3-1-2007 | On October 7, 2006, with the plant in Mode 1, in-place testing of main steam safety valve 3508 determined that the as-found lift pressure did not meet the acceptance band of +1% / - 3% of setpoint (1085 psig), as specified by Technical Specification surveillance SR 3.7.1.1. This was the second unsatisfactory as-found lift pressure for a main steam safety valve, as in-place sequential testing had previously determined that safety valve 3515 had failed to meet the as-found acceptance band.
Technical Specification LCO 3.7.1, "Main Steam Safety Valves (MSSVs)", requires eight main steam safety valves to be operable in Modes 1, 2 and 3. Since the two unsatisfactory as-found lift pressures may have arisen over a period of time (found during sequential testing), it is assumed that at least one required main steam safety valve was not operable during past plant operation for a time greater than allowed. Therefore, this occurrence is considered reportable in accordance with 10 CFR 50.73(a)(2)(i)(B) as a condition prohibited by the plant's Technical Specifications.
The apparent cause of the set point drift in the MSSVs is additional friction in the spindle guide area.
Corrective action to address the condition is outlined in Section V.
Operation of the facility with the main steam safety valves as-found settings was within analytical bounds; therefore, this event had no impact on the health and safety of the public. |
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I. PRE-EVENT PLANT CONDITIONS:
At the time the condition was identified, the plant was in Mode 1 at approximately 90% rated thermal power.
II. DESCRIPTION OF EVENT:
A. � EVENT:
On October 7, 2006, with the plant in Mode 1, in-place testing of main steam safety valve 3508 determined that the as-found lift pressure did not meet the acceptance band of +1% / - 3% of setpoint, as specified by Technical Specification surveillance SR 3.7.1.1. The initial as-found lift pressure for safety valve 3508 was 1.39% above the specified lift setting. This was the second unsatisfactory as- found lift pressure for a main steam safety valve, as in-place testing had previously determined that safety valve 3515 had failed to meet the as-found acceptance band, with an initial as-found lift pressure of 1.09% above the specified lift setting. All of the other valves were tested within range, but at an elevated lift setpoint when compared to their previous as-left value.
Technical Specification LCO 3.7.1 requires eight main steam safety valves to be operable in Modes 1, 2 and 3. Testing of main steam safety valves is performed one valve at a time, with each valve adjusted if necessary and returned to operable status before proceeding with the testing of another valve. In this manner, a maximum of one valve is known to be inoperable at any time during testing.
However, since the cause of the two unsatisfactory as-found lift pressures may have arisen over a period of time, it is assumed that at least one required main steam safety valve was not operable during past plant operation for a time greater than allowed. Therefore, this occurrence is considered reportable in accordance with 10 CFR 50.73(a)(2)(i)(B) as a condition prohibited by the plant's Technical Specifications.
B. INOPERABLE STRUCTURES, COMPONENTS, OR SYSTEMS THAT CONTRIBUTED TO
THE EVENT:
None
C. DATES AND APPROXIMATE TIMES OF MAJOR OCCURENCES:
October 7, 2006, 1240 EDST: main steam safety valve 3515 removed from service for lift setpoint testing and returned to service following adjustment.
- October 7, 2006, 1445 EDST: main steam safety valve 3508 removed from service for lift setpoint testing and returned to service following adjustment.
D. OTHER SYSTEMS OR SECONDARY FUNCTIONS AFFECTED:
None
E. METHOD OF DISCOVERY:
Review of test data associated with as-found setpoint testing.
F. SAFETY SYSTEM RESPONSES:
No safety systems were actuated.
III. CAUSE OF EVENT:
The apparent cause of the set point drift in the MSSVs is additional friction in the spindle guide area.
The additional friction can be caused by a reduced clearance between the spindle point and the guide bearing and/or a collection of dirt and other debris in this area. It has been determined by the manufacturer that there is a tendency for the bearing material to close up on the spindle point over time. Additional operating experience associated with MSSVs was recently issued by the NRC in Information Notice 2006-24, Recent Operating Experience Associated with Pressure and Main Steam Safety/Relief Valve Lift Setpoints.
IV. ASSESSMENT OF THE SAFETY CONSEQUENCES OF THE EVENT:
This event is reportable in accordance with 10 CFR 50.73, Licensee Event Report System, item (a)(2)(i)(B), which requires a report of, "Any operation or condition which was prohibited by the plant's Technical Specifications.
The operability of the main steam safety valves ensures that the secondary system pressure will be limited to within 110% of its design pressure of 1085 psig during the most severe anticipated system operational transient. The as-found condition of the main steam safety valves was compared to the current overpressure analysis prepared in support of extended power uprate and it was concluded that the analysis remained bounding. This analysis is conservative with regards to prior operation. As such, the applicable acceptance criteria for design basis events would have been met and the safety valves remained capable of performing their intended safety function.
Operation of the facility with the main steam safety valves as-found settings was within analytical bounds; therefore, this event had no impact on the health and safety of the public.
V.�CORRECTIVE ACTIONS:
A. ACTION TAKEN TO RETURN AFFECTED SYSTEMS TO PRE-EVENT NORMAL STATUS:
Immediate actions included adjusting main steam safety valves 3513 and 3508 to within +/-1% of their required set lift pressure.
The main steam safety valves were subsequently tested on October 31, 2006 during the plant startup from the refueling outage, and all of the valves exhibited a reduced as-found setpoint (within the +1% / - 3% allowed range).
B. ACTION TAKEN OR PLANNED TO PREVENT RECURRENCE:
A training session was held at the MSSV manufacturer's facility, which included verification testing of the identical Set Point Verification Device used at Ginna on October 7, 2006, as well as set point testing of an identical safety valve while simulating the Ginna conditions.
- The MSSVs will be evaluated for refurbishment during an upcoming refueling outage on a valve specific basis, based on vendor recommendations and analysis of test data.
VI.�ADDITIONAL INFORMATION:
A. FAILED COMPONENTS:
No other structures, systems, or components failed as result of this event.
B. PREVIOUS LERs ON SIMILAR EVENTS:
A similar Ginna LER event historical search was conducted which resulted in no similar events.
C. THE ENERGY INDUSTRY IDENTIFICATION SYSTEM (EIIS) COMPONENT FUNCTION
IDENTIFIER AND SYSTEM NAME OF EACH COMPONENT OR SYSTEM REFERRED TO IN
THIS LER:
COMPONENT IEEE 803 � IEEE 805 FUNCTION NUMBER�SYSTEM IDENTIFICATION Valve, Relief RV� SB
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05000305/LER-2006-010 | | | 05000456/LER-2006-001 | Unit 1 Reactor Coolant System Pressure Boundary Leakage Due To Inter-Granular Stress Corrosion Cracking of a Pressurizer Heater Sleeve | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications 10 CFR 50.73(a)(2)(ii)(A), Seriously Degraded | 05000454/LER-2006-001 | Technical Specification Required Action Completion Time Exceeded for Inoperable Containment Isolation Valves Due to Untimely Operability Determination | | 05000423/LER-2006-001 | Loss Of Safety Function Of The Control Room Emergency Ventilation System | 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident | 05000369/LER-2006-001 | Ice Condenser and Floor Cooling System Containment Isolation Valve inoperable longer than allowed by Technical Specification 3.6.3. | | 05000353/LER-2006-001 | HPCI Ramp Generator Signal Converter 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)(v), Loss of Safety Function | 05000352/LER-2006-001 | Loss Of One Offsite Circuit Due To Invalid Actuation Of Fire Suppression System | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000336/LER-2006-001 | | 10 CFR 50.73(a)(2)(v)(A), Loss of Safety Function - Shutdown the Reactor | 05000316/LER-2006-001 | Failure to Comply with Technical Specification 3.6.2, Containment Air Locks | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000315/LER-2006-001 | Plant Shutdown Required by Technical Specification Action 3.6.5.B.1 | | 05000293/LER-2006-001 | | 10 CFR 50.73(a)(2)(iv), System Actuation | 05000289/LER-2006-001 | | | 05000287/LER-2006-001 | Actuation of Emergency Generator due to Spurious Transformer Lockout | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000251/LER-2006-001 | Turkey Point Unit 4 05000251 1 OF 6 | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000247/LER-2006-001 | Manual Reactor Trip Due to Multiple Dropped Control Rods Caused by Loss of Control Rod Power Due to Personnel Error | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000440/LER-2006-001 | Incorrect Wiring in the Remote Shutdown Panel Results in a Fire Protection Program Violation | | 05000413/LER-2006-001 | | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000368/LER-2006-001 | Completion of a Plant Shutdown Required by Technical Specifications Due to Loss of Motive Power to Certain Containment Isolation Valves as a Result of a Phase to Ground Short Circuit in a Motor Control Cubicle | 10 CFR 50.73(a)(2)(i)(A), Completion of TS Shutdown | 05000306/LER-2006-001 | | 10 CFR 50.73(a)(2)(v), Loss of Safety Function 10 CFR 50.73(a)(2)(i)(A), Completion of TS Shutdown | 05000298/LER-2006-001 | Cooper Nuclear Station 05000298 1 of 4 | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000286/LER-2006-001 | I | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000282/LER-2006-001 | | 10 CFR 50.73(a)(2)(iv)(A), System Actuation 10 CFR 50.73(a)(2)(v), Loss of Safety Function | 05000266/LER-2006-001 | | 10 CFR 50.73(a)(2)(v), Loss of Safety Function | 05000261/LER-2006-001 | Manual Reactor Trip Due to Failure of a Turbine Governor Valve Electro-Hydraulic Control Card | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000255/LER-2006-001 | | 10 CFR 50.73(a)(2)(ii)(B), Unanalyzed Condition | 05000461/LER-2006-002 | Turbine Bypass Function Lost Due to Circuit Card Maintenance Frequency | | 05000458/LER-2006-002 | Loss of Safety Function of High Pressure Core Spray Due to Manual Deactivation | | 05000456/LER-2006-002 | Units 1 and 2 Entry into Limiting Condition for Operation 3.0.3 due to Main Control Room Ventilation Envelope Low Pressure | | 05000443/LER-2006-002 | Noncompliance with the Requirements of Technical Specification 6.8.1.2.a | | 05000387/LER-2006-002 | DMissed Technical Specification surveillance requirement | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000362/LER-2006-002 | Unit 3 Shutdown to Inspect Safety Injection Tank Spiral Wound Gaskets | | 05000336/LER-2006-002 | Manual Reactor Trip Due To Trip Of Both Feed Pumps Following A Loss Of Instrument Air | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000316/LER-2006-002 | | 10 CFR 50.73(a)(2)(vii), Common Cause Inoperability 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000315/LER-2006-002 | Failure to Comply with Technical Specification Requirement 3.6.13, Divider Barrier Integrity | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000293/LER-2006-002 | | | 05000289/LER-2006-002 | | | 05000251/LER-2006-002 | Intermediate Range High Flux Trip Setpoint Exceeded Technical Specification Allowable Value | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000440/LER-2006-002 | Scaffold Built in the Containment Pool Swell Region | 10 CFR 50.73(a)(2)(ii)(B), Unanalyzed Condition | 05000413/LER-2006-002 | Safe Shutdown Potentially Challenged by an External Flooding Event and Inadequate Design and Configuration Control | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000388/LER-2006-002 | Missed Technical Specification LCO 3.8.1 Entry for Unit 2 During Unit 1 ESS Bus Testing | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000348/LER-2006-002 | Main Steam Isolation Valve Failure to Close | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000305/LER-2006-002 | | 10 CFR 50.73(a)(2)(v)(C), Loss of Safety Function - Release of Radioactive Material 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000301/LER-2006-002 | | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000286/LER-2006-002 | 450 Broadway, GSB P.O. Box 249 Buchanan, N.Y. 10511-0249Entergy Tel (914) 734-6700 Fred Dacimo Site Vice President Administration September 13, 2006 Indian Point Unit No. 3 Docket No. 50-286 N L-06-084 Document Control Desk U.S. Nuclear Regulatory Commission Mail Stop O-P1-17 Washington, DC 20555-0001 Subject:L Licensee Event Report # 2006-002-00, "Manual Reactor Trip as a Result of Arcing Under the Main Generator Between Scaffolding and Phase A&B of the Isophase Bus Housing" Dear Sir: The attached Licensee Event Report (LER) 2006-002-00 is the follow-up written report submitted in accordance with 10 CFR 50.73. This event is of the type defined in 10 CFR 50.73(a)(2)(iv)(A) for an event recorded in the Entergy corrective action process as Condition Report CR-IP3-2006-02255. There are no commitments contained in this letter. Should you or your staff have any questions regarding this matter, please contact Mr. Patric W. Conroy, Manager, Licensing, Indian Point Energy Center at (914) 734-6668. Fred R. Dacimo Site Vice President Indian Point Energy Center Docket No. 50-286 NL-06-084 Page 2 of 2 Attachment: LER-2006-002-00 CC: Mr. Samuel J. Collins Regional Administrator — Region I U.S. Nuclear Regulatory Commission U.S. Nuclear Regulatory Commission Resident Inspector's Office Resident Inspector Indian Point Unit 3 Mr. Paul Eddy State of New York Public Service Commission INPO Record Center NRC FORM 366 U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB NO. 3150-0104 EXPIRES: 06/30/2007
(6-2004)
. Estimated burden per response to comply with this mandatory collection request: 50 hours.DReported lessons learned are incorporated into the licensing process and fed back to industry. Send comments regarding burden estimate to the Records and FOIA/Privacy Service Branch (T-5 F52), U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001, or by internetLICENSEE EVENT REPORT (LER) e-mail to infocollects@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. ■ 1. FACILITY NAME 2. DOCKET NUMBER I 3. PAGE
INDIAN POINT 3 05000-286 1 OF 6
4.TITLE: Manual Reactor Trip as a Result of Arcing Under the Main Generator Between
Scaffolding and Phase A&B of the Iso-phase Bus Housing | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000282/LER-2006-002 | | 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-2006-002 | High Energy Line Breaks Outside Licensing Basis May Result in Loss of Safety Function | | 05000263/LER-2006-002 | | | 05000255/LER-2006-002 | | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000254/LER-2006-002 | Quad Cities Nuclear Power Station Unit 1 05000254 1 of 3 | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000483/LER-2006-003 | Unexpected Inoperability of the Emergency Exhaust System due to Inoperable Pressure Boundary | 10 CFR 50.73(a)(2)(v)(C), Loss of Safety Function - Release of Radioactive Material 10 CFR 50.73(a)(2)(vii), Common Cause Inoperability 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications |
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