05000317/LER-2015-002, Regarding Automatic Reactor Trips Due to Transmission System Disturbance
| ML15160A321 | |
| Person / Time | |
|---|---|
| Site: | Calvert Cliffs  |
| Issue date: | 06/05/2015 |
| From: | Flaherty M Exelon Generation Co |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| LER 15-002-00 | |
| Download: ML15160A321 (6) | |
| Event date: | |
|---|---|
| Report date: | |
| Reporting criterion: | 10 CFR 50.73(a)(2)(i) 10 CFR 50.73(a)(2)(vii), Common Cause Inoperability 10 CFR 50.73(a)(2)(ii)(A), Seriously Degraded 10 CFR 50.73(a)(2)(viii)(A) 10 CFR 50.73(a)(2)(ii)(B), Unanalyzed Condition 10 CFR 50.73(a)(2)(viii)(B) 10 CFR 50.73(a)(2)(iii) 10 CFR 50.73(a)(2)(ix)(A) 10 CFR 50.73(a)(2)(iv)(A), System Actuation 10 CFR 50.73(a)(2)(x) 10 CFR 50.73(a)(2)(v)(A), Loss of Safety Function - Shutdown the Reactor 10 CFR 50.73(a)(2)(v)(B), Loss of Safety Function - Remove Residual Heat 10 CFR 50.73(a)(2)(i)(A), Completion of TS Shutdown 10 CFR 50.73(a)(2)(v), Loss of Safety Function 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications 10 CFR 50.73(a)(2)(iv)(B)(1) 10 CFR 50.73(a)(2)(iv)(B)(8) 10 CFR 50.73(a)(2)(iv)(B), System Actuation |
| 3172015002R00 - NRC Website | |
text
Mark Flaherty Exelon GenerationG Plant Manager Calvert Cliffs Nuclear Power Plant 1650 Calvert Cliffs Parkway Lusby, MD 20657 410 495 5205 Office 443-534-5475 Mobile www exeloncoro.com mark.flaherty@exeloncorp.com 10 CFR 50.73 June 5, 2015 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555 Calvert Cliffs Nuclear Power Plant, Unit Nos. 1 and 2 Renewed Facility Operating License Nos. DPR-53 and DPR-69 NRC Docket Nos. 50-317 and 50-318
Subject:
Licensee Event Report 2015-002, Revision 00 Calvert Cliffs Unit 1 and Unit 2 Automatic Reactor Trips Due to Transmission System Disturbance The attached report is being sent to you as required by 10 CFR 50.73.
There are no regulatory commitments contained in this correspondence.
Should you have questions regarding this report, please contact Mr. Larry D. Smith at (410) 495-5219.
Respectfully, Mark D. Flaherty Plant Manager MDF/SMR/bjd
Attachment:
As stated cc:
NRC Project Manager, Calvert Cliffs NRC Resident Inspector, Calvert Cliffs NRC Regional Administrator, Region I S. Gray, MD-DNR
1.
NRC FORM 366 U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB: NO. 3150-0104 EXPIRES: 01/31/2017 (02-2014)
Estimated burden per response to comply with this mandatory collection request: 80 hours9.259259e-4 days <br />0.0222 hours <br />1.322751e-4 weeks <br />3.044e-5 months <br />. Reported lessons learned are incorporated into the licensing process and fed back to industry. Send comments regarding burden estimate to the FOIA, Privacy and Information Collections Branch (T-5 F53),
LICENSEE EVENT REPORT (LER)
U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001, or by intemet e-mail to lnfocollects.Resource@nrc.gov, and to the Desk Officer, Office of Information and Regulatory Affairs, NEOB-10202, (3150-0104), Office (See Page 2 for required number of of Management and Budget, Washington, DC 20503. If a means used to impose an information collection does not display a currently valid OMB digits/characters for each block) control number, the NRC may not conduct or sponsor, and a person is not N required to respond to, the information collection.
- 3. PAGE Calvert Cliffs Nuclear Power Plant, Unit 1 05000317 1 OF 5
- 4. TITLE Calvert Cliffs Unit 1 and Unit 2 Automatic Reactor Trips Due to Transmission System Disturbance
- 5. EVENT DATE
- 6. LER NUMBER _
- 7. REPORT DATE
- 8. OTHER FACILITIES INVOLVED MONTH DAY YEAR YEAR SEQUENTIAL REVI MONTH I YE.
FACILITY NAME 05000 NUMBER NO. I MONTH DAY YEAR iCalvert Cliffs Unit 2 318 I
FACILITY NAME 04 07 2015 2015 - 002 -
00 06 05 2015
- 9. OPERATING MODE
- 11. THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR§: (Check all that apply)
[1 20.2201(b)
El 20.2203(a)(3)(i)
[I 50.73(a)(2)(i)(C)
El 50.73(a)(2)(vii) 1 [1 20.2201(d)
El 20.2203(a)(3)(ii)
El 50.73(a)(2)(ii)(A)
El 50.73(a)(2)(viii)(A) 0l 20.2203(a)(1)
El 20.2203(a)(4) 0 50.73(a)(2)(ii)(B)
El 50.73(a)(2)(viii)(B)
[I 20.2203(a)(2)(i)
El 50.36(c)(1)(i)(A)
[I 50.73(a)(2)(iii)
[I 50.73(a)(2)(ix)(A)
- 10. POWER LEVEL El 20.2203(a)(2)(ii)
[I 50.36(c)(1)(ii)(A)
Z 50.73(a)(2)(iv)(A)
El 50.73(a)(2)(x)
El 20.2203(a)(2)(iii)
[I 50.36(c)(2)
El 50.73(a)(2)(v)(A)
El 73.71 (a)(4) 100 El 20.2203(a)(2)(iv)
[I 50.46(a)(3)(ii)
El 50.73(a)(2)(v)(B)
[] 73.71(a)(5)
El 20.2203(a)(2)(v)
El 50.73(a)(2)(i)(A)
[I 50.73(a)(2)(v)(C)
El 50.73(a)(2)(vii)
El 20.2203(a)(2)(vi)
El 50.73(a)(2)(i)(B) 0 50.73(a)(2)(v)(D)
Specify in Abstract below or in =
- 1.
DESCRIPTION OF EVENT
Energy Industry Identification System (EIIS) codes are typically identified in the text as [XX].
A.
INITIAL CONDITIONS:
Both Unit 1 and Unit 2 were operating at 100 percent power in Mode 1 on April 7, 2015 prior to the event.
B.
EVENT:
On April 7, 2015 at 1239, Unit 1 and Unit 2 reactors [RCT] tripped during a degraded grid event.
The Unit 1 Main Turbine Generator [TG] lost field excitation thus causing a turbine trip on loss of load and subsequent reactor trip. The Steam Generator Feed Pumps (SGFP) [SB P] tripped due to loss of power effects and Auxiliary Feedwater (AFW.) [SA] was manually actuated.
Unit 2 also experienced a loss of load causing the Unit 2 reactor to trip. The Unit 2 trip was complicated by the 2B Emergency Diesel Generator (EDG) [EK] failing to energize the 24 4 kV Engineered Safety Features (ESF) Bus [BU] following loss of power to the bus due to the under voltage condition. The 2B EDG started but tripped due to a failed electronic speed switch [SS]
in the startup circuitry. Normal power was manually restored to the 24 4 kV ESF bus.
Additionally, the shutdown sequencer [JE 44] for the 2A EDG did not perform its safety function to automatically restart selected equipment. Most significantly, the shutdown sequencer failure resulted in a failure of the 21 Saltwater (SW) [BS] pump to be automatically restarted following loss of power to 21 4 kV ESF bus. This failure, combined with the loss of power to 24 4 kV ESF bus, resulted in the loss of flow in both SW trains for 12 minutes until 21 SW pump was subsequently restarted manually. The SGFPs tripped due to loss of power effects and an Auxiliary Feedwater Actuation Signal (AFAS) [BA] started the AFW pumps.
Operator actions were appropriate and in accordance with procedures and proper stabilizing actions were taken to successfully manage a dual unit trip.
C.
INOPERABLE STRUCTURES, COMPONENTS, OR SYSTEMS THAT CONTRIBUTED TO THE EVENT:
There were no inoperable structures, components, or systems at the start of the event that contributed to the event.
D.
DATES AND APPROXIMATE TIMES OF MAJOR OCCURRENCES
April 7, 2015 (1239) Units 1 and 2 experienced reactor trips due to degraded grid voltage condition.
April 7, 2015 (1239) Units 1 and 2 - ESF bus undervoltage
April 7, 2015 (1239) Unit 2 - 2A EDG started and the shutdown sequencer failed April 7, 2015 (1239) Unit 2 - 21 SW pump doesn't start due to failed shutdown sequencer April 7, 2015 (1239) Unit 2 - 2B EDG started but failed to energize 24 4 kV ESF bus April 7, 2015 (1251) Unit 2 - 21 SW pump manually started April 7, 2015 (1259) Unit 2 - Normal power restored to the 24 4 kV ESF bus April 7, 2015 (1545) Event Notification 50961 made to the Nuclear Regulatory Commission (NRC) due to automatic system actuations on Units land 2 April 8, 2015 (1730) Unit 2 - 2B EDG restored April 9, 2015 (0336) Update to ENS#50961 to add the subsequent determination that a loss of safety function and an unanalyzed condition had occurred on Unit 2.
April 9, 2015 (0433) Unit 2 - 2A EDG shutdown sequencer restored April 9, 2015 (0631) Unit 1 paralleled to the grid April 9, 2015 (1432) Unit 2 paralleled to the grid E.
FAILURE MODES:
The 2B EDG started but failed to energize the 24 4 kV ESF bus following the Unit 2 trip. The cause of the failure was a failed speed switch due to a failed integrated circuit (IC) chip. A new speed switch was installed and tested satisfactorily prior to its return to operation. The 2B EDG was inoperable for approximately 29 hours3.356481e-4 days <br />0.00806 hours <br />4.794974e-5 weeks <br />1.10345e-5 months <br />.
The shutdown sequencer failed to load some equipment onto the 21 4 kV ESF bus due to a failed IC chip in step 1 of the sequencer. A replacement shutdown sequencer was installed and tested satisfactorily prior to its return to operation. The shutdown sequencer was returned to service following 2B EDG return to service. The shutdown sequencer was inoperable for approximately 40 hours4.62963e-4 days <br />0.0111 hours <br />6.613757e-5 weeks <br />1.522e-5 months <br />.
F.
METHOD OF DISCOVERY
The event was self-revealing. The reactor trip event is documented in station Issue Report number 02481527. The 2B EDG failure to start and the shutdown sequencer failure are documented in station Issue Report number 02484165.
II.
CAUSE OF EVENT
The root cause of the reactor trip event was determined to be an off-site grid disturbance resulting in an undervoltage condition (transient under voltage relays actuated) on the 4 kV ESF buses.
The root cause of the 2B EDG failure to load was due to a failure of the input transistors on an IC chip in the speed switch. The cause of the shutdown sequencer failure was due to a failure of the U-8 IC chip in the step 1 portion of the sequencer.
A.
SAFETY CONSEQUENCES
The Reactor Protection System (RPS) [JC] on both Unit 1 and Unit 2 automatically actuated on loss of load and tripped the Units.
The 2B EDG failed to energize 24 4 kV ESF bus following 24 4 kV ESF bus loss of power due to the undervoltage condition. Normal power was manually restored to the 24 4 kV ESF bus. The shutdown sequencer for the 2A EDG did not automatically load the 21 SW pump onto the 21 4 kV ESF bus. The 21 SW pump was manually started. The Unit 2 SGFP's tripped due to loss of power effects and an AFAS started the AFW pumps.
This event did not result in any actual nuclear safety consequences. The safety significance of this event was that Calvert Cliffs experienced an undervoltage condition on each unit's safety-related 4 kV ESF buses that resulted in automatic actuation of the reactor protection system and the emergency diesel generators to safely shutdown each unit. While Unit 1 equipment performed their required safety functions, the failure of 2B EDG to energize 24 4 kV ESF bus and the failure of 21 4 kV ESF bus shutdown sequencer resulted in the trip on Unit 2 being classified as an unplanned scram with complications. Despite these failures, Operations was able to effectively perform a safe shutdown of both units.
This event was reviewed for probable risk assessment impact. For Unit 1 the estimated conditional core damage probability was 1 E-6 while the Unit 2 estimated conditional core damage probability damage was 2 E-5. These conditional core damage probability damage values fall into a range which triggered a NRC special inspection team investigation. There were no NRC identified findings from the inspection.
This event is reportable against several criteria in NUREG-1 022, Revision 3. Both Unit 1 and 2 tripped on loss of load (RPS actuation), therefore the event meets the criteria of 10 CFR 50.73 (a)(2)(iv)(B)(1). For Unit 1 the EDGs were automatically actuated which is reportable under 10 CFR 50.73(a)(2)(iv)(B)(8). On Unit 2, the EDGs and AFW were automatically actuated, which is reportable under 10 CFR 50.73(a)(2)(iv)(B), sections (6) and (8). Since both Unit 2 EDGs were inoperable at the same time, this event is also reportable as an unanalyzed condition 50.73(a)(2)(ii)(B), and a condition that could have prevented the fulfilment of a safety function 50.73(a)(2)(v)(D). The event was reported in ENS 50961.
B.
CORRECTIVE ACTIONS
The failed 2B EDG speed switch and the 2A EDG shutdown sequencer were replaced and tested satisfactorily prior to restart of Unit 2.
Future corrective actions are:
Evaluate, design, approve, and implement a speed switch modification to eliminate it as a single-point failure risk.
Procure and install a newly manufactured shutdown sequencer in each channel.
II1.
PREVIOUS SIMILAR EVENTS
There was a dual unit trip in 2010 (LER 317/318-2010-001) and 2014 (317/318-2014-001).
There were no common initiating events amongst all these events. The commonality between those two trips and the 2015 event is that due to various equipment issues each Unit 2 trip met the criteria for being an unplanned scram with complications. In 2010 the 2B EDG tripped on low lube oil pressure due to a failed Agastat relay; in 2015 the 2B EDG started but tripped due to a failed speed switch. The previous dual unit trip investigations and resulting corrective actions to prevent recurrence would not have prevented this event.
A.
COMPONENT INFORMATION:
The 2A/2B EDGs are manufactured by Fairbanks Morse (F010).
" The LOCI/SDS Sequencer is manufactured by Vitro Labs Division Automation Indication Incorporated (V124), part number 1628-1076.
The EDG Speed Switch is manufactured by Synchro-Start Products (S519), Model ESSB-2AT, part number SA-1 905.