On June 23, 2004 Catawba identified an unanalyzed condition related to fire protection cable separation requirements.� (EIIS:EB] was A fire in the Unit 2 A-train 4160V switchgear room (2ETA)� postulated to cause a hot short to spuriously close centrifugal charging pump suction valve 2NV188A and damage the running pump (EIIS:CB].� Because the running pump and the 4160V switchgear room may be opposite train components, the postulated fire may result in both charging pumps being unavailable for post-fire plant recovery. A fire in 2ETA may also affect the standby makeup pump.
This postulated loss of both trains of charging pumps was not analyzed in the Safe Shutdown Analysis.� On June 24, 2004 Unit 1 was determined to have a similar vulnerably for a fire in the S- train 4160V switchgear room (lETB).
Further review of the cable routing for the charging pump suction valves identified a fire in 5 additional Unit 1 fire areas and 6 additional Unit 2 fire areas may result in damage to both charging pumps.� The Safe Shutdown Analysis for these fire areas was based on one charging pump being available.
The apparent cause is inadequate original Safe Shutdown Analysis of certain spurious hot short valve operations.� Corrective actions included fire watches for the switchgear rooms until operating procedures were implemented to protect the correct train charging pump for post-fire plant recovery.
The conditions addressed by this report are related to postulated accidents and potential failures and had no direct effect on the health and safety of the public. |
LER-2004-003, Unanalyzed Condition Due To Inadequate Evaluation of Fire InteractionsDocket Number |
Event date: |
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4132004003R01 - NRC Website |
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BACKGROUND AND EVENT DESCRIPTION
This event is being reported in accordance with the 30-day reporting requirement of the Catawba Facility Operating License Section 2F and 50.73(a)(2)(ii)(B).
NUREG-0800 Standard Review Plan and subsequent Safety Evaluation Reports (NUREG-0954) state that one train of systems necessary to achieve and maintain Hot Standby conditions from the control room is required to be free of fire damage. The separation criteria for components to be free from fire damage are:
1.Separation of cables and equipment and associated circuits of redundant trains by a fire barrier having a 3-hour rating; or, 2.Separation of cables and equipment and associated circuits of redundant trains by a horizontal distance of more than 20 feet with no intervening combustible or fire hazards. In addition, fire detectors and an automatic fire suppression system should be installed in the fire area; or, 3.Enclosure of cable and equipment and associated circuits of one redundant train in a fire barrier having a 1-hour rating. In addition, fire detectors and an automatic fire suppression system should be installed in the fire area.
If the separation criteria cannot be met, then an alternative, dedicated shutdown capability should be provided.
During the Catawba initial licensing in the early 1980s, Catawba elected to meet the existing fire protection regulations using the following three fire response strategies:
1.Plant shutdown from the control room using A-train equipment.
2.Plant shutdown from the control room using B-train equipment.
3.Plant shutdown from a dedicated, safe shutdown facility independent from the control room.
On June 23, 2004, electrical components were identified within the same fire area that did not meet the cable separation criteria in that a postulated single fire may damage both charging pumps and damage the standby makeup pump cable. The standby makeup pump is used for alternate shutdown to provide reactor coolant pump seal injection flow.
The components identified within the fire area for 2ETA include:
- Unit 2 A-train charging pump breaker and cables
- Unit 2 valve 2NV188A breaker and cables (volume control tank outlet valve)
- Unit 2 standby makeup pump cable
- Reactor coolant pump thermal barrier heat exchanger valve breakers and cables [EIIS:CC] If the Unit 2 B-train charging pump is initially in service and a fire in 2ETA causes valve 2NV188A to hot short to spuriously close, then the 2B charging pump is assumed to be damaged due to a loss of suction.
The fire in 2ETA is also assumed to damage the 2A charging pump cable and standby makeup pump cable. The thermal barrier cooling water system is initially in service and should provide cooling to the reactor coolant pump seals unless another hot short causes a second spurious actuation. The Catawba Licensing Basis is to postulate "one worst case spurious actuation". The scenario that includes spurious actuation of both the volume control tank outlet valve and thermal barrier isolation valve is beyond the design basis but is being evaluated for safety significance.
A similar vulnerability exits for the fire area for the Unit 1 B-train 4160V switchgear room (1ETB). Components within lETB include:
- Unit 1 B-train charging pump breaker and cables
- Unit 1 valve 1NV189B breaker and cables (volume control tank outlet valve)
- Unit 1 standby makeup pump cable
- Reactor coolant pump thermal barrier heat exchanger valve breakers and cables The plant Safe Shutdown Analysis did not consider the postulated common failure mechanism for both charging pumps due to a spurious closure of a volume control tank outlet valve. The analysis assumed that one train of charging pumps would be available following a fire in a 4160V switchgear room.
The 4160V switchgear rooms are equipped with fire detection capability but are not protected by an automatic fire suppression system. The electrical components within each of the 4160V switchgear rooms, lETB or 2ETA, are not separated by a 3-hour fire barrier.
Because the cable separation criteria for a 3-hour fire barrier could not be satisfied, operations personnel initiated hourly fire watches in accordance with the Selected Licensee Commitment for Fire Rated Assemblies. Fire watches were started on June 23, 2004 for all four switchgear rooms (ZETA, lETB, 2ETA, and 2ETB).
The phone notification to the NRC Operations Center was completed June 23, 2004 for Unit 2 and June 24, 2004 for Unit 1.
Subsequent review of the cable routing for the volume control tank outlet valves identified a fire in the following fire areas may also result in damage to both charging pumps:
Fire Area 6, 1B Penetration Room Fire Area 13, lA Penetration Room Fire Area 15, 1A Switchgear Room Fire Area 32, Unit 1 Auxiliary Shutdown Panel A-train Fire Area 34, Unit 1 Auxiliary Shutdown Panel B-train Fire Area 5, 2B Penetration Room Fire Area 7, 2B Switchgear Room Fire Area 12, 2A Penetration Room Fire Area 31, Unit 2 Auxiliary Shutdown Panel A-train Fire Area 33, Unit 1 Auxiliary Shutdown Panel B-train Fire Area 46, Unit 2 Corridor The Safe Shutdown Analysis for these fire areas was based on one charging pump being available.
A noteworthy design feature of Catawba is the extensive use of grounded, shielded armor cables. The NUREG-0954 Safety Evaluation Report dated February 1983 description of cables states:
"The power, control, and instrumentation cables used in Catawba are of an interlocked armor design in a galvanized steel jacket. All cables pass the IEEE standard 383-1974 flame test. In addition, the applicant has submitted samples of the cable for testing at Underwriters Laboratories in their "corner test" configuration. When subjected to a 400,000 BTU/hr heat flux, the cable exhibited no tendency to propagate fire. In addition, the applicant has conducted tests that demonstrate that no fire propagation from cable to cable or tray to tray occurs as a result of an electrically initiated fire. The staff finds this acceptable.
The Sandia National Laboratories, Circuit Failure Mode and Likelihood Analysis, draft revision 2 December 20, 1999 page 15 states:
"For an armored (metal jacketed) cable, cable-to-cable shorting without a short to ground would be considered highly unlikely, if not impossible. Armoring might also influence the likelihood and duration of non-grounded conductor-to-conductor shorts within the cable. In effect, the armor represents a readily accessible ground plane. The ready availability of a strong ground plane may increase the likelihood of ground shorts, especially considering that the heating during a fire will occur from the outside in.
Hence, conductors (or insulation) nearest the cable surface will likely fail first.
Some experimental evidence regarding armored cables is available, in particular, from testing by EdF (EF.30.15.R/96.442). In this program several samples of various armored cables were tested.
Most showed evidence of the initial failures involving one conductor and the armor, and relatively few showed conductor-to conductor shorts independent of the shield. Hence, the experimental evidence indicates that in comparison to non-armored multi-conductor cables, the likelihood of conductor-to-conductor hot shorts is substantially reduced.
Additional correspondence on armored cables is contained in the February 19, 2003 NRC Risk-Informing Post-Fire Shutdown Circuit Analysis Inspection meeting transcript and September 15, 2003 Duke letter to the NRC entitled, "Comments on Proposed Generic Communication Risk-Informed Inspection Guidance for Post-Fire Safe Shutdown Inspection".
At the time of this event, Unit 1 and 2 were operating in Mode 1 at 100 percent power. No structures, systems, or components were removed from service that had any effect on the event or conflicted with Technical Specifications.
CAUSAL FACTORS
This condition is historical and dates to the original development of the assumptions used to support the Safe Shutdown Analysis.
Consequently, a root cause evaluation was not performed. The apparent cause is attributed to an inadequate original Safe Shutdown Analysis of certain spurious hot short valve operations.
CORRECTIVE ACTIONS
Immediate:
1. Hourly fire watches established for switchgear rooms lETA, lETB, 2ETA, and 2ETB.
Subsequent:
1.Cable routing locations for Unit 1 and Unit 2 charging pump suction valves within ETA and ETB were identified. Valves included the two volume control tank outlet valves (NV188A and NV189B) and the two refueling water storage tank valves (NV252A and NV253B).
2.Following the review and evaluation of the cable routes for NV188A, NV189B, NV252A, and NV253B, guidance was provided to the operators such that control room actions would be taken to maintain at least one charging pump available for post-fire recovery following a fire in the 13 identified fire areas.
3.Following the implementation of the operator guidance, the hourly fire watches were terminated.
4. Cable routing evaluations were completed for the charging pumps, standby makeup pump, suction and discharge valves for the standby makeup pump, thermal barrier isolation valves, offsite power cables for the 4160V switchgear, and diesel generator power cables for the 4160V switchgear.
Planned:
1. Update the Safe Shutdown Analysis based on the results of the cable routing evaluation.
The planned corrective actions are being addressed within the Catawba Corrective Action Program. There are no NRC commitments contained in this LER.
SAFETY ANALYSIS
There were no fire events that challenged the operability of the charging pumps, standby makeup pump, reactor coolant pump seal cooling by seal injection, or thermal barrier heat exchanger operation. The conditions addressed by this report are related to postulated accidents and potential failures and had no direct effect on the health and safety of the public.
The 4160V switchgear rooms have minimal in-situ combustible materials and are maintained free of significant transient combustible materials by administrative controls. Ignition sources are limited to the electrical cabinets and switchgears. The switchgear rooms are equipped with fire detectors to alarm the operators of fire events. The fire brigade members are trained to immediately respond to any plant fire.
Test data from the December 2002 EPRI report, Characterization of Fire- Induced Circuit Faults, supports the conclusion that spurious hot shorts will not occur for approximately 30 minutes following fire initiation.
Within the 4160V switchgear rooms, the Unit 2 volume control tank outlet valve cable and the standby makeup pump cable are separated by a horizontal distance of greater than 20 feet with no intervening combustibles. The Unit 1 volume control tank outlet valve cable and the standby makeup pump cable are separated by a horizontal distance of approximately 9 feet with no intervening combustibles.
The risk of core damage was analyzed for a potential spurious closure of each unit's volume control tank outlet valve. The analysis was performed using the NRC Fire Significance Determination Process (SDP), Phase II procedure, including use of the SDP Fire Ignition Frequencies, Zone of Influence Charts, and manual suppression curves. The analysis for each area was performed conservatively, with some cables not traced, but assumed failed by any fire. Additionally, numerous conservatisms were applied throughout.
The Phase II analysis showed an overall Core Damage Frequency of less than 1E-06/year for each unit. A number of fire areas were qualitatively screened as low risk, due to a number of factors such as not affecting the SSF and other important components in the PRA scenarios analyzed. A more detailed Fire SDP Phase III calculation would likely result in core damage estimates much lower than the above Phase II results.
The analysis used extensive cable tracing, circuit analysis and walk downs provided by site engineering as a good-faith approximation of cable locations and cable interactions. As Catawba continues with the transition to the NFPA 805, Performance-Based Standard for Fire Protection for Light Water Reactor Generating Plants, a more formal verification of cable locations will be documented. Therefore, the results of the PRA analysis cannot be considered finalized until the completion of the formal cable location verification.
ADDITIONAL INFORMATION
Within the last three years, no other LERs occurred at Catawba involving fire events or the safe shutdown analysis. Therefore, this event was determined to be non-recurring.
Energy Industry Identification System (EIIS) codes are identified in the text as [EIIS: XX].
.� , This event did not meet the criteria for a Safety System Functional Failure.
There were no releases of radioactive materials, radiation exposures or personnel injuries associated with this event.
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05000348/LER-2004-001 | | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000333/LER-2004-001 | Inadvertent Actuation of ECCS and EDGs While in Refueling Mode | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000306/LER-2004-001 | | 10 CFR 50.73(a)(2)(v)(C), Loss of Safety Function - Release of Radioactive Material 10 CFR 50.73(a)(2)(v), Loss of Safety Function 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000315/LER-2004-001 | Failure To Comply With Technical Specification 3 .7 .5 .1, Control Room Emergency Ventilation System | | 05000301/LER-2004-001 | | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000313/LER-2004-001 | | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000285/LER-2004-001 | Failure To Perform A Leakage Test Due To Lack Of Understanding of Penetration Design | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000271/LER-2004-001 | Main Steam Isolation Valve Leakage Exceeds a Technical Specification Leakage Rate Limit | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000266/LER-2004-001 | | 10 CFR 50.73(a)(2)(ii)(A), Seriously Degraded | 05000318/LER-2004-001 | . Reactor Trip Due to Low Steam Generator Water Level After Feed Pump Trip | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000289/LER-2004-001 | | 10 CFR 50.73(a)(2)(v), Loss of Safety Function 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000263/LER-2004-001 | | | 05000247/LER-2004-001 | Manual Reactor Trip Due to Oscillating Feedwater Flow and Steam Generator Level with Flow Perturbations Caused by a Degraded Feed Water Regulating Valve | 10 CFR 50.73(a)(2)(iv)(A), System Actuation 10 CFR 50.73(a)(2)(iv), System Actuation | 05000244/LER-2004-001 | Gaps in the Control Room Emergency Zone Boundary | | 05000255/LER-2004-001 | | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000364/LER-2004-001 | | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000461/LER-2004-001 | Clinton Power Station 05000461 1 OF 4 | | 05000414/LER-2004-001 | relPowere Vice President A Duke Energy Company Duke Power Catawba Nuclear Station 4800 Concord Rd. / CNO1VP York, SC 29745-9635 803 831 4251 803 831 3221 fax November 9, 2004
U. S. Nuclear Regulatory Commission
ATTENTION: Document Control Desk
Washington, DC 20555-0001
SUBJECT: Duke Energy Corporation
Catawba Nuclear Station Unit 2
Docket No. 50-414
Licensee Event Report 414/04-001 Revision 0
Reactor Coolant System Pressure Boundary Leakage
Due to Small Cracks Found in Steam Generator
Channel Head Bowl Drain Line on 2C & 2D Steam
Generators
Attached please find Licensee Event Report 414/04-001
Revision 0, entitled "Reactor Coolant System Pressure
Boundary Leakage Due to Small Cracks Found in.Steam
Generator Channel Head Bowl Drain Line on 2C & 2D Steam
Generators."
This Licensee Event Report does not contain any regulatory
commitments. Questions regarding this Licensee Event Report
should be directed to R. D. Hart at (803) 831-3622.
Sincerely,
Dhiaa Jamil
Attachment
www.dukepower.corn 00- U.S. Nuclear Reguldhory Commission
November 9, 2004
Page 2
XC: W.D. Travers
U.S. Nuclear Regulatory Commission
Regional Administrator, Region II
Atlanta Federal Center
61 Forsyth St., SW, Suite 23T85
Atlanta, GA 30303
E.F. Guthrie
Senior Resident Inspector (CNS)
U.S. Nuclear Regulatory Commission
Catawba Nuclear Station
S.E. Peters (addressee only)
NRC Project Manager (CNS)
U.S. Nuclear Regulatory Commission
One White Flint North, Mail Stop 10-B3
11555 Rockville Pike
Rockville, MD 20852-2738
NRC FORM 366� U.S. NUCLEAR REGULATORY APPROVED BY OMB: NO. 3150-0104 EXPIRES: 06/30/2007 (6-2004)� COMMISSION Estimated burden per response to comply with this mandatory collection request 50
hours. Reported lessons learned are Incorporated Into the licensing process and fed back
to Industry. Send comments regarding burden estimate to the Records and FOIA/Privacy
Service Branch (T-5 F52), U.S. Nuclear Regulatory Commission, WashinMon, DC 2055
LICENSEE EN/ENT REPORT (LER) 0001, or by Internet e-mail to infocollects@nrc.gov, and to the Desk Officer, Office of Information and Regulatory Affairs, NEOB-10202, (3150-0104). Office of Management(See reverse for required number of and Budget, Washington, DC 20503. If a means used to impose an Information col ectiond( inverse �for each block) does not display a currently valid OMB control number, the NRC may not conduct or sponsor. and a person Is not required to respond o. the Information collection. 1. FACILITY NAME 2. DOCKET NUMBER 3. PAGE Catawba Nuclear Station, Unit 2 050- 00414 1 OF�6 4. TITLE Reactor Coolant System Pressure Boundary Leakage Due to Small Cracks Found in
Steam Generator Channel Head Bowl Drain Line on 2C & 2D Steam Generators | | 05000368/LER-2004-001 | | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000423/LER-2004-001 | | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000334/LER-2004-001 | Control Rod Shutdown Bank Anomaly Causes Entry into Technical Specification 3.0.3 | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000413/LER-2004-001 | Gas Accumulation in Centrifugal Charging Pump Suction Piping | 10 CFR 50.73(a)(2)(v)(A), Loss of Safety Function - Shutdown the Reactor 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)(ii)(A), Seriously Degraded | 05000395/LER-2004-001 | Reactor Trip Due to Valve Failure During Forced Shutdown | 10 CFR 50.73(a)(2)(iv)(A), System Actuation 10 CFR 50.73(a)(2)(ii)(A), Seriously Degraded 10 CFR 50.73(a)(2)(i)(A), Completion of TS Shutdown | 05000390/LER-2004-001 | Automatic Reactor Trip Due to a Invalid Turbine Trip Signal (P-4) | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000369/LER-2004-001 | Auxiliary Feedwater System in prohibited condition due to inadequate procedure. | | 05000454/LER-2004-001 | Exelent
Exelon Generation Company, LLCRwww.exeloncorp.com NuclearByron Station 4450 North German Church Road Byron, IL 61010-9794 October 17, 2004 LTR: BYRON 2004-0111 File: 2.01.0700 United States Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Subject:RLicensee Event Report (LER) 454-2004-001-00, "Reactor Containment Fan Coolers Flow Rates Below Technical Specification Requirements Due to Inaccurate Flow Indication" Byron Station, Unit 1
Facility Operating License No. NPF-37
NRC Docket No. STN 50-454
Enclosed is an LER involving the August 17, 2004, event involving low flow conditions discovered in Unit 1 Reactor Containment Fan Coolers for a time period longer than allowed by the Technical Specifications. This event is reportable to the NRC in accordance with 10CFR 50.73 (a)(2)(i)(B), as a condition prohibited by Technical Specifications. Should you have any questions concerning this matter, please contact Mr. William Grundmann, Regulatory Assurance. Manager, at (815) 234-5441, extension 2800. Respectfully, Stephen E. Kuczynski Site Vice President Byron Nuclear Generating Station Attachment LER 454-2004-001-00 cc:RRegional Administrator, Region III, NRC NRC Senior Resident Inspector— Byron Station NRC FORM 366 U.S. NUCLEAR REGULATORY APPROVED BY OMB NO. 3150-0104 EXPIRES 7-31-2004 (7.2001) COMMISSION Estimated burden per response to comply with this mandatory information collection request 50 hours. Reported lessons learned are incorporated into the licensing process and fed back to industry. Send comments regarding burden estimate to the Records Management Branch (T.6 E6), U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001, or by Internet e-mail toLICENSEE EVENT REPORT (LER) *I@ nrc.gov, and to the Desk Officer, Office of Informabon and Regulatory Affairs, NEOB:10202 (3150-0104), Office of Management and Budget, Washington, DC 20503. If a means used to impose information collection does not display a currently valid OMB control number, the NRC may not _ conduct or sponsor, and a person is not required to respond to, the information collection. 1 rand ITV NAUP o natuerr An warn q par= . Byron Station, Unit 1 0500454 1 OF 5 4. Reactor Containment Fan Coolers Flow Rates Below Technical Specifications Requirements Due to Inaccurate Flow Indication | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000305/LER-2004-001 | | 10 CFR 50.73(a)(2)(vii), Common Cause Inoperability | 05000336/LER-2004-001 | | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000364/LER-2004-002 | | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000423/LER-2004-002 | | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000237/LER-2004-002 | Dresden Nuclear Power Station Unit 2 05000237 1 of 5 | 10 CFR 50.73(a)(2)(iv)(A), System Actuation 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000261/LER-2004-002 | | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000244/LER-2004-002 | Consolidated Rod Storage Canister Placed in Incorrect Storage Location | | 05000530/LER-2004-002 | Main Turbine Control System Malfunction Results in Automatic Reactor Trip on Low DNBR | 10 CFR 50.73(a)(2)(iv)(A), System Actuation 10 CFR 50.73(a)(2)(v), Loss of Safety Function | 05000305/LER-2004-002 | | | 05000247/LER-2004-002 | Manual Reactor Trip Due to Decreasing 23 Steam Generator Level Caused by Feedwater Regulating Valve Closure Due to a De-energized Solenoid Operated Valve from Wiring Failure | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000414/LER-2004-002 | Manual Reactor Trip Initiated Due to Control Rods from Shutdown Bank D Dropping into the Core | | 05000251/LER-2004-002 | AAA | 10 CFR 50.73(a)(2)(iv)(A), System Actuation 10 CFR 50.73(a)(2)(iv)(b) | 05000397/LER-2004-002 | | 10 CFR 50.73(a)(2)(v)(D), Loss of Safety Function - Mitigate the Consequences of an Accident | 05000346/LER-2004-002 | Reactor Trip During Reactor Trip Breaker Testing Due To Fuse Failure | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000395/LER-2004-002 | Emergency Diesel Generator Start and Load Due to Momentary Fault on Incoming Feed | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000269/LER-2004-002 | eif Powere RON A. JONES Vice President A Duke Energy Company Oconee Nuclear Site Duke Power ONO1VP / 7800 Rochester Highway Seneca, SC 29672 864 885 3158 864 885 3564 fax September 9, 2004
U.S. Nuclear Regulatory Commission
Document Control Desk
Washington, D.C. 20555
Subject: Oconee Nuclear Station
Docket Nos. 50-269,-270, -287
Licensee Event Report 269/2004-02, Revision 1
Problem Investigation Process No.: 0-04-2808
Gentlemen:
Pursuant to 10 CFR 50.73 Sections (a)(1) and (d), attached
is Licensee Event Report 269/2004-02, Revision 1, regarding
a Main Steam Line Break mitigation design/analysis
deficiency which could result in the main and startup
feedwater control valves being technically inoperable for
mitigation of some steam line break scenarios.
This report is being submitted to supplement Revision 0
submitted July 6, 2004. At that time the root cause
investigation and an analysis of the consequences of
potentially exceeding the Environment Qualification (EQ)
envelope curve were still in progress.
This event is being reported in accordance with 10 CFR
50.73 (a)(2)(i)(B) as a condition prohibited by Technical
Specifications, 50.73(a)(2)(ii)(B) as an Unanalyzed
Condition, and 50.73(a)(2)(V)(D) as a potential loss of
safety function for Accident Mitigation. This event is
considered to be of no significance with respect to the
health and safety of the public.
www.dukepower.corn Document Control Desk
Date: September 9, 2004
Page 2
Attachment: Licensee Event Report 269/2004-02, Revision 1
cc: Mr. William D. Travers
Administrator, Region II
U.S. Nuclear Regulatory Commission
61 Forsyth Street, S. W., Suite 23T85
Atlanta, GA 30303
Mr. L. N. Olshan
Project Manager
U.S. Nuclear Regulatory Commission
Office of Nuclear Reactor Regulation
Washington, D.C. 20555
Mr. M. C. Shannon
NRC Senior Resident Inspector
Oconee Nuclear Station
INPO (via E-mail)
NRC FORM 366 U.S. NUCLEAR REGULATORY APPROVED BY OMB NO. 3150-0104 EXPIRES 7-31-2004 (7-2001) COMMISSION Estimated burden per response to comply with this mandatory information collection request: 50 hours. Reported lessons learned are incorporated into the licensing process and fed back to industry. Send comments regarding burden estimate to the Records Management Branch (T-6 E6), U.S. Nuclear Regulatory Commission, Washington. DCLICENSEE EVENT REPORT (LER) 20555-0001, or by Internet e-mail to bpi @nrc.gov, and to the Desk Officer, Office of Information and Regulatory Affairs, NEOB-10202 (3150-0104), Office of Management and(See reverse for required number of Budget, Washington, DC 20503. If a means used to impose information collection doesdigits/characters for each block) not display a currently valid OMB control number, the NRC may not conduct or sponsor, and,1 nnmnn lc not rent Owl to tocnnni-I to the intnrmatinn rntlentinn 1. FACILITY NAME 2. DOCKET NUMBER 3. PAGE Oconee Nuclear Station, Unit 1 050-81 OF 0269 11 4. TITLE Main Steam Line Break Mitigation Design/Analysis Deficiency | 10 CFR 50.73(a)(2)(ii)(B), Unanalyzed Condition | 05000313/LER-2004-002 | | 10 CFR 50.73(a)(2)(ii)(A), Seriously Degraded | 05000271/LER-2004-002 | Special Nuclear Material Inventory Location Discrepancy | | 05000285/LER-2004-002 | Inoperable Diesel Generator for 28 Days Due to Blown Fuse During Shutdown | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000336/LER-2004-002 | | 10 CFR 50.73(a)(2)(iv)(A), System Actuation | 05000311/LER-2004-002 | Failure To Comply With Technical Specifications During Reactor Protection Instrument Calibration . | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000254/LER-2004-002 | Quad Cities Nuclear Power Station Unit 1 05000254 1 of 4 | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications | 05000263/LER-2004-002 | | | 05000302/LER-2004-002 | Emergency Diesel Generator Inoperable Due To Fuel Oil Header Outlet Check Valve Leaking Past Seat | 10 CFR 50.73(a)(2)(i)(B), Prohibited by Technical Specifications |
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