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| {{#Wiki_filter:NRC FORM 366 . U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB NO. 3150-0104 (5*92) EXPIRES 5/31/95 c ESTIMATED BURDEN PER RESPONSE TO COMPLY WITH THIS LICENSEE EVENT REPORT (LER) INFORMATION COLLECTION REQUEST: 50.0 HRS. FORWARD COMMENTS REGARDING BURDEN ESTIMATE TO THE INFORMATION AND RECORDS MANAGEMENT BRANCH (MNBB 7714), U.S. NUCLEAR REGULATORY COMMISSION, WASHINGTON, DC 20555-0001, AND TO THE PAPERWORK REDUCTION PROJECT (3150-0104), OFFICE OF (See reverse for required number of digits/characters for each block) MANAGEMENT AND BUDGET, WASHINGTON, DC 20503. FACILITY NAME (1) DOCKET NUMBER (2) PAGE (3) Salem Generating Station -Unit 1 05000272 1 OF4 TITLE(41Use ot ten (!U) contairunent air temperature | | {{#Wiki_filter:NRC FORM 366 . U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB NO. 3150-0104 (5*92) EXPIRES 5/31/95 c ESTIMATED BURDEN PER RESPONSE TO COMPLY WITH THIS INFORMATION COLLECTION REQUEST: 50.0 HRS. FORWARD LICENSEE EVENT REPORT (LER) COMMENTS REGARDING BURDEN ESTIMATE TO THE INFORMATION AND RECORDS MANAGEMENT BRANCH (MNBB 7714), U.S. NUCLEAR REGULATORY COMMISSION, WASHINGTON, DC 20555-0001, AND TO THE PAPERWORK REDUCTION PROJECT (3150-0104), OFFICE OF (See reverse for required number of digits/characters for each block) MANAGEMENT AND BUDGET, WASHINGTON, DC 20503. |
| *points to determine primary contairunent average air temperature (both.units) | | FACILITY NAME (1) DOCKET NUMBER (2) PAGE (3) |
| EVENT DATE (5) LER NUMBER (6 REPORT NUMBER (7) OTHER FACILITIES INVOLVED f8l SEQUENTIAL REVISION FACILITY NAME DOCKET NUMBER MONTH DAY YEAR YEAR NUMBER NUMBER MONTH DAY YEAR Salem .,... Uri.it 2 05000311 -d5 15 79 95 004 00 05 18 95 FACILITY NAME DOCKET NUMBER ----05000 OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR §: (Check one or more (111 MODE (9) 1 20.402(b) 20.405(c) 50.73(a) (2) (iv) 73.7.1 (b) POWER 94% 20.405(a)(1)(i) 50.36(c) (1) 50.73(a)(2)(v) 73.71(c) LEVEL (10) 20.405 (a) (1) (ii) 50.36 (c) (2) 50.73(a)(2) (vii) OTHER -20.405(a)(1)(iii) x 50.73(a)(2)(i) 50.73(a)(2) (viii) (A) (Specify in Abstract below and in Text, NRG 20.405(a} | | Salem Generating Station - Unit 1 05000272 1 OF4 TITLE(41Use ot ten (!U) contairunent air temperature *points to determine primary contairunent average air temperature (both.units) |
| (1) (iv) 50. 73 (a) (2) (ii) 50. 73 (a) (2) (viii) (B) Form 366A) 20.405(a)(1)(v) 50.73(a}(2)(iii) 50.73(a)(2)(x} | | EVENT DATE (5) LER NUMBER (6 REPORT NUMBER (7) OTHER FACILITIES INVOLVED f8l FACILITY NAME DOCKET NUMBER SEQUENTIAL REVISION MONTH DAY YEAR YEAR NUMBER NUMBER MONTH DAY YEAR Salem .,. . Uri.it 2 05000311 FACILITY NAME |
| LICENSEE CONTACT FOR THIS LEA 12) NAME LER Coordinator TELEPHONE NUMBER l"clude Area Code) Michael J. Pastva, Jr. 609 339-5 65 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13) REPORTABLE SYSTEM COMPONENT MANUFACTURER REPORTABLE CAUSE SYSTEM COMPONENT MANUFACTURER TO NPRDS CAUSE TO NPRDS SUPPLEMENTAL REPORT EXPECTED 14) EXPECTED MONTH DAY YEAR I YES x SUBMISSION yes, complete EXPECTED SUBMISSION DATE) NO DATE (15) ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16) Since 5/15/79, PSE&G has used 10 primary containment perimeter locations to determine the primary containment average air temperature to comply with Technical Specification (TS) SURVEILLANCE REQUIREMENT 4.6.1.5, on both Units. In 1992, an internal evaluation determined this practice was an acceptable approach to the surveillance requirement, which specifies use of any 5 of the 10 specified locations. | | - |
| On 3/21/95, PSE&G determined this practice was not in verbatim compliance with the surveillance requirement. | | d5 15 79 95 |
| This event resulted from interpretative oversight of the verbatim requirement to use any 5 of the specified locations. | | -- 004 -- 00 05 18 95 DOCKET NUMBER 05000 OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR §: (Check one or more (111 MODE (9) 1 20.402(b) 20.405(c) 50.73(a) (2) (iv) 73.7.1 (b) |
| Procedure revisions have been implemented to satisfy the requirement. | | POWER 94% 20.405(a)(1)(i) 50.36(c) (1) 50.73(a)(2)(v) 73.71(c) |
| The average air temperature value will be obtained from use c:if 5 primary designated locations. | | LEVEL (10) 20.405 (a) (1) (ii) 50.36 (c) (2) 50.73(a)(2) (vii) OTHER 20.405(a)(1)(iii) x 50.73(a)(2)(i) 50.73(a)(2) (viii) (A) (Specify in Abstract |
| These designated location::; | | - |
| have been determined to be representative of containment average air temperature. | | below and in Text, NRG 20.405(a} (1) (iv) 50. 73 (a) (2) (ii) 50. 73 (a) (2) (viii) (B) Form 366A) 20.405(a)(1)(v) 50.73(a}(2)(iii) 50.73(a)(2)(x} |
| The long term solution is to revise the existing TS Surveillance 4.6.1.5 to ref le ct these designated locations. | | LICENSEE CONTACT FOR THIS LEA 12) |
| The importance of procedure adequacy to ensure TS compliance will be stressed with appropriate plant groups. The late submittal of this report has been discussed with NRC Region I Management. | | NAME TELEPHONE NUMBER l"clude Area Code) |
| 9505310243 950518 PDR A DOCK 05000272 --s PDR --... NRC FORM 366 (5-92) | | Michael J. Pastva, Jr. LER Coordinator 609 339-5 65 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13) |
| BLOCK NUMBER 1 2 3 4 5 6 7 8 g 10 11 12 13 14 15 REQUIRED NUMBER OF DIGITS/CHARACTERS FOR EACH BLOCK NUMBER OF DIGITS/CHARACTERS TITLE UP TO 46 FACILITY NAME 8 TOTAL DOCKET NUMBER 3 IN ADDfflON.
| | REPORTABLE REPORTABLE CAUSE SYSTEM COMPONENT MANUFACTURER CAUSE SYSTEM COMPONENT MANUFACTURER TO NPRDS TO NPRDS SUPPLEMENTAL REPORT EXPECTED 14) EXPECTED MONTH DAY YEAR I YES |
| TO OSOOO VARIES PAGE NUMBER UP T0-76 -TITLE 6 TOTAL 2 PER BLOCK EVENT DATE 7 TOTAL 2 FOR YEAR 3 FOR SEQUENTIAL NUMBER LER NUMBER 2 FOR REVISION NUMBER 6 TOTAL 2 PER BLOCK REPORT DATE UP TO 18 FACILITY NAME 8 TOTAL -DOCKET NUMBER OTHER FACILITIES INVOLVED 3 IN ADDITION TO 05000 1 OPERATING MODE 3 POWER LEVEL 1 CHECK BOX THAT APPLIES REQUIREMENTS OF .10 CFR UP TO 50 FOR NAME 14 FOR TELEPHONE LICENSEE CONTACT CAUSE VARIES 2 FOR SYSTEM 4 FOR COMPONENT EACH COMPONENT FAILURE 4 FOR MANUFACTURER NPRDS VARIES ... . ..... ****** 1 CHECK BOX THAT APPLIES SUPPLEMENTAL REPORT EXPECTED 6 TOTAL 2 PER BLOCK EXPECTED SUBMISSION DATE .. | | ~I yes, complete EXPECTED SUBMISSION DATE) x NO SUBMISSION DATE (15) |
| ' ' I* I * .. LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Docket Number LER Number Page 2 of 4 Unit # I 50-272 95-004-00 Plant and System Identification: | | ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16) |
| Westinghouse | | Since 5/15/79, PSE&G has used 10 primary containment perimeter locations to determine the primary containment average air temperature to comply with Technical Specification (TS) SURVEILLANCE REQUIREMENT 4.6.1.5, on both Units. In 1992, an internal evaluation determined this practice was an acceptable approach to the surveillance requirement, which specifies use of any 5 of the 10 specified locations. On 3/21/95, PSE&G determined this practice was not in verbatim compliance with the surveillance requirement. This event resulted from interpretative oversight of the verbatim requirement to use any 5 of the specified locations. Procedure revisions have been implemented to satisfy the requirement. The average air temperature value will be obtained from use c:if 5 primary designated locations. These designated location::; have been determined to be representative of containment average air temperature. The long term solution is to revise the existing TS Surveillance 4.6.1.5 to ref le ct these designated locations. The importance of procedure adequacy to ensure TS compliance will be stressed with appropriate plant groups. The late submittal of this report has been discussed with NRC Region I Management. |
| -Pressurized Water Reactor Energy Industry Identification System (EIIS) codes appear in the text as {xx} Identification of Occurrence: | | 9505310243 950518 - - |
| Use of Ten (10) Containment Air Temperature Points To Determine Primary Containment Average Air Temperature (Both Units) Event Date: May 15, 1979. Event Discovery Date: March 21, 1995 Report Date: May 18, 1995 This report was initiated by Incident Report No. 95-273. Conditions Prior to Occurrence: | | PDR ADOCK 05000272 s -- PDR |
| Unit 1 Mode** 1 Unit 2 Mode 1 Reactor Power 94% Reactor Power 96% Description of Occurrence: | | ... |
| Unit Load 1090 MWe Unit Load 1060 MWe Since May 15, 1979, ten (10) primary containment perimeter locations have been used, on both Units, for the arithmetical average to determine the primary containment average air temperature.
| | NRC FORM 366 (5-92) |
| This practice does not constitute verbatim compliance with Technical Specifications (TS) SURVEILLANCE REQUIREMENT 4.6.1.5, which specifies use of any five (5) of the ten (10) specified locations. | | |
| On March 21, 1995, this occurrence was confirmed by PSE&G as a TS compliance issue. The late submittal of this report has been discussed with NRC Region I Management. | | REQUIRED NUMBER OF DIGITS/CHARACTERS FOR EACH BLOCK BLOCK NUMBER OF NUMBER TITLE DIGITS/CHARACTERS 1 UP TO 46 FACILITY NAME 8 TOTAL ... . ..... ****** .. |
| LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Docket Number LER Number Page 3 of 4 Unit # 1 50-272 95-004-00 Analysis of Occurrence: | | 2 DOCKET NUMBER 3 IN ADDfflON. TO OSOOO 3 VARIES PAGE NUMBER 4 UP T0-76 - TITLE 6 TOTAL 5 EVENT DATE 2 PER BLOCK 7 TOTAL 2 FOR YEAR 6 LER NUMBER 3 FOR SEQUENTIAL NUMBER 2 FOR REVISION NUMBER 6 TOTAL 7 REPORT DATE 2 PER BLOCK UP TO 18 FACILITY NAME 8 OTHER FACILITIES INVOLVED 8 TOTAL - DOCKET NUMBER 3 IN ADDITION TO 05000 g 1 OPERATING MODE 10 3 POWER LEVEL 1 |
| | 11 REQUIREMENTS OF .10 CFR CHECK BOX THAT APPLIES UP TO 50 FOR NAME 12 LICENSEE CONTACT 14 FOR TELEPHONE CAUSE VARIES 2 FOR SYSTEM 13 4 FOR COMPONENT EACH COMPONENT FAILURE 4 FOR MANUFACTURER NPRDS VARIES 1 |
| | 14 SUPPLEMENTAL REPORT EXPECTED CHECK BOX THAT APPLIES 6 TOTAL 15 EXPECTED SUBMISSION DATE 2 PER BLOCK |
| | |
| | ' |
| | ' |
| | I* |
| | I LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Docket Number LER Number Page 2 of 4 Unit # I 50-272 95-004-00 Plant and System Identification: |
| | Westinghouse - Pressurized Water Reactor Energy Industry Identification System (EIIS) codes appear in the text as {xx} |
| | Identification of Occurrence: |
| | Use of Ten (10) Containment Air Temperature Points To Determine Primary Containment Average Air Temperature (Both Units) |
| | Event Date: May 15, 1979. |
| | Event Discovery Date: March 21, 1995 Report Date:~*r May 18, 1995 This report was initiated by Incident Report No. 95-273. |
| | Conditions Prior to Occurrence: |
| | *.. ~ Unit 1 Mode** 1 Reactor Power 94% Unit Load 1090 MWe Unit 2 Mode 1 Reactor Power 96% Unit Load 1060 MWe Description of Occurrence: |
| | Since May 15, 1979, ten (10) primary containment perimeter locations have been used, on both Units, for the arithmetical average to determine the primary containment average air temperature. This practice does not constitute verbatim compliance with Technical Specifications (TS) |
| | SURVEILLANCE REQUIREMENT 4.6.1.5, which specifies use of any five (5) of the ten (10) specified locations. On March 21, 1995, this occurrence was confirmed by PSE&G as a TS compliance issue. |
| | The late submittal of this report has been discussed with NRC Region I Management. |
| | |
| | LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Docket Number LER Number Page 3 of 4 Unit # 1 50-272 95-004-00 Analysis of Occurrence: |
| Limitations on containment average air temperature ensure the overall containment average air temperature does not exceed the initial temperature condition assumed in the accident analysis for a loss of coolant accident or steam line break inside containment. | | Limitations on containment average air temperature ensure the overall containment average air temperature does not exceed the initial temperature condition assumed in the accident analysis for a loss of coolant accident or steam line break inside containment. |
| Since May 1979, ten (10) primary containment perimeter locations have been used in accordance with procedure by the P-250 and Doric process computers to determine primary containment average air temperature. | | Since May 1979, ten (10) primary containment perimeter locations have been used in accordance with procedure by the P-250 and Doric process computers to determine primary containment average air temperature. This practice conflicts with the ~pecified method to meet the TS surveillance requirement. On October 20, 1992, Nuclear Licensing & Regulation had determined this practice complied with the intent of the TS surveillance requirement. |
| This practice conflicts with the method to meet the TS surveillance requirement. | |
| On October 20, 1992, Nuclear Licensing | |
| & Regulation had determined this practice complied with the intent of the TS surveillance requirement. | |
| Following the subsequent identification of this occurrence on March 21, 1995, immediate action was taken to satisfy the TS surveillance requirement. | | Following the subsequent identification of this occurrence on March 21, 1995, immediate action was taken to satisfy the TS surveillance requirement. |
| Apparent Cause of Occurrence: | | Apparent Cause of Occurrence: |
| The use of ten (10) locations to determine primary containment ave.rage air temperature is attributed to Quality Assurance Deficiency", as classified in NUREG-1022, Appendix B. This occurred as a result of interpretative oversight of the verbatim requirement to use five (5) locations (averaging ten locations yields a truer average than averaging five locations). | | The use of ten (10) locations to determine primary containment ave.rage air temperature is attributed to |
| | ~Management/ Quality Assurance Deficiency", as classified in NUREG-1022, Appendix B. This occurred as a result of interpretative oversight of the verbatim requirement to use five (5) locations (averaging ten locations yields a truer average than averaging five locations). |
| Prior Similar Occurrence: | | Prior Similar Occurrence: |
| Review of documentation did not reveal a prior similar occurrence. | | Review of documentation did not reveal a prior similar occurrence. |
| Safety Significance: | | Safety Significance: |
| This occurrence is reportable pursuant to 10CFR50. 73 (a) (2) (i) (B), due to failure to comply with the requirements of TS SURVEILLANCE REQUIREMENT 4.6.1.5. This occurrence had minimal safety significance as use of ten (10) primary containment perimeter locations results in LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Docket Number LER Number Page 4 of 4 Unit # 1 50-272 95-004-00 Safety Significance: (cont'd) a more accurate value of primary containment average air temperature, than use of the TS prescribed number of locations. | | This occurrence is reportable pursuant to 10CFR50. 73 (a) (2) (i) (B), due to failure to comply with the requirements of TS SURVEILLANCE REQUIREMENT 4.6.1.5. |
| Corrective Action: Following discovery, procedure revisions were implemented to satisfy the TS surveillance requirement by requiring use of designated five (5) primary of the ten (10) primary containment perimeter locations to determine primary containment average air temperature. | | This occurrence had minimal safety significance as use of ten (10) primary containment perimeter locations results in |
| These designated locations were determined by Nuclear Engineering to be representative of containment average air temperature. | | |
| | LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Docket Number LER Number Page 4 of 4 Unit # 1 50-272 95-004-00 Safety Significance: (cont'd) a more accurate value of primary containment average air temperature, than use of the TS prescribed number of locations. |
| | Corrective Action: |
| | Following discovery, procedure revisions were implemented to satisfy the TS surveillance requirement by requiring use of designated five (5) primary of the ten (10) primary containment perimeter locations to determine primary containment average air temperature. These designated locations were determined by Nuclear Engineering to be representative of containment average air temperature. |
| The long-term solution, in progress, is to revise the existing TS Surveillance 4.6.1.5 to reflect these designated temperature detector locations. | | The long-term solution, in progress, is to revise the existing TS Surveillance 4.6.1.5 to reflect these designated temperature detector locations. |
| The importance of procedure adequacy to ensure TS compliance will be stressed with appropriate plant groups. MJPJ:vs REF: SORC Mtg. 95-049 J. C. Summers General Manager -Salem Operations}} | | The importance of procedure adequacy to ensure TS compliance will be stressed with appropriate plant groups. |
| | J. C. Summers General Manager - |
| | Salem Operations MJPJ:vs REF: SORC Mtg. 95-049}} |
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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
NRC FORM 366 . U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB NO. 3150-0104 (5*92) EXPIRES 5/31/95 c ESTIMATED BURDEN PER RESPONSE TO COMPLY WITH THIS INFORMATION COLLECTION REQUEST: 50.0 HRS. FORWARD LICENSEE EVENT REPORT (LER) COMMENTS REGARDING BURDEN ESTIMATE TO THE INFORMATION AND RECORDS MANAGEMENT BRANCH (MNBB 7714), U.S. NUCLEAR REGULATORY COMMISSION, WASHINGTON, DC 20555-0001, AND TO THE PAPERWORK REDUCTION PROJECT (3150-0104), OFFICE OF (See reverse for required number of digits/characters for each block) MANAGEMENT AND BUDGET, WASHINGTON, DC 20503.
FACILITY NAME (1) DOCKET NUMBER (2) PAGE (3)
Salem Generating Station - Unit 1 05000272 1 OF4 TITLE(41Use ot ten (!U) contairunent air temperature *points to determine primary contairunent average air temperature (both.units)
EVENT DATE (5) LER NUMBER (6 REPORT NUMBER (7) OTHER FACILITIES INVOLVED f8l FACILITY NAME DOCKET NUMBER SEQUENTIAL REVISION MONTH DAY YEAR YEAR NUMBER NUMBER MONTH DAY YEAR Salem .,. . Uri.it 2 05000311 FACILITY NAME
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d5 15 79 95
-- 004 -- 00 05 18 95 DOCKET NUMBER 05000 OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR §: (Check one or more (111 MODE (9) 1 20.402(b) 20.405(c) 50.73(a) (2) (iv) 73.7.1 (b)
POWER 94% 20.405(a)(1)(i) 50.36(c) (1) 50.73(a)(2)(v) 73.71(c)
LEVEL (10) 20.405 (a) (1) (ii) 50.36 (c) (2) 50.73(a)(2) (vii) OTHER 20.405(a)(1)(iii) x 50.73(a)(2)(i) 50.73(a)(2) (viii) (A) (Specify in Abstract
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below and in Text, NRG 20.405(a} (1) (iv) 50. 73 (a) (2) (ii) 50. 73 (a) (2) (viii) (B) Form 366A) 20.405(a)(1)(v) 50.73(a}(2)(iii) 50.73(a)(2)(x}
LICENSEE CONTACT FOR THIS LEA 12)
NAME TELEPHONE NUMBER l"clude Area Code)
Michael J. Pastva, Jr. LER Coordinator 609 339-5 65 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13)
REPORTABLE REPORTABLE CAUSE SYSTEM COMPONENT MANUFACTURER CAUSE SYSTEM COMPONENT MANUFACTURER TO NPRDS TO NPRDS SUPPLEMENTAL REPORT EXPECTED 14) EXPECTED MONTH DAY YEAR I YES
~I yes, complete EXPECTED SUBMISSION DATE) x NO SUBMISSION DATE (15)
ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16)
Since 5/15/79, PSE&G has used 10 primary containment perimeter locations to determine the primary containment average air temperature to comply with Technical Specification (TS) SURVEILLANCE REQUIREMENT 4.6.1.5, on both Units. In 1992, an internal evaluation determined this practice was an acceptable approach to the surveillance requirement, which specifies use of any 5 of the 10 specified locations. On 3/21/95, PSE&G determined this practice was not in verbatim compliance with the surveillance requirement. This event resulted from interpretative oversight of the verbatim requirement to use any 5 of the specified locations. Procedure revisions have been implemented to satisfy the requirement. The average air temperature value will be obtained from use c:if 5 primary designated locations. These designated location::; have been determined to be representative of containment average air temperature. The long term solution is to revise the existing TS Surveillance 4.6.1.5 to ref le ct these designated locations. The importance of procedure adequacy to ensure TS compliance will be stressed with appropriate plant groups. The late submittal of this report has been discussed with NRC Region I Management.
9505310243 950518 - -
PDR ADOCK 05000272 s -- PDR
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NRC FORM 366 (5-92)
REQUIRED NUMBER OF DIGITS/CHARACTERS FOR EACH BLOCK BLOCK NUMBER OF NUMBER TITLE DIGITS/CHARACTERS 1 UP TO 46 FACILITY NAME 8 TOTAL ... . ..... ****** ..
2 DOCKET NUMBER 3 IN ADDfflON. TO OSOOO 3 VARIES PAGE NUMBER 4 UP T0-76 - TITLE 6 TOTAL 5 EVENT DATE 2 PER BLOCK 7 TOTAL 2 FOR YEAR 6 LER NUMBER 3 FOR SEQUENTIAL NUMBER 2 FOR REVISION NUMBER 6 TOTAL 7 REPORT DATE 2 PER BLOCK UP TO 18 FACILITY NAME 8 OTHER FACILITIES INVOLVED 8 TOTAL - DOCKET NUMBER 3 IN ADDITION TO 05000 g 1 OPERATING MODE 10 3 POWER LEVEL 1
11 REQUIREMENTS OF .10 CFR CHECK BOX THAT APPLIES UP TO 50 FOR NAME 12 LICENSEE CONTACT 14 FOR TELEPHONE CAUSE VARIES 2 FOR SYSTEM 13 4 FOR COMPONENT EACH COMPONENT FAILURE 4 FOR MANUFACTURER NPRDS VARIES 1
14 SUPPLEMENTAL REPORT EXPECTED CHECK BOX THAT APPLIES 6 TOTAL 15 EXPECTED SUBMISSION DATE 2 PER BLOCK
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I LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Docket Number LER Number Page 2 of 4 Unit # I 50-272 95-004-00 Plant and System Identification:
Westinghouse - Pressurized Water Reactor Energy Industry Identification System (EIIS) codes appear in the text as {xx}
Identification of Occurrence:
Use of Ten (10) Containment Air Temperature Points To Determine Primary Containment Average Air Temperature (Both Units)
Event Date: May 15, 1979.
Event Discovery Date: March 21, 1995 Report Date:~*r May 18, 1995 This report was initiated by Incident Report No.95-273.
Conditions Prior to Occurrence:
- .. ~ Unit 1 Mode** 1 Reactor Power 94% Unit Load 1090 MWe Unit 2 Mode 1 Reactor Power 96% Unit Load 1060 MWe Description of Occurrence:
Since May 15, 1979, ten (10) primary containment perimeter locations have been used, on both Units, for the arithmetical average to determine the primary containment average air temperature. This practice does not constitute verbatim compliance with Technical Specifications (TS)
SURVEILLANCE REQUIREMENT 4.6.1.5, which specifies use of any five (5) of the ten (10) specified locations. On March 21, 1995, this occurrence was confirmed by PSE&G as a TS compliance issue.
The late submittal of this report has been discussed with NRC Region I Management.
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Docket Number LER Number Page 3 of 4 Unit # 1 50-272 95-004-00 Analysis of Occurrence:
Limitations on containment average air temperature ensure the overall containment average air temperature does not exceed the initial temperature condition assumed in the accident analysis for a loss of coolant accident or steam line break inside containment.
Since May 1979, ten (10) primary containment perimeter locations have been used in accordance with procedure by the P-250 and Doric process computers to determine primary containment average air temperature. This practice conflicts with the ~pecified method to meet the TS surveillance requirement. On October 20, 1992, Nuclear Licensing & Regulation had determined this practice complied with the intent of the TS surveillance requirement.
Following the subsequent identification of this occurrence on March 21, 1995, immediate action was taken to satisfy the TS surveillance requirement.
Apparent Cause of Occurrence:
The use of ten (10) locations to determine primary containment ave.rage air temperature is attributed to
~Management/ Quality Assurance Deficiency", as classified in NUREG-1022, Appendix B. This occurred as a result of interpretative oversight of the verbatim requirement to use five (5) locations (averaging ten locations yields a truer average than averaging five locations).
Prior Similar Occurrence:
Review of documentation did not reveal a prior similar occurrence.
Safety Significance:
This occurrence is reportable pursuant to 10CFR50. 73 (a) (2) (i) (B), due to failure to comply with the requirements of TS SURVEILLANCE REQUIREMENT 4.6.1.5.
This occurrence had minimal safety significance as use of ten (10) primary containment perimeter locations results in
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Docket Number LER Number Page 4 of 4 Unit # 1 50-272 95-004-00 Safety Significance: (cont'd) a more accurate value of primary containment average air temperature, than use of the TS prescribed number of locations.
Corrective Action:
Following discovery, procedure revisions were implemented to satisfy the TS surveillance requirement by requiring use of designated five (5) primary of the ten (10) primary containment perimeter locations to determine primary containment average air temperature. These designated locations were determined by Nuclear Engineering to be representative of containment average air temperature.
The long-term solution, in progress, is to revise the existing TS Surveillance 4.6.1.5 to reflect these designated temperature detector locations.
The importance of procedure adequacy to ensure TS compliance will be stressed with appropriate plant groups.
J. C. Summers General Manager -
Salem Operations MJPJ:vs REF: SORC Mtg.95-049
