IR 05000302/2007004
| ML072910494 | |
| Person / Time | |
|---|---|
| Site: | Crystal River  |
| Issue date: | 10/18/2007 |
| From: | Vias S J NRC/RGN-II/DRP/RPB3 |
| To: | Young D E Progress Energy Florida |
| References | |
| IR-07-004 | |
| Download: ML072910494 (17) | |
Text
October 18, 2007
Mr. Dale E. Young, Vice PresidentCrystal River Nuclear Plant (NA1B)
ATTN: Supervisor, Licensing & Regulatory Programs15760 West Power Line Street Crystal River, FL 34428-6708
SUBJECT: CRYSTAL RIVER UNIT 3 - NRC INTEGRATED INSPECTION REPORT 05000302/2007004
Dear Mr. Young:
On September 30, 2007, the US Nuclear Regulatory Commission (NRC) completed aninspection at your Crystal River Unit 3. The enclosed integrated inspection report documents the inspection results, which were discussed on October 1, 2007, with you and members of your staff.The inspection examined activities conducted under your license as they relate to safety andcompliance with the Commission's rules and regulations and with the conditions of your license.
The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel.Based on the results of this inspection, no findings of significance were identified.
In accordance with 10 CFR 2.390 of the NRC's "Rules of Practice," a copy of this letter and itsenclosure will be available electronically for public inspection in the NRC Public DocumentRoom or from the Publicly Available Records (PARS) component of NRC's document 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/Steven J. Vias, ChiefReactor Projects Branch 3 Division of Reactor ProjectsDocket No.: 50-302License No.: DPR-72
Enclosure:
Inspection Report 05000302/2007004
w/Attachment:
Supplemental Informationcc w/encl: (See page 2)
_________________________OFFICERII:DRPRII:DRPRII:DRPSIGNATURESJVTXM1RJR1NAMESViasTMorrisseyRReyesDATE10/18/200710/18/200710/18/2007 E-MAIL COPY? YESNO YESNO YESNO YESNO YESNO YESNO YESNO FPC2cc w/encls:Jon A. Franke Director Site Operations Crystal River Nuclear Plant (NA2C)
Electronic Mail DistributionMichael J. AnnaconePlant General Manager Crystal River Nuclear Plant (NA2C)
Electronic Mail DistributionPhyllis DixonManager, Nuclear Assessment Crystal River Nuclear Plant (NA2C)
Electronic Mail DistributionStephen J. CahillEngineering Manager Crystal River Nuclear Plant (NA2C)
Electronic Mail DistributionDaniel L. RoderickVice President, Nuclear Projects and Construction Crystal River Nuclear Plant Electronic Mail DistributionDavid M. VarnerManager, Support Services - Nuclear Crystal River Nuclear Plant Electronic Mail DistributionR. Alexander GlennAssociate General Counsel (MAC - BT15A)
Florida Power Corporation Electronic Mail DistributionSteven R. CarrAssociate General Counsel - Legal Dept.
Progress Energy Service Company, LLC Electronic Mail DistributionAttorney GeneralDepartment of Legal Affairs The Capitol PL-01 Tallahassee, FL 32399-1050William A. PassettiBureau of Radiation Control Department of Health Electronic Mail DistributionCraig Fugate, DirectorDivision of Emergency Preparedness Department of Community Affairs Electronic Mail DistributionChairmanBoard of County Commissioners Citrus County 110 N. Apopka Avenue Inverness, FL 36250Jim MallayFramatome Technologies Electronic Mail Distribution FPC3Letter to Dale from Steven J. Vias, dated October 18, 2007.
SUBJECT: CRYSTAL RIVER UNIT 3 - NRC INTEGRATED INSPECTION REPORT 05000302/2007004Distribution w/encl
- S. Bailey, NRR C. Evans (Part 72 Only)
L. Slack, RII EICS RIDSNRRDIRS OE Mail PUBLIC U. S. NUCLEAR REGULATORY COMMISSIONREGION IIDocket No.:50-302 License No.:DPR-72 Report No:05000302/2007004 Licensee:Progress Energy Florida (Florida Power Corporation)
FacilityCrystal River Unit 3 Location:15760 West Power Line StreetCrystal River, FL 34428-6708Dates:July 1, 2007 - September 30, 2007 Inspectors:T. Morrissey, Senior Resident InspectorR. Reyes, Resident InspectorApproved by:Steven J. Vias, ChiefReactor Projects Branch 3 Division of Reactor Projects Enclosure
SUMMARY OF FINDINGS
IR 05000302/2007-004; 07/01/2007 - 09/30/2007; Crystal River Unit 3; Routine IntegratedReport.The report covered a 3-month period of inspection by the resident inspectors. The NRC'sprogram for overseeing the safe operation of commercial nuclear power reactors is described in
NUREG-1649, "Reactor Oversight Process," Revision 4, dated December 2006.A.
NRC-Identified Findings and Self-Revealing Findings
No findings of significance were identified.B.Licensee-identified Violations None Enclosure
REPORT DETAILS
Summary of Plant Status
- The unit operated at essentially 100 percent power during the quarter.
REACTOR SAFETY
Cornerstones: Initiating Events, Mitigating Systems, Barrier Integrity
1R04 Equipment Alignment
.1 Partial System Walkdowns
a. Inspection Scope
The inspectors performed walkdowns of the critical portions of the selected trains toverify correct system alignment. The inspectors reviewed plant documents to determine the correct system and power alignments, and the required positions of select valves and breakers. The inspectors verified that the licensee had properly identified and resolved equipment alignment problems that could cause initiating events or impact mitigating system availability. The inspectors verified the following four partial system alignments in system walkdowns using the listed documents:Nuclear service water (SW) pumps SWP-1B and SWP-1C systems, usingOperating Procedure OP-408, Nuclear Services Cooling System, while SWP-1A was out of service for planned maintenance;Control complex chilled water system (CHHE-1A), using OP-409, PlantVentilation System, while chiller CHHE-1B was out of service for planned maintenance;Makeup (MU) system pumps MUP-1A, MUP-1B, and MUP-1C, using OperatingProcedure OP-402, Makeup and Purification System, and raw water (RW)pumps RWP-2A, RWP-2B, RWP-3A, and RWP-3B, using OP-408, Nuclear Services Cooling System, while the alternate AC emergency diesel generator (EGDG-1C) and feedwater pump (FWP-7) were both out of service for maintenance; and "A" train decay heat closed cycle cooling (DC) and decay heat removal (DHR)systems, using OP-404, Decay Heat Removal System, while the B train emergency core cooling system (ECCS) was out of service for maintenance.
b. Findings
No findings of significance were identified.
4Enclosure.2Complete System Walkdown
a. Inspection Scope
The inspectors conducted one detailed walkdown/review of the alignment and conditionof the emergency diesel generator EGDG-1B and its associated 4160V engineered safeguards (ES) Bus 3B. The inspectors utilized licensee procedures, as well as licensing and design documents to verify that the system (i.e., pump, valve, and electrical) alignment was correct. During the walkdown, the inspectors also verified that:
the pumps, valves and piping associated with the diesel did not exhibit leakage thatwould impact its function, major portions of the systems and components were correctly labeled, hangers and supports were installed and functional; and essential support systems were operational. In addition, pending design and equipment issues were reviewed to determine if the identified deficiencies impacted the systems functions. A review of open nuclear condition reports (NCRs) was performed to verify that the licensee had appropriately characterized and prioritized equipment problems for resolution in corrective action program. Documents reviewed are listed in the attachment.
b. Findings
No findings of significance were identified.
1R05 Fire ProtectionFire Protection Walkdowns
a. Inspection Scope
The inspectors walked down accessible portions of the plant to assess the licensee'simplementation of the fire protection program. The inspectors checked that the areas were free of transient combustible material and other ignition sources. Also, fire detection and suppression capabilities, fire barriers, and compensatory measures for fire protection problems were verified. The inspectors checked fire suppression and detection equipment to determine whether conditions or deficiencies existed which could impair the function of the equipment. The inspectors selected the areas based on a review of the licensee's probabilistic risk assessment. The inspectors also reviewed the licensee's fire protection program to verify the requirements of Final Safety Analysis Report (FSAR) Section 9.8, Plant Fire Protection Program, were met. Documents reviewed are listed in the attachment. The inspectors toured the following nine areas important to reactor safety:*Emergency feed pump (EFP-3) building*Intermediate building 95' elevation, EFP-1 and EFP-2 areas
- Emergency feed tank (EFT-2) building and the alternate AC emergency dieselgenerator EGDG-1C building*FWP-7 area
- Cable spreading room 5Enclosure*Makeup pump cubicles*Control complex chiller room
- Auxiliary building 95' level sea water room
- Control complex B train ES 4160 V switchgear room
b. Findings
No findings of significance were identified.
1R11 Licensed Operator Requalification ProgramResident Inspector Quarterly Review
a. Inspection Scope
On August 8, 2007, the inspectors observed one separate licensed operating trainingactivity associated with a loss of decay heat removal during shutdown conditions. The inspectors observed a classroom training session associated with a loss of reactor coolant system coolant (lesson OPS-5-114) and operator response and actions for the Crystal River, Unit 3 simulator training session, LOR-1-05. The simulator session involved a loss of the operating decay removal pump and required the crew to use plant abnormal procedure AP-404, Loss of Decay Heat Removal.The inspectors specifically evaluated the following attributes related to crewperformance:
- Clarity and formality of communication including crew briefings
- Ability to take timely action to safely control the unit
- Prioritization, interpretation, and verification of alarms
- Correct use and implementation of off-normal procedures; and emergency planimplementing procedures *Control board operation and manipulation, including operator actions
- Oversight and direction provided by supervision, including ability to identify andimplement appropriate technical specification actions, regulatory reporting requirements, and emergency plan classification and notification*Crew overall performance and interactions
b. Findings
No findings of significance were identified.
1R12 Maintenance Effectiveness
a. Inspection Scope
The inspectors reviewed the licensee's effectiveness in performing routine maintenanceactivities. This review included an assessment of the licensee's practices pertaining to the identification, scope, and handling of degraded equipment conditions, as well as 6Enclosurecommon cause failure evaluations and the resolution of historical equipment problems. For those systems, structures, and components within the scope of the maintenance rule per 10 CFR 50.65, the inspectors verified that reliability and unavailability were properly monitored, and that 10 CFR 50.65 (a)(1) and (a)(2) classifications were justified in light of the reviewed degraded equipment condition. Documents reviewed are listed in the attachment. The inspectors conducted this inspection for three degraded equipment conditions listed below. *NCR 227266, Repetitive maintenance rule functional failure of RC-1-LIR3*NCR 221234, Maintenance rule functional failure of boric acid water storage tank(BWST) level indicator DH-37-LT*NCR 186375, Control complex chiller CHHE-1A trip
b. Findings
No findings of significance were identified.
1R13 Maintenance Risk Assessments and Emergent Work Control
a. Inspection Scope
The inspectors reviewed the risk impact associated with those activities listed below andverified the licensee's associated risk management actions. This review primarily focused on equipment determined to be risk significant within the maintenance rule.
The inspectors also assessed the adequacy of the licensee's identification and resolution of problems associated with risk management including emergent work activities. The licensee's implementation of compliance procedure CP-253, Power Operation Risk Assessment, was verified in each of the following seven work week
assessments:*Work Week 07W27, Risk assessment for preventative maintenance on servicewater pump SWP-1A, testing of emergency diesel generator EGDG-1A and emergent work to replace a main steam pressure transmitter and a failed A train reactor protection system reactor coolant system high pressure bistable;*Work Week 07W29, Risk assessment for preventative maintenance on controlcomplex chiller CHHE-1B, preventative maintenance and testing of emergency diesel generator EGDG-1B, and emergent battery cell replacement on ES battery DPBA-1B;*Work Week 07W30, Risk assessment for maintenance performed on feedwaterpump FWP-9 and testing of FWP-7, and preventive maintenance on emergency diesel generator EGDG-1C;*Work Week 07W32, Risk assessment for emergency feedwater pump EFP-3maintenance outage, and emergent issues associated with emergency feed valve (EFV-55), and EFP-3 crank case pressure switch DL-37-PS; 7Enclosure*Work Week 07W33, Risk assessment for operations with B emergency corecooling train (DC, RW and DHR) out of service for scheduled maintenance (Yellow risk condition);*Work Week 07W35, Risk assessment for maintenance on makeup pump MUP-1B, routine testing of emergency diesel generator EGDG-1A and corrective maintenance on emergency feedwater pump EFP-3; and*Work Week 07W36, Risk assessment for operations with A emergency coolcooling train (DC, RW and DHR) out of service for scheduled maintenance (Yellow risk condition).
b. Findings
No findings of significance were identified.
1R15 Operability Evaluations
a. Inspection Scope
The inspectors reviewed the following seven NCRs to verify that the operability ofsystems important to safety was properly established, that the affected components or systems remained capable of performing their intended safety function, and that no unrecognized increase in plant or public risk occurred. The inspectors determined if operability of systems or components important to safety was consistent with technical specifications, the FSAR, 10 CFR Part 50 requirements, and when applicable, NRC Inspection Manual, Part 9900, Technical Guidance, "Operability Determinations &
Functionality Assessments for Resolution of Degraded or Nonconforming Conditions Adverse to Quality or Safety." The inspectors reviewed licensee NCRs, work schedules, and engineering documents to check if operability issues were being identified at an appropriate threshold and documented in the corrective action program, consistent with 10 CFR 50, Appendix B requirements; and licensee procedure NGGC-CAP-200, corrective action program.*NRC 213617, Engineered safeguards loads are not evaluated for EGDGoperating frequencies other than 60 Hertz*NCR 238440, CR3 Low flow analysis power operated relief valve (PORV)closure value different from plant value*NCR 239342, Anti-rotation devises are bent on emergency feedwater valvesEFV-11 and EFV-14*NCR 240381, RW pit manway has rust and spalling
- NCR 243181, Emergency feed pump EFP-3 high crankcase pressure alarm atengine start 8Enclosure*NCR 237842, Emergency diesel generator EGDG-1B fuel-oil pressure low out ofspecification*NCR 247738, Part 21 potential defective circuit card installed in ES emergencydiesel generator voltage control circuit
b. Findings
No findings of significance were identified.
1R19 Post-Maintenance Testing
a. Inspection Scope
The inspectors witnessed and/or reviewed post-maintenance test procedures and/or testactivities, as appropriate, for selected risk significant systems to verify whether: (1)testing was adequate for the maintenance performed;
- (2) acceptance criteria were clear, and adequately demonstrated operational readiness consistent with design and licensing basis documents;
- (3) test instrumentation had current calibrations, range, and accuracy consistent with the application;
- (4) tests were performed as written with applicable prerequisites satisfied, and
- (5) equipment was returned to the status required to perform its safety function. The six post-maintenance tests reviewed are listed below: *Surveillance Procedure (SP)-344A, RWP-2A, SWP-1A and Valve Surveillance,after performing maintenance on service water pump SWP-1A per work orders (WOs) 804902 and 1035290;*Surveillance Procedure SP-110A, "A" Channel Reactor Protection SystemFunctional Test (partial), after performing emergent work replacing a reactor coolant system high pressure bistable in reactor protection system channel A per WO 1089059;*Surveillance Procedure SP-349C, EFP-3 and Valve Surveillance, afterperforming maintenance on emergency feed pump EFP-3 per WO 1054756;*Surveillance Procedure SP-344B, RWP-2B, SWP-1B and Valve Surveillance,and SP-340E, DHP-1B, BSP-1B and Valve Surveillance, after performing maintenance on the B ECCS train per WOs 1027049, 744594, 885123, 831227
and 1058638;*Surveillance Procedure SP-344A, RWP-2A, SWP-1A and Valve Surveillance,and SP-340E, DHP-1A, BSP-1A and Valve Surveillance, after performing maintenance on the A ECCS train per WOs 1016359, 101359, 697505, 756488 and 1082829; and*Surveillance Procedure SP-349B, EFP-2 and Valve Surveillance, afterperforming valve maintenance per WOs 853662 and 856067.
b. Findings
No findings of significance were identified.
1R22 Surveillance Testing
a. Inspection Scope
The inspectors observed and/or reviewed the surveillance tests listed below to verify that technical specification surveillance requirements were followed and that test acceptance criteria were properly specified. The inspectors verified that proper test conditions were established as specified in the procedures, that no equipment preconditioning activities occurred, and that acceptance criteria had been met.
Additionally, the inspectors also verified that equipment was properly returned to service and that proper testing was specified and conducted to ensure that the equipment could perform its intended safety function following maintenance or as part of surveillance testing. The following five activities were observed/reviewed:In-Service Test:*SP-334A, Spent Fuel Pump SFP-1A Quarterly Surveillance Surveillance Tests
- SP-130, Engineered Safeguards Monthly Functional Test
- SP-457A, ECCS Response to a Safety Injection Test Signal (Mode 1-3)
- SP-101, Moderator Temperature Coefficient Determination at 300 PPM Boron Reactor Coolant System Leak Detection Test
- SP-317, RC System Water Inventory Balance
b. Findings
No findings of significance were identified.
1R23 Temporary Plant Modifications
a. Inspection Scope
The inspectors evaluated one temporary modification and the associated 10 CFR 50.59screening against the system design basis documentation and FSAR to verify the modification did not adversely affect the safety functions of important safety systems.
Additionally, the inspectors reviewed licensee procedure EGR-NGGC-0005, Engineering Change, to assess if the modification was properly developed and implemented.
10Enclosure*WO 1095194, Jumper in spare cell on vital battery DPBA-1B in accordance withmaintenance procedure MP-401, battery maintenance
b. Findings
No findings of significance were identified.4.OTHER ACTIVITIES 4OA1Performance Indicator (PI) VerificationInitiating Events and Mitigating systems Cornerstones
a. Inspection Scope
The inspectors checked the accuracy of the performance indicators listed below.Performance indicator data submitted from October 2006 through June 2007, was compared for consistency to data obtained through the review of engineering department records, control room logs, and licensee event reports. Performance indicator definitions and guidance contained in NEI 99-02, "Regulatory Assessment Performance Indicator Guideline," Rev. 4, were used to check the reporting for each data element. The inspectors checked that any deficiencies affecting the licensee's performance indicator program were entered into the corrective action program (CAP)and appropriately resolved.*Safety System Functional Failures
b. Findings
No findings of significance were identified.4OA2Problem Identification and Resolution.1Daily Review
a. Inspection Scope
As required by inspection procedure 71152, "Identification and Resolution of Problems,"and in order to help identify repetitive equipment failures or specific human performance issues for follow-up, the inspectors performed a daily screening of items entered into the licensee's CAP. This review was accomplished by attending daily plant status meetings; interviewing plant operators and applicable system engineers, and accessing the licensee's computerized database.
b. Findings
No findings of significance were identified.
11Enclosure.2Annual Sample Review
a. Inspection Scope
The inspectors reviewed the operator workaround program to verify the licensee isidentifying workarounds at an appropriate threshold and is entering them in a correction action program. The inspectors performed an evaluation of the potential cumulative effect of all outstanding operator workarounds. Documents reviewed are listed in the attachment.
b. Findings and Observations
No findings of significance were identified. 4OA6Meetings
Exit Meeting Summary
On October 1, 2007, the resident inspectors presented the inspection results to Mr. D.Young, Site Vice President and other members of licensee management. The inspectors confirmed that proprietary information was not provided or examined during the inspection.ATTACHMENT:
SUPPLEMENTAL INFORMATION
KEY POINTS OF CONTACT
Licensee
- M. Annacone, Plant General Manager
- W. Brewer, Manager, Maintenance
- S. Cahill, Manager, Engineering
- P. Dixon, Manager, Nuclear Assessment
- J. Franke, Director of Site Operations
- R. Hons, Manager, Training
- I. Wilson, Manager, Outage and Scheduling
- J. Holt, Manager, Operations
- D. Herrin (Acting), Supervisor, Licensing
- M. Rigsby, Superintendent, Radiation Protection
- J. Stephenson, Supervisor, Emergency Preparedness
- D. Young, Vice President, Crystal River Nuclear Plant
NRC personnel
- S. Vias, Chief, Reactor Projects Branch 3, NRC Region II
LIST OF ITEMS
OPENED AND CLOSEDOpened and
Closed
- None
LIST OF DOCUMENTS REVIEWED
Section 1R05: Fire ProtectionProceduresAI-2200, Guidelines for Handling Use and Control of Transient CombustiblesAI-2205A, Pre Fire Plan - Control Complex
- AI-2205B, Pre Fire Plan - Turbine Building
- AI-2205C, Pre Fire Plan - Auxiliary Building
- AI-2205F, Pre Fire Plan - Miscellaneous Buildings and Components
Section 1R12: Maintenance EffectivenessSE07-0052 Maintenance Rule
- RCS Instrument Performance MonitoringNuclear Condition Reports231293
- CHHE-1A tripped on high condenser pressure221306 Safety related transmitter failed due to water damage
- 198642
- DH-37-LI reads zero
- 21602 Safety related transmitter failed due to water damage
- A-2Attachment222513
- RC-1-LI3 Does not appear to be working correctlyMiscellaneousMaintenance Rule data base for control complex chillerSystem Health Report decay heat removal system
Section 4OA2: Problem Identification and ResolutionNuclear Condition Reports218670
- AHF-1C can not be started in "Slow" from the MCB227445
- RWP-2A is binding
- 210706 Removal of ICS from track can cause a change in plant output