IR 05000341/2002003

IR 05000341/2002-003, Fermi 2, Inspection on 02/16-3/31/02 Related to Plant Operations. No Violations Noted

ML021080483
Person / Time
Site:	Fermi
Issue date:	04/18/2002
From:	Ring M NRC/RGN-III/DRP/RPB1
To:	O'Connor W Detroit Edison
References
IR-02-003
Download: ML021080483 (21)

Text

ril 18, 2002

SUBJECT:

FERMI 2 NUCLEAR POWER STATION NRC INSPECTION REPORT 50-341/02-03(DRP)

Dear Mr. OConnor:

On March 31, 2002, the NRC completed an inspection at your Fermi 2 Nuclear Power Station.

The enclosed report documents inspection findings which were discussed on March 28, 2002, 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 Commissions rules and regulations and with the conditions of your license.

The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel. Specifically, this inspection focused on plant operations.

No findings of significance were identified.

In accordance with 10 CFR 2.790 of the NRC's "Rules of Practice," a copy of this letter and its enclosure will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records (PARS) component of NRCs document system (ADAMS). ADAMS is accessible from the NRC Web site at http://www.nrc.gov/NRC/ADAMS/index.html (the Public Electronic Reading Room).

Sincerely,

/RA/

Mark A. Ring, Chief Branch 1 Division of Reactor Projects Docket No. 50-341 License No. NPF-43

Enclosure:

Inspection Report 50-341/02-03(DRP)

See Attached Distribution

DOCUMENT NAME: G:\ferm\ML021080483.wpd To receive a copy of this document, indicate in the box "C" = Copy without attachment/enclosure "E" = Copy with attachment/enclosure "N" = No copy OFFICE RIII RIII RIII RIII NAME PPelke/trn MRing DATE 04/12/02 04/18/02 OFFICIAL RECORD COPY

W. OConnor, Jr. -2-

REGION III==

Docket No: 50-341 License No: DPR-43 Report No: 50-341/02-03(DRP)

Licensee: Detroit Edison Company Facility: Enrico Fermi, Unit 2 Location: 6400 N. Dixie Hwy.

Newport, MI 48166 Dates: February 16 through March 31, 2002 Inspectors: S. Campbell, Senior Resident Inspector J. Larizza, Resident Inspector Approved by: Mark Ring, Chief Branch 1 Division of Reactor Projects

SUMMARY OF FINDINGS IR 05000341-02-03, on 2/16-3/31/2002, Detroit Edison Company, Fermi 2 Nuclear Power Station.

The inspection was conducted by the resident inspectors. No findings of significance were identified. The significance of most findings is indicated by their color (Green, White, Yellow, Red) using Inspection Manual Chapter 0609, Significance Determination Process (SDP).

Findings for which the SDP does not apply are indicated by No Color or by the severity level of the application violation. The NRCs program for overseeing the safe operation of commercial nuclear power reactors is described at its Reactor Oversight Process website at http://www.nrc.gov/NRR/OVERSIGHT/index.html.

Report Details Plant Status Fermi 2 operated at or near 100 percent power throughout the inspection period. On March 2, 2002, power was decreased to 65 percent to remove the south reactor feedwater pump from service for planned maintenance. Reactor power was returned to 100 percent on March 3, 2002. On March 9, 2002, power was decreased to 65 percent to perform a control rod swap and planned maintenance on a steam line drain valve.

Reactor power was returned to 100 percent on the same day. On March 30, 2002, power was reduced automatically to 55 percent due to the trip of the A reactor recirculation motor generator set caused by a generator field ground. Reactor power remained at 55 percent the remainder of the inspection period to perform corrective maintenance on the motor end slip ring of the A reactor recirculation motor generator set and to determine the root cause of the generator field ground.

1. REACTOR SAFETY Cornerstone: Mitigating Systems 1R04 Equipment Alignments (71111.04Q)

b. Inspection Scope The inspectors conducted a partial walkdown of emergency diesel generator 12 and its related diesel generator service water, diesel generator fuel oil transfer and starting air systems. The inspectors reviewed associated piping and instrumentation drawings, condition assessment resolution documents (CARDs), and the independent lineup verification of operating and surveillance procedures to complete the walkdown. The inspectors used the documents to verify that system components were aligned properly and that no outstanding deficient conditions existed to prevent proper operation of the emergency diesel.

c. Findings No findings of significance were identified.

1R05 Fire Protection (71111.05Q)

a. Inspection Scope The inspectors toured the following areas to determine whether combustible hazards were present, fire extinguishers were properly filled and tested, the CARDOX units were operable, hose stations were properly maintained, and if the fire hazard analysis drawings were correct:

• Updated Final Safety Analysis Report (UFSAR) Section 9A.4.1.3, Zone 2, Reactor Building Basement Corner Rooms

• UFSAR Section 9A.4.1.6, Zone 5, Reactor Building First Floor

• UFSAR Section 9A.4.1.7, Zone 6, Reactor Building Second Floor

• UFSAR Section 9A.4.2.15, Zone 14, Standby Gas Treatment and Control Center Air Conditioning System Rooms

• UFSAR Section 9A.4.3, Division 1 Residual Heat Removal Complex

• UFSAR Section 9A.4.2.11, Zone 10, Divisions 1 and 2 Battery Rooms b. Findings No findings of significance were identified.

1R06 Flood Protection (71111.06)

a. Inspection Scope The inspectors reviewed risk significant systems and components which are below internal or external flood levels or otherwise susceptible to flooding, to verify that the licensees flooding mitigation plans and equipment are consistent with the licensees design requirement.

b. Findings No findings of significance were identified.

1R12 Maintenance Rule Implementation (71111.12Q)

a. Inspection Scope The inspectors reviewed the system health reports, associated CARDs, white papers for probabilistic risk assessments on conditional probabilities, and the control room unit logs for the following systems to evaluate the characterization of failed structures, systems, and components in the maintenance rule program. The inspectors also evaluated performance goals and performance monitoring.

C Sumps and Drains (G1100)

C Extraction Steam (N3016)

b. Findings No findings of significance were identified 1R13 Maintenance Risk Assessments and Emergent Work Evaluation (71111.13)

a. Inspection Scope The inspectors reviewed the licensees lubrication analysis for the Fermi main unit transformer 2A and system service transformer 69, and the requirement to resample the transformer oil within 6 months. The inspectors also reviewed the justification for continued operation to determine if the conditions would place the plant in an unacceptable configuration and to verify that the licensee managed plant risks

adequately.

b. Findings No findings of significance were identified.

1R15 Operability Evaluations (71111.15)

.1 Reactor Core Isolation Cooling Room Temperature Switches out of Tolerance a. Inspection Scope The inspectors reviewed documents associated with surveillance performed on the high pressure coolant injection (HPCI) and reactor core isolation cooling (RCIC) system room area temperature monitoring equipment. The function of the room temperature monitors is to detect a leak from the associated HPCI and RCIC system steam piping. The isolation of HPCI and RCIC results when a small steam leak is detected. If allowed to continue without isolation, radiation dose limits could be reached and the associated system equipment could be damaged. The allowable values on the room temperature high signals are set low enough to detect a leak equivalent to 25 gallons per minute.

b. Findings On March 8, 2002, while performing surveillance 44.020.227, Nuclear Steam Supply System - HPCI and RCIC Room Area Temperature, Channel A Functional Test, E41N602A and E51N602A (Temperature switch electric: steam leak detection A signal to system isolation and temperature switch electric: steam leak detection RCIC equipment area, respectively) were found out of tolerance high at 185o F. Technical Specification Table 3.3.6.1-1, Functions 3.d and 4.d, require the HPCI Equipment Room Temperature - High and the RCIC Equipment Room Temperature - High, respectively, to be set at less or equal to 162o F.

During the December 2001 Channel A Functional Test, the setpoint of the temperature switch was inadvertently set too high. On January 9, 2002, the other channel, B, was calibrated with no discrepancies. During the calibration of the B channel and for the duration of a period of 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and 15 minutes, both channels A and B were inoperable. Technical Specification 3.5.2, Emergency Core Cooling System - Operating Action E states that when the HPCI system is inoperable an immediate verification of RCIC operability is required. In this case, for a period of 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and 15 minutes both HPCI and RCIC systems were inoperable, requiring the licensee to take actions within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to place the unit in Startup Mode within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />. This was not done because the licensee at that time did not recognize that channel A was out of specification and thus inoperable.

At the close of the inspection period, the licensee had not determined the root cause for the instrument temperature high out of tolerance setting. The inspectors considered this an unresolved item (URI 50-341/02-003-01) pending the root cause determination for this issue and the inspectors review of the associated corrective actions.

.2 Failed Stroke Time of RCIC Suppression Pool Isolation Valve E5150F031 a. Inspection Scope On March 6, 2002, the licensee conducted a post maintenance test on valve E5150-F031 and found a stroke time of 21.5 seconds which did not meet the acceptance criteria of 21.3 seconds. The inspectors reviewed applicable Technical Specifications, design calculations, and procedures to determine if the operability evaluation documented in CARD 02-10311 was properly justified and the component remained available, such that no unrecognized increase in risk occurred.

b. Findings No findings of significance were identified.

1R17 Permanent Plant Modifications (71111.17)

a. Inspection Scope Equivalent Replacement Evaluation 31882, Part Number Changes for RCIC System Governor Control Valve Stem and Spacers, was reviewed for adequacy of the evaluation, disposition, and conclusion. The modification was for equipment upgrade.

The vendor has made changes to the part numbers and material for the stem and spacers and suggested changing the inside diameter of the valve spring seat.

b. Findings No findings of significance were identified.

1R19 Post Maintenance Testing (71111.19)

a. Inspection Scope The inspectors reviewed the post maintenance testing surveillance procedures for the following systems:

• Standby Feedwater

• RCIC

• HPCI The procedures were performed to determine the operability of the systems following preventive maintenance activities. Operability determination was based on system response to simulated initiation signals, pump flows, system pressures, valve stroke times, valve position indications, and pre-established acceptance criteria. The

inspectors reviewed the packages to verify that the tests were adequate for the scope of the maintenance. The inspectors also determined that the tests restored the operational readiness consistent with the design and licensing documents.

b. Findings No findings of significance were identified.

1R22 Surveillance Testing (71111.22)

a. Inspection Scope The inspectors witnessed and reviewed test data for the following surveillance activities conducted to demonstrate that risk-significant structures, systems, and components were capable of performing their intended safety functions. The reviews included, but were not limited to, avoidance of preconditioning, clear acceptance criteria, properly calibrated test equipment, proper procedure performance, control of electrical jumpers, complete test data, Technical Specification and UFSAR compliance, and proper equipment restoration:

C Procedure 24.020.235, Nuclear Steam Supply System - RCIC Steam Line Pressure Division I Functional Test C Procedure 44.010.143, Division 2 Reactor Protection System - Two-out-of-Four Logic Modules Channel Functional Test C Procedure 24.202.07, HPCI Vacuum Breaker Test C Procedure 24.208.03, Division 2 Emergency Equipment Cooling Water Test b. Findings No findings of significance were identified.

1R23 Temporary Plant Modifications (71111.23)

a. Inspection Scope The inspectors reviewed Temporary Modification 02-0001, which evaluated the installation of monitoring instrumentation onto the HPCI system lubricating oil system and associated valves. Two pressure transducers will measure oil pressure in the HPCI turbine lube oil system and two position transducers will measure valve stem movement of the HPCI turbine stop and control valves. The purpose of the temporary modification is to minimize the setup time for installing the monitoring instrumentation. The inspectors also reviewed procedure MES 12, Performing Temporary Modifications.

b. Findings No findings of significance were identified.

Cornerstone: Emergency Preparedness

1EP1 Drill, Exercise, and Actual Events (71114.01)

a. Inspection Scope The inspectors observed the Blue team respond to an emergency drill on March 19, 2002, that included emergency personnel performance in the Technical Support Center, Emergency Operating Facility, and Control Room Simulator. Further, the inspectors attended the controller critique of the Control Room Simulator and Technical Support Center emergency personnel response to the drill.

b. Findings No findings of significance were identified.

4. OTHER ACTIVITIES (OA)

4OA2 Performance Indicator Verification (71151)

a. Inspection Scope The inspectors reviewed licensee event reports, licensee memoranda, unit logs, and NRC inspection reports to verify the residual heat removal safety system unavailability performance indicator for the fourth quarter of 2001.

b. Findings No findings of significance were identified.

4OA3 Event Followup (71153)

(Closed) Licensee Event Report 50-341/01002: Licensed Power Limit Exceeded Due to a Non-Conservative Steam Moisture Carryover Fraction. On September 28, 2001, the licensee determined that a non-conservative bias existed in the reactor heat balance methodology for calculating core thermal power. The main steam moisture carryover fraction used in the heat balance calculation was found to be higher than the actual value. This bias constituted a small portion of thermal power (less than 0.1 percent) but it was possible that Fermi 2, on occasion, might have exceeded its licensed thermal power limit. Based on the small magnitude of the calculation bias and conservatism of power used in safety analysis this condition had low safety significance As an interim measure, the maximum reactor power level was administratively reduced by three megawatts thermal and later the moisture carryover fraction was changed to zero to eliminate the potential non-conservative bias. The final value will be determined when a review of heat balance terms will be completed during the second quarter of 2002. The cause of this event was attributed to information provided by the vendor as input to the heat balance calculation. A contributing factor was the failure to analyze empirical data obtained on two previous occasions against the input parameters of the heat balance methodology.

The failure to meet the requirement of the thermal power limit in Fermi 2 License Section 2.C(1) is of very low safety significance and constitutes a violation of minor significance that is not subject to enforcement action in accordance with Section IV of the Enforcement Policy. The licensee entered this issue into their corrective action program as CARD 01-13286. Although the corrective actions will remain open until the second quarter of 2002, the inspectors determined that the proposed corrective actions were sufficient to close this item.

4OA5 Management Meetings Exit Meeting Summary The inspectors presented the inspection results to M and other members of licensee management at the conclusion of the inspection on March 28, 2002. The licensee acknowledged the findings presented. No proprietary information was identified.

KEY POINTS OF CONTACT Licensee D. Cobb, Plant Manager J. Davis, Manager, Nuclear Outage T. Dong, Manager, Performance Engineering T. Haberland, Manager, Work Control D. Hemmele, Shift Manager H. Higgins, Manager, Radiation Protection K. Hlavaty, Manager, Nuclear Maintenance S. Hassoun, Principal Engineer, Licensing R. Johnson, Supervisor, Nuclear Licensing A. Lim, Supervisor, Mechanical & Civil M. McDonough, Engineer, Fire Protection A. Mann, Manager, Operations W. OConnor, Vice President, Nuclear Generation N. Peterson, Manager, Nuclear Licensing S. Stasek, Director, Nuclear Assessment NRC M. Ring, Chief, Division of Reactor Projects, Branch 1

LIST OF ITEMS OPENED, CLOSED, AND DISCUSSED Opened 50-341/02-003-01 URI Setting on the High Pressure Coolant Injection and Reactor Core Isolation Cooling System Room Area Temperature Monitoring Equipment Found out of Tolerance High.

Closed 50-341/01002 LER Licensed Power Limit Exceeded Due to a Non-Conservative Steam Moisture Carryover Fraction.

Discussed None LIST OF ACRONYMS USED CARD Condition Assessment Resolution Document HPCI High Pressure Coolant Injection System RCIC Reactor Core Isolation Cooling System UFSAR Updated Final Safety Analysis Report

LIST OF DOCUMENTS REVIEWED The following documents were selected and reviewed by the inspectors to accomplish the objectives and scope of the inspection and to support any findings.

1R04 Equipment Alignment Procedure Emergency Diesel Generator 12 - Start and Load Revision 47 24.307.15 Test Procedure DGSW, DFOT and Starting Air Operability Test - Revision 42 24.307.35 EDG 12 1R05 Fire Protection UFSAR Reactor Building Basement Corner Rooms, Revision 11 Section 9A.4.1.3 Zone 2, El. 540 Ft and 562 Ft UFSAR Reactor Building First Floor, Revision 11 Section 9A.4.1.6 Zone 5, El. 583 Ft 6 In UFSAR Reactor Building Second Floor, Revision 10 Section 9A.4.1.7 Zone 6, El. 613 Ft 6 In UFSAR Section Residual Heat Removal Complex Revision 8 9A.4.3.1 UFSAR Section Control Room Ventilation Equipment Room and Revision 11 9A.4.2.15 Standby Gas Treatment Room, Zone 14, El. 677 Ft 6 In UFSAR Section Divisions 1 and 2 Battery Rooms Revision 10 9A.4.2.11 Drwg 6A721-2401 Fire Protection Evaluation Reactor Building Revision K Subbasement Plan El. 540' 0" Drwg 6A721-2403 Fire Protection Evaluation Reactor and Auxiliary Revision O Buildings First Floor Plan El. 583' 6" Drwg 6A721-2405 Fire Protection Evaluation Reactor and Auxiliary Revision Q Buildings Second Floor Plan El. 613' 6" Drwg 6A721-2409 Fire Protection Evaluation Reactor and Auxiliary Revision R Building Fifth Floor Plan (Elevations 677.5 FT and 684.5 FT)

Drwg 6A721-2041 Fire Protection Evaluation Residual Heat Revision E Removal Complex (Elevation 590.0 FT)

Drwg 6A721-2407 Fire Protection Evaluation Reactor and Auxiliary Revision Q Building Third Floor Plan (Elevations 641.5 FT and 643.5 FT)

1R06 Flood Protection UFSAR Section Internal Flood Protection Revision 7 3.4.4.4 UFSAR Section Floods Revision 10 9.2.5.3.1.4 UFSAR Section Flood Protection Revision 9 11.7.2.2.5 UFSAR Section Analysis of Effects and Consequences of Floods Revision 6 15.10.2.2.1 Regulatory Guide Flood Protection for Nuclear Power Plants September 1976, 1.102 Revision 1 AOP20.000.01 Flooding Revision 32 Maintenance Barrier Identification Classification Revision 30 Procedure 35.000.242 Technical Shore Barriers Protection Revision 31 Requirement Manual 3.7.4 1R12 Maintenance Rule Implementation CARD 02-11760 Functional Failure Reviews Were Not Conducted April 3, 2002 for Valve T4500F601 (NRC Identified)

CARD 98-17088 Failed Local Leak Rate Test (P4400F615) September 7, 1998 CPEP CPEP Data for G1100 and N3016 Systems Since January 1998 CARD 01-19553 Valve Failed to Close During Performance of December 7, 2001 27.702.01 Control Room Control Room Log Entries for Sumps and Drains Logs (G1100) and Extraction Steam (N3016), Since January 1998 Maintenance Rule Appendix G, Maintenance Rule SSC Specific Revision 9 Program Manual Functions

Maintenance Rule Appendix H, Maintenance Rule Performance Revision 9 Program Manual Criteria Log No.96-002 Development of Train and Divisional Level October 2, 1998, Conditional Probability, Allowed Number of Revision 1 Failures and Out-of Service Hours, and Redundancy Factor Determination Log No.96-001 Development of Conditional Probability for October 2, 1998, SSCs Modeled in the Fermi 2 PSA Revision 1 Regulatory Guide Monitoring the Effectiveness of Maintenance at March 1997, 1.160 Nuclear Power Plants Revision 2 Regulatory Guide An Approach for Plant-Specific, Risk Informed August 1998 1.177 Decision Making: Technical Specifications NUMARC 93-01 Nuclear Energy Institute Industry Guideline for April 1996 Monitoring the Effectiveness of Maintenance at Nuclear Power Plants 1R13 Maintenance Risk Assessment and Emergent Work Report Lubrication Analysis Fermi 2 PP Main Unit January 24, 2002 01L084-20395 Transformer No. 2A Report Lubrication Analysis Fermi 2 PP Main Unit February 22, 2002 02L084-00149 Transformer No. 2A and System Service Transformer No. 69 Report Lubrication Analysis Fermi 2 PP System Service January 24, 2002 01L084-20412 Transformer No. 69 CARD 02-11799 Transformer 2A and SS 69 Have Exceeded the February 25, 2002 NEIL Limits 1R15 Operability Evaluations CARD 02-13570 44.020.227 Tables 1 and 2 Found Greater than March 8, 2002 the Required Limit TS Table 3.3.6.1-1 Primary Containment Isolation Instrumentation Amendment 134 Function 3.d HPCI Equipment Room Temperature High TS Table 3.3.6.1-1 Primary Containment Isolation Instrumentation Amendment 134 Function 4.d RCIC Equipment Room Temperature High TS 3.5.1 ECCS -Operating Action E Amendment 134

CARD 02-10311 E5150F031 Stroke Time Out of Tolerance March 6, 2002 Operability Operability Justification for E5150F031 March 6, 2002 Evaluation Procedure RCIC System Pump and Valve Operability Test Revision 51 24.206.01 DC-2712 Design Specification of Motor Operated Valve December 29, 1986 Stroke GE Spec Reactor Core Isolation Cooling System April 13, 2002 22A1354AR WR E530020100 RCIC Torus Suction Inboard Isolation Valve March 5, 2002 1R17 Permanent Plant Modifications Equivalent Part Number Changes for RCIC Governor Revision 0 Replacement Control Valve Stem and Spacers Evaluation ERE 31882 1R19 Post Maintenance Testing Procedure HPCI Pump Time Response and Operability Test Revision 74 24.202.01 at 1025 PSI Procedure TCNs 10835 and 10836 24.202.01 Temporary Change Notice Procedure RCIC System Pump Operability and Valve Test Revision 51 24.206.01 at 1000 psig Procedure SBFW Pump and Valve Operability and Lineup Revision 30 24.107.03 Verification Test 1R22 Surveillance Testing Procedure NSSS - RCIC Steam Line Pressure Division I Revision 29 44.020.235 Functional Test.

TSSR 3.3.6.1.2 Perform Channel Functional Test Amendment 134 TSSR 3.3.6.1.3 Verify the Trip Unit Setpoint Amendment 134

TS Table 3.3.6.1-1 RCIC Steam Supply Line Pressure - Low Amendment 134 Function 4.b.

Procedure Div 2 RPS - Two-out-of-Four Logic Modules Revision 3 44.010.143 Channel Functional Test.

TSSR 3.3.1.1.12 Perform Channel Functional Test Amendment 134 TS Table 3.3.1.1- Two-out-of-Four Voter Amendment 139 1, Function 2.e.

Procedure HPCI Vacuum Breaker Test Revision 28 24.202.07 Procedure Division 2 EESW Pump & Valve Operability Test Revision 42 24.208.03 1R23 Temporary Plant Modifications Temp Mod Install Monitoring Instrumentation Onto HPCI Revision 0 02-0001 Lube Oil System and HPCI Valves E4100F067 and E5100F068 1EP1 Drill, Exercise, and Actual Events Scenario 32 Sequence of Events March 14, 2002 Drill Package CARD 02-13073 RERP Objectives not Met During the March 19, April 5, 2002 2002 Drill Scenario 32 Drill Exercise Critique Summary (Blue Team) April 5, 2002 NRC Performance Indicator (RERP) April 2, 2002 Documentation Form 4OA2 Performance Indicator Verification 4Q/2001 Performance Indicators - Fermi 2 Control Room Logs from October 1 through December 31, 2001 Nuclear Performance Engineering Group NRC January 15, 2002 Generation Memo Performance Indicator Fourth Quarter 2001 Data Submittal

Log 01-013 Performance Evaluation Program Evaluation January 10, 2002 Sheet NRC Performance Indicator Data Submittal for 2001 Q4 NEI 99-02 Regulatory Assessment Performance Indicator Revision 2 Guideline 17