8-21-2012 | On 6/25/12, Turkey Point Unit 3 was in Mode 5. The High Head Safety:Injection ( HHSI) manual isolation valve, 3-867 was previously closed, but not locked, while the HHSI Cold Leg Injection Isolation valves MOV-3-843A/B were closed and de-energized. At approximately 1710, Turkey Point Unit 3 inadvertently.entered into an unplanned 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Technical Specification (TS) Action for not meeting TS 3.4.9.3 Limiting Condition for Operation (LCO), when during the preparations for Engineered Safeguards Testing, Equipment Clearance Order (ECO 63-62) closed the breakers for MOV-3-843A/B.
This condition was recognized on 7/1/12 at approximately 1000, while the Unit 3 Reactor Controls Operator (RCO) was reviewing Technical Specification (TS) requirements for an upcoming evolution and noted the requirement for manual valve 3-867 to be locked closed. Operations recognized that Turkey Point Unit 3 had been in TS 3.4.9.3 Action (a), restored manual isolation valve 3-867 to its correct TS configuration by locking it closed. On 7/1/12 at approximately 1045, Unit 3 exited TS 3.4.9.3 Action (a) and complied with TS 3.4.9.3 LCO.
The root cause determined that the Engineered Safeguards Testing lacks a rigorous control process to ensure verification of manual valve 3-867 is in its required TS 3.4.9.3 configuration prior to energizing MOV-3-843A/Bs.
Corrective actions include process and procedural changes to add a verification step just prior to energizing MOV-3-843A/B breakers to ensure locally that manual isolation valve 3-867 is locked closed along with procedurally disallowing the breakers from being included on the ECO. |
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DESCRIPTION OF THE EVENT
On 6/25/12, Unit 3 was in Mode 5. The High Head Safety Injection (HHSI) manual isolation valve, 3-867 was closed, but not locked while the HHSI Cold Leg isolation valves [BQ,ISV], MOV-3-843NB were closed and de-energized.
Technical Specification (TS) 3.4.9.3 Limiting Condition for Operation (LCO) requires that the high pressure safety injection flow path to the Reactor Coolant System (RCS) be isolated by means of locked closed manual valves or by closed valves with power removed in Modes 4 (with RCS cold leg temperature less than 275 °F), 5 and 6 (with the reactor vessel head on.) TS 3.4.9.3, Action (a) states that with the high pressure safety injection flow paths to the RCS unisolated, restore isolation of these flow paths within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
At approximately 1710 on 6/25/12, as the portion of the Engineered Safeguards Testing energized MOV-3-843A/B during the course of hanging Equipment Clearance Order (ECO) 3-063-062 (referred to as ECO 63-62) with 3-867 closed but not locked, Turkey Point Unit 3 entered into an unplanned 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> TS Action for not meeting TS 3.4.9.3 LCO. This condition was recognized on 7/1/12, at approximately 1000, while the Unit 3 Reactor Controls Operator (RCO) was reviewing TS requirements for an upcoming evolution involving TS Overpressure Mitigating System (OMS) operability, when he noted the requirement for manual isolation valve 3-867 to be locked closed. Operations recognized that Turkey Point Unit 3 had been in TS 3.4.9.3 Action (a) since the time that ECO 63-62 closed the breakers for MOV-3-843A/B on 6/25/12.
Operators restored 3-867 to its correct TS configuration by locking it closed.
On 7/1/12 at approximately 1045, Unit 3 exited TS 3.4.9.3 Action (a) and complied with TS 3.4.9.3 LCO. It was discovered that several days prior to hanging ECO 63-62, on 6/21/12 at 0342, an administrative clearance ECO 3-062-3 867 ADMIN (referred to as ECO 3-867 Admin) had hung a caution tag on 3-867 in the closed position (but unlocked) for supporting post-maintenance testing (PMT) on MOV-3-843A/B. At that time, Turkey Point Unit 3 was in Mode 6 with the Reactor Vessel Head off, and TS 3.4.9.3 was not in effect. When ECO 63-62, which included a caution tag with a note to lock close 3-867, was subsequently authorized, the clearance "tag shared" with the administrative ECO on 3-867.
Although the caution tag note instruction fields differed (closed versus locked closed), the caution tag position field was the same 'Hang Tag' for each ECO. The electronic clearance module eSOMS is unable to differentiate the tag note field.
Consequently, there was no new caution tag generated for 3-867 since eSOMS automatically credited the earlier tag placement signatures into ECO 63-62's tag hang list sheet. Additionally, the existing caution tag instructions to close 3 867 for MOV-3-843A/B testing coincidentally matched the section of safeguards testing that was being prepared for at the time. Condition Report 1781044 was initiated to determine causes and corrective actions.
This report is submitted in accordance with 10 CFR 50.73(a)(2)(i)(6), any operation or condition which was prohibited by the plant's Technical Specifications.
CAUSE OF THE EVENT
The root cause identified that the Engineered Safeguards Testing lacked rigorous control process to ensure verification of 3-867 is in its required Tech Spec 3.4.9.3 configuration prior to energizing MOV-3-843A/B.
The following programmatic and organizational contributing causes were identified:
1. Turkey Point clearance program allows caution tags to "tag share" despite having in the notes different and even conflicting component positioning instructions.
2. No guidance exists for managing tag sharing in eSOMS or for dealing with warnings on conflict checks.
3. Operations practice is to not use actual tag positions when hanging caution tags. Component positioning information is contained only in the tag notes field.
4. Vague and conflicting guidance exists on using the Special Instruction field.
5. Pre-outage Operations training did not include a review of TS 3.4.9.3.
ANALYSIS
System Description:
The HHSI system is designed to supply borated water to the RCS system to make up for any loss of inventory and to maintain core cooling during a Loss of Coolant Accident (LOCA). Safety Injection boundary isolation valve, 3-867 is downstream of the HHSI pumps. Valve 3-867 is located in the Containment Spray Pump room with a reach rod handwheel located on the Auxiliary Building roof. The HHSI Cold Leg Injection Isolation valves, MOV-3-843A/B, are located downstream of 3-867 in a parallel arrangement and actuate open upon a Safety Injection signal. During Modes 1-3, valve 3-867 is locked open and MOV-3-843A/B are closed with their associated power supply breakers energized. While shutdown in Modes 4-6, MOV-3-843A/B are required to be closed with the breakers de-energized or 3-867 is required to be locked closed in order to prevent pressurized thermal shock in the event of an inadvertent safety injection and subsequent over- pressurization of the RCS. The following schematic represents the configuration for the manual isolation valve 3-867, and the HHSI Cold Leg Injection Isolation valves MOV-3-843A/B:
013 - TO 1 TOS/SAS bo n 010 13.
FROM SAFETY
INJECTION PUMP
DISCHARGE
1C, RO3= 13-41E7 / 3/4..3/9 v V L S/8" 3-10:78 V) UOV-3-11438 3fir B.SiC
COLD LEG
3-11.185� 3-4488 Technical Specification 3.4.9.3:
In Modes 4 (when the temperature of any RCS cold leg is less than or equal to 275 °F), 5, and 6 with the reactor vessel head on, the high pressure safety injection flow paths to the RCS shall be isolated pursuant to T.S. 3.4.9.3. If this Limiting Condition for Operation (LCO) is not met, i.e., with the high head safety injection flow paths to the RCS unisolated, isolation to these flow paths is required to be restored within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> per the corresponding action statement. T.S. 4.4.9.3.3 is the surveillance requirement for T.S. 3.4.9.3, which requires that high pressure injection flowpath isolation to the RCS is verified at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> by de-energized closed valves (i.e., MOV-3-843NB) or by locked closed manual valves (i.e., 3 867).
Event Analysis
On 6/25/2012, Turkey Point Unit 3 was inadvertently placed in a 4-hour action statement, pursuant to Technical Specification 3.4.9.3 Action (a), due to the cold leg safety injection flow path to the RCS being unisolated in Mode 5. Even though 3-867, manual isolation valve was closed, it failed to meet Surveillance Requirement 4.4.9.3.3 definition of isolation, which requires a "locked closed manual valve".
Previously, on 6/17/12, Equipment Clearance Order (ECO) 3-063-062 (referred to as ECO 63-62) was prepared to support Train B Engineered Safeguards Testing. The purpose of this ECO was to keep cold leg safety injection isolated while testing safety injection signals to cold leg isolation Motor Operated Valves (MOVs) MOV-3-843A/B. The ECO accomplished this by containing a step to hang a caution tag on 3-867 locked closed and a special instruction note, which stated "Valve 3-867 MUST BE LOCKED CLOSED prior to turning breakers ON for MOV-843's". ECO 63-62 includes the entire line up from locking 3-867 closed, to energizing MOV-3-843A/B during its execution. Compliance with TS 3.4.9.3 requirements is encapsulated within the hang execution sequence of the ECO. Due to plant conditions, Train B Safeguards was postponed for 7 days, which caused ECO 63-62 to remain unapproved. Meanwhile, clearance ECO 3-062-3-867 ADMIN (referred to as ECO 3-867 Admin) was authorized on 6/21/12, hung a caution tag on valve 3-867 stating "Closed by Shift Manager (SM) direction for testing MOV-3-843A/B".
On 6/21/12 at 2311, when the Reactor Head was set on the flange, TS 3.4.9.3 was applicable to Turkey Point Unit 3. In Modes 4 (when the temperature of any RCS cold leg is less than or equal to 275 °F), 5, and 6 with the reactor vessel head on, T.S. 3.4.9.3 LCO requires that the high pressure safety injection flow paths to the RCS be isolated to prevent inadvertent pressurization. If the LCO cannot be satisfied, the flow path isolation is required to be restored within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. The associated surveillance T.S. 4.4.9.3.3 defines this isolation as closed valves with power removed (i.e., closed and de energized MOV-3-843A/B) or by locked closed manual valves (i.e., locked closed 3-867) and requires this lineup to be verified at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. At the time the vessel head was set, both MOV-3-843A/B were closed and de-energized in compliance with TS 3.4.9.3 LCO.
Subsequently, on 6/24/12, the Engineered Safeguards Testing clearance, ECO 63-62 was approved, but because the caution tag from the Admin ECO 3-867 was already hanging, the eSOMS Clearance program database tag-shared with the existing caution tag on 3-867 Admin. As such, eSOMS did not generate a caution tag for 3-867 specifically for ECO 63-62, which would have included the tag note instructions to "Lock Close for 3B Safeguards." The existing Admin caution tag hanging on 3-867 had note instructions that read "Closed by Shift Manager direction for MOV-3-843A/B testing.
Additionally, the tag hang sheet checklist for ECO 63-62 was updated with the verification signatures from ECO 3-867 Admin making it appear as though the caution tag from ECO 63-62 was hanging.
This tag-sharing occurred because the high level tag position on both Caution Tags was "Hang Tag," instead of having an actual position directed. Per procedure OP-AA-101-1000, Clearance and Tagging, tag sharing is a "system software feature that shares tags between clearances when a common component is tagged with the same tag type (Danger, Caution, etc.).
When a tag is shared between active clearances, the component tag is hung only when the first clearance is authorized. All subsequent clearances that share this common tag will electronically reflect the initial component tag as being in place.
The Work Control Center Supervisor approving the ECO 63-62 was aware of this tag sharing and contacted the Senior Nuclear Plant Operator (SNPO), who reported that 3-867 was locked in the open position. Previously, on 6/22/12, the manual valve 3-867 was cycled to the locked open position in accordance with procedural guidance as part of a test evolution. The Work Control Center Supervisor changed the Special Instructions section to add that "(3-867 is currently open).
During dayshift on 6/24/12, a briefing was held for hanging ECO 63-62 and the special instructions were discussed, but the ECO hang never commenced. On 6/25/12 midshift, a different crew was briefed by the Field Supervisor (FS) for ECO 63-62 and the special instructions were discussed including the need to have 3-867 locked closed. Following an ECO walkdown, the operators identified that 3-867 was locked open and reported back-to the FS. Since the ECO hang sheet did not have a step to reposition the valve, the FS directed the operators to the Safeguards team lead for further guidance. The team lead instructed the operators to reposition the valve according to the instruction from the existing caution tag hanging on 3-867 without mentioning the requirement to lock it. The FS then sent the operators to the control room to validate the repositioning instruction they had received. The ensuing control room discussion with the Shift Manager (SM) concentrated on 0-ADM-051, Outage Risk Assessment and Control, requirements to keep the cold leg injection flowpath available, and concluded with SM direction to close 3-867 with no mention of locking.
At the end of midshift on 6/25/12 at 0641, 3-867 was positioned closed but left unlocked due to the existing caution tag instruction and previous team lead and control room discussion. The remainder of ECO 63-62 hang was turned over to dayshift to perform. The new dayshift crew was then briefed to complete the hang of ECO 63-62 and believed that 3-867 was already verified in the position required by the special instructions.
At approximately 1710 on 6/25/12, MOV-3-843A was energized when breaker (30738) was closed by ECO 63-62, and Turkey Point Unit 3 entered a 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> action statement per TS 3.4.9.3 LCO Action (a) because valve 3-867 was not in the Technical Specification required configuration of locked closed.
On 7/1/12 at approximately 1000, while reviewing T.S. 3.4.9.3 requirements for an upcoming evolution involving Overpressure Mitigating System (OMS) operability, the Unit 3 RCO noted the requirement to have 3-867 locked closed.
Realizing that the operator rounds had been crediting the valve as caution tagged closed, he dispatched a field operator to check the configuration of 3-867. The field operator reported back that the valve was closed but unlocked. The manual isolation valve 3-867 was locked closed at 1045, at which time Turkey Point Unit 3 exited T.S. 3.4.9.3 Action (a).
Reportability The unplanned entry into Turkey Point Unit 3 TS 3.4.9.3 Action (a) lasted from approximately 1710 on 6/25/12 to 1045 on 7/1/12. This event exceeded the TS allowed time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> to address the TS 3.4.9.3 LCO non-compliance. The event is reportable in accordance with 10 CFR 50.73 (a)(2)(i)(B), for any operation or condition which was prohibited by the plant's Technical Specifications.
ANALYSIS OF SAFETY SIGNIFICANCE
The High Head Safety Injection manual isolation valve 3-867 was found in the required closed position but was not administratively locked. With 3-867 physically closed, the potential for inadvertently transferring water from the Refueling Water Storage Tank (RWST) or actually injecting water into the reactor vessel during the safeguards testing procedure when the downstream motor operated valves MOV-3-843A/B were opened did not exist. Since the unit was in Mode 5 and 3-867 was in the required closed position, there was no risk to personnel safety, radiological safety, or nuclear safety. As such, there is no safety significance associated with this event.
CORRECTIVE ACTIONS
Corrective actions are in accordance with Condition Report 1781044 and include the following:
1. Process and procedural changes to add verification step just prior to energizing MOV-3/4-843A/B breakers to ensure locally that manual isolation valve 3/4-867 is locked closed along with procedurally disallowing the breakers from being included on the ECO.
2. ECO Process changes related to tag position of manual isolation valve 3/4-867.
3. Add procedural guidance regarding the use of tag position on caution tags.
4. Add procedural guidance on using tag sharing with caution tags and instructions for handling the various types of soft or warning ECO conflicts.
5. Provide guidance on use of Special instructions for component manipulations FAILED COMPONENTS IDENTIFIED:�None PREVIOUS SIMILAR EVENTS: The following Turkey Point station condition reports have been identified as similar events involving manipulation of HHSI cold leg injection manual isolation valve (867): ARs: 403629,405606, 584026. The corrective actions for these events did not focus on the process and programmatic changes to strengthen 3-867 configuration control to prevent this event.
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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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