04-20-2010 | Event Description: On February 18, 2010, with the unit in Mode 4, a reactor coolant pressure boundary leak was identified at the 1A reactor coolant hot leg thermowell 1NCTW5850 seal weld. A cool down to Mode 5 was initiated. , Unit Status: At the time of the event, Unit 1 was in Mode 4 at 096 power.
Power had been reduced to perform an inspection in containment to identify the source of primary leakage.
Event Cause: The cause of the failed seal weld was inadequate weld control when the weld was fabricated during initial construction. The weld failure resulted from the presence of a discontinuity involving a metal removal process. Applied loads, primarily pressure loads (high strain - low cycle fatigue) to the weakened area (i.e. location metal removed) contributed to the seal weld failure.
Corrective Actions: After reducing primary system pressure, additional weld passes were applied at the seal weld associated with the mechanical joint located between the weld boss and the thermowell. Visual examination of the other three Unit 1 hot leg RTD thermowells concluded no sign of leakage. |
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LER-2010-002, Discovery of Reactor Coolant System Pressure Boundary Leak at Thermowell 1NCTW5850 Seal Weld.Docket Number |
Event date: |
02-18-2010 |
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Report date: |
04-20-2010 |
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4132010002R00 - NRC Website |
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BACKGROUND
Catawba Nuclear Station is a Westinghouse Pressurized Water Reactor [EIIS:
� RCT].
(NC) System�� [EIIS:AB] is removal of the heat generated in the fuel due to the fission process, and transfer of this heat via the steam generators (SG) [EIIS:SG] to the secondary plant. The reactor coolant is circulated through four loops connected in parallel to the reactor vessel, each loop containing a SG, a reactor coolant pump [EIIS:P], and appropriate flow and temperature instrumentation for both control and protection.
The primary function of the Reactor Coolant (RCS) Components that contain or transport the coolant to or from the reactor core make up the NC system. Component joints are made by welding, bolting, rolling, or pressure loading, and valves isolate connecting systems from the RCS.
Technical Specification (TS) 3.4.13 specifies that in Modes 1, 2, 3 and 4, RCS operational leakage shall be limited to: No pressure boundary leakage, 1 gallon per minute (gpm) unidentified leakage, 10 gpm identified leakage, and 150 gallons per day primary to secondary leakage through any one SG. TS 3.4.13 Condition B states that if any pressure boundary leakage exists, the unit must be in Mode 3 in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and Mode 5 in 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.
EVENT DESCRIPTION
(Dates and times are appropriate) 12/30/2009 While performing Unit 1 Mode surveillance, the Radiation Protection group noted the count rate on lEMF38 (containment particulate monitor) increased significantly since 12/26/09.
1/4/2010 Engineering identified a trend of an approximate 1 gallon per hour (gph) input to the "B" Containment Floor and Equipment sump (CF&E).
1/5/2010 - 2/15/2010 A failure investigation/troubleshooting team was formed. Troubleshooting activities included boroscope and robotic inspections to identify the leak location.0 Air samplers were located such that a leak in the reactor vessel head area could be identified. A tracer dye was also added to the Lower Containment Ventilation Unit (LCVU) drain lines to determine if any portion of the condensate was an input to the 1B CF&E sump. It was determined that a drain valve from the 1D LCVU was leaking and providing a small input to the sump. During inspection of LCVUs, boron was found on the motor housing of the 1D LCVU.
2/15/2010 - 2/16/2010 Engineering identified leak on lower containment floor. Potential leak sources identified. Robotic inspection device was acquired and readied for subsequent inspections.
2/17/2010 Engineering identified boron in "A" hot leg insulation and an active leak.
Station Management decided to shut down the unit to visually identify the leak source.
2/17/2010 2052 Operations entered abnormal procedure AP/1/A/5500/009, Rapid Downpower.
2/18/2010 0333 Mode 3 entered.
2/18/2010 0600 Engineering confirmed the source of leak was coming from hot leg 1A.
2/18/2010 0700 Station Management determined that the unit needed to be cooled to Mode 4 to safely remove insulation and identify the leak source.
2/18/2010 1348 Entered Mode 4.
2/18/2010 1900 Insulation was removed and the leak source was confirmed as coming from the thermowell seal weld.
2/18/2010 1915 Operations entered Technical Specification Action Item Log (TSAIL) for RCS pressure boundary leakage and commenced a cool down to Mode 5.
2/19/2010 0223 Entered Mode 5.
2/19/2010 1630 Peening and weld repair of the seal weld on the 1A hot leg thermowell were not successful at a primary pressure of 330 psi. Primary system pressure was reduced to eliminate water flow to facilitate weld repair.
2/20/2010 0605 The PZR was solid, and 1B NC Pump running 2/20/2010 1400 Following a reduction in RCS pressure, repair welding was started at approximately 1200. The areas were sealed and follow-up welding was performed to yield a near flush configuration of the boss and thermowell.
CAUSAL FACTORS
The cause of the failed seal weld was inadequate weld control when the weld was fabricated during initial construction. The weld failure resulted from the presence of a discontinuity involving a metal removal process (i.e.
local grinding or manual filing). Applied loads (primarily high strain - low cycle fatigue pressure loads) to this weakened local area of the weld led to the eventual failure. This observation was supported by the original weld documentation. The initial seal weld was rejected both visually and by a liquid penetrant test. The weld was later accepted, presumably after only surface conditioning (i.e. the addition of weld material was not required) where manual filing or grinding of the surface was performed to clear the rejectable location.
Contributing Causes:
The original design of this thermowell configuration included a metal o-ring which provided pressure boundary. During thermowell installation, the o- ring was removed to allow fitment for welding. By removing the o-ring, the seal weld became the pressure retaining boundary (see attached figure). The configuration change was reviewed and approved by the NSSS vendor.
CORRECTIVE ACTIONS
Immediate:
1.The extent of condition was addressed with respect to Unit 2. Absence of increased activity on 2EMF38, normal levels in the Ventilation Unit Condensation Drain Tank, and normal levels in the CF&E sump indicates a similar condition does not exist.
2.The affected weld was repaired. The welding was performed to yield a near flush configuration of the boss and thermowell.
3.Visual inspections (VT-2) were performed on RCS loops 1B, 1C and 1D for extent of condition. No additional problems were identified 4.Initiated Corrective Actions to inspect the Unit 2 NC Wide Range Hot Leg RTD configurations and assure the RTDs are added to the Trip List for Unit 2.
Subsequent: None Planned:
1.Determine the seal weld size considering all operating/design loads to preclude leakage on the hot leg wide range thermowell/weld boss joint.
2.Increase the seal weld size on the 1A, 1B, 1C, 1D, 2A, 2B, 2C and 2D hot leg wide range thermowell / weld boss joints, if necessary.
SAFETY ANALYSIS
There were no adverse safety consequences associated with this event.
With the completed repair on thermowell 1NCTW5850, pressure boundary integrity was restored and there are no current operability concerns. Visual inspections (VT-2) have been performed to address the extent of-condition on similar wide range thermowells on 1B, 1C, and 1D hot legs and no evidence of leakage was identified.
With this leak present during Modes 1 - 4, Technical Specification 3.4.13 was not satisfied. No pressure boundary leakage is acceptable. The degraded condition of the thermowell seal weld did not represent a challenge to the nuclear safety of the unit. The configuration of the joint is controlled under all loads by the mating threads and threaded insert installed between the boss and thermowell. The base materials including the threads of the boss and thermowell prevent a catastrophic failure under all conditions.
The seal weld is not credited in resisting loads. The consequences of a complete failure of the seal weld are limited by the structural configuration of the thermowell assembly such that any leak would have no impact on system function and be promptly identified by the leakage detection system.
Leakage from thermowell 1NCTW5850 seal weld did not challenge the nuclear safety of Unit 1. The basis of this conclusion is:
- Leak rates were low, on the order of 0.05 gpm.
- There was no risk of catastrophic failure based on the configuration of the thermowell and welding boss.
- Leakage was promptly identified by the use of existing leakage detection equipment.
- All leakage was maintained within the containment structure.
A risk-informed approach was used to determine the risk significance associated with the pressure boundary leakage.
The Conditional Core Damage Probability (CCDP) and the Conditional Large Early Release Probability (CLERP) of this event was evaluated by considering the following:
- The duration of the LCO non-compliance (approximately 2 months)
- A conservative approach via the use of the average maintenance PRA model to represent plant configuration, equipment unavailability, and maintenance activities.
The CCDP associated with this event was'determined to be less than 1.0E-06.
The CLERP associated with this event is non-limiting with respect to the CCDP and was determined to be less than 1.0E-7.
Given the above, this event was determined to be of no significance to the health and safety of the public.
ADDITIONAL INFORMATION
To determine if a recurring or similar event exists, a search of Catawba's three year history was conducted. There have been no reportable events with respect to failures of the NC system pressure boundary.
This event does not constitute a Safety System Functional Failure.
Adaptor and RTD instrument are not shown.
Thermowel l 1.65" Location of originally specified 0-ring
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| | Reporting criterion |
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Mitigate the Consequences of an Accident 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000498/LER-2010-001 | Unit Shutdown Required by Technical Specifications | 10 CFR 50.73(a)(2)(i)(A), Completion of TS Shutdown | 05000316/LER-2010-001 | Valid Actuation of Auxiliary Feedwater System in Response to Valid Steam Generator Low-Low Levels | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000321/LER-2010-001 | Corrosion Induced Bonding Results in Safety Relief Valve Lift Setpoint Drift | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000336/LER-2010-001 | Millstone Power Station Unit 2 Reactor Trip | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000413/LER-2010-001 | Technical Specification Violation Associated with Failure to Perform Offsite Circuit Verification | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000440/LER-2010-001 | Invalid Isolation Signal Results in Shutdown Cooling Interruption | 10 CFR 50.73(a)(2)(v)(B), Loss of Safety Function - Remove Residual Heat | 05000424/LER-2010-001 | Breaker Failure Results in I B Train Containment Cooling System Being Declared Inoperable | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000416/LER-2010-001 | Automatic Reactor Scram On Decreasing Reactor Water Level Due To Inadvertent Reactor Feed Pump Trip | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000249/LER-2010-001 | OPRM Power Supply Failure during Maintenance Results in Unit 3 Automatic Reactor Scram | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000251/LER-2010-001 | Two Shutdown Bank Rods Were Dropped from Fully Withdrawn Position | 10 CFR 50.73(a)(2)(iv)(A), System Actuation 10 CFR 50.73(a)(2)(iv), System Actuation | 05000261/LER-2010-002 | Plant Trip due to Electrical Fault | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000255/LER-2010-002 | Condition that Could Have Prevented the Fulfillment of a Safety Function | 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 | 05000335/LER-2010-002 | Opened ECCS Boundary Door in Violation of Identified Compensatory Measures | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000334/LER-2010-002 | 270 Degree Circumferential Flaw Found on Residual Heat Removal System Drain Valve Socket Weld | 10 CFR 50.73(a)(2)(v)(B), Loss of Safety Function - Remove Residual Heat 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000316/LER-2010-002 | Containment Divider Barrier Seal Mounting Bolts Not Properly Installed | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000250/LER-2010-002 | Fuel Transfer Pump Failure Renders 3B Emergency Diesel Generator Inoperable | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000269/LER-2010-002 | Manual Reactor Trip due to 1A1 and 1A2 Reactor Coolant PumDHigh Vibration Indication | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000315/LER-2010-002 | Manual Auxiliary Feedwater Actuation in Response to Main Feedpump Failure | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000271/LER-2010-002 | Inoperability of Main Steam Safety Relief Valves due to Degraded Thread Seals | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000277/LER-2010-002 | Improperly Fastened Rod Hanger Results in Inoperable Subsystem of Emergency Service Water | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000413/LER-2010-002 | Discovery of Reactor Coolant System Pressure Boundary Leak at Thermowell 1NCTW5850 Seal Weld. | | 05000282/LER-2010-002 | Postulated Flooding of Unit 1 Fuel Oil Transfer Pump Motor Starters Could Have Resulted In Reduced Fuel Oil Inventory | | 05000414/LER-2010-002 | Duke Energy Corporation Catawba Nuclear Station 4800 Concord Road York, SC 29745 803-701-4251 803-701-3221 fax December 15, 2010 U.S. Nuclear Regulatory Commission
Attention: Document Control Desk
Washington, D.C. 20555
Subject:�Duke Energy Carolinas, LLC (Duke Energy)
Catawba Nuclear Station, Unit 2
Docket No. 50-414
Licensee Event Report 414/2010-002
Pursuant to 10 CFR 50.73(a)(1) and (d), attached is Licensee Event Report 414/2010-002, Revision 0 entitled, "Technical Specification Violation Involving Mode Change with Inoperable Auxiliary Feedwater System Train Due to Closed Pump Discharge Valves". This report is being submitted in accordance with 10 CFR 50.73(a)(2)(i)(B). 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. Sincerely, faius4- A James R. Morris LJR/s Attachment www.duke-energy.corn (14 Document Control Desk Page 2 December 15, 2010 xc (with attachment): L.A. Reyes 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, Ill NRC Senior Resident Inspector Catawba Nuclear Station INPO Records Center 700 Galleria Place Atlanta, GA 30339-5957 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 infocollectssesource@nre.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(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 info(mation collection. 1.. FACILITY NAME 2. DOCKET NUMBER I3. PAGE Catawba Nuclear Station, Unit 2 05000414 1 OF 7 4. TITLE Technical Specification Violation Involving Mode Change with Inoperable Auxiliary Feedwater System Train Due to Closed Pump Discharge ValvesD • | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000306/LER-2010-002 | Unit 2 Turbine Shutdown Due To the Loss of a Main Feed Water Pump That Resulted in a Reactor Scram | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000440/LER-2010-002 | Piping Leak Results in Condition Prohibited by Technical Specifications | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000382/LER-2010-002 | Main Feedwater Isolation Valve B exceeded allowed outage time due to tubing connection failure | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000370/LER-2010-002 | ref Energy® REGIS T. REPKO Vice President McGuire Nuclear Station Duke Energy MGO1VP / 12700 Hagers Ferry Rd. Huntersville, NC 28078 980-875-4111 980-875-4809 fax regis.repko(Codu ke-energy.corn 10 CFR 50.73 May 10, 2011 U.S. Nuclear Regulatory Commission ATTENTION: Document Control Desk Washington, D.C. 20555 Subject: D Duke Energy Carolinas, LLC McGuire Nuclear Station, Unit 2 Docket Nos. 50-370 Licensee Event Report (LER) 370/2010-02, Supplement 1 Problem Investigation Process (PIP) M-10-05982 Pursuant to 10 CFR 50.73 Sections (a) (1) and (d), attached is Supplement 1 to Licensee Event Report 370/2010-02, regarding past inoperability of the Unit 2 "A" Train Nuclear Service Water System and satisfies the commitment to supplement the LER following completion of the root cause analysis This supplement to LER 370/2010-02 supersedes the LER previously submitted December 20, 2010. Completion of the root cause analysis has not affected the original reporting criteria which was completed in accordance with 10 CFR 50.73 (a) (2) (i) (B), an Operation Prohibited by Technical Specifications, and 10 CFR 50.73 (a) (2) (v) (B), any Event or Condition That Could Have Prevented Fulfillment of the Safety Function needed to remove residual heat. Additionally, the supplement did not affect the significance of the event which was considered to be of no significance with respect to the health and safety of the public. There are no regulatory commitments contained in this report. If questions arise regarding this LER, contact Rick Abbott at 980-875-4685. Very truly yours, Zi1:77 Regis T. Repko Attachment www. duke-energy. corn U.S. Nuclear Regulatory Commission May 10, 2011 Page 2 cc:�V. M. McCree, Regional Administrator U.S. Nuclear Regulatory Commission, Region II
Marquis One Tower
245 Peachtree Center Ave., NC, Suite 1200
Atlanta, Georgia 30303-1257
Jon H. Thompson (Addressee Only)
Senior Project Manager (McGuire)
U.S. Nuclear Regulatory Commission
11555 Rockville Pike
Rockville, MD 20852-2738
J. B. Brady
Senior Resident Inspector
U.S. Nuclear Regulatory Commission
McGuire Nuclear Station
W. L. Cox Ill, Section Chief North Carolina Department of Environment and Natural Resources Division of Environmental Health Radiation Protection Section 1645 Mail Service Center Raleigh, NC 27699-1645 NRC FORM 366 U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB. NO 3150-0104 EXPIRES: 08/31/2013 (10-2010) Estimated burden per response to comply with this mandatory collection request: SO hours. Reported 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 info (See reverse for required number of collects resmirceOnrc.gov, and to the Desk Officer, Office of Information and Regulatory digits/characters for each block) Affairs, NEOB-10202, (3150-01041, 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. LICENSEE EVENT REPORT (LER) 1. FACILITY NAME 2. DOCKET NUMBER 3. PAGE McGuire Nuclear Station,2Unit 2 05000-212
0370 OF-7 4. TITLE Unit 2 Nuclear Service Water System "A" Train Past Inoperable due to
Failed Strainer Differential Pressure Instrument. | 10 CFR 50.73(a)(2)(v)(B), Loss of Safety Function - Remove Residual Heat 10 CFR 50.73(a)(2)(v), Loss of Safety Function 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000369/LER-2010-002 | | | 05000456/LER-2010-002 | Limiting Condition for Operation Action Not Completed Within the Required Time | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000249/LER-2010-003 | Steam Leak Results in HPCI Inoperability | 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident | 05000251/LER-2010-003 | Damaged Speed Sensor Caused the 4A Emergency Diesel Generator to be Inoperable | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications |
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