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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:CPS~~ |
| | * Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station August 31, 1992 |
| | : 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 92-017-00 August 31, 1992 This Licensee Event Report is being submitted pursuant to the requirements of the Code of Federal Regulations lOCFR 50.73(a) (2) (iv). This report is required to be issued within thirty (30) days of event discovery. | | |
| MJP:pc Distribution 030020 The Energy People 9209030188 920831 PDR ADOCK 05000272 S PDR Sincerely yours, C. A Vondra General Manager -Salem Operations 95-2189 (10M) 12-89 NRC FORM 366 ! (6-89) .. U.S. NUCLEAR REGULATORY COMMISSION APPROVED OMB NO. 3150-0104 EXPIRES: 4/30/92 LICENSEE EVENT REPORT (LER) ESTIMATED BURDEN PER RESPONSE TO COMPLY WTH THIS INFORMATION COLLECTION REQUEST: 50.0 HRS. FORWARD COMMENTS REGARDING BURDEN ESTIMATE TO THE RECORDS AND REPORTS MANAGEMENT BRANCH (P-530), U.S. NUCLEAR REGULATORY COMMISSION, WASHINGTON, DC 20555, AND TO THE PAPERWORK REDUCTION PROJECT (3150-0104), OFFICE OF MANAGEMENT AND BUDGET, WASH.INGTON, DC 20503. F4CILITV N4ME 111 r..on.,.r>>t-in" S+-<>+-;nn
| | SALEM GENERATING STATION LICENSE NO. DPR-70 DOCKET NO. 50-272 UNIT NO. 1 LICENSEE EVENT REPORT 92-017-00 This Licensee Event Report is being submitted pursuant to the requirements of the Code of Federal Regulations 10CFR 50.73(a) (2) (iv). This report is required to be issued within thirty (30) days of event discovery. |
| -IJnit-. 1 I DOCKET NUMBER 12) I 1'4GE I 11 0 15 I 0 I 0 I 0 I 217 I 1 loF al 3 TITLE 141 ... .. | | Sincerely yours, C. A Vondra General Manager - |
| actuation: | | Salem Operations MJP:pc Distribution 030020 The Energy People 9209030188 920831 95-2189 (10M) 12-89 PDR ADOCK 05000272 S PDR |
| main steamline isolation due to desiqn. EVENT DATE 151 LER NUMBER 16) REPORT DATE (71 OTHER FACILITIES INVOLVED CBI MONTH DAY VEAR VEAR | | |
| )} | | NRC FORM 366 ! U.S. NUCLEAR REGULATORY COMMISSION (6-89) .. APPROVED OMB NO. 3150-0104 EXPIRES: 4/30/92 ESTIMATED BURDEN PER RESPONSE TO COMPLY WTH THIS INFORMATION COLLECTION REQUEST: 50.0 HRS. FORWARD LICENSEE EVENT REPORT (LER) COMMENTS REGARDING BURDEN ESTIMATE TO THE RECORDS AND REPORTS MANAGEMENT BRANCH (P-530), U.S. NUCLEAR REGULATORY COMMISSION, WASHINGTON, DC 20555, AND TO THE PAPERWORK REDUCTION PROJECT (3150-0104), OFFICE OF MANAGEMENT AND BUDGET, WASH.INGTON, DC 20503. |
| }) | | I F4CILITV N4ME 111 DOCKET NUMBER 12) I 1'4GE I 11 eo~1~- r..on.,.r>>t-in" S+-<>+-;nn - IJnit-. 1 0 15 I 0 I 0 I 0 I 217 I ~ 1 loF al 3 TITLE 141 F.nninoo~on a~~ ... ~ .. *~A>>rnrA ~;nnal actuation: main steamline isolation due to desiqn. |
| MONTH DAV VEAR FACILITY NAMES DOCKET NUMBER(SI OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE Rl:QUIREMENTS OF 10 CFR §: (Check ono or more of the following} | | EVENT DATE 151 LER NUMBER 16) REPORT DATE (71 OTHER FACILITIES INVOLVED CBI MONTH DAY VEAR VEAR )} sez~~~~~AL }) ~~~~~~ MONTH DAV VEAR FACILITY NAMES DOCKET NUMBER(SI OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE Rl:QUIREMENTS OF 10 CFR §: (Check ono or more of the following} 1111 |
| 1111 ---M-OD_E_ | | __._.4.....i - - l .x 60.731oll2llivl I ....__ 20.406Ccl 73.71Cbl |
| ** _, _ __._.4 ..... i--l 20.402Cbl 20.406Ccl .x 60.731oll2llivl 73.71Cbl ....__ -&0.38Ccl111 60.731oll2lM 73.71Ccl ....__ --50.38lcll2) 60.73l*ll211viil OTHER ISPt!cify in Absrr*ct POWER I 20.406C*ll1lll)
| | ---M-OD_E_** _,_ 20.402Cbl |
| I I -20.4051*11111111 ............................................
| | ....__ &0.38Ccl111 60.731oll2lM |
| ----1 1111111ilil= | | - 73.71Ccl POWER L~~~L I I - |
| :::::::::;:
| | 20.406C*ll1lll) 20.4051*11111111 ....__ 50.38lcll2) |
| ....__ --b*low *nd in Tt1xr. NRC Form 50.73Coll2llil 60.731oll21CviiillAI 366AJ ....__ -&0.73Coll2lliil ll0.73Coll2llvllil1Bl | | - 60.73l*ll211viil |
| ,__ -60.73l*ll2lliii) 60.731oll21Cxl LICENSEE CONTACT FOR THIS LER 112) NAME TELEPHONE NUMBER AREA CODE M .T 'Dl"ll 1 ,,,..,. -
| | - OTHER ISPt!cify in Absrr*ct |
| rnnrdinat:Or 610 I 9 3 13 I 91-12 I 0 12 12 CAUSE SYSTEM COMPONENT I I I I I I I I COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT 113) MANUFAC* TUR ER I I I I I I CAUSE SYSTEM I I COMPONENT MANUFAC* TUR ER I I I I I I I I I I I I SUPPLEMENTAL REPORT EXPECTED 114) MONTH DAV VEAR n YES (If y11, compl*r. EXPECTED SUBMISSION DATE} EXPECTED SUBMISSION DATE 1151 rx-i NO I I ABSTRACT (Limit to 1400 1poce1, i.* .* *pproxim*tely fifr.*n 1ingle-1poc* | | ~ ............................................----1 |
| typewrimn lined 116) On July 30 1992, at 1600 hours, a main steamline isolation (MSI) occurred on a low T (< 543°F) coincident with high steamline flow signal | | ....__ 50.73Coll2llil |
| * Iii v g during The plant had entered Mode 4 at 1146 hours on July 30, 1992. MSI is an Engineered Safety Feature (ESF). In Mode 4, Reactor Coolant System T ranges from 200°F to 350°F (actual temperature was therefore, the low T bistables are tripped providing half of the logic required The high steamline flow logic requires high flow indication in one (1) of two (2) channels per Steam Generator (S/G) in two (2) of the four (4) S/Gs. The MSI occurred when the steamline flow channel bistables tripped for several S/Gs. The root of this event is "Design, Manufacturing, Construc:t.ion/Installation" inadequacy.
| | - 60.731oll21CviiillAI |
| With the plant in Mode 4, condensation occurs in the steamline flow reference legs resulting in channel spikes. This occurred coincidently in several S/G channels satisfying the logic for MSI. Salem Units 1 and 2 have experienced similar MSI actuations (e.g., reference LERs 272/91-031-00 and 311/92-008-01). | | - b*low *nd in Tt1xr. NRC Form 366AJ 1111111ilil= :::::::::;: ,__ &0.73Coll2lliil 60.73l*ll2lliii) |
| An in-depth study was completed. | | LICENSEE CONTACT FOR THIS LER 112) ll0.73Coll2llvllil1Bl 60.731oll21Cxl NAME TELEPHONE NUMBER AREA CODE M .T 'Dl"ll 1 ,,,..,. - T.F.~ rnnrdinat:Or 610 I 9 3 13 I 91- 12 I 0 12 12 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT 113) |
| Engineering is developing design modifications to correct the main steamline flow sensing line concerns. | | MANUFAC* MANUFAC* |
| NRC Form 386 I | | CAUSE SYSTEM COMPONENT CAUSE SYSTEM COMPONENT TUR ER TUR ER I I I I I I I I I I I I I I I I I I I I I I I I I I I I SUPPLEMENTAL REPORT EXPECTED 114) MONTH DAV VEAR EXPECTED n |
| *
| | SUBMISSION YES (If y11, compl*r. EXPECTED SUBMISSION DATE} |
| * LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 1 DOCKET NUMBER 5000272 PLANT AND SYSTEM IDENTIFICATION: | | ABSTRACT (Limit to 1400 1poce1, i.*.* *pproxim*tely fifr.*n 1ingle-1poc* typewrimn lined 116) rx-i NO DATE 1151 I I I On July 30 1992, at 1600 hours, a main steamline isolation (MSI) occurred on a* low TIii v g (< 543°F) coincident with high steamline flow signal during hea~up. The plant had entered Mode 4 at 1146 hours on July 30, 1992. MSI is an Engineered Safety Feature (ESF). In Mode 4, Reactor Coolant System T ranges from 200°F to 350°F (actual temperature was approximatelyv~50°F); therefore, the low T 9 bistables are tripped providing half of the logic required f~~ MSI. The high steamline flow logic requires high flow indication in one (1) of two (2) channels per Steam Generator (S/G) in two (2) of the four (4) S/Gs. The MSI occurred when the steamline flow channel bistables tripped for several S/Gs. The root caus~ of this event is "Design, Manufacturing, Construc:t.ion/Installation" inadequacy. With the plant in Mode 4, condensation occurs in the steamline flow reference legs resulting in channel spikes. This occurred coincidently in several S/G channels satisfying the logic for MSI. Salem Units 1 and 2 have experienced similar MSI actuations (e.g., reference LERs 272/91-031-00 and 311/92-008-01). An in-depth study was completed. Engineering is developing design modifications to correct the main steamline flow sensing line concerns. |
| Westinghouse | | NRC Form 386 1~91 |
| -Pressurized Water Reactor LER NUMBER 92-017-00 PAGE 2 of 3 Energy Industry Identification System (EIIS) codes are identified in the text as {xx} IDENTIFICATION OF OCCURRENCE: | | |
| Engineered Safety Feature signal actuation: | | Salem Generating Station |
| main steamline isolation due to design Event Date: Report Date: 7/30/92 8/31/92 This report was initiated by Incident Report No. 92-475. CONDITIONS PRIOR TO OCCURRENCE: | | * DOCKET NUMBER LICENSEE EVENT REPORT (LER) TEXT CONTINUATION LER NUMBER PAGE Unit 1 5000272 92-017-00 2 of 3 PLANT AND SYSTEM IDENTIFICATION: |
| Mode 4 (Hot Shutdown) | | Westinghouse - Pressurized Water Reactor Energy Industry Identification System (EIIS) codes are identified in the text as {xx} |
| | IDENTIFICATION OF OCCURRENCE: |
| | Engineered Safety Feature signal actuation: main steamline isolation due to design Event Date: 7/30/92 Report Date: 8/31/92 This report was initiated by Incident Report No. 92-475. |
| | CONDITIONS PRIOR TO OCCURRENCE: |
| | Mode 4 (Hot Shutdown) |
| DESCRIPTION OF OCCURRENCE: | | DESCRIPTION OF OCCURRENCE: |
| On July 30 1992, at 1600 hours, a main steamline isolation (MSI) occurred on low T (< 543°F) coincident with high steamline flow signal during healtip. The plant had entered Mode 4 at 1146 hours on July 30, 1992. In Mode 4, Reactor Coolant system T ranges from 200°F to 350°F (actual temperature was approximately 9 250°F); therefore, the low T bistables are tripped providing half of the logic required for MSI:vg The high steamline flow logic requires high flow indication in one (1) of two (2) channels per Steam Generator (S/G) in two (2) of the four (4) S/Gs. The MSI occurred when the steamline flow channel bistables tripped for several S/Gs. MSI is an Engineered Safety Feature (ESF). Therefore, on July 30, 1992, at 1750 hours, this event was reported to the Nuclear Regulatory Commission (NRC) in accordance with Code of Federal Regulations lOCFR 50. 72 (b) (2) (ii). APPARENT CAUSE OF OCCURRENCE: | | On July 30 1992, at 1600 hours, a main steamline isolation (MSI) occurred on low T (< 543°F) coincident with high steamline flow signal during healtip. The plant had entered Mode 4 at 1146 hours on July 30, 1992. |
| | In Mode 4, Reactor Coolant system T ranges from 200°F to 350°F 9 |
| | (actual temperature was approximately 250°F); therefore, the low T bistables are tripped providing half of the logic required for MSI:vg The high steamline flow logic requires high flow indication in one (1) of two (2) channels per Steam Generator (S/G) in two (2) of the four (4) S/Gs. The MSI occurred when the steamline flow channel bistables tripped for several S/Gs. |
| | MSI is an Engineered Safety Feature (ESF). Therefore, on July 30, 1992, at 1750 hours, this event was reported to the Nuclear Regulatory Commission (NRC) in accordance with Code of Federal Regulations 10CFR |
| | : 50. 72 (b) (2) (ii). |
| | APPARENT CAUSE OF OCCURRENCE: |
| The root cause of this event is "Design, Manufacturing, Construction/ | | The root cause of this event is "Design, Manufacturing, Construction/ |
| Installation" inadequacy. | | Installation" inadequacy. With the plant in Mode 4, condensation occurs in the steamline flow reference legs resulting in channel spikes. This occurred coincidently in several S/G channels satisfying the logic for MSI. Salem Units 1 and 2 have experienced similar MSI actuations (e.g., reference LERs 272/91-031-00 and 311/92-008-01). |
| With the plant in Mode 4, condensation occurs in the steamline flow reference legs resulting in channel spikes. This occurred coincidently in several S/G channels satisfying the logic for MSI. Salem Units 1 and 2 have experienced similar MSI actuations (e.g., reference LERs 272/91-031-00 and 311/92-008-01). | | Assessment of this event, by Maintenance personnel, concluded that the false high steam flow signals were not caused by failed components. |
| Assessment of this event, by Maintenance personnel, concluded that the false high steam flow signals were not caused by failed components. | | |
| "" . . * | | "" . . ~ |
| * LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 1 DOCKET NUMBER 5000272 LER NUMBER 92-017-00 PAGE 3 of 3 APPARENT CAUSE OF OCCURRENCE: (cont'd) The false signals cleared, on their own, after a few hours. Channel functional tests of the main steamline flow instrumentation were successfully completed.
| | LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 92-017-00 3 of 3 APPARENT CAUSE OF OCCURRENCE: (cont'd) |
| The Salem design arrangement for main steamline flow differential pressure measurement includes two (2) taps (to provide redundancy) on the high and low pressure side of the main steamline venturi. Attached to the taps are 1 11 manual globe valves. Steam is directed through 1 11 pipe to condensate pots located near the high pressure tap. Condensate is then directed to a Rosemount model 1153HD5 differential pressure transmitter via a 3/8" line. ANALYSIS OF OCCURRENCE: | | The false signals cleared, on their own, after a few hours. Channel functional tests of the main steamline flow instrumentation were successfully completed. |
| MSI protection is applicable in Mode 1 (Power Operation), Mode 2 (Startup), and Mode 3 (Hot Standby). | | The Salem design arrangement for main steamline flow differential pressure measurement includes two (2) taps (to provide redundancy) on the high and low pressure side of the main steamline venturi. |
| It is provided to mitigate the consequences of various design base accidents including main steamline rupture and steam generator primary to secondary tube rupture. In Mode 4, the reactor is subcritical with T between o o , , avg ' 200 F and 350 F. Decay heat is removed either by the Residual Heat Removal (RHR) System {BP} or steaming from the steam generators. | | Attached to the taps are 1 11 manual globe valves. Steam is directed through 1 11 pipe to condensate pots located near the high pressure tap. Condensate is then directed to a Rosemount model 1153HD5 differential pressure transmitter via a 3/8" line. |
| Makeup water to the S/Gs can be supplied by either a Condensate Pump or by an Auxiliary Feedwater Pump. At the time of the actuation, decay heat removal was being accomplished using the RHR System. All valves which close on an MSI signal were already closed. | | ANALYSIS OF OCCURRENCE: |
| * Since the actuation was not the result of an actual plant need for Main Steam Isolation, this event did not affect the health or safety of the public. However, since Main steam Isolation is an ESF system, this event is reportable to the Nuclear Regulatory Commission in accordance with Code of Federal Regulations 10CFR50. 73 (a) (2) (iv). CORRECTIVE ACTION: As identified in Salem Unit 1 LER 272/91-031-00 and Salem Unit 2 LER 311/92-008-01, main steamline flow instrumentation was being assessed. | | MSI protection is applicable in Mode 1 (Power Operation), Mode 2 (Startup), and Mode 3 (Hot Standby). It is provided to mitigate the consequences of various design base accidents including main steamline rupture and steam generator primary to secondary tube rupture. |
| An in-depth study was completed. | | In Mode o |
| Engineering is developing design modifications to correct the main steamline flow sensing line concerns. | | 4, the o reactor is subcritical with, Tavg between ' |
| | 200 F and 350 F. Decay heat is removed either by the Residual Heat Removal (RHR) System {BP} or steaming from the steam generators. |
| | Makeup water to the S/Gs can be supplied by either a Condensate Pump or by an Auxiliary Feedwater Pump. |
| | At the time of the actuation, decay heat removal was being accomplished using the RHR System. All valves which close on an MSI signal were already closed. |
| | * Since the actuation was not the result of an actual plant need for Main Steam Isolation, this event did not affect the health or safety of the public. However, since Main steam Isolation is an ESF system, this event is reportable to the Nuclear Regulatory Commission in accordance with Code of Federal Regulations 10CFR50. 73 (a) (2) (iv). |
| | CORRECTIVE ACTION: |
| | As identified in Salem Unit 1 LER 272/91-031-00 and Salem Unit 2 LER 311/92-008-01, main steamline flow instrumentation was being assessed. An in-depth study was completed. Engineering is developing design modifications to correct the main steamline flow sensing line concerns. |
| MJP:pc SORC Mtg. 92-096}} | | MJP:pc SORC Mtg. 92-096}} |
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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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CPS~~
- Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station August 31, 1992
- 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 92-017-00 This Licensee Event Report is being submitted pursuant to the requirements of the Code of Federal Regulations 10CFR 50.73(a) (2) (iv). This report is required to be issued within thirty (30) days of event discovery.
Sincerely yours, C. A Vondra General Manager -
Salem Operations MJP:pc Distribution 030020 The Energy People 9209030188 920831 95-2189 (10M) 12-89 PDR ADOCK 05000272 S PDR
NRC FORM 366 ! U.S. NUCLEAR REGULATORY COMMISSION (6-89) .. APPROVED OMB NO. 3150-0104 EXPIRES: 4/30/92 ESTIMATED BURDEN PER RESPONSE TO COMPLY WTH THIS INFORMATION COLLECTION REQUEST: 50.0 HRS. FORWARD LICENSEE EVENT REPORT (LER) COMMENTS REGARDING BURDEN ESTIMATE TO THE RECORDS AND REPORTS MANAGEMENT BRANCH (P-530), U.S. NUCLEAR REGULATORY COMMISSION, WASHINGTON, DC 20555, AND TO THE PAPERWORK REDUCTION PROJECT (3150-0104), OFFICE OF MANAGEMENT AND BUDGET, WASH.INGTON, DC 20503.
I F4CILITV N4ME 111 DOCKET NUMBER 12) I 1'4GE I 11 eo~1~- r..on.,.r>>t-in" S+-<>+-;nn - IJnit-. 1 0 15 I 0 I 0 I 0 I 217 I ~ 1 loF al 3 TITLE 141 F.nninoo~on a~~ ... ~ .. *~A>>rnrA ~;nnal actuation: main steamline isolation due to desiqn.
EVENT DATE 151 LER NUMBER 16) REPORT DATE (71 OTHER FACILITIES INVOLVED CBI MONTH DAY VEAR VEAR )} sez~~~~~AL }) ~~~~~~ MONTH DAV VEAR FACILITY NAMES DOCKET NUMBER(SI OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE Rl:QUIREMENTS OF 10 CFR §: (Check ono or more of the following} 1111
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LICENSEE CONTACT FOR THIS LER 112) ll0.73Coll2llvllil1Bl 60.731oll21Cxl NAME TELEPHONE NUMBER AREA CODE M .T 'Dl"ll 1 ,,,..,. - T.F.~ rnnrdinat:Or 610 I 9 3 13 I 91- 12 I 0 12 12 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT 113)
MANUFAC* MANUFAC*
CAUSE SYSTEM COMPONENT CAUSE SYSTEM COMPONENT TUR ER TUR ER I I I I I I I I I I I I I I I I I I I I I I I I I I I I SUPPLEMENTAL REPORT EXPECTED 114) MONTH DAV VEAR EXPECTED n
SUBMISSION YES (If y11, compl*r. EXPECTED SUBMISSION DATE}
ABSTRACT (Limit to 1400 1poce1, i.*.* *pproxim*tely fifr.*n 1ingle-1poc* typewrimn lined 116) rx-i NO DATE 1151 I I I On July 30 1992, at 1600 hours0.0185 days <br />0.444 hours <br />0.00265 weeks <br />6.088e-4 months <br />, a main steamline isolation (MSI) occurred on a* low TIii v g (< 543°F) coincident with high steamline flow signal during hea~up. The plant had entered Mode 4 at 1146 hours0.0133 days <br />0.318 hours <br />0.00189 weeks <br />4.36053e-4 months <br /> on July 30, 1992. MSI is an Engineered Safety Feature (ESF). In Mode 4, Reactor Coolant System T ranges from 200°F to 350°F (actual temperature was approximatelyv~50°F); therefore, the low T 9 bistables are tripped providing half of the logic required f~~ MSI. The high steamline flow logic requires high flow indication in one (1) of two (2) channels per Steam Generator (S/G) in two (2) of the four (4) S/Gs. The MSI occurred when the steamline flow channel bistables tripped for several S/Gs. The root caus~ of this event is "Design, Manufacturing, Construc:t.ion/Installation" inadequacy. With the plant in Mode 4, condensation occurs in the steamline flow reference legs resulting in channel spikes. This occurred coincidently in several S/G channels satisfying the logic for MSI. Salem Units 1 and 2 have experienced similar MSI actuations (e.g., reference LERs 272/91-031-00 and 311/92-008-01). An in-depth study was completed. Engineering is developing design modifications to correct the main steamline flow sensing line concerns.
NRC Form 386 1~91
Salem Generating Station
- DOCKET NUMBER LICENSEE EVENT REPORT (LER) TEXT CONTINUATION LER NUMBER PAGE Unit 1 5000272 92-017-00 2 of 3 PLANT AND SYSTEM IDENTIFICATION:
Westinghouse - Pressurized Water Reactor Energy Industry Identification System (EIIS) codes are identified in the text as {xx}
IDENTIFICATION OF OCCURRENCE:
Engineered Safety Feature signal actuation: main steamline isolation due to design Event Date: 7/30/92 Report Date: 8/31/92 This report was initiated by Incident Report No.92-475.
CONDITIONS PRIOR TO OCCURRENCE:
Mode 4 (Hot Shutdown)
DESCRIPTION OF OCCURRENCE:
On July 30 1992, at 1600 hours0.0185 days <br />0.444 hours <br />0.00265 weeks <br />6.088e-4 months <br />, a main steamline isolation (MSI) occurred on low T (< 543°F) coincident with high steamline flow signal during healtip. The plant had entered Mode 4 at 1146 hours0.0133 days <br />0.318 hours <br />0.00189 weeks <br />4.36053e-4 months <br /> on July 30, 1992.
In Mode 4, Reactor Coolant system T ranges from 200°F to 350°F 9
(actual temperature was approximately 250°F); therefore, the low T bistables are tripped providing half of the logic required for MSI:vg The high steamline flow logic requires high flow indication in one (1) of two (2) channels per Steam Generator (S/G) in two (2) of the four (4) S/Gs. The MSI occurred when the steamline flow channel bistables tripped for several S/Gs.
MSI is an Engineered Safety Feature (ESF). Therefore, on July 30, 1992, at 1750 hours0.0203 days <br />0.486 hours <br />0.00289 weeks <br />6.65875e-4 months <br />, this event was reported to the Nuclear Regulatory Commission (NRC) in accordance with Code of Federal Regulations 10CFR
- 50. 72 (b) (2) (ii).
APPARENT CAUSE OF OCCURRENCE:
The root cause of this event is "Design, Manufacturing, Construction/
Installation" inadequacy. With the plant in Mode 4, condensation occurs in the steamline flow reference legs resulting in channel spikes. This occurred coincidently in several S/G channels satisfying the logic for MSI. Salem Units 1 and 2 have experienced similar MSI actuations (e.g., reference LERs 272/91-031-00 and 311/92-008-01).
Assessment of this event, by Maintenance personnel, concluded that the false high steam flow signals were not caused by failed components.
"" . . ~
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 92-017-00 3 of 3 APPARENT CAUSE OF OCCURRENCE: (cont'd)
The false signals cleared, on their own, after a few hours. Channel functional tests of the main steamline flow instrumentation were successfully completed.
The Salem design arrangement for main steamline flow differential pressure measurement includes two (2) taps (to provide redundancy) on the high and low pressure side of the main steamline venturi.
Attached to the taps are 1 11 manual globe valves. Steam is directed through 1 11 pipe to condensate pots located near the high pressure tap. Condensate is then directed to a Rosemount model 1153HD5 differential pressure transmitter via a 3/8" line.
ANALYSIS OF OCCURRENCE:
MSI protection is applicable in Mode 1 (Power Operation), Mode 2 (Startup), and Mode 3 (Hot Standby). It is provided to mitigate the consequences of various design base accidents including main steamline rupture and steam generator primary to secondary tube rupture.
In Mode o
4, the o reactor is subcritical with, Tavg between '
200 F and 350 F. Decay heat is removed either by the Residual Heat Removal (RHR) System {BP} or steaming from the steam generators.
Makeup water to the S/Gs can be supplied by either a Condensate Pump or by an Auxiliary Feedwater Pump.
At the time of the actuation, decay heat removal was being accomplished using the RHR System. All valves which close on an MSI signal were already closed.
- Since the actuation was not the result of an actual plant need for Main Steam Isolation, this event did not affect the health or safety of the public. However, since Main steam Isolation is an ESF system, this event is reportable to the Nuclear Regulatory Commission in accordance with Code of Federal Regulations 10CFR50. 73 (a) (2) (iv).
CORRECTIVE ACTION:
As identified in Salem Unit 1 LER 272/91-031-00 and Salem Unit 2 LER 311/92-008-01, main steamline flow instrumentation was being assessed. An in-depth study was completed. Engineering is developing design modifications to correct the main steamline flow sensing line concerns.
MJP:pc SORC Mtg.92-096
