On January 27, 2005, during scheduled testing in accordance with Surveillance Test Procedure M-77, "Safety and Relief Valve Testing," Pacific Gas and Electric Company ( PG&E) identified two of three pressurizer safety valves (PSVs) outside the Technical Specification (TS) 3.4.10, "Pressurizer Safety Valves, ... lift setting of ?2460 and and 3.6 percent low, and within analyzed safety limits; thus, this condition did not adversely affect the health and safety of the public.
The PSVs were disassembled, inspected, and reset within the TS 3.4.10 lift setting requirements.
PG&E believes the cause of the PSVs being outside the TS allowance is random lift spread.
PSV lift setting repeatability has been recognized as an industry-wide problem. PG&E has participated in extensive investigative test programs, both jointly with the nuclear steam supply system vendor, Westinghouse Owners Group, and independently. The results of the industry investigations are documented in WCAP-12910, "Pressurizer Safety Valve Set Pressure.
PG&E has reanalyzed PSV capability, revised TS 3.4.10 bases, and enhanced the PSV testing procedures consistent with the revised analysis criteria. |
LER-2005-001, TS 3.4.10 Not Met During Pressurizer Safety Valve Surveillance Testing Due to Random Lift SpreadDocket Number |
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10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications |
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3232005001R01 - NRC Website |
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I. Plant Conditions
Unit 2 has operated in various plant modes with the described condition.
II. Description of Problem
A. Background
Technical Specification (TS) 3.4.10, "Pressurizer Safety Valves" (PSVs), requires that three PSVs [AWN/ shall be operable with a lift setting greater than or equal to 2460 psig and less than or equal to 2510 psig corresponding to ambient conditions of the valve at nominal operating temperature and pressure. This upper and lower pressure limit is based on a nominal pressure of 2485 psig, with an upper and lower tolerance limit of plus or minus one percent. TS 3.4.10 and associated bases did not discuss the as-found testing analysis limits for the PSVs.
Surveillance Test Procedure (STP) M-77, "Safety and Relief Valve Testing," verifies the PSV's lift setting in accordance with the requirements of the ASME Boiler and Pressure Vessel Code, Section Xl.
The initial (as-found) lift setting is evaluated for TS compliance.
STP M-77 requires that the valves lift within the required tolerance in order to declare them operable.
STP M-77 test methodology obtains the as-found lift setting by placing the PSVs in an environmentally controlled enclosure and heating the ambient air to the temperature conditions typical at Diablo Canyon Power Plant (DCPP). The loop seal is also heated to simulate the piping temperature conditions at DCPP. Testing is accomplished by the addition of steam at a defined ramp rate. Steam is added until physical evidence of stem movement is visible on the remote data acquisition display screen. The data is then reviewed to ascertain first discernible stem movement and the pressure at which it took place.
El.�Event Description Following the Unit 1 eleventh refueling outage in May 2002, the subject PSVs lift settings were verified to be within the range required by TS 3.4.10. The PSVs were then returned to warehouse stock. During the Unit 2 eleventh refueling outage in February 2003, these three PSVs were placed in service in Unit 2 without any additional adjustment of the lift settings. The valves were replaced during the Unit 2 twelfth refueling outage in November 2004 and tested offsite in January 2005.
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3) Diablo Canyon Unit 2 0 5 0 0 0 3 2 3 2005 0 0 1 0 1 3 OF On January 27, 2005, during scheduled offsite testing in accordance with STP M-77, "Safety and Rellief Valve Testing," Pacific Gas and Electric Company (PG&E) identified two of three PSVs outside the TS 3.4.10, "Pressurizer Safety Valves, ... lift setting of >2460 and initial lift settings were 4.4 and 3.6 percent low. The second valve lifts of these same two PSVs were found to be 3.1 percent low and 0.3 percent low, respectively.
PSV lift setting repeatability has been recognized as an industry-wide problem. PG&E has participated in extensive investigative test programs, both jointly with the nuclear steam supply system vendor, Westinghouse Owners Group, and independently. The results of the industry investigations are documented in WCAP-12910, "Pressurizer Safety Valve Set Pressure.
C. Inoperable Structures, Systems, or Components that Contributed to the
Event
None.
D. Other Systems or Secondary Functions Affected None.
E. Method of Discovery This condition was identified during routine scheduled testing of the three PSVs performed in accordance with STP M-77 at the offsite testing facility.
F. Operator Actions None.
G. Safety System Responses None.
Ill.�Cause of the Problem A.�Immediate Cause Two of three PSVs did not lift within the TS 3.4.10 lift setting tolerance.
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3) Diablo Canyon Unit 2 0 5 0 0 0 3 2 3 2005 0 0 1 0 1 4 OF 13.CRoot Cause The cause of the as-found lift setting has been determined to be random lift spread.
C. Contributory Cause None.
IV. Assessment of Safety Consequences
The limiting event for evaluating the lift setting is the loss of load analysis that requires the maximum reactor coolant system (RCS) pressure of 2750 psia not be exceeded. The RETRAN computer model was run to determine if, with the as-found PSV lift setpoint, the RCS pressure would exceed 110 percent of ASME design acceptance criteria, or 2750 psia. The analysis confirmed that the as-found set points would have maintained adequate RCS pressure relief capacity, such that the plant remained bounded by the limiting loss of load analysis provided in Final Safety Analysis Report Update, Section 15.2.7, "Loss of External Electrical Load and/or Turbine Trip." Also, the as-found lift setting was reviewed for potential interaction with the pressurizer power-operated relief valves and the potential for inadvertent low pressure lifting, and were found acceptable.
Therefore, this event was of very low risk significance, was not a Safety System Functional Failure, and did not adversely affect the health and safety of the public.
V. Corrective Actions
A.CImmediate Actions The valves were disassembled, inspected, reset within tolerance, and returned to warehouse stock. No degraded PSV condition was identified.
El.CCorrective Actions 1. PG&E has revised the loss-of-load analysis to determine the upper and lower as-found allowable PSV lift setting. This reanalysis formed the technical basis for a change in the acceptance criteria utilized for the evaluation of the as-found lift setting of the PSVs.
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3) Diablo Canyon Unit 2 0 5 0 0 0 3 2 3 2005 0 0 1 0 1 5 OF 2. PG&E has updated the TS 3.4.10 bases to reflect the above reanalysis conditions and establish the as-found surveillance test criteria.
3. PG&E has revised STP M-77 to reflect the applicable testing conditions and as-found lift setting criteria in the revised TS 3.4.10 bases.
VI.�Additional Information A.�Failed Components None.
E3.�Previous Similar Events Licensee Event Report (LER) 1-94-009, Revision 2, submitted in PG&E Letter DCL-95-248, dated November 7, 1995, regarding PSVs found outside TS limits during the Unit 1 sixth refueling outage. The root cause of this event was determined to be random lift-setting spread. No corrective action to prevent recurrence was required because this inherent characteristic of the valve was within the analysis basis of DCPP.
seventh refueling outage. The root cause of this event was determined to be random lift setting spread. No corrective action to prevent recurrence was required because this inherent characteristic of the valve was within the analysis basis of DCPP.
August 27, 2001, regarding one PSV found 3.4 percent low and one PSV found 2.8 percent high during offsite testing. The root cause of this event was determined to be random lift-setting spread. No corrective action to prevent recurrence was required because this inherent characteristic of the valve was within the analysis basis of DCPP.
August 9, 2002, regarding one PSV found 1.9 percent low and one PSV found 2.6 percent high during offsite testing. The root cause of this event was determined to be random lift-setting spread. No corrective action to prevent recurrence was required because this inherent characteristic of the valve was within the analysis basis of DCPP.
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Mitigate the Consequences of an Accident 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000361/LER-2005-002 | Missing Taper Pins on CCW Valve Cause Technical Specification Required Shutdown | 10 CFR 50.73(a)(2)(i)(A), Completion of TS Shutdown | 05000370/LER-2005-002 | Ice Condenser Lower Inlet Door Failed Surveillance Testing | | 05000353/LER-2005-002 | High Pressure Coolant Injection System Inoperable due to a Degraded Control Power Fuse Clip | 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident | 05000263/LER-2005-002 | | | 05000454/LER-2005-002 | One of Two Trains of Hydrogen Recombiners Inoperable Longer Than Allowed by Technical Specifications Due to Inadequate Procedure | | 05000244/LER-2005-002 | Emergency Diesel Generator Start Resulting From Loss of Off-Site Power Circuit 751 | | 05000362/LER-2005-002 | Emergency Containment Cooling Inoperable for Longer than Allowed by Technical Specifications | 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 | 05000247/LER-2005-002 | DTechnical Specification Prohibited Condition Due to Exceeding the Allowed Completion Time for One Inoperable Train of ECCS Caused by Gas Intrusion from a Leaking Check Valve | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000306/LER-2005-002 | | 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 10 CFR 50.73(a)(2)(i)(A), Completion of TS Shutdown | 05000265/LER-2005-002 | Main Steam Relief Valve Actuator Degradation Due to Failure to Correct Vibration Levels Exceeding Equipment Design Capacities | 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident 10 CFR 50.73(a)(2)(vii), Common Cause Inoperability 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications 10 CFR 50.73(a)(2)(i)(A), Completion of TS Shutdown | 05000286/LER-2005-002 | • Entergy Nuclear Northeast Indian Point Energy Center 450 Broadway, GSB P.O. Box 249Entergy Buchanan. NY 10511-0249 Tel 914 734 6700 Fred Dacimo Site Vice President Administration July 5, 2005 Indian Point Unit No. 3 Docket Nos. 50-286 N L-05-078 Document Control Desk U.S. Nuclear Regulatory Commission Mail Stop O-P1-17 Washington, DC 20555-0001 Subject:L Licensee Event Report # 2005-002-00, "Automatic Reactor Trip Due to 32 Steam Generator Steam Flow/Feedwater Flow Mismatch Caused by Low Feedwater Flow Due to Inadvertent Condensate Polisher Post Filter Bypass Valve Closure." Dear Sir: The attached Licensee Event Report (LER) 2005-002-00 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-IP3-2005-02478. 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. Sincerely, 4F-/t R. Dacimo Vice President Indian Point Energy Center Docket No. 50-286 NL-05-078 Page 2 of 2 Attachment: LER-2005-002-00 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 3660 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.RReported lessons teamed 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 29555-0001, or by InternetLICENSEE EVENT REPORT (LER) e-mail to Infocoilectsenrc.gov, and to the Desk Officer, Office of Information and Regulatory Affairs, NEOB-l0202, (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. FACIUTY NAME 2. DOCKET NUMBER 3. PAGE INDIAN POINT 3 05000-286 10OF06 4. TITLE Automatic Reactor Trip Due to 32 Steam Generator Steam Flow/Feedwater Flow Mismatch Caused by Low Feedwater Flow Due to Inadvertent Condensate Polisher Post Filter Bypass Valve Closure | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000287/LER-2005-002 | Unit 3 trip with ES actuation due to CRD Modification Deficiencies | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000336/LER-2005-002 | | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications |
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