06-03-2013 | On November 6, 2012, while in the cold shutdown reactor operating condition, Nine Mile Point Unit 1 experienced an unexpected rise in reactor water level that caused an automatic turbine trip signal and actuation of the High Pressure Coolant Injection ( HPCI) initiation logic. The HPCI system is a mode of operation that uses selected equipment of the condensate and feedwater system to perform its function. The HPCI system is not an emergency core cooling system.
At the time of the event, the HPCI system was not required to be operable. Though the HPCI initiation logic was actuated, HPCI system injection into the reactor vessel neither occurred nor was required.
The rise in reactor water level resulted from the unexpected opening of the 12 Feedwater flow control valve (FCV) during the application of a tagout to perform feedwater level control circuitry maintenance that was caused by a failure to use adequate human performance tools when performing the last periodic test of the feedwater FCVs. This resulted in the testing being performed improperly such that degradation of o-rings within the FCV actuator lockup valves was not detected. The o-ring degradation prevented the lockup valves from maintaining the FCV in the closed position.
This event is reportable in accordance with 10 CFR 50.73(a)(2)(iv)(A) as an event or condition that resulted in automatic actuation of the HPCI system.
To prevent recurrence, maintenance personnel have been briefed on the importance of continual use of human performance tools, and the applicable FCV test procedure has been revised to provide additional guidance for properly testing the FCV actuator lockup valves. |
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I. DESCRIPTION OF EVENT
A. PRE-EVENT PLANT CONDITIONS:
Prior to and during the event, Nine Mile Point Unit 1 (NMP1) was in the cold shutdown reactor operating condition with the reactor pressure at 0 psig. The main turbine had been reset in preparation for plant startup, which enabled the automatic turbine trip circuitry.
B. EVENT:
On November 6, 2012, the 12 Feedwater flow control valve (FCV-29-137) opened unexpectedly during the application of a tagout for the performance of maintenance on the reactor feedwater level control circuitry, causing reactor water level to rise. Plant operators tripped the 11 Control Rod Drive (CRD) pump and initiated closure of the 12 Feedwater pump discharge blocking valve (VLV-29-09) to control reactor water level; however, while the blocking valve was stroking closed, the reactor water level continued to rise causing an automatic turbine trip signal on high reactor water level at 0006 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, which then resulted in actuation of the High Pressure Coolant Injection (HPCI) channels 11 and 12 initiation logic, by design. Full closure of the 12 Feedwater pump discharge blocking valve terminated the rise in reactor water level. The operators stabilized reactor water level by using reject flow from the reactor water cleanup system and by re-starting the 11 CRD pump. The operators also observed that local indication was showing the 12 Feedwater flow control valve (FCV-29-137) to be in mid-position.
Flow control valve FCV-29-137 has a double-acting actuator that is designed to fail in place (lockup) on a loss of supply air pressure. The tagout required the removal of two fuses that de energized a solenoid operated valve, allowing air to port from the actuator of FCV-29-137. This should have resulted in closure of the bottom and top cylinder lockup valves (BV-29-231 and BV 29-232), thereby maintaining FCV-29-137 in the closed position. Subsequent troubleshooting determined that FCV-29-137 partially opened due to a degraded top cylinder lockup valve o-ring. Hardening of the o-ring likely allowed air on top of the cylinder to leak by to atmosphere.
HPCI is a mode of operation of the condensate and feedwater system that utilizes the condensate storage tanks, main condenser hotwell, two condensate pumps, condensate filters and demineralizers, two feedwater booster pumps, feedwater heaters, two motor-driven feedwater pumps, an integrated control system, and associated piping and valves. The HPCI system is not an emergency core cooling system and is not considered in any loss of coolant accident analyses. It is available to provide core cooling in the event of a small reactor coolant line break which exceeds the capability of the CRD pumps. HPCI is automatically initiated by a reactor vessel low level signal, a turbine trip, or excessive flow through an individual feedwater pump.
At the time of the event on November 6, 2012, with the reactor in cold shutdown, the main turbine was not in service and the HPCI system was not required to be operable. In this operating condition, the feedwater booster pumps were not in service. Without the booster pumps operating, the feedwater pumps' start permissive circuitry is not satisfied. Therefore, though the HPCI initiation logic was actuated, no HPCI components actually started or actuated, and HPCI system injection into the reactor vessel neither occurred nor was required.
II� There was no impact on Nine Mile Point Unit 2 from this event.
The event notification per 10 CFR 50.72(b)(3)(iv)(A) for the HPCI system actuation was initially completed on November 6, 2012 at 0356 hours0.00412 days <br />0.0989 hours <br />5.886243e-4 weeks <br />1.35458e-4 months <br /> (Event Number 48481). This notification was subsequently retracted on December 17, 2012, on the basis that the actuation was invalid.
Following further review, on April 24, 2013, Nine Mile Point Nuclear Station, LLC (NMPNS) confirmed that the event did constitute a valid actuation of the HPCI system and was reportable per 10 CFR 50.72(b)(3)(iv)(A). NMPNS recognizes that, based on the initial date of occurrence of the event, submittal of this LER is not timely.
C. INOPERABLE STRUCTURES, COMPONENTS, OR SYSTEMS THAT CONTRIBUTED TO
THE EVENT:
Prior to the event, there were no inoperable structures, systems, or components that contributed to the event.
D. DATES AND APPROXIMATE TIMES OF MAJOR OCCURRENCES:
On November 6, 2012, the 12 Feedwater flow control valve (FCV-29-137) opened unexpectedly, causing reactor water level to rise. An automatic turbine trip signal on high reactor water level occurred at 0006 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, which then resulted in actuation of the HPCI channels 11 and 12 initiation logic, by design. The operators closed the 12 Feedwater pump discharge blocking valve to terminate the rise in reactor water level.
E. OTHER SYSTEMS OR SECONDARY FUNCTIONS AFFECTED:
None.
F. METHOD OF DISCOVERY:
This event was discovered by operator observation of control room indication of rising reactor water level following application of the tagout for the performance of maintenance on the reactor feedwater level control circuitry.
G. MAJOR OPERATOR ACTION:
Upon observing the rising reactor water level indication in the control room, the operators tripped the 11 CRD pump and closed the 12 Feedwater pump discharge blocking valve (VLV 29-09) to control reactor water level. The operators stabilized reactor water level by using reject flow from the reactor water cleanup system and by re-starting the 11 CRD pump.
H. SAFETY SYSTEM RESPONSES:
The HPCI system initiation logic actuated in response to the automatic turbine trip signal, as designed. No other safety system responses occurred or were required as a result of this event.
questioning attitude) when performing periodic testing of the feedwater flow control valves in accordance with procedure N1-IPM-029-010, "Calibration of Feedwater FCV-29-134, FCV-29-137, and FCV-29-141." The procedure tests the functioning of the lockup valves by applying air pressure to the top and bottom cylinders of the flow control valve actuator and then determining the amount of air pressure decrease over a 5-minute time period. A pressure decrease of 20 percent or more in either cylinder indicates that the lockup valve should be re-built. The last time that this test was performed in March 2011, the test was performed improperly in that the lockup valve pressure drop test was conducted without the actuating cylinder being pressurized. The test personnel did not question the test results when zero test pressure was measured. Thus, since performance of procedure N1-IPM-029-010 did not detect the degraded lockup valve o-rings, no corrective actions were taken. In addition, there is no preventive maintenance activity to re-build the lockup valves at any given frequency; thus, the lockup valve o-ring degradation was not identified and corrected prior to the event that occurred on November 6, 2012.
This event was entered into the NMPNS corrective action program as condition report number CR 2012-010141.
III. ANALYSIS OF THE EVENT:
This event is reportable in accordance with 10 CFR 50.73(a)(2)(iv)(A) as an event or condition that resulted in manual or automatic actuation of any of the systems listed in paragraph 10 CFR 50.73 (a)(2)(iv)(B). The NMP1 HPCI system is a feedwater coolant injection system, which is one of the systems listed in 10 CFR 50.73(a)(2)(iv)(B).
There were no actual safety consequences associated with this event. The unexpected opening of the 12 Feedwater flow control valve (FCV-29-137) resulted in a rising reactor water level that caused a turbine trip signal, which then resulted in actuation of the HPCI channels 11 and 12 initiation logic, by design. HPCI is a mode of operation that utilizes selected equipment of the condensate and feedwater system to perform its function. The HPCI system is not an emergency core cooling system and is not considered in any loss of coolant accident analyses. It is available to provide core cooling in the event of a small reactor coolant line break which exceeds the capability of the CRD pumps.
At the time of the event on November 6, 2012, with the reactor in cold shutdown, the main turbine was not in service and the HPCI system was not required by the NMP1 Technical Specifications to be operable. Though the HPCI initiation logic was actuated, no HPCI components actually started or actuated, and HPCI system injection into the reactor vessel neither occurred nor was required, since adequate core cooling was already being provided. Plant parameters other than reactor water level remained within normal values throughout the event.
Based on the above, it is concluded that the actual safety significance of this event is low and the event did not pose a threat to the health and safety of the public or plant personnel.
IV. CORRECTIVE ACTIONS:
A. ACTION TAKEN TO RETURN AFFECTED SYSTEMS TO PRE-EVENT NORMAL STATUS:
Immediate actions were taken by the operators to terminate the rise in reactor water level and to restore reactor water level to the operating band. With the plant already in the cold shutdown condition, no further actions were required.
B. ACTION TAKEN OR PLANNED TO PREVENT RECURRENCE:
1. The rubber goods in the lockup valves for the 11 and 12 Feedwater flow control valves (FCV-29-141 and FCV-29-137) were replaced.
2. Instrumentation and Controls maintenance personnel were briefed on this event, including the importance of the continual use of human performance tools when performing maintenance tasks.
3. A change to procedure N1-IPM-029-010 was processed to clearly define the minimum starting air pressure required prior to commencing the lockup valve test.
V. ADDITIONAL INFORMATION:
A. FAILED COMPONENTS:
The lockup valves (BV-29-231 and BV-29-232) for Feedwater flow control valve FCV-29-137.
B. PREVIOUS LERs ON SIMILAR EVENTS:
There have been several previous LERs for events involving a turbine trip and subsequent actuation of the HPCI system initiation logic (LERs 2006-002, 2009-002, and 2012-005). The causes and actions described in these previous LERs were different than the current event and would not have prevented this event.
C. THE ENERGY INDUSTRY IDENTIFICATION SYSTEM (EIIS) COMPONENT FUNCTION
IDENTIFIER AND SYSTEM NAME OF EACH COMPONENT OR SYSTEM REFERRED TO
IN THIS LER:
IEEE 803 COMPONENT IEEE 805 SYSTEM �COMPONENT IDENTIFIER�IDENTIFICATION Feedwater System� SJ Feedwater Flow Control Valve� FCV� SJ Feedwater Isolation Valve� ISV SJ High Pressure Coolant Injection System� SJ Main Turbine/Supervisory Control� TRB� JJ Reactor Vessel� RPV AD Control Rod Drive Pump� P� AA
None
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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 50.72(b)(3)(ii), Degraded or Unanalyzed Condition | 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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