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| * 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 | | * Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station February 3, 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.,..70 DOCKET NO. 50-272 UNIT NO. 1 LICENSEE EVENT REPORT 94-001-00 February 3, 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.,..70 DOCKET NO. 50-272 UNIT NO. 1 LICENSEE EVENT REPORT 94-001-00 This Licensee Event Report is being submitted pursuant to the requirements of Code of Federal Regulation lOCFR50.73(a) (2) (i) (B). |
| MJPJ:pc Distribution 940203 S ADOCK 05000272 PDR Sincerely yours, //;* £//
| | Issuance of this report is required within thirty (30) days of event discovery. |
| : c. A. Vondra General Manager -' Salem Operations rc"LL I I I 95-2189 REV 7-92 | | Sincerely yours, |
| ------------------ | | //;* £// |
| NRC FOJ3M 366 U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY-OMB NO. 3150-0104 (5-92) . EXPIRES 5/31 /95 -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 05000 272 1 OF04 TITLE (4) TS 3.0.3 Entries; More Than One Inoperable ARPI Per Bank. EVENT DATE (5) LER NUMBER (6 REPORT NUMBER (7l OTHER FACILITIES INVOLVED (8) SEQUENTIAL REVISION FACILITY NAME DOCKET NUMBER MONTH DAY YEAR YEAR NUMBER MONTH DAY YEAR 05000 311 NUMBER Salem Unit 2 FACILITY NAME DOCKET NUMBER 01 05 94 94 --001 --00 02 94 05000 03 OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR §: (Check one or more (11 l MODE (9) 2 20.402(b) 20,405(c) | | tWJf/~"- |
| : 50. 73(a)(2)(iv) 73.71(b) POWEI=l 20.405(a)(1
| | : c. A. Vondra General Manager - |
| )(i) 50.36(c) (1) 50. 73(a)(2)(v) 73.71 (c) LEVEL (10) 000 20.405(a) | | ' Salem Operations MJPJ:pc Distribution |
| (1) (ii) 50.36(c) (2) 50.73(a)(2)(vii) | | ~D4R021B0173 940203 S ADOCK 05000272 PDR rc"LL I II 95-2189 REV 7-92 |
| OTHER .
| | |
| 20.405(a) | | --~- ------------------ |
| (1) (iii) x 50.73(a)(2)(i) | | NRC (5-92) |
| : 50. 73(a)(2)(viii)(A) (Specify in Abstract 20.405(a)
| | FOJ3M 366 . U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY-OMB NO. 3150-0104 EXPIRES 5/31 /95 |
| (1) (iv) 50.73(a)(2)(ii) 50.73(a) (2)(viii)(B) below and in Tex1, NRG Form 366A) 20.405(a)(1 | | -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. |
| )(v) 50.73(a) (2) (iii) 50.73(a)(2)(x) | | FACILITY NAME (1) DOCKET NUMBER (2) PAGE (3) |
| 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 REPORTl13l CAUSE SYSTEM COMPONENT MANUFACTURER REPORTABLE CAUSE SYSTEM COMPONENT MANUFACTURER REPORTABLE TO NPRDS TO NPRDS SUPPLEMENTAL REPORT EXPECTED (14) EXPECTED MONTH DAY YEAR YES SUBMISSION (If yes, complete EXPECTED SUBMISSION DATE) NO DATE (15) x ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16) -Intentional Technical Specification (TS) 3.0.3 entries were made: for Unit 2 on 1/5/94, from 1637 to 1642 hours, and on 1/16/94, fr_om 0037 to 0045 hours, and for Unit 1 on 1/24/94, from 2215 to 2245 hours. This was done to permit calibrating the respective Analog Rod Position Indicator (ARP!) control Board dual indicator modules for Unit 2 control rods 2B4 and 1D2 and for Unit 1 control rods 2Al and 2B2. Calibrating the indicators required removing the dual indicator modules, which rendered ARP! for subject rods and for the rods sharing the same module inoperable: | | Salem Generating Station - Unit 1 05000 272 1 OF04 TITLE (4) |
| 2B3 and lDl (Unit 2)* and 2A2 and 2Bl (Unit 1). In each case, actual rod positions (per group demand) were correct. The root cause of these events is design of ARP! position.indicators requiring entering TS 3.0.3 whenever ARP! calibrations are performed. | | TS 3.0.3 Entries; More Than One Inoperable ARPI Per Bank. |
| The subject position indicators were calibrated and TS 3.0.3 was exited. A Night Order Book (NOB) entry was made, on 1/27/94, to provide guidance/restrictions for ARP! Dixon indicator calibrations and TS 3.0.3 entries. An Information Directive will be issued to formalize the 1/27/94 NOB entry. NRG FORM 366 (5-92) | | EVENT DATE (5) LER NUMBER (6 REPORT NUMBER (7l OTHER FACILITIES INVOLVED (8) |
| -* LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating station Unit 1 DOCKET NUMBER 5000272 PLANT AND SYSTEM IDENTIFICATION: | | SEQUENTIAL FACILITY NAME DOCKET NUMBER REVISION MONTH DAY YEAR YEAR MONTH DAY YEAR NUMBER NUMBER Salem Unit 2 05000 311 FACILITY NAME DOCKET NUMBER 01 05 94 -- -- 05000 94 001 00 02 03 94 OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR §: (Check one or more (11 l MODE (9) 2 20.402(b) 20,405(c) 50. 73(a)(2)(iv) 73.71(b) |
| Westinghouse | | POWEI=l 20.405(a)(1 )(i) 50.36(c) (1) 50. 73(a)(2)(v) 73.71 (c) |
| * -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: | | LEVEL (10) 000 20.405(a) (1) (ii) 50.36(c) (2) 50.73(a)(2)(vii) OTHER |
| Technical Specification (TS) 3.0.3 Entries On Both Salem Units; More Than One Inoperable Analog Rod Position Indicator (ARPI) Per Bank Event Dates: (Unit 2) 1/5/94 and 1/16/94 (Unit 1) 1/24/94 Report Date: 2/3/94 This report was initiated by Incident Report Nos. 94-006, 94-019 and 94-028. CONDITIONS PRIOR TO OCCURRENCE: (Unit 2) 1/5/94: Mode 1 Reactor Power 34% Unit Load -300 MWe 1/16/94: Mode 1 Reactor Power 100% Unit Load -1180 MWe (Unit 1) Mode 2 Reactor Power lOE-8 Amps Unit Load -o-DESCRIPTION OF OCCURRENCES: | | .llii~1ll,I (Specify in Abstract 20.405(a) (1) (iii) x 50.73(a)(2)(i) 50. 73(a)(2)(viii)(A) below and in Tex1, 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) |
| Intentional TS 3.0.3 entries were made: for Unit 2 on January 5, 1994, from.1637 to 1642 hours, and on January 16, 1994, from 0037 to 0045 hours, and for Unit 1 on January 24, 1994, from 2215 to 2245 hours. This was done to permit calibrating the respective ARPI {AA} Control Board dual indicator modules for Unit 2 control rods 2B4 and 1D2 and Unit 1 control rods 2Al and 2B2. The calibration process rendered ARPI inoperable for the subject rods and for the rods sharing the same dual indicator module: Unit 2 rods 2B3 and lDl and Unit 1 rods 2A2 and | | LICENSEE CONTACT FOR THIS LER 12\ |
| * 2Bl. In *each case, actual rod positions (per group demand) were correct. ANALYSIS OF OCCURRENCES: | | NAME TELEPHONE NUMBER (Include Area Code) |
| ARPI operability is required to determine individual control* rod position and ensure compiiance with control rod alignment and insertion limits assumed in the accident analyses. | | M. J. Pastva, Jr. - LER Coordinator (609) 339-5165 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORTl13l REPORTABLE REPORTABLE CAUSE SYSTEM COMPONENT MANUFACTURER CAUSE SYSTEM COMPONENT MANUFACTURER TO NPRDS TO NPRDS SUPPLEMENTAL REPORT EXPECTED (14) EXPECTED MONTH DAY YEAR YES SUBMISSION NO (If yes, complete EXPECTED SUBMISSION DATE) x DATE (15) |
| ARPI provides actual rod position to the following locations: | | ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16) |
| the Control Board dual channel position indicator modules (supplied by Dixon), the Safety Parameter Display System (SPDS), the main process P250 computer,.and iocally via the digital multimeter (DMM) ._ | | - |
| LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 1 --DOCKET NUMBER 5000272 ANALYSIS OF OCCURRENCES: (cont'd) LER NUMBER 94-001-00 PAGE 3 of *4 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 system agrees within twelve (12) steps of the group demand counters. | | Intentional Technical Specification (TS) 3.0.3 entries were made: for Unit 2 on 1/5/94, from 1637 to 1642 hours, and on 1/16/94, fr_om 0037 to 0045 hours, and for Unit 1 on 1/24/94, from 2215 to 2245 hours. |
| 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. o. 3 therefore applies. -On January 5th, 16th, and 24th, TS 3.0.3 was intentionally entered to allow calibrating the respective ARPI Dixon dual position indicators for control rods 2B4 and 1D2 (Unit 2) and for 2Al anci 2B2 (Unit 1). Calibrating the indicators required removing the dual indicator modules, which rendered the ARP! for subject rods and for the rods sharing the same module inoperable:- | | This was done to permit calibrating the respective Analog Rod Position Indicator (ARP!) control Board dual indicator modules for Unit 2 control rods 2B4 and 1D2 and for Unit 1 control rods 2Al and 2B2. |
| 2B3 and lDl (Unit 2) and 2A2 and 2Bl (Unit 1). In each case, actual rod positions (per group demand) were correct. The indicators were then calibrated, ARP! for the affected control rods was restored, and in each case TS 3.0.3 was exited. -APPARENT CAUSE OF .OCCURRENCES: | | Calibrating the indicators required removing the dual indicator modules, which rendered ARP! for subject rods and for the rods sharing the same module inoperable: 2B3 and lDl (Unit 2)* and 2A2 and 2Bl (Unit 1). In each case, actual rod positions (per group demand) were correct. The root cause of these events is design of ARP! |
| The root cause of these events is "Design, Manufacturing, Construction/Installation", per NUREG-1022. | | position.indicators requiring entering TS 3.0.3 whenever ARP! |
| Design of ARPI position indication is such that two rods share each Dixon indicator module. Consequently, TS 3.0.3 is entered whenever the ARP! position indicator | | calibrations are performed. The subject position indicators were calibrated and TS 3.0.3 was exited. A Night Order Book (NOB) entry was made, on 1/27/94, to provide guidance/restrictions for ARP! Dixon indicator calibrations and TS 3.0.3 entries. An Information Directive will be issued to formalize the 1/27/94 NOB entry. |
| -modules are removed from service for calibration. | | NRG FORM 366 (5-92) |
| | |
| | -* |
| | LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating station DOCKET NUMBER LER NUMBER PAGE. |
| | Unit 1 5000272 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 On Both Salem Units; More Than One Inoperable Analog Rod Position Indicator (ARPI) Per Bank Event Dates: (Unit 2) 1/5/94 and 1/16/94 (Unit 1) 1/24/94 Report Date: 2/3/94 This report was initiated by Incident Report Nos. 94-006, 94-019 and 94-028. |
| | CONDITIONS PRIOR TO OCCURRENCE: |
| | (Unit 2) 1/5/94: Mode 1 Reactor Power 34% Unit Load - 300 MWe 1/16/94: Mode 1 Reactor Power 100% Unit Load - 1180 MWe (Unit 1) Mode 2 Reactor Power lOE-8 Amps Unit Load -o-DESCRIPTION OF OCCURRENCES: |
| | Intentional TS 3.0.3 entries were made: for Unit 2 on January 5, 1994, from.1637 to 1642 hours, and on January 16, 1994, from 0037 to 0045 hours, and for Unit 1 on January 24, 1994, from 2215 to 2245 hours. |
| | This was done to permit calibrating the respective ARPI {AA} Control Board dual indicator modules for Unit 2 control rods 2B4 and 1D2 and fo~ Unit 1 control rods 2Al and 2B2. The calibration process rendered ARPI inoperable for the subject rods and for the rods sharing the same dual indicator module: Unit 2 rods 2B3 and lDl and Unit 1 rods 2A2 and |
| | * 2Bl. In *each case, actual rod positions (per group demand) were correct. |
| | ANALYSIS OF OCCURRENCES: |
| | ARPI operability is required to determine individual control* rod position and ensure compiiance with control rod alignment and insertion limits assumed in the accident analyses. ARPI 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 computer,.and iocally via the digital multimeter (DMM) ._ |
| | |
| | LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 - - 5000272 94-001-00 3 of *4 ANALYSIS OF OCCURRENCES: (cont'd) |
| | 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 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. o. 3 therefore applies. - |
| | On January 5th, 16th, and 24th, TS 3.0.3 was intentionally entered to allow calibrating the respective ARPI Dixon dual position indicators for control rods 2B4 and 1D2 (Unit 2) and for 2Al anci 2B2 (Unit 1). |
| | Calibrating the indicators required removing the dual indicator modules, which rendered the ARP! for subject rods and for the rods sharing the same module inoperable:- 2B3 and lDl (Unit 2) and 2A2 and 2Bl (Unit 1). In each case, actual rod positions (per group demand) were correct. The indicators were then calibrated, ARP! for the affected control rods was restored, and in each case TS 3.0.3 was exited. - |
| | APPARENT CAUSE OF .OCCURRENCES: |
| | The root cause of these events is "Design, Manufacturing, Construction/Installation", per NUREG-1022. Design of ARPI position indication is such that two rods share each Dixon indicator module. |
| | Consequently, TS 3.0.3 is entered whenever the ARP! position indicator |
| | - modules are removed from service for calibration. |
| PRIOR SIMILAR OCCURRENCES: | | PRIOR SIMILAR OCCURRENCES: |
| Prior events requiring TS 3.0.3 entry, due to ARP! control rod design concerns, have occurred on both Salem Units, as reported in LERs | | Prior events requiring TS 3.0.3 entry, due to ARP! control rod design concerns, have occurred on both Salem Units, as reported in LERs |
| * 272/93-007-00, 311/92-016-00, and 311/93-010-00. | | * 272/93-007-00, 311/92-016-00, and 311/93-010-00. As a result of these events, 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! |
| As a result of these events, 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 the vendors will be used to develop appropriate action. -SAFETY SIGNIFICANCE: | | System drift. Recommendations from this group and the vendors will be used to develop appropriate action. - |
| These events did not affect the health and safety of the public. With entry into TS 3.0.3, these events are reportable to the NRC pursuant to Code of Federal Regulations lOCFR 50.73(a) (2) (i) (B). TS required actions were met for these events. In each case, actual rod positions (per group demand) were correct, with only the Control Board indication wrong. Verification of position was available via the SPDS, the P250 computer, and local DMM. | | SAFETY SIGNIFICANCE: |
| . LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 1 CORRECTIVE ACTION: DOCKET NUMBER 5000272 LER NUMBER 94-001-00 PAGE 4 of 4 The position indicators of the affected rods were calibrated and TS 3.0.3 was exited. A Night Order Book (NOB) entry was made, on January 27, 1994, to provide guidance/restrictions for ARPI Dixon indicator calibrations and TS 3.0.3 entries. An Information Directive will be issued to formalize the above-referenced NOB entry. PSE&G will continue to participate in the industry Rod Control User's Group efforts to resolve the industry-wide problem with ARPI System drift. ,/} / MJPJ:pc SORC Mtg. 94-011 I ,i_ General Manager -Salem Operations}} | | These events did not affect the health and safety of the public. With entry into TS 3.0.3, these events are reportable to the NRC pursuant to Code of Federal Regulations lOCFR 50.73(a) (2) (i) (B). |
| | TS required actions were met for these events. In each case, actual rod positions (per group demand) were correct, with only the Control Board indication wrong. Verification of position was available via the SPDS, the P250 computer, and local DMM. |
| | |
| | . LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 94-001-00 4 of 4 CORRECTIVE ACTION: |
| | The position indicators of the affected rods were calibrated and TS 3.0.3 was exited. |
| | A Night Order Book (NOB) entry was made, on January 27, 1994, to provide guidance/restrictions for ARPI Dixon indicator calibrations and TS 3.0.3 entries. |
| | An Information Directive will be issued to formalize the above-referenced NOB entry. |
| | PSE&G will continue to participate in the industry Rod Control User's Group efforts to resolve the industry-wide problem with ARPI System drift. ,/} ~~ ~ |
| | / |
| | /*~ ~~ |
| | /)t?f!~~' ,i_ |
| | I General Manager - |
| | Salem Operations MJPJ:pc SORC Mtg. 94-011}} |
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LER 98-012-01:on 980725,noted That Afs Was Operated with Less than Required Number of Operable AFW Pumps.Caused by Improper Procedure Implementation.Runout Protection Pressure Device for 22 AFW Pumps Was Returned to Svc.With 980928 Ltr
ML18106A8821998-09-21021 September 1998
LER 98-013-00:on 980820,noted Surveillance of Containment Penetration Overcurrent Protection Devices Missed.Caused by Human Error.Satisfactorily Tested Apprpriate Breakers & Disciplined Involved Personnel.With 980921 Ltr
ML18106A8791998-09-16016 September 1998
LER 96-006-01:on 960717,determined That non-radioactive Liquid Basin Radwaste Monitor Inoperable During Low Head Conditions.Caused by Inadequate Design Change Package.Design Change 1EC3663-01 Has Been Installed.With 980916 Ltr
ML18106A8801998-09-0808 September 1998
LER 98-013-00:on 980806,operation with TS Required Equipment OOS Was Noted.Caused by Human Error.Reviewed Processes & Practices Re Safety Sys Status Control,Procedure Rev & Extra Training.With 980908 Ltr
ML18106A8531998-08-27027 August 1998
LER 98-007-00:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Cause of Event Has Not Yet Been Determined.Assembled Root Cause Team & Replaced Affected tubing.W/980827 Ltr
ML18106A8521998-08-27027 August 1998
LER 98-011-00:on 980803,ESFA During a 4KV Automatic Transfer Test Was Noted.Caused by Premature Release of Control Console Pushbutton Due to Inadequate Procedural Step.Revised procedure.W/980827 Ltr
ML18106A8421998-08-24024 August 1998
LER 98-012-00:on 980725,discovered That Plant Had Operated in Modes 1 & 2 w/twenty-two AFW Pumps Inoperable.Caused by Failure to Restore Pump Runout Protection Pressure Device to Svc.Returned Subject Device to svc.W/980824 Ltr
ML18106A8431998-08-24024 August 1998
LER 98-009-00:on 980810,failure to Post Continuous Firewatch as Required by Fire Protection Plan Noted.Caused by Failure to Recognize Concurrent Conditions.Continuous Firewatch Was Posted Immediately & Repaired Smoke detectors.W/980824 Ltr
ML18106A8141998-08-13013 August 1998
LER 98-010-00:on 980714,determined That Leakage from Boron Injection Tank Exceeded Max Allowable ECCS Leakage from Sources Outside Containment.Caused by Leaking 2SJ404 Manual Sample valve.2SJ404 Valve repaired.W/980813 Ltr
ML18106A8201998-08-13013 August 1998
LER 98-012-00:on 980715,potential to Exceed Rating of Piping Due to Isolation of Overpressure Protection Line Was Noted. Caused by Inadequate Procedural Guidance.Appropriate Operations Dept Procedures Have Been revised.W/980813 Ltr
ML18106A6931998-06-29029 June 1998
LER 98-003-00:on 980122,inappropriate Plugging of Tubes R9C60 & R10C60 in Salem Unit 2 Sg,Was Performed.Caused by Failure of Qualification,Verification & Validation Process. Tubes Reviewed to Verify No Others Inappropriately Plugged
ML18106A6471998-06-0404 June 1998
LER 98-011-00:on 980505,improper Isolation of Single Cell Battery Charger from 125 Vdc Battery Was Noted.Caused by Inadequate 10CFR50.59 Applicability Review.Placed Procedure SC.MD-CM.ZZ-0024(Q) on Administrative hold.W/980604 Ltr
ML18106A6421998-06-0101 June 1998
LER 98-010-00:on 931019,reactor Pressure Vessel Insp Plugs Were Out of Configuration,Was Noted.Caused by Personnel Error.Proper Configuration Was Restored Shortly After Discovery Prior to Entering Mode 2.W/980601 Ltr
ML18106A6431998-05-29029 May 1998
LER 98-006-01:on 980227,determined Incorrect Scaling Error of First Stage Pressure Transmitter Existed.Caused by Human Error.Revised Setpoint Calculation SC-MS002-01 & Revised Associated Instrument Calibr Database info.W/980529 Ltr
ML18106A6141998-05-18018 May 1998
LER 98-008-00:on 970814,failure to Test 21 & 22 AF 40 Valves in Closed Direction as Required by TS 4.0.5 Was Noted.Caused by Inadequate Design Mod Process.Motor Driven 21/22 AF 40 Valves Were Tested IAW Revised procedure.W/980518 Ltr
ML18106A5901998-05-0101 May 1998
LER 98-009-00:on 980405,epoxy Missing from Terminals of H Analyzer Was Noted.Caused by Inadequate Development of Procedure.H Analyzers Were Repaired & Review of Other Safety Related Equipment in Containment Was performed.W/980501 Ltr
ML18106A5611998-04-20020 April 1998
LER 98-008-00:on 980323,inadequate Testing of Salem Unit 1 Containment Air Locks Resulted in Entering TS 3.0.3.Caused by less-than-adequate Work Practices During Replacement of Equalizing Valve.Salem Unit 2 Airlocks Were Inspected
ML18106A6061998-04-0101 April 1998
Corrected LER 98-004-00:on 980302,failure to Comply W/Tss 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Have Been Taken to Correctly Document Safety Factors.Corrects Prior Similar Occurrences
ML18106A4451998-04-0101 April 1998
LER 98-004-00:on 980302,failure to Perform TS 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Were Taken to Correctly Document Safety factors.W/980401 Ltr
ML18106A4351998-03-30030 March 1998
LER 98-006-00:on 980227,incorrect Scaling of First Stage Turbine Impulse Pressure Transmitters Noted.Cause Indeterminate.Implemented Procedure Changes & re-scaled Affected Turbine Impulse Pressure transmitters.W/980330 Ltr
ML18106A3961998-03-20020 March 1998
LER 98-005-00:on 980219,inoperability of Twelve EDG Fuel Oil Transfer Pump (FOTP) Noted.Caused by Installation of Incorrect Control Switch.Installed Correct off-auto-manual Switch & Verified Operability of Twelve FOTP.W/980320 Ltr
ML18106A5781998-03-20020 March 1998
Corrected LER 98-005-00:on 980219,inoperability of 12 Fuel Oil Transfer Pump (Fotp),Noted.Caused by Installation of Incorrect Control Switch.Field Insp Performed to Verify Configuration of Switches for 11,21 & 22 FOTPs
ML18106A4021998-03-20020 March 1998
LER 98-007-00:on 980218,failure to Establish Containment Integrity (Closure) Prior to Fuel Movement Was Noted.Caused by Failure to Identify & Include Condensate Pot Vent in Appropriate Valve Lineup.Valves identified.W/980320 Ltr
ML18106A4031998-03-20020 March 1998
LER 98-006-00:on 980221,ESF Actuation of 11 & 12 Auxiliary Feedwater Pumps Occurred.Caused by Human Error.Operators Promptly Established Feedwater to All SG & Restored Proper Water levels.W/980320 Ltr
1999-08-26
[Table view]
Category:RO)
MONTHYEARML18107A5031999-08-26026 August 1999
LER 99-006-00:on 990729,determined That SG Blowdown RMs Setpoint Was non-conservative.Caused by Inadequate ACs for Incorporating Original Plant Licensing Data Into Plant Procedures.Blowdown Will Be Restricted.With 990826 Ltr
ML18107A4691999-07-28028 July 1999
LER 99-008-00:on 990714,determined That Limit Switch Cables Were Subject to Multiple Hot Shorts in Same Fire Area.Caused by Inadequate Original Post Fire Safe Shutdown Analysis.All Limit Switch Cables for MOVs Were Reviewed.With 990728 Ltr
ML18107A4441999-07-0606 July 1999
LER 99-007-00:on 990605,surveillance for Quadrant Power Tilt Ratio (QPTR) Was Missed.Caused by Human Error.Qptr Calculation Was Performed & Personnel Involved Have Been Held Accountable IAW Pse&G Policies.With 990706 Ltr
ML18107A4211999-07-0202 July 1999
LER 99-005-00:on 990605,11 Containment Declared Inoperable. Caused by Valves 11SW72 & 11SW223 Both Leaking.Procedure S1.OP-ST.SW-0010(Q) Was Enhanced to Provide Specific Instructions to Ensure Proper Sequencing.With 990702 Ltr
ML18107A4321999-07-0101 July 1999
LER 99-006-01:on 990501,determined That There Was No Flow in One of Four Injection Legs.Caused by Sticking of Valve in Safety Injection Discharge Line to 21 Cold Leg.Valve Was Cut Out of Sys & Replaced.With 990701 Ltr
ML18107A4331999-07-0101 July 1999
LER 99-002-01:on 990405,determined That 2SA118 Failed as Found Leakrate Test.Caused by Foreign Matl Found in 2SA118 valve.2SA118 Valve Was Cycled Several Times & Seat Area Was Air Blown in Order to Displace Foreign Matl.With 990701 Ltr
ML18107A3951999-06-17017 June 1999
LER 99-004-00:on 990520,reactor Tripped from 100% Power,Due to Negative Flux Trip Signal from Nuclear Instrumentation. Cause Has Not Been Determined.Discoloration Was Identified on One of Penetrations.With 990617 Ltr
ML18107A3661999-06-0909 June 1999
LER 99-003-00:on 990513,unplanned Entry Into TS 3.0.3 Was Made.Caused by Human error.Re-positioned Creacs Supply Fan Selector Switches & Revised Procedures S1 & S2.OP-ST.SSP-0001(Q).With 990609 Ltr
ML18107A3551999-06-0202 June 1999
LER 99-005-00:on 990504,failure to Meet TS Action Statement Requirements for High Oxygen Concentration in Waste Gas Holdup Sys Occurred.Caused by Inability of Operators. Existing Procedures Will Be Evaluated.With 990602 Ltr
ML18107A3541999-06-0101 June 1999
LER 99-006-00:on 990501,HHSI Flow Balance Discrepancy Was Noted During Surveillance.Caused by Sticking of Check Valve in SI Discharge Line to 21 Cold Leg.Valve 21SJ17,was Cut Out of Sys & Replaced.With 990601 Ltr
ML18107A2931999-05-12012 May 1999
LER 99-002-00:on 990413,determined That Number 12 Auxiliary Bldg Exhaust Fan Was Rotating Backwards.Caused by mis-wiring of Motor Due to Human Error by Maint technician.Mis-wiring Was Corrected & Fan Was Returned to Svc.With 990512 Ltr
ML18107A2781999-05-10010 May 1999
LER 99-004-00:on 990411,automatic Actuation of ESF Occurred During Reactor Vessel Head Removal in Support of Refueling Operations.Caused by High Radiation Condition.Containment Atmosphere Was Monitored.With 990505 Ltr
ML18107A2791999-05-0404 May 1999
LER 99-003-00:on 990406,all Salem Unit 2 Chillers Rendered Inoperable.Caused by Human Error.Lessons Learned from Event Were Communicated to All Operators by Including Them in Night Orders.With 990504 Ltr
ML18107A2741999-05-0303 May 1999
LER 99-002-00:on 990405,determined That Containment Isolation Valve Failed as Found Leakrate Test.Caused by Foreign Matl Blocking Valves from Closing.Check Valve Mechanically Agitated.With 990504 Ltr
ML18107A2351999-04-23023 April 1999
LER 99-001-00:on 990330,MSSV Failed Lift Set Test.Caused by Setpoint Variance Which Is Result of Aging.Valves Were Adjusted & Retested to Ensure TS Tolerance.With 990423 Ltr
ML18106B1471999-03-29029 March 1999
LER 99-001-00:on 990228,reactor Scram Was Noted as Result of Turbine Trip.Caused by Operator Error.Lesson Plans Revised to Explicitly Demonstrate Manner in Which Valve Functions. with 990329 Ltr
ML18106B0701999-02-16016 February 1999
LER 98-015-00:on 981208,inadvertent Discharge Through RHR Relief Valve During Startup Was Noted.Caused by Operator Performing Too Many Tasks Simultaneously.Appropriate Actions Have Been Taken IAW Policies & Procedures.With 990216 Ltr
ML18106B0491999-01-28028 January 1999
LER 98-007-01:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Caused by Transgranular Stress Corrosion Cracking.Replaced Affected Tubing.With 990128 Ltr
ML18106B0401999-01-18018 January 1999
LER 98-016-00:on 981219,ECCS Leakage Was Outside of Design Value.Caused by Leakage Past Seat of 21RH34 Manual Drain. Valve 21RH34 Was Reseated.With 990118 Ltr
ML18106B0081998-12-24024 December 1998
LER 97-001-01:on 970215,failure to Perform TS Surveillance of Component Cooling Water Sys Check Valves Occurred.Caused by Inadequate Communication Between EOP Group & IST Reviewers.Procedure Revised.With 981224 Ltr
ML18106B0021998-12-17017 December 1998
LER 98-015-01:on 980924,improper Installation of Test Equipment to RPS Occurred.Caused by Inadequate 10CFR50.59 Applicability Reviews During Past Revs.Revised Procedures. with 981217 Ltr
ML18106A9551998-11-0303 November 1998
LER 96-013-01:on 960711,concluded That Current Gain & Bias Settings Had Rendered Overtemperature Delta Temp Protection Channels Inoperable.Caused by Scaling Error.Licensee Will Revise Scaling Calculations.With 981105 Ltr
ML18106A9451998-10-30030 October 1998
LER 97-004-01:on 970408,failure to Comply with TS Action Statement,Dg Start & Inadequate Surveillance Testing,Was Noted.Caused by Inadequate Tracking of Inoperable Equipment. Discussed Event & Lessons Learned.With 981022 Ltr
ML18106A9491998-10-22022 October 1998
LER 98-015-00:on 980924,identified Improper Installation of Test Equipment to Rps.Cause Indeterminate.Procedures for Installation of Test Equipment for Collection of State Point Data Were Placed on Administrative Hold.With 981022 Ltr
ML18106A9301998-10-21021 October 1998
LER 98-014-00:on 980725,noted Improper Calibr of Liquid Radwaste Effluent Line Radiation Monitor.Caused by Inattention to Detail by Maint Personnel.Channel Calibr Was Successfully Performed on 1R18 on 980821.With 981019 Ltr
ML18106A9071998-10-0101 October 1998
LER 98-014-00:on 980918,discovered That Fire Barrier Matl for HVAC Ducts Does Not Meet Required Level of Fire Resistance.Cause Indeterminate.Established Appropriate Compensatory Actions for Fire Barriers.With 981001 Ltr
ML18106A8951998-09-28028 September 1998
LER 98-012-01:on 980725,noted That Afs Was Operated with Less than Required Number of Operable AFW Pumps.Caused by Improper Procedure Implementation.Runout Protection Pressure Device for 22 AFW Pumps Was Returned to Svc.With 980928 Ltr
ML18106A8821998-09-21021 September 1998
LER 98-013-00:on 980820,noted Surveillance of Containment Penetration Overcurrent Protection Devices Missed.Caused by Human Error.Satisfactorily Tested Apprpriate Breakers & Disciplined Involved Personnel.With 980921 Ltr
ML18106A8791998-09-16016 September 1998
LER 96-006-01:on 960717,determined That non-radioactive Liquid Basin Radwaste Monitor Inoperable During Low Head Conditions.Caused by Inadequate Design Change Package.Design Change 1EC3663-01 Has Been Installed.With 980916 Ltr
ML18106A8801998-09-0808 September 1998
LER 98-013-00:on 980806,operation with TS Required Equipment OOS Was Noted.Caused by Human Error.Reviewed Processes & Practices Re Safety Sys Status Control,Procedure Rev & Extra Training.With 980908 Ltr
ML18106A8531998-08-27027 August 1998
LER 98-007-00:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Cause of Event Has Not Yet Been Determined.Assembled Root Cause Team & Replaced Affected tubing.W/980827 Ltr
ML18106A8521998-08-27027 August 1998
LER 98-011-00:on 980803,ESFA During a 4KV Automatic Transfer Test Was Noted.Caused by Premature Release of Control Console Pushbutton Due to Inadequate Procedural Step.Revised procedure.W/980827 Ltr
ML18106A8421998-08-24024 August 1998
LER 98-012-00:on 980725,discovered That Plant Had Operated in Modes 1 & 2 w/twenty-two AFW Pumps Inoperable.Caused by Failure to Restore Pump Runout Protection Pressure Device to Svc.Returned Subject Device to svc.W/980824 Ltr
ML18106A8431998-08-24024 August 1998
LER 98-009-00:on 980810,failure to Post Continuous Firewatch as Required by Fire Protection Plan Noted.Caused by Failure to Recognize Concurrent Conditions.Continuous Firewatch Was Posted Immediately & Repaired Smoke detectors.W/980824 Ltr
ML18106A8141998-08-13013 August 1998
LER 98-010-00:on 980714,determined That Leakage from Boron Injection Tank Exceeded Max Allowable ECCS Leakage from Sources Outside Containment.Caused by Leaking 2SJ404 Manual Sample valve.2SJ404 Valve repaired.W/980813 Ltr
ML18106A8201998-08-13013 August 1998
LER 98-012-00:on 980715,potential to Exceed Rating of Piping Due to Isolation of Overpressure Protection Line Was Noted. Caused by Inadequate Procedural Guidance.Appropriate Operations Dept Procedures Have Been revised.W/980813 Ltr
ML18106A6931998-06-29029 June 1998
LER 98-003-00:on 980122,inappropriate Plugging of Tubes R9C60 & R10C60 in Salem Unit 2 Sg,Was Performed.Caused by Failure of Qualification,Verification & Validation Process. Tubes Reviewed to Verify No Others Inappropriately Plugged
ML18106A6471998-06-0404 June 1998
LER 98-011-00:on 980505,improper Isolation of Single Cell Battery Charger from 125 Vdc Battery Was Noted.Caused by Inadequate 10CFR50.59 Applicability Review.Placed Procedure SC.MD-CM.ZZ-0024(Q) on Administrative hold.W/980604 Ltr
ML18106A6421998-06-0101 June 1998
LER 98-010-00:on 931019,reactor Pressure Vessel Insp Plugs Were Out of Configuration,Was Noted.Caused by Personnel Error.Proper Configuration Was Restored Shortly After Discovery Prior to Entering Mode 2.W/980601 Ltr
ML18106A6431998-05-29029 May 1998
LER 98-006-01:on 980227,determined Incorrect Scaling Error of First Stage Pressure Transmitter Existed.Caused by Human Error.Revised Setpoint Calculation SC-MS002-01 & Revised Associated Instrument Calibr Database info.W/980529 Ltr
ML18106A6141998-05-18018 May 1998
LER 98-008-00:on 970814,failure to Test 21 & 22 AF 40 Valves in Closed Direction as Required by TS 4.0.5 Was Noted.Caused by Inadequate Design Mod Process.Motor Driven 21/22 AF 40 Valves Were Tested IAW Revised procedure.W/980518 Ltr
ML18106A5901998-05-0101 May 1998
LER 98-009-00:on 980405,epoxy Missing from Terminals of H Analyzer Was Noted.Caused by Inadequate Development of Procedure.H Analyzers Were Repaired & Review of Other Safety Related Equipment in Containment Was performed.W/980501 Ltr
ML18106A5611998-04-20020 April 1998
LER 98-008-00:on 980323,inadequate Testing of Salem Unit 1 Containment Air Locks Resulted in Entering TS 3.0.3.Caused by less-than-adequate Work Practices During Replacement of Equalizing Valve.Salem Unit 2 Airlocks Were Inspected
ML18106A6061998-04-0101 April 1998
Corrected LER 98-004-00:on 980302,failure to Comply W/Tss 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Have Been Taken to Correctly Document Safety Factors.Corrects Prior Similar Occurrences
ML18106A4451998-04-0101 April 1998
LER 98-004-00:on 980302,failure to Perform TS 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Were Taken to Correctly Document Safety factors.W/980401 Ltr
ML18106A4351998-03-30030 March 1998
LER 98-006-00:on 980227,incorrect Scaling of First Stage Turbine Impulse Pressure Transmitters Noted.Cause Indeterminate.Implemented Procedure Changes & re-scaled Affected Turbine Impulse Pressure transmitters.W/980330 Ltr
ML18106A3961998-03-20020 March 1998
LER 98-005-00:on 980219,inoperability of Twelve EDG Fuel Oil Transfer Pump (FOTP) Noted.Caused by Installation of Incorrect Control Switch.Installed Correct off-auto-manual Switch & Verified Operability of Twelve FOTP.W/980320 Ltr
ML18106A5781998-03-20020 March 1998
Corrected LER 98-005-00:on 980219,inoperability of 12 Fuel Oil Transfer Pump (Fotp),Noted.Caused by Installation of Incorrect Control Switch.Field Insp Performed to Verify Configuration of Switches for 11,21 & 22 FOTPs
ML18106A4021998-03-20020 March 1998
LER 98-007-00:on 980218,failure to Establish Containment Integrity (Closure) Prior to Fuel Movement Was Noted.Caused by Failure to Identify & Include Condensate Pot Vent in Appropriate Valve Lineup.Valves identified.W/980320 Ltr
ML18106A4031998-03-20020 March 1998
LER 98-006-00:on 980221,ESF Actuation of 11 & 12 Auxiliary Feedwater Pumps Occurred.Caused by Human Error.Operators Promptly Established Feedwater to All SG & Restored Proper Water levels.W/980320 Ltr
1999-08-26
[Table view]
Category:TEXT-SAFETY REPORT
MONTHYEARML20217A9931999-09-30030 September 1999
NRC Regulatory Assessment & Oversight Pilot Program, Performance Indicator Data
ML18107A5581999-09-30030 September 1999
Monthly Operating Rept for Sept 1999 for Salem,Unit 2.With 991014 Ltr
ML18107A5571999-09-30030 September 1999
Monthly Operating Rept for Sept 1999 for Salem,Unit 1.With 991014 Ltr
ML18107A5301999-08-31031 August 1999
Monthly Operating Rept for Aug 1999 for Salem,Unit 2.With 990913 Ltr
ML18107A5311999-08-31031 August 1999
Monthly Operating Rept for Aug 1999 for Salem,Unit 1.With 990913
ML18107A5031999-08-26026 August 1999
LER 99-006-00:on 990729,determined That SG Blowdown RMs Setpoint Was non-conservative.Caused by Inadequate ACs for Incorporating Original Plant Licensing Data Into Plant Procedures.Blowdown Will Be Restricted.With 990826 Ltr
ML18107A5201999-08-12012 August 1999
Rev 0 to Sgs Unit 2 ISI RFO Exam Results (S2RFO#9) Second Interval,Second Period, First Outage (96RF).
ML18107A4811999-07-31031 July 1999
Monthly Operating Rept for July 1999 for Salem,Unit 1.With 990813 Ltr
ML18107A4821999-07-31031 July 1999
Monthly Operating Rept for July 1999 for Salem,Unit 2.With 990813 Ltr
ML18107A4691999-07-28028 July 1999
LER 99-008-00:on 990714,determined That Limit Switch Cables Were Subject to Multiple Hot Shorts in Same Fire Area.Caused by Inadequate Original Post Fire Safe Shutdown Analysis.All Limit Switch Cables for MOVs Were Reviewed.With 990728 Ltr
ML18107A4441999-07-0606 July 1999
LER 99-007-00:on 990605,surveillance for Quadrant Power Tilt Ratio (QPTR) Was Missed.Caused by Human Error.Qptr Calculation Was Performed & Personnel Involved Have Been Held Accountable IAW Pse&G Policies.With 990706 Ltr
ML18107A4211999-07-0202 July 1999
LER 99-005-00:on 990605,11 Containment Declared Inoperable. Caused by Valves 11SW72 & 11SW223 Both Leaking.Procedure S1.OP-ST.SW-0010(Q) Was Enhanced to Provide Specific Instructions to Ensure Proper Sequencing.With 990702 Ltr
ML18107A4331999-07-0101 July 1999
LER 99-002-01:on 990405,determined That 2SA118 Failed as Found Leakrate Test.Caused by Foreign Matl Found in 2SA118 valve.2SA118 Valve Was Cycled Several Times & Seat Area Was Air Blown in Order to Displace Foreign Matl.With 990701 Ltr
ML18107A4321999-07-0101 July 1999
LER 99-006-01:on 990501,determined That There Was No Flow in One of Four Injection Legs.Caused by Sticking of Valve in Safety Injection Discharge Line to 21 Cold Leg.Valve Was Cut Out of Sys & Replaced.With 990701 Ltr
ML18107A5211999-07-0101 July 1999
Rev 0 to Sgs Unit 2 ISI RFO Exam Results (S2RFO#10) Second Interval,Second Period,Second Outage (99RF).
ML18107A4351999-06-30030 June 1999
Monthly Operating Rept for June 1999 for Salem,Unit 1.With 990713 Ltr
ML18107A4341999-06-30030 June 1999
Monthly Operating Rept for June 1999 for Salem,Unit 2.With 990713 Ltr
ML20196H8621999-06-30030 June 1999
NRC Regulatory Assessment & Oversight Pilot Program, Performance Indicator Data, June 1999 Rept
ML18107A3951999-06-17017 June 1999
LER 99-004-00:on 990520,reactor Tripped from 100% Power,Due to Negative Flux Trip Signal from Nuclear Instrumentation. Cause Has Not Been Determined.Discoloration Was Identified on One of Penetrations.With 990617 Ltr
ML18107A3661999-06-0909 June 1999
LER 99-003-00:on 990513,unplanned Entry Into TS 3.0.3 Was Made.Caused by Human error.Re-positioned Creacs Supply Fan Selector Switches & Revised Procedures S1 & S2.OP-ST.SSP-0001(Q).With 990609 Ltr
ML18107A3551999-06-0202 June 1999
LER 99-005-00:on 990504,failure to Meet TS Action Statement Requirements for High Oxygen Concentration in Waste Gas Holdup Sys Occurred.Caused by Inability of Operators. Existing Procedures Will Be Evaluated.With 990602 Ltr
ML18107A3441999-06-0101 June 1999
Interim Part 21 Rept Re Premature Over Voltage Protection Actuation in Circuit Specific Application in Dc Power Supply.Testing & Evaluation Activities Will Be Completed on 990716
ML18107A3541999-06-0101 June 1999
LER 99-006-00:on 990501,HHSI Flow Balance Discrepancy Was Noted During Surveillance.Caused by Sticking of Check Valve in SI Discharge Line to 21 Cold Leg.Valve 21SJ17,was Cut Out of Sys & Replaced.With 990601 Ltr
ML18107A3681999-05-31031 May 1999
Monthly Operating Rept for May 1999 for Salem Generating Station,Unit 1.With 990611 Ltr
ML18107A3721999-05-31031 May 1999
Monthly Operating Rept for May 1999 for Salem Generating Station,Unit 2.With 990611 Ltr
ML18107A2931999-05-12012 May 1999
LER 99-002-00:on 990413,determined That Number 12 Auxiliary Bldg Exhaust Fan Was Rotating Backwards.Caused by mis-wiring of Motor Due to Human Error by Maint technician.Mis-wiring Was Corrected & Fan Was Returned to Svc.With 990512 Ltr
ML18107A2781999-05-10010 May 1999
LER 99-004-00:on 990411,automatic Actuation of ESF Occurred During Reactor Vessel Head Removal in Support of Refueling Operations.Caused by High Radiation Condition.Containment Atmosphere Was Monitored.With 990505 Ltr
ML18107A2791999-05-0404 May 1999
LER 99-003-00:on 990406,all Salem Unit 2 Chillers Rendered Inoperable.Caused by Human Error.Lessons Learned from Event Were Communicated to All Operators by Including Them in Night Orders.With 990504 Ltr
ML18107A2741999-05-0303 May 1999
LER 99-002-00:on 990405,determined That Containment Isolation Valve Failed as Found Leakrate Test.Caused by Foreign Matl Blocking Valves from Closing.Check Valve Mechanically Agitated.With 990504 Ltr
ML18107A3711999-04-30030 April 1999
Corrected Monthly Operating Rept for Apr 1999 for Salem Generating Station,Unit 1
ML18107A3151999-04-30030 April 1999
Submittal-Only Screening Review of Salem Generating Station Individual Plant Exam for External Events (Seismic Portion), Rev 1
ML18107A2991999-04-30030 April 1999
Monthly Operating Rept for Apr 1999 for Salem Unit 1.With 990514 Ltr
ML18107A2971999-04-30030 April 1999
Monthly Operating Rept for Apr 1999 for Salem Unit 2.With 990514 Ltr
ML18107A2351999-04-23023 April 1999
LER 99-001-00:on 990330,MSSV Failed Lift Set Test.Caused by Setpoint Variance Which Is Result of Aging.Valves Were Adjusted & Retested to Ensure TS Tolerance.With 990423 Ltr
ML18107A2881999-04-0707 April 1999
Rev 0 to NFS-0174, COLR for Salem Unit 2 Cycle 11.
ML18107A1821999-03-31031 March 1999
Monthly Operating Rept for Mar 1999 for Salem,Unit 1.With 990414 Ltr
ML18107A1831999-03-31031 March 1999
Monthly Operating Rept for Mar 1999 for Salem,Unit 2.With 990414 Ltr
ML18106B1471999-03-29029 March 1999
LER 99-001-00:on 990228,reactor Scram Was Noted as Result of Turbine Trip.Caused by Operator Error.Lesson Plans Revised to Explicitly Demonstrate Manner in Which Valve Functions. with 990329 Ltr
ML18106B1021999-02-28028 February 1999
Monthly Operating Rept for Feb 1999 for Salem Unit 2.With 990315 Ltr
ML18106B1011999-02-28028 February 1999
Monthly Operating Rept for Feb 1999 for Salem Unit 1.With 990315 Ltr
ML18106B0931999-02-25025 February 1999
Part 21 Rept Re Possible Defect in Swagelok Pipe Fitting Tee,Part Number SS-6-T.Caused by Crack Due to Improper Location of Heated Bar.Only One Part Out of 7396 Pieces in Forging Lot Was Found to Be Cracked.Affected Util,Notified
ML18106B0701999-02-16016 February 1999
LER 98-015-00:on 981208,inadvertent Discharge Through RHR Relief Valve During Startup Was Noted.Caused by Operator Performing Too Many Tasks Simultaneously.Appropriate Actions Have Been Taken IAW Policies & Procedures.With 990216 Ltr
ML18106B0551999-02-0101 February 1999
Part 21 Rept Re Possible Matl Defect in Swagelok Pipe Fitting Tee,Part Number SS-6-T.Defect Is Crack in Center of Forging.Analysis of Part Is Continuing & Further Details Will Be Provided IAW Ncr Timetables.Drawing of Part,Encl
ML18106B0561999-01-31031 January 1999
Monthly Operating Rept for Jan 1999 for Salem Generating Station,Unit 2.With 990212 Ltr
ML18106B0571999-01-31031 January 1999
Monthly Operating Rept for Jan 1999 for Salem Generating Station,Unit 1.With 990212 Ltr
ML20205P1671999-01-31031 January 1999
a POST-PLUME Phase, Federal Participation Exercise
ML18106B0441999-01-29029 January 1999
Part 21 Rept Re Possible Defect in Swagelok Pipe Fitting Tee Part Number SS-6-T.Caused by Crack in Center of Forging. Continuing Analysis of Part & Will Provide Details in Acoordance with NRC Timetables
ML18106B0491999-01-28028 January 1999
LER 98-007-01:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Caused by Transgranular Stress Corrosion Cracking.Replaced Affected Tubing.With 990128 Ltr
ML18106B0401999-01-18018 January 1999
LER 98-016-00:on 981219,ECCS Leakage Was Outside of Design Value.Caused by Leakage Past Seat of 21RH34 Manual Drain. Valve 21RH34 Was Reseated.With 990118 Ltr
ML18106B0251998-12-31031 December 1998
Monthly Operating Rept for Dec 1998 for Salem Unit 2.With 990115 Ltr
1999-09-30
[Table view] |
Text
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- Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station February 3, 1994 U. s. Nuclear Regulatory Commission Document Control Desk Washington-, DC 20555
Dear Sir:
SALEM GENERATING STATION LICENSE NO. DPR.,..70 DOCKET NO. 50-272 UNIT NO. 1 LICENSEE EVENT REPORT 94-001-00 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.
Sincerely yours,
//;* £//
tWJf/~"-
- c. A. Vondra General Manager -
' Salem Operations MJPJ:pc Distribution
~D4R021B0173 940203 S ADOCK 05000272 PDR rc"LL I II 95-2189 REV 7-92
--~- ------------------
NRC (5-92)
FOJ3M 366 . U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY-OMB NO. 3150-0104 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 1 05000 272 1 OF04 TITLE (4)
TS 3.0.3 Entries; More Than One Inoperable ARPI Per Bank.
EVENT DATE (5) LER NUMBER (6 REPORT NUMBER (7l OTHER FACILITIES INVOLVED (8)
SEQUENTIAL FACILITY NAME DOCKET NUMBER REVISION MONTH DAY YEAR YEAR MONTH DAY YEAR NUMBER NUMBER Salem Unit 2 05000 311 FACILITY NAME DOCKET NUMBER 01 05 94 -- -- 05000 94 001 00 02 03 94 OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR §: (Check one or more (11 l MODE (9) 2 20.402(b) 20,405(c) 50. 73(a)(2)(iv) 73.71(b)
POWEI=l 20.405(a)(1 )(i) 50.36(c) (1) 50. 73(a)(2)(v) 73.71 (c)
LEVEL (10) 000 20.405(a) (1) (ii) 50.36(c) (2) 50.73(a)(2)(vii) OTHER
.llii~1ll,I (Specify in Abstract 20.405(a) (1) (iii) x 50.73(a)(2)(i) 50. 73(a)(2)(viii)(A) below and in Tex1, 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 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 REPORTl13l REPORTABLE REPORTABLE CAUSE SYSTEM COMPONENT MANUFACTURER CAUSE SYSTEM COMPONENT MANUFACTURER TO NPRDS TO NPRDS SUPPLEMENTAL REPORT EXPECTED (14) EXPECTED MONTH DAY YEAR YES SUBMISSION NO (If yes, complete EXPECTED SUBMISSION DATE) x DATE (15)
ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16)
-
Intentional Technical Specification (TS) 3.0.3 entries were made: for Unit 2 on 1/5/94, from 1637 to 1642 hours0.019 days <br />0.456 hours <br />0.00271 weeks <br />6.24781e-4 months <br />, and on 1/16/94, fr_om 0037 to 0045 hours5.208333e-4 days <br />0.0125 hours <br />7.440476e-5 weeks <br />1.71225e-5 months <br />, and for Unit 1 on 1/24/94, from 2215 to 2245 hours0.026 days <br />0.624 hours <br />0.00371 weeks <br />8.542225e-4 months <br />.
This was done to permit calibrating the respective Analog Rod Position Indicator (ARP!) control Board dual indicator modules for Unit 2 control rods 2B4 and 1D2 and for Unit 1 control rods 2Al and 2B2.
Calibrating the indicators required removing the dual indicator modules, which rendered ARP! for subject rods and for the rods sharing the same module inoperable: 2B3 and lDl (Unit 2)* and 2A2 and 2Bl (Unit 1). In each case, actual rod positions (per group demand) were correct. The root cause of these events is design of ARP!
position.indicators requiring entering TS 3.0.3 whenever ARP!
calibrations are performed. The subject position indicators were calibrated and TS 3.0.3 was exited. A Night Order Book (NOB) entry was made, on 1/27/94, to provide guidance/restrictions for ARP! Dixon indicator calibrations and TS 3.0.3 entries. An Information Directive will be issued to formalize the 1/27/94 NOB entry.
NRG FORM 366 (5-92)
-*
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating station DOCKET NUMBER LER NUMBER PAGE.
Unit 1 5000272 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 On Both Salem Units; More Than One Inoperable Analog Rod Position Indicator (ARPI) Per Bank Event Dates: (Unit 2) 1/5/94 and 1/16/94 (Unit 1) 1/24/94 Report Date: 2/3/94 This report was initiated by Incident Report Nos.94-006, 94-019 and 94-028.
CONDITIONS PRIOR TO OCCURRENCE:
(Unit 2) 1/5/94: Mode 1 Reactor Power 34% Unit Load - 300 MWe 1/16/94: Mode 1 Reactor Power 100% Unit Load - 1180 MWe (Unit 1) Mode 2 Reactor Power lOE-8 Amps Unit Load -o-DESCRIPTION OF OCCURRENCES:
Intentional TS 3.0.3 entries were made: for Unit 2 on January 5, 1994, from.1637 to 1642 hours0.019 days <br />0.456 hours <br />0.00271 weeks <br />6.24781e-4 months <br />, and on January 16, 1994, from 0037 to 0045 hours5.208333e-4 days <br />0.0125 hours <br />7.440476e-5 weeks <br />1.71225e-5 months <br />, and for Unit 1 on January 24, 1994, from 2215 to 2245 hours0.026 days <br />0.624 hours <br />0.00371 weeks <br />8.542225e-4 months <br />.
This was done to permit calibrating the respective ARPI {AA} Control Board dual indicator modules for Unit 2 control rods 2B4 and 1D2 and fo~ Unit 1 control rods 2Al and 2B2. The calibration process rendered ARPI inoperable for the subject rods and for the rods sharing the same dual indicator module: Unit 2 rods 2B3 and lDl and Unit 1 rods 2A2 and
- 2Bl. In *each case, actual rod positions (per group demand) were correct.
ANALYSIS OF OCCURRENCES:
ARPI operability is required to determine individual control* rod position and ensure compiiance with control rod alignment and insertion limits assumed in the accident analyses. ARPI 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 computer,.and iocally via the digital multimeter (DMM) ._
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 - - 5000272 94-001-00 3 of *4 ANALYSIS OF OCCURRENCES: (cont'd)
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 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. o. 3 therefore applies. -
On January 5th, 16th, and 24th, TS 3.0.3 was intentionally entered to allow calibrating the respective ARPI Dixon dual position indicators for control rods 2B4 and 1D2 (Unit 2) and for 2Al anci 2B2 (Unit 1).
Calibrating the indicators required removing the dual indicator modules, which rendered the ARP! for subject rods and for the rods sharing the same module inoperable:- 2B3 and lDl (Unit 2) and 2A2 and 2Bl (Unit 1). In each case, actual rod positions (per group demand) were correct. The indicators were then calibrated, ARP! for the affected control rods was restored, and in each case TS 3.0.3 was exited. -
APPARENT CAUSE OF .OCCURRENCES:
The root cause of these events is "Design, Manufacturing, Construction/Installation", per NUREG-1022. Design of ARPI position indication is such that two rods share each Dixon indicator module.
Consequently, TS 3.0.3 is entered whenever the ARP! position indicator
- modules are removed from service for calibration.
PRIOR SIMILAR OCCURRENCES:
Prior events requiring TS 3.0.3 entry, due to ARP! control rod design concerns, have occurred on both Salem Units, as reported in LERs
- 272/93-007-00, 311/92-016-00, and 311/93-010-00. As a result of these events, 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 the vendors will be used to develop appropriate action. -
SAFETY SIGNIFICANCE:
These events did not affect the health and safety of the public. With entry into TS 3.0.3, these events are reportable to the NRC pursuant to Code of Federal Regulations lOCFR 50.73(a) (2) (i) (B).
TS required actions were met for these events. In each case, actual rod positions (per group demand) were correct, with only the Control Board indication wrong. Verification of position was available via the SPDS, the P250 computer, and local DMM.
. LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 94-001-00 4 of 4 CORRECTIVE ACTION:
The position indicators of the affected rods were calibrated and TS 3.0.3 was exited.
A Night Order Book (NOB) entry was made, on January 27, 1994, to provide guidance/restrictions for ARPI Dixon indicator calibrations and TS 3.0.3 entries.
An Information Directive will be issued to formalize the above-referenced NOB entry.
PSE&G will continue to participate in the industry Rod Control User's Group efforts to resolve the industry-wide problem with ARPI System drift. ,/} ~~ ~
/
/*~ ~~
/)t?f!~~' ,i_
I General Manager -
Salem Operations MJPJ:pc SORC Mtg.94-011
