|Perry Nuclear Power Plant|
|Reporting criterion:||10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident|
10 CFR 50.73(a)(2)(v)(A), Loss of Safety Function - Shutdown the Reactor
|ENS 52727||10 CFR 50.72(b)(3)(v)(A), Loss of Safety Function - Shutdown the Reactor, 10 CFR 50.72(b)(3)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident|
|4402017002R00 - NRC Website|
|Person / Time|
|From:||Hamilton D B|
FirstEnergy Nuclear Operating Co
Document Control Desk, Office of Nuclear Reactor Regulation
|Download: ML17179A208 (6)|
Estimated buraen per response to comply th.s mandatory collection request 30 hours
. Reportec lessons learned are .ncorporated into the licensing process and fed back to industry. Senc comments regarding burden estimate to the Irtrmation Services Branca (T-2 F431 U.S Nuclear Regulatory Commission, Washington. DC 20555-0001. or by e-mail to NEOB-10202. (3150-0104). Office of Management and Budget. Wash rigton. DC 20503. If a means used to impose an information collection does not display a currently valid OME control number. the NRC nay not conduct or sponsor, ana a person is not recuired to resperd to. the information co ec.on.
3. LER NUMBER
Perry Nuclear Power Plant Unit 1 05000-440 YEAR 2017 - 002 - 00 Energy Industry Identification System (EIIS) codes are identified in the text as [XX].
On April 30, 2017, at1818 hours
, while the plant was at 100 percent rated thermal power, main turbine steam bypass [JI] valve number 1 partially opened. Power was subsequently lowered in an attempt to close the bypass valve. While lowering power the bypass valve would shut and then reopen and power would again be lowered. When power was lowered to approximately 74 percent the bypass valve remained closed.
During the transient the reactor protection system (RPS) [JC] trip functions for the main turbine stop valve closure and turbine control valve fast closure scram were declared inoperable due to the opening of the bypass valve which changes the bypass setpoint for those RPS trips. With the loss of RPS trip capability for this function a loss of safety function existed intermittently for approximately 37 minutes. The manual reactor trip function and other RPS functions remained operable.
Both channels of the rod withdrawal [AA] limiter (RWL) and the end of cycle reactor recirculation pump [AD] trip (EOC-RPT) function were also declared inoperable in accordance with the plants Technical Specification (TS) bases. These functions are credited in accident analysis. this also resulted in a loss of safety function.
On April 30. 2017, at1910 hours
, the action statements for TS 22.214.171.124 "Reactor Protection System (RPS) Instrumentation"; 126.96.36.199 Control Rod Block Instrumentation", and 188.8.131.52 "End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation" were exited following confirmation of bypass valve closure. On May 3, 2017, at1259 hours
On April 30, 2017. at1818 hours
, while the plant was at 100 percent rated thermal power main turbine steam bypass valve number 1 partially opened. Power was subsequently lowered in an attempt to close the bypass valve. While lowering power the bypass valve would shut and then reopen and power would again be lowered. When power was lowered to approximately 74 percent the bypass valve remained closed.
Certain TS functions are automatically bypassed based upon certain sensed reactor power levels. Four of those functions rely on the pressure in the first stage of the turbine to correlate reactor power. With a bypass valve open. the pressure in the first stage of the turbine may not be representative of true reactor power so these functions are declared inoperable. The following functions use the first stage pressure:
and heat flux transients that must be limited. Therefore, a reactor scram is initiated at the start of TSV and TCV closure in anticipation of the transients that would result from the closure of these valves. This function must be enabled at thermal power greater than or equal to 38 percent. This is normally accomplished automatically by pressure switches sensing turbine first stage pressure; therefore, to consider this function operable. the turbine bypass valves must remain shut at power greater than or equal to 38 percent.
End of Cycle Recirculation Pump Trip (EOC-RPT) — TS 184.108.40.206:
Estimated burden per response :o comply with this mandatory co!lec: on recuest:82 hours
. Reported comments regarding burden est mate to the Information Services Branch (T-2 F43). U.S Nuclear Regulatory Commission. Washington DC 20555-0001 or by e-mail to infocollects Resource@nrc.gov and to the Desk Officer. Office of Information and Regulatory Affairs.
NEOB-10202. (3150-0104). Office of Management and Budget. Washington. DC 20503. If a means used to impose an informabor collection aces not display a currently valid OMB control number. the NRC may not conduct or sponsor and a person is not rem, red to respond to. the rfiormanon collection.
To mitigate pressurization transient effects of a main turbine trip the EOC-RPT must trip the recirculation pumps from fast speed operation after initiation of initial closure movement of either the TSVs or the TCVs.
The combined effects of this trip and a scram reduce fuel bundle power more rapidly than does a scram alone, resulting in an increased margin to the Minimum Critical Power Ratio (MCPR) safety limit. The EOC- RPT function is automatically disabled when turbine first stage pressure is less than 38 percent power. To consider this function operable, the turbine bypass valves must remain shut at power greater than or equal to 38 percent.
Rod Withdrawal Limiter (RWL) —TS 220.127.116.11:
The RWL is designed to prevent violation of the MCPR safety limit and the cladding 1 percent plastic strain fuel design limit that may result from a single control rod withdrawal error (RWE) event. The RWL is assumed to mitigate the consequences of an RWE event when operating greater than 33.3 percent power.
With any bypass valve open both channels of the listed functions are inoperable resulting in a loss of safety function. During the transient the following TS action statements were entered: TS 18.104.22.168 conditions A, B and C, 22.214.171.124 condition A and 126.96.36.199 conditions A and B. The required action for TS 188.8.131.52 C.1 requires restoration of RPS trip capability within1 hour
. TS 184.108.40.206 Action A.1 requires immediate suspension of control rod withdrawal and verification of no rod motion by 2 licensed operators. 220.127.116.11 Action B.1 requires restoration of EOC-RPT capability within2 hours
. On April 30, 2017, at1910 hours
. the action statements for TS 18.104.22.168. 22.214.171.124, and 126.96.36.199 were exited following confirmation of bypass valve closure. On May 3. 2017, at1259 hours
The direct cause of the bypass valve opening was degradation of the Primary Low Value Gate (PLVG) card in the main turbine speed control circuit [SC].
The problem solving team assembled for this issue evaluated monitoring equipment attached to the speed control portion of the Electro-Hydraulic system in order to determine the source of the inadvertent opening of the bypass valve. The failure mode was narrowed down to the turbine speed control portion of the circuitry based upon the alarms received during the transient. The decision was made to replace the Primary Low Value Gate and the Primary Frequency to Voltage Converter Speed Control cards. After the replacement was completed, the turbine was re-synchronized to the electrical grid. The installed monitoring equipment showed no evidence of an issue within the Electro-Hydraulic control systems and there were no further openings of the bypass valves.
The analysis of the removed cards is not yet completed, and if a change to the primary cause is warranted a LER revision will be submitted. Preliminary testing found a degradation of the PLVG card. During bench checks of the card it was discovered that an intermittent varying output signal was created with no changes to the input of the card. This intermittent change in output of the card would have caused the opening of the bypass valve. The second card that was replaced was the Primary Frequency to Voltage Converter card although initial analysis has identified no issues with this card.
- den per response to comply with this mandatory collection request: 80 hours9.259259e-4 days. Reported comments regarding burden estimate to the Information Services Branch (T-2 F43). U.S Nuclear Regulatory Commission. Washirgton, DC 20555-0001, or by e-mail to Infocollects Resou
- email@example.com, and to the Desk Ofce
- . Offce of Information and Regulatory Alairs.
NEOB-10202, (3150-0104). Office of Management ano Budget. Washington. DO 20503. If a means used to impose an information collection does not display a currently valid OMB contra number the NRC may not conduct or sponsor. and a person is not requ red to respond to the .1-formation col.ection.
3. LER NUMBER
The event is of small safety significance from the Probabilistic Risk Assessment (PRA) perspective as no PRA related mitigative components or strategies were affected by this event. While the corresponding functions were declared inoperable from a Technical Specification perspective. functionality was maintained and the plant was correspondingly controlled via proper actions to reduce power. The event did not result in an automatic trip.
With no transient and no impact to any PRA related components or functions, there would be no corresponding change (delta) in core damage frequency (CDF). and no corresponding change (delta) in the large early release frequency (LERF). The delta CDF and delta LERF values would therefore be well below the acceptable thresholds of 1.0E-06/yr and 1.0E-07/yr. respectively. as discussed in Regulatory Guide 1.174. The risk of this event is therefore considered small in accordance with the Regulatory Guidance.
During the transient. the sensed reactor pressure at the turbine first stage did not drop low enough to impede the ability for the listed parameters to perform their function, therefore, this is not considered a safety system functional failure.
The PLVG card was replaced following discovery of the failure. No other issues have been noted since replacement.
In addition to the card replacement, the mitigation strategy for the control system will be reviewed.
PREVIOUS SIMILAR EVENTS
A review of LERs and the corrective action database for the past three years identified no similar events.
There are no regulatory commitments contained in this report. Actions described in this document represent intended or planned actions, are described for the NRC's information, and are not regulatory commitments.