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| | issue date = 02/10/1994 | | | issue date = 02/10/1994 |
| | title = LER 94-001-00:on 940115,TS 3.0.3 Entries Occurred Due to Deenergizing Analog Rod Position Indication Sys for All Control Rods.Module 2SB4 & Span of Module Adjusted,Channel Check Performed & TS 3.0.3 exited.W/940210 Ltr | | | title = LER 94-001-00:on 940115,TS 3.0.3 Entries Occurred Due to Deenergizing Analog Rod Position Indication Sys for All Control Rods.Module 2SB4 & Span of Module Adjusted,Channel Check Performed & TS 3.0.3 exited.W/940210 Ltr |
| | author name = HAGAN J J, PASTVA M J | | | author name = Hagan J, Pastva M |
| | author affiliation = PUBLIC SERVICE ELECTRIC & GAS CO. OF NEW JERSEY | | | author affiliation = PUBLIC SERVICE ELECTRIC & GAS CO. OF NEW JERSEY |
| | addressee name = | | | addressee name = |
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| {{#Wiki_filter:Public Service, Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station u. s. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 | | {{#Wiki_filter:Public Service, Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station February 10, 1994 |
| | : u. s. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 |
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| ==Dear Sir:== | | ==Dear Sir:== |
| SALEM GENERATING STATION LICENSE NO. DPR-75 DOCKET NO. 50-311 UNIT NO. 2 LICENSEE EVENT REPORT 94-001-00 February 10, 1994 This Licensee Event Report is being submitted pursuant to the requirements of Code of Federal Regulation lOCFR50.73(a) | | |
| (2) (i) (B). Issuance of this report is required within thirty (30) days of event discovery. | | SALEM GENERATING STATION LICENSE NO. DPR-75 DOCKET NO. 50-311 UNIT NO. 2 LICENSEE EVENT REPORT 94-001-00 This Licensee Event Report is being submitted pursuant to the requirements of Code of Federal Regulation 10CFR50.73(a) (2) (i) (B). |
| MJPJ:pc Distribution 2200;)0 9403030068 940210 :DR ADOCK PDR Sincerely yours, t \\ 95-2189 REV 7-92 NRC FORM 366 (5*92) . NUCLEAR REGULATORY COMMISSION | | Issuance of this report is required within thirty (30) days of event discovery. |
| !APPROVED BY OMB NO. 3150-0104 EXPIRES 5/31 /95 LICENSEE EVENT REPORT (LER) !See reverse for required number of digits/characters for each block) ESTIMATED BURDEN PER RESPONSE TO COMPLY WITH THIS 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 MANAGEMENT AND BUDGET, WASHINGTON, DC 20503. FACILITY NAME (1) DOCKET NUMBER (2) PAGE (3) Salem Generating Station -Unit 2 05000 311 1 OF 04 TITLE (4) TS 3.0.3 Entry: Inoperability of ARPI System to Support Maintenance Troubleshooting. | | Sincerely yours, MJPJ:pc Distribution 2200;)0 9403030068 940210 |
| EVENT DATE (5) LER NUMBER (6 REPORT NUMBER (7) OTHER FACILITIES INVOLVED (8) FACILITY NAME DOCKET NUMBER MONTH DAY YEAR YEAR SEQUENTIAL NUMBER 05000 REVISION YEAR MONTH DAY NUMBER FACILITY NAME DOCKET NUMBER 01 15 94 001 00 02 10 94 05000 OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR t: (Check one or more (11) MODE (9) 1 20.402(b) 20.405(c) 50.73(a)(2)(iv) 73.71 (b) POWER 20.405(a)(1 | | :DR ADOCK 0~000311 |
| )(i) 50.36(c)(1) 50.73(a)(2)(v) 73.71 (c) LEVEL (10) 100 20.405(a)(1 | | ~ |
| )(ii) 50.36(c)(2) 50.73(a)(2)(vii) | | ~* t \\ |
| OTHER ***************:*!**** | | PDR 95-2189 REV 7-92 |
| .. -;:: :**. :.: . :*** 20.405(a)
| | |
| (1) (iii) x 50.73(a)(2)(i) 50.73(a)(2)(viii)(A) (Specify in Abstract below and in Text, NRC 20.405(a)(1 | | NRC FORM 366 . NUCLEAR REGULATORY COMMISSION !APPROVED BY OMB NO. 3150-0104 (5*92) EXPIRES 5/31 /95 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 |
| )(iv) 50.73(a)(2)(ii) 50.73(a)(2)(viii)(B) | | !See reverse for required number of digits/characters for each block) MANAGEMENT AND BUDGET, WASHINGTON, DC 20503. |
| Form 366A) 20.405(a)(1
| | FACILITY NAME (1) DOCKET NUMBER (2) PAGE (3) |
| )(v) 50. 73(a)(2)(iii) | | Salem Generating Station - Unit 2 05000 311 1 OF 04 TITLE (4) |
| : 50. 73(a)(2)(x) . LICENSEE CONTACT FOR THIS LER (12) NAME TELEPHONE NUMBER (Include Area Code) M. J. Pastva, Jr. -LER Coordinator (609) 339-5165 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13) CAUSE SYSTEM COMPONENT MANUFACTURER REPORTABLE TO NPRDS SUPPLEMENTAL REPORT EXPECTED (14) I YES NO (If yes, complete EXPECTED SUBMISSION DATE) X CAUSE ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16) SYSTEM COMPONENT MANUFACTURER 11EPORTABLE TO NPRDS EXPECTED MONTH DAY YEAR SUBMISSION DATE (15) Two intentional Technical Specification (TS) 3.0.3 entries occurred on 1/15/94 (from 0045 to 0047 hours, and from 0056 to 0059 hours) due to deenergizing the Analog Rod Position Indication (ARPI) System for all control rods. These events occurred due to removil'ig the 115-volt alternating current (AC) power supply fuses to the ARPI System primary and auxiliary 13-volt direct current negative and positive power supplies. | | TS 3.0.3 Entry: Inoperability of ARPI System to Support Maintenance Troubleshooting. |
| This was done to support correction 9f ARPI indicator drift for rod 2SB4. Rod positions, as compared to the rod group demand indicator, were correct prior to fuse removal and following fuse The root cause of these events is ARPI System design that resulted in the conservative approach requiring the TS 3.0.3 entries to avoid possible equipment damage during repair of the 2SB4 indication drift. Adjustments were made to the 2SB4 signal conditioning module and the module span, based on redeveloped secondary voltage value to the module. 'A channel check demonstrated ARPI operability, and TS 3.0.3 was exited. PSE&G will continue participation in the industry Rod control User's Group and will utilize User's Group and vendor recommendations regarding ARPI System drift. NRC FORM 366 15-92) | | EVENT DATE (5) LER NUMBER (6 REPORT NUMBER (7) OTHER FACILITIES INVOLVED (8) |
| * LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating station Unit 2 DOCKET NUMBER 5000311 PLANT AND SYSTEM IDENTIFICATION:
| | SEQUENTIAL REVISION FACILITY NAME DOCKET NUMBER MONTH DAY YEAR YEAR MONTH DAY YEAR NUMBER NUMBER 05000 FACILITY NAME DOCKET NUMBER 01 15 94 001 00 02 10 94 05000 OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR t: (Check one or more (11) |
| Westinghouse | | MODE (9) 1 20.402(b) 20.405(c) 50.73(a)(2)(iv) 73.71 (b) |
| -Pressurized Water Reactor LER NUMBER 94-001-00 PAGE 2 of 4 Energy Industry Identification System (EIIS) codes are identified in the text as {xx} IDENTIFICATION OF OCCURRENCE: | | POWER 20.405(a)(1 )(i) 50.36(c)(1) 50.73(a)(2)(v) 73.71 (c) |
| Technical Specification | | LEVEL (10) 100 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 l-+=.:~.:..::~..:,....:.------+-.;.:.+~=-=--7'7::7-::::------+--+:~::::7.:~'77.';';'7;:;~---1 below and in Text, NRC 20.405(a)(1 )(iv) 20.405(a)(1 )(v) 50.73(a)(2)(ii) |
| {TS) 3.0.3 entries; Inoperability of Analog Rod Position Indication (ARPI) System to Support Maintenance Troubleshooting Event Date: 1/15/94 Report Date: 2/10/94 This report was initiated by Incident Report No. 94-017. CONDITIONS PRIOR TO OCCURRENCE: | | : 50. 73(a)(2)(iii) 50.73(a)(2)(viii)(B) |
| Mode 1 Reactor Power 100% -Unit Load 1180 MWe DESCRIPTION OF OCCURRENCE: | | : 50. 73(a)(2)(x) |
| | Form 366A) |
| | ***************:*!**** . LICENSEE CONTACT FOR THIS LER (12) |
| | NAME TELEPHONE NUMBER (Include Area Code) |
| | M. J. Pastva, Jr. - LER Coordinator (609) 339-5165 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13) |
| | REPORTABLE 11EPORTABLE CAUSE SYSTEM COMPONENT MANUFACTURER CAUSE SYSTEM COMPONENT MANUFACTURER TO NPRDS TO NPRDS SUPPLEMENTAL REPORT EXPECTED (14) EXPECTED MONTH DAY YEAR SUBMISSION I YES (If yes, complete EXPECTED SUBMISSION DATE) X NO ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16) |
| | DATE (15) |
| | Two intentional Technical Specification (TS) 3.0.3 entries occurred on 1/15/94 (from 0045 to 0047 hours, and from 0056 to 0059 hours) due to deenergizing the Analog Rod Position Indication (ARPI) System for all control rods. These events occurred due to removil'ig the 115-volt alternating current (AC) power supply fuses to the ARPI System primary and auxiliary 13-volt direct current negative and positive power supplies. This was done to support correction 9f ARPI indicator drift for rod 2SB4. Rod positions, as compared to the rod group demand indicator, were correct prior to fuse removal and following fuse r~installation. The root cause of these events is ARPI System design that resulted in the conservative approach requiring the TS 3.0.3 entries to avoid possible equipment damage during repair of the 2SB4 indication drift. Adjustments were made to the 2SB4 signal conditioning module and the module span, based on redeveloped secondary ~c voltage value to the module. 'A channel check demonstrated ARPI operability, and TS 3.0.3 was exited. PSE&G will continue participation in the industry Rod control User's Group and will utilize User's Group and vendor recommendations regarding ARPI System drift. |
| | NRC FORM 366 15-92) |
| | |
| | LICENSEE EVENT REPORT (LER) TEXT CONTINUATION PAGE Salem Generating station DOCKET NUMBER LER NUMBER Unit 2 5000311 94-001-00 2 of 4 PLANT AND SYSTEM IDENTIFICATION: |
| | Westinghouse - Pressurized Water Reactor Energy Industry Identification System (EIIS) codes are identified in the text as {xx} |
| | IDENTIFICATION OF OCCURRENCE: |
| | Technical Specification {TS) 3.0.3 entries; Inoperability of Analog Rod Position Indication (ARPI) System to Support Maintenance Troubleshooting Event Date: 1/15/94 Report Date: 2/10/94 This report was initiated by Incident Report No. 94-017. |
| | CONDITIONS PRIOR TO OCCURRENCE: |
| | Mode 1 Reactor Power 100% - Unit Load 1180 MWe DESCRIPTION OF OCCURRENCE: |
| Two intentional TS 3.0.3 entries occurred on January 15, 1994 (from 0045 to 0047 hours, and from 005'6 to 0059 hours) due to deenergizing the ARPI system {AA} for all control rods. These events occurred due to removing the 115-volt alternating current {AC) power supply fuses to the primary and auxiliary 13-volt direct current negative and positive power supplies for the ARP! System. This was done, as a conservative measure, to support correction of ARP! indication drift affecting rod 2SB4. Rod positions, as compared to the rod group demand indicator, were correct prior to fuse removal and following fuse reinstallation. | | Two intentional TS 3.0.3 entries occurred on January 15, 1994 (from 0045 to 0047 hours, and from 005'6 to 0059 hours) due to deenergizing the ARPI system {AA} for all control rods. These events occurred due to removing the 115-volt alternating current {AC) power supply fuses to the primary and auxiliary 13-volt direct current negative and positive power supplies for the ARP! System. This was done, as a conservative measure, to support correction of ARP! indication drift affecting rod 2SB4. Rod positions, as compared to the rod group demand indicator, were correct prior to fuse removal and following fuse reinstallation. |
| ANALYSIS OF OCCURRENCE: | | ANALYSIS OF OCCURRENCE: |
| ARP! operability is required to determine individual control rod position and ensure compliance with control rod alignment and insertion limits assumed in the accident analyses. | | ARP! operability is required to determine individual control rod position and ensure compliance with control rod alignment and insertion limits assumed in the accident analyses. ARP! provides actual rod position to the following locations: the Control Board dual channel position indicator modules (supplied by Dixon), the Safety Parameter Display System {SPDS), the main process.P250 compu~er, and |
| ARP! provides actual rod position to the following locations: | | .locally via the digital multimeter (DMM). |
| the Control Board dual channel position indicator modules (supplied by Dixon), the Safety Parameter Display System {SPDS), the main process.P250 and .locally via the digital multimeter (DMM). TS 3.1.3.2.1 addresses the operability requirement of the "Reactivity Control System's" position indicating systems. The indicators are determined operable by verifying that the rod position indication | | TS 3.1.3.2.1 addresses the operability requirement of the "Reactivity Control System's" position indicating systems. The indicators are determined operable by verifying that the rod position indication |
| * LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 2 DOCKET NUMBER 5000311 ANALYSIS OF OCCURRENCE: (cont'd) LER NUMBER 94-001-00 PAGE 3 of 4 system agrees within twelve (12) steps of the group demand counters.
| | |
| If more than one ARPI per bank is inoperable, the Limiting Condition For Operation and associated ACTION requirements of TS 3.1.3.2.1 are not met and TS 3.0.3 therefore applies. *Two intentional TS 3. o_. 3 entries occurred to support correction of instrument drift affecting the ARP! of control rod 2SB4. The 115-volt alternating current power supply fuses (total of four) to the primary and auxiliary 13-volt direct current negative and positive power supply for the ARP! system were removed. This was done, as a conservative measure, to eliminate potential electrical shorting of the 2SB4 ARP! signal conditioning module and damage to the 13-volt de power supplies. | | LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 2 5000311 94-001-00 3 of 4 ANALYSIS OF OCCURRENCE: (cont'd) system agrees within twelve (12) steps of the group demand counters. |
| Rod positions, as compared to the rod group demand indicator, were correct prior to fuse removal and following fuse reinstallation. | | If more than one ARPI per bank is inoperable, the Limiting Condition For Operation and associated ACTION requirements of TS 3.1.3.2.1 are not met and TS 3.0.3 therefore applies. |
| Adjustments were made to the 2SB4 signal conditioning module and the module span, based on redeveloped secondary AC voltage value to the module. A channel check demonstrated ARP! operability, and TS 3.0.3 was exited. APPARENT CAUSE OF OCCURRENCE: | | *Two intentional TS 3. o_. 3 entries occurred to support correction of instrument drift affecting the ARP! of control rod 2SB4. The 115-volt alternating current power supply fuses (total of four) to the primary and auxiliary 13-volt direct current negative and positive power supply for the ARP! system were removed. This was done, as a conservative measure, to eliminate potential electrical shorting of the 2SB4 ARP! signal conditioning module and damage to the 13-volt de power supplies. Rod positions, as compared to the rod group demand indicator, were correct prior to fuse removal and following fuse reinstallation. Adjustments were made to the 2SB4 signal conditioning module and the module span, based on redeveloped secondary AC voltage value to the module. A channel check demonstrated ARP! operability, and TS 3.0.3 was exited. |
| The cause of these events is "Design, Manufacturing, Construction/Installation", as classified in Appendix B of NUREG-1022. | | APPARENT CAUSE OF OCCURRENCE: |
| Design of the ARPI System necessitated the TS 3.0.3 entries to avoid possible equipment damage during repair of the 2SB4 indication drift. PREVIOUS OCCURRENCES: | | The cause of these events is "Design, Manufacturing, Construction/Installation", as classified in Appendix B of NUREG-1022. Design of the ARPI System necessitated the TS 3.0.3 entries to avoid possible equipment damage during repair of the 2SB4 indication drift. |
| Prior events, requiring TS entry due to ARPI design concerns, have occurred on both Salem Units, as reported in LERs 272/93-007-00, 272/94-001-00, 311/92-016-00, and 311/93-010-00. | | PREVIOUS OCCURRENCES: |
| As a result of these events (those occurring prior to 1994), System Engineering has developed an ARP! trending data base to identify problem electronic modules. In addition, the industry Rod Control User's Group has recognized an industry-wide problem with ARP! System drift. Recommendations from this group and from the vendors will be used to develop appropriate action. SAFETY SIGNIFICANCE: | | Prior events, requiring TS 3~0.3 entry due to ARPI design concerns, have occurred on both Salem Units, as reported in LERs 272/93-007-00, 272/94-001-00, 311/92-016-00, and 311/93-010-00. As a result of these events (those occurring prior to 1994), System Engineering has developed an ARP! trending data base to identify problem electronic modules. In addition, the industry Rod Control User's Group has recognized an industry-wide problem with ARP! System drift. |
| These events did not affect the health and safety of the public and are reportable to the NRC pursuant to Code.of Federal Regulations lOCFR 50. 73 (a) (2) (i) (B). Removing the subject fuses deenergized ARPI and resulted in no control rod position indication at the Control Room control rod console. | | Recommendations from this group and from the vendors will be used to develop appropriate action. |
| * ,.
| | SAFETY SIGNIFICANCE: |
| * LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 2 SAFETY SIGNIFICANCE: (cont'd) DOCKET NUMBER 5000311 LER 94-001-00 PAGE 4 of 4 However, fuse removal did not affect operability of control rod overhead annunciators and RP3 "Rod Bottom" indication.
| | These events did not affect the health and safety of the public and are reportable to the NRC pursuant to Code.of Federal Regulations 10CFR 50. 73 (a) (2) (i) (B). |
| Had a Reactor trip occurred while the fuses were removed, performing the 2SB4 troubleshooting and repair, could have reinstalled the fuses to restore the ARPI System. As such, the removal of the fuses would not have significantly affected the Control Operators' response to a trip. | | Removing the subject fuses deenergized ARPI and resulted in no control rod position indication at the Control Room control rod console. |
| * In response to any known or suspected complete/partial loss of ARPI, the Control Operator will notify Reactor Engineering and the Maintenance Controls Department, in accordance with procedure Sl.OP-AB.ROD-OU04(Q), "ROD POSITION INDICATION FAILURE", to ensure that shutdown margin is maintained and to investigate and correct the cause of the problem. In addition, Reactor Operators utilize alternate monitoring systems; i.e. Nuclear Instrumentation, Reactor Power Range channels, and Intermediate and Source Range channels to confirm a Reactor trip coincident with unavailability of the ARPI. CORRECTIVE ACTION: The 2SB4 module and the span of the modul.e were adjusted, a channel check was performed which demonstrated the ARPI operability, and TS 3.0.3 was exited. PSE&G will continue participation in the industry Rod Control User's Group and will utilize User's Group and vendor recommendations regarding ARPI system drift. MJPJ:pc SORC Mtg. 94-014}} | | |
| | LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBE~ PAGE Unit 2 5000311 94-001-00 4 of 4 SAFETY SIGNIFICANCE: (cont'd) |
| | However, fuse removal did not affect operability of control rod overhead annunciators and RP3 "Rod Bottom" indication. |
| | Had a Reactor trip occurred while the fuses were removed, technici~ns performing the 2SB4 troubleshooting and repair, could have reinstalled the fuses to restore the ARPI System. As such, the removal of the fuses would not have significantly affected the Control Operators' response to a trip. |
| | * In response to any known or suspected complete/partial loss of ARPI, the Control Operator will notify Reactor Engineering and the Maintenance Controls Department, in accordance with procedure Sl.OP-AB.ROD-OU04(Q), "ROD POSITION INDICATION FAILURE", to ensure that shutdown margin is maintained and to investigate and correct the cause of the problem. In addition, Reactor Operators utilize alternate monitoring systems; i.e. Nuclear Instrumentation, Reactor Power Range channels, and Intermediate and Source Range channels to confirm a Reactor trip coincident with unavailability of the ARPI. |
| | CORRECTIVE ACTION: |
| | The 2SB4 module and the span of the modul.e were adjusted, a channel check was performed which demonstrated the ARPI operability, and TS 3.0.3 was exited. |
| | PSE&G will continue participation in the industry Rod Control User's Group and will utilize User's Group and vendor recommendations regarding ARPI system drift. |
| | MJPJ:pc SORC Mtg. 94-014}} |
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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
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Text
Public Service, Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station February 10, 1994
- u. s. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555
Dear Sir:
SALEM GENERATING STATION LICENSE NO. DPR-75 DOCKET NO. 50-311 UNIT NO. 2 LICENSEE EVENT REPORT 94-001-00 This Licensee Event Report is being submitted pursuant to the requirements of Code of Federal Regulation 10CFR50.73(a) (2) (i) (B).
Issuance of this report is required within thirty (30) days of event discovery.
Sincerely yours, MJPJ:pc Distribution 2200;)0 9403030068 940210
- DR ADOCK 0~000311
~
~* t \\
PDR 95-2189 REV 7-92
NRC FORM 366 . NUCLEAR REGULATORY COMMISSION !APPROVED BY OMB NO. 3150-0104 (5*92) EXPIRES 5/31 /95 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 2 05000 311 1 OF 04 TITLE (4)
TS 3.0.3 Entry: Inoperability of ARPI System to Support Maintenance Troubleshooting.
EVENT DATE (5) LER NUMBER (6 REPORT NUMBER (7) OTHER FACILITIES INVOLVED (8)
SEQUENTIAL REVISION FACILITY NAME DOCKET NUMBER MONTH DAY YEAR YEAR MONTH DAY YEAR NUMBER NUMBER 05000 FACILITY NAME DOCKET NUMBER 01 15 94 001 00 02 10 94 05000 OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR t: (Check one or more (11)
MODE (9) 1 20.402(b) 20.405(c) 50.73(a)(2)(iv) 73.71 (b)
POWER 20.405(a)(1 )(i) 50.36(c)(1) 50.73(a)(2)(v) 73.71 (c)
LEVEL (10) 100 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 l-+=.:~.:..::~..:,....:.------+-.;.:.+~=-=--7'7::7-::::------+--+:~::::7.:~'77.';';'7;:;~---1 below and in Text, NRC 20.405(a)(1 )(iv) 20.405(a)(1 )(v) 50.73(a)(2)(ii)
- 50. 73(a)(2)(iii) 50.73(a)(2)(viii)(B)
- 50. 73(a)(2)(x)
Form 366A)
- !**** . LICENSEE CONTACT FOR THIS LER (12)
NAME TELEPHONE NUMBER (Include Area Code)
M. J. Pastva, Jr. - LER Coordinator (609) 339-5165 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13)
REPORTABLE 11EPORTABLE CAUSE SYSTEM COMPONENT MANUFACTURER CAUSE SYSTEM COMPONENT MANUFACTURER TO NPRDS TO NPRDS SUPPLEMENTAL REPORT EXPECTED (14) EXPECTED MONTH DAY YEAR SUBMISSION I YES (If yes, complete EXPECTED SUBMISSION DATE) X NO ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16)
DATE (15)
Two intentional Technical Specification (TS) 3.0.3 entries occurred on 1/15/94 (from 0045 to 0047 hours5.439815e-4 days <br />0.0131 hours <br />7.771164e-5 weeks <br />1.78835e-5 months <br />, and from 0056 to 0059 hours6.828704e-4 days <br />0.0164 hours <br />9.755291e-5 weeks <br />2.24495e-5 months <br />) due to deenergizing the Analog Rod Position Indication (ARPI) System for all control rods. These events occurred due to removil'ig the 115-volt alternating current (AC) power supply fuses to the ARPI System primary and auxiliary 13-volt direct current negative and positive power supplies. This was done to support correction 9f ARPI indicator drift for rod 2SB4. Rod positions, as compared to the rod group demand indicator, were correct prior to fuse removal and following fuse r~installation. The root cause of these events is ARPI System design that resulted in the conservative approach requiring the TS 3.0.3 entries to avoid possible equipment damage during repair of the 2SB4 indication drift. Adjustments were made to the 2SB4 signal conditioning module and the module span, based on redeveloped secondary ~c voltage value to the module. 'A channel check demonstrated ARPI operability, and TS 3.0.3 was exited. PSE&G will continue participation in the industry Rod control User's Group and will utilize User's Group and vendor recommendations regarding ARPI System drift.
NRC FORM 366 15-92)
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION PAGE Salem Generating station DOCKET NUMBER LER NUMBER Unit 2 5000311 94-001-00 2 of 4 PLANT AND SYSTEM IDENTIFICATION:
Westinghouse - Pressurized Water Reactor Energy Industry Identification System (EIIS) codes are identified in the text as {xx}
IDENTIFICATION OF OCCURRENCE:
Technical Specification {TS) 3.0.3 entries; Inoperability of Analog Rod Position Indication (ARPI) System to Support Maintenance Troubleshooting Event Date: 1/15/94 Report Date: 2/10/94 This report was initiated by Incident Report No.94-017.
CONDITIONS PRIOR TO OCCURRENCE:
Mode 1 Reactor Power 100% - Unit Load 1180 MWe DESCRIPTION OF OCCURRENCE:
Two intentional TS 3.0.3 entries occurred on January 15, 1994 (from 0045 to 0047 hours5.439815e-4 days <br />0.0131 hours <br />7.771164e-5 weeks <br />1.78835e-5 months <br />, and from 005'6 to 0059 hours6.828704e-4 days <br />0.0164 hours <br />9.755291e-5 weeks <br />2.24495e-5 months <br />) due to deenergizing the ARPI system {AA} for all control rods. These events occurred due to removing the 115-volt alternating current {AC) power supply fuses to the primary and auxiliary 13-volt direct current negative and positive power supplies for the ARP! System. This was done, as a conservative measure, to support correction of ARP! indication drift affecting rod 2SB4. Rod positions, as compared to the rod group demand indicator, were correct prior to fuse removal and following fuse reinstallation.
ANALYSIS OF OCCURRENCE:
ARP! operability is required to determine individual control rod position and ensure compliance with control rod alignment and insertion limits assumed in the accident analyses. ARP! provides actual rod position to the following locations: the Control Board dual channel position indicator modules (supplied by Dixon), the Safety Parameter Display System {SPDS), the main process.P250 compu~er, and
.locally via the digital multimeter (DMM).
TS 3.1.3.2.1 addresses the operability requirement of the "Reactivity Control System's" position indicating systems. The indicators are determined operable by verifying that the rod position indication
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 2 5000311 94-001-00 3 of 4 ANALYSIS OF OCCURRENCE: (cont'd) system agrees within twelve (12) steps of the group demand counters.
If more than one ARPI per bank is inoperable, the Limiting Condition For Operation and associated ACTION requirements of TS 3.1.3.2.1 are not met and TS 3.0.3 therefore applies.
- Two intentional TS 3. o_. 3 entries occurred to support correction of instrument drift affecting the ARP! of control rod 2SB4. The 115-volt alternating current power supply fuses (total of four) to the primary and auxiliary 13-volt direct current negative and positive power supply for the ARP! system were removed. This was done, as a conservative measure, to eliminate potential electrical shorting of the 2SB4 ARP! signal conditioning module and damage to the 13-volt de power supplies. Rod positions, as compared to the rod group demand indicator, were correct prior to fuse removal and following fuse reinstallation. Adjustments were made to the 2SB4 signal conditioning module and the module span, based on redeveloped secondary AC voltage value to the module. A channel check demonstrated ARP! operability, and TS 3.0.3 was exited.
APPARENT CAUSE OF OCCURRENCE:
The cause of these events is "Design, Manufacturing, Construction/Installation", as classified in Appendix B of NUREG-1022. Design of the ARPI System necessitated the TS 3.0.3 entries to avoid possible equipment damage during repair of the 2SB4 indication drift.
PREVIOUS OCCURRENCES:
Prior events, requiring TS 3~0.3 entry due to ARPI design concerns, have occurred on both Salem Units, as reported in LERs 272/93-007-00, 272/94-001-00, 311/92-016-00, and 311/93-010-00. As a result of these events (those occurring prior to 1994), System Engineering has developed an ARP! trending data base to identify problem electronic modules. In addition, the industry Rod Control User's Group has recognized an industry-wide problem with ARP! System drift.
Recommendations from this group and from the vendors will be used to develop appropriate action.
SAFETY SIGNIFICANCE:
These events did not affect the health and safety of the public and are reportable to the NRC pursuant to Code.of Federal Regulations 10CFR 50. 73 (a) (2) (i) (B).
Removing the subject fuses deenergized ARPI and resulted in no control rod position indication at the Control Room control rod console.
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBE~ PAGE Unit 2 5000311 94-001-00 4 of 4 SAFETY SIGNIFICANCE: (cont'd)
However, fuse removal did not affect operability of control rod overhead annunciators and RP3 "Rod Bottom" indication.
Had a Reactor trip occurred while the fuses were removed, technici~ns performing the 2SB4 troubleshooting and repair, could have reinstalled the fuses to restore the ARPI System. As such, the removal of the fuses would not have significantly affected the Control Operators' response to a trip.
- In response to any known or suspected complete/partial loss of ARPI, the Control Operator will notify Reactor Engineering and the Maintenance Controls Department, in accordance with procedure Sl.OP-AB.ROD-OU04(Q), "ROD POSITION INDICATION FAILURE", to ensure that shutdown margin is maintained and to investigate and correct the cause of the problem. In addition, Reactor Operators utilize alternate monitoring systems; i.e. Nuclear Instrumentation, Reactor Power Range channels, and Intermediate and Source Range channels to confirm a Reactor trip coincident with unavailability of the ARPI.
CORRECTIVE ACTION:
The 2SB4 module and the span of the modul.e were adjusted, a channel check was performed which demonstrated the ARPI operability, and TS 3.0.3 was exited.
PSE&G will continue participation in the industry Rod Control User's Group and will utilize User's Group and vendor recommendations regarding ARPI system drift.
MJPJ:pc SORC Mtg.94-014