IR 05000254/2004011
| ML043340388 | |
| Person / Time | |
|---|---|
| Site: | Quad Cities  |
| Issue date: | 11/26/2004 |
| From: | Ring M NRC/RGN-III/DRP/RPB1 |
| To: | Crane C Exelon Generation Co, Exelon Nuclear |
| References | |
| IR-04-011 | |
| Download: ML043340388 (27) | |
Text
November 26, 2004
SUBJECT:
QUAD CITIES NUCLEAR POWER STATION, UNITS 1 AND 2 PROBLEM IDENTIFICATION AND RESOLUTION REPORT 05000254/2004011; 05000265/2004011
Dear Mr. Crane:
On October 29, 2004, the U.S. Nuclear Regulatory Commission (NRC) completed a team inspection at the Quad Cities Nuclear Power Station. The enclosed report documents the inspection results which were discussed on October 29, 2004, with you and members of your staff.
This inspection was an examination of activities conducted under your license as they relate to the identification and resolution of problems, compliance with the Commissions rules and regulations and with the conditions of your operating license. Within these areas, the inspection involved selected examination of procedures and representative records, observations of activities, and interviews with personnel. No findings were identified.
On the basis of the sample selected for review, the team concluded that in general, problems were being properly identified, evaluated, and corrected. While no findings were identified during the inspection, the team had several observations regarding the effectiveness of corrective action program implementation as detailed in the enclosed report.
In accordance with 10 CFR 2.390 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 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/
Mark A. Ring, Chief Branch 1 Division of Reactor Projects Docket Nos. 50-254; 50-265 License Nos. DPR-29; DPR-30
Enclosure:
Inspection Report 05000254/2004011; 05000265/2004011 w/Attachment: Supplemental Information
REGION III==
Docket Nos:
50-254; 50-265 License Nos:
05000254/2004011; 05000265/2004011 Licensee:
Exelon Nuclear Facility:
Quad Cities Nuclear Power Station, Units 1 and 2 Location:
22710 206th Avenue North Cordova, IL 61242 Dates:
October 18 through 29, 2004 Inspectors:
G. Wright, Team Lead K. Stoedter, Senior Resident Inspector, Quad Cities C. Brown, Resident Inspector, Clinton R. Ganser, IEMA, Quad Cities Approved by:
M. Ring, Chief Branch 1 Division of Reactor Projects
Enclosure
SUMMARY OF FINDINGS
IR 05000254/2004011, 05000265/2004011; 10/18/2004 - 10/29/2004; Quad Cities Nuclear
Power Station, Units 1 & 2; Problem Identification and Resolution Inspection The inspection was conducted by one region-based inspector, two resident inspectors and an inspector from the Illinois Emergency Management Agency. No findings of significance were identified.
Identification and Resolution of Problems In general, the licensee identified issues and entered them into the corrective action process at an appropriate level. Nuclear Oversight (NOS) assessment reports identified issues for the licensee to resolve, including issues with corrective action follow through and effectiveness.
The majority of issues reviewed were properly categorized and evaluated. In general, corrective actions reviewed were appropriately implemented and appeared to have been effective. While no findings were identified during the inspection, the team developed a number of observations.
The team observed that many condition reports or issue reports were narrowly focused.
Documentation was often weak, resulting in lack of ties between problem statements and corrective actions. The weak documentation also contributed to a lack of clarity on how the licensee arrived at corrective actions. Condition reports and assessments addressing maintenance rework or inadequate/ineffective corrective actions, did not routinely evaluate why the responsible organization had put ineffective actions in place. The team also observed that the threshold for identifying deficiencies on non-safety related systems may not be consistent with the systems contribution to the sites overall risk profile.
REPORT DETAILS
OTHER ACTIVITIES (OA)
4OA2 Problem Identification and Resolution
.1 Effectiveness of Problem Identification
a. Inspection Scope
The team reviewed selected documents generated over the past 2 years including:
NRC inspection report findings, selected plant corrective action documents, and trend assessments to determine if problems were being identified at the proper threshold and entered into the corrective action process. The team also conducted a focused plant walkdown of the turbine building closed cooling water (TBCCW) system to ensure that equipment problems were entered into the corrective action system. The TBCCW system was selected due to its high risk significance. The walkdown represented one semiannual sample. The corrective action documents used during the reviews are listed in Attachment 1 and were selected from the following areas:
1)
Human performance 2)
Inadequate corrective actions 3)
Rework 4)
Operator workarounds 5)
Operability evaluations 6)
Configuration control 7)
Operating experience 8)
Root cause assessments 9)
Common cause assessments
.
10)
Apparent cause assessments 11)
Issues generated during the last three refueling outages for each unit.
b.
Observations In general, the licensee identified issues and entered them into the corrective action program (CAP) at an appropriate level. The licensee appropriately used the CAP to document instances where previous corrective actions were ineffective or inappropriate.
The team conducted a detailed walkdown of selected portions of the TBCCW system to assess the licensee identification and documentation of degraded conditions within the corrective action program.
b.1 Turbine Building Closed Cooling Water (TBCCW) System Walk Down The team verified that major equipment issues identified in the system walk down, such as malfunctioning valves and pump leakage, were addressed within the licensees corrective action program. However, the team identified a relatively high number of system material deficiencies that were not identified by the licensee. These included numerous improperly secured piping supports, corrosion on system components and valves, and improper labels on air compressors. This indicated that the threshold for identifying deficient conditions was not as low as that given to a safety-related system with equal or lower risk significance. Subsequent to the walk down, the system engineer submitted issue reports (IRs) to address the teams concerns. The licensee initiated extent of condition walk downs to identify similar conditions and initiate the necessary corrective action.
b.2 Identification Threshold From December 2002 until July 2004, the licensees CAP allowed conditions adverse to quality to be documented in condition reports or maintenance work requests. In July 2004, the licensee implemented a new CAP which instituted the use of issue reports to document items adverse to quality or in need of repair. With the change, all activities are entered into the system as IRs. The IRs are reviewed daily by a team consisting of managers from the major departments. The licensees review team, with input from the various organizations, determines which course the item will take (e.g., event report, work request). The number of condition reports in the previous CAP appeared to be appropriate for a dual unit site. The number of issues being generated in the new CAP has not stabilized; about 950 items were generated in September. The teams review of CRs generated under the previous program and a small sample of items from the current system, indicated that an adequate threshold had been established for documenting issues and an appropriate prioritization system had been used.
While the licensee appeared to appropriately identify most issues, the TBCCW walkdown identified a number of deficiencies. The individual deficiencies did not directly affect the operation of the system; however, they did indicate that the licensees threshold for identifying and documenting deficiencies on the system may not be consistent with the systems risk importance. For example, the inspector identified a number of deficiencies with pipe supports, (e.g., lock nuts missing and loose fasteners).
In following up on the teams findings, a system engineer identified that responsibility for pipe supports had changed from a designated individual for all systems to each system engineer. The change was brought about by the elimination of the pipe support specialist position at the site.
b.3 Operating Experience The team reviewed a sampling of industry operating experience (OPEX) reports and concluded that the licensee was appropriately including OPEX items in the corrective action program. The team identified one example where the licensees corporate OPEX coordinator had not sent General Electric Service Information Letter (SIL) 448, Revision 2, to the site for review. The team reviewed the SIL revision and concluded that the information in the SIL had no impact on the current operation of equipment at Quad Cities. The licensee initiated IR 266809 to document the oversight by the corporate OPEX coordinator.
b.4 Identification of Issues Associated with Inadequate/Ineffective Corrective Actions or Maintenance Rework The team reviewed a sample of IRs and CRs written for inadequate or ineffective corrective actions. In general, the licensee adequately addressed the technical issue, (i.e., the issue which had not been corrected by the original corrective action). However, in almost none of the cases did the licensee address why it had not corrected the problem the first time.
-
CR 216467 Ineffective ACE & ACIT Closure Problems: The CR appropriately addressed the specific issues addressed by the ACE (Apparent Cause Evaluation). The CR did not address why the organization developed an ineffective ACE. Additional discussions with the licensee identified they had assessed the cause of the problem and taken actions; however, none of that information had been included in the CR evaluation.
.2 Prioritization and Evaluation of Issues
a. Inspection Scope
The team conducted an independent assessment of the prioritization and evaluation of selected CRs generated after the 2002 problem identification and resolution inspection.
The assessment included a review of the category assigned, the operability and reportability determinations, the extent of condition evaluations, the cause investigations, and the appropriateness of assigned corrective actions. Other attributes reviewed by the team included the quality of the licensees condition trending and the corresponding corrective actions. In addition, one member of the team attended a management meeting to observe the licensees assessment of IRs. This review included the controlling procedures and selected records of activities. In addition, the team conducted interviews with cognizant licensee personnel.
The team reviewed previous NRC inspection reports and associated corrective action documents to verify that identified issues were appropriately characterized and entered into the CAP.
The team likewise reviewed the licensees efforts to capture industry operating experience (OPEX) issues in the CAP. Documents reviewed included the licensees assessment of industry operating event reports, NRC, and vendor generic notices.
b.
Observations The team verified that, in general, issues reviewed through the CR/IR process were properly categorized and evaluated. However, the team had several observations regarding the quality of the evaluations as follows:
b.1 Overview of Prioritization and Evaluation Process The team identified several items where narrowly focused assessments missed opportunities to identify broader causes and to determine complete corrective actions for specified causes. For example:
-
CR 138696; Low Pressure Coolant Injection Inoperable due to Failure to Reset Isolation Logic Following Surveillance Testing, dated January 9, 2003. This condition report was written when operations personnel discovered a residual heat removal valve which did not operate as expected during testing. The licensee determined that the valve did not operate as expected due to the presence of a Group II containment isolation signal which had not been reset during surveillance testing conducted on December 18, 2002. The failure to reset the containment isolation logic was caused by an inadequate procedural development and review process which did not ensure that a step to reset the logic was placed in the procedure before the procedure was issued for use. The corrective actions to prevent recurrence included reviewing the other logic tests to identify any similar discrepancies, revising any deficient procedures, and revising the applicable surveillance procedures to include visual verification that the logic had been reset. However, the corrective actions to prevent recurrence did not address the deficient procedural development and review process.
-
CR 154716; Valve 2-1001-43A will not Open from the Control Room, dated April 24, 2003, and CR 169407; Troubleshooting of Valve 2-1001-43A Should Have Been Better Documented, dated July 29, 2003. Condition Report 154716 was initiated when shutdown cooling suction valve 2-1001-43A could not be opened from the control room. The team reviewed this condition report and identified several examples where the licensee had failed to follow procedure (see the Non-Cited Violation documented in Inspection Report 50-254/2003009; 50-265/203009). These failures resulted in several human performance issues including failing to initiate a work request when required, performance of troubleshooting activities before developing a formal troubleshooting plan, use of repetitive cycling to resolve equipment deficiencies, and using equipment cycling results as a basis for continued operability. In addition, the team identified that even though CR 154716 had received numerous supervisory reviews, no one had recognized that the root cause of the valves failure to stroke had not been addressed. The team reviewed the licensees corrective actions for this issue and found that the actions were very narrowly focused. Specifically, the licensee addressed the deficiencies in the work request and troubleshooting plan initiation by conducting additional training. However, none of the other deficiencies documented in the inspection report were addressed.
-
CR 130676, 1B Fuel Pool Pump Failure to Start. The CR documented a problem where a fuel pool pump failed to start. An associated work request (WR) identified that the pump had not been properly wired. The WR & CR resulted in the wiring being corrected; however, it did not address why the pump wasnt tested after the activities which had resulted in the errant wiring.
IR 266075 was written to follow up on this issue.
-
CR 166557, HPCI MO 2-2301-03 valve possible leak by. The CR identified that a high pressure coolant injection (HPCI ) steam valve was leaking into the HPCI room sump. The evaluation of possible leakpaths through the valve documented on the CR was very good. The CR stated that the sump high level alarms were coming in once to twice per day; however, no further evaluation was performed. In response to the teams questions, the licensee determined that the normal frequency of the alarm was once every 3 to 4 days, this indicated that the operators missed an opportunity to identify the leakage 2 to 3 days earlier.
The operators did verify that the alarm cleared within an appropriate amount of time, but did not send anyone to investigate the situation. The HPCI steam valve has had a history of leakage which may have desensitized the operators to the alarm.
-
IR 143666, White residue found at 480V MCCs aux contacts. The IR documented potential dried grease on CR105X auxiliary contacts. The extent of condition investigation found similar white powdery residue on 22 additional auxiliary contact assemblies. Appropriate actions were taken to correct the identified conditions and a preventive maintenance activity to grease the auxiliary contact assemblies was established. However, the team noted that the periodicity of the preventive maintenance activity was 6 years when one of the auxiliary contact assemblies (CR-143005, ECCS Keep Fill Pump motor unexpectedly shut off) had failed after only 4 years of operation. When the team questioned the appropriateness of the 6 year periodicity, the licensee stated that the period was in accordance with industry guidance for critical breakers and that the dried powder was a precursor to dried grease and did not indicate that binding was imminent. The licensee also noted that the corrective actions were being monitored under the licensees SHIP [system health indicator program]
actions. The licensee did not directly address the failure of the one breaker in evaluating its surveillance periodicity.
-
CR 132397, Failed Time Delay Relay. On April 5, 2001, the under voltage permissive time delay relay for the emergency diesel generator loading onto 4kV Bus 24-1 failed routine bench calibration check following removal from its installed location. The calibration check was performed to confirm proper relay timing and operation before operations surveillance QCOS 6500-10. The team reviewed the operability evaluation for CR 132397 and the root cause report, CR Q2001-01049, for the cause of the relay failure. The team found the root cause investigation to be very comprehensive. The documentation detailed an excellent case for an improper solder joint which allowed slight wire movement causing electrical discontinuity as the failure mechanism. However, the operability evaluation for CR 132397 was not as thorough.
The operability evaluation appeared to default to the possibility that removing the relay for bench testing caused the relay coil wire to be moved, resulting in the relays failure. While the team concluded that the licensees assessment was plausible, the team was unable to identify where the licensee had considered and investigated other possibilities (e.g., work in the cabinet during routine system maintenance activities, that could have caused the relay to fail). The lack of a thorough assessment of alternative causes for the relays failure, reduced the teams confidence that the relay had been operable prior to its removal from the circuit. Despite the lack of a convincing case that the relay had not failed while in-service, the team could not positively conclude that the operability evaluation was incorrect -- only that it was based on weak logic and a possible scenario for the time of failure. The team noted that the relay was replaced immediately after it was discovered to be failed and the operability surveillance test successfully completed.
The team also identified an oversight in the licensees evaluation process for addressing items identified by the NRC as Non-Cited Violations. The NRCs Enforcement Manual indicates that a Severity Level IV violation can be dispositioned as a Non-Cited Violation as long as the licensee has placed the violation into their corrective action program to address recurrence. The Enforcement Manual also states for Non-Cited Violations: At the time a violation is closed in an inspection report, the licensee may not have...begun the process to identify the root cause and develop action to prevent recurrence. The team identified that the licensees corrective actions for Non-Cited Violations were generally appropriate. However, the licensees CAP procedure does not include steps to ensure that the root cause of each Non-Cited Violation was identified and that corrective actions to prevent recurrence were implemented. The licensee initiated IR 268389 to address this oversight.
b.2 Trending Program The team reviewed how the licensees trending activities, noted below, interfaced with the CAP Component Maintenance Optimization Corrective Maintenance Unexpected Maintenance Rule Equipment Reliability System Health Indicator Program Component Health Indicator Program Instrument Trending The team also observed use of the engineering work station program used by system engineering to monitor system performance. The Engineering Work Station program gathered information from a number of sources including the plant computer and non-licensed operator rounds for evaluation by the system engineer. The system also allowed the engineer to input values or formulas with provisions for notifying the engineer when the specified conditions have been met or exceeded. This feature allowed for almost real-time monitoring of system parameters. The program also allowed the engineers at all Exelon sites to share information with their counterparts.
The team noted good coordination between the various trending programs and the CAP.
However, the team also noted that the trending program relies on individuals to identify the trends, with the computers only holding and sorting the information. With the exception of the Engineering Work Station program, noted above, the licensee did not use computers to flag potential trends or problems.
The team performed an in-depth examination of the licensees instrument set-point and calibration trending program as a follow-on to an observation made in the previous problem identification and resolution inspection. The team found that the licensee had corrected the difficulty in trending instrument performance, specifically, the current data base was comprehensive and was reviewed quarterly for any developing trends. The team noted one possible weakness in that the initial CR, where a trend was noted, was closed separately from an additional CR initiated to identify the trend. The team noted that a more clearly defined documentation trail would have the trend tracked as a corrective action to the initial CR. On October 29, 2004, the licensee initiated IR 268311, Possible Enhancement to IR Processing, to assess the trend identification process
.3 Effectiveness of Corrective Action
a. Inspection Scope
The team reviewed past inspection results, selected CRs, root cause reports, and common cause evaluations to verify that corrective actions, commensurate with the safety significance of the issues, were specified and implemented in a timely manner.
The team evaluated the effectiveness of corrective actions. The team also reviewed the licensees corrective actions for Non-Cited Violations (NCVs) documented in NRC inspections in the past 2 years.
b.
Observations In general, the licensees corrective actions for the sample reviewed were appropriate and appeared to have been effective. The team noted that the licensee appropriately used the CAP to document instances where previous corrective actions were ineffective or inappropriate.
.4 Documentation
a. Inspection Scope
The team independently assessed the thoroughness of the licensees documentation to determine whether the documents could stand on their own or required additional inputs.
If additional information was necessary, the team also assessed the availability of the information.
b.
Observations In general, the team found the licensees documentation practices associated with the corrective action program to be weak.
b.1 In several instances, the team was only able to successfully understand the licensees actions because key individuals recalled details of what had occurred and, more important, why it occurred. The team noted that this documentation weakness left the licensee vulnerable to the loss of key information. For example:
-
OPEX Item 171244 was initiated to perform a review of NRC Information Notice 2002-29, Design Problems in Safety Functions of Pneumatic Systems. The licensees review stated that no actions were needed as the information in the notice was similar to that included in Generic Letter 88-14, Instrument Air Supply Problems Affecting Safety-Related Equipment. While this was true, it was not apparent that the licensee considered physical or operational changes in the pneumatic systems between 1988 and 2002 which could have resulted in the information included in Information Notice 2002-29 having increased applicability at the station. The team discussed this OPEX item with the responsible engineering personnel and found that a full review of pneumatic system performance had been performed. However, this review was not documented.
-
CR 144464, "Concerns with CAPR closure and EFR for ECCS venting." While containing valuable information, the CR did not identify clearly what the inadequacies were, what the procedural changes were, or how the corrective actions addressed the inadequacies. Initial discussions with the licensee identified they were unable to address the deficiencies. The teams questions were appropriately addressed only after a discussion with the individual who wrote the document.
-
A number of CRs (e.g., 161395, 171039, 175517, 183316) identified inadequate assessments or evaluations and indicated that the evaluation had been returned to the originator along with comments. The CRs neither itemized the specific problems with the documents nor addressed the cause for the deficiencies.
Without detailed information in the CR, it is difficult to identify whether CAs were being effective or if repeat failures were continuing to occur.
b.2 The team also identified a number of CRs involving human performance where from the documentation, it did not appear that the individual had been interviewed regarding the error. The failure to interview individuals associated with issues limits an assessments ability to identify broader corrective actions.
-
CR 158648 1/2-5599-Y valve operator air supply hooked up in reverse. The CR documented what had occurred and evaluated the extent of condition. The CR did not identify whether the mechanics who connected the air lines backwards had been interviewed. Further, the CR did not address potential knowledge deficiencies which may have led to the problem. In answering the teams questions, the licensee indicated that potential knowledge deficiencies were addressed in a subsequent CR written on a similar performance error.
.5 Safety-Conscious Work Environment (SCWE) Assessment
a. Inspection Scope
The team conducted interviews with plant staff to assess whether there were impediments to the establishment of a SCWE. During the interviews, the team used Appendix 1 to Inspection Procedure 71152, Suggested Questions for Use in Discussions with Licensee Individuals Concerning PI&R Issues, as a guide to gather information and develop insights. The team also discussed the implementation of the Employee Concerns Program (ECP) with the plants ECP Coordinator.
b.
Observations Plant staff interviewed did not express any concerns regarding the safety conscious work environment. The staff was aware of and generally familiar with the corrective action program. During the interviews, the team found that the plant staff was generally unfamiliar with the process to use for initiating an anonymous issue report. However, the plant staff felt that the option of anonymous issue reports was not needed since they were comfortable documenting potential safety issues. The licensee staffs unfamiliarity with anonymous issue reports was provided to licensee management for information.
The licensee initiated IR 267841 on this issue and provided a site-wide communication to ensure that everyone was knowledgeable on the methods available to generate anonymous issue reports.
None of the individuals interviewed expressed any reluctance to identify plant safety issues. However, only a few of the people interviewed readily identified the use of the Employee Concerns Program as an alternative method for raising a concern. While most individuals favored the ease of use of the new system, some individuals indicated they were not adept at using the computer system to initiate an item into the corrective action program. In all cases, these workers stated that they would ask for assistance in initiating an IR. None of the workers interviewed appeared reluctant to identify safety issues or bring them to the attention of the NRC if they felt it was necessary. They did say they would go through their supervisor first and use the alternate methods if they needed to do so.
4OA6 Management Meetings
.1
Exit Meeting Summary
The team presented the inspection results to Mr. R. Gideon and other members of licensee management in an exit meeting on October 29, 2004. The licensee acknowledged the observations presented and indicated that no proprietary information was provided to the team.
ATTACHMENT:
SUPPLEMENTAL INFORMATION
Individuals Contacted
Licensee:
J. Bartlet
Operations Training Manager
W. Beck
Regulatory Assurance Manager
T. Bell
On Line Work Center Manager
D. Craddick
Electrical Maintenance Superintendent
T. Fuhs
Regulatory Assurance
R. Gideon
Plant Manager
D. Hieggelke
Nuclear Oversight Manager
D. Kallenbach
Radiation Protection Superintendent
J. ONeil
Corrective Action Program Manager
M. Perito
QC/Operations Manager
C. VanDenburgh
Engineering
NRC:
M. Kurth
NRC Quad Cities Resident Inspector
Acronyms Used in the Report
Apparent Cause Evaluation
Action Item
Corrective Action to Prevent Recurrence
CFR
Code of Federal Regulations
CR
Condition Report
Division of Reactor Projects
Employee Concerns Program
EFR
Effectiveness Review
High Pressure Coolant Injection
Illinois Emergency Management Agency
IR
Issue Report
Non-cited violation
Operating Experience
Safety Conscious Work Environment
Service Information Letter
TBCCW
Turbine Building Closed Cooling Water
Documents Reviewed
Human Performance Related Condition Reports
Ar Number
Ar Subject
Origination Date
00134002 MRule: ECCS Room Coolers
20021204
00134318 Improper respirator installed in SCBA used for fire drill
20021206
00135466 Vibration of Steam lines may risk test tap line to break
20021212
00136195 IMPROPER USE OF BOUNDING FOR 1A RHR HX
OPEVAL ISSUE
20021217
00137008 Late CR initiation to evaluate U1 HPCI venting results
20021220
00137396 Sheet Metal Screw Installation Causes Electrical Arc
20021227
00140164 Valve Found Already Closed And Tagged During C/O
First Hang
20030119
00141008 Compensatory action for Op Eval 105454-08 not
implemented
20030124
00144309 Due date of PMID 33784-01 beyond interval for late
due date
20030212
00145840 Air Supply to Regulator for AOV 2-3507-A Isolated
20030223
00147691 Failed PMT for New Valve
20030306
00150278 Inadvertent RCIC Trip Throttle Valve trip & unplanned LCO 20030322
00151852 Unit One Emergency Diesel Generator Trip Checks
20030401
00152430 Operability Determination Actions Inappropriately Closed
20030404
00156029 2Bcrd motor oil drain plug found loose on running pump
20030428
00158648 1/2-5599-Y valve operator air supply hooked up in reverse. 20030513
00164026 "B" Core Spray Loop Air venting investigation results
20030619
00164221 3-VALVE MANIFOLD MISPOSITION
20030620
00164355 Wrong valve opened when recircing 2B Cond Phase
Separator
20030622
00181083 Improper Verification Practices
20031015
00182811 Apparent incorrect pressure indicator calibrated.
20031024
201012 Orifice plates for RO and FE installed reversed (EC24429) 20040211
202221 Venture electricians working on equipment not out
of service
20040217
205444 NOS ID'd equipment staged in electrical cabinet
20040302
205639 Potential containment breach
20040302
205695 Contractor Tools Stored in Electrical Panel (Q2R17 OLL)
20040303
205740 EC# 24553 Components Not Installed Per Approved
Design
20040303
206505 Water pressure encountered when unbolting north
H2 cooler
20040305
209409 RV 2-3607 Leaks 60 dpm After System Placed In Service
20040319
211163 Inoperable CRD Accumulator During Scram Timing
20040326
211425 HCU 22-15 113 valve found out of position
20040329
211881 Rework - CS Rm Cooler Temp Switch cal'd to
incorrect data
20040330
211966 Hand Tools Found Stuffed in Cable Tray
20040331
221700 Red Window in Engineering Technical Rigor Fundamental 20040517
223488 Appendix R Not Addressed in OpEval 220863
20040525
225847 FME In Electrical Cabinets
20040604
256816 North Main Control Room Door #329 Difficulties Closing
20040925
Root and Common Cause Analyses
00138696 2-1001-29A immediately reclosed when opened
during testing
20030109
00138737 Flammables not being properly stored
20030109
00139325 Leak in line 1-1043B-14"-L Approx 1 Gal per Minute
20030114
00140818 NOS identified apparent trends in RCR themes
20030123
00151852 Unit One Emergency Diesel Generator Trip Checks
20030401
00152094 Challenges to Radwaste shipping activities
20030403
00158786 Two Corrective Actions Not Entered for CR 152884
20030514
00159607 Pressure boundry leakage from 2" Rx head vent line
20030520
00159864 Inability to cool upper elevations for Rx disassembly
20030521
00162091 FP DRILL PERFORMANCE DEFICIENCIES
20030605
00162743 Dresden CAPCo Identifies Adverse Trend in EPU
Modifications
20030611
00164026 "B" Core Spray Loop Air venting investigation results
20030619
00170142 MSL hi flow instrument drift - reportable
20030804
00170378 Trend of CR's dealing with reactor pressure >1005 psig
20030805
00172349 Review of July CAP data identifies a potential trend
20030820
00179578 Review of Chemistry CAP data identifies a potential trend
20031006
00181022 Security Safety FASA Recommendations
20031015
00181083 Improper Verification Practices
20031015
00197277 CCA needed for External Identified CRs
20040123
00198137 INOP D/W Rad Monitor due to BAD SOLDER JOINT ON
RIS 2-2419-A
20040129
202476 Human performance errors
20040218
208111 Q2R17 OLL U-2 Refuel Bridge experienced "Hoist Tube
Hangup"
20040312
209752 Site CR Trending CC Document Quality as Issue
20040321
211724 Unexpected U2 reactor scram during turbine weekly testing 20040330
216684 Untimely Initiation of Condition Reports by Engineering
20040423
216941 Common Cause for SRM/IRM outage problems
20040426
222787 Initiate Planned CCA for Unplanned Modification Revisions 20040521
235678 OOT, DPIS 1-0261-2M, TREND CODE B2
20040713
240264 Ineffective CAPR For Main Steam Line Flow Switch
Root Cause
20040730
240494 OOT, 1-263-111A, 1-263-111C, TREND CODE B2
20040730
243058 Operations Human Error Prevention Fundamental Id'd
As Yellow
20040810
255735 E-3 Walk Down Identified Additional Parts Required.
20040922
Operating Experience Condition Reports
00136898 GE SIL 646 Target Rock SRV failed to fully open
20021220
00141461 GE SC 03-01, Additional material concerns for TIP valve
qualification
20030128
00145346 Complete SOER 2002-03 Recommendations
20030220
00148037 NER DR-03-001, Rev1, High Flow Control Line After
Load Drop
20030307
00151777 GE SIL 448R1 GE AK/AKR breaker lube OPEX
20030401
00156575 NER KS-03-006, Corrective actions for 2002 plant events
20030430
00164755 NRC GL 2003-01, Control Room Habitability, OPEX
20030625
00168622 NER QC-03-047, Inadvertent Opening of PORV and
20030722
00171244 NRC IN2002-29 Des Problems in Sfty Functions of
Pneu Sys
20030812
00171258 NRC IN2002-34 Fail Of Sfty-Related Circ Break Aux Switch 20030812
00174867 NER KS-03-016 Red, Scram Due To Inadequate SSPV
Disposition
20030909
00175971 SME Review Of NER DR 03-096, MOV Stroke Time Issues 20030916
00179572 NRC, IN 2003-18, GE SBM Control Switches W/Defective
Cam
20031006
200024 NER DR-04-006 Red U3 Reactor Scram-Turbine Oil
Cooler Trsfr
20040206
200989 SER 6-03 Cooling Water System Debris Intrusion
20040211
202720 Sme Review Of Ner Dr-04-009, Water In Hpci Steam
Line /Scram
20040219
219125 Sme Review Of Oe-18201, Hydrogen Found In Srv
Downcomers
20040506
227149 INPO SEN 249 Worker Injured Removing Water Box Cover 20040609
254371 NER LI-04-067 Red Unit 1 Thermal Power Exceeded By
.2-.4 percent
20040918
NRC Item Related Condition Reports
205862 Wrong oil in the 2A Core Spray motor upper and lower
resrvr.
20040303
222870 SSDR not updated with max. torus temp. with HPCI
running
20040521
00182811 Apparent incorrect pressure indicator calibrated.
20031024
205892 Wrong oil in the 2B Core Spray motor upper and lower rsrvr.20040303
223815 (SSDI) Potential to Drain the Torus on Failure of RCIC Line 20040526
00167725 Missed Opportunity - Corrective Action Program
20030715
00171034 Past Operability not Addressed for 1B RHRSW Pump Leak 20030811
00181040 Cable Tabulation Dwgs contain Incorrect Service
Description
20031015
00182702 Deficiency Identified in Calculation QDC-0000-E-0853, R/0 20031024
00185418 Flood Protection Alarm PM Review is Needed
20031107
00189928 Additional Corrective Action Prudent for CR 110756
(RHRSW Screens)
20031210
00190069 1A RHR HX Repair Not Included in the Sec. XI R/R Prog.
20031210
00190175 RHRSW Pump Cubicle Cooler tube plugging limit in UFSAR 20031211
200169 CCST Heaters--use of increased monitoring as
compensatory ac
20040206
205146 Load rating for Hoist found greater than support structure.
20040301
220295 QCOA 1300-02 Has Error for Maintaining
RCIC </= 400gpm
20040511
220460 SSDI Walkdown Identified Incorrect TOL Setting
20040512
220546 Operations Procedures lists old ITS limits for Rx Lo-Lo Lvl
20040512
220748 Cal QDC-1300-E-021 apparent omission
20040513
221078 RCIC Operation w/ App R torus pressure not well
documented
20040514
222543 SSMP Motor Start Limitations
20040520
222713 SSDI Issue RCIC Operation During an Appendix R Fire
20040521
223638 SSDI RCIC/CS Rm Temp Switch Locations Do Not
Match UFSAR
20040525
224355 Wrong Vendor letter used for engineering reference
20040528
243264 Non-conservative technical specifications requirement
20040810
247298 Error Discovered In SRV Discharge Flange Calculation
20040825
254931 Qcos 5750-04 Test Acceptance Criteria
20040920
254936 Maintenance Procedures Lack Some Acceptance Criteria
20040920
00194680 Identifying Non-Conservative Technical Specifications
20040112
Configuration Control Condition Reports
00134855 Feed Water Pump Low Suction Pressure
20021210
00135995 Bkr For Mcc 27-1 Cub F1 Found To Be Wrong Size For
Application
20021216
00144400 Fit-Up Anomalies Id'd For 1a Rhr Ht Exchanger Floating
Head
20030213
00145867 Valve 1-4799-824 Not Installed Per Drawing
20030224
00151852 Unit One Emergency Diesel Generator Trip Checks
20030401
00155349 Received RFP Suction Low Pressure Alarms
20030423
00155624 Several Hundred Calculation Revisions "Inprog" In
Passport
20030424
00157697 Qcop 6000-4 Not Revised Post Epu
20030507
00158439 Insufficient Oil Placed Into 2a Serv Wtr Motor Upper Bearing 20030512
00160467 3c ERV Pilot Valve Independently Cycles When Operated
20030525
00161015 QCOP 5600-04 Not Revised For Unit 1 Epu
Conditions
20030529
00162743 Dresden CAPCO Identifies Adverse Trend In EPU
Modifications
20030611
00163226 Station Vent System Controlled Drawings Need Major
Revision
20030613
00166134 FASA Supplement - Permanent Plant Modification
20030703
00167422 Offgas Glycol System Discrepancies
20030714
00175380 Piping Clamps Missing From Various Crd System Pipes.
20030911
00176455 Overload Heater Size Drawing Issues
20030919
00180661 Loss Of HPCI Room Cooler Fan On Appendix K And Eq
20031013
00182969 HRSS Line Broken Loose From Pipe Hangers.
20031026
00184538 Fw Discharge Pipe Hanger Fastener Falls To Floor In
Rfp Room
20031103
00187652 Classification Change From Non-Safety To Safety-Related
20031121
00188277 Ec 337692 Specified Torque Valves Exceeded Yield Of
U-Bolt
20031126
00188306 Inadequate Input Verification For Calculation Qc-10q-301
20031126
00188668 New Xl-3 System Is Safety Hazard.
20031201
00190175 RHRSW Pump Cubicle Cooler Tube Plugging Limit In
20031211
00194651 EC 341397 Scope Increase Due To Voltage Drop Concerns 20040112
00196677 Incorrect Trip Settings For Epn 2-6900-26-2b
20040121
201118 GE Identifies Potential HPCI Design Issues
20040211
202451 Irregularities While Performing Ec 341370
20040218
206203 Rx Vessel Bottom Drain Temperature Continuing Trend
20040304
207872 Existing Overload Heater Size Do Not Match Drawing.
20040312
212087 EC 24424 Requires Revision For The Unit 2 Edg
20040331
215791 Unplanned Revisions To Ec 23918 Ups/Battery Room Hvac 20040419
218406 Print 4e-2679f Shows The Wrong Size Transformer
In MCC 29-2
20040503
219901 Dwgs Identify Ss Piping Replacements Never Installed
20040510
221865 Pressure/Temperature Curves Non-Conservative
20040518
222787 Initiate Planned Cca For Unplanned Modification Revisions 20040521
231212 Nrc Uri 04-002-01 Concerning Mssv Setpoint Drift
20040624
233191 Pipe Support Clamp On Sw Line To 1-5746-A With No
Hangar Att
20040701
234471 "As Found" Circuit Breaker Size Does Not Match
Plant Drawing
20040708
236208 Potential Breaker Sizing Issue In Cubicle
20040715
237095 Ec Eval. 347941 Used To Implement A Configuration
Change
20040719
237204 System Function Changed Without 50.59 Screening
Review
20040719
239516 Power Changes Due To Which Feedwater Pumps
(Rfp) Are Running
20040728
239545 Im Work Order 00584879-01 Cancelled In Error.
20040728
245512 Pm Completed On Breaker 603 Instead Of
Breaker 607
20040818
247373 Fail Open Valve Installed Instead Of A Fail Close
Valve.
20040825
Rework Condition Reports
00149922 Gross EHC leak during attempt to return 2A EHC
pump
20030320
00186069 1-0203-3D steam leak at flange
20031112
00132066 Wrong Splice Kits Installed on 250V Cables
20021118
00147691 Failed PMT for New Valve
20030306
00160405 PMT Failure on WO579144-01
20030524
00166787 Unit 1 CIV #3 EHC leak
20030709
00169754 Reactor level indication
20030731
00172229 Failed Pmt For WO #586281 (2-3201-A 2A
RFP Min Flow)
20030819
00182424 Torus High Level Switches
20031022
00196997 OOT, (LT 1-1641-5A) Trend Code =B4
20040122
201012 Orifice plates for RO and FE installed
reversed (EC24429)
20040211
216730 Water in sensing lines (rework)
20040423
00130676 1B Fuel Pool pump failed to start.
20021107
00132857 Oil Mist From Concrete Piping
Repair To Ground
20021122
00135932 Flow blockage in NORMAL lineup for Gen Thermal Gas
Analyzer
20021216
00139873 Failed PMT for Work Order 98131574
20030117
00154484 Auto Start Relay (ASR) for 1/2 EDG Lost Continuity
20030417
00158353 High vibration on the OV2 Fan due to bearing degradation
20030512
00183900 Wrong parts reserved for valve overhaul
20031030
Operations Configuration Control & Closed Level 1 & 2 CRs
00126235 RHR logic electric lead disconnected
20021007
00137908 2A Recirc MG set scoop tube inadvertent reset
20030102
00138149 H2/ O2 Monitor System Control Switch Found in OFF
Position
20030105
00140164 Valve Found Already Closed And Tagged During C/O First
Hang
20030119
00150278 Inadvertent RCIC Trip Throttle Valve trip & unplanned LCO 20030322
00151220 Valve position differences between QOM, procedure and
20030328
00159607 Pressure boundary leakage from 2" Rx head vent line
20030520
00161345 CAM System Alarms
20030531
211163 Inoperable CRD Accumulator During Scram Timing
20040326
218906 Discovered 1-1901-12,Fuel Pool Gate Drain Vlv Close 20040505
Operator Work Arounds
227718 Review RCIC system Design and Licensing Basis
20040611
00146146 Rising offgas levels unit 1
20030225
00133579 1B1 heater normal LCV tripping due to Flash Tank high
level
20021201
00136806 2A MSDT level indication (LI 2-3541-59A) is pegged high.
20021219
00141665 SJAE Rad Monitors elevated (Ref. CR 146146)
20030129
00076147 Q2001-02891 - System modification creates excess entries 20010917
00102082 Low Flow Feedwater Reg Oscillations
20020403
00129665 2B3 Heater Trip
20021031
00138067 CNMT H2/O2 MON Torus Sample Line Heat Trace
Temperature
20030103
00156214 Offgas Sample parameters > Action Lvl One for Failed Fuel 20030428
00161391 1B RR MG Set Voltage Regulator Volts/Hertz
20030601
00193417 Rework on FT 0-7541-1B, continues to act erractic
20040105
207287 Toxic Gas Analyzer false high concentration inops CREVs
20040310
00101668 U-2 Digital FWLC response during shutdown
20020330
00131422 Service Air Back-Up Valve Auto Open
20021113
00142151 Low Flow FRV oscillations
20030130
00142500 Feedwater Low Flow Feed Regulator valve
20030201
00148161 Low flow frv cable loose causing erratic operation of valve
20030308
00148469 NOS ID'd no CRs written for frequent alarms from
HCU 26-39
20030311
00193621 CCST Heaters Reliability
20040106
210224 OOT, (0-7541-1B), TREND CODE = (B3)
20040323
244262 Owa Review For Defeating Rcic Suction Vlv Swap Logic
20040813
Operability CRs
00132397 Agastat Time-Delay Relays -Coil Lead Solder Connection
Issue
20021120
00138067 CNMT H2/O2 MON Torus Sample Line Heat Trace
Temperature
20030103
00143666 White residue found at 480V MCCs aux contacts
20030209
00148103 Moore Type SCT signal converters/isolators design
problem
20030307
00179235 Potentially non-conservative pressure temperature curves
20031003
223815 (SSDI) Potential to Drain the Torus on Failure of RCIC Line 20040526
235997 Installed Transformer Does Not Match
Print #4e-1438j
20040714
00105454 GE Part 21 Notification SC 02-05
20020426
00126208 Missing bolt on cplg guard
20021007
00159950 1-1001-43A follow up to CR 159693
20030521
00186375 Main Steam SRVDL Flange Rating Lower Than
Max Pressure
20031113
221865 Pressure/Temperature Curves Non-Conservative
20040518
00159693 Failure of 1-1001-43A to fully stroke
20030520
Outage Related CRs
00095024 LLRT on 2-0220-1 valve exceeded its Required Action
limit
20020213
00094984 LLRT,MSIV exceeded the allowable leakage limit of
< 46 scfh
20020213
00095044 LLRT on 2-0220-2 valve exceeded its admin Alarm Limit
20020213
208828 Unplanned TS Entry, CREVs Inop
20040317
00097303 Deficiencies in DG2 PT compt of aux cubicle at Bus 24-1
20020228
00095273 EHC Discharge pressure switch OOT
20020215
00095515 Out of tolerance
20020217
00095554 Line 2-3009A-1" as-found wall thickness below
minimum wall.
20020217
00095557 LLRT Failed on valve 2-1301-64, would not hold pressure. 20020217
00095798 Bus 24-1 UV relay found Out of Tolerance
20020219
00095965 2-2301-45 failed leak test QCOS 2300-19.
20020220
00096226 LLRT on 2599-4B exceeded its Admin Limit
20020221
00096239 LLRT on 2-2599-5A exceeded its Administrative limit
20020221
00097628 Found 1-1459B out of tolerance while performing
qcis 1400-03
20020304
204106 APRM #6, TB #3 has Multiple Discrepancies
20040225
204737 OOT, Relay 2-6701-21-1 (AC)
20040227
204739 OOT, Relay 2-6701-21-1 (AD)
20040227
205670 Bus 26 4kV Feed Breaker "A" phase relay OOT
20040303
205671 2-203-1D 2B switch out of tech spec allowable value
20040303
205672 Bus 26 4kV Feed Breaker "C" phase relay OOT
20040303
207572 Found loose wire in plug for drywell rad monitor 2-2419B.
20040310
208197 TIP Tubing Missing Clamps Undervessel
20040313
208205 LPRM 4041B Failure
20040313
208870 LPRM 56-25D failed downscale
20040317
211248 2B DW Rad Monitor 2-2419B Reading Downscale
20040327
Q1998-04844
Discovered localized wall pitting HPCI
suction during ISI
11/07/1998
Q1998-04863
PS 1-5641-124 Out of Tolerance
11/08/1998
Q1998-04887
HPCI switches found Out of Tolerance
11/09/1998
Q1998-04894
Turbine Trip PS 1-5650-100A found Out
of Tolerance
11/09/1998
Q1998-04937
RCIC temperature switches (2) as funds
were Out of Tolerance
11/11/1998
Q1998-04942
DPIS 2-302-52 found Out of Tolerance
11/12/1998
Q1998-05035
Condenser low vacuum switch found Out
of Tolerance
11/15/1998
Q1998-05036
Relay 287-121B time delay fund slightly Out
of Tolerance
11/15/1998
Q1998-05051
LS 1-5441-34A Out of Tolerance
11/16/1998
Q1998-05084
Instrument failure
11/17/1998
Q1998-05117
Out of Tolerance
11/18/1998
Q1998-05133
As found date OOT
11/18/1998
Q1998-05158
Trip Out of Tolerance
11/19/1998
Q1998-05200
PS 1-263-37b found Out of Tolerance
11/21/1998
Q1998-05207
HPCI flow loop calibration found Out
of Tolerance
11/21/1998
Q1998-05220
Out of Tolerance
11/23/1998
Q1998-05290
Out of Tolerances found during QCIS 0200-01
11/25/1998
Q1998-05305
Out of Tolerance (per IMD Administrative
Guidance) while performing QIP 263-1
11/26/1998
Q1998-05318
Transmitter Out of Calibration
11/28/1998
Corrective Action Program Process Coded CRs
00136710
Delay in Condition Report Issuance after Problem
Identified
20021219
00136729
Identified problem reporting
20021219
00137020
Corrective Action Assignment completed inappropriately 20021220
00139529
CR 132067 closed without completion of recommended
action
20030115
00140355
NOS ID'd RCR on B14-1 fuse drawer didn't address
CR 132496
20030121
00140371
MRC Rejected RP Root Cause Report
20030121
00140818
NOS identified apparent trends in RCR themes
20030123
00144464
Concerns with CAPR closure & EFR for ECCS venting
20030213
00145305
Dried grease at Dresden/Quad aux contacts-Untimely
response
20030219
00145609
Investigation Timeliness Needs Improvement
20030221
00146496
NOS Identified Untimely Corrective Actions
20030227
00146791
NOS identified ineffective freeze seal
20030228
00146799
NOS id'd problems with Effectiveness Review 95542-07
20030228
00146878
Corrective Action AT Assignment 00143607-04 Overdue 20030228
00147253
ACE Assignment 142318-01 Rejected by MRC
20030303
00149149
QRT Grade 3 for ACE 101650-01
20030314
00152154
Corrective action items from CR149922 not initiated
20030403
00152972
Action Tracking Item Overdue
20030408
00153078
NOS identified trend codes not updated after ACE
performed.
20030409
00153101
CR 89176 CAPR Action Not as Directed
20030409
00153525
Soer 02-4 FASA for SCWE at Quad Cities-Objective 4
20030411
00156697
NOS rated site CAP implementation as ineffective for
2003Q1
20030501
00157332
NOS "Ineffective Performance" CR Not Timely
20030505
00160946
NOS IDd CR processing quality issues - supervisory
reviews
20030529
00161395
EACE 154698 Receives MQRT Grade of "D"
20030601
00161396
ACE 150851 Receives MQRT Grade of "D"
20030601
00161503
ACE 150278 Receives MQRT Grade of "D"
20030602
00161528
NOS ID'd CR not written for test failure and TS entry
20030602
00161792
Corrective Action not performed due to cancellation of
00162160
QRT Grade 3 for ACE 148822-01
20030605
00163851
Corrective action entered that MRC did not approve
20030618
00164210
ACE 152803 Receives MQRT Grade of "D"
20030620
00166557
HPCI MO 2-2301-3 possible leak by
20030708
00167058
Station response to venting issues challenges
investigation
20030710
00167281
NOS Rated Site Corrective Action Program Ineffective
20030711
00167442
Priority for CRs not properly identified
20030714
00167972
20030717
00168928
NRC NCV 03-05-02 - Inadequate CA for a
Preconditioning Issue
20030724
00171039
EACE 127687 Receives MQRT Grade of "D"
20030811
00171042
EACE 145402 Receives MQRT Grade of "D"
20030811
00172936
NOS ID'd: Outage Lessons Learned Database
20030825
00175517
ACE 137396 Receives MQRT Grade of "D"
20030912
00176282
NOS ID: Weakness in a Root Cause Analysis
20030918
00177029
20030923
00177583
Unsatisfactory Closure of CR 174617
20030925
00178914
CR 143866 - Two Corrective Actions not Assigned
Upon Closure
20031002
00179144
Engineering RCR expectations not met
20031003
00180371
Inadequate information to complete corrective actions
20031010
00180678
CCA CAP Performance Indicator Yellow
20031013
00181086
Apparent Cause Administrative Deficiencies (CR)
20031015
00181949
Untimely CR Initiation
20031020
00183316
ACE 131050 Receives MQRT Grade of "F"
20031010
00186434
FASA Deficiency - Ineffective Corrective Action
20031113
00196512
PI for Median Age of CA is Red
20040120
00197277
CCA needed for External Identified CRs
20040123
201217
Corrective Action AT closed without all actions
performed
20040212
216467
Ineffective ACE and ACIT closure problems
20040422
216684
Untimely Initiation of Condition Reports by Engineering
20040423
227203
Cr Initiation Not Always Timely For Some Areas
20040609
227259
Nos Id D: Mrff Cr Processing Issues
20040609
227368
Site Wide Trending Not Consistently Used To Improve
Performance
20040610
239314
Cr210037 Corrective Action Incomplete
20040727
240264
Ineffective Capr For Main Steam Line Flow Switch
Root Cause
20040730
244665
Evaluation For Ir 232361 Does Not Exist In Passport
20040816
246150
Potential Problem With The Timely Routing Of Irs
To Ops
20040820
Additional Items Reviewed
NRC Information Notice 2002-29; Design Problems in Safety Functions of Pneumatic
Systems; dated October 15, 2002
General Electric Service Information Letter 448; Maintenance and Lubricants for GE
Type AK/AKR Circuit Breakers; Revision 2
ENG-04-07; Quad Cities June 2004 Quarterly System Health Indicators; dated July 22,
2004
NRC Generic Letter 88-14; Instrument Air Supply System Problems Affecting
Safety-Related Components; dated August 8, 1988
Commonwealth Edisons Response to Generic Letter 88-14; dated February 6, 1989
Maintenance Rule Performance Criteria Information for Function Z0012-01; Provide
Internal Flood Protection for the Reactor Building; dated October 22, 2004
Common Cause Analysis 209720; Analysis of the Trend in Work Practice Work
Instructions Coded Condition Reports Attributed to Maintenance; dated June 27, 2004
Common Cause Analysis 209752; Engineering Document Quality; dated July 28, 2004
CC-AA-103-2001; Setpoint Change Control; Revision 1
ESPT Continuing Training Course 04TESCT; Operability Determination; Revision 1
List of Camera Used for ALARA Purposes; dated October 26, 2004
Operating Experience Item 129522; Review of General Electric Technical Information
Letter 1360-2, EHC Power Supply Inspections; dated September 23, 2002
Operating Experience Item 136842; Review of General Electric SC02-22, Potential
Non-Conservatism in Small Steam Line Break Analysis Assumptions for Mark I
Containment Equipment Qualification; dated January 19, 2003
Operating Experience Item 136898; Review of General Electric Service Information
Letter 646, Target Rock Safety Relief Valve Failure to Fully Open; dated January 29,
2003
Operating Experience Item 141461; Review of General Electric SC03-01, Additional
Material Consideration for TIP System Ball and Shear Valve Qualifications; dated
June 16, 2003
Operating Experience Item 148037; Review of Nuclear Event Report DR-03-001, High
Flow Control Line Following Load Drop; dated April 4, 2003
Operating Experience Item 156575; Review of Nuclear Event Report KS-03-006,
Fleet-Wide Actions for Operating Events from 2002; dated August 26, 2003
Operating Experience Item 171258; Review NRC Information Notice 2002-37, Failure
of Safety-Related Circuit Breaker External Auxiliary Switches at Columbia Generating
Station; dated January 5, 2003
Operating Experience Item 174867; Review of Nuclear Event Report KS-03-007,
Inadequate Disposition of Single Point Vulnerability Results; dated October 1, 2003
Operating Experience Item 175971; Review of Nuclear Event Report DR-03-096,
Stroke Time Issue with High Pressure Coolant Injection Pump Discharge to
Condensate Storage Tank Motor Operated Valves; dated October 27, 2003
Operating Experience Item 179572; Review NRC Information Notice 2003-18, General
Electric SBM Control Switches with Defective Cam Followers; dated March 30, 2004
Operating Experience Item 200024; Review of Nuclear Event Report DR-04-006, Unit 3
Reactor Scram While Transferring Main Turbine Lube Oil Cooler; dated April 20, 2004
Operating Experience Item 202720; Review of Nuclear Event Report DR-04-009, Water
Entered Into the High Pressure Coolant Injection Steam Line Following a Scram; dated
March 31, 2004
Operating Experience Item 254371; Review of Nuclear Event Report LI-04-067, Unit 1
Thermal Power Exceeded by 0.2 - 0.4 Percent; dated September 21, 2004
P & ID, 21, Diagram of Turbine Building Closed Cooling Water System (Unit 1)
QOM, 1-3800-01, Rev. 8, U1 TBCCW Valve Check List
TBCCW System Engineering Notebook Index and Sample of Notebook
List of OPEN Work Orders and Work Requests for TBCCW System
Common Cause Analysis, CCA 203885-19 (Local Leak Rate Test Failures Affect Refuel
Outage Performance)
Issue Reports Submitted as a Result of the Team Observations
IR 00265130; Trapeze Type Piping Support Nut and Locknut Not Engaged
IR 00265397; Surface Corrosion on Pump Flanges/Hardware
IR 00265505; Valve Has Residue On/Near Packing Gland
IR 00265625; U-1 TBCCW Expansion Tank LCV Air Line Vibrates
IR 00265729; TBCCW Piping Hanger Issues in Crib House
IR 00266695; Valve has Residue on/Near Packing Gland
IR 00266711; TBCCW Pipe Hanger Issues in U-2 Crib House
IR 00266714; Pipe Support U-Bolts Lose or Missing, U-1 CRD Level
IR 00266734; U-1 RFP U-Bolt Pipe Supports Have Loose/Missing Jamb Nuts
IR 00266747; U-2 RFP U-Bolt Pipe Supports Have Loose/Missing Jamb NutsAR
266778; TBCCW Valves & Gauges for 1A IAC Have SW System EPNS
AR 00266814; TBCCW Valves Have 3900 System EPNS & SW and DW System
Names
IR 00266891; TBCCW Valves/Gauges Have 3900 System EPNS & Noun Names
IR 00267665; Extent of Condition From Pipe Support/Hanger Issues Found