|Entered date||Site||Region||Scram||Reactor type||Event description|
|ENS 52406||4 December 2016 01:48:00||Calvert Cliffs||NRC Region 1||Automatic Scram||CE||On 12/3/16 at 2224 EST, Calvert Cliffs Unit-2 experienced an automatic reactor trip from full power due to a leak in the Unit-2 Main Turbine Electro-Hydraulic Control (EHC) system. The EHC leak caused the Unit-2 Main Turbine governor valves to close, resulting in a turbine trip and automatic reactor trip. The site Outage Control Center is manned, and investigation into the cause of the leak is underway. Unit-2 remains stable in Mode 3 with normal heat removal. Unit-1 remains at full power and was not affected by the trip. The plant is in a normal shutdown electrical lineup. All Control rods fully inserted and no primary or secondary safety relief valves lifted during the trip. The licensee has notified the NRC Resident Inspector. The licensee will be notifying Calvert County.|
|ENS 51683||25 January 2016 05:45:00||Calvert Cliffs||NRC Region 1||Manual Scram||CE||At 0315 EST on 1/25/16, Calvert Cliffs Unit 1 was manually tripped from 10 percent power due to elevated condenser sodium levels. All systems responded per design. Main Feed was secured and auxiliary feed water was initiated. The elevated sodium levels are believed to be due to a condenser tube leak. The reactor is currently shutdown and stable in Mode 3 and will remain in Mode 3 until repairs are effected. Unit 2 was not affected and remains at full power. The Licensee has notified the NRC Resident Inspector.|
|ENS 51577||1 December 2015 20:25:00||Calvert Cliffs||NRC Region 1||Manual Scram||CE||On 12/01/2015 at 1820 EST, the Main Control Room received a 22 Steam Generator Feed Pump trip. The 22 Steam Generator Feed Pump was not able to be reset and the Main Control Room manually tripped the Unit 2 Reactor. The licensee entered Emergency Operating Procedure (EOP)-0, 'Post Trip Immediate Actions' and all safety functions were met. At 1833, Unit 2 transitioned into EOP-1, 'Uncomplicated Reactor Trip.' At 1841, Unit 2 transitioned into Operating Procedure #4 , 'Plant Shutdown from Power to Hot Stand-by.' The plant is stable in Mode 3. All control rods inserted fully on the reactor trip. No primary or secondary safety relief valves lifted. The steam generators are being fed by the 21 steam generator feed pump and decay heat is being dumped to the condenser via the steam dumps. The electric plant is in a normal shutdown electrical lineup and there was no impact on Unit 1. Unit 1 continues to operate at 100 percent power. The cause of the 22 steam generator feed pump trip is still under investigation. The licensee notified the NRC Resident Inspector.|
|ENS 50961||7 April 2015 15:45:00||Calvert Cliffs||NRC Region 1||Automatic Scram||CE|
A loss of Main Generator Load which caused a Reactor Trip on Units 1 & 2. A switchyard voltage transient from a highline occurred, which caused an undervoltage condition on both units' safety related 4KV buses. Unit 1 is on normal heat removal to the condenser. Unit 2 is on auxiliary feedwater and normal condenser bypass valves for temperature control. An Auxiliary Feedwater Actuation System (AFAS) actuation occurred on Unit 2. The (Unit 2) 2B emergency diesel generator did not start and load on its respective 24-4 KV bus. The 24-4KV Bus was repowered from the alternate feeder breaker. Cause of the emergency diesel failure to start is under investigation. All safety functions are met for both units. All control rods fully inserted. The site is in a normal shutdown electrical configuration powered from offsite. The site plans to stay in Mode 3 pending restart. The licensee notified the NRC Resident Inspector, State and local authorities. A press release is planned.
During post trip review, it was determined that the 21 saltwater pump had to be manually started. With the failure of 2B emergency diesel generator, there were no saltwater pumps running for approximately 12 minutes. Additional troubleshooting determined the 2A emergency diesel generator sequencer did not automatically start 21 saltwater pump. The 2B emergency diesel generator was returned to service on 4/8/2015 at 1730 (EDT). The loss of saltwater (pump) and emergency diesel generator is reportable as an event that could have prevented fulfillment of a safety function and is also an unanalyzed condition. The licensee has notified the NRC Resident Inspector. Notified R1DO (Ferdas), IRD MOC (Grant), NRR EO (Morris).
|ENS 49754||22 January 2014 00:33:00||Calvert Cliffs||NRC Region 1||Automatic Scram||CE||Dual Unit Trip due to loss of '21' 13 KV bus . All safety functions are met for both units. Unit 1 remained with normal heat removal. Unit 2 lost power to its normal heat sink and is stable on Auxiliary Feed water and Atmospheric Dump Valves for temperature control. Both trips were automatic trips. Due to loss of power a Under Voltage actuation occurred on both units ('14' and '24' 4Kv bus). Due to loss of main feed on Unit 2 a Auxiliary Feed water Actuation System (AFW) actuation occurred on Unit 2. Cause is under investigation. All control rods fully inserted on the loss of power to the Control Rod Drive Mechanisms (CRDMs). Both Units Reactor Coolant Pumps (RCPs) remained running during the transient. The normal Unit 2 heat sink was unavailable due to the loss of the operating circulating water pumps resulting in a loss of condenser vacuum. The Unit 2 AFW actuation included one of two steam-driven pumps and the motor-driven pump. Both Units Emergency Diesel Generators started and loaded and have since been secured. Both Units are stable and will remain in mode 3 (Hot Standby) pending the results of the investigation. The licensee will inform the NRC Resident Inspector.|
|ENS 49054||21 May 2013 06:20:00||Calvert Cliffs||NRC Region 1||Manual Scram||CE||Reactor trip. All safety functions met with normal heat removal. 22 SGFP (Steam Generator Feedpump) exhibited high vibrations and signs of coupling damage. Further investigation will be performed. All control rods fully inserted on the trip. Steam Generator level is being maintained with the remaining feedpump. Decay heat is being dumped to the main condenser. Electrical power is in the normal shutdown lineup. No relief or safety valves lifted during the trip. There was no effect on Unit 1. The licensee notified the NRC Resident Inspector.|
|ENS 47208||27 August 2011 23:27:00||Calvert Cliffs||NRC Region 1||Automatic Scram||CE|
At 2248 on 8/27/2011, the Unit 1 Reactor experienced an automatic trip due to loss of load. This trip occurred due to a phase to phase short on the main generator output step-up transformer that resulted from a large section of turbine building siding breaking loose in high winds from Hurricane Irene and impacting the transformer. This impact resulted in an explosion (briefly until the trip removed power from the impact area) which met emergency action level declaration criteria A.U.6.2.2, 'Unanticipated explosion within Protected Area resulting in visible damage to permanent structures or equipment.' The Unusual Event was declared at 2302, 8/27/2011. Follow-up investigation determined no fire resulted from the explosion. Following the trip, Emergency Procedure, EOP-0, 'Post Trip Immediate Actions' was implemented. All safety functions were met during EOP-0 indicating an uncomplicated reactor trip response, allowing transition to EOP-1, 'Reactor Trip,' at 2300, 8/27/2011. During implementation of EOP-1, it was noted that #14 Containment Air Cooler had stopped running, as had #21 and #24 Containment Air Coolers on Unit 2. This was investigated and it was determined they had stopped running due to an instantaneous voltage drop that had occurred on the site distribution system during the phase to phase short event. This short duration voltage drop caused the Containment Air Coolers' controller to drop out and secure them. They were restarted without issue. At 2400, 8/27/2011, numerous alarms on the 1A DG started to be received. These were investigated and it was found that water was intruding down the DG exhaust piping resulting in a DC ground. Based on these indications the 1A DG was declared inoperable and appropriate technical specifications implemented. Besides the above issues plant response was as expected and EOP-1 was exited at 0130, 8/28/2011. (Procedure) OP-4, 'Shutdown from Power Operation to Hot Standby,' was implemented at that time. All control rods fully inserted on the reactor trip. The plant is in a normal post-trip electrical lineup. The licensee notified the NRC Resident Inspector.
* * * UPDATE FROM GREGG BUCKMASTER TO PETE SNYDER AT 0811 EDT ON 8/28/11 * * *
At 0755 EDT the licensee exited the Unusual Event condition based on the fact that they were able to inspect the area in the daylight and were satisfied that they knew the extent and nature of the damage. The licensee will notify the NRC Resident Inspector. Notified R1 IRC (Dentel), DHS (Hill), FEMA (Via).
|ENS 45709||18 February 2010 11:47:00||Calvert Cliffs||NRC Region 1||Automatic Scram||CE||Both U-1 and U-2 automatically tripped due to valid actuation of the Reactor Protection Systems (RPS). U-1 due to loss of 12B Reactor Coolant Pump (RCP) which resulted in a RCS Low Flow RPS Trip. Cause for loss of 12B RCP is currently not known but is suspected to be related to the electrical transient that occurred on U-2. U-2 tripped due to Loss of Load RPS Trip when the main turbine tripped due to an electrical malfunction and partial loss of offsite power. The electrical malfunction resulted in loss of power to all 4 Kv buses on U-2 with the exception of 21 4Kv bus (ZA train power) (Lost 22-26 4Kv buses) and the loss of 14 Kv bus (ZB train power) on U-1. All the buses lost are powered from the same in house service transformer, P-13000-2, which was lost due to the electrical transient. Cause of the electrical transient is being pursued but is unknown at this time. Loss of the 14 4Kv bus on U-1 and the 24 4Kv bus on U-2 resulted in an Engineered Safeguards Actuation System (ESFAS) valid actuations on both units due to Under Voltage (UV) conditions on those buses. The 1B (Diesel Generator) DG started automatically due to the 14 bus UV and is carrying that bus. The 2B DG received an automatic start signal due to the 24 bus UV but failed to start as expected. No other system actuations occurred. Both units are currently stable in Mode 3 at normal operating temperature (532 degrees) and pressure (2250 PSIA) with no other significant equipment malfunctions. Due to the loss of P-13000-2 (transformer), U-2 sustained a loss of normal heat removal due to loss of the main condenser cooling and the loss of secondary pumps. U-2 is removing heat with auxiliary feedwater pumps and (Steam Generator) SG atmospheric dump valves without issues. Current plans are to cool U-2 down to 445 degrees to maintain RCP seals cool until RCP's can be restarted. A decision on U-1 cool down has not yet been made. There is no primary to secondary leakage. U-2 is currently in a 12 hour LCO due to the partial loss of offsite power and 2B DG failing to start. The licensee has notified the NRC Resident Inspector.|
|ENS 43046||12 December 2006 11:17:00||Calvert Cliffs||NRC Region 1||Manual Scram||CE||At 0907 Calvert Cliffs Unit 1 experienced a manual reactor trip during turbine control maintenance. Maintenance was being performed on turbine control to replace circuit cards. This system is a two out of three logic system. Only one logic branch was being de-powered at a time. When the first logic branch was de-powered, the control room supervisor noticed a transient on the reactor coolant system and ordered a manual trip. Decay heat is being removed via normal methods through the Turbine Bypass Valves to the condenser. At the time of the trip, 11 Auxiliary Feedwater (AFW) Pump was being tested but it was not feeding the steam generators. This was an uncomplicated trip. The plant responded normally to the event. All control rods fully inserted. The plant is stable and operators are maintaining the unit in Hot Standby. The licensee notified the NRC Resident Inspector. The trip had no effect on Unit 2, The licensee was in no significant safety system LCO action statement at the time (other than for the AFW 11 surveillance that was in progress at the time of the event.) The steam generators remained on normal feed throughout the event. No Porv's or safeties lifted during the transient. All systems functioned as required. The licensee is investigating how de-powering only one control system logic circuits resulted in the transient.|
|ENS 42995||16 November 2006 03:02:00||Calvert Cliffs||NRC Region 1||Automatic Scram||CE|
At 0018 Calvert Cliffs Unit 2 experienced an automatic reactor trip due to a turbine trip. "At the time a clearance order was being performed for upcoming maintenance on P-13000-2 (transformer). As a result of the turbine trip, RCS pressure rose to approximately 2420 psia causing the PORV's to open. Unexpectedly, a Pressurizer Safety Valve, RV-200 also lifted and reclosed when RCS pressure was lowered to approximately 1500 psia. As a result of the pressure decrease, a Safety Injection Actuation Signal (SIAS) occurred. Once the Pressurizer Safety Valve reclosed, RCS pressure began to rise to return to normal values. Decay heat is being removed via normal methods through the Turbine Bypass Valves to the Condenser. Normal Feedwater is being used. No Auxiliary Feedwater actuation occurred. Two Reactor Coolant Pumps were secured as a result of the SIAS. The plant responded normally to the event. The plant is currently stable and operators are conducting a plant cooldown to mode 5. All control rods fully inserted. The licensee notified the NRC Resident Inspector.
The automatic trip was due to high RCS pressure from the closure of the Turbine Intercept Valves. Both PORV's opened as designed. One remained open approximately 1.5 minutes causing RCS pressure to reduce to 1500 psia. The PORV should have closed at 2400 psia. Relief Valve 200 (RV-200) did not open as previously reported and was not the cause of the RCS pressure lowering. Acoustic monitoring indication were due to the close proximity of the PORV. Since the SIAS signal did not cause a reportable ECCS actuation, the reported 50.72(b)(2)(iv)(A) ECCS Actuation is retracted. The licensee notified the NRC Resident Inspector. Notified R1DO (P. Henderson).
Upon further review, the licensee has determined that this event met the criteria for Unusual Event Emergency Action Level (EAL A.U.2.2.1) for identified RCS leakage greater than 25 gpm. The licensee met this criteria for the duration that the PORV valve remained open (less than 2 minutes). The licensee did not recognize that it had met the criteria at the time of the event and is reporting this as an after-the-fact emergency condition of unusual event per the guidance in NUREG-1022. The licensee notified the NRC Resident Inspector. Notified R1DO (P. Henderson), NRR EO (Ross-Lee), and IRD Manager (Leach).
|ENS 42484||9 April 2006 02:37:00||Calvert Cliffs||NRC Region 1||Manual Scram||CE||During the performance of PSTP-2, Low Power Physics Testing on U-1 for Regulating Control Element Assemblies Group 2, CEA #21 was declared untrippable, Technical Specification 3.1.4.F, CEA Alignment, was entered and Plant shutdown to Mode 3 was commenced at 2342 on 4/8/06. The reactor is shutdown in Mode 3. The licensee borated to maintain adequate shutdown margin. The reactor trip breakers were opened but CEA #21 remains not fully inserted into the core. The licensee is currently troubleshooting to determine the cause of the stuck CEA. Offsite power is stable and powers the safety buses. Emergency Diesel Generators are available. The licensee is currently at normal operating pressure and temperature with decay heat being removed by the steam generators steaming to the condenser. The licensee notified the NRC Resident Inspector.|
|ENS 41452||1 March 2005 02:51:00||Calvert Cliffs||NRC Region 1||Manual Scram||CE||The following details were provided by the licensee via fax as part of their telephonic notification: Manual reactor scram due to high turbine generator vibration during a planned Unit 1 power reduction to Mode 2 to perform maintenance to replace the vent line piping on 11 MSR drain tank. The manual reactor scram was initiated per AOP-7E, section V, 'High Turbine Vibration' trip criteria when bearing #5 exceeded 12 mils vibration. This event meets NUREG-1022 Rev. 2, Section 3.2.6 'System Actuation' Part 50.72(b)(2)(iv)(B) 'Any event or condition that results in actuation of the reactor protection system (RPS) when the reactor is critical except when the actuation results from and is part of a pre-planned sequence during testing or reactor operation.' All rods fully inserted and no ECCS or relief valve actuations occurred. Heat sink is the condenser and turbine bypass valves. The NRC resident inspector was notified.|
|ENS 40601||20 March 2004 15:25:00||Calvert Cliffs||NRC Region 1||Automatic Scram||CE|
At 1340 on 3/20/2004, Calvert Cliffs Unit 1 Reactor automatically shutdown due to low Steam Generator Water Level. The low water level was caused by a loss of at least one Steam Generator Feed Pump. The loss was initially caused by a short or ground from Chart Recorder maintenance in Panel 1C29. 1C29 is a control panel in the control room. The chart recorder was a 500KV Bus Voltage Monitor. The post trip primary indications responded normally. The auto steam dump operation responded normally until the quick open signal was cleared at which time the Turbine Bypass Valves failed shut. It is unclear at this time why they failed shut. Steam dump continues through the use of the Atmospheric dump valves and feedwater is supplied via the Auxiliary Feedwater System with the use of 11 (Steam Driven Pump) & 13 AFW Pump (electric driven pump). Lowest Steam Generator Level was -210" in 11 S/G and -115" in 12 S/G level.
All control rods properly inserted into the reactor core. The NRC Resident Inspector was notified.
|ENS 40472||23 January 2004 17:45:00||Calvert Cliffs||NRC Region 1||Manual Scram|
At 1529 ET the reactor was manually tripped due to low steam generator level as a result of the loss of the 22 SGFP (Steam Generator Feed Pump). When the reactor was tripped, the turbine bypass and atmospheric dump valves went full open and did not shut. This lead to a SIAS (Safety Injection Actuation Signal) and SGIS (Steam Generator Isolation Signal). At 1718 ET, a second SIAS actuation occurred while reestablishing pressurizer level. The cause of the SGFP trip is unknown. The cause of the over steaming on turbine bypass valves and atmospheric dump valves is unknown. All control rods fully inserted. Auxiliary Feedwater initiated normally. The licensee stated that there was no actual ECCS injection to the RCS. The plant electrical system responded normally and all emergency diesel generators remain operable. All ECCS systems remain operable. There are no primary to secondary leaks. Decay heat is currently being removed via the steam-driven auxiliary feedwater pump and the atmospheric steam dumps. As of 1830 ET, primary pressure is approximately 2103 psi and pressurizer level is at 242 inches. Plant conditions are being stabilized at normal hot standby values . The licensee notified the NRC Resident Inspector who responded to the Control Room.
The licensee reported that their post trip review determined that the reactor received an automatic trip about 2 seconds before the manual trip. The automatic trip was due to low steam generator water level. The licensee notified the NRC Resident Inspector. Notified NRR (Reis) and R1DO (Meyer)
During post event review of the 1/23/04 Rx Trip event (40472), it was discovered that Unit 2 met the entry criteria for EOP-4, Excess Steam Demand event. This condition required declaration of an Unusual Event. No declaration was made at the time because of the transitory nature of the condition. Transitory conditions such as this, however, still require reporting per NUREG-1022, Rev. 2. Immediate notification to the NRC via the Emergency Notification System is required per 10 CFR 50.72(a)(1)(i). The NRC Resident Inspector will be notified.