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On May 6, 2009, Beaver Valley Power Statio … On May 6, 2009, Beaver Valley Power Station Unit 1 was in Mode 5 during a refueling outage. At 1352, a Low Steam Line Pressure Reactor Trip and Safety Injection (SI) signal was unexpectedly received on Train A. The Train A Emergency Diesel Generator started upon the SI signal, as designed, but did not load since there was no actual emergency bus low voltage condition. The Train A Charging pump (Emergency Core Cooling Pump) was in service and operating before the generation of the SI signal, and continued to operate following the SI signal. Other plant components not isolated for plant outage conditions properly actuated in response to the generated SI signal.</br>A SI Block must be inserted whenever the Solid State Protection System (SSPS) is operating in Mode 5 to prevent a SI signal from being generated on low steam line pressure since steam line pressure will be below the low steam line pressure setpoint. Since the plant was in Mode 5 (temperature less than 200F), there can be no steam in the steam lines. Thus, the receipt of a Low Steam Line Pressure Safety Injection signal while the plant was in Mode 5 was invalid.</br>It was determined that the SI Block was removed due to a degraded Steam Line Pressure SI Block/Reset switch on the control room benchboard. Further troubleshooting detected a similar erratic type degradation on the Train A Pressurizer SI Block switch. Both switches were replaced.</br>This event is reportable pursuant to 10 CFR 50.73(a)(2)(iv)(A) since it involved an actuation of the Reactor Protection System (RPS) per 10 CFR 50.73(a)(2)(iv)(B)(1), an Emergency Core Cooling System (ECCS) pump per 10 CFR 50.73(a)(2)(iv)(B)(3), and an Emergency Diesel Generator (EDG) per 10 CFR 50.73(a)(2)(iv)(B)(8). However, pursuant to 10 CFR 50.73(a)(1), this event is being reported via this telephone notification, instead of</br>submitting a written Licensee Event Report, since the automatic actuation of the RPS, ECCS Pump and EDG was not generated by a valid actuation.</br>The licensee notified the NRC Resident Inspector.ensee notified the NRC Resident Inspector.
17:52:00, 6 May 2009 +
45,099 +
08:59:00, 28 May 2009 +
17:52:00, 6 May 2009 +
On May 6, 2009, Beaver Valley Power Statio … On May 6, 2009, Beaver Valley Power Station Unit 1 was in Mode 5 during a refueling outage. At 1352, a Low Steam Line Pressure Reactor Trip and Safety Injection (SI) signal was unexpectedly received on Train A. The Train A Emergency Diesel Generator started upon the SI signal, as designed, but did not load since there was no actual emergency bus low voltage condition. The Train A Charging pump (Emergency Core Cooling Pump) was in service and operating before the generation of the SI signal, and continued to operate following the SI signal. Other plant components not isolated for plant outage conditions properly actuated in response to the generated SI signal.</br>A SI Block must be inserted whenever the Solid State Protection System (SSPS) is operating in Mode 5 to prevent a SI signal from being generated on low steam line pressure since steam line pressure will be below the low steam line pressure setpoint. Since the plant was in Mode 5 (temperature less than 200F), there can be no steam in the steam lines. Thus, the receipt of a Low Steam Line Pressure Safety Injection signal while the plant was in Mode 5 was invalid.</br>It was determined that the SI Block was removed due to a degraded Steam Line Pressure SI Block/Reset switch on the control room benchboard. Further troubleshooting detected a similar erratic type degradation on the Train A Pressurizer SI Block switch. Both switches were replaced.</br>This event is reportable pursuant to 10 CFR 50.73(a)(2)(iv)(A) since it involved an actuation of the Reactor Protection System (RPS) per 10 CFR 50.73(a)(2)(iv)(B)(1), an Emergency Core Cooling System (ECCS) pump per 10 CFR 50.73(a)(2)(iv)(B)(3), and an Emergency Diesel Generator (EDG) per 10 CFR 50.73(a)(2)(iv)(B)(8). However, pursuant to 10 CFR 50.73(a)(1), this event is being reported via this telephone notification, instead of</br>submitting a written Licensee Event Report, since the automatic actuation of the RPS, ECCS Pump and EDG was not generated by a valid actuation.</br>The licensee notified the NRC Resident Inspector.ensee notified the NRC Resident Inspector.
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00:00:00, 28 May 2009 +
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