghouse and Cutler-Hammer Molder Case Circuit Breakers, Revision 15
- Attachment
Condition Reports
- 2014-11748
- 2013-17546
- 2013-00624
- 2013-03722
- 2012-08364
- 2012-07488
- 2012-07445 2013-02346
- 2013-00032
- 2013-08670
- 2013-06544
- 2013-16450
- 2013-00647
Work Orders
- 200075648
- 200380641
Miscellaneous
- Maintenance Rule System Basis Document, Unit 1 System 37, Revision 4
- Unit 1 480 Volt Station Service System Health Report 1st Half 2013-1 Unit 1 480 Volt Station Service System Health Report 1st Half 2013-2 Unit 1 480 Volt Station Service System Health Report 1st Half 2014-1
Section 1R13: Maintenance Risk Assessments and Emergent Work Control
Procedures
- 1OST-39.6, 125 VDC Control System Operating Surveillance Test Station Battery Check, Revision 6 1/2-ADM-0804 On-Line Risk Assessment and Management, Revision 12
Condition Reports
- 2007-17486 2014-15696
- Maintenance Orders/Work Orders 200618032
Section 1R15: Operability Determinations and Functionality Assessments
Procedures
- 1MSP-36.51A-E, 1N 480 Volt Emergency Bus Degraded Voltage Relays 27-RN2100AB and 27-RN2100BC Calibration, Revision 16
- NOP-LP-4003, Evaluation of Changes, Tests and Experiments, Revision 7
- NOP-OP-1009, Operability Determinations and Functionality Assessments, Revision 4 1OST-47.3M, Containment Isolation and ASME Test
- Work Week 9, Revision 20
- NOP-OP-1009, Operability Determinations and Functionality Assessments, Revision 4
Condition Reports
- 2009-59019 2013-01643 2014-16054 2014-15990 2014-15944 2014-16602
- 2014-16618 2014-16652 2014-16878 2014-16958 2014-15874
- Maintenance Orders/Work Orders
- 200535757
- 200620643
Miscellaneous
- 211-N-265, Flood Analysis Outside Containment, Revision 6
- Attachment
Section 1R19: Post-Maintenance Testing
Procedures
- NOP-CC-2007, Part/Component Equivalent Replacement Packages, Revision 3 1OST-30.6A, Reactor Plant River Water Pump 1C Test on Train A Header, Revision 35 1OST-36.1, Diesel Generator No. 1 Monthly Test, Revision 61 1/2CMP-75-Expansion Joint-1M, Inspection and Replacement of Rubber Expansion Joints, Revision 6
- 1/2RCP-96-PC, Calibration of Westinghouse and McGraw Edison Load Tap Changer (LTC) Voltage Regulating Relays, Revision 5 2OST-36.7, Offsite to Onsite Power Distribution System Breaker Alignment Verification, Revision 18
Condition Reports
- 2014-16902 2014-18142
- Maintenance Orders/Work Orders
- 200520018
- 200520078
- 200621378
Miscellaneous
- Part/Component Equivalent Replacement Package
- 000988,
- REJ-1RW-6C Replacement with New Dimensions, Revision 0
Section 1R22: Surveillance Testing
Procedures
- 1OST-13.7B, 2B Recirculation Spray Pump Flow Test, Revision 12 2OST-11.2, Low Head Safety Injection Pump (2SIS*P21B) Test, Revision 31
Work Orders
- 200519658
- 200519661
- 200537566
- 200582204 200541118
Section 1EP6: Drill Evaluation
Procedures
- A5-735A, Emergency Preparedness Plan, Revision 29
Condition Reports
- 2014-15536
Section 2RS6: Radioactive Gaseous and Liquid Effluent Treatment
Procedures
- 1/2-ADM-7 1/2-ENV-
- 1/2-ENV-
- 1-HPP- 1/2-HPP- 2-HPP- 2-HPP--
- Attachment
- Abnormal Release Packages
- RWDA-L-2-JUN-13-02,
- RWDA-L-2-JUN-13-03
- Other 14-01373, Regulatory Applicability Determination, 11/6/2014 Five-Year Update of Groundwater Flow Characteristics Report, Environmental Resources Management, April 28, 2014 Proposal for Tritium Age Dating Analysis, Environmental Resources Management, May 7, 2014 Proposal for Groundwater Protection Program Technical Support, Environmental Resources Management, November 14, 2014
Section 2RS8: Radioactive Solid Waste Processing and Radioactive Material Handling, Storage, and Transportation
- Procedures: 1/2OM-18.4A.C, Use and Handling of High Integrity Containers, Revision 7 1OM-18.4.AF, Dewatering High Integrity Containers, Revision 3 1OM-18.4.AG, Transferring Spent Resin From Resin Waste Hold Tank to a High Integrity Container Using Resin Metering Pump, Revision 5 1OM-18.4.AH, Resin Transfer From Any Group I Ion Exchanger to a Liner/Shipping Container, Revision 9 1OM-18.4.AI, Resin Transfer From Any Group II Ion Exchanger to a Liner/Shipping Container, Revision 7 1OM-18.4.AJ, Rev 4, Resin Transfer From Any Group III Ion Exchanger to a Liner/Shipping Container 1OM-18.4.AO, Transferring Resin Waste Hold Tank to a HIC
- Vendor Procedure Support, Revision 4 1OM-18.4.A, Flushing Resin From Any Group I Ion Exchanger to 1SW-TK-2, Revision 6 2OM-18.4A, Flushing Any Group I Ion Exchanger Resin to the Spent Resin Holding Tank, Revision 5 2OM-18.4.AAB, Local Spent Resin Hold Tank High Level, Revision 2 2OM-18.4.AC, Transfer of Resins From 55-Gallon Drums to the HIC at Unit 2 WHB Truck Bay, Revision 1 2OM-18.4.D, Flushing Any Group I Ion Exchanger Resin to a High Integrity Container,
- Revision 5 2OM-18.4.Y, Dewatering Shipping Containers (HIC) , Revision 7 2OM-18.4.Z, Transferring Spent Resin Hold Tank to a HIC Using a Portable Pump, Revision 1 2OM-18.4.F, Flushing Any Group III Ion Exchanger Resin to a High Integrity Container,
- Revision 2 1/2-HPP-3.07.014, Sampling of Volumetric Materials and Miscellaneous Media for Radioactivity Evaluation, Revision 2
- NOP-OP-5201, Shipment of Radioactive Material
- Waste, Revision 5 1/2-PCP-1.01, Process Control Program, Revision 5 Beaver Valley Business Practice (BVBP)-RP-0011, Seavan Management for the Onsite Storage of Radioactive Material, Revision 6
- BVBP-RP-002, Temporary On-Site Storage of Radioactive Waste, Revision 2 10CFR50.59 Screen # 12-04251, Installation of New Demineralizers in Solid Waste Building
Condition Reports
- 2014-05360 2013-18327 2013-08877 2013-12630 2013-19498 2013-17253 2013-10732
- Attachment
- EnergySolutions DOT/NRC Radioactive Waste Packaging, Transportation and Disposal Dangerous Goods regulations (IATA) Load securing for radioactive Materials NUPIC Audit #23769, Erwin ResinSolutions NUPIC Audit #23201, EnergySolutions
- GEL Laboratories 10CFR Part 50/61 certificates of Analysis for
- U-1 DAW; U-1 Liquid Waste Resin
- U-1 Primary Filters U-1 Primary resin
- U-2 DAW; U-2 Liquid Waste Resin U-2 Primary Filters; U-2 Primary resin
- Beaver Valley Self-Assessment Reports
- SN-SA-13-0205, Radwaste Shipment
- SN-SA-14-0654, Radwaste Shipment
Miscellaneous
- USNRC Quality Assurance Program Approval #0275, Revision 10 FENOC Fleet Oversight Audit Report MS-C-13-08-03
Section 4OA1: Performance Indicator Verification
Condition Reports
- 2013-14499 2013-14653 2013-15561 2013-16937 2013-17070 2013-19558 2014-03890 2014-05255 2014-07793 2014-07834 2014-08765 2014-08948
Miscellaneous
- BVRM-RAS-0001, Unit 1 Mitigating System Performance Index Basis Document, Revision 7
- BVRM-RAS-0002, Unit 2 Mitigating System Performance Index Basis Document, Revision 9 Unit 1 Chemical and Volume Control System Health Report 2013-2 and 2014-1 Unit 2 Chemical and Volume Control System Health Report 2013-2 and 2014-1 Unit 1 Emergency Diesel Generators System Health Report 2013-2 and 2014-1 Unit 2 Emergency Diesel Generators System Health Report 2013-2 and 2014-1
Section 4OA2: Problem Identification and Resolution
Procedures
- NOP-LP-2001, Corrective Action Program, Revision 35
Condition Reports
- 2013-16140 2014-13572 2014-16360
Miscellaneous
- Fire Protection Action Plan, Revision 1 Fire Protection Program Health Report 2014-1 Unit 1 Fire Protection System Health Report 2014-1 Unit 2 Fire Protection System Health Report 2014-1
- Attachment
Section 4OA5: Preoperational Testing of an Independent Spent Fuel Storage Installation
Procedures
- 1OM- ision 0
- 1OM-- 1OM-- 1OM- 1OM- 1OM- 1PFP-DCNM-735, Decon Building Fire Area
- FB-1 Pre Fire Plan, Revision 1
- ITLS Procedure 37PTH PT, Liquid Dye Penetrant Examination Procedure, Revision 0
- NOP-MS-4001, Warehousing, Revision 9
- NOP-LP-2018, Quality Control Inspection and Modification Activities, Revision 9 NUHOMS 37PTH LT , Helium Leak Test Procedure, Revision 1
- SPM 9.5, NUHOMS 37PTH DSC Closure Procedure, Revision 0 TN P8-P8-GT1, Procedure Qualification Record, Revision 1
- WPS-TN P8-P8-GT1, Welding Procedure Specification, Revision 1
Condition Reports
- 2014-14864 2014-14881 2014-14939 2014-15105 2014-17962 2014-18003
Calculations
- Calculation 1/2-DMC- Calculation 1/2-DMC-nt
Miscellaneous
- CFR 72.212 Evaluations Report, Revision 0 dated 9/18/14 BVPS Independent Spent Fuel Storage Installation (ISFSI) 10
- CFR 72.212 Evaluations Report, Revision 0 dated 10/9/14
- DIN 009; Risk Management Program Documentation, Midland Terminal, DCP Midstream; dated May 3, 2007 Form SPM 9.1a-1, Welding Procedure Specification Form SPM 9.1b-2, Welding Operator Performance Qualification ITLS, Certificate of Qualification and Certification Summary Attachment