05000265/LER-2010-001, For Quad Cities, Unit 2 Regarding Main Condenser Low Vacuum Scram RPS Switch Inoperable and Exceeded Technical Specifications
| ML101690087 | |
| Person / Time | |
|---|---|
| Site: | Quad Cities  |
| Issue date: | 06/11/2010 |
| From: | William Gideon Exelon Generation Co, Exelon Nuclear |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| SVP-10-042 LER 10-001-00 | |
| Download: ML101690087 (7) | |
| Event date: | |
|---|---|
| Report date: | |
| Reporting criterion: | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications 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 |
| 2652010001R00 - NRC Website | |
text
Exeln.
Exelon Generation Company, LLC www.exeloncorp.com Nuclear Quad Cities Nuclear Power Station 22710 206" Avenue North Cordova, IL 61242-9740 June 11, 2010 10 CFR 50.73 SVP-10-042 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D.C. 20555 Quad Cities Nuclear Power Station, Unit 2 Renewed Facility Operating License No. DPR-30 NRC Docket No. 50-265
Subject:
Licensee Event Report 265/2010-001-00, "Main Condenser Low Vacuum Scram RPS Switch Inoperable Exceeded Technical Specifications" Enclosed is Licensee Event Report (LER) 265/2010-001-00, "Main Condenser Low Vacuum Scram RPS Switch Inoperable Exceeded Technical Specifications," for Quad Cities Nuclear Power Station, Unit 2.
This report is submitted in accordance with the requirements of the Code of Federal Regulations, Title 10, Part 50.73(a)(2)(i)(B), which requires the reporting of any operation or condition which was prohibited by the plant's Technical Specifications.
There are no regulatory commitments contained in this letter.
Should you have any questions concerning this report, please contact Mr. W. J. Beck at (309) 227-2800.
William R. Gideon Site Vice President Quad Cities Nuclear Power Station cc:
Regional Administrator - NRC Region III NRC Senior Resident Inspector - Quad Cities Nuclear Power Station
NRC FORM 366 U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB: NO. 3150-0104 EXPIRES: 08/31/2010 (9-2007)
, the NRC may digits/characters for each block) not conduct or sponsor, and a person is not required to respond to, the information collection.
- 3. PAGE Quad Cities Nuclear Power Station Unit 2 05000265 1 OF 6
- 4. TITLE Main Condenser Low Vacuum Scram RPS Switch Inoperable and Exceeded Technical Specifications
- 5. EVENT DATE
- 6. LER NUMBER I
- 7. REPORT DATE
[
- 8. OTHER FACILITIES INVOLVED M SEQUENTIAL REV FACILITY NAME DOCKET NUMBER MONTH DAY YEAR YEAR NUMBER NO.
MONTH DAY YEAR N/A N/A I I I
FACILITY NAME DOCKET NUMBER 04 14 10 2010 -
001 00 06 11 2010 N/A N/A
- 9. OPERATING MODE
- 11. THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR §: (Check all that apply)
El 20.2201(b)
El 20.2203(a)(3)(i)
[I 50.73(a)(2)(i)(C)
El 50.73(a)(2)(vii)
El 20.2201(d)
El 20.2203(a)(3)(ii)
[I 50.73(a)(2)(ii)(A)
El 50.73(a)(2)(viii)(A)
[I 20.2203(a)(1)
El 20.2203(a)(4)
[E 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)
[1 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)
El 50.73(a)(2)(iv)(A)
[I 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) 10%
El 20.2203(a)(2)(iv)
[I 50.46(a)(3)(ii) 0l 50.73(a)(2)(v)(B)
El 73.71 (a)(5)
El 20.2203(a)(2)(v)
[I 50.73(a)(2)(i)(A)
El 50.73(a)(2)(v)(C)
El OTHER El 20.2203(a)(2)(vi)
- 50.73(a)(2)(i)(B)
El 50.73(a)(2)(v)(D)
Specify in Abstract below or in activity could have identified the blockage in the line before the reactor startup was performed and is being considered a failed barrier.
Condenser backpressure plots during shutdown prior to the outage indicated pressure channels were tracking uniformly, however upon outage completion, the startup condenser pressure plots indicated anomalous readings (2C reading higher and lagging other readings), therefore the isolation valve had been inadvertently repositioned during the outage.
Since the 2C Main condenser low vacuum scram switch was inadvertently isolated during the Q2R20 outage, and the Unit entered Mode 1 on 4/14/10 at 1111 with the scram switch isolated, the 2C turbine condenser low vacuum RPS channel was inoperable and TS LCO 3.0.4 (Mode change preconditions) was not met since the minimum number of required channels operable per TS 3.3.1.1, Function 10 was not met prior to entering Mode 1. Hence this event is a past operation or condition which was prohibited by the plant Technical Specifications, and is therefore reportable per 10 CFR 50.73(a)(2)(i)(B).
C.
CAUSE OF EVENT
During reactor start-up, the Station determined that the 2C Condenser Backpressure reading was higher than the other main condenser sections based on the computer points and Control Room recorder. The lagging pressure indications and the completed Instrument Maintenance surveillances led Operations department and the Station to respond in a manner that they would for a degraded plant indicator, not an inoperable Tech Spec required RPS trip channel instrument. Even though the actions were rigorous for what they thought was an indication problem, in that a troubleshooting guide was developed and Instrument Maintenance was investigating within nine hours of the issue being identified, the improper evaluation of the relationship between the indication and the input to the Tech Spec RPS function, resulted in a reduced priority of corrective actions that allowed the plant to move to Mode 1 without first meeting the requirements of TS LCO 3.0.4.
The apparent cause of this event is the Station did not place sufficient importance on the improperly indicating Control Room indicators. This resulted in a reduced priority of investigating and correcting the improper indication. The contributing cause of the event is outage activities in the area of the Main Condenser hatches were determined to be the most likely cause for the inadvertent closing of the 2-3199-75C isolation valve (potentially due to lack of awareness of surroundings, lack of flagging and robust operational barriers, and lack of use of pertinent work briefings).
The inadvertent isolation valve closure resulted in the improper entering of Mode 1 with an inoperable turbine condenser low vacuum RPS channel since the Mode change did not meet TS 3.0.4 since the minimum number of required channels operable per TS 3.3.1.1, Function 10 was not met prior to entering Mode 1.
D.
SAFETY ANALYSIS
System Operation The Turbine Condenser Vacuum-Low Function is provided to shut down the reactor and reduce the energy input to the main condenser to help prevent over-pressurization of the main condenser in the event of a loss of the main condenser vacuum. Loss of condenser vacuum occurs when the condenser can no longer handle the heat input (e.g.,
loss of heat transfer capability or excessive in-leakage). This condition initiates a closure of the turbine stop valves and turbine bypass valves, which eliminates the reactor heat input to the condenser. Closure of the turbine stop and
bypass valves causes a pressure transient, neutron flux rise and an increase in fuel surface heat flux. To prevent the fuel cladding integrity Safety Limit from being exceeded if this occurs, a reactor scram occurs on turbine stop valve closure. The turbine stop valve closure scram function alone is adequate to prevent the fuel cladding integrity Safety Limit from being exceeded, in the event of a turbine trip transient with bypass closure. The condenser low vacuum scram is anticipatory to the turbine stop valve closure scram. Turbine condenser vacuum pressure signals are derived from four pressure switches that sense the pressure in the condenser. The Allowable Value is consistent with the main turbine trip on low main condenser vacuum set-point, and provides main condenser overpressure protection by shutting down the reactor; thereby, reducing energy into the main condenser. Four channels of Turbine Condenser Vacuum-Low Function, with two channels in each trip system arranged in a one-out of-two logic, are required to be OPERABLE to ensure that no single instrument failure will preclude a scram from this Function on a valid signal. The Function is required in MODE 1 since in this MODE there is a significant amount of core energy that can be rejected to the main condenser.
During MODES 2, 3, 4, and 5, the core energy is significantly lower. This Function is automatically bypassed with the reactor mode switch in any position other than run.
Safety Impact This instrument inputs into RPS as one of the four channels of Turbine Condenser Vacuum-low function, with two channels in each trip system arranged in a one-out-of two logic. The function is designed with all instruments required to be operable to ensure that no single instrument failure will preclude a scram from this function on a valid signal.
With the "C" Main Condenser switch inoperable, a "B" RPS channel trip would have occurred from the Pressure switch 2-0503-D to allow a scram to occur on loss of vacuum. Although the pressure switch would have tripped at the proper set-point, the "C" pressure switch would have very likely taken slightly longer to trip than the other three unaffected RPS condenser backpressure pressure switches. There was no impact to the "A" RPS channel due to this event. Scram capability was maintained during this event.
The Main Condenser low vacuum pressure switches are required operable in Mode 1. Unit 2 entered Mode 1 at 11:11 on 4/14/10, the isolation valve was reopened at 23:51, and Technical Specification 3.3.1.1, Action A was exited at 00:32 on 4/15/2010. Although the required instrument was not operable for a short period of time, this did not create any actual plant or safety consequences since the Unit was not in an accident or transient condition requiring use of the RPS during this period of time.
In conclusion, this event resulted in a minimal impact on plant risk, and the overall safety significance of this event was minimal.
E.
CORRECTIVE ACTIONS
Immediate:
Valve 2-3199-75C was placed in the open position and verified in the correct position.
Initiated a prompt investigation on the event.
Follow-up:
Revise QCGP 1-1 to add requirements to review abnormal plant indications to verify there is no impact to Technical specification required equipment or proper resolution prior to entering Mode 1 or 2.
Install robust barrier to protect the Unit 1 Main Condenser vacuum sensing isolation valves during Q1 R21.
Review high traffic work areas each outage and determine vital components that need to have valve or component line -ups performed.
Review high traffic work areas each outage and determine vital components that should be protected.
Revise model work orders and any existing work orders to verify air flow during backblow of these sensing lines.
Review this event with Operations Shift Managers and under Operations training emphasizing the importance of challenging the operability of improper responses of equipment and the impact of making decisions without fully verifying the data.
F.
PREVIOUS OCCURRENCES
The Station Events Database, EPIX, NPRDS, and LERs were reviewed for similar events. This event was caused by the Station not placing sufficient importance on the improperly indicating Control Room indicators, which resulted in a reduced priority of investigating and correcting the improper indication.
Station Event Database - Quad Cities IR 761287 (4/9/08) - On April 20, 2008, while preparing to perform a work order, the 2B Reactor Building [VA] Supply Fan failed to stop running after the Control Room attempted to open the breaker. When the 2B Reactor Building Supply Fan failed to trip, Operations entered QGA 300 and Technical Specification 3.6.4.1 Condition A on loss of negative differential pressure. Troubleshooting identified that the breaker (S058) had failed to open because a wire that supplies control power to the trip coil [94RLY] had broken free from a butt splice connecting it to the trip coil. The red light is in the trip circuit for the breaker, and the lack of light indication was a symptom of the broken wire. With the broken wire to the trip coil, the breaker trip function was lost. Corrective actions included revising Station 480V and 4KV breaker racking-in procedures to add a statement that lack of red light indication during breaker closure could be symptom of an inoperable breaker trip function, and communications and training for Operations concerning the red light function. Although this event is similar to the subject of this LER since a wrong disposition for the initial indication problem resulted in the operation of the plant with compromised equipment, the scope of corrective actions for the event was targeted at 480V and 4KV breaker closure light indication issues, and did not focus on the general topic of this LER being, Station personnel not placing sufficient importance on the improperly indicating Control Room indicators, which resulted in a reduced priority of investigating and correcting the improper indication.
Station Event Database - Quad Cities IR 933472 (6/5/09) - During pre-turnover panel monitoring checks, the Ul Admin NSO checked for "Normal" status of all SPING channels, and discovered that channels 11-01 and 11-02 indicated "Uninitialized."
The Chemistry technician was contacted and it was determined that the Service Water Effluent Rad Monitor was inoperable. The Ul SW Effluent Rad Monitor was inoperable for 15 days without samples being taken, in violation of the ODCM.
Although the recorder was functional, the alarms were not. The Operations Department did not utilize a sufficient questioning attitude in addressing the Sping Instrument, "uninitialized" reading. The NSO should have reviewed the indication in sufficient detail to take the actions necessary to have the condition addressed or to determine that the instrument was inoperable. Corrective actions included Operations training related to the SPING "uninitialized" indication, procedure revisions to address the initialize indication, and reinforcement of Operations standards on addressing off normal conditions during turnovers. Although the SPING event is similar to the subject of this
LER since a wrong disposition for the initial indication problem resulted in the operation of the plant with compromised equipment, the scope of corrective actions for the SPING event was targeted at a sufficient questioning attitude in addressing the in-plant SPING Instrument, "uninitialized" condition, and did not focus on the general topic of this LER being, Station personnel not placing sufficient importance on the improperly indicating control room indicators, which resulted in a reduced priority of investigating and correcting the improper indication. The Operations Department was responsible for a questioning attitude concerning the SPING "uninitialized" condition, whereas for this LER, the Operations Department was responsible for determining the priority for the identification and correction of the main condenser backpressure issue.
EPIX/ NPRDS - No similar events identified for Quad Cities.
LER 05000265/2009-001-00, Failure of Common Unit EDG Auxiliaries to Transfer Power Sources to Support Unit 2 (06/09/09) - A loss of indication of power to the 1/2 EDG auxiliaries on March 25, 2009 was misunderstood to be a problem with the in-plant light bulb when in fact the circuit had lost power. Operations shift personnel did not challenge the conclusion that the loss of the light bulb was only an "indication." The cause of the 1/2 EDG event was that key Operations shift personnel did not adequately question and challenge critical information provided by subject matter experts.
Corrective actions included developing procedural guidance expectations related to ensuring a questioning attitude of abnormal plant conditions when critical information is provided by subject matter experts. Although the 1/2 EDG event is similar to the subject of this LER since a wrong disposition for the initial indication problem resulted in the operation of the plant with compromised equipment, the scope of corrective actions for the 1/2 EDG event was targeted at a questioning attitude of abnormal plant conditions when critical information is provided by subject matter experts, and did not focus on the general topic of this LER being, Station personnel not placing sufficient importance on the improperly indicating control room indicators, which resulted in a reduced priority of investigating and correcting the improper indication. The Operations Shift was responsible for determining the priority for the identification and correction of the main condenser backpressure issue, as opposed to determining the validity of the subject matter expert inputs as identified in the 1/2 EDG event.
G.
COMPONENT FAILURE DATA
This event does not involve the failure of any equipment. An EPIX report has not been generated.PRINTED ON RECYCLED PAPER NRIC FORM 366A (9-2007)
PRINTED ON RECYCLED PAPER