02-14-2014 | On August 28, 2012, while testing the High Pressure Coolant Injection System ( HPCI), it was discovered that water was leaking into the reactor building sump ( 20TK-69A). This leakage was due to the lifting of HPCI booster pump recirculation safety valve ( 23SV-66) caused by a failure of HPCI booster pump P-1B recirculation pressure control valve ( 23PCV-50).
Due to the amount of leakage, the HPCI system may not have been able to meet its mission time without realigning its suction source to the torus. As a result, HPCI was declared inoperable. The most probable cause of the 23PCV-50 failure was material introduced into the sensing line and sensing line filter when the system was filled using torus water during a maintenance activity on June 8, 2012.
Immediate corrective actions included replacing the snubber and filter, refilling the sensing line with condensate storage tank water, and then venting the system. Future corrective actions will include revising the procedure used to fill the HPCI system such that it contains additional guidance when filling the HPCI suction piping.
This event is reportable in accordance with 10 CFR 50.73(a)(2)(v)(D) as an event or condition that could have prevented the fulfillment of a safety function of a system required to mitigate the consequences of an accident, and 10 CFR 50.73(a)(2)(i)(B), any operation or condition which was prohibited by the plant's Technical Specifications.
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Reported lessons learned are incorporated into the licensing process and fed back to industry.
Send comments regarding burden estimate to the FOIA, Privacy and Information Collections Branch (T-5 F53), U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001, or by internet e-mail to Infocollects.Resource@nrc.gov, and to the Desk Officer, Office of Information and Regulatory Affairs, NEOB-10202, (3150-0104), Office of Management and Budget, Washington, DC 20503. If a means used to impose an information collection does not display a currently valid OMB control number, the NRC may not conduct or sponsor, and a person is not required to respond to, the information collection.
BACKGROUND
On January 18, 1988, a design change was made that installed a larger inline filter in the pressure sensing line for the High Pressure Coolant Injection (HPCI) [EIIS System Identifier: BJ] booster pump P-1B recirculation pressure control valve (23PCV-50) [EIIS Component Identifier: PCV]. This change was made because of several instances where the 23PCV-50 filter or snubber would become blocked by debris thereby preventing the pressure control valve from controlling. A two year preventative maintenance (PM) activity was also established to clean, inspect, and replace the filter and snubber.
On April 30, 2012, a new revision of OP-15, “High Pressure Coolant Injection” was issued. This revision of OP- 15 added a new section, G.9, “Fill and Vent HPCI Suction Piping From Condensate Storage Tanks (CST),” to address a corrective action identified during the Nuclear Regulatory Commission (NRC) inspection on gas accumulation earlier in the year.
On June 8, 2012, a HPCI outage was conducted in order to perform PM on HPCI Booster Pump P-1B Suction From Suppression Pool Check Valve (23HPCI-61) [EIIS Component Identifier: V]. This required the HPCI system to be isolated and drained, including the pump and suction line piping. In addition, the filter and snubber on the pressure sensing line for 23PCV-50 were also replaced as required by the PM.
During restoration, a portion of the HPCI suction piping was filled and vented from the torus per OP-15, Section G.8, “Fill and Vent HPCI Suction Piping from Torus.” The remaining HPCI suction piping was filled and vented from the CSTs in accordance with OP-15, Section G.9. Post work and return to service testing was completed satisfactory three days later and operability was demonstrated by a successful completion of ST-4N, “HPCI Quick-Start, Inservice, and Transient Monitoring Test (IST).” EVENT DESCRIPTION & ANALYSIS On August 28, 2012, while running the HPCI turbine for ST-4N, several annunciators were received in the control room, indicating that the reactor building equipment sump “A” (20TK-69A) [EIIS Component Identifier:
TK] was being overflowed and water was running down into the floor sump. This condition was confirmed visually by an operator. At that time the source of the extra water was unknown. Since the volume of water entering 20TK-69A was greater than what was expected to come from the HPCI system. It was assumed that torus water was coming through a leaking check valve on the discharge of the reactor building equipment drain sump pump. At the time of discovery, torus water level was being lowered by pumping it to the radwaste system [EIIS System Identifier: WD] via the equipment drain discharge header.
On August 30, 2012, operators performed ST-4E, “HPCI and SGT Logic System Functional and Simulated Automatic Actuation Test.” The data collected during this surveillance revealed that while the HPCI turbine was in operation, there was approximately 75 gpm of water going into the “A” reactor building sump. The source of this water was determined to come from HPCI Booster Pump P-1B Recirculation Safety Valve (23SV-66) [EIIS Component Identifier: RV] which was lifting on high pressure. Troubleshooting determined that the cause of 23SV-66 to lift was a failure of 23PCV-50 to properly control pressure.
Control pressure for 23PCV-50 is 75 psia which is the design pressure for the HPCI lube oil cooler (23E-2) [EIIS Component Identifier: CLR] and gland seal condenser (23E-1) [COND]. However, data collected during the ST- 4E run on August 30, 2012, demonstrated that 23PCV-50 was not repositioning as expected. The increased down stream pressure caused 23SV-66 to lift, allowing CST water into the reactor building equipment sump.
The HPCI system is considered operable when it is aligned to one or both CSTs with power available to support automatic realignment to the suppression pool if required. This is based on the design of the CSTs and the accident analysis which credits the suppression pool for supplying the HPCI System. With an assumed leakage of 75 gpm of CST water being directed into 20TK-69A, HPCI may not have been able to meet its mission time without realigning its suction to the torus. If the HPCI suction source re-aligned to the torus, due to low CST levels, the water being discharged to 20TK-69A would be torus water; this condition would result in total leakage sources outside containment exceeding the 5 gpm limit established by the Final Safety Analysis Report (FSAR).
As a result, HPCI was declared inoperable on August 30, 2012. On September 2, 2012, after replacing the sensing line filter and snubber; flushing the system with clean CST water; and successfully performing return to service testing; HPCI was restored to operable status. This was reported to the NRC on August 30, 2012, via ENS #48258. It is being reported in this LER in accordance with 10 CFR 50.73(a)(2)(v)(D), any event or condition that could have prevented the fulfillment of the safety function of structures or systems that are needed to mitigate the consequences of an accident.
The action that led to 23PCV-50 failing to control pressure was filling the HPCI pump suction from the torus during restoration from the June 2012 maintenance outage. That action introduced foreign material into the suction line that eventually fouled the filter in the 23PCV-50 sensing line. The date that 23PCV-50 was not capable of performing its function is indeterminate. The period of time from June 2012 to August 2012 is greater than the allowed outage time for HPCI (TS LCO 3.5.1), therefore this event is also being reported under 10 CFR 50.73(a)(2)(i)(B), any operation or condition which was prohibited by the plant's Technical Specifications.
CAUSE OF EVENT
Mechanistic The apparent cause of the event was determined to be material in the 23PCV-50 sensing line and filter. This was validated by physical inspection during troubleshooting. The material was a result of filling and venting the 23PCV-50 sensing line with torus water containing suspended solids.
Normally the 23PCV-50 sensing line is maintained full of water. With its short stroke, suspended solids don't make their way up the line and into the filter. However, during the HPCI LCO in June, both the HPCI system and the 23PCV-50 pressure sensing lines were drained at the same time. Therefore, when the HPCI suction piping was filled from the torus, the sensing line was also filled. This resulted in suspended solids from the torus water clogging the filter in the sensing line.
Programmatic The event was reviewed for organizational and programmatic deficiencies that may have caused or contributed to the event. It was determined that Operations Procedure, OP-15 had insufficient detail in its guidance for filling and venting from the torus. This had the unintended consequence of filling portions of the HPCI line, including the instrument line for 23PCV-50, with material from the torus.
An extent of condition review was performed for other PCVs subject to the same failure mode. The systems reviewed were HPCI, Reactor Core Isolation Cooling [EIIS System Identifier: BN], Residual Heat Removal [EIIS System Identifier: BO], and Core Spray [EIIS System Identifier: BM]. This review did not identify any other PCV that was applicable to the failure mode described in this LER.
FAILED COMPONENT IDENTIFICATION
Description: HPCI Booster Pump P-1B Recirc Pressure Control Valve Manufacturer: Masoneilan Intl, Inc.
Model/Part Number: 525 NPRDS Manufacturer Code: M120 FitzPatrick Component ID: 23PCV-50
CORRECTIVE ACTIONS
Completed The PCV in-line filter and snubber have been replaced.
The pressure sensing line for 23PCV-50 was flushed with clear water.
23PCV-50 was tested satisfactory.
All other components in the HPCI system have been evaluated for extent of condition, and are not susceptible to this failure mode.
HPCI system has been tested successfully per ST-4N.
Future Actions Revise OP-15 to add additional guidance for filling the HPCI suction piping.
Evaluate a design change to have 23SV-66 discharge into torus vice equipment sump.
Revise PM to fill sensing line using a clean water source.
ASSESSMENT OF SAFETY CONSEQUENCES
The HPCI System is designed to provide adequate core cooling to limit fuel clad temperatures in the event of a small break in the Reactor Coolant System piping with a loss of coolant that does not result in rapid depressurization of the reactor pressure vessel (RPV).
The significance of this condition is based on the safety function performed by the HPCI system. With 23PCV- 50 not controlling pressure, 23SV-66 would lift continuously with HPCI in operation. This would initially result in CST water being directed to 20TK-69A. If the HPCI suction source re-aligned to the torus, due to low CST levels, the water being discharged to 20TK-69A would be torus water; this condition would result in total leakage sources outside containment exceeding the 5 gpm limit established by the FSAR. An assessment of the potential risk contributions associated with this alignment was performed, and the result screened, per the criteria established in NRC IMC 0609, as very low safety significance with nominal risk.
Radiological & Industrial Safety There were no actual radiological or industrial safety consequences. The potential impact on radiological and industrial safety is minimal; Secondary Containment is required to be Operable in all applicable Modes of operation.
There was no actual or potential nuclear safety consequences associated with this condition. At all times HPCI was available to provide a source of RPV water inventory in the event of a loss of coolant accident. Additionally, the Automatic Depressurization System (ADS) in combination with the Low Pressure Coolant Injection system (LPCI) and the Core Spray system (CS) were available to provide core cooling during the period of HPCI inoperability. Secondary containment also remained OPERABLE during this period.
This deficiency did have a potential impact on the Primary Coolant Sources Outside Containment Program required by TS 5.5.2. This program is in place to ensure that leaks are tracked, assessed, and prioritized such that the potential to exceed post accident release rates are minimized. With respect to this program, it would only be impacted in the event that the HPCI suction was aligned to the torus.
The potential impact of this condition was minimized because during the course of this event, the HPCI system suction was aligned to the CST's. In addition, Emergency Operating Procedures (EOP) preferentially maintain the HPCI suction aligned to the CSTs and during accident conditions the EOPs do address high water levels in the reactor building sumps and crescents; actions include isolating systems discharging into the area, shutting down the reactor and depressurizing the reactor.
SIMILAR EVENTS
Internal operating experience (OE) was reviewed through Entergy's corrective action program. There were no relevant events found. Similarly, external industry OE was reviewed via INPO. Although there were several events that had some applicability to JAF, none of the events were relevant with regards to the event being reported in this LER. Insights from the OE search were incorporated into the corrective action plan.
REFERENCES
JAF Condition Reports: CR-JAF-2012-04994, CR-JAF-2012-04958, CR-JAF-2012-03015 JAF TS 3.5.1, ECCS – Operating, TS 5.5.2 – Primary Coolant Sources Outside Containment JAF Engineering Change 39479 JAF FSAR 6.4.1 High Pressure Coolant Injection System
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05000413/LER-2012-001 | | 10 CFR 50.73(a)(2)(iv)(A), System Actuation 10 CFR 50.73(a)(2)(v)(A), Loss of Safety Function - Shutdown the Reactor 10 CFR 50.73(a)(2)(v), Loss of Safety Function 10 CFR 50.73(a)(2)(vii), Common Cause Inoperability 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000327/LER-2012-001 | Unanalyzed Condition Affecting Essential Raw Cooling Water System due to External Flooding | 10 CFR 50.73(a)(2)(ii)(B), Unanalyzed Condition | 05000388/LER-2012-001 | Two Control Room Floor Cooling Systems Inoperable | 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident | 05000395/LER-2012-001 | Vice President, Nuclear Operations 803.345.4342 August 3, 2012SCE~r .so A SCANA COMPANY Document Control Desk U. S. Nuclear Regulatory Commission
Washington, DC 20555
Dear Sir / Madam: Subject:VVIRGIL C. SUMMER NUCLEAR STATION (VCSNS) UNIT 1 DOCKET NO. 50-395 OPERATING LICENSE NO. NPF-12 LICENSEE EVENT REPORT (LER 2012-001-01) CORE EXIT THERMOCOUPLES & REACTOR WATER LEVEL INDICATION SYSTEM INOPERABLE DUE TO AN INADEQUATE MAINTENANCE PROCEDURE Attached is Licensee Event Report (LER) No. 2012-001-01 for the Virgil C. Summer Nuclear Station Unit 1. This revised report describes a condition where Core Exit Thermocouples and Reactor Water Level Indication System would not be operable for accident monitoring. This report is submitted in accordance with 10 CFR 50.73(a)(2)(i)(B). This letter and attached LER contain no new commitments and no revisions to existing
commitments.
Should you have any questions, please call Bruce Thompson at (803) 931-5042. Very truly yours, Dal Thomas D. Gatlin TS/TDG/jw
Attachment
c: K. B. Marsh P. Ledbetter S. A. Byrne J. C. Mellette J. B. Archie EPIX Coordinator N. S. Carps K. M. Sutton J. H. Hamilton INPO Records Center R. J. White Marsh USA, Inc. W. M. Cherry R. J. Schwartz V. M. McCree NSRC R. E. Martin RTS (CR-11-01807) NRC Resident Inspector FileV(818.07) M. N. Browne PRSF (RC-12-0116) V fALVirgil C. Summer Station • Post Office Box 88 .Jenkinsville, SC • 29065 • F (803) 345-5209 1 NRC FORM 366 U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB: NO. 3150-0104 EXPIRES: 10/31/2013 (10-2010) Estimated burden per response to comply with this mandatory collection request: 80 hours.0Reported lessons learned are incorporated into the licensing process and fed back to industry. Send comments regarding burden estimate to the FOIA/Privacy Section (T-5 F53), U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001, or by Internet e-mail to infocollects.resource@nrc.gov, and to the Desk Officer, Office of Information and Regulatory Affairs, NEOB-10202, (3150-0104), Office of Management andLICENSEE EVENT REPORT (LER) Budget, Washington, DC 20503. If a means used to impose an information(See reverse for required number of collection does not display a currently valid OMB control number, the NRC may not conduct or sponsor, and a person is not required to respond to, thedigits/characters for each block) information collection. 1. FACILITY NAME 2. DOCKET NUMBER 3. PAGE Virgil C. Summer Nuclear Station Unit 1 05000 395 1 OF 5 4. TITLE Core Exit Thermocouples & Reactor Water Level Indication System Inoperable due to Inadequate Maintenance Procedure | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000397/LER-2012-001 | DG-3 Inoperable for Longer than Allowed by TS Due to Failed Governor 05000 | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000410/LER-2012-001 | Forced Shutdown Due to an Increase in Drywell Leakage in Excess of Technical Specifications Limit | 10 CFR 50.73(a)(2)(i)(A), Completion of TS Shutdown | 05000289/LER-2012-001 | Single Condition Making Independent Trains Inoperable | 10 CFR 50.73(a)(2)(vii), Common Cause Inoperability | 05000286/LER-2012-001 | Common Cause Inoperability of Both Trains of Motor Driven Auxiliary Feedwater (AFW) Pumps Due to Inability to Control AFW Regulating Valves After Isolation of Nitrogen Backup | 10 CFR 50.73(a)(2)(v), Loss of Safety Function 10 CFR 50.73(a)(2)(vii), Common Cause Inoperability | 05000265/LER-2012-001 | Main Steam Isolation Valve Local Leak Rate Test Exceeds Technical Specifications Limit | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000456/LER-2012-001 | Two Main Steam Safety Valves Failed Pre-outage Setpoint Testing Due to Abnormal Spring Geometry | 10 CFR 50.73(a)(2)(vii), Common Cause Inoperability 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000261/LER-2012-001 | Technical Specification Required Plant Shutdown Due to Missed Surveillance and Operation Prohibited by Technical Specifications | 10 CFR 50.73(a)(2)(iv)(A), System Actuation 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications 10 CFR 50.73(a)(2)(i)(A), Completion of TS Shutdown | 05000483/LER-2012-001 | Modification Implementation Error Adversely Impacted the Containment Cooling System | 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident 10 CFR 50.73(a)(2)(v), Loss of Safety Function 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000250/LER-2012-001 | Containment Concrete Thickness At Spalled Patch Does Not Meet Technical Specification Design Value | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000414/LER-2012-001 | Carolinas Duke Energy Carolinas, LLC 4800 Concord Rd. York, SC 29745 803-701-4251 December 20, 2012 U.S. Nuclear Regulatory Commission
Attention: Document Control Desk
Washington, D.C. 20555
Subject:�Duke Energy Carolinas, LLC (Duke Energy)
Catawba Nuclear Station, Units 1 and 2
Docket Nos. 50-413 and 50-414
Licensee Event Report 414/2012-001
Pursuant to 10 CFR 50.73(a)(1) and (d), attached is Licensee Event Report 414/2012-001,
Revision 0 entitled, "Diesel Generator (DG) 2B Was Unknowingly inoperable from 09/28/12 to
10/23/12 Due to Failed Tachometer Relay Power Supply".
This report is being submitted in accordance with 10 CFR 50.73(a)(2)(i)(B), 10 CFR
50.73(a)(2)(ii)(B), and 10 CFR 50.73(a)(2)(v)(A)-(D).
There are no regulatory commitments contained in this letter or its attachment. This event is considered to be of no significance with respect to the health and safety of the
public.
If there are any questions on this report, please contact L.J. Rudy at (803) 701-3084. Kelvin Henderson LJR/s Attachment www. duke-energy. corn Document Control Desk Page 2 December 20, 2012 xc (with attachment): V.M. McCree Regional Administrator U.S. Nuclear Regulatory Commission - Region II Marquis One Tower 245 Peachtree Center Ave., NE Suite 1200 Atlanta, GA 30303-1257 J.H. Thompson (addressee only) NRC Project Manager U.S. Nuclear Regulatory Commission Mail Stop 8-G9A 11555 Rockville Pike Rockville, MD 20852-2738 G.A. Hutto, III NRC Senior Resident Inspector Catawba Nuclear Station INPO Records Center 700 Galleria Place Atlanta, GA 30339-5957 Document Control Desk Page 3 December 20, 2012 bxc (electronic copy)(with attachment): INPO L.E. Harmon C.S. Kamilaris R.D. Hart G.Y. Helton S.F. Hatley (ICES) M.K. Green R.T. Simril, Jr. B.C. Carroll M.C. Nolan W.J. Pritchett, Jr. T.L. Patterson K.R. Alter H.D. Brewer R.E. Abbott, Jr. B.J. Horsley S.L. Western bxc (hard copy)(with attachment): D.B. Alexander L.S. Nichols L.J. Rudy ELL Master File CN-801.01 LER File RGC Date File NCMPA-1 NCEMC PMPA ICES Lee.Harmon@NRC.gov NRC FORM 366 U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB: NO. 3150-0104 EXPIRES: 10/31/2013
(10-2010) Estimated burden per response to comply with this mandatory collection request: 80 hours. Reported
lessons learned are incorporated into the licensing process and fed back to industry. Send commentsLICENSEE EVENT REPORT (LER) regarding burden estimate to the Records and FOIA/Privacy Service Branch (T-5 F53), U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001, or by internet e-mail to infocollects.resource@nrclov, and to the Desk Officer, Office of Information and Regulatory Affairs, NEOB-10202, (3150-0104), Office of Management and Budget, Washington, DC 20503. If a means used(See reverse for required number of to impose an information collection does not display a currently valid OMB control number, the NRCdigits/characters for each block) may not conduct or sponsor, and a person is not required to respond to, the information collection. r1. FACILITY NAME 2. DOCKET NUMBER 3. PAGE Catawba Nuclear Station, Unit 2 05000414 10OF •4. TITLE Diesel Generator (DG) 2B Was Unknowingly Inoperable from 09/28/12 to 10/23/12 Due to Failed Tachometer
Relay Power Supply | 10 CFR 50.73(a)(2)(ii)(B), Unanalyzed Condition 10 CFR 50.73(a)(2)(v)(A), Loss of Safety Function - Shutdown the Reactor 10 CFR 50.73(a)(2)(v), Loss of Safety Function 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications 10 CFR 50.73(a)(2)(ii) | 05000247/LER-2012-001 | Technical Specification (TS) Prohibited Condition Caused by an Inoperable 23 Emergency Diesel Generator Fuel Oil Storage Tank Due to Fuel Oil Below TS Limit | 10 CFR 50.73(a)(2)(v), Loss of Safety Function 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000269/LER-2012-001 | Unanalyzed Conditions Exist for Standby Shutdown Facility Mitizated Events | 10 CFR 50.73(a)(2)(ii)(B), Unanalyzed Condition 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000445/LER-2012-002 | COMANCHE PEAK 05000445 10OF06 | 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident 10 CFR 50.73(a)(2)(ix)(A), Prevented Safety Function in Multiple System | 05000413/LER-2012-002 | Discovery of Inadequacy in Surveillance Testing of Solid State Protection System | 10 CFR 50.73(a)(2)(vii), Common Cause Inoperability 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000261/LER-2012-002 | Unplanned LCO 3.5.4 Entry Due to RWST alignment to Purification | 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000410/LER-2012-002 | Loss of Isolation Function on RHR Shutdown Cooling Suction Line due to Breaker Trip | 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident | 05000482/LER-2012-002 | . One Train of Automatic Safety Infection Blocked During Entry Into Mode 3 Due To Procedural Weakness | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000361/LER-2012-002 | Emergency Diesel Generator Vibration Trip Not Bypassed For Non-Accident Condition | 10 CFR 50.73(a)(2)(ii)(B), Unanalyzed Condition | 05000346/LER-2012-002 | Leak from Reactor Coolant Pump Seal Piping Socket Weld due to High Cycle Fatigue | 10 CFR 50.73(a)(2)(ii)(A), Seriously Degraded | 05000333/LER-2012-002 | High Pressure Coolant Injection Pressure Control Valve Failure | 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000306/LER-2012-002 | Unit 2 Emergency Diesel Generators Inoperable Due To Missing Flood Control Barrier Seal | 10 CFR 50.73(a)(2)(v)(A), Loss of Safety Function - Shutdown the Reactor 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications 10 CFR 50.73(a)(2)(ix)(A), Prevented Safety Function in Multiple System | 05000250/LER-2012-002 | Non-compliance with TS 3.4.9.3 due to Manual Isolation Valve Found in Incorrect TS Configuration | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications 10 CFR 50.73(a)(2)(i) | 05000278/LER-2012-002 | Failure of Primary Containment Isolation Valve due to Foreign Material Results in Condition Prohibited by TS | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000316/LER-2012-002 | Unit 2 Reactor Trip from Generator Trip Due to Incorrect Relay Setting | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000282/LER-2012-002 | Unplanned Actuation of 121 Motor Driven Cooling Water Pump | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000298/LER-2012-002 | Improper Rotor Installation Causes Failure of Diesel Generator to Start | 10 CFR 50.73(a)(2)(v), Loss of Safety Function 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000247/LER-2012-002 | Technical Specification (TS) Prohibited Condition Caused by New Fuel Assemblies Stored in a Configuration Prohibited by the TS | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000237/LER-2012-002 | Inlet Steam Drain Pot Drain Line Leaks Result in HPCI Inoperabilities | 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident | 05000298/LER-2012-003 | Reactor Building Doors Opened Simultaneously Causes Loss of Safety Function | 10 CFR 50.73(a)(2)(v), Loss of Safety Function | 05000410/LER-2012-003 | Suppression Pool Level Below Technical Specification Limit During Mode Change | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000261/LER-2012-003 | Plant Modification Interfered with the Operation of Containment Wide Range Level Indicator | | 05000298/LER-2012-004 | Cooper Nuclear Station 05000298 1 of 4 | 10 CFR 50.73(a)(2)(v)(B), Loss of Safety Function - Remove Residual Heat | 05000410/LER-2012-004 | Manual Reactor Scram due to a Loss of Main Turbine Gland Sealing Steam Resulting in Lowering Condenser Vacuum | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000382/LER-2012-004 | Essential Chiller Oil Leak Creates Unanalyzed Past Operability Condition | 10 CFR 50.73(a)(2)(ii)(B), Unanalyzed Condition 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000265/LER-2012-004 | Drywell Radiation Monitor Failed Downscale | | 05000261/LER-2012-004 | Reactor Tripped Due to a Turbine Trip Caused by a Feedwater Isolation Signal from Steam Generator 'B' High Level | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000454/LER-2012-004 | Reactor Pressure Vessel Head Control Rod Drive Mechanism Penetration Nozzle Weld Repair Surface Indications | | 05000254/LER-2012-004 | Breech in Secondary Containment | | 05000482/LER-2012-004 | Two Charging Pumps Capable of Injecting into the RCS Due to Inadequate Definition of Centrifugal Charging Pump in LCO 3.4.12 | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000410/LER-2012-005 | Automatic Diesel Actuation Due to the Loss of a 115 kV Offsite Power Source | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000298/LER-2012-005 | Cooper Nuclear Station 05000298 1 of 4 | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000298/LER-2012-006 | Missing Vent Plug Results in Technical Specifications Prohibited Condition | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000220/LER-2012-007 | High Pressure Coolant Injection System Logic Actuation Following an Automatic Turbine Trip Signal Due to High Reactor Water Level | 10 CFR 50.73(a)(2)(iv)(A), System Actuation |
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