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 Entered dateSiteScramRegionReactor typeEvent description
ENS 5407218 May 2019 14:00:00Turkey PointManual ScramNRC Region 2This is a non-emergency notification to the NRC Operations Center in accordance with 10 CFR 50.72(b)(2)(iv)(B) for a valid actuation of the Reactor Protection System (RPS) (four hour notification) and 10 CFR 50.72(b)(3)(iv)(A) for a valid Engineered Safeguards (ESF) actuation (eight hour notification) due to Auxiliary Feedwater (AFW) initiation. Unit 3 manual reactor trip following grid disturbance. Following the grid disturbance, a manual reactor trip was initiated due to lowering steam generator water levels. All control rods fully inserted. AFW started as expected. All other systems responded as expected. Current reactor temperature is 547 degrees F. Current reactor pressure is 2235 psig. Decay heat is being removed through the Atmospheric Steam Dumps (no known primary to secondary Reactor Coolant System leakage exists). The unit is in a normal post-trip electrical lineup. There was no affect on Unit 4. The cause of the grid disturbance is under investigation. The licensee notified the NRC Resident Inspector.
ENS 5402725 April 2019 12:04:00Saint LucieAutomatic ScramNRC Region 2At 0918 (EDT) on 4/25/19, with (Saint Lucie) Unit 1 in Mode 1 at 100% power, the reactor automatically tripped due to a Turbine Trip. The reactor trip was uncomplicated with all systems responding normally. Operations is maintaining the plant stable in Mode 3. Decay heat removal is being accomplished by main feed water and the main condenser using the turbine steam bypass valves. Unit 2 is not affected and remains at 100% power. This event is being reported pursuant to 10 CFR 50.72(b)(2)(iv)(B). The NRC Resident Inspector has been notified."
ENS 5401220 April 2019 09:54:00Duane ArnoldManual ScramNRC Region 3At 0507 (CDT on April 20, 2019), the DAEC (Duane Arnold Energy Center) experienced a trip of both reactor feed pumps. Operators inserted a manual scram. All control rods inserted, as required. As a result of the feed pump trips and scram, HPCI and RCIC automatically injected. Also, containment isolations occurred, as expected for this event. All systems responded as designed. Operators are currently taking the unit to cold shutdown conditions. Vessel level is being controlled by RCIC with Condensate System available. Pressure is being controlled using Main Steam Line drains and the Main Condenser is available. Normal electrical lineup remains. The cause of the reactor feed pumps tripping is believed to be an instrument air leak to flow control valves, causing loss of suction to both feed pumps. The licensee notified the NRC Resident Inspector.
ENS 537795 December 2018 20:07:00Point BeachManual ScramNRC Region 3At 1539 (CST) December 5, 2018, with Unit 1 at 100 percent power, the reactor was manually tripped due to degrading condenser vacuum. The trip was uncomplicated with all systems responding normally, post-trip. An actuation of the auxiliary feedwater system occurred during the manual trip. The auxiliary feedwater system automatically started as designed when the valid actuation signal was received. Operations stabilized the plant in mode 3 (hot standby). Decay heat is being removed by atmospheric dump valves. Unit 2 is not affected. This event is being reported pursuant to 10 CFR 50.72(b)(2)(iv)(B) and 10 CFR 50.72(b)(3)(iv)(A). The loss of condenser vacuum resulted because one of two circulating water pumps was running and its discharge valve shut. The cause for the valve shutting is under investigation. There is no primary to secondary leakage. The licensee notified the NRC Resident Inspector
ENS 5370329 October 2018 16:47:00Saint LucieManual ScramNRC Region 2On October 29, 2018 at 1317 EDT, with St. Lucie Unit 1 in Mode 1 at 100% power, the reactor was manually tripped due to inadequate feedwater flow to both 1A and 1B Steam Generators (S/Gs). The trip was uncomplicated with all systems responding normally post-trip. (All control rods fully inserted and there were no specified system actuations.) Operators responded and stabilized the plant in Mode 3. The cause of the inadequate feed flow to the 1A and 1B Steam Generators is currently under investigation. Decay Heat removal is being accomplished through forced circulation with stable conditions from Main Feedwater and the Steam Bypass Control System to the Main Condenser. Currently maintaining Pressurizer pressure at 2250 psia and Reactor Coolant System temperature at 532 degrees F. St. Lucie Unit 2 was unaffected and remains in Mode 1 at 100% power. This report is submitted in accordance with 10CFR50.72(b)(2)(iv)(B) for the reactor trip. The NRC Senior Resident Inspector has been notified."
ENS 5367619 October 2018 21:44:00Duane ArnoldAutomatic ScramNRC Region 3At 1725 CDT, a Feedwater Regulating valve failed closed, resulting in a reactor level transient, which initiated a reactor trip, Primary Containment Isolation System signals to valves in Groups 2, 3, and 4 and initiation of High Pressure Coolant Injection and Reactor Core Isolation Cooling. All control rods inserted and level has been restored to normal. The cause of the feedwater valve failure is under investigation. All other systems responded as expected. This report is being made under 10 CFR 50.72 (b)(2)(iv)(B), (b)(3)(iv)(A) and (b)(2)(iv)(A). The Senior Resident Inspector has been informed. Decay heat is being removed via the main condenser and reactor vessel water level is being maintained by the condensate and feedwater systems.
ENS 5303626 October 2017 05:54:00Saint LucieAutomatic ScramNRC Region 2CEOn October 26, 2017 at 0212 EDT St. Lucie Unit 2 experienced a reactor trip due to a loss of load event resulting in an RPS (Reactor Protection System) actuation. The cause of the loss of load is currently under investigation. Following the reactor trip, an Auxiliary Feedwater Actuation Signal occurred due to low level in the 2A Steam Generator. One of the two Main Feed Isolation Valves to the 2A Steam Generator did not close on the Auxiliary Feedwater Actuation Signal. 2A Steam Generator level was restored by Auxiliary Feedwater. The 2B Steam Generator level is being maintained by Main Feedwater. All CEAs (Control Element Assemblies) fully inserted into the core. Decay heat removal is being accomplished through forced circulation with stable conditions from Auxiliary Feedwater/Main Feedwater and Steam Bypass Control System. Currently maintaining pressurizer pressure at 2250 psia and Reactor Coolant System temperature at 532 degrees F. St. Lucie Unit 1 was unaffected and remains in Mode 1 at 100 percent power. This report is submitted in accordance with 10 CFR 50.72(b)(2)(iv)(B) for the reactor trip and 10 CFR 50.72(b)(3)(iv)(A) for the Specified System Actuation. The licensee notified the NRC Resident Inspector.
ENS 5296010 September 2017 22:20:00Turkey PointManual ScramNRC Region 2Westinghouse PWR 3-LoopOn 09/10/17 at 1855 (EDT), (Turkey Point) Unit 4 reactor was manually tripped from 88% RTP (Rated Thermal Power) due to a failure of 4C Steam Generator main feed regulating valve causing lowering S/G (Steam Generator) level. All other systems operated normally. Auxiliary Feed Water initiated as designed to provide S/G water level control. EOP's (Emergency Operating Procedures) have been exited and General Operating procedures (GOP'S) were entered. Unit 4 is stable in Mode 3 at NOT/NOP (Normal Operating Temperature/Normal Operating Pressure). The licensee is investigating the failure of the feed regulating valve. Offsite power is available. Decay heat is being removed via main feedwater with steam discharged to atmosphere using the ADVs (Atmospheric Dump Valves). There is no known primary-secondary steam generator tube leakage. The licensee informed the NRC Resident Inspector.
ENS 5271829 April 2017 21:19:00SeabrookManual ScramNRC Region 1Westinghouse PWR 4-LoopAt 1844 (EDT) on 04/29/2017, while the unit was in a low power condition exiting from a refueling outage, the reactor was manually tripped following a P-14 signal (Steam Generator Hi-Hi Level) and a resulting feedwater isolation signal. All control rods were verified to be fully inserted. The cause of the ('B') steam generator high level is currently being investigated. Emergency feedwater actuated at 1845 due to a low-low water level in steam generator 'D'. Plant equipment response is being evaluated and the plant is stabilized in Mode 3 with decay heat removal through the steam dump system to the condensers. There was no release and the emergency feedwater system has been restored to standby. The event description is based on information currently available. If through subsequent reviews of this event, additional information is identified that is pertinent to this event or alters the information being provided at this time, a follow up notification will be made via the ENS or under the reporting requirements of 10 CFR 50.73. The licensee notified the NRC Resident Inspector.
ENS 5213630 July 2016 03:52:00Turkey PointManual ScramNRC Region 2Westinghouse PWR 3-Loop

Power had been reduced for planned maintenance on the 3B feedwater heater. During isolation of the feedwater heaters, a repeated water hammer was experienced. A normal shutdown of Unit 3 was performed. Unit 4 was not affected by the water hammer. The decay heat is being removed via the condenser and all offsite and onsite electrical power is available. The investigation of the cause is underway. The licensee will notify the NRC Resident Inspector.

  • * * UPDATE AT 2141 EDT ON 07/30/16 FROM ERIC JUERGENS TO S. SANDIN * * *

The licensee is retracting this report based on the following: At 0352 EDT on July 30, 2016, EN #52136 provided notification of a Reactor Protection System (RPS) actuation during a normal shutdown of Unit 3 in response to a secondary system equipment issue. Upon further investigation, the unit shutdown and manual RPS actuation were in accordance with general plant operating procedures. The manual RPS actuation was in accordance with the general operating procedure and not required to mitigate the consequences of the secondary system equipment issue. As such, the notification made by EN #52136 for a valid actuation of a specified system is hereby retracted. The NRC Resident lnspector will be notified. Notified R2DO (Rose).

ENS 5157028 November 2015 23:54:00Point BeachAutomatic ScramNRC Region 3Westinghouse PWR 2-LoopUnit 1 automatic reactor trip actuated due to an automatic voltage regulator (AVR) malfunction which caused a generator lockout and turbine trip. The cause of the AVR malfunction is unknown at this time. All control rods fully inserted. The RCS is being cooled by forced flow (reactor coolant pumps). Secondary heat sink is being provided by the condenser steam dumps utilizing the main feed water system. The auxiliary feed water system actuated based on low steam generator level, but since has been secured. Off-site power remains available. No release is occurring and emergency core cooling systems did not actuate. Emergency plan entry was not required. The plant is in its normal shutdown electrical lineup at normal operating temperature and pressure. Unit 2 was not affected by the Unit 1 transient. The licensee has notified the NRC Resident Inspector
ENS 5130210 August 2015 00:23:00Saint LucieAutomatic ScramNRC Region 2CEOn August 9, 2015, during the performance of Reactor Protection System Logic Matrix Testing, a reactor trip occurred. All CEA's (control rods) fully inserted into the core. Decay Heat removal is from Main Feedwater and Steam Bypass to the Main Condenser. All equipment operated as expected. Currently maintaining pressurizer pressure at 2250 psia, temperature maintaining at 532 degrees F. Unit 2 was unaffected and remains in Mode 1 at 100% power. This event is reportable pursuant to 10CFR 50.72(b)(2)(iv)(B) for the Reactor Trip and 10CFR 50.72(b)(3)(iv)(A) for the Specified System Actuation. The plant is in its normal shutdown electrical lineup. No safety or relief valves lifted during this event. The cause of the trip is under investigation. The licensee notified the NRC Resident Inspector.
ENS 5106512 May 2015 05:48:00Turkey PointAutomatic ScramNRC Region 2Westinghouse PWR 3-LoopThis is an non-emergency notification to the NRC (Headquarters) Operations Center in accordance with 10 CFR 50.72(b)(2)(iv)(B) for a valid actuation of the reactor protection system (RPS) (four hour notification) and 10 CFR 50.72(b)(3)(iv)(A) for a valid Engineered Safeguards (ESF) actuation (eight hour notification) due to auxiliary feedwater (AFW) initiation. On 5/12/15 at 0430 EDT, Unit 4 experienced an automatic reactor trip due to Generator Differential Trip. Investigation is underway to determine the cause. Auxiliary feedwater automatically initiated as expected. All systems operated correctly in response to the reactor trip. Unit 4 is currently in Mode 3 and stable. All control rods fully inserted. Normal offsite power is available with decay heat is being removed by the atmospheric steam dumps. There is no known primary to secondary reactor coolant system leakage. The licensee has notified the NRC Resident Inspector.
ENS 506493 December 2014 01:10:00Point BeachManual ScramNRC Region 3Westinghouse PWR 2-LoopInitiated a manual Unit 1 reactor trip due to imminent failure of 1P-25B Condensate Pump. Unit 1 had commenced a rapid down power due to the degradation of the pump. The event is reportable under 10CFR50.72(b)(2)(iv)(B) for a manual actuation of the reactor protection system when the reactor is critical and 10CFR50.72(b)(3)(iv)(A) for an actuation of specified system (6) PWR auxiliary feedwater system. Auxiliary feedwater system actuation was due to low steam generator water levels in both 'A' and 'B' Steam Generators, an expected system response during a reactor trip. Decay heat removal is by forced circulation and is being controlled by auxiliary feedwater system and condenser steam dumps. After the trip, both main steam generator feedwater pumps were secured due to feed pump suction pressure remaining low post trip. All other plant systems functioned as required. All control rods fully inserted in the core due to the manual trip. There was no ECCS actuation. Off-site power has been maintained throughout the event. No primary or secondary safety relief valves lifted during the reactor trip. Unit 1 is in a normal shutdown electrical lineup. There was no effect on Unit 2. The licensee notified the NRC Resident Inspector.
ENS 5060712 November 2014 18:31:00Saint LucieManual ScramNRC Region 2CEOn November 12, 2014 at 1548 (EST), Unit 2 was manually tripped due to a lowering 2B steam generator level caused by the spurious (slow) closure of 2B Main Feedwater Isolation Valve, HCV-09-2B. All CEAs (control element assemblies) fully inserted into the core. All safety systems responded as expected with the 2B Auxiliary Feedwater Actuation System Channel 2 (AFAS 2) actuating on low 2B steam generator level. Decay heat removal is from main feedwater to the 2A steam generator and manual control of auxiliary feedwater to the 2B steam generator, with steam bypass to the main condenser. This event is reportable pursuant to 10 CFR 50.72(b)(2)(iv)(B) for the reactor trip and 10 CFR 50.72(b)(3)(iv)(A) for the AFAS 2 actuation. During the transient, no relief or safety valves lifted. The grid is stable and the plant is in its normal shutdown electrical lineup at normal operating pressure and temperature. The cause of the feedwater isolation valve malfunction is under investigation. There was no effect on Unit 1. The licensee has notified the NRC Resident Inspector.
ENS 5035411 August 2014 14:20:00Turkey PointManual ScramNRC Region 2Westinghouse PWR 3-LoopThis is an non-emergency notification to the NRCOC (Nuclear Regulatory Commission Operations Center) in accordance with 10 CFR 50.72(b)(2)(iv)(B) for a valid actuation of the reactor protection system (RPS) (four hour notification) and 10 CFR 50.72(b)(3)(iv)(A) for a valid Engineered Safeguards (ESF) actuation (eight hour notification) due to auxiliary feedwater (AFW) initiation , safety injection (SI) initiation, and emergency diesel generator (EDG) auto start. On 8/11/14 at 1028 EDT, Unit 3 experienced a manual reactor trip due to a loss of instrument air. Auxiliary feed water automatically initiated as expected. Unit 3 is currently in Mode 3 and stable. Instrument air has been restored. At 1305 a safety injection signal (SI) occurred due to main steamline high differential pressure during a plant cooldown to 470 degrees Fahrenheit. High head safety injection (HHSI) pump, residual heat removal (RHR) pumps, and emergency diesel generators (EDGs) auto started as expected due to the safety injection signal. Based on plant conditions, the HHSI and RHR pumps did not inject into the reactor coolant system. The plant was stabilized after the reactor trip, however, the loss of instrument air resulted in a loss of letdown and PZR level continued to slowly increase to approximately 91%. All rods fully inserted and normal offsite power was maintained. Operators initiated a plant cooldown to stabilize and lower PZR level using the S/G atmospheric steam dumps. Unequal opening of the S/G atmospheric steam dumps caused the SI to occur due to main steamline high differential pressure. No RCS injection occurred and all SI equipment operated as expected and has been subsequently secured. Unit 3 is stable in mode 3 at 490 degrees Fahrenheit and RCS pressure is 1940 psig. There was no effect on Unit 4 which continues to operate at 100% power. The loss of instrument air is being investigated. The licensee has notified the NRC Resident Inspector.
ENS 5014025 May 2014 07:37:00Turkey PointAutomatic ScramNRC Region 2Westinghouse PWR 3-LoopThis is an non-emergency event notification to the NRC Operations Center in accordance with 10 CFR 50.72(b)(2)(iv)(B) for a valid actuation of the reactor protection system (RPS) (four hour notification). On 05/25/2014 at 0536 EDT, as part of a planned maintenance outage to repair a leaking check valve inside the containment building, Unit 4 power level had been lowered to 19% reactor power for the planned opening of the reactor trip breakers. Unit 4 experienced a loss of condenser vacuum. An automatic turbine trip signal was generated which initiated a reactor trip signal. The reactor tripped as required on the automatic trip signal. Unit 4 is currently in Mode 3 and stable. The loss of vacuum is under investigation at this time. All other plant systems are working as designed. The reactor trip was uncomplicated with no other safety system actuations. Decay heat is being removed via steam dumps to atmosphere. There is no known primary to secondary leakage. The grid is stable and Unit 4 is in its normal shutdown electrical lineup. Unit 3 was not affected and continues to operate at 100% power. The licensee has notified the NRC Resident Inspector.
ENS 499791 April 2014 02:44:00SeabrookAutomatic ScramNRC Region 1Westinghouse PWR 4-LoopAt 0026 on 04/01/2014, following the turbine shutdown and removal of the main generator from service in preparation for refueling outage 16, Seabrook had a reactor trip and all control rods were fully inserted. The trip was caused by an electrical issue that caused 345 KV bus 6 to deenergize and power was lost to the Unit Auxiliary Transformers (UATs). The in-house busses transferred to the Reserve Auxiliary Transformer (RAT) supplies and the momentary loss of power to in-house Bus 1 caused 2 reactor coolant pumps to trip, generating a 2 loop loss of flow reactor trip signal. The exact cause of the initiating electrical issue is being investigated. The NRC Resident Inspector has been notified. Emergency feedwater actuated at 0035 due to a low low water level in steam generator 'C'. Plant equipment response is being evaluated and the plant is stabilized in Mode 3 with decay heat removal through the steam dump system to the condensers. There was no release and the emergency feedwater system is being restored to standby. The event description is based on information currently available. If through subsequent reviews of this event, additional information is identified that is pertinent to this event or alters the information being provided at this time, a follow-up notification will be made via the ENS or under the reporting requirements of 10CFR50.73.
ENS 4953614 November 2013 14:57:00Saint LucieManual ScramNRC Region 2CEOn November 14, 2013 at 1218 EST, Unit 2 was manually tripped due to a lowering 2B Steam Generator level caused by the spurious closure of 2B Main Feedwater Isolation Valve HCV-09-2A. All CEAs (Control Element Assemblies) fully inserted into the core. All safety systems responded as expected with the 2B Train Auxiliary Feedwater Actuation System Channel 2 (AFAS 2) actuating on low 2B Steam Generator level. Decay Heat Removal is from Main Feedwater to the 2A Steam Generator and Auxiliary Feedwater to the 2B Steam Generator with Steam Bypass to the Main Condenser. This event is reportable pursuant to 10CFR 50.72(b)(2)(iv)(B) for the Reactor Trip and 10CFR 50.72(b)(3)(iv)(A) for the AFAS 2 actuation. The plant is in its normal shutdown electrical lineup. No safeties or relief valves lifted during this event. The NRC Resident Inspector has been notified by the licensee.
ENS 4952812 November 2013 01:23:00Saint LucieManual ScramNRC Region 2CEAt 0002 EST, Unit 1 Manually tripped the Reactor from 90% power due to an unisolable leak in the Digital Electro-Hydraulic (DEH) System. All CEAs fully inserted into the Reactor Core. All systems responded as expected on the trip. Decay Heat removal currently using Main Feedwater and Steam Bypass Control System. After the trip, DEH pumps were secured to stop the transfer of fluid from the DEH system to the Turbine Building. Investigation ongoing to determine exact location of the leak. This condition is reportable pursuant to 10CFR50.72(b)(2)(iv)(B). The was no impact on Unit 2. The NRC Resident Inspector has been notified.
ENS 4908231 May 2013 10:26:00Saint LucieManual ScramNRC Region 2CEOn May 31, 2013 at 0712 (EDT), Unit 2 (reactor) was manually tripped due to high differential pressure on the debris filter for the 2A1 Condenser Waterbox which required a trip of the 2A1 Circulating Water Pump. The 2A2 Condenser Waterbox and the 2A2 Circulating Water Pump were already removed from service due to a suspected condenser tube leak. All CEAs (Control Element Assembly) fully inserted into the core. Decay heat removal is from main feedwater and steam bypass to the main condenser. The cause of the rising differential pressure on the 2A1 debris filter was potentially due to an influx of algae. This event is reportable pursuant to 10CFR 50.72(b)(2)(iv)(B) for the reactor trip. The reactor trip response is considered uncomplicated and the unit is stable in Mode 3 at normal temperature and pressure. Unit 2 is in a normal shutdown electrical lineup. There was no impact on Unit 1. The licensee has notified the NRC Resident Inspector.
ENS 4902110 May 2013 12:42:00Turkey PointManual ScramNRC Region 2Westinghouse PWR 3-LoopThis is a non-emergency event notification to the NRCOC (Nuclear Regulatory Commission Operations Center) in accordance with 10 CFR 50.72(b)(2)(iv)(B) for a valid actuation of the Reactor Protection System (RPS) (four hour notification). On 5/10/13 (at 1108 EDT) Unit 3 was stabilizing at 25% (power) during a controlled shutdown from an initial power level of 38% (power). Prior to the planned insertion of the trip at 25% (power), a malfunction of the turbine valves (not yet understood) caused a loss of load and a manual reactor trip was performed at 1108 (EDT). Unit 3 is currently in Mode 3 (Hot Standby) and stable. Source Range Nuclear Instrument N-3-32 malfunctioned (loss of detector voltage). All other plant systems are working as designed. Unit 3 is stable in Mode 3 (Hot Standby) at normal operating temperature and pressure. All control rods fully inserted. All other Nuclear Instrumentation is operable. Decay heat removal is via main feedwater and atmospheric steam dumps however, the condenser steam dumps are available but not preferred for Tave control. There is no known primary to secondary leakage. Unit 3 is in a normal shutdown electrical lineup. The cause of the turbine valves malfunction is not known at this time. There is no impact on Unit 4. The licensee has notified the NRC Resident Inspector.
ENS 4881812 March 2013 18:01:00Saint LucieAutomatic ScramNRC Region 2CEOn 3/12/13 at 1451 EDT, during normal full power operations, Unit 1 automatically tripped due to the Thermal Margin/ Low Pressure trip setpoint being exceeded. The trip was uncomplicated and all CEAs (control element assembly) fully inserted when the reactor was tripped. Main Steam Safety valves lifted momentarily post trip and reseated. No automatic safety system actuations were required and none occurred. The cause and details of the automatic trip are under investigation. The plant is stable in Mode 3 at normal operating temperature and pressure. RCS Heat Removal is being maintained with Main Feedwater and Atmospheric Dump Valves in operation. The operation of the Steam Bypass Control System is under review by Engineering. The Offsite power grid is available and stable. The licensee has notified the NRC Resident Inspector and there was no impact on Unit 2.
ENS 4881712 March 2013 17:31:00Turkey PointAutomatic ScramNRC Region 2Westinghouse PWR 3-LoopUnit 3 experienced an automatic reactor trip from approximately 3% power. The turbine was off-line and undergoing testing following a control valve position indication repair. A turbine inlet pressure channel perturbation momentarily actuated the 'Reactor Trip by Turbine Trip' protection, causing the Unit 3 reactor to trip. Unit 3 is currently stable in Mode 3. No other complications were noted following the reactor trip. The cause of the turbine inlet pressure channel perturbation is currently under investigations. All control rods fully inserted. Normal feedwater is supplying the steam generators and decay heat removal is to atmosphere via the atmospheric steam dumps. There is no primary to secondary leakage. Unit 3 is in a normal shutdown offsite electrical power alignment. There is no impact on Unit 4. The NRC Resident Inspector has been notified.
ENS 4876418 February 2013 03:19:00Turkey PointManual ScramNRC Region 2Westinghouse PWR 3-LoopThis is an non-emergency event notification to the NRCOC in Accordance with 10 CFR 50.72(b)(2)(iv)(B) for a valid actuation of the Reactor Protection System (RPS) (four hour notification) and 10 CFR 50.72(b)(3)(iv)(A) for a valid Engineered Safeguards (ESF) actuation due to Auxiliary Feedwater (AFW) initiation (eight hour notification). On 2/18/2013 at 0055 Unit 3 commenced a unit shutdown due to high # 1 seal leak-off on the 3A Reactor Coolant Pump (RCP). At 0129 3A RCP #1 seal leak-off exceeded operating limits. Unit 3 reactor was manually tripped. Auxiliary feedwater actuated as designed based on steam generator levels as a result of the trip. Unit 3 is currently in Mode 3 and stable. No complications were noted as a result of the reactor trip. Steam generator levels are being returned to normal level following the reactor trip. All other plant systems functioned as designed during and after the reactor trip. 3A RCP high #1 seal leak-off is under investigation. All control rods fully inserted on the trip. Decay heat was removed by AFW to the steam generators out the atmospheric reliefs. There was no primary to secondary leakage. Electrical buses are being supplied via offsite power. The licensee notified the NRC Resident Inspector.
ENS 4874412 February 2013 00:45:00Turkey PointAutomatic ScramNRC Region 2Westinghouse PWR 3-LoopThis is a non-emergency event notification to the NRCOC (Nuclear Regulatory Commission Operations Center) in accordance with 10 CFR 50.72(b)(2)(iv)(B) for a valid actuation of the Reactor Protection System (RPS) (four hour notification) and 10 CFR 50.72(b)(3)(iv)(A) for a valid Engineered Safeguards (ESF) actuation due to Auxiliary Feedwater (AFW) initiation (eight hour notification). On 2/11/2013 at 2236 EST Unit 3 experienced a loss of condenser vacuum. An automatic Turbine Trip signal was generated which initiated a Reactor Trip signal. The reactor tripped as required on the automatic trip signal. Auxiliary feedwater water actuated automatically based on low steam generator levels following the trip. Unit 3 is currently in Mode 3 and stable. Steam generator levels have been returned to normal levels . The loss of vacuum is under investigation at this time. All other plant systems are working as designed. The reactor trip was uncomplicated. All control rods fully inserted. The plant is stable at normal temperature and pressure. AFW has been secured and main feedwater is being used for Steam Generator water level control. The main condenser is unavailable and decay heat removal is to atmosphere via the atmospheric steam dumps. There are no indications of primary to secondary leakage. Unit 3 is in a normal offsite power electrical alignment. There is no impact on Unit 4. The licensee has notified the NRC Resident Inspector.
ENS 4831014 September 2012 22:05:00SeabrookAutomatic ScramNRC Region 1Westinghouse PWR 4-Loop(At) 2025 (EDT) reactor tripped on 'C' Steam Generator Low Low Level due to feed water regulating valve failing closed due to a 7300 process cabinet card failure. Control Room entered E-0, Reactor Trip or Safety Injection, then transitioned to ES-0.1, Reactor Trip Response. Emergency Feedwater actuated due to the Low Low Steam Generator Level. All other plant equipment functioned as expected. Plant is being stabilized in mode 3. Emergency News Manager will update the states and local media. NRC Resident Inspector was notified at 2045 (EDT). The trip was uncomplicated and all rods fully inserted. Decay heat is being removed to the condenser via the turbine bypass valves. Electrical buses are powered by offsite power.
ENS 4818915 August 2012 00:02:00Point BeachManual ScramNRC Region 3Westinghouse PWR 2-LoopUnit 1 Manual Reactor Trip was initiated in anticipation of an auto turbine trip due to operators noticing the turbine governor valves closing in response to an Electro-Hydraulic Control System signal. All Control Rods are fully inserted. The RCS is being cooled by forced flow (reactor coolant pumps). Secondary heat sink is being provided by the condenser steam dumps utilizing the main feedwater system. The auxiliary feedwater system actuated based on low steam generator level, but has since been secured. There were no unexpected (inconsistent with nature of trip) pressure or level transients. Offsite power remains available. No release occurred nor is ongoing. Emergency Core Cooling did not actuate. No unexpected isolations occurred. Emergency Plan entry was not required. The licensee informed the NRC Resident Inspector.
ENS 4805328 June 2012 01:06:00Point BeachManual ScramNRC Region 3Westinghouse PWR 2-Loop

Unit 2 Manual Reactor Trip was actuated due to indications of a 100% Load Rejection. The cause of the Load Rejection is not known at this time. All Control Rods are fully inserted. The RCS is being cooled by forced flow (reactor coolant pumps). Secondary heat sink is being provided by the condenser steam dumps utilizing the main feedwater system. The auxiliary feedwater system actuated based on low steam generator level, but has since been secured. There were no unexpected (inconsistent with nature of trip) pressure or level transients. Off site power remains available. No release occurred nor is ongoing. Emergency Core Cooling Systems did not actuate. No unexpected isolations occurred. Emergency Plan entry was not required. The plant is stable at normal temperature and pressure. The electrical system is in a normal offsite power alignment. The Unit 2 Reactor Trip had no effect on Unit 1 which continues to operate at 100% power. The licensee has notified the NRC Resident Inspector.

  • * * UPDATE FROM ERIC SONNENBERG TO HOWIE CROUCH AT 2337 EDT ON 7/6/12 * * *

On June 27, 2012 at 2046 CDT, a Unit 2 Manual Reactor Trip was initiated in anticipation of an automatic turbine trip due to operators noticing the turbine governor valves closing and turbine load reduction. It was originally reported that the cause was not known. This notification is updated to provide information to the cause of the load reduction. Troubleshooting has shown that the reduction of turbine load was due to a turbine speed channel card failing in the turbine control system. The card failure resulted in sending the auxiliary governor in the turbine control system an incorrect indicated overspeed condition and throttling the turbine governor valves to reduce the turbine speed. There was no actual turbine overspeed condition. The auxiliary governor is not part of the reactor protection system. No reactor protection setpoints were exceeded. All other plant systems functioned as required, including the Reactor Protection System. All control rods fully inserted into the core due to the manual reactor trip. There was no Emergency Core Cooling System actuation. No Emergency Diesel Generators were started and power continued to be supplied from off site. The reactor coolant system had forced circulation and the condenser steam dumps were used for decay heat removal from the steam generators. The licensee has notified the NRC Resident Inspector. Notified R3DO (Daley).

ENS 4791511 May 2012 07:07:00Saint LucieManual ScramNRC Region 2CEOn May 11, 2012, a failure of the High Power Feed Regulating Valve FCV-9011 resulted in '2A' S/G water level lowering. Manual operator control of the Main Feed Regulating system was unsuccessful in stabilizing S/G water level. '2A' S/G level lowered to the procedurally required manual reactor trip criteria. The crew inserted a manual trip. All CEAs fully inserted into the core. Following the trip, Auxiliary Feedwater actuated as designed and decay heat removal was via Auxiliary Feedwater and Steam Bypass to the Main Condenser. All equipment operated as expected. Currently, Unit 2 is maintaining pressurizer pressure at 2250 psia, temperature at 532 degrees F on Main Feedwater (using Low Power Feed Regulating Valves LCV-9005/9006) and Steam Bypass Control. 'Unit 1 was unaffected and remains in Mode 1 at 29% power. This event is reportable pursuant to 10CFR50.72(b)(2)(iv)(B) for the Reactor Trip, as well as 10CFR50.72(b)(3)(iv)(A) for specified system actuation (Auxiliary Feedwater). The licensee has notified the NRC Resident Inspector.
ENS 4779331 March 2012 03:42:00Saint LucieManual ScramNRC Region 2CEAt 0022 (EDT) on 03/31/12 while maintaining power stable at 10% for Steam Bypass Control System testing, Unit 1 was manually tripped due to an uncontrolled cooldown caused by PCV-8802 (Steam Bypass Control Valve) unexpectedly opening. Following the trip, PCV-8802 closed and the secondary was isolated by closing the Main Steam Isolation Valves per Standard Post Trip Actions. Following isolation of the steam demand, the trip was uncomplicated with all CEAs fully inserted. No automatic safety system actuations were required and none occurred. The cause of the unexpected opening of the Steam Bypass Control System valve is under investigation. The plant is stable in Mode 3 at normal operating temperature and pressure. RCS Heat Removal is being maintained with Auxiliary Feedwater and Atmospheric Dump Valves. The Offsite power grid is available and stable. This non-emergency notification is being made pursuant to 10 CFR 50.72(b)(2)(iv)(B) due to manual RPS actuation with the reactor at power. The RCS cooled down from 532 degree to 515 degrees over a period of approximately 2 minutes and 40 seconds. The reactor was manually tripped when RCS temperature reached 515 degrees and the lowest RCS temperature observed after the trip was 505 degrees. The licensee has notified the NRC Resident Inspector.
ENS 4775219 March 2012 02:24:00Saint LucieManual ScramNRC Region 2CEAt 2336 EDT, during performance at Low Power Physics Testing, Unit 1 was manually tripped while the reactor was critical at less than 1% power due to Control Element Assembly (CEA) Regulating Group #3 exhibiting anomalous behavior (continued to insert with no operator action). The trip was uncomplicated and all CEAs fully inserted when the reactor was tripped. No automatic safety system actuations were required and none occurred. The cause for the abnormal CEA performance is under investigation. The plant is stable in Mode 3 at normal operating temperature and pressure. RCS Heat Removal is being maintained with Auxiliary Feedwater and Atmospheric Dump Valves. The offsite power grid is available and stable. This non-emergency notification is being made pursuant to 10 CFR 50.72(b)(2)(iv)(B) due to manual RPS actuation with the reactor critical The NRC Resident Inspector has been informed.
ENS 4735319 October 2011 07:32:00Saint LucieManual ScramNRC Region 2CEOn October 19, 2011, at 0528, Unit 1 was manually tripped due to rising condenser backpressure. All (Control Element Assembly) CEAs fully inserted into the core. Decay Heat Removal is from Main Feedwater and Steam Bypass to the Main Condenser. The cause of the rising backpressure was an unplanned trip the Circulating Water Pump 1A1, which degraded the Circulating Water System performance. At the time of the trip, an additional Circulating Water Pump 1A2 was secured for planned maintenance. The cause of the Circulating Water Pump 1A1 trip is under investigation. This event is reportable pursuant to 10CFR 50.72(b)(2)(iv)(B) for the Reactor Trip. The plant is stable at normal operating temperature and pressure. The licensee notified the NRC Resident Inspector.
ENS 473276 October 2011 15:17:00SeabrookAutomatic ScramNRC Region 1Westinghouse PWR 4-LoopAt 1226 (EDT) today, Seabrook experienced an automatic reactor trip on low steam generator water levels. The low steam generator levels resulted following a trip of one of the two operating main feed pumps. Main feed pump 'A' tripped on low suction pressure while a condensate pump was being returned to service following maintenance on the pump. The emergency feedwater system actuated automatically and recovered steam generator levels. All systems actuated and functioned as designed. The wide range level indication on steam generator 'C' indicated erratically and was declared Inoperable. The plant is stable and being maintained in Mode 3. The station plans to cool the plant to Mode 5 for a previously planned forced outage. This notification provides a four-hour report for an actuation of the reactor protection system while the reactor is critical and an eight-hour report for a valid actuation of the emergency feedwater system. All rods fully inserted. Emergency feedwater has been secured and placed in standby and startup feedwater is supplying the steam generators. Decay heat is being removed to the condenser via the turbine bypass valves. Electrical systems are in a normal shutdown alignment. There is nothing unusual or not understood and all systems functioned as required. The licensee has notified the NRC Resident Inspector.
ENS 4717822 August 2011 17:48:00Saint LucieManual ScramNRC Region 2CE

On August 22, 2011 at 1513 (hrs. EDT), Unit 1 was manually tripped due to rising condenser backpressure. All CEAs fully inserted into the core. Decay heat removal was initially from main feedwater and steam bypass to the main condenser. The cause of the rising back pressure was an influx of jellyfish into the intake structure, degrading the circulating water system performance. Subsequent to the manual trip, the 1B Main Feedwater Pump was manually secured due to a leak on the pump casing. The 1A Main Feedwater Pump subsequently tripped due to low suction pressure after manually securing the 1B Condensate Pump, per procedure. Decay heat removal was transitioned to atmospheric dump valves and auxiliary feedwater. Unit 2 is in Mode 1, currently at 70 % power. Unit 2 power is being reduced from 100% in response to the influx of jellyfish. This event is reportable pursuant to 10 CFR 50.72(b)(2)(iv)(B) for the reactor trip. During the transient, no primary or secondary relief valves lifted. Offsite power is stable and the plant is in its normal shutdown electrical line-up with power being supplied from offsite. There is no known primary-to-secondary leakage. The cause of the 1A Main Feedwater Pump trip is under investigation. Unit 2 remained at 70% reactor power before and after the event. The licensee has notified the NRC Resident Inspector.

  • * * UPDATE AT 1856 EDT ON 08/22/11 FROM CARLOS SANTOS TO JOE O'HARA * * *

On August 22, 2011 an abnormal fish kill of at least 1000 lbs was observed in the combined unit's intake canal. The cause of the fish kill was related to an unusually large sustained influx of jellyfish into the intake canal. Per the plant's environmental permit, the Florida Fish and Wildlife Conservation Commission (FWCC) was notified at 1627 EDT. This non-emergency notification is being made pursuant to 10 CFR 50.72(b)(2)(xi) due to the notification of the FWCC. The licensee has notified the NRC Resident Inspector.

ENS 4714311 August 2011 15:29:00Duane ArnoldManual ScramNRC Region 3GE-4At 1138 CDT, while in the process of shutting down as required by Technical Specifications (Reference EN# 47142), with the reactor at approximately 15 percent power, a manual scram was inserted in order to complete the TS Required Action of being in Mode 3 within 12 hours. Upon inserting the manual scram, reactor water level dropped below 170 inches resulting in Primary Containment Isolation System (PCIS) Groups 2, 3 and 4 being received. This reactor water level response is considered normal following a reactor scram from power due to void collapse in the reactor vessel. Reactor water level is currently being controlled in the normal band. All PCIS group isolations went to completion and were subsequently reset. The PCIS isolations all functioned properly. This event is being reported pursuant to 10 CFR 50.72(b)(3)(iv)(A). The NRC Resident Inspector has been notified.
ENS 4695713 June 2011 23:29:00Point BeachAutomatic ScramNRC Region 3Westinghouse PWR 2-Loop

On June 13, 2011 at 1924 CDT, an automatic reactor trip was actuated during Shutdown Bank Insertion for Beginning of Life Physics Testing. Neutron flux lowered from the intermediate range to the point of automatic energization of the Source Range Nuclear Instruments. Energization of the Source Range Nuclear Instruments during this step is anticipated and permissible per the test procedure. When it energized, the N-31 Source Range Nuclear Instrument (Red Channel) failed high which initiated an automatic reactor trip. All plant systems functioned as required, including the Reactor Protection System. All control rods fully inserted into the core. There was no Emergency Core Cooling System or Auxiliary Feedwater System actuation. No Emergency Diesel Generators were started and power continues to be supplied from off site. The reactor coolant system has forced circulation and the atmospheric steam dumps are currently being used for decay heat removal from the steam generators. There was no radiological release and emergency plan implementation was not required. An investigation of the failure of the N-31 Source Range Nuclear Instrument is in progress There is no known primary to secondary leakage. The licensee notified the NRC Resident Inspector.

  • * * UPDATE FROM RUSS PARKER TO DONALD NORWOOD AT 2155 EDT ON 6/14/11 * * *

At the time of the trip, the reactor was subcritical. This notification is updated to reflect reporting in accordance with 10CFR50.72(b)(3)(iv)(A). An investigation of the failure of the N-31 source range nuclear instrument continues. This event was initially reported by the licensee as a four-hour report in accordance with 10CFR50.72(b)(2)(iv)(B). The licensee notified the NRC Resident Inspector. Notified R3DO (Kozak).

  • * * UPDATE FROM ALEX RIVAS TO HUFFMAN ON 10/12/11 AT 1502 EDT * * *

'On June 14, 2011 at 2055 EDT, EN 46957 was amended to state the reactor was subcritical at the time of the trip. Subsequent review of this situation by the licensee resulted in a determination that at the time the test sequence was initiated, the reactor was critical and in MODE 2. Accordingly, this non-emergency report is amended to reflect EN 46957 as originally submitted on 06/13/11 at 2229 CDT. LER 301/2011-004-01 (submitted on July 25, 2011) will be revised accordingly.' The licensee has notified the NRC Resident Inspector. R3DO (Peterson) notified.

ENS 466606 March 2011 19:38:00Turkey PointManual ScramNRC Region 2Westinghouse PWR 3-Loop

This is a 4-hr Non-Emergency notification to the NRCOC (Nuclear Regulatory Commission Operations Center) for an event that results in actuation of the Reactor Protection System (RPS) when the reactor is critical in accordance with 10CFR50.72(b)(2)(iv)(B). On 3/6/11 at approx 16:20 (EST), Steam Generator sodium concentrations started to rise and exceeded 3-ONOP-071.1 (Secondary Chemistry Deviation from limits) Action Level 3 criteria (250 ppb Sodium). The plant power was reduced to 25% per 3-ONOP-100, Fast Load Reduction, and a manual plant trip (was) initiated per procedure at 16:44 (EST). Unit (3) is stabilized in Mode 3, and (the licensee) is performing secondary clean-up.

All rods fully inserted. All safety systems functioned as required. The reactor trip was uncomplicated. Unit 4 was unaffected by this event.

The licensee has notified the NRC Resident Inspector.

ENS 4648215 December 2010 05:40:00Point BeachManual ScramNRC Region 3Westinghouse PWR 2-LoopOn 12/15/10 at 0148 (CST) Control room personnel initiated a manual reactor trip in order to abort a startup in progress with the Unit 2 Reactor subcritical. During the performance of OP-1B, Reactor Startup for Unit 2 both Rod Control System Urgent and Non-Urgent alarms were received. Shortly after receiving the alarms multiple groups of control rods fell into the core as indicated by Individual Rod Position Indicators (IRPl's) and rod bottom lights. Based on these indications a manual reactor trip was initiated. All systems functioned as expected, with all control rods fully inserting. The plant is currently in Mode 3 and operating in accordance with normal plant procedures. The cause of the control rod alarms is under investigation. The licensee informed the NRC Resident Inspector.
ENS 4647110 December 2010 01:25:00Turkey PointManual ScramNRC Region 2Westinghouse PWR 3-LoopAt 2200 (EST) 12/09/2010, Unit 4 had indication of a condenser tube leak. A power reduction was commenced in accordance with plant procedures to allow isolation of the leaking waterbox. Sodium levels in the Steam Generators increased and a unit shutdown was required. Power was reduced to 20% and a manual reactor trip was initiated at 2258 (EST) 12/09/10, in accordance with plant procedures. All systems operated as required and the unit is stable in mode 3. The reactor trip was not complicated. All control rods inserted fully and decay heat is being removed by the atmospheric steam dumps. There is no indications of primary to secondary leakage. Normal offsite power is available and Unit 3 is unaffected. 3 of 3 steam generators are affected by the increase in sodium levels. The licensee is in progress of conducting steam generator blowdowns. The licensee has notified the NRC Resident Inspector.
ENS 4641915 November 2010 07:06:00Turkey PointManual ScramNRC Region 2Westinghouse PWR 3-LoopOn 11/15/10 at 0603 (hrs. EST), the Unit 3 reactor was manually tripped after receiving a report that there was an overheating packing gland on the 3A2 Circulating Water Pump. The 3A1 Circulating Water Pump was already tagged out for maintenance. This required Unit 3 to be tripped due to only two Circulating Water Pumps in operation. The Unit 3 reactor was stabilized in Mode 3. Auxiliary Feedwater automatically actuated. A train of normal feedwater remains available to feed Steam Generators. During the Unit 3 reactor trip, the 3B Steam Dump to Atmosphere failed to close on operator demand per procedure. It was locally isolated with a manual isolation valve stopping the cooldown. The RCS was stabilized at 487.56?F and was borated as required by procedure. All boration systems operated as designed. The RCS returned to normal operating temperature and pressure. During the trip, all rods inserted into the core. Other than the steam dump to atmosphere valve lifting, no other relief valves lifted. There is no known primary to secondary leakage. The electrical grid is normal and the plant is in a normal shutdown electrical line-up. Decay heat is being removed via the 3A and 3C steam dumps to atmosphere since the Main Steam Isolation Valves were closed. The plant is heating up to normal operating temperature at which time auxiliary feedwater will be secured. The licensee has notified the NRC Resident Inspector.
ENS 4624610 September 2010 19:46:00Turkey PointManual ScramNRC Region 2Westinghouse PWR 3-LoopDuring a Unit 4 reactor startup on 9/9/2010 while the reactor was subcritical in Mode 3, the Control Bank C Group 1 Step Counter failed (due to a battery failure). The reactor trip breakers were opened in accordance with procedures as required by the Action of Technical Specification 3.1.3.3. All rods fully inserted. The unit remained in Mode 3. This was a manual actuation of the reactor protection system. This report is made in accordance with 10 CFR 50.72(b)(3)(iv)(A) - Valid actuation of the Reactor Protection System. This is a late report. Reportability was not recognized at the time of the event as a result of misleading guidance in 0-ADM-115 'Notification of Plant Events' (site specific) procedure. A condition report is being initiated (by the licensee) to evaluate procedure changes to avoid further occurrences. The licensee notified the NRC Resident Inspector.
ENS 462358 September 2010 15:52:00Turkey PointAutomatic ScramNRC Region 2Westinghouse PWR 3-Loop

AUTOMATIC REACTOR TRIP DURING MAINTENANCE ON A REACTOR PROTECTION SYSTEM RELAY

At 1345 (EDT) on 9/8/10, Turkey Point Unit 4 automatically tripped during the repair of a failed Turbine Stop Valve Relay which inputs into the Reactor Protection System. During the replacement of this relay, the logic condition was met causing a Reactor Trip and Turbine Trip.

At the time of the trip, reactor power was 100%. Auxiliary Feedwater was automatically initiated when Steam Generator levels lowered below the actuation setpoint. Steam Generator levels are now stable at their normal band and Auxiliary Feedwater is now secured.

Additionally, the Source Range Detectors did not automatically energize and were manually energized and are operating correctly.

Unit 4 has been stabilized in Mode 3 on normal off-site power. This event is reportable per 10CFR50.72(b)(2)(iv)(B) - actuation of the Reactor Protection System with the reactor critical and 10CFR50.72(b)(3)(iv)(A) - valid actuation of an ESF system (AFW).

The trip was characterized as uncomplicated. All rods fully inserted. No relief valves lifted during the transient. Normal feedwater has been re-established to the steam generators and decay heat is being removed via the turbine bypass valves to the condenser. The unit is in a normal shutdown electrical lineup. There was no impact on Unit 3.

The license has notified the NRC Resident Inspector.

ENS 4612926 July 2010 22:45:00Point BeachManual ScramNRC Region 3Westinghouse PWR 2-LoopOn 7/26/2010 at 2001 (hrs. CDT), Control Room personnel initiated a manual reactor trip from approximately 19% reactor power. Unit 1 was in the process of coming off-line to support Main Generator repair. The generator breaker had just been opened and load transferred to condenser steam dumps when a loss of condenser vacuum occurred. The reactor was manually tripped due to a loss of main condenser vacuum with reactor power above P-10 permissive. All systems functioned as expected. All control rods fully inserted. Main Steam Isolation valves were manually shut. All reactor coolant system parameters are as expected, with reactor coolant temperature being maintained by atmospheric steam dumps. Currently, the plant is at normal operating temperature and pressure with the steam generators being fed by the main feed pumps. Feedwater is being supplied via the condenser and condensate storage tank. There were no lifts of safeties or reliefs during the transient. The plant is in its normal shutdown electrical line-up with no effect on Unit 2. There is no known primary-to-secondary leakage. The cause of the loss of vacuum is under investigation. The licensee has notified the NRC Resident Inspector.
ENS 460809 July 2010 10:44:00Point BeachManual ScramNRC Region 3Westinghouse PWR 2-LoopOn 07/09/10 at 0647 (CDT) hours, control room personnel initiated a manual reactor trip of Unit 2 from approximately 64% power as a result of a failure of the "A" feedwater regulating valve (FRV). All (other) systems functioned as expected. All rods fully inserted into the core. The unit is stable in MODE 3 at normal RCS (Reactor Coolant System) pressure and temperature. The cause of the FRV failure is being investigated. This event is being reported in accordance with 10 CFR 50.72(b)(2)(iv)(B) and 10 CFR 50.72(b)(3)(iv)(A). The unit electrical power is lined up to offsite power in a normal configuration. Decay heat is being removed from the steam generator through the steam dumps to the main condenser. The FRV failed open and the valve controller was unable to place the FRV into the correct position. The steam generator HI-Hi level provided a feedwater isolation signal and a high level lockout of the FRV. Currently, the feedwater bypass valve is controlling steam generator level. There was no impact on Unit 1. The licensee has notified the NRC Resident Inspector.
ENS 4603219 June 2010 11:25:00Point BeachManual ScramNRC Region 3Westinghouse PWR 2-LoopAt 0636 hours, control room personnel initiated a manual reactor trip of Unit 2 from MODE 2 at 0% power. Just prior to the initiation of the manual reactor trip, an automatic turbine trip had occurred as a result of the receipt of a generator lockout signal. Prior to the automatic turbine trip, an orderly power reduction to 44% power had been completed and the unit was being maintained in a stable condition in MODE 1. At the time of the turbine trip, two sets of condenser steam dump valves were isolated, in preparation for scheduled condenser waterbox tube cleaning. Following the manual reactor trip, all safety systems and equipment operated as expected. The cause of the turbine trip, including receipt of the generator lockout signal, is under investigation. The unit is stable in MODE 3 at normal RCS temperature and pressure. This event is being reported in accordance with 10 CFR 50.72(b)(2)(iv)(B) t and 10 CFR 50.72(b)(3)(iv)(A). The NRC Senior Resident Inspector has been notified. Just prior to the trip, the unit was critical in Mode 2. All rods are fully inserted into the core.
ENS 4601816 June 2010 19:20:00Saint LucieManual ScramNRC Region 2CEAt 1710 EDT, Unit 1 was manually tripped due to two dropped control rods. All CEAs (Control Element Assemblies) fully inserted on the trip. Steam generator level control responded as expected and no pressurizer or power operated relief valves opened. RCS heat removal is being maintained by main feedwater and steam bypass control systems. All other systems functioned normally and the plant has stabilized at normal operating temperature and pressure in Mode 3. This non-emergency notification is being made pursuant 10 CFR 50.72(b)(2)(iv)(B) due to manual actuation of RPS. The licensee characterized the manual trip as uncomplicated. The second rod dropped within a very short time of the first rod. The cause of the rod drops is still under investigation. The licensee noted that no activities involving the rod control system were in progress when the event occurred. The licensee was at 45% as part of its post outage power ascension unrelated to the rod drop. The manual reactor trip action was taken per procedure when the second rod dropped. The reactor trip had no impact on Unit 2 operation. The NRC Resident Inspector has been notified.
ENS 4587326 April 2010 05:18:00Duane ArnoldManual ScramNRC Region 3GE-4This report is being made under 50.72(b)(2)(iv)(B) for inserting a manual reactor scram due to rising vibrations on the #6 turbine bearing. A planned reactor shutdown was in progress with reactor power at 13.8% when turbine vibrations approached procedural limits which would require a manual scram of the reactor. The scram was uncomplicated; all control rods fully inserted. The reactor is in Mode 3, Hot Shutdown. Cooldown has been established to the condenser using main steam line drains. The NRC Resident Inspector has been informed.
ENS 4584315 April 2010 17:49:00Saint LucieManual ScramNRC Region 2CEAt 1539 (EDT), Unit 2 was manually tripped due to lifting of the 2B moisture separator reheater relief valve. The Unit commenced a rapid downpower and then a manual reactor trip was initiated at approximately 95% power. All CEA's (control element assemblies) fully inserted on the trip. Auxiliary feedwater automatically initiated on low steam generator level due the 2A steam generator 15% feedwater bypass not opening. No pressurizer power operated relief valves (PORVs) opened. RCS heat removal is now being maintained with auxiliary feedwater and the steam bypass control system. Main feedwater is available. All other systems functioned normally, and the plant is stabilized at normal operating temperature and pressure in Mode 3. This non-emergency notification is being made pursuant to 10 CFR 50.72(b)(2)(iv)(B) due to manual RPS actuation and 10 CFR 50.72(b)(3)(iv)(A) due to auxiliary feedwater system actuation. The licensee notified the NRC Resident Inspector.
ENS 4561911 January 2010 12:54:00Turkey PointManual ScramNRC Region 2Westinghouse PWR 3-LoopAt 1055 on 1/11/2010, Turkey Point Unit 4 was manually tripped on high steam generator level. Steam generator level was high due to plant response to a turbine runback. The runback was manually initiated by stopping the 4A Steam Generator Feed Pump from the Control Room due to mechanical seal failure. At the time of the trip, reactor power was 30%. Auxiliary Feedwater was not required since Steam Generator levels were maintained above the low level actuation setpoint. Unit 4 has been stabilized in Mode 3 on normal off-site power. No significant equipment problems were encountered. This event is reportable per 10 CFR 50.72(b)(2)(iv)(B) - actuation of the Reactor Protection System with the reactor critical. All rods inserted during the trip. There were no relief or safety valves that lifted during the transient. Decay heat is being removed via steam dumps to atmosphere. There is no known primary to secondary leakage. Unit 4 is in a normal shutdown electrical lineup. Unit 3 was not affected by the transient. The licensee has notified the NRC Resident Inspector.