IR 05000458/2014005: Difference between revisions
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| number = ML15042A392 | | number = ML15042A392 | ||
| issue date = 02/10/2015 | | issue date = 02/10/2015 | ||
| title = | | title = Ir 05000458/2014005; on 10/01/2014 - 12/31/2014; River Bend Station; Integrated Resident and Regional Report; Licensed Operator Requalification Program and Licensed Operator Performance; Problem Identification and Resolution | ||
| author name = Groom J R | | author name = Groom J R | ||
| author affiliation = NRC/RGN-IV/DRP/RPB-C | | author affiliation = NRC/RGN-IV/DRP/RPB-C | ||
Revision as of 02:08, 13 February 2018
| ML15042A392 | |
| Person / Time | |
|---|---|
| Site: | River Bend  |
| Issue date: | 02/10/2015 |
| From: | Groom J R NRC/RGN-IV/DRP/RPB-C |
| To: | Olson E W Entergy Operations |
| Groom J R | |
| References | |
| EA-14-147 IR 2014005 | |
| Download: ML15042A392 (33) | |
Text
February 10, 2015
EA-14-147 Mr. Eric W. Olson, Site Vice President Entergy Operations, Inc. River Bend Station 5485 U.S. Highway 61N St. Francisville, LA 70775
SUBJECT: RIVER BEND STATION - NRC INTEGRATED INSPECTION REPORT 05000458/2014005
Dear Mr. Olson:
On December 31, 2014, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at your River Bend Station, Unit 1. On January 20, 2015, the NRC inspectors discussed the results of this inspection with you and other members of your staff. Inspectors documented the results of this inspection in the enclosed inspection report. NRC inspectors documented two findings of very low safety significance (Green) in this report. Both of these findings involved violations of NRC requirements. The NRC is treating these violations as non-cited violations consistent with Section 2.3.2.a of the NRC Enforcement Policy. Further, as described in Section 4OA7 of the enclosed report, inspectors documented a Severity Level IV licensee-identified violation involving actions where a security officer deliberately falsified training records by using a training proctor's login credentials to take three exams necessary to support unescorted access for a subcontractor. Because you are responsible for the actions of your employees, and because the violation involved willful aspects, the violation was evaluated under the traditional enforcement process as set forth in the NRC Enforcement Policy. The NRC determined that because the deliberately falsified test records did not immediately allow for unescorted access to River Bend Station and because you took significant remedial corrective actions, the failure to maintain complete and accurate information will be a Severity Level IV non-cited violation, with no increase in severity due to a deliberate activity. The NRC is treating this violation as a non-cited violation consistent with Section 2.3.2.a of the NRC Enforcement Policy. If you contest the violations or significance of these non-cited violations, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the U.S. Nuclear Regulatory Commission, ATTN: Document Control Desk, Washington, DC 20555-0001; with copies to the Regional Administrator, Region IV; the Director, Office of Enforcement, U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001; and the NRC resident inspector at the River Bend Station. If you disagree with a cross-cutting aspect assignment in this report, you should provide a response within 30 days of the date of this inspection report, with the basis for your disagreement, to the Regional Administrator, Region IV; and the NRC resident inspector at the River Bend Station. In accordance with Title 10 of the Code of Federal Regulations (10 CFR) 2.390, "Public Inspections, Exemptions, Requests for Withholding," a copy of this letter, its enclosure, and your response (if any) will be available electronically for public inspection in the NRC's Public Document Room or from the Publicly Available Records (PARS) component of the NRC's Agencywide Documents Access and Management System (ADAMS). ADAMS is accessible from the NRC Web site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).
Sincerely,/RA/ Jeremy R. Groom, Acting Branch Chief Project Branch C Division of Reactor Projects Docket Nos.: 50-458 License Nos.: NPF-47
Enclosure:
Inspection Report 05000458/2014005 w/
Attachment:
Supplemental Information cc w/ encl: Electronic Distribution for River Bend Station
Letter and Inspection Report to Eric from Jeremy R. Groom, dated February 10, 2015 SUBJECT: RIVER BEND STATION - NRC INTEGRATED INSPECTION REPORT 05000458/2014005 DISTRIBUTION: Regional Administrator (Marc.Dapas@nrc.gov) Deputy Regional Administrator (Kriss.Kennedy@nrc.gov) DRP Director (Troy.Pruett@nrc.gov) Acting DRP Deputy Director (Thomas.Farnholtz@nrc.gov) DRS Director (Anton.Vegel@nrc.gov) DRS Deputy Director (Jeff.Clark@nrc.gov) Senior Resident Inspector (Jeffrey.Sowa@nrc.gov) Resident Inspector (Andy.Barrett@nrc.gov) RBS Administrative Assistant (Lisa.Day@nrc.gov) Acting Branch Chief, DRP/C (Jeremy.Groom@nrc.gov) Senior Project Engineer (Ray.Azua@nrc.gov) Senior Project Engineer (Nick.Taylor@nrc.gov) Project Engineer (Paul.Nizov@nrc.gov) Project Engineer (Michael.Langelier@nrc.gov) Public Affairs Officer (Victor.Dricks@nrc.gov) Public Affairs Officer (Lara.Uselding@nrc.gov) Project Manager (Alan.Wang@nrc.gov) Acting Branch Chief, DRS/EB1 (Eric.Ruesch@nrc.gov) Branch Chief, DRS/EB2 (Greg.Werner@nrc.gov) Branch Chief, DRS/OB (Vincent.Gaddy@nrc.gov) Branch Chief, DRS/PSB1 (Mark.Haire@nrc.gov) Branch Chief, DRS/PSB2 (Heather.Gepford@nrc.gov) Branch Chief, DRS/TSB (Geoffrey.Miller@nrc.gov) RITS Coordinator (Marisa.Herrera@nrc.gov) ACES (R4Enforcement.Resource@nrc.gov) Regional Counsel (Karla.Fuller@nrc.gov) Technical Support Assistant (Loretta.Williams@nrc.gov) Congressional Affairs Officer (Jenny.Weil@nrc.gov) RIV Congressional Affairs Officer (Angel.Moreno@nrc.gov) RIV/ETA: OEDO (Michael.Waters@nrc.gov) ROPreports Enclosure U.S. NUCLEAR REGULATORY COMMISSION REGION IV Docket: 05000458 License: NPF-47 Report: 05000458/2014005 Licensee: Entergy Operations, Inc. Facility: River Bend Station, Unit 1 Location: 5485 U.S. Highway 61N St. Francisville, LA 70775 Dates: October 1 through December 31, 2014 Inspectors: J. Sowa, Senior Resident Inspector A. Barrett, Resident Inspector T. Farina, Operations Engineer M. Kennard, Operations Engineer C. Steely, Operations Engineer J. Braisted, PhD, Reactor Inspector Approved By: J. Groom, Acting Branch Chief Project Branch C Division of Reactor Projects
SUMMARY
IR 05000458/2014005; 10/01/2014 - 12/31/2014; River Bend Station; Integrated Resident and Regional Report; Licensed Operator Requalification Program and Licensed Operator Performance; Problem Identification and Resolution The inspection activities described in this report were performed between October 1 and December 31, 2014, by the resident inspectors at River Bend Station and inspectors from the NRC's Region IV office. Two findings of very low safety significance (Green) are documented in this report. Both of these findings involved violations of NRC requirements. The significance of inspection findings is indicated by their color (Green, White, Yellow, or Red), which is determined using Inspection Manual Chapter 0609, "Significance Determination Process." Their cross-cutting aspects are determined using Inspection Manual Chapter 0310, "Aspects within the Cross-Cutting Areas." Violations of NRC requirements are dispositioned in accordance with the NRC Enforcement Policy. The NRC's program for overseeing the safe operation of commercial nuclear power reactors is described in NUREG-1649, "Reactor Oversight Process."
Cornerstone: Mitigating Systems
- Green.
The inspectors identified a non-cited violation of 10 CFR 55.46, "Simulation Facilities," for the failure of the licensee to retain the results of required performance tests for four years after completion, or until superseded by updated test results. The licensee could not locate scenario-based testing documentation conducted for the March 2014 initial license exam. The licensee asserted in writing that the testing was performed, but that the electronic test packages had been lost. This issue was entered into the licensee's corrective action program as CR-RBS-2014-04595. The failure of the licensee's training staff to retain the results of scenario-based testing for four years or until superseded was a performance deficiency. The performance deficiency is more than minor, and therefore a finding, because it meets the more-than-minor example of Inspection Manual Chapter 0612, Appendix E, Example 1.b, which states that a record keeping issue is "Not minor if: Required records were irretrievably lost." This is associated with the human performance attribute of the mitigating systems cornerstone and it adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. Specifically, because of the lack of documentation the licensee was unable to demonstrate that its scenario-based testing would ensure the simulator is capable of producing the expected reference unit response without significant performance discrepancies, or deviation from an approved scenario sequence, for scenarios used to evaluate licensed operators and applicants. Using Inspection Manual Chapter 0609, "Significance Determination Process," Phase 1 worksheets, and the corresponding Appendix I, "Licensed Operator Requalification Significance Determination Process" (block 14), the finding was determined to have very low safety significance (Green) because it is a "Simulator Testing, Maintenance, or Modification Deficiency." This finding has a cross-cutting aspect in the procedure adherence component of the human performance cross-cutting area because the licensee failed to ensure that individuals follow processes, procedures, and work instructions [H.8]. (Section 1R11.3)
- Green.
The inspectors reviewed a self-revealing, non-cited violation of Technical Specification 5.4.1.a, "Procedures," for the failure to develop lubrication schedules to ensure the reliability of safety-related motor operated valves (MOV). Specifically, the station failed to properly lubricate the residual heat removal B heat exchanger bypass valve E12-MOV-48B which resulted in the failure of the valve to open when demanded during a system restoration alignment. The station repaired the valve, lubricated the torque arm bearing and all potentially affected torque arm bearings on similar motor operated valves, and updated the preventive maintenance procedure to include lubrication of torque arm bearings. The licensee entered this issue into their corrective action program as Condition Report CR-RBS-2014-04327.
The inspectors determined that the failure of the licensee to promptly implement preventive maintenance to lubricate Velan-style MOV torque arm bearings was a performance deficiency. This performance deficiency is more than minor, and therefore a finding, because it is associated with the Mitigating Systems Cornerstone attribute of equipment performance, and adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences (i.e., core damage). Specifically, E12-MOV-48B could not have performed its safety function to open upon a low pressure core injection initiation signal, due to the lack of lubrication on the valve's torque arm bearing. The senior resident inspector performed the initial significance determination for the inoperable Division II residual heat removal heat exchanger bypass valve. The inspector used the NRC Inspection Manual 0609, Appendix A, Exhibit 2, "Mitigating Systems Screening Questions," dated June 19, 2012, to evaluate this issue. The finding required a detailed risk evaluation because it involved the potential loss of a single train of safety equipment for longer than the technical specification allowed outage time. The exposure period was 8 days. A Region IV senior reactor analyst performed a detailed risk evaluation for this issue and determined that the change to the core damage frequency was much less than 1E-6, and therefore the finding was determined to be of very low safety significance (Green). The diverse coolant injection pathways helped to minimize the risk. This performance deficiency occurred in 2000 and, is not reflective of current licensee performance. (Section 4OA2.3)
Licensee-Identified Violations
One Severity Level IV violation that was identified by the licensee has been reviewed by the inspectors. Corrective actions taken or planned by the licensee have been entered into the licensee's corrective action program. This violation and associated corrective action tracking numbers are listed in Section 4OA7 of this report.
PLANT STATUS
The River Bend Station began the inspection period at 100 percent reactor power. It departed from full power as follows: On October 17, 2014, the plant scrammed from full power. The licensee restarted the reactor on October 22, 2014, and returned the plant to full power on October 27. On December 11, 2014, operators reduced power to 85 percent for a rod sequence exchange. On December 12, 2014, while at 85 percent, the station received a reactor recirculation pump flow control valve runback and power was reduced to 74 percent. The licensee returned the plant to full power on December 13. On December 23, 2014, operators reduced power to 85 percent for feedwater pump maintenance. The plant scrammed from 85 percent power on December 25, 2014, following a trip of the B reactor protection system (RPS) motor generator (MG) set. At the time of the MG set trip, a Division 1 half scram existed due to an unrelated equipment issue with a relay for the #2 turbine control valve fast closure RPS function. The combination of the B RPS MG set trip and the Division 1 half scram satisfied the logic for a full scram. The licensee restarted the reactor on December 27 and the plant was at 85 percent power at the end of December 31, 2014.
REPORT DETAILS
REACTOR SAFETY
Cornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity
1R01 Adverse Weather Protection
.1 Readiness for Seasonal Extreme Weather Conditions
a. Inspection Scope
On November 10, 2014, the inspectors completed an inspection of the station's readiness for seasonal extreme weather conditions. The inspectors reviewed the licensee's adverse weather procedures for seasonal extreme low temperatures and evaluated the licensee's implementation of these procedures. The inspectors verified that prior to the onset of seasonal extreme cold weather, the licensee had corrected weather-related equipment deficiencies identified during the previous seasonal extreme cold weather season.
The inspectors selected two risk-significant systems that were required to be protected from cold weather: Control building chilled water system Instrument air system The inspectors reviewed the licensee's procedures and design information to ensure the systems would remain functional when challenged by adverse weather. The inspectors verified that operator actions described in the licensee's procedures were adequate to maintain readiness of these systems. The inspectors walked down portions of these systems to verify the physical condition of the adverse weather protection features. These activities constituted one sample of readiness for seasonal adverse weather, as defined in Inspection Procedure 71111.01.
b. Findings
No findings were identified.
===.2 Readiness for Impending Adverse Weather Conditions
a. Inspection Scope
On October 14, 2014, the inspectors completed an inspection of the station's readiness for impending adverse weather conditions due to a tornado watch on October 13, 2014. The inspectors reviewed plant design features, the licensee's procedures to respond to severe thunderstorm warnings and tornado watches, and the licensee's planned implementation of these procedures. The inspectors evaluated operator staffing and accessibility of controls and indications for those systems required to control the plant. These activities constituted one sample of readiness for impending adverse weather conditions, as defined in Inspection Procedure 71111.01.
b. Findings
No findings were identified.
1R05 Fire Protection
=
Quarterly Inspection
a. Inspection Scope
The inspectors evaluated the licensee's fire protection program for operational status and material condition. The inspectors focused their inspection on four plant areas important to safety: October 9, 2014, low pressure core spray pump room, fire area AB-6/Z-1 October 9, 2014, containment airlock area, fire area AB-15/Z-5 November 20, 2014, standby switchgear 1A room, fire area C-15 November 20, 2014, standby switchgear 1B room, fire area C-14 For each area, the inspectors evaluated the fire plan against defined hazards and defense-in-depth features in the licensee's fire protection program. The inspectors evaluated control of transient combustibles and ignition sources, fire detection and suppression systems, manual firefighting equipment and capability, passive fire protection features, and compensatory measures for degraded conditions. These activities constituted four quarterly inspection samples, as defined in Inspection Procedure 71111.05.
b. Findings
No findings were identified.
1R07 Heat Sink Performance
a. Inspection Scope
The inspectors reviewed licensee programs to verify heat exchanger performance and operability for the following heat exchangers: Residual heat removal heat exchanger E12-EB001B Spent fuel pool heat exchanger SFC-E2B Reactor plant component cooling water heat exchanger CCP-E1A The inspectors verified whether testing, inspection, maintenance, and chemistry control programs are adequate to ensure proper heat transfer. The inspectors verified that the periodic testing and monitoring methods, as outlined in commitments to NRC Generic Letter 89-13, utilized proper industry heat exchanger guidance. Additionally, the inspectors verified that the licensee's chemistry program ensured that biological fouling was properly controlled between tests. The inspectors reviewed previous maintenance records of the heat exchangers to verify that the licensee's heat exchanger inspections adequately addressed structural integrity and cleanliness of their tubes. Specific documents reviewed during this inspection are listed in the attachment. These activities constitute completion of three triennial heat sink inspection samples, as defined in Inspection Procedure 71111.07-05.
b. Findings
No findings were identified.
1R11 Licensed Operator Requalification Program and Licensed Operator Performance
(71111.11)
.1 Review of Licensed Operator Requalification
a. Inspection Scope
On October 28, 2014, the inspectors observed simulator training for an operating crew. The inspectors assessed the performance of the operators and the evaluators' critique of their performance. The inspectors also assessed the modeling and performance of the simulator during the requalification activities.
These activities constitute completion of one quarterly licensed operator requalification program sample, as defined in Inspection Procedure 71111.11.
b. Findings
No findings were identified.
.2 Review of Licensed Operator Performance
a. Inspection Scope
On October 22, 2014, the inspectors observed the performance of on-shift licensed operators in the plant's main control room. At the time of the observations, the plant was in a period of heightened activity due to plant startup following a forced maintenance outage.
In addition, the inspectors assessed the operators' adherence to plant procedures, including the conduct of operations procedure and other operations department policies.
These activities constitute completion of one quarterly licensed operator performance sample, as defined in Inspection Procedure 71111.11.
b. Findings
No findings were identified.
.3 Biennial Inspection of Licensed Operator Requalification Program
The licensed operator requalification program involves two training cycles that are conducted over a two year period. In the first cycle, the annual cycle, the operators are administered an operating test consisting of job performance measures and simulator scenarios. In the second part of the training cycle, the biennial cycle, operators are administered an operating test and a comprehensive written examination.
a. Inspection Scope
To assess the performance effectiveness of the licensed operator requalification program, the inspectors conducted personnel interviews, reviewed both the operating tests and written examinations, and observed ongoing operating test activities.
The inspectors interviewed five licensee personnel, consisting of three operators and two instructors, to determine their understanding of the policies and practices for administering requalification examinations. The inspectors also reviewed operator performance on the written exams and operating tests. These reviews included observations of portions of the operating tests by the inspectors. The operating tests observed included five job performance measures and three scenarios that were used in the current biennial requalification cycle. These observations allowed the inspectors to assess the licensee's effectiveness in conducting the operating test to ensure operator mastery of the training program content. The inspectors also reviewed medical records of five licensed operators for conformance to license conditions and the licensee's system for tracking qualifications and records of license reactivation for six operators.
The results of these examinations were reviewed to determine the effectiveness of the licensee's appraisal of operator performance and to determine if feedback of performance analyses into the requalification training program was being accomplished. The inspectors interviewed members of the training department and reviewed minutes of training review group meetings to assess the responsiveness of the licensed operator requalification program to incorporate the lessons learned from both plant and industry events. Examination results were also assessed to determine if they were consistent with the guidance contained in NUREG 1021, "Operator Licensing Examination Standards for Power Reactors", Revision 9, Supplement 1, and NRC Manual Chapter 0609, Appendix I, "Operator Requalification Human Performance Significance Determination Process."
In addition to the above, the inspectors reviewed examination security measures, simulator testing and fidelity, and existing logs of simulator deficiencies.
On October 3, 2014, the licensee informed the lead inspector of the results of the written examinations and operating tests for the Licensed Operator Requalification Program. The inspectors compared these results to the Appendix I, "Licensed Operator Requalification Significance Determination Process," values and determined that there were no findings based on these results.
The inspectors completed one inspection sample of the biennial licensed operator requalification program.
b. Findings
Introduction.
The inspectors identified a Green non-cited violation of 10 CFR 55.46, "Simulation Facilities," for the failure of the licensee to retain the results of required performance tests for four years after completion, or until superseded by updated test results. The licensee could not locate scenario-based testing documentation conducted for the March 2014 initial license exam. The licensee confirmed in writing that the testing was performed, but that the electronic test packages had been lost.
Description.
During the week of September 15, 2014, while performing a biennial requalification inspection in accordance with Inspection Procedure 71111.11, "Licensed Operator Requalification Program and Licensed Operator Performance," the inspectors requested to review documentation of the scenario-based testing performed for the March 2014 initial license exam scenarios. The licensee was unable to locate the documentation that week, but hoped to locate it the following week upon the return of a knowledgeable individual. On September 26, the licensee informed the lead inspector that the documentation still could not be located, and was considered lost. Title 10 CFR 55.46, "Simulation Facilities," Section (d)(1) requires that "The results of performance tests must be retained for four years - or until superseded by updated test results." Entergy procedure EN-TQ-202, Revision 9, "Simulator Configuration Control," Section 7.3 also states that "The results of performance tests shall be retained for four years" or until superseded. EN-TQ-210, Rev. 8, "Conduct of Simulator Training," requires in part that "All validation documentation of NRC Initial Exam scenarios (SBT requirements)" be submitted for record retention. In order to determine that the testing actually occurred, the licensee interviewed two operations training individuals who were involved in the validation and collection of the scenario-based testing data for the March 2014 initial license exam. These individuals separately described the collection of the data for the exam between March 1 and 3, 2014, its transfer onto a USB jump drive, and its storage in the exam development room's secure storage cabinet. This jump drive was stored in the cabinet at least until completion of the exam and relaxation of exam security, in early April 2014.
The data was not transferred to the superintendent, simulator support, for final storage as required, and its ultimate fate is unknown. The individuals involved in the testing, provided a signed statement to the inspectors asserting that they performed the testing as described. As an immediate corrective action, the licensee re-performed scenario-based testing for the March 2014 initial licensing exam scenarios during the week of September 22, 2014, and retained the documentation. This issue was entered into the licensee's corrective action program as CR-RBS-2014-04595.
Analysis.
The failure of the licensee's training staff to retain the results of scenario-based testing for four years as required by 10 CFR 55.46 was a performance deficiency. The performance deficiency is more than minor, and therefore a finding, because it meets the more than minor example of Inspection Manual Chapter 0612, Appendix E, Example 1.b, which states that a record keeping issue is "Not minor if: Required records were irretrievably lost." This is associated with the human performance attribute of the mitigating systems cornerstone and it adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. Specifically, because of the lack of documentation the licensee was unable to demonstrate that its scenario-based testing would ensure the simulator is capable of producing the expected reference unit response without significant performance discrepancies, or deviation from an approved scenario sequence, for scenarios used to evaluate licensed operators and applicants. Using Inspection Manual Chapter 0609, "Significance Determination Process," Phase 1 worksheets, and the corresponding Appendix I, "Licensed Operator Requalification Significance Determination Process," the finding was determined to have very low safety significance (Green) because it is a "Simulator Testing, Maintenance, or Modification Deficiency." This finding has a cross-cutting aspect in the human performance area of procedure adherence. Specifically, the licensee failed to ensure that individuals follow processes, procedures, and work instructions, by failing to forward the completed scenario-based testing packages to the superintendent of simulator support for retention, as required by EN-TQ-210, Revision 8, "Conduct of Simulator Training" [H.8].
Enforcement.
Title 10 CFR 55.46, "Simulation Facilities," Section (d)(1) requires that "The results of performance tests must be retained for four years - or until superseded by updated test results." Contrary to the above, the licensee failed to retain documentation of the scenario-based testing performed for the March 2014 initial license exam. The licensee asserted in writing that the testing was performed between March 1 and 3, 2014, but that records of the testing were lost after relaxing exam security in early April, 2014. The inspectors determined that there was no actual or potential safety consequence, because the testing was actually performed. As an immediate corrective action, scenario-based testing was re-performed for the March 2014 initial license exam scenarios, and documentation retained. The licensee has also submitted a change request for procedure EN-TQ-105, "NRC Initial License Exam Development and Administration," to add a step requiring submittal of performance testing documentation to the superintendent, simulator and training support for retention. Because this finding is of very low safety significance and has been entered into the licensee's corrective action program as CR-RBS-2014-04595, it is being treated as a non-cited violation consistent with Section 2.3.2.a of the Enforcement Policy. (NCV 05000458/2014005-01, "Failure to Retain Scenario-Based Testing Documentation")
1R13 Maintenance Risk Assessments and Emergent Work Control
a. Inspection Scope
On October 23, 2014, the inspectors reviewed a risk assessment performed by the licensee prior to changes in plant configuration and the risk management actions taken by the licensee in response to the elevated risk caused by the control building chilled water system chiller C being inoperable during startup from Forced Outage 14-01. The inspectors verified that this risk assessment was performed timely and in accordance with the requirements of 10 CFR 50.65 (the Maintenance Rule) and plant procedures. The inspectors reviewed the accuracy and completeness of the licensee's risk assessment and verified that the licensee implemented appropriate risk management actions based on the result of the assessment. These activities constitute completion of one maintenance risk assessments and emergent work control inspection sample, as defined in Inspection Procedure 71111.13.
b. Findings
No findings were identified.
1R15 Operability Determinations and Functionality Assessments
a. Inspection Scope
The inspectors reviewed four operability determinations and functionality assessment that the licensee performed for degraded or nonconforming structures, systems, and components: October 7, 2014, operability determination of suppression pool leakage (CR-RBS-2014-03353) October 7, 2014, functionality assessment of condensate pump P1A (CR-RBS-2014-04888) October 21, 2014, operability determination of the reactor core isolation cooling trip throttle valve failure to reset (CR-RBS-2014-05310) October 23, 2014, operability determination of high shutdown cooling suction pressure during startup from Forced Outage 14-01 (CR-RBS-2014-05314)
The inspectors reviewed the timeliness and technical adequacy of the licensee's evaluations. Where the licensee determined the degraded structures, systems, and components to be operable or functional, the inspectors verified that the licensee's compensatory measures were appropriate to provide reasonable assurance of operability or functionality. The inspectors verified that the licensee had considered the effect of other degraded conditions on the operability or functionality of the degraded structures, systems, and components.
These activities constitute completion of four operability and functionality review samples, as defined in Inspection Procedure 71111.15.
b. Findings
No findings were identified.
1R19 Post-Maintenance Testing
a. Inspection Scope
The inspectors reviewed five post-maintenance testing activities that affected risk-significant structures, systems, and components: October 15, 2014, WO 52574888, "EJS-SWG1A-ACB006-TX Perform Contact Cleaning" October 15, 2014, WO 52575128, "EJS-SWG1A-ACB006-52XX Perform Contact Cleaning" October 21, 2014, WO 52528936, "Lubricate and Adjust RCIC Trip Throttle Valve Operator Mechanism" November 3, 2014, WO 00396351, "Repair Elbow Leak on Purge Compressor HVK-CHL1C" November 13, 2014, WO 00397449, "EDG 1A Failed to Start During STP-309-0206" The inspectors reviewed licensing- and design-basis documents for the structures, systems, and components and the maintenance and post-maintenance test procedures. The inspectors observed the performance of the post-maintenance tests to verify that the licensee performed the tests in accordance with approved procedures, satisfied the established acceptance criteria, and restored the operability of the affected structures, systems, and components. These activities constitute completion of five post-maintenance testing inspection samples, as defined in Inspection Procedure 71111.19.
b. Findings
No findings were identified.
1R20 Refueling and Other Outage Activities
a. Inspection Scope
During the station's maintenance outage that concluded on October 23, 2014, the inspectors evaluated the licensee's outage activities. The inspectors verified that the licensee considered risk in developing and implementing the outage plan, appropriately managed personnel fatigue, and developed mitigation strategies for losses of key safety functions. This verification included the following: Review of the licensee's outage plan prior to the outage Monitoring of shut-down and cool-down activities Verification that the licensee maintained defense-in-depth during outage activities Monitoring of heat-up and startup activities These activities constitute completion of one outage activities sample, as defined in Inspection Procedure 71111.20.
b. Findings
No findings were identified.
1R22 Surveillance Testing
a. Inspection Scope
The inspectors observed three risk-significant surveillance tests and reviewed test results to verify that these tests adequately demonstrated that the structures, systems, and components were capable of performing their safety functions: Other surveillance tests: October 9, 2014, STP-205-6301, "Division I Low Pressure Core Spray Pump and Valve Operability Test," performed on October 7, 2014 November 12, 2014, STP-203-6305, "HPCS Quarterly Pump and Valve Operability Test," performed on September 23, 2014 November 14, 2014, STP-0309-0206, "Division I Diesel Generator 184 Day Operability Test," performed on November 6, 2014 The inspectors verified that these tests met technical specification requirements, that the licensee performed the tests in accordance with their procedures, and that the results of the test satisfied appropriate acceptance criteria. The inspectors verified that the licensee restored the operability of the affected structures, systems, and components following testing. These activities constitute completion of three surveillance testing inspection samples, as defined in Inspection Procedure 71111.22.
b. Findings
No findings were identified.
Cornerstone:
1EP6 Drill Evaluation
Emergency Preparedness Drill Observation
a. Inspection Scope
The inspectors observed an emergency preparedness drill on October 7, 2014, to verify the adequacy and capability of the licensee's assessment of drill performance. The inspectors reviewed the drill scenario, observed the drill from the Technical Support Center, Simulator Control Room, Operations Support Center, and the Emergency Operations Facility, and attended the post-drill critique. The inspectors verified that the licensee's emergency classifications, off-site notifications, and protective action recommendations were appropriate and timely. The inspectors verified that any emergency preparedness weaknesses were appropriately identified by the licensee in the post-drill critique and entered into the corrective action program for resolution. These activities constitute completion of one emergency preparedness drill observation sample, as defined in Inspection Procedure 71114.06.
b. Findings
No findings were identified.
OTHER ACTIVITIES
Cornerstones: Initiating Events, Mitigating Systems, Barrier Integrity, Emergency Preparedness, Public Radiation Safety, Occupational Radiation Safety, and Security
4OA1 Performance Indicator Verification
.1 Reactor Coolant System Specific Activity (BI01)
a. Inspection Scope
The inspectors reviewed the licensee's reactor coolant system chemistry sample analyses for the period of October 2013 through September 2014 to verify the accuracy and completeness of the reported data. The inspectors observed a chemistry technician obtain and analyze a reactor coolant system sample on November 20, 2014. The inspectors used definitions and guidance contained in Nuclear Energy Institute Document 99-02, "Regulatory Assessment Performance Indicator Guideline," Revision 7, to determine the accuracy of the reported data. These activities constituted verification of the reactor coolant system specific activity performance indicator, as defined in Inspection Procedure 71151.
b. Findings
No findings were identified.
===.2 Reactor Coolant System Total Leakage (BI02)
a. Inspection Scope
The inspectors reviewed the licensee's records of reactor coolant system total leakage for the period of October 2013 through September 2014 to verify the accuracy and completeness of the reported data. The inspectors observed the performance of the RCS leakage surveillance procedure on November 12, 2014. The inspectors used definitions and guidance contained in Nuclear Energy Institute Document 99-02, "Regulatory Assessment Performance Indicator Guideline," Revision 7, to determine the accuracy of the reported data. These activities constituted verification of the reactor coolant system leakage performance indicator, as defined in Inspection Procedure 71151.
b. Findings
No findings were identified.
4OA2 Problem Identification and Resolution
=
.1 Routine Review
a. Inspection Scope
Throughout the inspection period, the inspectors performed daily reviews of items entered into the licensee's corrective action program and periodically attended the licensee's condition report screening meetings. The inspectors verified that licensee personnel were identifying problems at an appropriate threshold and entering these problems into the corrective action program for resolution. The inspectors verified that the licensee developed and implemented corrective actions commensurate with the significance of the problems identified. The inspectors also reviewed the licensee's problem identification and resolution activities during the performance of the other inspection activities documented in this report.
b. Findings
No findings were identified.
.2 Semiannual Trend Review
a. Inspection Scope
The inspectors performed a review of the licensee's corrective action program and associated documents to identify adverse trends. The inspectors focused their review on maintenance effectiveness, but also considered the results of daily corrective action item screening discussed in Section 4OA2.1, above, licensee trending efforts, and licensee human performance results. The inspectors nominally considered the 7-month period of June 2014 through December 2014; although, some examples expanded beyond those dates where the scope of the trend warranted.
The inspectors also included issues documented outside the normal corrective action program in major equipment problem lists, repetitive and/or rework maintenance lists, departmental problem/challenges lists, system health reports, quality assurance audit/surveillance reports, self-assessment reports, and Maintenance Rule assessments. The inspectors compared and contrasted their results with the results contained in the licensee's corrective action program trending reports. Corrective actions associated with a sample of the issues identified in the station's trending reports were reviewed for adequacy. These activities constitute completion of one semi-annual trend review sample, as defined in Inspection Procedure 71152.
b. Findings and Observations
No findings were identified, but the inspectors did have the following observations: The inspectors reviewed equipment failures documented in the corrective action program for potential trends that had not been identified by the licensee. In addition, the inspectors assessed the effectiveness of maintenance to improve the equipment reliability at the station.
The inspectors identified an adverse trend in procedural adherence throughout the assessment period, specifically in the area of Operations and Maintenance. These previously identified failures have resulted in tagging errors, failure of the Division III emergency diesel generator to start during surveillance testing, and prolonged equipment unavailability (control building chilled water system 1A).
.3 Annual Follow-up of Selected Issues
a. Inspection Scope
The inspectors selected two issues for an in-depth follow-up: On August 31, 2014, the station experienced a failure of residual heat removal (RHR) B heat exchanger bypass valve E12-MOV-48B. The valve failed to open during system restoration from a bi-weekly heat exchanger flush. The station documented the event in Condition Report CR-RBS-2014-04307, and performed an apparent cause analysis. The station identified the cause to be that the existing preventive maintenance procedures did not contain instructions to lubricate the torque arm bearing associated with the motor operated valve (MOV). The inspectors assessed the licensee's problem identification threshold, cause analyses, extent of condition reviews, and compensatory actions. The inspectors verified that the licensee appropriately prioritized the planned corrective actions and that these actions were adequate to prevent recurrence.
On November 17, 2014, the inspectors assessed the licensee's problem identification threshold, cause analyses, extent of condition reviews, and compensatory actions for issues associated with operator workarounds. The inspectors then assessed the impact of the cumulative effect of the workarounds. The inspectors verified that the licensee appropriately prioritized the planned corrective actions, that these actions were adequate to correct the conditions, and that the overall impact of all of the conditions did not adversely impact the plant.
These activities constitute completion of two annual follow-up samples, which included one operator work-around sample, as defined in Inspection Procedure 71152.
b. Findings
Introduction.
The inspectors reviewed a self-revealing, Green non-cited violation of Technical Specification 5.4.1.a., "Procedures," for the failure to develop lubrication schedules to ensure the reliability of safety-related MOVs. Specifically, the station failed to properly lubricate the RHR B heat exchanger bypass valve which resulted in the failure of the valve to open when demanded during a system restoration alignment.
Description.
E12-MOV-48B is the RHR loop B heat exchanger bypass valve. This valve has a safety function in the open position to allow water flow to the reactor vessel upon a low pressure coolant injection (LPCI) initiation. This AC powered, Velan-style MOV is normally open but receives an automatic open signal upon a LPCI initiation. On August 31, 2014, operators secured RHR B train from its suppression pool cooling mode, which was utilized for a bi-weekly heat exchanger flush. While stroking the heat exchanger bypass valve open, the main control room received an alarm indicating that RHR B was inoperative. In addition, operators noted erratic indication on E12-MOV-48B. Upon inspection, the licensee identified that the valve had failed to open, and that the valve motor was hot to the touch. The valve's torque arm bearing was determined to have been binding and had unwound and fallen off the assembly. The station determined that E12-MOV-48B failed to open because the torque arm bearing was not sufficiently lubricated.
The licensee reviewed preventive maintenance instructions for this MOV and similar valves, and determined the preventive maintenance procedure did not include instructions to inspect or lubricate the torque arm bearing. The station had previously documented a similar failure of E12-MOV-48A where the torque arm bearing fell off the assembly on May 17, 2000. The station did not identify the need to lubricate torque arm bearings at the time, and considered the failure to be an isolated incident. Upon determining E12-MOV-48B failed as a result of lack of lubrication on the torque arm bearing, the station immediately updated preventive maintenance procedures to lubricate the bearing and performed the updated preventive maintenance on E12-MOV-48B, and all identified similar MOVs to ensure proper lubrication of the torque arm bearing.
Analysis.
The inspectors determined that the failure of the licensee to promptly implement preventive maintenance to lubricate Velan-style MOV torque arm bearings was a performance deficiency. The performance deficiency is more than minor, and therefore a finding, because it is associated with the Mitigating Systems Cornerstone attribute of equipment performance, and adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences (i.e., core damage). Specifically, E12-MOV-48B could not have performed its safety function to open, on a LPCI initiation signal, due to the lack of lubrication on the valve's torque arm bearing.
The senior resident inspector used NRC Inspection Manual 0609, Appendix A, Exhibit 2, "Mitigating Systems Screening Questions," dated June 19, 2012, to evaluate this issue. The finding required a detailed risk evaluation because it involved the potential loss of a single train of safety equipment for longer than the technical specification allowed outage time. The exposure period was 8 days. A Region IV senior reactor analyst performed a detailed risk evaluation for this issue. The analyst used the River Bend Standardized Plant Analysis Risk (SPAR) model, Revision 8.20, to evaluate the change to the core damage frequency (delta-CDF) associated with this finding. The bypass valve was utilized by operators to throttle flow around the RHR heat exchangers for reactor coolant temperature control during shutdown cooling operations. The valve has a close safety function to ensure that cooling water does not entirely bypass the heat exchangers. The valve had recently successfully closed but would not re-open. Operators can operate shutdown cooling with this valve fully closed, but reactor coolant temperature control may require starting and stopping the pump. The valve also has an open safety function so that water can bypass the heat exchangers in the low pressure coolant injection mode, when the heat exchangers are not required. However, if this valve failed in the closed position, the resultant flow through the heat exchangers would be adequate to perform the probabilistic risk function of injecting water to the core. Consequently, none of the probability risk assessment functions were significantly affected by the finding. Further, the failure to open function was not modeled in the NRC SPAR model and was considered a negligible contributor to core damage. The purpose of the significance determination process is to assess the potential for significant core damage. There was no quantifiable increase in the core damage frequency from this finding. The change to the core damage frequency was much less than 1E-6, and therefore the finding is determined to be of very low safety significance (Green). The diverse coolant injection pathways helped to minimize the risk.
While processing this issue, the analyst identified an error in the River Bend SPAR model. Basic event HPI-PHN-FR-CFAILED, containment failure causes loss of high pressure injection, was not a valid event at River Bend. While this event has its origins in BWR-4 SPAR models, it was also included in some of the BWR-6 models. Containment failure will not cause the loss of high pressure injection at River Bend. The analyst set this basic event to zero. The inspectors determined that the apparent cause of the performance deficiency was the station's failure to take effective corrective actions to address issues in a timely manner commensurate with their safety significance. However, the performance deficiency occurred in 2000, and is not reflective of current licensee performance. Therefore, no cross-cutting aspect was identified for this finding.
Enforcement.
Technical Specification 5.4.1.a, "Procedures," requires, in part, that written procedures be established, implemented, and maintained as recommended in Regulatory Guide 1.33, Revision 2, Appendix A, dated February 1978. Paragraph 9.b of Regulatory Guide 1.33, Appendix A, requires, in part, that preventive maintenance schedules should be developed to specify lubrication schedules. Contrary to the above, between May 17, 2000, and August 31, 2014, the licensee failed to establish preventive maintenance lubrication schedules for Velan-style MOV torque arm bearings. Because this violation was of very low safety significance and entered into the licensee's corrective action program as Condition Report CR-RBS-2014-04327, this violation is being treated as a non-cited violation, consistent with Section 2.3.2.a of the NRC's Enforcement Policy: (NCV 05000458/2014005-02, "Failure to Lubricate Residual Heat Exchanger Bypass Valves")
4OA6 Meetings, Including Exit Exit Meeting Summary On September 19, 2014, the inspectors debriefed Mr. Bill Mashburn, Director, Engineering, and other members of the licensee's staff of the results of the licensed operator requalification program inspection, and telephonically exited with Mr. Eric Olson, Site Vice President, and other staff members on October 14, 2014.
The licensee representatives acknowledged the findings presented. The inspectors asked the licensee whether any materials examined during the inspection should be considered proprietary. No proprietary information was identified. On November 21, 2014, the inspector presented the final inspection results to Mr. E. Olson, Site Vice President, and other members of the licensee staff. The licensee acknowledged the issues presented. The inspector asked the licensee whether any materials examined during the inspection should be considered proprietary. No proprietary information was identified. On January 20, 2015, the inspectors presented the integrated inspection results to Mr. E. Olson, Site Vice President, and other members of the licensee staff. The licensee acknowledged the issues presented. The licensee confirmed that any proprietary information reviewed by the inspectors had been returned or destroyed.
On January 28, 2015, the inspectors presented the inspection results to Mr. T. Brumfield, Director, Regulatory & Performance Improvement, and other members of the licensee staff. The licensee acknowledged the issues presented. The licensee confirmed that any proprietary information reviewed by the inspectors had been returned or destroyed.
4OA7 Licensee-Identified Violations
The following Severity Level IV violation was identified by the licensee and is a violation of NRC requirements, which meet the criteria of the NRC Enforcement Policy for being dispositioned as a non-cited violation.
Title 10 of the Code of Federal Regulations, Part 50.9(a), states, in part, that information required by statute or by the Commission's regulations, orders, or license conditions to be maintained by the licensee shall be complete and accurate in all material respects. Technical Specification, Section 5.4.1 states, in part, that written procedures shall be established, implemented, and maintained covering the following activities in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978. Regulatory Guide 1.33, Revision 2, Appendix A, 7.e, "Radiation Protection Procedures" states, in part, that training in radiation protection should be covered by written procedures. River Bend Station administrative procedure EN-TQ-107, "General Employee Training" Revision 9, states, in part, that the requalification training program for unescorted access requires: 1) Generic Plant Access Training; 2) Generic Fitness-for-Duty and Behavior Observation; and 3) Generic Radiation Worker Training. The procedure establishes those requirements, methods, and responsibilities necessary to support unescorted access to the Protected Area and Radiological Controlled Area. River Bend Station administrative procedure EN-TQ-212, "Conduct of Training and Qualification" Revision 13, Section 4.0[1](c),
states, in part, that Entergy personnel are responsible for maintaining qualification and training records for supplemental personnel in a format that is accurate, complete and easily usable.
Contrary to the above, on October 6, 2013, the licensee failed to maintain training records as complete and accurate in all material respects. The training records were incomplete and inaccurate because the Security Officer took three tests representing someone other than herself. The tests results are material to the NRC in that the NRC relies on these test results for demonstration that licensee supplemental personnel (subcontractor) have been provided with appropriate training for access authorization to the Protected Area and Radiological Controlled Area.
Because the incomplete and inaccurate test information did not allow for unescorted access to River Bend Station and because the licensee took significant remedial corrective actions, the NRC determined this to be a Severity Level IV non-cited violation, with no increase in severity due to deliberateness. Therefore, this violation is being treated as a non-cited violation, consistent with Section 2.3.2.a of the Enforcement Policy. The violation was entered into the licensee's correction action program as Condition Report CR-RBS-2013-06417.
A-1 Attachment
SUPPLEMENTAL INFORMATION
KEY POINTS OF CONTACT
Licensee Personnel
- T. Brumfield, Director, Regulatory & Performance Improvement
- D. Burnett, Manager, Emergency Planning
- G. Bush, Manager, Material, Procurement, and Contracts
- M. Chase, Manager, Training
- J. Clark, Manager, Regulatory Assurance
- B. Cole, Manager, Radiation Protection
- F. Corley, Manager, Design & Program Engineering
- E. DeWeese, Engineering
- S. Durbin, Superintendent, Nuclear Operations Training
- B. Ford, Senior Manager, Fleet Regulatory Assurance
- R. Gadbois, General Manager, Plant Operations
- T. Gates, Manager, Operations Support
- K. Hallaran, Manager, Chemistry
- J. Henderson, Assistant Manager, Operations
- K. Huffstatler, Senior Licensing Specialist, Licensing
- P. Lucky, Manager, Performance Improvement
- J. Maher, Manager, Systems & Components Engineering
- W. Mashburn, Director, Engineering
- E. Olson, Site Vice President
- W. Renz, Director, Emergency Planning, Entergy South
- J. Reynolds, Senior Manager, Maintenance
- T. Santy, Manager, Security
- T. Shenk, Manager, Operations
- J. Vukovics, Supervisor, Reactor Engineering
- J. Wieging, Senior Manager, Production
- D. Yoes, Manager, Quality Assurance
LIST OF ITEMS OPENED, CLOSED, AND DISCUSSED
Opened and Closed
- 05000458/2014-005-01 NCV Failure to Retain Scenario-Based Testing Documentation (Section 1R11.3)
- 05000458/2014-005-02 NCV Failure to Lubricate Residual Heat Exchanger Bypass Valves (Section 4OA2.3)
LIST OF DOCUMENTS REVIEWED
Section 1R01: Adverse Weather Protection
Condition Reports
Procedures
- Number Title Revision
- AOP-0029 Severe Weather Operation 030
- OSP-0043 Freeze Protection and Temperature Maintenance 024
Work Orders
- WO 00392928 WO 00392929
Section 1R05: Fire Protection
Condition Report
Procedures
- Number Title Revision
- AB-070-501 LPCS Pump Room Fire Area
- AB-6/Z-1 4
- AB-170-537 Containment Airlock Area Fire Area
- AB-15/Z-5 2
- CB-098-117 Standby Switchgear 1B Room Fire Area C-14 4
- CB-098-118 Standby Switchgear 1A Room Fire Area C-15 2
Section 1R07: Heat Sink Performance
Calculations
- Number Title Revision/Date 0221.432-000-019A RHR Heat Exchanger Calculated Performance June 25, 1990 221.900-HBF-1720 Component Support Fuel Pool Cooling Heat Exchanger 2 223.312.-022 Nozzle Load and Seismic Stress Analysis for Fuel Pool Coolers 4
Calculations
- Number Title Revision/Date G13.18.10.2*38 Evaluate Steady-State Vibration in RHR Test Return Lines 1 G13.18.14.0*183 Required SSW Flow Rate into the SFC Heat Exchangers 2
- PN-235 RPCCW System Heat Exchanger Sizing 0
- PN-311 Spent Fuel Pool Temperatures for Normal and Abnormal Heat Loads for Compliance with NRC Standard Review Plan 9.1.3. 2
- System Health Reports Number Title Date 115
- Closed Cooling Water - Reactor Plant Q3-2014 204 Residual Heat Removal - LPCI Q3-2014
- Thermal Performance Analyses Number Title Revision
- RBS-EP-12-00001 RHR Heat Exchangers E12-EB001B and E12-EB001D Heat Transfer Capacity Verification March 28, 2012 0
- System Design Criteria Number Title Revision
- SDC-115 Reactor Plant Component Cooling Water System 1
- SDC-204 Residual Heat Removal System 4
Miscellaneous
- Number Title Revision/Date
- Closed Cooling Water Systems Strategic Plan 3
- Strategic Chemistry Plan 7 221.920 Design Specification for Fuel Pool Cooling and Clean-Up Heat Exchanger Supports 1 223.312 Specification for Fuel Pool Coolers May 7, 1973 3223.312-022-008A Heat Exchanger Flow Rate Information December 8, 1997
Miscellaneous
- Number Title Revision/Date 3237.210-005-001B Installation Operation and Maintenance Instructions for Reactor Component Cooling Water Heat Exchanger September 28, 1978 Hl-931083 Validation Manual for Computer Code ST_XPERT 3 Task 10774 Perform Flow Balance/Flow Verification on Normal Service Water and Standby Service Water Systems October 5, 2001
Drawings
- Number Title Revision 0223.312-002-005 Tube Layout for 28 I.D. Heat Exchanger 0 0232.900-803-013 Residual Heat Removal Heat Exchanger 1E12*B001B Waterbox: Inlet/Outlet C
- KA-0232.900-803-004 Reactor Plant Component Cooling Water Heat Exchanger 1CCP-E1A Waterbox Inlet 0
- PID-34-02A Fuel Pool Cooling 21
- PID-34-02B Fuel Pool Cooling 19
Procedures
- Number Title Revision/Date
- EN-DC-184 NRC Generic Letter 89-13 Service Water Program 3
- EN-DC-316 Heat Exchanger Performance and Condition Monitoring 6
- SEP-HX-RBS-001 Service Water Heat Exchanger Inspections 1
- SEP-HX-RBS-002 Performance Monitoring Program for the Residual Heat Removal Heat Exchangers E12-EB001B and E12-EB001D (Division II) 6
- SEP-SW-RBS-001 RBS GL89-13 Service Water Heat Exchanger Program 0 T10284 Division II SWP Flow Test October 30, 2014 T9511 RHR Heat Exchanger Inspection November 9, 2014
- STP-602-6312 Division II Fuel Pool Cooling Pump and Valve Operability Test 305
- SOP-0042 Standby Service Water System (System #256) 39
Condition Reports
(Reviewed during Inspection)
Condition Reports
(Initiated during Inspection)
Work Orders
- 50967574
- 00329151
- 51008285
- 5034491
- 50353437
- License Commitments P-15854 P-08340 P-15856 P-15857 P-15858
Section 1R11: Licensed Operator Requalification Program and Licensed Operator Performance
Condition Reports
- DR-14-0018
- DR-14-0030
- DR-14-0032
- DR-14-0034
Miscellaneous Documents
- Number Title Date N/A Baseline Data - Transient Test - Manual Scram January 15, 2004 N/A Baseline Data - Transient Test - Simultaneous Trip of all Feedwater Pumps August 28, 2007 N/A Baseline Data - Transient Test - Simultaneous Closure of all Main Steam Isolation Valves August 28, 2007 N/A Baseline Data - Transient Test - Single Recirculation Pump Trip December 2012 N/A Reactor Core Performance Testing - Cold Startup January 17, 2014 N/A Reactor Core Performance Testing - BWR Power Coefficient of Reactivity and Control Rod Worth October 25, 2013
Miscellaneous Documents
- Number Title Date N/A Reactor Core Performance Testing - BWR Xenon Worth June 21, 2013 N/A Simulator Operability Test - Steady State August 25, 2014 N/A Post-event Scenario Testing 12-01 - Turbine-Generator Trip/Reactor Scram from 100% Power February 14, 2012 N/A Post-event Scenario Testing 13-02 - "C" FW Reg Valve Fails Open February 16, 2014 N/A Complete Operating Test - Week of 8/25/2014 August 25, 2014 N/A Complete Operating Test - Week of 9/1/2014 September 1, 2014 N/A Complete Operating Test - Week of 9/15/2014 September 15, 2014 N/A Complete Written Exam - Week of 8/25/2014 August 25, 2014
- CR-RBS-2014-1218 Apparent Cause Evaluation - Simulator Fidelity Issues April 8, 2014 OLTS Report 9 Active Operators Count - RBS September 3, 2014 OLTS Report 14 License Restriction Report - RBS September 3, 2014
- RBS-TT-01 Transient Test - Manual Scram October 17, 2013
- RBS-TT-03 Transient Test - Simultaneous Closure of all Main Steam Isolation Valves October 17, 2013
- RBS-TT-05 Transient Test - Single Recirculation Pump Trip October 24, 2013
Procedures
- Number Title Revision/Date
- AOP-0008 Loss of Instrument Air 37
Procedures
- Number Title Revision/Date
- AOP-0024 Thermal Hydraulic Stability Controls 25
- AOP-0027 Fuel Handling Mishaps 28
- AOP-0028 Seismic Event 11
- AOP-0051 Loss of Decay Heat Removal 312 EIP 2-001 Classification of Emergencies 24
- EN-TQ-112 Medical Program 12
- EN-TQ-114 Licensed Operator Requalification Training Program Description 9
- EN-TQ-202 Simulator Configuration Control 9
- EOP-0002 Emergency Operating Procedure - Primary Containment Control 15
- FHP-0001 Control of Fuel Handling and Refueling Operations 35
- GOP-0002 Power Decrease / Plant Shutdown 68
- OSP-0053 Attachment 13 Initiating Standby Liquid Control 22
- OSP-0066 Attachment 9 RCIC Alternate Flow Indication and RPV Water Level Indication 23 R-DAD-TQ-019 RBS Simulator Software Configuration Control and Verification Testing 00 R-DAD-TQ-024 RBS Simulator Performance Testing 00
Section 1R13: Maintenance Risk Assessments and Emergent Work Control
Condition Reports
Procedure
- Number Title Revision
- ADM-0096 Risk Management Program Implementation and On-Line Maintenance Risk Assessment 315
- Technical Document Number Title Revision NUMARC 93-01 Nuclear Energy Institute Industry Guideline for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants 4A
Section 1R15: Operability Determinations and Functionality Assessments
Condition Reports
Procedure
- Number Title Revision
- STP-207-4536 RCIC Isolation - RCIC Steam Line Flow High Channel Functional Test (E31-N683A, E31-N690A, E51A-K64) 302
- Work Order
Section 1R19: Post-Maintenance Testing
Condition Reports
- Maintenance Documents
- WO 52574888 WO 52575128
Section 1R20: Refueling and Other Outage Activities
Condition Reports
Procedures
- Number Title Revision
- ADM-0096 Risk Management Program Implementation and On-Line Maintenance Risk Assessment 315
- EN-LI-118 Causal Evaluation Process 20
- EN-LI-118-08 Rev. 2, Attachment 9.1 Failure Mode Analysis Worksheet - Reactor Trip Due to Unexpected Turbine Anomalies (Bypass and Control Valve Movement) ---
- EN-OP-111 Rev. 11, Attachment 9.2 Operational Decision-Making Issue Implementation Action Plan - Intermittent Failure of Turbine Steam Flow Reference Signal Draft
- GOP-0003 Scram Recovery 024
Procedure
- 022
- Training Documents Number Title Revision R-STM-0509 Turbine Electro-Hydraulic Control System 13
- RPPT-STM-0509-LOR Electro-Hydraulic Control (EHC) 000
Section 1R22: Surveillance Testing
Condition Report
- Maintenance Documents
Procedures
- Number Title Revision
- STP-203-6305 HPCS Quarterly Pump and Valve Operability Test 027
- STP-203-6501 HPCS Pump and Valve Operability Test 010
Procedures
- Number Title Revision
- STP-205-6301 LPCS Pump and Valve Operability Test 024
- STP-309-0206 Division I Diesel Generator 184 Day Operability Test 025
Section 1EP6: Drill Evaluation
Condition Report
Procedure
- Number Title Revision
- RDRL-EP-1200 Site Drill Scenario 03
Section 4OA1: Performance Indicator Verification
Miscellaneous
- Document Number Title Date
- RBG-47512 Electronic Submittal of Third Quarter 2014 NRC Performance Indicator Information October 21, 2014
Procedures
- Number Title Revision
- COP-0001 Sampling Via Various Balance of Plant Systems 23
- COP-0032 Startup and Operation of the Reactor Sample Panel G33-Z020 10
- COP-0044 Configuration Control of Sampling Valves 2
- EN-LI-114 Performance Indicator Process 6
- STP-000-0001 Daily Operating Logs 078
Section 4OA2: Problem Identification and Resolution
Procedure
- Number Title Revision
- EN-FAP-OP-006 Operator Aggregate Impact Index Performance Indicator 2