05000251/LER-2010-004
| Docket Number Sequential Revmonth Day Year Year Month Day Yearnumber No. | |
| Event date: | 09-08-2010 |
|---|---|
| Report date: | 11-05-2010 |
| Reporting criterion: | 10 CFR 50.73(a)(2)(iv)(B), System Actuation 10 CFR 50.73(a)(2)(iv)(A), System Actuation |
| Initial Reporting | |
| ENS 46235 | 10 CFR 50.72(b)(2)(iv)(B), RPS System Actuation, 10 CFR 50.72(b)(3)(iv)(A), System Actuation |
| 2512010004R00 - NRC Website | |
DESCRIPTION OF THE EVENT
On September 8, 2010, with Unit 4 operating at 100% power, an unplanned automatic reactor trip occurred at approximately 13:45 during replacement of the 4B Reactor Protection System (RPS) Left Turbine Stop Valve Closure Logic Relay 4-SL-X-B [JC:RLY]. All systems responded as designed and the unit was stabilized in Mode 3 on normal off-site power. Auxiliary Feedwater automatically initiated when Steam Generator levels lowered below the actuation setpoint. When Steam Generator levels were stabilized within the normal operating band, Auxiliary Feedwater was secured. Normal Feedwater was re-established to the Steam Generators and decay heat was removed via the turbine bypass valves to the condenser. Relay 4-SL- X-B was replaced and the unit was returned to service upon validation that the cause of the trip was not equipment-related.
At 15:52. an 4-hour report (EN 46235) was made to the NRC Operations Center in accordance with 10 CFR 50.72(b)(2)(iv)(B) due to actuation of the Reactor Protection System with the reactor critical and 10 CFR 50.72(b)(3)(iv)(A) due to a valid actuation of the Auxiliary Feedwater System, an Emergency Safeguards System. This event was entered into the Corrective Action Program as AR 578473578473
ANALYSIS OF THE EVENT
On September 8, 2010 at 0857, Operations commenced the performance of 4-0SP-049.1 "Reactor Protection System Logic Test." At this time, Operations closed the reactor trip bypass breaker 4B and entered a planned 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> action statement per Technical Specification (TS) 3/4.3.1 to perform the surveillance. TS 3/4.3.1, Reactor Trip System Instrumentation, Table 3.3-1, Functional Unit 19, Reactor Trip Breakers, Action 8 allows bypassing one channel for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing, provided the other channel is operable, otherwise, the unit must be in Hot Standby within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
At 0948, during performance of the 4-0SP-049.1, the 4B RPS Left Turbine Stop Valve Closure Logic Relay 4-SL-X-B responded as expected during testing but did not respond as expected during the reset portion of the evolution when it did not return to its energized position immediately. As a result, the station entered an unplanned 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> action statement per Technical Specification 3.3.1, Table 3.3-1, Functional Unit 15.b, Turbine Stop Valve Closure, Action 12. Action 12 allows continued power operation until performance of the next required actuation logic test provided the inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. Operations continued performing the surveillance testing of the RPS per 4-0SP-049.1 in parallel of the troubleshooting activities for relay 4-SL-X-B.
At 10:57, with the 4B reactor trip bypass breaker still in the closed position, Operations exited the surveillance testing exception of Table 3.3-1, Functional Unit 19, Reactor Trip Breakers, Action 8 and entered the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> shutdown action portion of Action 8. At 10:58 the 4B reactor trip bypass breaker was opened in accordance with 4-0SP-049.1 and Action 8 was exited.
Troubleshooting activities revealed that relay 4-SL-X-B was exhibiting possible armature binding, an age- related degradation, and it required replacement. Therefore, at 11:05 Operations commenced the performance of 4-0NOP-049.1, Deviation or Failure of Safety Related or Reactor Protection Channels, due to the failure of relay 4-SL-X-B.
At 12:25, relay 4-SL-X-B was placed in the tripped condition in accordance with the requirements of Table 3.3-1, Functional Unit 15.b, Action 12. As a result, the station exited the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> portion of the action statement per Technical Specification 3.3.1, Table 3.3-1, Functional Unit 15.b, Turbine Stop Valve Closure, Action 12. Action 12 allows continued power operation until performance of the next required actuation logic test provided the inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
Replacement of the degraded relay 4-SL-X-B was started in accordance to work order 39011940-01. Using 0-GMI-049.1 "Testing and Replacement of BFD/NBFD Relays in Reactor Protection and Safeguards Systems," Maintenance lifted the leads on Terminal 1 of Relay 4-SL-X-B. At 13:45, the Unit 4 Reactor tripped as a result of lifting the leads. The reactor trip was caused by the opening of the 4B RPS trip breaker due to the de-energizing of reactor trip relays RT-9 and RT-10 when the two leads were lifted off terminal 1 of relay 4-SL-X-B during the replacement evolution and with the 4B reactor trip bypass breaker open.
0-GMI-049.1 requires replacement of the relay per work order 39011940. Work order 39011940-01 used in the replacement of relay 4-SL-X-B is a generic contingency work order planned to replace any RPS relay.
The work order did not have a step requiring verification of plant conditions prior to performing the work.
This is contrary to the requirements and guidance in 0-ADM-701.1, "Desktop Instructions for PWO Planning and Assembly of Work Packages," which requires that work orders establish the plant conditions required to do the work. In addition, 0-GMI-049.1 did not have a step requiring verification that the Reactor Trip Bypass Breaker was in the closed position prior to commencing replacement of the RPS relay 4-SL-X- B. Although the procedure and work order did not require verification of plant conditions prior to performing the work, personnel involved with the task had the knowledge that the reactor trip bypass breaker was required to be in the closed position to prevent a reactor trip during the replacement of 4-SL-X- B relay. Restoration of the reactor trip bypass breaker to the racked out and open position was completed by Operations at 10:58, as required by 4-0SP-049.1. Maintenance and Engineering personnel did not specifically verify the position of the Reactor Trip Bypass Breaker before starting the relay replacement. In addition, Operations personnel authorized the RPS relay replacement without identifying the required plant conditions had been established to perform the work. Maintenance and Engineering made the assumption that if Operations authorized the work, then the Reactor Trip Bypass Breaker was in the required closed position.
CAUSE OF THE EVENT
The event was evaluated to determine the root cause and contributing causal factors. There were two root causes identified for the event:
1. Deficiencies in the work order package and guiding procedure failed to establish and/or verify the plant conditions required to successfully complete the evolution and relied on Operations staffing to provide the validation that the evolution could be performed.
2. The station failed to meet the standard of excellence expected for communication, accountability, ownership, formality, and rigor resulting in no one group having the full picture required to successfully complete the evolution.
REPORTAB ILITY
The event is reportable in accordance with 10 CFR 50.73(a)(2)(iv)(A) due to automatic actuation of the Reactor Protection System when an unplanned reactor trip occurred during replacement of degraded RPS turbine stop valve relay 4-SL-X-B. It is also reportable in accordance with 10 CFR 50.73(a)(2)(iv)(B) due to automatic actuation of the Auxiliary Feedwater system:
ANALYSIS OF SAFETY SIGNIFICANCE
The plant responded as expected to the automatic reactor trip. The Auxiliary Feedwater system actuated on low steam generator level as designed and the plant was stabilized in Mode 3. All systems functioned as required; therefore, there was no impact on safety. Upon validation that the cause of the trip was not equipment-related, the unit was restarted per the appropriate procedures.
CORRECTIVE ACTIONS
Short Term 1. The degraded 4-SL-X-B relay was replaced prior to unit restart.
2. The following compensatory actions were implemented:
- The generic work order requires that the Reactor Trip Bypass Breaker be in the closed position when replacing any reactor protection relay while the unit is in operational Modes 1 or 2.
- The generic work order requires that the position of the Reactor Trip Bypass Breaker be independently verified.
- The site leadership team was briefed on the event and failure to meet expectations.
Long Term Corrective Actions 1. The work order preparation checklist in 0-ADM-701.1 will be updated with a requirement that the work order meet one of the following three requirements:
1. The procedure specifies the required plant conditions, or 2. The work order establishes the required plant conditions, or 3. A step is added to the work order that requires the plant initial conditions be explicitly written in the work order and verified in the plant with signature and independent verification 2. A review of RPS work orders for both units was made and a list of work orders that involve or may involve relay replacements was identified. These work orders will be reviewed and changed accordingly to prevent an unexpected reactor trip.
3. Guidance on decision making expectations for short-duration Technical Specifications Action Statements and Limiting Condition of Operation statements will be developed to address expectations for communication and station response to emergent high risk activities.
4. Additional corrective actions have been identified to address the root cause related to the organizational aspects of communication, accountability and ownership which contributed to the event. These are documented in AR 578473578473
Implementation of the above corrective actions is being tracked by AR 578473578473
Corrective actions to address the event's contributing factors have been entered in the Turkey Point Corrective Action Program in AR 578473578473
ADDITIONAL INFORMATION
ElIS Codes are shown in the format [IEEE system identifier, component function identifier, second component function identifier (if appropriate)].
Condition Report AR 578473578473was initiated due to this event.
FAILED COMPONENTS IDENTIFIED: RPS Left Turbine Stop Valve Closure Logic Relay 4-SL-X-B.
PREVIOUS SIMILAR EVENTS: None