Event Notification Report for March 16, 2003
U.S. Nuclear Regulatory Commission
Operations Center
EVENT REPORTS FOR
03/15/2003 - 03/16/2003
Power Reactor
Event Number: 39672
Facility: BROWNS FERRY
Region: 2 State: AL
Unit: [] [2] []
RX Type: [1] GE-4,[2] GE-4,[3] GE-4
NRC Notified By: RAYMOND SWAFFORD
HQ OPS Officer: HOWIE CROUCH
Region: 2 State: AL
Unit: [] [2] []
RX Type: [1] GE-4,[2] GE-4,[3] GE-4
NRC Notified By: RAYMOND SWAFFORD
HQ OPS Officer: HOWIE CROUCH
Notification Date: 03/16/2003
Notification Time: 10:58 [ET]
Event Date: 03/16/2003
Event Time: 05:25 [CST]
Last Update Date: 03/16/2003
Notification Time: 10:58 [ET]
Event Date: 03/16/2003
Event Time: 05:25 [CST]
Last Update Date: 03/16/2003
Emergency Class: NON EMERGENCY
10 CFR Section:
50.72(b)(3)(v)(D) - ACCIDENT MITIGATION
10 CFR Section:
50.72(b)(3)(v)(D) - ACCIDENT MITIGATION
Person (Organization):
DAVID AYRES (R2)
DAVID AYRES (R2)
| Unit | SCRAM Code | RX Crit | Initial PWR | Initial RX Mode | Current PWR | Current RX Mode |
|---|---|---|---|---|---|---|
| 2 | N | Y | 31 | Power Operation | 31 | Power Operation |
ACCIDENT MITIGATION SYSTEM INADVERTENT ISOLATION
The following information was obtained from the licensee via facsimile:
"ON 03/16/2003 AT APPROXIMATELY 0525 CST, HPCI ISOLATED AND TRIPPED DURING PERFORMANCE OF 2-SR-3.5.1.7, HPCI MAIN & BOOSTER PUMP SET DEVELOPED HEAD & FLOW RATE TEST. INITIAL INDICATIONS [ARE] HPCI ISOLATED ON A HIGH STEAM FLOW SIGNAL. THERE IS NO INDICATION OF A STEAM LINE BREAK. INVESTIGATION IS ON-GOING.
"THIS IS REPORTABLE AS A 8-HOUR NON-EMERGENCY EVENT 10CFR50.72(b)(3)(v), AND A 60 DAY WRITTEN REPORT 10CFR50.73(a)(2)(vii), AS "ANY EVENT OR CONDITION THAT AT THE TIME OF DISCOVERY COULD HAVE PREVENTED THE [FULFILLMENT] OF THE SAFETY FUNCTION OF STRUCTURES OR SYSTEMS THAT ARE NEEDED TO:
(A) SHUTDOWN THE REACTOR AND MAINTAIN IT IN A SAFE SHUTDOWN CONDITION
(B) REMOVE RESIDUAL HEAT
(C) CONTROL THE RELEASE OF RADIOACTIVE MATERIAL; OR
(D) MITIGATE THE CONSEQUENCES OF AN ACCIDENT."
The licensee will notify the NRC Resident Inspector.
The following information was obtained from the licensee via facsimile:
"ON 03/16/2003 AT APPROXIMATELY 0525 CST, HPCI ISOLATED AND TRIPPED DURING PERFORMANCE OF 2-SR-3.5.1.7, HPCI MAIN & BOOSTER PUMP SET DEVELOPED HEAD & FLOW RATE TEST. INITIAL INDICATIONS [ARE] HPCI ISOLATED ON A HIGH STEAM FLOW SIGNAL. THERE IS NO INDICATION OF A STEAM LINE BREAK. INVESTIGATION IS ON-GOING.
"THIS IS REPORTABLE AS A 8-HOUR NON-EMERGENCY EVENT 10CFR50.72(b)(3)(v), AND A 60 DAY WRITTEN REPORT 10CFR50.73(a)(2)(vii), AS "ANY EVENT OR CONDITION THAT AT THE TIME OF DISCOVERY COULD HAVE PREVENTED THE [FULFILLMENT] OF THE SAFETY FUNCTION OF STRUCTURES OR SYSTEMS THAT ARE NEEDED TO:
(A) SHUTDOWN THE REACTOR AND MAINTAIN IT IN A SAFE SHUTDOWN CONDITION
(B) REMOVE RESIDUAL HEAT
(C) CONTROL THE RELEASE OF RADIOACTIVE MATERIAL; OR
(D) MITIGATE THE CONSEQUENCES OF AN ACCIDENT."
The licensee will notify the NRC Resident Inspector.
Power Reactor
Event Number: 39673
Facility: COMANCHE PEAK
Region: 4 State: TX
Unit: [1] [] []
RX Type: [1] W-4-LP,[2] W-4-LP
NRC Notified By: STEVEN SEWELL
HQ OPS Officer: HOWIE CROUCH
Region: 4 State: TX
Unit: [1] [] []
RX Type: [1] W-4-LP,[2] W-4-LP
NRC Notified By: STEVEN SEWELL
HQ OPS Officer: HOWIE CROUCH
Notification Date: 03/17/2003
Notification Time: 01:25 [ET]
Event Date: 03/16/2003
Event Time: 21:49 [CST]
Last Update Date: 03/17/2003
Notification Time: 01:25 [ET]
Event Date: 03/16/2003
Event Time: 21:49 [CST]
Last Update Date: 03/17/2003
Emergency Class: NON EMERGENCY
10 CFR Section:
50.72(b)(2)(iv)(B) - RPS ACTUATION - CRITICAL 50.72(b)(3)(iv)(A) - VALID SPECIF SYS ACTUATION
10 CFR Section:
50.72(b)(2)(iv)(B) - RPS ACTUATION - CRITICAL 50.72(b)(3)(iv)(A) - VALID SPECIF SYS ACTUATION
Person (Organization):
MARK SHAFFER (R4)
MARK SHAFFER (R4)
| Unit | SCRAM Code | RX Crit | Initial PWR | Initial RX Mode | Current PWR | Current RX Mode |
|---|---|---|---|---|---|---|
| 1 | M/R | Y | 100 | Power Operation | 0 | Hot Standby |
MANUAL REACTOR TRIP AND AUXILIARY FEEDWATER ACTUATION DUE TO CONDENSATE PUMP TRIP
The following information was obtained from the licensee via facsimile:
"Unit 1 manual reactor trip (RPS actuation) was initiated at 2149 [CST] due to a loss of main feedwater. The event was initiated by a trip of Condensate Pump 1-01 which resulted in a trip of Main Feedwater Pump 'B' and Main Feedwater Pump 'A' due to inadequate suction pressure.
"An automatic initiation of Auxiliary Feedwater (ESF actuation) occurred when both Main Feedwater Pumps tripped.
"Unit 1 is currently in Hot Standby (Mode 3) with decay heat removal via Auxiliary Feedwater and Steam Dump to the Main Condenser. All safety systems responded appropriately. The cause of the Condensate Pump 1-01 trip is currently under investigation."
All control rods fully inserted. There are no indications of any primary-to-secondary leakage. There were no primary or secondary power operated relief or manual relief valves lifted. The electrical grid is stable. The licensee did receive low steam generator level alarms (as expected) but levels were recovered and are being maintained via the Auxiliary Feedwater system. Unit 2 is stable and was not affected by the Unit 1 trip.
The licensee has notified the NRC Resident Inspector.
The following information was obtained from the licensee via facsimile:
"Unit 1 manual reactor trip (RPS actuation) was initiated at 2149 [CST] due to a loss of main feedwater. The event was initiated by a trip of Condensate Pump 1-01 which resulted in a trip of Main Feedwater Pump 'B' and Main Feedwater Pump 'A' due to inadequate suction pressure.
"An automatic initiation of Auxiliary Feedwater (ESF actuation) occurred when both Main Feedwater Pumps tripped.
"Unit 1 is currently in Hot Standby (Mode 3) with decay heat removal via Auxiliary Feedwater and Steam Dump to the Main Condenser. All safety systems responded appropriately. The cause of the Condensate Pump 1-01 trip is currently under investigation."
All control rods fully inserted. There are no indications of any primary-to-secondary leakage. There were no primary or secondary power operated relief or manual relief valves lifted. The electrical grid is stable. The licensee did receive low steam generator level alarms (as expected) but levels were recovered and are being maintained via the Auxiliary Feedwater system. Unit 2 is stable and was not affected by the Unit 1 trip.
The licensee has notified the NRC Resident Inspector.