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| MODE (9) 20.2201(b) 20.2203(a)(2)(v) 50. 73(a)(2)(i) 50. 73(a)(2)(viii) | | MODE (9) 20.2201(b) 20.2203(a)(2)(v) 50. 73(a)(2)(i) 50. 73(a)(2)(viii) |
| POWER 20.2203(a)(1) 20.2203(a)(3)(i) x 50. 73(a)(2)(ii) 50. 73(a)(2)(x) | | POWER 20.2203(a)(1) 20.2203(a)(3)(i) x 50. 73(a)(2)(ii) 50. 73(a)(2)(x) |
| LEVEL (10) 20.2203(a)(2)(i) 20.2203(a)(3)(ii) 50. 73(a)(2)(iii) 73.71 | | LEVEL (10) 20.2203(a)(2)(i) 20.2203(a)(3)(ii) 50. 73(a)(2)(iii) 73.71 20.2203(a)(2)(ii) 20.2203(a)(4) 50. 73(a)(2)(iv) OTHER 20.2203(a)(2)(iii) 50.36(c)(1) 50. 73(a)(2)(v) Spec~in Abstract below or in C Form 366A 20.2203(a)(2)(iv) 50.36(c)(2) 50._73(a)(2)(vii) |
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| 20.2203(a)(2)(ii) 20.2203(a)(4) 50. 73(a)(2)(iv) OTHER 20.2203(a)(2)(iii) 50.36(c)(1) 50. 73(a)(2)(v) Spec~in Abstract below or in C Form 366A 20.2203(a)(2)(iv) 50.36(c)(2) 50._73(a)(2)(vii) | |
| LICENSEE CONTACT FOR THIS LER (12) | | LICENSEE CONTACT FOR THIS LER (12) |
| NAME TELEPHONE NUMBER (Include Area Code) | | NAME TELEPHONE NUMBER (Include Area Code) |
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| * NRC FORM 366A (4-95) | | * NRC FORM 366A (4-95) |
| LICENSEE EVENT REPORT (LER) | | LICENSEE EVENT REPORT (LER) |
| TEXT CONTINUATION | | TEXT CONTINUATION U.S. NUCLEAR REGULATORY COMMISSION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3) |
| * U.S. NUCLEAR REGULATORY COMMISSION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3)
| |
| YEAR I SEQUENTIAL NUMBER IREVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 2 OF 8 95 - 025 - 00 TEXT (If more space is required, use additional copies of NRC Form 366A) (17) | | YEAR I SEQUENTIAL NUMBER IREVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 2 OF 8 95 - 025 - 00 TEXT (If more space is required, use additional copies of NRC Form 366A) (17) |
| Plant and System Identification: | | Plant and System Identification: |
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| NRC FORM 366A (4-95) | | NRC FORM 366A (4-95) |
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| ..
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| NRC FORM 366A (4-95) | | NRC FORM 366A (4-95) |
| LICENSEE EVENT REPORT (lER) | | LICENSEE EVENT REPORT (lER) |
| * U.S. NUCLEAR REGULATORY COMMISSION TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER LER NUMBER (6) PAGE (3)
| | U.S. NUCLEAR REGULATORY COMMISSION TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER LER NUMBER (6) PAGE (3) |
| YEAR I SEQUENTIAL NUMBER IREVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 4 OF 8 TEXT (If more space is required, use additional copies of NRC Form 366A) (17) | | YEAR I SEQUENTIAL NUMBER IREVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 4 OF 8 TEXT (If more space is required, use additional copies of NRC Form 366A) (17) |
| Description I Analysis of Occurrence Ccon'd): | | Description I Analysis of Occurrence Ccon'd): |
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| NRC FORM 366A (4-95) | | NRC FORM 366A (4-95) |
| * LICENSEE EVENT REPORT {LER) | | * LICENSEE EVENT REPORT {LER) |
| TEXT CONTINUATION | | TEXT CONTINUATION U.S. NUCLEAR REGULATORY COMMISSION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3) |
| * U.S. NUCLEAR REGULATORY COMMISSION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3)
| |
| YEAR I SEQUENTIAL NUMBER IREVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 5 OF 8 TEXT (If more space is required, use additional copies of NRC Form 366~) (17) | | YEAR I SEQUENTIAL NUMBER IREVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 5 OF 8 TEXT (If more space is required, use additional copies of NRC Form 366~) (17) |
| Description/Analysis of Occurrence (cont'd): | | Description/Analysis of Occurrence (cont'd): |
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Line 106: |
| NRC FORM 366A (4-95) | | NRC FORM 366A (4-95) |
| NRC FORM 366A (4-95) | | NRC FORM 366A (4-95) |
| *
| | U.S. NUCLEAR REGULATORY COMMISSION LICENSEE EVENT REPORT (LER) |
| * U.S. NUCLEAR REGULATORY COMMISSION LICENSEE EVENT REPORT (LER)
| |
| TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6\ PAGE (3) . | | TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6\ PAGE (3) . |
| YEAR l SEQUENTIAL NUMBER IREVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 6 OF 8 TEXT (If more apace is required, use additional copies of NRC Form 366A) (17) | | YEAR l SEQUENTIAL NUMBER IREVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 6 OF 8 TEXT (If more apace is required, use additional copies of NRC Form 366A) (17) |
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| NRC FORM 366A (4-95) | | NRC FORM 366A (4-95) |
| *
| | U.S. NUCLEAR REGULATORY COMMISSION LICENSEE EVENT REPORT (LER) |
| * U.S. NUCLEAR REGULATORY COMMISSION LICENSEE EVENT REPORT (LER)
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| TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3) | | TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3) |
| YEAR 1 SEQUENTIAL NUMBER l REVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 7 OF. 8 TEXT (If more space is required, use additional copies of NRC Form 366A) (17) | | YEAR 1 SEQUENTIAL NUMBER l REVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 7 OF. 8 TEXT (If more space is required, use additional copies of NRC Form 366A) (17) |
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| NRC FORM 366A (4-95) | | NRC FORM 366A (4-95) |
| * LICENSEE EVENT REPORT (LER) | | * LICENSEE EVENT REPORT (LER) |
| * U.S. NUCLEAR REGULATORY COMMISSION TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) II PAGE (3)
| | U.S. NUCLEAR REGULATORY COMMISSION TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) II PAGE (3) |
| YEAR I SEQUENTIAL NUMBER IREVISION MJM8ER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 8 OF 8 TEXT (If more space is required, use additional copies of NRC Form 366A) (17) | | YEAR I SEQUENTIAL NUMBER IREVISION MJM8ER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 8 OF 8 TEXT (If more space is required, use additional copies of NRC Form 366A) (17) |
| Corrective Actions (Cont'd): | | Corrective Actions (Cont'd): |
LER 95-025-00:on 951012,identified Plant Procedures Did Not Contain Specific Instructions to Limit Sys Flow for Pump Accident Alignments.Caused by Limited Appreciation of Significance of Operating.Baseline Document RevisedML18101B099 |
Person / Time |
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Site: |
Salem ![PSEG icon.png](/w/images/c/cc/PSEG_icon.png) |
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Issue date: |
11/13/1995 |
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From: |
Berrick H Public Service Enterprise Group |
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To: |
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Shared Package |
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ML18101B098 |
List: |
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References |
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LER-95-025, LER-95-25, NUDOCS 9511160234 |
Download: ML18101B099 (8) |
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Similar Documents at Salem |
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Category:LICENSEE EVENT REPORT (SEE ALSO AO
MONTHYEARML18107A5031999-08-26026 August 1999 LER 99-006-00:on 990729,determined That SG Blowdown RMs Setpoint Was non-conservative.Caused by Inadequate ACs for Incorporating Original Plant Licensing Data Into Plant Procedures.Blowdown Will Be Restricted.With 990826 Ltr ML18107A4691999-07-28028 July 1999 LER 99-008-00:on 990714,determined That Limit Switch Cables Were Subject to Multiple Hot Shorts in Same Fire Area.Caused by Inadequate Original Post Fire Safe Shutdown Analysis.All Limit Switch Cables for MOVs Were Reviewed.With 990728 Ltr ML18107A4441999-07-0606 July 1999 LER 99-007-00:on 990605,surveillance for Quadrant Power Tilt Ratio (QPTR) Was Missed.Caused by Human Error.Qptr Calculation Was Performed & Personnel Involved Have Been Held Accountable IAW Pse&G Policies.With 990706 Ltr ML18107A4211999-07-0202 July 1999 LER 99-005-00:on 990605,11 Containment Declared Inoperable. Caused by Valves 11SW72 & 11SW223 Both Leaking.Procedure S1.OP-ST.SW-0010(Q) Was Enhanced to Provide Specific Instructions to Ensure Proper Sequencing.With 990702 Ltr ML18107A4321999-07-0101 July 1999 LER 99-006-01:on 990501,determined That There Was No Flow in One of Four Injection Legs.Caused by Sticking of Valve in Safety Injection Discharge Line to 21 Cold Leg.Valve Was Cut Out of Sys & Replaced.With 990701 Ltr ML18107A4331999-07-0101 July 1999 LER 99-002-01:on 990405,determined That 2SA118 Failed as Found Leakrate Test.Caused by Foreign Matl Found in 2SA118 valve.2SA118 Valve Was Cycled Several Times & Seat Area Was Air Blown in Order to Displace Foreign Matl.With 990701 Ltr ML18107A3951999-06-17017 June 1999 LER 99-004-00:on 990520,reactor Tripped from 100% Power,Due to Negative Flux Trip Signal from Nuclear Instrumentation. Cause Has Not Been Determined.Discoloration Was Identified on One of Penetrations.With 990617 Ltr ML18107A3661999-06-0909 June 1999 LER 99-003-00:on 990513,unplanned Entry Into TS 3.0.3 Was Made.Caused by Human error.Re-positioned Creacs Supply Fan Selector Switches & Revised Procedures S1 & S2.OP-ST.SSP-0001(Q).With 990609 Ltr ML18107A3551999-06-0202 June 1999 LER 99-005-00:on 990504,failure to Meet TS Action Statement Requirements for High Oxygen Concentration in Waste Gas Holdup Sys Occurred.Caused by Inability of Operators. Existing Procedures Will Be Evaluated.With 990602 Ltr ML18107A3541999-06-0101 June 1999 LER 99-006-00:on 990501,HHSI Flow Balance Discrepancy Was Noted During Surveillance.Caused by Sticking of Check Valve in SI Discharge Line to 21 Cold Leg.Valve 21SJ17,was Cut Out of Sys & Replaced.With 990601 Ltr ML18107A2931999-05-12012 May 1999 LER 99-002-00:on 990413,determined That Number 12 Auxiliary Bldg Exhaust Fan Was Rotating Backwards.Caused by mis-wiring of Motor Due to Human Error by Maint technician.Mis-wiring Was Corrected & Fan Was Returned to Svc.With 990512 Ltr ML18107A2781999-05-10010 May 1999 LER 99-004-00:on 990411,automatic Actuation of ESF Occurred During Reactor Vessel Head Removal in Support of Refueling Operations.Caused by High Radiation Condition.Containment Atmosphere Was Monitored.With 990505 Ltr ML18107A2791999-05-0404 May 1999 LER 99-003-00:on 990406,all Salem Unit 2 Chillers Rendered Inoperable.Caused by Human Error.Lessons Learned from Event Were Communicated to All Operators by Including Them in Night Orders.With 990504 Ltr ML18107A2741999-05-0303 May 1999 LER 99-002-00:on 990405,determined That Containment Isolation Valve Failed as Found Leakrate Test.Caused by Foreign Matl Blocking Valves from Closing.Check Valve Mechanically Agitated.With 990504 Ltr ML18107A2351999-04-23023 April 1999 LER 99-001-00:on 990330,MSSV Failed Lift Set Test.Caused by Setpoint Variance Which Is Result of Aging.Valves Were Adjusted & Retested to Ensure TS Tolerance.With 990423 Ltr ML18106B1471999-03-29029 March 1999 LER 99-001-00:on 990228,reactor Scram Was Noted as Result of Turbine Trip.Caused by Operator Error.Lesson Plans Revised to Explicitly Demonstrate Manner in Which Valve Functions. with 990329 Ltr ML18106B0701999-02-16016 February 1999 LER 98-015-00:on 981208,inadvertent Discharge Through RHR Relief Valve During Startup Was Noted.Caused by Operator Performing Too Many Tasks Simultaneously.Appropriate Actions Have Been Taken IAW Policies & Procedures.With 990216 Ltr ML18106B0491999-01-28028 January 1999 LER 98-007-01:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Caused by Transgranular Stress Corrosion Cracking.Replaced Affected Tubing.With 990128 Ltr ML18106B0401999-01-18018 January 1999 LER 98-016-00:on 981219,ECCS Leakage Was Outside of Design Value.Caused by Leakage Past Seat of 21RH34 Manual Drain. Valve 21RH34 Was Reseated.With 990118 Ltr ML18106B0081998-12-24024 December 1998 LER 97-001-01:on 970215,failure to Perform TS Surveillance of Component Cooling Water Sys Check Valves Occurred.Caused by Inadequate Communication Between EOP Group & IST Reviewers.Procedure Revised.With 981224 Ltr ML18106B0021998-12-17017 December 1998 LER 98-015-01:on 980924,improper Installation of Test Equipment to RPS Occurred.Caused by Inadequate 10CFR50.59 Applicability Reviews During Past Revs.Revised Procedures. with 981217 Ltr ML18106A9551998-11-0303 November 1998 LER 96-013-01:on 960711,concluded That Current Gain & Bias Settings Had Rendered Overtemperature Delta Temp Protection Channels Inoperable.Caused by Scaling Error.Licensee Will Revise Scaling Calculations.With 981105 Ltr ML18106A9451998-10-30030 October 1998 LER 97-004-01:on 970408,failure to Comply with TS Action Statement,Dg Start & Inadequate Surveillance Testing,Was Noted.Caused by Inadequate Tracking of Inoperable Equipment. Discussed Event & Lessons Learned.With 981022 Ltr ML18106A9491998-10-22022 October 1998 LER 98-015-00:on 980924,identified Improper Installation of Test Equipment to Rps.Cause Indeterminate.Procedures for Installation of Test Equipment for Collection of State Point Data Were Placed on Administrative Hold.With 981022 Ltr ML18106A9301998-10-21021 October 1998 LER 98-014-00:on 980725,noted Improper Calibr of Liquid Radwaste Effluent Line Radiation Monitor.Caused by Inattention to Detail by Maint Personnel.Channel Calibr Was Successfully Performed on 1R18 on 980821.With 981019 Ltr ML18106A9071998-10-0101 October 1998 LER 98-014-00:on 980918,discovered That Fire Barrier Matl for HVAC Ducts Does Not Meet Required Level of Fire Resistance.Cause Indeterminate.Established Appropriate Compensatory Actions for Fire Barriers.With 981001 Ltr ML18106A8951998-09-28028 September 1998 LER 98-012-01:on 980725,noted That Afs Was Operated with Less than Required Number of Operable AFW Pumps.Caused by Improper Procedure Implementation.Runout Protection Pressure Device for 22 AFW Pumps Was Returned to Svc.With 980928 Ltr ML18106A8821998-09-21021 September 1998 LER 98-013-00:on 980820,noted Surveillance of Containment Penetration Overcurrent Protection Devices Missed.Caused by Human Error.Satisfactorily Tested Apprpriate Breakers & Disciplined Involved Personnel.With 980921 Ltr ML18106A8791998-09-16016 September 1998 LER 96-006-01:on 960717,determined That non-radioactive Liquid Basin Radwaste Monitor Inoperable During Low Head Conditions.Caused by Inadequate Design Change Package.Design Change 1EC3663-01 Has Been Installed.With 980916 Ltr ML18106A8801998-09-0808 September 1998 LER 98-013-00:on 980806,operation with TS Required Equipment OOS Was Noted.Caused by Human Error.Reviewed Processes & Practices Re Safety Sys Status Control,Procedure Rev & Extra Training.With 980908 Ltr ML18106A8531998-08-27027 August 1998 LER 98-007-00:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Cause of Event Has Not Yet Been Determined.Assembled Root Cause Team & Replaced Affected tubing.W/980827 Ltr ML18106A8521998-08-27027 August 1998 LER 98-011-00:on 980803,ESFA During a 4KV Automatic Transfer Test Was Noted.Caused by Premature Release of Control Console Pushbutton Due to Inadequate Procedural Step.Revised procedure.W/980827 Ltr ML18106A8421998-08-24024 August 1998 LER 98-012-00:on 980725,discovered That Plant Had Operated in Modes 1 & 2 w/twenty-two AFW Pumps Inoperable.Caused by Failure to Restore Pump Runout Protection Pressure Device to Svc.Returned Subject Device to svc.W/980824 Ltr ML18106A8431998-08-24024 August 1998 LER 98-009-00:on 980810,failure to Post Continuous Firewatch as Required by Fire Protection Plan Noted.Caused by Failure to Recognize Concurrent Conditions.Continuous Firewatch Was Posted Immediately & Repaired Smoke detectors.W/980824 Ltr ML18106A8141998-08-13013 August 1998 LER 98-010-00:on 980714,determined That Leakage from Boron Injection Tank Exceeded Max Allowable ECCS Leakage from Sources Outside Containment.Caused by Leaking 2SJ404 Manual Sample valve.2SJ404 Valve repaired.W/980813 Ltr ML18106A8201998-08-13013 August 1998 LER 98-012-00:on 980715,potential to Exceed Rating of Piping Due to Isolation of Overpressure Protection Line Was Noted. Caused by Inadequate Procedural Guidance.Appropriate Operations Dept Procedures Have Been revised.W/980813 Ltr ML18106A6931998-06-29029 June 1998 LER 98-003-00:on 980122,inappropriate Plugging of Tubes R9C60 & R10C60 in Salem Unit 2 Sg,Was Performed.Caused by Failure of Qualification,Verification & Validation Process. Tubes Reviewed to Verify No Others Inappropriately Plugged ML18106A6471998-06-0404 June 1998 LER 98-011-00:on 980505,improper Isolation of Single Cell Battery Charger from 125 Vdc Battery Was Noted.Caused by Inadequate 10CFR50.59 Applicability Review.Placed Procedure SC.MD-CM.ZZ-0024(Q) on Administrative hold.W/980604 Ltr ML18106A6421998-06-0101 June 1998 LER 98-010-00:on 931019,reactor Pressure Vessel Insp Plugs Were Out of Configuration,Was Noted.Caused by Personnel Error.Proper Configuration Was Restored Shortly After Discovery Prior to Entering Mode 2.W/980601 Ltr ML18106A6431998-05-29029 May 1998 LER 98-006-01:on 980227,determined Incorrect Scaling Error of First Stage Pressure Transmitter Existed.Caused by Human Error.Revised Setpoint Calculation SC-MS002-01 & Revised Associated Instrument Calibr Database info.W/980529 Ltr ML18106A6141998-05-18018 May 1998 LER 98-008-00:on 970814,failure to Test 21 & 22 AF 40 Valves in Closed Direction as Required by TS 4.0.5 Was Noted.Caused by Inadequate Design Mod Process.Motor Driven 21/22 AF 40 Valves Were Tested IAW Revised procedure.W/980518 Ltr ML18106A5901998-05-0101 May 1998 LER 98-009-00:on 980405,epoxy Missing from Terminals of H Analyzer Was Noted.Caused by Inadequate Development of Procedure.H Analyzers Were Repaired & Review of Other Safety Related Equipment in Containment Was performed.W/980501 Ltr ML18106A5611998-04-20020 April 1998 LER 98-008-00:on 980323,inadequate Testing of Salem Unit 1 Containment Air Locks Resulted in Entering TS 3.0.3.Caused by less-than-adequate Work Practices During Replacement of Equalizing Valve.Salem Unit 2 Airlocks Were Inspected ML18106A6061998-04-0101 April 1998 Corrected LER 98-004-00:on 980302,failure to Comply W/Tss 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Have Been Taken to Correctly Document Safety Factors.Corrects Prior Similar Occurrences ML18106A4451998-04-0101 April 1998 LER 98-004-00:on 980302,failure to Perform TS 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Were Taken to Correctly Document Safety factors.W/980401 Ltr ML18106A4351998-03-30030 March 1998 LER 98-006-00:on 980227,incorrect Scaling of First Stage Turbine Impulse Pressure Transmitters Noted.Cause Indeterminate.Implemented Procedure Changes & re-scaled Affected Turbine Impulse Pressure transmitters.W/980330 Ltr ML18106A3961998-03-20020 March 1998 LER 98-005-00:on 980219,inoperability of Twelve EDG Fuel Oil Transfer Pump (FOTP) Noted.Caused by Installation of Incorrect Control Switch.Installed Correct off-auto-manual Switch & Verified Operability of Twelve FOTP.W/980320 Ltr ML18106A5781998-03-20020 March 1998 Corrected LER 98-005-00:on 980219,inoperability of 12 Fuel Oil Transfer Pump (Fotp),Noted.Caused by Installation of Incorrect Control Switch.Field Insp Performed to Verify Configuration of Switches for 11,21 & 22 FOTPs ML18106A4021998-03-20020 March 1998 LER 98-007-00:on 980218,failure to Establish Containment Integrity (Closure) Prior to Fuel Movement Was Noted.Caused by Failure to Identify & Include Condensate Pot Vent in Appropriate Valve Lineup.Valves identified.W/980320 Ltr ML18106A4031998-03-20020 March 1998 LER 98-006-00:on 980221,ESF Actuation of 11 & 12 Auxiliary Feedwater Pumps Occurred.Caused by Human Error.Operators Promptly Established Feedwater to All SG & Restored Proper Water levels.W/980320 Ltr 1999-08-26
[Table view] Category:RO)
MONTHYEARML18107A5031999-08-26026 August 1999 LER 99-006-00:on 990729,determined That SG Blowdown RMs Setpoint Was non-conservative.Caused by Inadequate ACs for Incorporating Original Plant Licensing Data Into Plant Procedures.Blowdown Will Be Restricted.With 990826 Ltr ML18107A4691999-07-28028 July 1999 LER 99-008-00:on 990714,determined That Limit Switch Cables Were Subject to Multiple Hot Shorts in Same Fire Area.Caused by Inadequate Original Post Fire Safe Shutdown Analysis.All Limit Switch Cables for MOVs Were Reviewed.With 990728 Ltr ML18107A4441999-07-0606 July 1999 LER 99-007-00:on 990605,surveillance for Quadrant Power Tilt Ratio (QPTR) Was Missed.Caused by Human Error.Qptr Calculation Was Performed & Personnel Involved Have Been Held Accountable IAW Pse&G Policies.With 990706 Ltr ML18107A4211999-07-0202 July 1999 LER 99-005-00:on 990605,11 Containment Declared Inoperable. Caused by Valves 11SW72 & 11SW223 Both Leaking.Procedure S1.OP-ST.SW-0010(Q) Was Enhanced to Provide Specific Instructions to Ensure Proper Sequencing.With 990702 Ltr ML18107A4321999-07-0101 July 1999 LER 99-006-01:on 990501,determined That There Was No Flow in One of Four Injection Legs.Caused by Sticking of Valve in Safety Injection Discharge Line to 21 Cold Leg.Valve Was Cut Out of Sys & Replaced.With 990701 Ltr ML18107A4331999-07-0101 July 1999 LER 99-002-01:on 990405,determined That 2SA118 Failed as Found Leakrate Test.Caused by Foreign Matl Found in 2SA118 valve.2SA118 Valve Was Cycled Several Times & Seat Area Was Air Blown in Order to Displace Foreign Matl.With 990701 Ltr ML18107A3951999-06-17017 June 1999 LER 99-004-00:on 990520,reactor Tripped from 100% Power,Due to Negative Flux Trip Signal from Nuclear Instrumentation. Cause Has Not Been Determined.Discoloration Was Identified on One of Penetrations.With 990617 Ltr ML18107A3661999-06-0909 June 1999 LER 99-003-00:on 990513,unplanned Entry Into TS 3.0.3 Was Made.Caused by Human error.Re-positioned Creacs Supply Fan Selector Switches & Revised Procedures S1 & S2.OP-ST.SSP-0001(Q).With 990609 Ltr ML18107A3551999-06-0202 June 1999 LER 99-005-00:on 990504,failure to Meet TS Action Statement Requirements for High Oxygen Concentration in Waste Gas Holdup Sys Occurred.Caused by Inability of Operators. Existing Procedures Will Be Evaluated.With 990602 Ltr ML18107A3541999-06-0101 June 1999 LER 99-006-00:on 990501,HHSI Flow Balance Discrepancy Was Noted During Surveillance.Caused by Sticking of Check Valve in SI Discharge Line to 21 Cold Leg.Valve 21SJ17,was Cut Out of Sys & Replaced.With 990601 Ltr ML18107A2931999-05-12012 May 1999 LER 99-002-00:on 990413,determined That Number 12 Auxiliary Bldg Exhaust Fan Was Rotating Backwards.Caused by mis-wiring of Motor Due to Human Error by Maint technician.Mis-wiring Was Corrected & Fan Was Returned to Svc.With 990512 Ltr ML18107A2781999-05-10010 May 1999 LER 99-004-00:on 990411,automatic Actuation of ESF Occurred During Reactor Vessel Head Removal in Support of Refueling Operations.Caused by High Radiation Condition.Containment Atmosphere Was Monitored.With 990505 Ltr ML18107A2791999-05-0404 May 1999 LER 99-003-00:on 990406,all Salem Unit 2 Chillers Rendered Inoperable.Caused by Human Error.Lessons Learned from Event Were Communicated to All Operators by Including Them in Night Orders.With 990504 Ltr ML18107A2741999-05-0303 May 1999 LER 99-002-00:on 990405,determined That Containment Isolation Valve Failed as Found Leakrate Test.Caused by Foreign Matl Blocking Valves from Closing.Check Valve Mechanically Agitated.With 990504 Ltr ML18107A2351999-04-23023 April 1999 LER 99-001-00:on 990330,MSSV Failed Lift Set Test.Caused by Setpoint Variance Which Is Result of Aging.Valves Were Adjusted & Retested to Ensure TS Tolerance.With 990423 Ltr ML18106B1471999-03-29029 March 1999 LER 99-001-00:on 990228,reactor Scram Was Noted as Result of Turbine Trip.Caused by Operator Error.Lesson Plans Revised to Explicitly Demonstrate Manner in Which Valve Functions. with 990329 Ltr ML18106B0701999-02-16016 February 1999 LER 98-015-00:on 981208,inadvertent Discharge Through RHR Relief Valve During Startup Was Noted.Caused by Operator Performing Too Many Tasks Simultaneously.Appropriate Actions Have Been Taken IAW Policies & Procedures.With 990216 Ltr ML18106B0491999-01-28028 January 1999 LER 98-007-01:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Caused by Transgranular Stress Corrosion Cracking.Replaced Affected Tubing.With 990128 Ltr ML18106B0401999-01-18018 January 1999 LER 98-016-00:on 981219,ECCS Leakage Was Outside of Design Value.Caused by Leakage Past Seat of 21RH34 Manual Drain. Valve 21RH34 Was Reseated.With 990118 Ltr ML18106B0081998-12-24024 December 1998 LER 97-001-01:on 970215,failure to Perform TS Surveillance of Component Cooling Water Sys Check Valves Occurred.Caused by Inadequate Communication Between EOP Group & IST Reviewers.Procedure Revised.With 981224 Ltr ML18106B0021998-12-17017 December 1998 LER 98-015-01:on 980924,improper Installation of Test Equipment to RPS Occurred.Caused by Inadequate 10CFR50.59 Applicability Reviews During Past Revs.Revised Procedures. with 981217 Ltr ML18106A9551998-11-0303 November 1998 LER 96-013-01:on 960711,concluded That Current Gain & Bias Settings Had Rendered Overtemperature Delta Temp Protection Channels Inoperable.Caused by Scaling Error.Licensee Will Revise Scaling Calculations.With 981105 Ltr ML18106A9451998-10-30030 October 1998 LER 97-004-01:on 970408,failure to Comply with TS Action Statement,Dg Start & Inadequate Surveillance Testing,Was Noted.Caused by Inadequate Tracking of Inoperable Equipment. Discussed Event & Lessons Learned.With 981022 Ltr ML18106A9491998-10-22022 October 1998 LER 98-015-00:on 980924,identified Improper Installation of Test Equipment to Rps.Cause Indeterminate.Procedures for Installation of Test Equipment for Collection of State Point Data Were Placed on Administrative Hold.With 981022 Ltr ML18106A9301998-10-21021 October 1998 LER 98-014-00:on 980725,noted Improper Calibr of Liquid Radwaste Effluent Line Radiation Monitor.Caused by Inattention to Detail by Maint Personnel.Channel Calibr Was Successfully Performed on 1R18 on 980821.With 981019 Ltr ML18106A9071998-10-0101 October 1998 LER 98-014-00:on 980918,discovered That Fire Barrier Matl for HVAC Ducts Does Not Meet Required Level of Fire Resistance.Cause Indeterminate.Established Appropriate Compensatory Actions for Fire Barriers.With 981001 Ltr ML18106A8951998-09-28028 September 1998 LER 98-012-01:on 980725,noted That Afs Was Operated with Less than Required Number of Operable AFW Pumps.Caused by Improper Procedure Implementation.Runout Protection Pressure Device for 22 AFW Pumps Was Returned to Svc.With 980928 Ltr ML18106A8821998-09-21021 September 1998 LER 98-013-00:on 980820,noted Surveillance of Containment Penetration Overcurrent Protection Devices Missed.Caused by Human Error.Satisfactorily Tested Apprpriate Breakers & Disciplined Involved Personnel.With 980921 Ltr ML18106A8791998-09-16016 September 1998 LER 96-006-01:on 960717,determined That non-radioactive Liquid Basin Radwaste Monitor Inoperable During Low Head Conditions.Caused by Inadequate Design Change Package.Design Change 1EC3663-01 Has Been Installed.With 980916 Ltr ML18106A8801998-09-0808 September 1998 LER 98-013-00:on 980806,operation with TS Required Equipment OOS Was Noted.Caused by Human Error.Reviewed Processes & Practices Re Safety Sys Status Control,Procedure Rev & Extra Training.With 980908 Ltr ML18106A8531998-08-27027 August 1998 LER 98-007-00:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Cause of Event Has Not Yet Been Determined.Assembled Root Cause Team & Replaced Affected tubing.W/980827 Ltr ML18106A8521998-08-27027 August 1998 LER 98-011-00:on 980803,ESFA During a 4KV Automatic Transfer Test Was Noted.Caused by Premature Release of Control Console Pushbutton Due to Inadequate Procedural Step.Revised procedure.W/980827 Ltr ML18106A8421998-08-24024 August 1998 LER 98-012-00:on 980725,discovered That Plant Had Operated in Modes 1 & 2 w/twenty-two AFW Pumps Inoperable.Caused by Failure to Restore Pump Runout Protection Pressure Device to Svc.Returned Subject Device to svc.W/980824 Ltr ML18106A8431998-08-24024 August 1998 LER 98-009-00:on 980810,failure to Post Continuous Firewatch as Required by Fire Protection Plan Noted.Caused by Failure to Recognize Concurrent Conditions.Continuous Firewatch Was Posted Immediately & Repaired Smoke detectors.W/980824 Ltr ML18106A8141998-08-13013 August 1998 LER 98-010-00:on 980714,determined That Leakage from Boron Injection Tank Exceeded Max Allowable ECCS Leakage from Sources Outside Containment.Caused by Leaking 2SJ404 Manual Sample valve.2SJ404 Valve repaired.W/980813 Ltr ML18106A8201998-08-13013 August 1998 LER 98-012-00:on 980715,potential to Exceed Rating of Piping Due to Isolation of Overpressure Protection Line Was Noted. Caused by Inadequate Procedural Guidance.Appropriate Operations Dept Procedures Have Been revised.W/980813 Ltr ML18106A6931998-06-29029 June 1998 LER 98-003-00:on 980122,inappropriate Plugging of Tubes R9C60 & R10C60 in Salem Unit 2 Sg,Was Performed.Caused by Failure of Qualification,Verification & Validation Process. Tubes Reviewed to Verify No Others Inappropriately Plugged ML18106A6471998-06-0404 June 1998 LER 98-011-00:on 980505,improper Isolation of Single Cell Battery Charger from 125 Vdc Battery Was Noted.Caused by Inadequate 10CFR50.59 Applicability Review.Placed Procedure SC.MD-CM.ZZ-0024(Q) on Administrative hold.W/980604 Ltr ML18106A6421998-06-0101 June 1998 LER 98-010-00:on 931019,reactor Pressure Vessel Insp Plugs Were Out of Configuration,Was Noted.Caused by Personnel Error.Proper Configuration Was Restored Shortly After Discovery Prior to Entering Mode 2.W/980601 Ltr ML18106A6431998-05-29029 May 1998 LER 98-006-01:on 980227,determined Incorrect Scaling Error of First Stage Pressure Transmitter Existed.Caused by Human Error.Revised Setpoint Calculation SC-MS002-01 & Revised Associated Instrument Calibr Database info.W/980529 Ltr ML18106A6141998-05-18018 May 1998 LER 98-008-00:on 970814,failure to Test 21 & 22 AF 40 Valves in Closed Direction as Required by TS 4.0.5 Was Noted.Caused by Inadequate Design Mod Process.Motor Driven 21/22 AF 40 Valves Were Tested IAW Revised procedure.W/980518 Ltr ML18106A5901998-05-0101 May 1998 LER 98-009-00:on 980405,epoxy Missing from Terminals of H Analyzer Was Noted.Caused by Inadequate Development of Procedure.H Analyzers Were Repaired & Review of Other Safety Related Equipment in Containment Was performed.W/980501 Ltr ML18106A5611998-04-20020 April 1998 LER 98-008-00:on 980323,inadequate Testing of Salem Unit 1 Containment Air Locks Resulted in Entering TS 3.0.3.Caused by less-than-adequate Work Practices During Replacement of Equalizing Valve.Salem Unit 2 Airlocks Were Inspected ML18106A6061998-04-0101 April 1998 Corrected LER 98-004-00:on 980302,failure to Comply W/Tss 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Have Been Taken to Correctly Document Safety Factors.Corrects Prior Similar Occurrences ML18106A4451998-04-0101 April 1998 LER 98-004-00:on 980302,failure to Perform TS 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Were Taken to Correctly Document Safety factors.W/980401 Ltr ML18106A4351998-03-30030 March 1998 LER 98-006-00:on 980227,incorrect Scaling of First Stage Turbine Impulse Pressure Transmitters Noted.Cause Indeterminate.Implemented Procedure Changes & re-scaled Affected Turbine Impulse Pressure transmitters.W/980330 Ltr ML18106A3961998-03-20020 March 1998 LER 98-005-00:on 980219,inoperability of Twelve EDG Fuel Oil Transfer Pump (FOTP) Noted.Caused by Installation of Incorrect Control Switch.Installed Correct off-auto-manual Switch & Verified Operability of Twelve FOTP.W/980320 Ltr ML18106A5781998-03-20020 March 1998 Corrected LER 98-005-00:on 980219,inoperability of 12 Fuel Oil Transfer Pump (Fotp),Noted.Caused by Installation of Incorrect Control Switch.Field Insp Performed to Verify Configuration of Switches for 11,21 & 22 FOTPs ML18106A4021998-03-20020 March 1998 LER 98-007-00:on 980218,failure to Establish Containment Integrity (Closure) Prior to Fuel Movement Was Noted.Caused by Failure to Identify & Include Condensate Pot Vent in Appropriate Valve Lineup.Valves identified.W/980320 Ltr ML18106A4031998-03-20020 March 1998 LER 98-006-00:on 980221,ESF Actuation of 11 & 12 Auxiliary Feedwater Pumps Occurred.Caused by Human Error.Operators Promptly Established Feedwater to All SG & Restored Proper Water levels.W/980320 Ltr 1999-08-26
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARML20217A9931999-09-30030 September 1999 NRC Regulatory Assessment & Oversight Pilot Program, Performance Indicator Data ML18107A5581999-09-30030 September 1999 Monthly Operating Rept for Sept 1999 for Salem,Unit 2.With 991014 Ltr ML18107A5571999-09-30030 September 1999 Monthly Operating Rept for Sept 1999 for Salem,Unit 1.With 991014 Ltr ML18107A5301999-08-31031 August 1999 Monthly Operating Rept for Aug 1999 for Salem,Unit 2.With 990913 Ltr ML18107A5311999-08-31031 August 1999 Monthly Operating Rept for Aug 1999 for Salem,Unit 1.With 990913 ML18107A5031999-08-26026 August 1999 LER 99-006-00:on 990729,determined That SG Blowdown RMs Setpoint Was non-conservative.Caused by Inadequate ACs for Incorporating Original Plant Licensing Data Into Plant Procedures.Blowdown Will Be Restricted.With 990826 Ltr ML18107A5201999-08-12012 August 1999 Rev 0 to Sgs Unit 2 ISI RFO Exam Results (S2RFO#9) Second Interval,Second Period, First Outage (96RF). ML18107A4811999-07-31031 July 1999 Monthly Operating Rept for July 1999 for Salem,Unit 1.With 990813 Ltr ML18107A4821999-07-31031 July 1999 Monthly Operating Rept for July 1999 for Salem,Unit 2.With 990813 Ltr ML18107A4691999-07-28028 July 1999 LER 99-008-00:on 990714,determined That Limit Switch Cables Were Subject to Multiple Hot Shorts in Same Fire Area.Caused by Inadequate Original Post Fire Safe Shutdown Analysis.All Limit Switch Cables for MOVs Were Reviewed.With 990728 Ltr ML18107A4441999-07-0606 July 1999 LER 99-007-00:on 990605,surveillance for Quadrant Power Tilt Ratio (QPTR) Was Missed.Caused by Human Error.Qptr Calculation Was Performed & Personnel Involved Have Been Held Accountable IAW Pse&G Policies.With 990706 Ltr ML18107A4211999-07-0202 July 1999 LER 99-005-00:on 990605,11 Containment Declared Inoperable. Caused by Valves 11SW72 & 11SW223 Both Leaking.Procedure S1.OP-ST.SW-0010(Q) Was Enhanced to Provide Specific Instructions to Ensure Proper Sequencing.With 990702 Ltr ML18107A4331999-07-0101 July 1999 LER 99-002-01:on 990405,determined That 2SA118 Failed as Found Leakrate Test.Caused by Foreign Matl Found in 2SA118 valve.2SA118 Valve Was Cycled Several Times & Seat Area Was Air Blown in Order to Displace Foreign Matl.With 990701 Ltr ML18107A4321999-07-0101 July 1999 LER 99-006-01:on 990501,determined That There Was No Flow in One of Four Injection Legs.Caused by Sticking of Valve in Safety Injection Discharge Line to 21 Cold Leg.Valve Was Cut Out of Sys & Replaced.With 990701 Ltr ML18107A5211999-07-0101 July 1999 Rev 0 to Sgs Unit 2 ISI RFO Exam Results (S2RFO#10) Second Interval,Second Period,Second Outage (99RF). ML18107A4351999-06-30030 June 1999 Monthly Operating Rept for June 1999 for Salem,Unit 1.With 990713 Ltr ML18107A4341999-06-30030 June 1999 Monthly Operating Rept for June 1999 for Salem,Unit 2.With 990713 Ltr ML20196H8621999-06-30030 June 1999 NRC Regulatory Assessment & Oversight Pilot Program, Performance Indicator Data, June 1999 Rept ML18107A3951999-06-17017 June 1999 LER 99-004-00:on 990520,reactor Tripped from 100% Power,Due to Negative Flux Trip Signal from Nuclear Instrumentation. Cause Has Not Been Determined.Discoloration Was Identified on One of Penetrations.With 990617 Ltr ML18107A3661999-06-0909 June 1999 LER 99-003-00:on 990513,unplanned Entry Into TS 3.0.3 Was Made.Caused by Human error.Re-positioned Creacs Supply Fan Selector Switches & Revised Procedures S1 & S2.OP-ST.SSP-0001(Q).With 990609 Ltr ML18107A3551999-06-0202 June 1999 LER 99-005-00:on 990504,failure to Meet TS Action Statement Requirements for High Oxygen Concentration in Waste Gas Holdup Sys Occurred.Caused by Inability of Operators. Existing Procedures Will Be Evaluated.With 990602 Ltr ML18107A3441999-06-0101 June 1999 Interim Part 21 Rept Re Premature Over Voltage Protection Actuation in Circuit Specific Application in Dc Power Supply.Testing & Evaluation Activities Will Be Completed on 990716 ML18107A3541999-06-0101 June 1999 LER 99-006-00:on 990501,HHSI Flow Balance Discrepancy Was Noted During Surveillance.Caused by Sticking of Check Valve in SI Discharge Line to 21 Cold Leg.Valve 21SJ17,was Cut Out of Sys & Replaced.With 990601 Ltr ML18107A3681999-05-31031 May 1999 Monthly Operating Rept for May 1999 for Salem Generating Station,Unit 1.With 990611 Ltr ML18107A3721999-05-31031 May 1999 Monthly Operating Rept for May 1999 for Salem Generating Station,Unit 2.With 990611 Ltr ML18107A2931999-05-12012 May 1999 LER 99-002-00:on 990413,determined That Number 12 Auxiliary Bldg Exhaust Fan Was Rotating Backwards.Caused by mis-wiring of Motor Due to Human Error by Maint technician.Mis-wiring Was Corrected & Fan Was Returned to Svc.With 990512 Ltr ML18107A2781999-05-10010 May 1999 LER 99-004-00:on 990411,automatic Actuation of ESF Occurred During Reactor Vessel Head Removal in Support of Refueling Operations.Caused by High Radiation Condition.Containment Atmosphere Was Monitored.With 990505 Ltr ML18107A2791999-05-0404 May 1999 LER 99-003-00:on 990406,all Salem Unit 2 Chillers Rendered Inoperable.Caused by Human Error.Lessons Learned from Event Were Communicated to All Operators by Including Them in Night Orders.With 990504 Ltr ML18107A2741999-05-0303 May 1999 LER 99-002-00:on 990405,determined That Containment Isolation Valve Failed as Found Leakrate Test.Caused by Foreign Matl Blocking Valves from Closing.Check Valve Mechanically Agitated.With 990504 Ltr ML18107A3711999-04-30030 April 1999 Corrected Monthly Operating Rept for Apr 1999 for Salem Generating Station,Unit 1 ML18107A3151999-04-30030 April 1999 Submittal-Only Screening Review of Salem Generating Station Individual Plant Exam for External Events (Seismic Portion), Rev 1 ML18107A2991999-04-30030 April 1999 Monthly Operating Rept for Apr 1999 for Salem Unit 1.With 990514 Ltr ML18107A2971999-04-30030 April 1999 Monthly Operating Rept for Apr 1999 for Salem Unit 2.With 990514 Ltr ML18107A2351999-04-23023 April 1999 LER 99-001-00:on 990330,MSSV Failed Lift Set Test.Caused by Setpoint Variance Which Is Result of Aging.Valves Were Adjusted & Retested to Ensure TS Tolerance.With 990423 Ltr ML18107A2881999-04-0707 April 1999 Rev 0 to NFS-0174, COLR for Salem Unit 2 Cycle 11. ML18107A1821999-03-31031 March 1999 Monthly Operating Rept for Mar 1999 for Salem,Unit 1.With 990414 Ltr ML18107A1831999-03-31031 March 1999 Monthly Operating Rept for Mar 1999 for Salem,Unit 2.With 990414 Ltr ML18106B1471999-03-29029 March 1999 LER 99-001-00:on 990228,reactor Scram Was Noted as Result of Turbine Trip.Caused by Operator Error.Lesson Plans Revised to Explicitly Demonstrate Manner in Which Valve Functions. with 990329 Ltr ML18106B1021999-02-28028 February 1999 Monthly Operating Rept for Feb 1999 for Salem Unit 2.With 990315 Ltr ML18106B1011999-02-28028 February 1999 Monthly Operating Rept for Feb 1999 for Salem Unit 1.With 990315 Ltr ML18106B0931999-02-25025 February 1999 Part 21 Rept Re Possible Defect in Swagelok Pipe Fitting Tee,Part Number SS-6-T.Caused by Crack Due to Improper Location of Heated Bar.Only One Part Out of 7396 Pieces in Forging Lot Was Found to Be Cracked.Affected Util,Notified ML18106B0701999-02-16016 February 1999 LER 98-015-00:on 981208,inadvertent Discharge Through RHR Relief Valve During Startup Was Noted.Caused by Operator Performing Too Many Tasks Simultaneously.Appropriate Actions Have Been Taken IAW Policies & Procedures.With 990216 Ltr ML18106B0551999-02-0101 February 1999 Part 21 Rept Re Possible Matl Defect in Swagelok Pipe Fitting Tee,Part Number SS-6-T.Defect Is Crack in Center of Forging.Analysis of Part Is Continuing & Further Details Will Be Provided IAW Ncr Timetables.Drawing of Part,Encl ML18106B0561999-01-31031 January 1999 Monthly Operating Rept for Jan 1999 for Salem Generating Station,Unit 2.With 990212 Ltr ML18106B0571999-01-31031 January 1999 Monthly Operating Rept for Jan 1999 for Salem Generating Station,Unit 1.With 990212 Ltr ML20205P1671999-01-31031 January 1999 a POST-PLUME Phase, Federal Participation Exercise ML18106B0441999-01-29029 January 1999 Part 21 Rept Re Possible Defect in Swagelok Pipe Fitting Tee Part Number SS-6-T.Caused by Crack in Center of Forging. Continuing Analysis of Part & Will Provide Details in Acoordance with NRC Timetables ML18106B0491999-01-28028 January 1999 LER 98-007-01:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Caused by Transgranular Stress Corrosion Cracking.Replaced Affected Tubing.With 990128 Ltr ML18106B0401999-01-18018 January 1999 LER 98-016-00:on 981219,ECCS Leakage Was Outside of Design Value.Caused by Leakage Past Seat of 21RH34 Manual Drain. Valve 21RH34 Was Reseated.With 990118 Ltr ML18106B0251998-12-31031 December 1998 Monthly Operating Rept for Dec 1998 for Salem Unit 2.With 990115 Ltr 1999-09-30
[Table view] |
Text
..
NRCFORM 366 (4-95)
U.S. NUCLEAR REGULATORY COMMISSION *APPROVED BY OMO NO. 3150-0104 EXPIRES 04/30/98 ESTIMATED BURDEN PER RESPONSE TO COMPLY WITH THIS MANDATORY INFORMATION COLLECTION REQUEST: 60.0 HRS.
REPORTED LESSONS LEARNED ARE INCORPORATED INTO THE LiCENSEE EVENT REPORT (LER) LICENSING PROCESS AND FED BACK TO INDUSTRY. FORWARD COMMENTS REGARDING BURDEN ESTIMATE TO THE INFORMATION AND RECORDS MANAGEMENT BRANCH (T~ F3~, U.S. NUCLEAR (See reverse for required number of REGULATORY COMMISSION, WASHINGTON, DC 20 55-0001, AND TO THE PAPERWORK REDUCTION PROJECT (3150--0104), OFFICE OF digits/characters for each block) MANAGEMENT AND BUDGET, WASHINGTON, DC 20503.
FACILITY NAllE (1) DOCKET NUllBER (2) PAGE (3)
SALEM GENERATING STATION 05000272 1 of8 TITLE (4)
SINGLE FAILURE CONDITIONS THAT COULD HAVE POTENTIALLY COMPROMISED THE ABILITY OF THE SERVICE WATER SYSTEM FROM COMPLETING ITS SAFETY FUNCTION DURING THE RECIRCULATION PHASE
,... .. At.I A""lr"\r*o.1-r EVENT DATE (5) LER NUMBER (6) REPORT DATE (7) OTHER FACILITIES INVOLVED (8)
MONTH DAY YEAR YEAR I SEQUENTIAL NUMBER IREVISION NUMBER MONTH DAY YEAR FACILITY NAME Salem station Unit 2 DOCKET NUMBER 05000311 08 05 94 95 - 025 00 11 13 95 FACILITY NAME DOCKET NUMBER OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR §:(Check one or more) (11)
MODE (9) 20.2201(b) 20.2203(a)(2)(v) 50. 73(a)(2)(i) 50. 73(a)(2)(viii)
POWER 20.2203(a)(1) 20.2203(a)(3)(i) x 50. 73(a)(2)(ii) 50. 73(a)(2)(x)
LEVEL (10) 20.2203(a)(2)(i) 20.2203(a)(3)(ii) 50. 73(a)(2)(iii) 73.71 20.2203(a)(2)(ii) 20.2203(a)(4) 50. 73(a)(2)(iv) OTHER 20.2203(a)(2)(iii) 50.36(c)(1) 50. 73(a)(2)(v) Spec~in Abstract below or in C Form 366A 20.2203(a)(2)(iv) 50.36(c)(2) 50._73(a)(2)(vii)
LICENSEE CONTACT FOR THIS LER (12)
NAME TELEPHONE NUMBER (Include Area Code)
Howard Berrick 609 339-1862 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13)
CAUSE SYSTEM COMPONENT MANUFACTURER I REPORTABLE CAUSE SYSTEM COMPONENT MANUFACTURER REPORTABLE TONPRDS TONPRDS
- IYES (If yes, complete EXPECTED SUBMISSION DATE).
I SUPPLEMENTAL REPORT EXPECTED (14)
I x INO.
EXPECTED SUBMISSION DATE (15)
MONTH DAY YEAR ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16)
On October 12, 1995, during Salem system restart readiness reviews, Problem
.Reports (PRs) associated with Service Water System (SW) alignment concerns,*
which had been identified in 1994, were screened for the proper disposition of reportability. It was determined at this time that the reportability criteria, as defined in 10CFR50.72(b) (2) (i) I was met for these PRs, which had been initiated on August 5, 1994. The most significant conditions described in these PRs (i.e., single failures) could have resulted in an alignment with the potential for runout I cavitation with only 2 SW pumps running during the recirculation phase of a LOCA. This condition was beyond previously analyzed conditions and could have potentially affected the ability of the system to perform/complete its design function. At the point of initiation (8/94) I actions had already been implemented that would have significantly mitigated* these conditions and additional procedure changes were subsequently made to further improve the resulting condition.
9511160234 951113 NRC FORM 366 (4-95) PDR ADOCK 05000272 S PDR
I
LICENSEE EVENT REPORT (LER)
TEXT CONTINUATION U.S. NUCLEAR REGULATORY COMMISSION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3)
YEAR I SEQUENTIAL NUMBER IREVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 2 OF 8 95 - 025 - 00 TEXT (If more space is required, use additional copies of NRC Form 366A) (17)
Plant and System Identification:
Westinghouse - Pressurized Water Reactor Energy Industry Identification System (EIIS) *codes appear in the text as
{xx}
Identification of Occurrence:
Event Date: August 5, 1994 Discovery date: October 12, 1995 Report date: November 13, 1995 Conditions Prior to Occurrence:
Unit 1 Mode: Defueled Re~ctor Power: N/A Unit Load: N/A Unit 2 Mode: 5 Reactor Power: N/A Unit Load: N/A Description/Analysis of Occurrence:
The Salem Service water system is an open cooling water system that is described in section 9.2.1 of the Final Safety Analysis Report (FSAR). In this section of the FSAR it is stated that minimum recirculation requirements can be met with 2 SW pumps. The original (1978) PSE&G sws Description (and the subsequent Configuration Baseline Document) indicate that minimum safeguards can be carried with 2 SW pumps and that minimum safeguards includes 3 Containment Fan Coil Units (CFCU) and 1 Component cooling Heat Exchanger (CCHX).
NRC FORM 366A (4-95)
NRC FORM 366A U.S. NUCLEAR REGULATORY COMMISSION (4-95)
" LICENSEE EVENT REPORT (LER)
TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3)
YEAR I SEQUENTIAL NUMBER l REVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 3 OF 8 TEXT (If more space is required, use additional copies of NRC Form 366A) (17)
Description/Analysis of Occurrence (cont'd):
In June 1994, during preparation of a SW Mode of Operation calculation,.
which used the system hydraulic model to evaluate various co.nf iguration of the system and potential single failures, it was identified that plant procedures did not contain specific instructions to limit system flow for 2 pump accident alignments. The 2 pump conditions can typically result from initiating events (e.g. accident / blackout) in conjunction with single failures (or prior LCO condition). Compensatory actions had already been put in place for other high flow concerns, which significantly mitigated the consequence of these alignments. On August 5, 1994, the subject Problem Reports were initiated and evaluated for operability. The system was determined to be operable based on the compensatory actions noted above.
A procedure revision request was submitted to revise the Salem Emergency Operating Procedures to address these concerns, however, due to the complexities of the Salem design (3 vital bus, 2 safety trains), an immediate revision was not viable. Additional compensatory actions were*
taken shortly after the discovery point to further improve these alignments and a long term priority was assigned to the resolution of the PRs. A reportability review was requested from Licensing following the long term priority determination.
- on October 12, 1995, during subsequent reviews of the subject Problem Reports, it was determined that the conditions described (i.e. prior to compensatory actions) could have potentially challenged the ability of the system to perform its safety function. Accordingly, this condition was reported to the Commission (NRC) pursuant to the requirements of 10 CFR5 0
Analysis and timeline:
The technical issues identified in this LER were self-discovered during preparation for a Service Water Operational Performance Inspection (SWSOPI) conducted in 1994. During this period a computer flow model was developed that enabled an improved understanding of the system design basis and led to the discovery of potential for higher pump flows under certain conditions. The following time line is provided to facilitate the understanding of this occurrence:
In 1992 a project was initiated for the upgrade of the Salem SW pumps with an improved design. This scope included the development of a computer based system flow model in order to provide an updated basis for the design rating of the new SW pumps. Until this time, the only basis that could be located for the pump rating was the flow tables of the original PSE&G system description.
NRC FORM 366A (4-95)
NRC FORM 366A (4-95)
LICENSEE EVENT REPORT (lER)
U.S. NUCLEAR REGULATORY COMMISSION TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER LER NUMBER (6) PAGE (3)
YEAR I SEQUENTIAL NUMBER IREVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 4 OF 8 TEXT (If more space is required, use additional copies of NRC Form 366A) (17)
Description I Analysis of Occurrence Ccon'd):
One of the driving factors for the pump upgrade was a Design.Discrepancy relative to pump NPSH requirements at the design low low water level of 76 feet. Initial screening of this discrepancy assigned a long term priority based on PRA. This assessment was not questioned, based on the fact that the lowest levels of the Delaware River experienced during the years of plant operation, still provided a reasonable margin above the point that would challenge NPSH at the pump design flow rate (10,875 gpm).
In late 1993 during the incorporation of test data on the flow model, preliminary results (using the still unverified model) indicated that higher flows were possible due to the single failure of a CCHX air operated control valve to the full open position with 3 operating pumps .. Engineering and Licensing personnel discussed the Licensing implications of these evolving issues (SW flow and pump NPSH). It was determined, since the prevalent system flow con~itions were low due to cold water, and the predictive calculation had not yet been verified / approved, no immediate Licensing actions would be appropriate.
In May 1994, a Justification for Continued Operation (JCO) was approved by the Station SORC to address SW pump NPSH concerns, including DCPs for the addition of fixed resistances to the CCHX flow paths, a Severe Weather Procedure revision, and CCHX normal Operating Procedure Revisions. DCPs for the CCHX fixed resistances were implemented prior to the end of May.
In June 1994, during the initial reviews of the input assumptions for the Mode Op Calculation, engineering was unable to confirm the existence of procedures that limit flow for 2 SW pump accident alignments. This calculation was intended to review all known system alignments (based on a detailed procedural review) and potential single failures, using the approved model.
A procedure revision request was subsequently initiated to revise the Salem Emergency Operating Procedures (EOPs) in order to address the 2 Service Water pump alignment concerns. At the point.that it was recognized that an immediate revision was not viable, the subject PR's were initiated. The PRs were originally evaluated for operability based on the compensatory actions that had already been implemented in May of 1994. Although intended to specifically address a different failure, these actions also significantly mitigated the concerns with high SW pump flows and NPSH for the subject PRs.
In September of 1994, additional compensatory measures were established by revising the CCHX operating procedures to support flows that were consistent with those previously evaluated by the JCO. These actions specifically addressed the 2 pump alignment concerns of the PRs on an interim basis until more permanent Salem EOP changes could be developed and implemented.
NRC FORM 366A (4-95)
I **
NRC FORM 366A (4-95)
- LICENSEE EVENT REPORT {LER)
TEXT CONTINUATION U.S. NUCLEAR REGULATORY COMMISSION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3)
YEAR I SEQUENTIAL NUMBER IREVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 5 OF 8 TEXT (If more space is required, use additional copies of NRC Form 366~) (17)
Description/Analysis of Occurrence (cont'd):
In August of 1995 during SW system readiness reviews, the disposition of the reportability screens contained in these PRs were raised with the system Manager. At this point it was discovered that the reportability evaluation screens for the PRs had not been dispositioned. on October 12, 1995, the conditions described in the problem reports are determined to have been reportable as a 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> report to the NRC.
Apparent cause of Occurrence:
The apparent cause of this occurrence has been attributed to a limited appreciation of the significance of operating the the SW system in a normally cross-tied mode. The reason for this mode of operation was not clearly stated in original plant design basis documents. This design results in pumps that are affected equally by potential high flow conditions. The importance of the normal alignment was not fully understood until the development of the computer*flow model in 1994 and the subsequent single failure evaluations/procedural reviews, which identified pump flows significantly higher than the original design basis (10,875 gpm). These high flows provided a further concern for the already recognized small NPSH margin for the existing SW pump design.
Additional significant contributing causal factors to this event are; A)
Lack of clear, consistent procedural guidance for correcting conditions adverse to quality (making prompt reportability determinations) as demonstrated by the long term priority assigned by the DEF / PRs and B)
Limited training on Operability / Licensing Basis reportability requirements in the design organization.
Prior similar Occurrences:
There are no prior similar occurrences to this event.
Safety Significance The relative Safety Significance at the point of discovery of these issues was very low. Positive compensatory actions had already been taken (5/94) in response to other high flow scenarios that had been discovered earlier (late 1993 to early 1994) with the development of the SW system flow model.
These compensatory actions significantly mitigated the concerns with high pump flows and NPSH margin.
NRC FORM 366A (4-95)
NRC FORM 366A (4-95)
NRC FORM 366A (4-95)
U.S. NUCLEAR REGULATORY COMMISSION LICENSEE EVENT REPORT (LER)
TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6\ PAGE (3) .
YEAR l SEQUENTIAL NUMBER IREVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 6 OF 8 TEXT (If more apace is required, use additional copies of NRC Form 366A) (17)
Safety Significance (Cont'd)
With regard to the NPSH discrepancy, until the development of the flow model in early 1994, only the original pump design flow rate had been used for NPSH evaluation purposes. At this flow rate even the lowest river levels experienced during the years of Plant operation exceeded the required NPSH for the currerit SW pumps by a reasonable margin. The high SW flow conditions are typically the result of design basis accident alignments with single failures and, as such, are not required to be postulated concurrently with the *extremely low low design water level (76 feet) identified in the Salem FSAR.
Prior to the discovery of the potential for higher pump flows with the development of the flow model, there was little safety significance for these issues for the following reasons:
- 1. If left uncorrected, high SW pump flow would have the potential to affect the ability of the system to meet design basis requirements in the ECCS recirculation mode. While no specific procedural guidance existed (prior to 1994) to avoid placing the system in this configuration, the condition (high SW flow) would have been readily detectable by the low system pressure alarm (overhead alarm) or fluctuating pump amperage indications (control console). Furthermore, since this condition (highest SW flow demand) would have typically occurred in the ECCS recirculation mode, operator action would have been expected, by training, although specific procedural guidance was not available.
- 2. Generic Letter 91-018 states that PRA is a useful tool for determining relative safety significance. The probability of the scenarios in each of the 2 pump system alignments, that were the most significant item of these PRs, is very low. Several of the scenarios involve an assumption that redundant equipment is out of service, which further reduces the probability of occurrence.
Corrective Actions:
with respect to the technical issues of the SW system:
The SW System Configuration Baseline Document (CBD) will be revised to clearly identify the design basis and significance for normal operation in the cross-tied mode. This revision will be completed by May 31, 1996.
NRC FORM 366A (4-95)
U.S. NUCLEAR REGULATORY COMMISSION LICENSEE EVENT REPORT (LER)
TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3)
YEAR 1 SEQUENTIAL NUMBER l REVISION NUMBER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 7 OF. 8 TEXT (If more space is required, use additional copies of NRC Form 366A) (17)
Corrective Actions (Cont'd):
Pump NPSH margin is currently protected by the river level/NPSH monitoring instructions contained in the Abnormal Environmental Procedure (SC.OP-AB. ZZ-0001 (Q), which require the plants to be taken to cold shutdown condition if NPSH available drops to a pre-established threshold value.
These instructions will be removed when the pump upgrades are completed, which is scheduled to be completed in 1996. There are presently 2 new design (Johnston) SW pumps installed (#12 and 26). The new design pumps have substantially lower NPSH requirements (includes the full range of possible flow) than the current Layne and Bowler pumps.
Fixed flow restrictions were applied to the largest flow path in the Nuclear area of the system (CCHX's). This was added by DCP's 1EC3316 and 2EC3274 as documented in JCO S-C-SW-MEE-0893, Revision 1. This restriction significantly improved the maximum pump flows for all of the possible alignment scenarios that have been evaluated.
Restoration of SW flow to the CCHXs during recovery from a safety injection
/ blackout alignment is established by a direct EOP reference to the normal operating procedures. These procedures have different control valve restoration instructions based on the number of operating pumps.
The Loss Of SW Header Pressure Procedure (Sl/2 OP-AB.SW-OOOl(Q)) was revised to specifically call attention to the potential concern with SW pump high flow/NPSH and to identify appropriate operator responses to these conditions.
With respect to the technical issues of the SW system:
Permanent procedure revisions are being developed (both Normal and Emergency Operating) to address the specific concerns of the Problem Reports. These revisions will be implemented by April 1996.
In regard to the lateness of this report:
The Corrective Action Program (NC.NA-AP.ZZ-0006(Q), has been significantly improved by combining the previous processes for reporting conditions adverse to quality, lowering the program threshold, formalizing the Operability Determination Process, increasing management involvement and oversight, and clearly communicating management expectations regarding timeliness of evaluations and corrective actions.
J NRC FORM 366A (4-95)
NRC FORM 366A (4-95)
- LICENSEE EVENT REPORT (LER)
U.S. NUCLEAR REGULATORY COMMISSION TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) II PAGE (3)
YEAR I SEQUENTIAL NUMBER IREVISION MJM8ER SALEM GENERATING STATION UNIT 1 05000272 95 - 025 - 00 8 OF 8 TEXT (If more space is required, use additional copies of NRC Form 366A) (17)
Corrective Actions (Cont'd):
The Program has also been improved to specifically define a hierarchy of event significance levels with corresponding required levels of cause investigation, including prompt operability/reportability determination.
The revision also simplified and centralized the method used to enter, track and process conditions adverse to quality.
A new corrective action department has been established to provide heightened management focus on the corrective action process and established daily (weekday) management review of identified conditions*
adverse to quality.
A copy of this LER will be forwarded to the Nuclear Training Center for evaluation and incorporation into the Operability / Reportability training for Design Engineering personnel.