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| | issue date = 01/15/1996 | | | issue date = 01/15/1996 |
| | title = LER 95-008-00:on 951215,Tech Spec 4.9.9 Missed Isolation Testing Discovered.Caused by Lack of Adequate Controls to Ensure All Testing Requirements Addressed.Procedure S2.IC-FT.RM--0088(Q) revised.W/960115 Ltr | | | title = LER 95-008-00:on 951215,Tech Spec 4.9.9 Missed Isolation Testing Discovered.Caused by Lack of Adequate Controls to Ensure All Testing Requirements Addressed.Procedure S2.IC-FT.RM--0088(Q) revised.W/960115 Ltr |
| | author name = GREENLEE S, WARREN C | | | author name = Greenlee S, Warren C |
| | author affiliation = PUBLIC SERVICE ELECTRIC & GAS CO. OF NEW JERSEY | | | author affiliation = PUBLIC SERVICE ELECTRIC & GAS CO. OF NEW JERSEY |
| | addressee name = | | | addressee name = |
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| =Text= | | =Text= |
| {{#Wiki_filter:e "' C/;; | | {{#Wiki_filter:e C/; |
| ' | | ~ |
| * & Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038-0236 Nuclear Business Unit JAN 1 5 1996 LR-N96006 | | ~'ffe.I |
| | * PS~G- "' |
| | Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038-0236 Nuclear Business Unit JAN 1 5 1996 LR-N96006 |
| : u. S. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 Gentlemen: | | : u. S. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 Gentlemen: |
| LER 311/95-008 SALEM GENERATING STATION -UNIT 2 FACILITY OPERATING LICENSE NO. DPR-75 DOCKET NO. 50-311 This License Event Report entitled "Technical Specification | | LER 311/95-008 SALEM GENERATING STATION - UNIT 2 FACILITY OPERATING LICENSE NO. DPR-75 DOCKET NO. 50-311 This License Event Report entitled "Technical Specification 4.9.9 Missed Isolation Initiation Testing'' is being submitted pursuant to the requirements of the Code of Federal Regulations 10 CFR5 0 . 7 3 (a) ( 2 ) ( i) ( b) . |
| | S&reJuu_ |
| | Cla?warren * - |
| | General Manager - |
| | Salem Operations Attachment SORC Mtg. 96-004 JEH/tcp C Distribution LER File 3.7 190<!29 9601190424 960115 PDR ADOCK 05000311 S PDR 95-2168 REV. 6/94 |
|
| |
|
| ====4.9.9 Missed====
| | Attachment A The following items represent commitments that Public Service Electric & Gas (PSE&G) made to the Nuclear Regulatory Commission (NRC) relative to this LER (311/95-008-00) . The commitments are as follows: |
| Isolation Initiation Testing''
| | : 1. A task specific procedure for Unit 1 will be developed to address all the requirements of Technical Specification 4.9.9. This will be completed prior to core alterations on Unit 1. |
| is being submitted pursuant to the requirements of the Code of Federal Regulations 10 CFR5 0 . 7 3 (a) ( 2 ) ( i) ( b) . Attachment SORC Mtg. 96-004 JEH/tcp C Distribution LER File 3.7 190<!29 9601190424 960115 PDR ADOCK 05000311 S PDR S&reJuu_ Cla?warren
| | : 2. A Technical Specification Surveillance Improvement Project (TSSIP) has been initiated for Salem station. As part of the TSSIP, a review will be performed to ensure that each Technical Specification surveillance requirement is adequately proceduralized. The review will be completed in two stages. The first stage will involve verification that each Technical Specification surveillance requirement has an associated procedure which is listed in the Technical Specification matrix. These reviews will be prioritized such that Mode change requirements are verified prior to the applicable Mode change. Administrative processes will also be revised, as necessary, to ensure adequate controls are established for the revision of Technical Specification surveillance procedures. The first stage of the TSSIP will be complete prior to unit restart. The second stage of the TSSIP will, with exceptions, involve validation of the technical accuracy of the Technical Specification surveillance procedures. The exceptions will include inservice testing and inspection procedures, snubber inspection procedures and any procedures that will change significantly when Improved Technical Specifications are implemented. The second stage of the TSSIP is expected to be completed during 1997. |
| * -General Manager -Salem Operations 95-2168 REV. 6/94 Attachment A The following items represent commitments that Public Service Electric & Gas (PSE&G) made to the Nuclear Regulatory Commission (NRC) relative to this LER (311/95-008-00) . The commitments are as follows: 1. A task specific procedure for Unit 1 will be developed to address all the requirements of Technical Specification 4.9.9. This will be completed prior to core alterations on Unit 1. 2. A Technical Specification Surveillance Improvement Project (TSSIP) has been initiated for Salem station. As part of the TSSIP, a review will be performed to ensure that each Technical Specification surveillance requirement is adequately proceduralized.
| |
| The review will be completed in two stages. The first stage will involve verification that each Technical Specification surveillance requirement has an associated procedure which is listed in the Technical Specification matrix. These reviews will be prioritized such that Mode change requirements are verified prior to the applicable Mode change. Administrative processes will also be revised, as necessary, to ensure adequate controls are established for the revision of Technical Specification surveillance procedures. | |
| The first stage of the TSSIP will be complete prior to unit restart. The second stage of the TSSIP will, with exceptions, involve validation of the technical accuracy of the Technical Specification surveillance procedures. | |
| The exceptions will include inservice testing and inspection procedures, snubber inspection procedures and any procedures that will change significantly when Improved Technical Specifications are implemented. | |
| The second stage of the TSSIP is expected to be completed during 1997. | |
| .. NRCFORM366 U.S. NUCLEAR REGULATORY COMMISSION
| |
| * APPROVED BY OMB NO. 3150-0104 (4-96) EXPIRES 04130198 EmMATED BURDEN PER RESPONSE TO COMPLY WITH THIS MANDATORY INFORMATION COLLECTION REQUEST: 50.0 HRS. -LICENSEE EVENT REPORT (LER) REPORTED LESSONS LEARNED ARE INCORPORATED INTO THE LICENSING PROCESS AND FED BACK TO INDUSTRY.
| |
| FORWARD COMMENTS REGARDING BURDEN ESTIMATE TO THE INFORMATION (See reverse for required number of AND RECORDS MANAGEMENT BRANCH REGULATORY COMMISSION, WASHINGTON, DC , AND TO digits/characters for each block) THE PAPERWORK REDUCTION PROJECT OFFICE OF MANAGEMENT AND BUDGET, WASHINGTON, 20503. . FACILITY NAllE (1) DOCKET NUllBER (2) PAGE(3) SALEM GENERATING STATION -UNIT 2 05000311 .. 1 OF4 TITLE(4) Technical Specification
| |
|
| |
|
| ====4.9.9 Missed====
| | NRCFORM366 U.S. NUCLEAR REGULATORY COMMISSION |
| Isolation Testing EVENT DATE (5) LEA NUMBER (6) REPORT DATE (7) OTHER FACILITIES INVOLVED (8) YEAR I I REVISION FACILITY NAME DO.CKET NUMBER MONTH DAY YEAR SEQUENTIAL MONTH DAY YEAR NUMBER NUMBER 05000 12 15 95 95 008 00 01 15 96 FACILITY NAME DOCKET NUMBER --05000 OPERATING 6 THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR §: (Check one or more) (11) MODE(9) 20.2201(b) 20.2203(a)(2)(v) x 50. 73(a)(2)(i)
| | * APPROVED BY OMB NO. 3150-0104 (4-96) EXPIRES 04130198 EmMATED BURDEN PER RESPONSE TO COMPLY WITH THIS MANDATORY INFORMATION COLLECTION REQUEST: 50.0 HRS. |
| : 50. 73(a)(2)(viii)
| | REPORTED LESSONS LEARNED ARE INCORPORATED INTO THE |
| POWER 0 20.2203(a)(1) 20.2203(a)(3)(i)
| | - LICENSEE EVENT REPORT (LER) LICENSING PROCESS AND FED BACK TO INDUSTRY. FORWARD COMMENTS REGARDING BURDEN ESTIMATE TO THE INFORMATION AND RECORDS MANAGEMENT BRANCH (T~ ~~NUCLEAR (See reverse for required number of REGULATORY COMMISSION, WASHINGTON, DC , AND TO THE PAPERWORK REDUCTION PROJECT ~15CMl104), OFFICE OF digits/characters for each block) MANAGEMENT AND BUDGET, WASHINGTON, 20503. . |
| : 50. 1s(a)(2)(ii) | | FACILITY NAllE (1) DOCKET NUllBER (2) PAGE(3) |
| : 50. 73(a)(2)(x)
| | SALEM GENERATING STATION - UNIT 2 05000311 .. 1 OF4 TITLE(4) |
| LEVEL (10) 20.2203(a)(2)(i) 20.2203(a)(3)(ii)
| | Technical Specification 4.9.9 Missed Isolation Testing EVENT DATE (5) LEA NUMBER (6) REPORT DATE (7) OTHER FACILITIES INVOLVED (8) |
| : 50. 73(a)(2)(iii) 73.71 -20.2203(a)(2)(ii) 20.2203(a)(4)
| | FACILITY NAME DO.CKET NUMBER MONTH DAY YEAR YEAR I SEQUENTIAL I REVISION MONTH DAY YEAR NUMBER NUMBER 05000 12 15 95 95 - 008 - 00 01 15 96 FACILITY NAME DOCKET NUMBER 05000 OPERATING 6 THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR §: (Check one or more) (11) |
| : 50. 73(a)(2)(iv)
| | MODE(9) 20.2201(b) 20.2203(a)(2)(v) x 50. 73(a)(2)(i) 50. 73(a)(2)(viii) |
| OTHER 20.2203(a)(2)(iii)
| | POWER 0 20.2203(a)(1) 20.2203(a)(3)(i) 50. 1s(a)(2)(ii) 50. 73(a)(2)(x) |
| : 50. 73(a)(2)(v)
| | LEVEL (10) 20.2203(a)(2)(i) 20.2203(a)(3)(ii) 50. 73(a)(2)(iii) 73.71 20.2203(a)(2)(ii) 20.2203(a)(4) 50. 73(a)(2)(iv) OTHER 20.2203(a)(2)(iii) 50~36(c)(1) 50. 73(a)(2)(v) S~~ln Abstract below or in C Form 366A 20.2203(a)(2)(iv) 50.36(c)(2) 50. 73(a)(2)(vii) |
| Abstract below or in C Form 366A 20.2203(a)(2)(iv) 50.36(c)(2)
| | LICENSEE CONTACT FOR THIS LER (12) |
| : 50. 73(a)(2)(vii)
| | NAME TELEPHONE NUMBER (Include ArH Code) |
| LICENSEE CONTACT FOR THIS LER (12) NAME TELEPHONE NUMBER (Include ArH Code) .Scot Greenlee, Operations Support Technical Manager 609-339-3500 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13) CAUSE SYSTEM COMPONENT MANUFACTURER REPORTABLE I CAUSE SYSTEM COMPONENT MANUFACTURER REPORTABLE
| | .Scot Greenlee, Operations Support Technical Manager 609-339-3500 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13) |
| * TONPRDS TONPRDS SUPPLEMENTAL REPORT EXPECTED (14) EXPECTED MONTH DAY YEAR IYES XINO SUBMISSION (If yes, complete EXPECTED SUBMISSION DATE). DATE (15) ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16) On December 15, 1995, a review identified that the requirements of Technical Specification 4.9.9 were never fully proceduralized at Unit 2. Specifically, the surveillance procedure that has been used to implement Technical Specification 4.9.9 did not direct testing of the Containment Purge and Pressure-Vacuum Relief manual initiation function.
| | CAUSE SYSTEM COMPONENT MANUFACTURER REPORTABLE CAUSE SYSTEM COMPONENT MANUFACTURER REPORTABLE |
| Thus, with the exception of the current refueling outage, it is likely that the Unit 2 Containment Purge and Pressure-Vacuum Relief manual initiation function was never tested prior to or during core alterations.
| | * TONPRDS TONPRDS IYES SUPPLEMENTAL REPORT EXPECTED (14) |
| The most recent period of non-compliance was during the last core reload in late November through early December 1994. A similar issue of non-compliance did not exist at Unit 1. The cause of this occurrence was a lack of adequate controls for the development and revision of Technical Specification surveillance procedures.
| | (If yes, complete EXPECTED SUBMISSION DATE). |
| Corrective actions will verify the adequacy of Technical Specification surveillance procedures and will ensure that adequate controls are in place to maintain the adequacy of the procedures.
| | IXINO EXPECTED SUBMISSION DATE (15) |
| This event is in accordance with 10 CFR 73 (a) (2) (i) (B) I any condition prohibited by the plant's Technical Specifications NRC FORM 388 (4-95)
| | MONTH DAY YEAR ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16) |
| NRC FORM 366A (4-95) U.S. NUCLEAR REGULATORY COMMISSION LICENSEE EVENT REPORT (LER) TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) 05000311 YEAR I I == SALEM GENERATING STATION -UNIT 2 95 -008 -00 TEXT (If more space i* required, ulle additional copies of NRC Form 366A) (17) PLANT AND SYSTEM IDENTIFICATION
| | On December 15, 1995, a review identified that the requirements of Technical Specification 4.9.9 were never fully proceduralized at Unit 2. |
| -Westinghouse
| | Specifically, the surveillance procedure that has been used to implement Technical Specification 4.9.9 did not direct testing of the Containment Purge and Pressure-Vacuum Relief manual initiation function. Thus, with the exception of the current refueling outage, it is likely that the Unit 2 Containment Purge and Pressure-Vacuum Relief manual initiation function was never tested prior to or during core alterations. The most recent period of non-compliance was during the last core reload in late November through early December 1994. A similar issue of non-compliance did not exist at Unit 1. The cause of this occurrence was a lack of adequate controls for the development and revision of Technical Specification surveillance procedures. Corrective actions will verify the adequacy of Technical Specification surveillance procedures and will ensure that adequate controls are in place to maintain the adequacy of the procedures. |
| -Pressurized Water Reactor Containment Purge and Pressure-Vacuum Relief {BF/-}* PAGE (3) 2 OF 4 *Energy Industry Identification System (EIIS) codes and component function identifier codes appear in the text as {SS/CC } IDENTIFICATION OF OCCURRENCE Discovery Date: December 15, 1995 Event Dates: The most recent period of non-compliance was during the las*t core reload in late November through early December 1994. Prior to November 1994, it is that the same event occurred on each entry into core alterations and every seven days during core alterations since plant startup. CONDITIONS PRIOR TO OCCURRENCE The plant would have been in Mode 6 or defueled prior to each' event. There were no structures, components, or systems that were inoperable at the start of each event that contributed to the event. DESCRIPTION OF OCCURRENCE On December 8, 1995, Unit 2 operators were making preparations for core alterations.
| | This event is re~ortable in accordance with 10 CFR 73 (a) (2) (i) (B) I any condition prohibited by the plant's Technical Specifications NRC FORM 388 (4-95) |
| A reactor operator was reviewing the Technical Specifications and identified a Unit 2 surveillance procedure that did not adequately address one of the tests required prior to core alterations.
| | |
| Specifically, Technical Specification 4.9.9 states, Containment Purge and Vacuum Relief isolation system shall be demonstrated OPERABLE within 100 hours prior to the start of and at least once per 7 days during CORE ALTERATIONS by verifying that Containment Purge and Pressure-Vacuum Relief isolation occurs on manual initiation and on a high radiation test signal from each of the containment radiation monitoring instrumentation
| | NRC FORM 366A U.S. NUCLEAR REGULATORY COMMISSION (4-95) |
| * channels." The surveillance procedure that has been used to implement Technical Specification 4.9.9 did not direct testing of the Containment Purge and Pressure-Vacuum Relief manual initiation function.
| | LICENSEE EVENT REPORT (LER) |
| Additional testing was performed on December 8 that demonstrated the operability of the Unit 2 Containment Purge and Pressure-Vacuum Relief manual isolation function.
| | TEXT CONTINUATION FACILITY NAME (1) |
| Core alterations subsequently commenced with all required tests complete.
| | SALEM GENERATING STATION - UNIT 2 DOCKET NUMBER (2) 05000311 LER NUMBER (6) |
| NRC FORM 366A (4-95)
| | YEAR I SE3JIJ':J~AL I== 2 PAGE (3) |
| -NRC FORM 366A . (4-96) -U.S. NUCLEAR REGULATORY COMMISSION LICENSEE EVENT REPORT (LER) TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) _ 05000311 SALEM GENERATING STATION -UNIT 2 TEXT (If more space is required, use additional copies of NRC Form 366A) (17) DESCRIPTION OF OCCURRENCE
| | OF 4 95 - 008 - 00 TEXT (If more space i* required, ulle additional copies of NRC Form 366A) (17) |
| -(cont'd) LER NUMBER 6) YEAR I SEQUENTIAL NUMBER REVISION NUMBER 95 -008 -00 P_AGE (3) 3 OF 4 A Containment Purge and Pressure-Vacuum Relief surveillance procedure history review for both units was performed.
| | PLANT AND SYSTEM IDENTIFICATION Westinghouse - Pressurized Water Reactor Containment Purge and Pressure-Vacuum Relief {BF/-}* |
| It revealed that testing of the manual initiation function had never been proceduralized at Unit 2. Thus, with the exception of the current refueling outage, the Unit 2 Containment Purge and Pressure-Vacuum Relief manual initiation function most likely was never tested prior to or during core alterations.
| | *Energy Industry Identification System (EIIS) codes and component function identifier codes appear in the text as {SS/CC } |
| This noncompliance issue wa_"s identified on December 15, 1995. The most recent period of non-compliance was during the previous refueling outage, which occurred in late November through early December, 1994. The Unit 1 procedure history review further revealed that only the most recent revision of the pre-core alterations Containment Purge and Pressure-Vacuum Relief surveillance procedures, Containment or Vent Air Particulate Radiation Monitor" and "lrl2a Containment or Vent Gas Effluent Process Radiation Monitor", did not contain manual initiation testing requirements.
| | IDENTIFICATION OF OCCURRENCE Discovery Date: December 15, 1995 Event Dates: The most recent period of non-compliance was during the las*t core reload in late November through early December 1994. Prior to November 1994, it is l~kely that the same event occurred on each entry into core alterations and every seven days during core alterations since plant startup. |
| These particular procedure revisions were never used. CAUSE OF OCCURRENCE The cause of this occurrence was that the program which implemented Technical Specification test requirements in the late l970's did not have adequate controls to ensure that all testing requirements were properly addressed.
| | CONDITIONS PRIOR TO OCCURRENCE The plant would have been in Mode 6 or defueled prior to each' event. |
| In addition, the current programs do not have sufficient controls to identify similar existing deficiencies, or to prevent removal of steps from-procedures which are required to comply with existing Technical Specifications.
| | There were no structures, components, or systems that were inoperable at the start of each event that contributed to the event. |
| PRIOR SIMILAR OCCURRENCES Though there have been six previous missed surveillances over the last six years, a review of LERs for Salem Units 1 & 2 identified one LER related to missed surveillances due to procedural deficiencies during the last two years. This is: LER 272/94-008 Channel Ftinctional Testing of Position Indication For Power Operated Relief Valves Missed On Both Units" identified an occurrence where a procedure was revised in response to Generic Letter 90-06 without a revision to Technical Specifications which resulted in missed surveillance testing of Power Operated Relief Valves while in modes 1 & 2. NRC FORM 366A (4-95)
| | DESCRIPTION OF OCCURRENCE On December 8, 1995, Unit 2 operators were making preparations for core alterations. A reactor operator was reviewing the Technical Specifications and identified a Unit 2 surveillance procedure that did not adequately address one of the tests required prior to core alterations. Specifically, Technical Specification 4.9.9 states, ~The Containment Purge and Pressure-Vacuum Relief isolation system shall be demonstrated OPERABLE within 100 hours prior to the start of and at least once per 7 days during CORE ALTERATIONS by verifying that Containment Purge and Pressure-Vacuum Relief isolation occurs on manual initiation and on a high radiation test signal from each of the containment radiation monitoring instrumentation |
| .Q.... ..... .. NRC FORM 368A . U.S. NUCLEAR REGULATORY COMMISSION i (4-95) LICENSEE EVENT REPORT (LER) . TEXT CONTINUATION. | | * channels." The surveillance procedure that has been used to implement Technical Specification 4.9.9 did not direct testing of the Containment Purge and Pressure-Vacuum Relief manual initiation function. Additional testing was performed on December 8 that demonstrated the operability of the Unit 2 Containment Purge and Pressure-Vacuum Relief manual isolation function. Core alterations subsequently commenced with all required tests complete. |
| FACILITY NAME (1) DOCKET NUMBER (2) 05000311 SALEM GENERATING STATION -UNIT 2 TEXT (If more space is required, use additional copies of NRC Form 366A) (17) SAFETY SIGNIFICANCE LER NUMBER 6) YEAR I SEQUENTIAL NUMBER REVISION NUMBER 95 -008 -00 PAGE (3) 4 OF 4 The safety significance for this incident is considered minimal since isolation bf the Containment Purge and Pressure-Vacuum Relief valves on a simulated high radiation signal is demonstrated as required by Technical Specification 4.9.9. The individual valves are routinely manipulated while in.Modes 5 and 6, which demonstrates proper manual circuit operation.
| | NRC FORM 366A (4-95) |
| In adqition, Containment Purge and Pressure-Vacuum Relief isolation on the Phase A and Phase B manual isolation signals are also demonstrated to occur as required by Technical Specification 4.6.3.2.d on an 18 month CORRECTIVE ACTIONS The immediate corrective action taken*was to verify the ability to manually close of the Containment Purge and Pressure-Vacuum Relief isolation valves from the Control Room. The task specific procedure for Unit 2, Procedure "High Radiation Signal and Manual Initiation for Containment Isolation", was revised to address the requirements of Technical Specification 4.9.9. This procedure is now approved for use. A task specific procedure for Unit 1 will be developed to address all the requirements of Technical Specification 4.9.9. This will be completed pribr to core alterations on Unit 1.-A Technical Specification Surveillance Improvement Project (TSSIP) has been initiated for Salem station. As part of the TSSIP, a review will be performed to ensure that each Technical Specification surveillance requirement is adequately proceduralized.
| | |
| The review will be completed in two stages. The first stage will involve verification that each Technical Specification surveillance requirement has an associated procedure which is listed in the Technical Specifications matrix. These reviews will be prioritized such that Mode change requirements are verified prior to the applicable Mode Administrative processes will also be. revised, as necessary, to ensure adequate controls are established for the revision of Technical Specification surveillance procedures. | | -~ - |
| The first stage of the TSSIP will be complete prior to unit restart. The second stage of the TSSIP will, with exceptions, involve validation of the technical accuracy of the Technical Specification surveillance procedures.
| | NRC FORM 366A . U.S. NUCLEAR REGULATORY COMMISSION (4-96) - |
| The exceptions will include inservice testing and inspection procedures, snubber inspection procedures and any procedures that will change significantly when Improved Technical Specifications are implemented.
| | LICENSEE EVENT REPORT (LER) |
| The second stage of the TSSIP is expected to be completed during 1997. NRC FORM 366A (4-95)}}
| | TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) _ LER NUMBER 6) P_AGE (3) 05000311 YEAR I SEQUENTIAL NUMBER REVISION NUMBER 3 OF 4 SALEM GENERATING STATION - UNIT 2 95 - 008 - 00 TEXT (If more space is required, use additional copies of NRC Form 366A) (17) |
| | DESCRIPTION OF OCCURRENCE - (cont'd) |
| | A Containment Purge and Pressure-Vacuum Relief surveillance procedure history review for both units was performed. It revealed that testing of the manual initiation function had never been proceduralized at Unit 2. |
| | Thus, with the exception of the current refueling outage, the Unit 2 Containment Purge and Pressure-Vacuum Relief manual initiation function most likely was never tested prior to or during core alterations. This noncompliance issue wa_"s identified on December 15, 1995. The most recent period of non-compliance was during the previous refueling outage, which occurred in late November through early December, 1994. The Unit 1 procedure history review further revealed that only the most recent revision of the pre-core alterations Containment Purge and Pressure-Vacuum Relief surveillance procedures, Sl.IC-FT.RM-0014(Q)-~lrlla Containment or Vent Air Particulate Proc~ss Radiation Monitor" and Sl.IC-FT.RM-0016(Q)- |
| | "lrl2a Containment or Vent Gas Effluent Process Radiation Monitor", did not contain manual initiation testing requirements. These particular procedure revisions were never used. |
| | CAUSE OF OCCURRENCE The cause of this occurrence was that the program which implemented Technical Specification test requirements in the late l970's did not have adequate controls to ensure that all testing requirements were properly addressed. In addition, the current programs do not have sufficient controls to identify similar existing deficiencies, or to prevent removal of steps from-procedures which are required to comply with existing Technical Specifications. |
| | PRIOR SIMILAR OCCURRENCES Though there have been six previous missed surveillances over the last six years, a review of LERs for Salem Units 1 & 2 identified one LER related to missed surveillances due to procedural deficiencies during the last two years. This is: |
| | LER 272/94-008 ~Quarterly Channel Ftinctional Testing of Position Indication For Power Operated Relief Valves Missed On Both Units" identified an occurrence where a procedure was revised in response to Generic Letter 90-06 without a revision to Technical Specifications which resulted in missed surveillance testing of Power Operated Relief Valves while in modes 1 & 2. |
| | NRC FORM 366A (4-95) |
| | |
| | .Q.... ..... .. |
| | NRC FORM 368A . U.S. NUCLEAR REGULATORY COMMISSION i (4-95) |
| | LICENSEE EVENT REPORT (LER) |
| | . TEXT CONTINUATION. |
| | FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER 6) PAGE (3) 05000311 YEAR I SEQUENTIAL NUMBER REVISION NUMBER 4 OF 4 SALEM GENERATING STATION - UNIT 2 95 - 008 - 00 TEXT (If more space is required, use additional copies of NRC Form 366A) (17) |
| | SAFETY SIGNIFICANCE The safety significance for this incident is considered minimal since isolation bf the Containment Purge and Pressure-Vacuum Relief valves on a simulated high radiation signal is demonstrated as required by Technical Specification 4.9.9. The individual valves are routinely manipulated while in.Modes 5 and 6, which demonstrates proper manual circuit operation. |
| | In adqition, Containment Purge and Pressure-Vacuum Relief isolation on the Phase A and Phase B manual isolation signals are also demonstrated to occur as required by Technical Specification 4.6.3.2.d on an 18 month frequen~y. |
| | CORRECTIVE ACTIONS The immediate corrective action taken*was to verify the ability to manually close ~ach of the Containment Purge and Pressure-Vacuum Relief isolation valves from the Control Room. |
| | The task specific procedure for Unit 2, Procedure S2.IC-FT.RM-0088(Q)- |
| | "High Radiation Signal and Manual Initiation for Containment Isolation", |
| | was revised to address the requirements of Technical Specification 4.9.9. |
| | This procedure is now approved for use. |
| | A task specific procedure for Unit 1 will be developed to address all the requirements of Technical Specification 4.9.9. This will be completed pribr to core alterations on Unit 1.- |
| | A Technical Specification Surveillance Improvement Project (TSSIP) has been initiated for Salem station. As part of the TSSIP, a review will be performed to ensure that each Technical Specification surveillance requirement is adequately proceduralized. The review will be completed in two stages. The first stage will involve verification that each Technical Specification surveillance requirement has an associated procedure which is listed in the Technical Specifications matrix. These reviews will be prioritized such that Mode change requirements are verified prior to the applicable Mode change~ Administrative processes will also be. revised, as necessary, to ensure adequate controls are established for the revision of Technical Specification surveillance procedures. The first stage of the TSSIP will be complete prior to unit restart. The second stage of the TSSIP will, with exceptions, involve validation of the technical accuracy of the Technical Specification surveillance procedures. The exceptions will include inservice testing and inspection procedures, snubber inspection procedures and any procedures that will change significantly when Improved Technical Specifications are implemented. The second stage of the TSSIP is expected to be completed during 1997. |
| | NRC FORM 366A (4-95)}} |
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LER 99-006-01:on 990501,determined That There Was No Flow in One of Four Injection Legs.Caused by Sticking of Valve in Safety Injection Discharge Line to 21 Cold Leg.Valve Was Cut Out of Sys & Replaced.With 990701 Ltr
ML18107A4331999-07-0101 July 1999
LER 99-002-01:on 990405,determined That 2SA118 Failed as Found Leakrate Test.Caused by Foreign Matl Found in 2SA118 valve.2SA118 Valve Was Cycled Several Times & Seat Area Was Air Blown in Order to Displace Foreign Matl.With 990701 Ltr
ML18107A3951999-06-17017 June 1999
LER 99-004-00:on 990520,reactor Tripped from 100% Power,Due to Negative Flux Trip Signal from Nuclear Instrumentation. Cause Has Not Been Determined.Discoloration Was Identified on One of Penetrations.With 990617 Ltr
ML18107A3661999-06-0909 June 1999
LER 99-003-00:on 990513,unplanned Entry Into TS 3.0.3 Was Made.Caused by Human error.Re-positioned Creacs Supply Fan Selector Switches & Revised Procedures S1 & S2.OP-ST.SSP-0001(Q).With 990609 Ltr
ML18107A3551999-06-0202 June 1999
LER 99-005-00:on 990504,failure to Meet TS Action Statement Requirements for High Oxygen Concentration in Waste Gas Holdup Sys Occurred.Caused by Inability of Operators. Existing Procedures Will Be Evaluated.With 990602 Ltr
ML18107A3541999-06-0101 June 1999
LER 99-006-00:on 990501,HHSI Flow Balance Discrepancy Was Noted During Surveillance.Caused by Sticking of Check Valve in SI Discharge Line to 21 Cold Leg.Valve 21SJ17,was Cut Out of Sys & Replaced.With 990601 Ltr
ML18107A2931999-05-12012 May 1999
LER 99-002-00:on 990413,determined That Number 12 Auxiliary Bldg Exhaust Fan Was Rotating Backwards.Caused by mis-wiring of Motor Due to Human Error by Maint technician.Mis-wiring Was Corrected & Fan Was Returned to Svc.With 990512 Ltr
ML18107A2781999-05-10010 May 1999
LER 99-004-00:on 990411,automatic Actuation of ESF Occurred During Reactor Vessel Head Removal in Support of Refueling Operations.Caused by High Radiation Condition.Containment Atmosphere Was Monitored.With 990505 Ltr
ML18107A2791999-05-0404 May 1999
LER 99-003-00:on 990406,all Salem Unit 2 Chillers Rendered Inoperable.Caused by Human Error.Lessons Learned from Event Were Communicated to All Operators by Including Them in Night Orders.With 990504 Ltr
ML18107A2741999-05-0303 May 1999
LER 99-002-00:on 990405,determined That Containment Isolation Valve Failed as Found Leakrate Test.Caused by Foreign Matl Blocking Valves from Closing.Check Valve Mechanically Agitated.With 990504 Ltr
ML18107A2351999-04-23023 April 1999
LER 99-001-00:on 990330,MSSV Failed Lift Set Test.Caused by Setpoint Variance Which Is Result of Aging.Valves Were Adjusted & Retested to Ensure TS Tolerance.With 990423 Ltr
ML18106B1471999-03-29029 March 1999
LER 99-001-00:on 990228,reactor Scram Was Noted as Result of Turbine Trip.Caused by Operator Error.Lesson Plans Revised to Explicitly Demonstrate Manner in Which Valve Functions. with 990329 Ltr
ML18106B0701999-02-16016 February 1999
LER 98-015-00:on 981208,inadvertent Discharge Through RHR Relief Valve During Startup Was Noted.Caused by Operator Performing Too Many Tasks Simultaneously.Appropriate Actions Have Been Taken IAW Policies & Procedures.With 990216 Ltr
ML18106B0491999-01-28028 January 1999
LER 98-007-01:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Caused by Transgranular Stress Corrosion Cracking.Replaced Affected Tubing.With 990128 Ltr
ML18106B0401999-01-18018 January 1999
LER 98-016-00:on 981219,ECCS Leakage Was Outside of Design Value.Caused by Leakage Past Seat of 21RH34 Manual Drain. Valve 21RH34 Was Reseated.With 990118 Ltr
ML18106B0081998-12-24024 December 1998
LER 97-001-01:on 970215,failure to Perform TS Surveillance of Component Cooling Water Sys Check Valves Occurred.Caused by Inadequate Communication Between EOP Group & IST Reviewers.Procedure Revised.With 981224 Ltr
ML18106B0021998-12-17017 December 1998
LER 98-015-01:on 980924,improper Installation of Test Equipment to RPS Occurred.Caused by Inadequate 10CFR50.59 Applicability Reviews During Past Revs.Revised Procedures. with 981217 Ltr
ML18106A9551998-11-0303 November 1998
LER 96-013-01:on 960711,concluded That Current Gain & Bias Settings Had Rendered Overtemperature Delta Temp Protection Channels Inoperable.Caused by Scaling Error.Licensee Will Revise Scaling Calculations.With 981105 Ltr
ML18106A9451998-10-30030 October 1998
LER 97-004-01:on 970408,failure to Comply with TS Action Statement,Dg Start & Inadequate Surveillance Testing,Was Noted.Caused by Inadequate Tracking of Inoperable Equipment. Discussed Event & Lessons Learned.With 981022 Ltr
ML18106A9491998-10-22022 October 1998
LER 98-015-00:on 980924,identified Improper Installation of Test Equipment to Rps.Cause Indeterminate.Procedures for Installation of Test Equipment for Collection of State Point Data Were Placed on Administrative Hold.With 981022 Ltr
ML18106A9301998-10-21021 October 1998
LER 98-014-00:on 980725,noted Improper Calibr of Liquid Radwaste Effluent Line Radiation Monitor.Caused by Inattention to Detail by Maint Personnel.Channel Calibr Was Successfully Performed on 1R18 on 980821.With 981019 Ltr
ML18106A9071998-10-0101 October 1998
LER 98-014-00:on 980918,discovered That Fire Barrier Matl for HVAC Ducts Does Not Meet Required Level of Fire Resistance.Cause Indeterminate.Established Appropriate Compensatory Actions for Fire Barriers.With 981001 Ltr
ML18106A8951998-09-28028 September 1998
LER 98-012-01:on 980725,noted That Afs Was Operated with Less than Required Number of Operable AFW Pumps.Caused by Improper Procedure Implementation.Runout Protection Pressure Device for 22 AFW Pumps Was Returned to Svc.With 980928 Ltr
ML18106A8821998-09-21021 September 1998
LER 98-013-00:on 980820,noted Surveillance of Containment Penetration Overcurrent Protection Devices Missed.Caused by Human Error.Satisfactorily Tested Apprpriate Breakers & Disciplined Involved Personnel.With 980921 Ltr
ML18106A8791998-09-16016 September 1998
LER 96-006-01:on 960717,determined That non-radioactive Liquid Basin Radwaste Monitor Inoperable During Low Head Conditions.Caused by Inadequate Design Change Package.Design Change 1EC3663-01 Has Been Installed.With 980916 Ltr
ML18106A8801998-09-0808 September 1998
LER 98-013-00:on 980806,operation with TS Required Equipment OOS Was Noted.Caused by Human Error.Reviewed Processes & Practices Re Safety Sys Status Control,Procedure Rev & Extra Training.With 980908 Ltr
ML18106A8531998-08-27027 August 1998
LER 98-007-00:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Cause of Event Has Not Yet Been Determined.Assembled Root Cause Team & Replaced Affected tubing.W/980827 Ltr
ML18106A8521998-08-27027 August 1998
LER 98-011-00:on 980803,ESFA During a 4KV Automatic Transfer Test Was Noted.Caused by Premature Release of Control Console Pushbutton Due to Inadequate Procedural Step.Revised procedure.W/980827 Ltr
ML18106A8421998-08-24024 August 1998
LER 98-012-00:on 980725,discovered That Plant Had Operated in Modes 1 & 2 w/twenty-two AFW Pumps Inoperable.Caused by Failure to Restore Pump Runout Protection Pressure Device to Svc.Returned Subject Device to svc.W/980824 Ltr
ML18106A8431998-08-24024 August 1998
LER 98-009-00:on 980810,failure to Post Continuous Firewatch as Required by Fire Protection Plan Noted.Caused by Failure to Recognize Concurrent Conditions.Continuous Firewatch Was Posted Immediately & Repaired Smoke detectors.W/980824 Ltr
ML18106A8141998-08-13013 August 1998
LER 98-010-00:on 980714,determined That Leakage from Boron Injection Tank Exceeded Max Allowable ECCS Leakage from Sources Outside Containment.Caused by Leaking 2SJ404 Manual Sample valve.2SJ404 Valve repaired.W/980813 Ltr
ML18106A8201998-08-13013 August 1998
LER 98-012-00:on 980715,potential to Exceed Rating of Piping Due to Isolation of Overpressure Protection Line Was Noted. Caused by Inadequate Procedural Guidance.Appropriate Operations Dept Procedures Have Been revised.W/980813 Ltr
ML18106A6931998-06-29029 June 1998
LER 98-003-00:on 980122,inappropriate Plugging of Tubes R9C60 & R10C60 in Salem Unit 2 Sg,Was Performed.Caused by Failure of Qualification,Verification & Validation Process. Tubes Reviewed to Verify No Others Inappropriately Plugged
ML18106A6471998-06-0404 June 1998
LER 98-011-00:on 980505,improper Isolation of Single Cell Battery Charger from 125 Vdc Battery Was Noted.Caused by Inadequate 10CFR50.59 Applicability Review.Placed Procedure SC.MD-CM.ZZ-0024(Q) on Administrative hold.W/980604 Ltr
ML18106A6421998-06-0101 June 1998
LER 98-010-00:on 931019,reactor Pressure Vessel Insp Plugs Were Out of Configuration,Was Noted.Caused by Personnel Error.Proper Configuration Was Restored Shortly After Discovery Prior to Entering Mode 2.W/980601 Ltr
ML18106A6431998-05-29029 May 1998
LER 98-006-01:on 980227,determined Incorrect Scaling Error of First Stage Pressure Transmitter Existed.Caused by Human Error.Revised Setpoint Calculation SC-MS002-01 & Revised Associated Instrument Calibr Database info.W/980529 Ltr
ML18106A6141998-05-18018 May 1998
LER 98-008-00:on 970814,failure to Test 21 & 22 AF 40 Valves in Closed Direction as Required by TS 4.0.5 Was Noted.Caused by Inadequate Design Mod Process.Motor Driven 21/22 AF 40 Valves Were Tested IAW Revised procedure.W/980518 Ltr
ML18106A5901998-05-0101 May 1998
LER 98-009-00:on 980405,epoxy Missing from Terminals of H Analyzer Was Noted.Caused by Inadequate Development of Procedure.H Analyzers Were Repaired & Review of Other Safety Related Equipment in Containment Was performed.W/980501 Ltr
ML18106A5611998-04-20020 April 1998
LER 98-008-00:on 980323,inadequate Testing of Salem Unit 1 Containment Air Locks Resulted in Entering TS 3.0.3.Caused by less-than-adequate Work Practices During Replacement of Equalizing Valve.Salem Unit 2 Airlocks Were Inspected
ML18106A6061998-04-0101 April 1998
Corrected LER 98-004-00:on 980302,failure to Comply W/Tss 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Have Been Taken to Correctly Document Safety Factors.Corrects Prior Similar Occurrences
ML18106A4451998-04-0101 April 1998
LER 98-004-00:on 980302,failure to Perform TS 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Were Taken to Correctly Document Safety factors.W/980401 Ltr
ML18106A4351998-03-30030 March 1998
LER 98-006-00:on 980227,incorrect Scaling of First Stage Turbine Impulse Pressure Transmitters Noted.Cause Indeterminate.Implemented Procedure Changes & re-scaled Affected Turbine Impulse Pressure transmitters.W/980330 Ltr
ML18106A3961998-03-20020 March 1998
LER 98-005-00:on 980219,inoperability of Twelve EDG Fuel Oil Transfer Pump (FOTP) Noted.Caused by Installation of Incorrect Control Switch.Installed Correct off-auto-manual Switch & Verified Operability of Twelve FOTP.W/980320 Ltr
ML18106A5781998-03-20020 March 1998
Corrected LER 98-005-00:on 980219,inoperability of 12 Fuel Oil Transfer Pump (Fotp),Noted.Caused by Installation of Incorrect Control Switch.Field Insp Performed to Verify Configuration of Switches for 11,21 & 22 FOTPs
ML18106A4021998-03-20020 March 1998
LER 98-007-00:on 980218,failure to Establish Containment Integrity (Closure) Prior to Fuel Movement Was Noted.Caused by Failure to Identify & Include Condensate Pot Vent in Appropriate Valve Lineup.Valves identified.W/980320 Ltr
ML18106A4031998-03-20020 March 1998
LER 98-006-00:on 980221,ESF Actuation of 11 & 12 Auxiliary Feedwater Pumps Occurred.Caused by Human Error.Operators Promptly Established Feedwater to All SG & Restored Proper Water levels.W/980320 Ltr
1999-08-26
[Table view]
Category:RO)
MONTHYEARML18107A5031999-08-26026 August 1999
LER 99-006-00:on 990729,determined That SG Blowdown RMs Setpoint Was non-conservative.Caused by Inadequate ACs for Incorporating Original Plant Licensing Data Into Plant Procedures.Blowdown Will Be Restricted.With 990826 Ltr
ML18107A4691999-07-28028 July 1999
LER 99-008-00:on 990714,determined That Limit Switch Cables Were Subject to Multiple Hot Shorts in Same Fire Area.Caused by Inadequate Original Post Fire Safe Shutdown Analysis.All Limit Switch Cables for MOVs Were Reviewed.With 990728 Ltr
ML18107A4441999-07-0606 July 1999
LER 99-007-00:on 990605,surveillance for Quadrant Power Tilt Ratio (QPTR) Was Missed.Caused by Human Error.Qptr Calculation Was Performed & Personnel Involved Have Been Held Accountable IAW Pse&G Policies.With 990706 Ltr
ML18107A4211999-07-0202 July 1999
LER 99-005-00:on 990605,11 Containment Declared Inoperable. Caused by Valves 11SW72 & 11SW223 Both Leaking.Procedure S1.OP-ST.SW-0010(Q) Was Enhanced to Provide Specific Instructions to Ensure Proper Sequencing.With 990702 Ltr
ML18107A4321999-07-0101 July 1999
LER 99-006-01:on 990501,determined That There Was No Flow in One of Four Injection Legs.Caused by Sticking of Valve in Safety Injection Discharge Line to 21 Cold Leg.Valve Was Cut Out of Sys & Replaced.With 990701 Ltr
ML18107A4331999-07-0101 July 1999
LER 99-002-01:on 990405,determined That 2SA118 Failed as Found Leakrate Test.Caused by Foreign Matl Found in 2SA118 valve.2SA118 Valve Was Cycled Several Times & Seat Area Was Air Blown in Order to Displace Foreign Matl.With 990701 Ltr
ML18107A3951999-06-17017 June 1999
LER 99-004-00:on 990520,reactor Tripped from 100% Power,Due to Negative Flux Trip Signal from Nuclear Instrumentation. Cause Has Not Been Determined.Discoloration Was Identified on One of Penetrations.With 990617 Ltr
ML18107A3661999-06-0909 June 1999
LER 99-003-00:on 990513,unplanned Entry Into TS 3.0.3 Was Made.Caused by Human error.Re-positioned Creacs Supply Fan Selector Switches & Revised Procedures S1 & S2.OP-ST.SSP-0001(Q).With 990609 Ltr
ML18107A3551999-06-0202 June 1999
LER 99-005-00:on 990504,failure to Meet TS Action Statement Requirements for High Oxygen Concentration in Waste Gas Holdup Sys Occurred.Caused by Inability of Operators. Existing Procedures Will Be Evaluated.With 990602 Ltr
ML18107A3541999-06-0101 June 1999
LER 99-006-00:on 990501,HHSI Flow Balance Discrepancy Was Noted During Surveillance.Caused by Sticking of Check Valve in SI Discharge Line to 21 Cold Leg.Valve 21SJ17,was Cut Out of Sys & Replaced.With 990601 Ltr
ML18107A2931999-05-12012 May 1999
LER 99-002-00:on 990413,determined That Number 12 Auxiliary Bldg Exhaust Fan Was Rotating Backwards.Caused by mis-wiring of Motor Due to Human Error by Maint technician.Mis-wiring Was Corrected & Fan Was Returned to Svc.With 990512 Ltr
ML18107A2781999-05-10010 May 1999
LER 99-004-00:on 990411,automatic Actuation of ESF Occurred During Reactor Vessel Head Removal in Support of Refueling Operations.Caused by High Radiation Condition.Containment Atmosphere Was Monitored.With 990505 Ltr
ML18107A2791999-05-0404 May 1999
LER 99-003-00:on 990406,all Salem Unit 2 Chillers Rendered Inoperable.Caused by Human Error.Lessons Learned from Event Were Communicated to All Operators by Including Them in Night Orders.With 990504 Ltr
ML18107A2741999-05-0303 May 1999
LER 99-002-00:on 990405,determined That Containment Isolation Valve Failed as Found Leakrate Test.Caused by Foreign Matl Blocking Valves from Closing.Check Valve Mechanically Agitated.With 990504 Ltr
ML18107A2351999-04-23023 April 1999
LER 99-001-00:on 990330,MSSV Failed Lift Set Test.Caused by Setpoint Variance Which Is Result of Aging.Valves Were Adjusted & Retested to Ensure TS Tolerance.With 990423 Ltr
ML18106B1471999-03-29029 March 1999
LER 99-001-00:on 990228,reactor Scram Was Noted as Result of Turbine Trip.Caused by Operator Error.Lesson Plans Revised to Explicitly Demonstrate Manner in Which Valve Functions. with 990329 Ltr
ML18106B0701999-02-16016 February 1999
LER 98-015-00:on 981208,inadvertent Discharge Through RHR Relief Valve During Startup Was Noted.Caused by Operator Performing Too Many Tasks Simultaneously.Appropriate Actions Have Been Taken IAW Policies & Procedures.With 990216 Ltr
ML18106B0491999-01-28028 January 1999
LER 98-007-01:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Caused by Transgranular Stress Corrosion Cracking.Replaced Affected Tubing.With 990128 Ltr
ML18106B0401999-01-18018 January 1999
LER 98-016-00:on 981219,ECCS Leakage Was Outside of Design Value.Caused by Leakage Past Seat of 21RH34 Manual Drain. Valve 21RH34 Was Reseated.With 990118 Ltr
ML18106B0081998-12-24024 December 1998
LER 97-001-01:on 970215,failure to Perform TS Surveillance of Component Cooling Water Sys Check Valves Occurred.Caused by Inadequate Communication Between EOP Group & IST Reviewers.Procedure Revised.With 981224 Ltr
ML18106B0021998-12-17017 December 1998
LER 98-015-01:on 980924,improper Installation of Test Equipment to RPS Occurred.Caused by Inadequate 10CFR50.59 Applicability Reviews During Past Revs.Revised Procedures. with 981217 Ltr
ML18106A9551998-11-0303 November 1998
LER 96-013-01:on 960711,concluded That Current Gain & Bias Settings Had Rendered Overtemperature Delta Temp Protection Channels Inoperable.Caused by Scaling Error.Licensee Will Revise Scaling Calculations.With 981105 Ltr
ML18106A9451998-10-30030 October 1998
LER 97-004-01:on 970408,failure to Comply with TS Action Statement,Dg Start & Inadequate Surveillance Testing,Was Noted.Caused by Inadequate Tracking of Inoperable Equipment. Discussed Event & Lessons Learned.With 981022 Ltr
ML18106A9491998-10-22022 October 1998
LER 98-015-00:on 980924,identified Improper Installation of Test Equipment to Rps.Cause Indeterminate.Procedures for Installation of Test Equipment for Collection of State Point Data Were Placed on Administrative Hold.With 981022 Ltr
ML18106A9301998-10-21021 October 1998
LER 98-014-00:on 980725,noted Improper Calibr of Liquid Radwaste Effluent Line Radiation Monitor.Caused by Inattention to Detail by Maint Personnel.Channel Calibr Was Successfully Performed on 1R18 on 980821.With 981019 Ltr
ML18106A9071998-10-0101 October 1998
LER 98-014-00:on 980918,discovered That Fire Barrier Matl for HVAC Ducts Does Not Meet Required Level of Fire Resistance.Cause Indeterminate.Established Appropriate Compensatory Actions for Fire Barriers.With 981001 Ltr
ML18106A8951998-09-28028 September 1998
LER 98-012-01:on 980725,noted That Afs Was Operated with Less than Required Number of Operable AFW Pumps.Caused by Improper Procedure Implementation.Runout Protection Pressure Device for 22 AFW Pumps Was Returned to Svc.With 980928 Ltr
ML18106A8821998-09-21021 September 1998
LER 98-013-00:on 980820,noted Surveillance of Containment Penetration Overcurrent Protection Devices Missed.Caused by Human Error.Satisfactorily Tested Apprpriate Breakers & Disciplined Involved Personnel.With 980921 Ltr
ML18106A8791998-09-16016 September 1998
LER 96-006-01:on 960717,determined That non-radioactive Liquid Basin Radwaste Monitor Inoperable During Low Head Conditions.Caused by Inadequate Design Change Package.Design Change 1EC3663-01 Has Been Installed.With 980916 Ltr
ML18106A8801998-09-0808 September 1998
LER 98-013-00:on 980806,operation with TS Required Equipment OOS Was Noted.Caused by Human Error.Reviewed Processes & Practices Re Safety Sys Status Control,Procedure Rev & Extra Training.With 980908 Ltr
ML18106A8531998-08-27027 August 1998
LER 98-007-00:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Cause of Event Has Not Yet Been Determined.Assembled Root Cause Team & Replaced Affected tubing.W/980827 Ltr
ML18106A8521998-08-27027 August 1998
LER 98-011-00:on 980803,ESFA During a 4KV Automatic Transfer Test Was Noted.Caused by Premature Release of Control Console Pushbutton Due to Inadequate Procedural Step.Revised procedure.W/980827 Ltr
ML18106A8421998-08-24024 August 1998
LER 98-012-00:on 980725,discovered That Plant Had Operated in Modes 1 & 2 w/twenty-two AFW Pumps Inoperable.Caused by Failure to Restore Pump Runout Protection Pressure Device to Svc.Returned Subject Device to svc.W/980824 Ltr
ML18106A8431998-08-24024 August 1998
LER 98-009-00:on 980810,failure to Post Continuous Firewatch as Required by Fire Protection Plan Noted.Caused by Failure to Recognize Concurrent Conditions.Continuous Firewatch Was Posted Immediately & Repaired Smoke detectors.W/980824 Ltr
ML18106A8141998-08-13013 August 1998
LER 98-010-00:on 980714,determined That Leakage from Boron Injection Tank Exceeded Max Allowable ECCS Leakage from Sources Outside Containment.Caused by Leaking 2SJ404 Manual Sample valve.2SJ404 Valve repaired.W/980813 Ltr
ML18106A8201998-08-13013 August 1998
LER 98-012-00:on 980715,potential to Exceed Rating of Piping Due to Isolation of Overpressure Protection Line Was Noted. Caused by Inadequate Procedural Guidance.Appropriate Operations Dept Procedures Have Been revised.W/980813 Ltr
ML18106A6931998-06-29029 June 1998
LER 98-003-00:on 980122,inappropriate Plugging of Tubes R9C60 & R10C60 in Salem Unit 2 Sg,Was Performed.Caused by Failure of Qualification,Verification & Validation Process. Tubes Reviewed to Verify No Others Inappropriately Plugged
ML18106A6471998-06-0404 June 1998
LER 98-011-00:on 980505,improper Isolation of Single Cell Battery Charger from 125 Vdc Battery Was Noted.Caused by Inadequate 10CFR50.59 Applicability Review.Placed Procedure SC.MD-CM.ZZ-0024(Q) on Administrative hold.W/980604 Ltr
ML18106A6421998-06-0101 June 1998
LER 98-010-00:on 931019,reactor Pressure Vessel Insp Plugs Were Out of Configuration,Was Noted.Caused by Personnel Error.Proper Configuration Was Restored Shortly After Discovery Prior to Entering Mode 2.W/980601 Ltr
ML18106A6431998-05-29029 May 1998
LER 98-006-01:on 980227,determined Incorrect Scaling Error of First Stage Pressure Transmitter Existed.Caused by Human Error.Revised Setpoint Calculation SC-MS002-01 & Revised Associated Instrument Calibr Database info.W/980529 Ltr
ML18106A6141998-05-18018 May 1998
LER 98-008-00:on 970814,failure to Test 21 & 22 AF 40 Valves in Closed Direction as Required by TS 4.0.5 Was Noted.Caused by Inadequate Design Mod Process.Motor Driven 21/22 AF 40 Valves Were Tested IAW Revised procedure.W/980518 Ltr
ML18106A5901998-05-0101 May 1998
LER 98-009-00:on 980405,epoxy Missing from Terminals of H Analyzer Was Noted.Caused by Inadequate Development of Procedure.H Analyzers Were Repaired & Review of Other Safety Related Equipment in Containment Was performed.W/980501 Ltr
ML18106A5611998-04-20020 April 1998
LER 98-008-00:on 980323,inadequate Testing of Salem Unit 1 Containment Air Locks Resulted in Entering TS 3.0.3.Caused by less-than-adequate Work Practices During Replacement of Equalizing Valve.Salem Unit 2 Airlocks Were Inspected
ML18106A6061998-04-0101 April 1998
Corrected LER 98-004-00:on 980302,failure to Comply W/Tss 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Have Been Taken to Correctly Document Safety Factors.Corrects Prior Similar Occurrences
ML18106A4451998-04-0101 April 1998
LER 98-004-00:on 980302,failure to Perform TS 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Were Taken to Correctly Document Safety factors.W/980401 Ltr
ML18106A4351998-03-30030 March 1998
LER 98-006-00:on 980227,incorrect Scaling of First Stage Turbine Impulse Pressure Transmitters Noted.Cause Indeterminate.Implemented Procedure Changes & re-scaled Affected Turbine Impulse Pressure transmitters.W/980330 Ltr
ML18106A3961998-03-20020 March 1998
LER 98-005-00:on 980219,inoperability of Twelve EDG Fuel Oil Transfer Pump (FOTP) Noted.Caused by Installation of Incorrect Control Switch.Installed Correct off-auto-manual Switch & Verified Operability of Twelve FOTP.W/980320 Ltr
ML18106A5781998-03-20020 March 1998
Corrected LER 98-005-00:on 980219,inoperability of 12 Fuel Oil Transfer Pump (Fotp),Noted.Caused by Installation of Incorrect Control Switch.Field Insp Performed to Verify Configuration of Switches for 11,21 & 22 FOTPs
ML18106A4021998-03-20020 March 1998
LER 98-007-00:on 980218,failure to Establish Containment Integrity (Closure) Prior to Fuel Movement Was Noted.Caused by Failure to Identify & Include Condensate Pot Vent in Appropriate Valve Lineup.Valves identified.W/980320 Ltr
ML18106A4031998-03-20020 March 1998
LER 98-006-00:on 980221,ESF Actuation of 11 & 12 Auxiliary Feedwater Pumps Occurred.Caused by Human Error.Operators Promptly Established Feedwater to All SG & Restored Proper Water levels.W/980320 Ltr
1999-08-26
[Table view]
Category:TEXT-SAFETY REPORT
MONTHYEARML20217A9931999-09-30030 September 1999
NRC Regulatory Assessment & Oversight Pilot Program, Performance Indicator Data
ML18107A5581999-09-30030 September 1999
Monthly Operating Rept for Sept 1999 for Salem,Unit 2.With 991014 Ltr
ML18107A5571999-09-30030 September 1999
Monthly Operating Rept for Sept 1999 for Salem,Unit 1.With 991014 Ltr
ML18107A5301999-08-31031 August 1999
Monthly Operating Rept for Aug 1999 for Salem,Unit 2.With 990913 Ltr
ML18107A5311999-08-31031 August 1999
Monthly Operating Rept for Aug 1999 for Salem,Unit 1.With 990913
ML18107A5031999-08-26026 August 1999
LER 99-006-00:on 990729,determined That SG Blowdown RMs Setpoint Was non-conservative.Caused by Inadequate ACs for Incorporating Original Plant Licensing Data Into Plant Procedures.Blowdown Will Be Restricted.With 990826 Ltr
ML18107A5201999-08-12012 August 1999
Rev 0 to Sgs Unit 2 ISI RFO Exam Results (S2RFO#9) Second Interval,Second Period, First Outage (96RF).
ML18107A4811999-07-31031 July 1999
Monthly Operating Rept for July 1999 for Salem,Unit 1.With 990813 Ltr
ML18107A4821999-07-31031 July 1999
Monthly Operating Rept for July 1999 for Salem,Unit 2.With 990813 Ltr
ML18107A4691999-07-28028 July 1999
LER 99-008-00:on 990714,determined That Limit Switch Cables Were Subject to Multiple Hot Shorts in Same Fire Area.Caused by Inadequate Original Post Fire Safe Shutdown Analysis.All Limit Switch Cables for MOVs Were Reviewed.With 990728 Ltr
ML18107A4441999-07-0606 July 1999
LER 99-007-00:on 990605,surveillance for Quadrant Power Tilt Ratio (QPTR) Was Missed.Caused by Human Error.Qptr Calculation Was Performed & Personnel Involved Have Been Held Accountable IAW Pse&G Policies.With 990706 Ltr
ML18107A4211999-07-0202 July 1999
LER 99-005-00:on 990605,11 Containment Declared Inoperable. Caused by Valves 11SW72 & 11SW223 Both Leaking.Procedure S1.OP-ST.SW-0010(Q) Was Enhanced to Provide Specific Instructions to Ensure Proper Sequencing.With 990702 Ltr
ML18107A4331999-07-0101 July 1999
LER 99-002-01:on 990405,determined That 2SA118 Failed as Found Leakrate Test.Caused by Foreign Matl Found in 2SA118 valve.2SA118 Valve Was Cycled Several Times & Seat Area Was Air Blown in Order to Displace Foreign Matl.With 990701 Ltr
ML18107A4321999-07-0101 July 1999
LER 99-006-01:on 990501,determined That There Was No Flow in One of Four Injection Legs.Caused by Sticking of Valve in Safety Injection Discharge Line to 21 Cold Leg.Valve Was Cut Out of Sys & Replaced.With 990701 Ltr
ML18107A5211999-07-0101 July 1999
Rev 0 to Sgs Unit 2 ISI RFO Exam Results (S2RFO#10) Second Interval,Second Period,Second Outage (99RF).
ML18107A4351999-06-30030 June 1999
Monthly Operating Rept for June 1999 for Salem,Unit 1.With 990713 Ltr
ML18107A4341999-06-30030 June 1999
Monthly Operating Rept for June 1999 for Salem,Unit 2.With 990713 Ltr
ML20196H8621999-06-30030 June 1999
NRC Regulatory Assessment & Oversight Pilot Program, Performance Indicator Data, June 1999 Rept
ML18107A3951999-06-17017 June 1999
LER 99-004-00:on 990520,reactor Tripped from 100% Power,Due to Negative Flux Trip Signal from Nuclear Instrumentation. Cause Has Not Been Determined.Discoloration Was Identified on One of Penetrations.With 990617 Ltr
ML18107A3661999-06-0909 June 1999
LER 99-003-00:on 990513,unplanned Entry Into TS 3.0.3 Was Made.Caused by Human error.Re-positioned Creacs Supply Fan Selector Switches & Revised Procedures S1 & S2.OP-ST.SSP-0001(Q).With 990609 Ltr
ML18107A3551999-06-0202 June 1999
LER 99-005-00:on 990504,failure to Meet TS Action Statement Requirements for High Oxygen Concentration in Waste Gas Holdup Sys Occurred.Caused by Inability of Operators. Existing Procedures Will Be Evaluated.With 990602 Ltr
ML18107A3441999-06-0101 June 1999
Interim Part 21 Rept Re Premature Over Voltage Protection Actuation in Circuit Specific Application in Dc Power Supply.Testing & Evaluation Activities Will Be Completed on 990716
ML18107A3541999-06-0101 June 1999
LER 99-006-00:on 990501,HHSI Flow Balance Discrepancy Was Noted During Surveillance.Caused by Sticking of Check Valve in SI Discharge Line to 21 Cold Leg.Valve 21SJ17,was Cut Out of Sys & Replaced.With 990601 Ltr
ML18107A3681999-05-31031 May 1999
Monthly Operating Rept for May 1999 for Salem Generating Station,Unit 1.With 990611 Ltr
ML18107A3721999-05-31031 May 1999
Monthly Operating Rept for May 1999 for Salem Generating Station,Unit 2.With 990611 Ltr
ML18107A2931999-05-12012 May 1999
LER 99-002-00:on 990413,determined That Number 12 Auxiliary Bldg Exhaust Fan Was Rotating Backwards.Caused by mis-wiring of Motor Due to Human Error by Maint technician.Mis-wiring Was Corrected & Fan Was Returned to Svc.With 990512 Ltr
ML18107A2781999-05-10010 May 1999
LER 99-004-00:on 990411,automatic Actuation of ESF Occurred During Reactor Vessel Head Removal in Support of Refueling Operations.Caused by High Radiation Condition.Containment Atmosphere Was Monitored.With 990505 Ltr
ML18107A2791999-05-0404 May 1999
LER 99-003-00:on 990406,all Salem Unit 2 Chillers Rendered Inoperable.Caused by Human Error.Lessons Learned from Event Were Communicated to All Operators by Including Them in Night Orders.With 990504 Ltr
ML18107A2741999-05-0303 May 1999
LER 99-002-00:on 990405,determined That Containment Isolation Valve Failed as Found Leakrate Test.Caused by Foreign Matl Blocking Valves from Closing.Check Valve Mechanically Agitated.With 990504 Ltr
ML18107A3711999-04-30030 April 1999
Corrected Monthly Operating Rept for Apr 1999 for Salem Generating Station,Unit 1
ML18107A3151999-04-30030 April 1999
Submittal-Only Screening Review of Salem Generating Station Individual Plant Exam for External Events (Seismic Portion), Rev 1
ML18107A2991999-04-30030 April 1999
Monthly Operating Rept for Apr 1999 for Salem Unit 1.With 990514 Ltr
ML18107A2971999-04-30030 April 1999
Monthly Operating Rept for Apr 1999 for Salem Unit 2.With 990514 Ltr
ML18107A2351999-04-23023 April 1999
LER 99-001-00:on 990330,MSSV Failed Lift Set Test.Caused by Setpoint Variance Which Is Result of Aging.Valves Were Adjusted & Retested to Ensure TS Tolerance.With 990423 Ltr
ML18107A2881999-04-0707 April 1999
Rev 0 to NFS-0174, COLR for Salem Unit 2 Cycle 11.
ML18107A1821999-03-31031 March 1999
Monthly Operating Rept for Mar 1999 for Salem,Unit 1.With 990414 Ltr
ML18107A1831999-03-31031 March 1999
Monthly Operating Rept for Mar 1999 for Salem,Unit 2.With 990414 Ltr
ML18106B1471999-03-29029 March 1999
LER 99-001-00:on 990228,reactor Scram Was Noted as Result of Turbine Trip.Caused by Operator Error.Lesson Plans Revised to Explicitly Demonstrate Manner in Which Valve Functions. with 990329 Ltr
ML18106B1021999-02-28028 February 1999
Monthly Operating Rept for Feb 1999 for Salem Unit 2.With 990315 Ltr
ML18106B1011999-02-28028 February 1999
Monthly Operating Rept for Feb 1999 for Salem Unit 1.With 990315 Ltr
ML18106B0931999-02-25025 February 1999
Part 21 Rept Re Possible Defect in Swagelok Pipe Fitting Tee,Part Number SS-6-T.Caused by Crack Due to Improper Location of Heated Bar.Only One Part Out of 7396 Pieces in Forging Lot Was Found to Be Cracked.Affected Util,Notified
ML18106B0701999-02-16016 February 1999
LER 98-015-00:on 981208,inadvertent Discharge Through RHR Relief Valve During Startup Was Noted.Caused by Operator Performing Too Many Tasks Simultaneously.Appropriate Actions Have Been Taken IAW Policies & Procedures.With 990216 Ltr
ML18106B0551999-02-0101 February 1999
Part 21 Rept Re Possible Matl Defect in Swagelok Pipe Fitting Tee,Part Number SS-6-T.Defect Is Crack in Center of Forging.Analysis of Part Is Continuing & Further Details Will Be Provided IAW Ncr Timetables.Drawing of Part,Encl
ML18106B0561999-01-31031 January 1999
Monthly Operating Rept for Jan 1999 for Salem Generating Station,Unit 2.With 990212 Ltr
ML18106B0571999-01-31031 January 1999
Monthly Operating Rept for Jan 1999 for Salem Generating Station,Unit 1.With 990212 Ltr
ML20205P1671999-01-31031 January 1999
a POST-PLUME Phase, Federal Participation Exercise
ML18106B0441999-01-29029 January 1999
Part 21 Rept Re Possible Defect in Swagelok Pipe Fitting Tee Part Number SS-6-T.Caused by Crack in Center of Forging. Continuing Analysis of Part & Will Provide Details in Acoordance with NRC Timetables
ML18106B0491999-01-28028 January 1999
LER 98-007-01:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Caused by Transgranular Stress Corrosion Cracking.Replaced Affected Tubing.With 990128 Ltr
ML18106B0401999-01-18018 January 1999
LER 98-016-00:on 981219,ECCS Leakage Was Outside of Design Value.Caused by Leakage Past Seat of 21RH34 Manual Drain. Valve 21RH34 Was Reseated.With 990118 Ltr
ML18106B0251998-12-31031 December 1998
Monthly Operating Rept for Dec 1998 for Salem Unit 2.With 990115 Ltr
1999-09-30
[Table view] |
Text
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~'ffe.I
Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038-0236 Nuclear Business Unit JAN 1 5 1996 LR-N96006
- u. S. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 Gentlemen:
LER 311/95-008 SALEM GENERATING STATION - UNIT 2 FACILITY OPERATING LICENSE NO. DPR-75 DOCKET NO. 50-311 This License Event Report entitled "Technical Specification 4.9.9 Missed Isolation Initiation Testing is being submitted pursuant to the requirements of the Code of Federal Regulations 10 CFR5 0 . 7 3 (a) ( 2 ) ( i) ( b) .
S&reJuu_
Cla?warren * -
General Manager -
Salem Operations Attachment SORC Mtg.96-004 JEH/tcp C Distribution LER File 3.7 190<!29 9601190424 960115 PDR ADOCK 05000311 S PDR 95-2168 REV. 6/94
Attachment A The following items represent commitments that Public Service Electric & Gas (PSE&G) made to the Nuclear Regulatory Commission (NRC) relative to this LER (311/95-008-00) . The commitments are as follows:
- 1. A task specific procedure for Unit 1 will be developed to address all the requirements of Technical Specification 4.9.9. This will be completed prior to core alterations on Unit 1.
- 2. A Technical Specification Surveillance Improvement Project (TSSIP) has been initiated for Salem station. As part of the TSSIP, a review will be performed to ensure that each Technical Specification surveillance requirement is adequately proceduralized. The review will be completed in two stages. The first stage will involve verification that each Technical Specification surveillance requirement has an associated procedure which is listed in the Technical Specification matrix. These reviews will be prioritized such that Mode change requirements are verified prior to the applicable Mode change. Administrative processes will also be revised, as necessary, to ensure adequate controls are established for the revision of Technical Specification surveillance procedures. The first stage of the TSSIP will be complete prior to unit restart. The second stage of the TSSIP will, with exceptions, involve validation of the technical accuracy of the Technical Specification surveillance procedures. The exceptions will include inservice testing and inspection procedures, snubber inspection procedures and any procedures that will change significantly when Improved Technical Specifications are implemented. The second stage of the TSSIP is expected to be completed during 1997.
NRCFORM366 U.S. NUCLEAR REGULATORY COMMISSION
- APPROVED BY OMB NO. 3150-0104 (4-96) EXPIRES 04130198 EmMATED BURDEN PER RESPONSE TO COMPLY WITH THIS MANDATORY INFORMATION COLLECTION REQUEST: 50.0 HRS.
REPORTED LESSONS LEARNED ARE INCORPORATED INTO THE
- LICENSEE EVENT REPORT (LER) LICENSING PROCESS AND FED BACK TO INDUSTRY. FORWARD COMMENTS REGARDING BURDEN ESTIMATE TO THE INFORMATION AND RECORDS MANAGEMENT BRANCH (T~ ~~NUCLEAR (See reverse for required number of REGULATORY COMMISSION, WASHINGTON, DC , AND TO THE PAPERWORK REDUCTION PROJECT ~15CMl104), OFFICE OF digits/characters for each block) MANAGEMENT AND BUDGET, WASHINGTON, 20503. .
FACILITY NAllE (1) DOCKET NUllBER (2) PAGE(3)
SALEM GENERATING STATION - UNIT 2 05000311 .. 1 OF4 TITLE(4)
Technical Specification 4.9.9 Missed Isolation Testing EVENT DATE (5) LEA NUMBER (6) REPORT DATE (7) OTHER FACILITIES INVOLVED (8)
FACILITY NAME DO.CKET NUMBER MONTH DAY YEAR YEAR I SEQUENTIAL I REVISION MONTH DAY YEAR NUMBER NUMBER 05000 12 15 95 95 - 008 - 00 01 15 96 FACILITY NAME DOCKET NUMBER 05000 OPERATING 6 THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR §: (Check one or more) (11)
MODE(9) 20.2201(b) 20.2203(a)(2)(v) x 50. 73(a)(2)(i) 50. 73(a)(2)(viii)
POWER 0 20.2203(a)(1) 20.2203(a)(3)(i) 50. 1s(a)(2)(ii) 50. 73(a)(2)(x)
LEVEL (10) 20.2203(a)(2)(i) 20.2203(a)(3)(ii) 50. 73(a)(2)(iii) 73.71 20.2203(a)(2)(ii) 20.2203(a)(4) 50. 73(a)(2)(iv) OTHER 20.2203(a)(2)(iii) 50~36(c)(1) 50. 73(a)(2)(v) S~~ln Abstract below or in C Form 366A 20.2203(a)(2)(iv) 50.36(c)(2) 50. 73(a)(2)(vii)
LICENSEE CONTACT FOR THIS LER (12)
NAME TELEPHONE NUMBER (Include ArH Code)
.Scot Greenlee, Operations Support Technical Manager 609-339-3500 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13)
CAUSE SYSTEM COMPONENT MANUFACTURER REPORTABLE CAUSE SYSTEM COMPONENT MANUFACTURER REPORTABLE
- TONPRDS TONPRDS IYES SUPPLEMENTAL REPORT EXPECTED (14)
(If yes, complete EXPECTED SUBMISSION DATE).
IXINO EXPECTED SUBMISSION DATE (15)
MONTH DAY YEAR ABSTRACT (Limit to 1400 spaces, i.e., approximately 15 single-spaced typewritten lines) (16)
On December 15, 1995, a review identified that the requirements of Technical Specification 4.9.9 were never fully proceduralized at Unit 2.
Specifically, the surveillance procedure that has been used to implement Technical Specification 4.9.9 did not direct testing of the Containment Purge and Pressure-Vacuum Relief manual initiation function. Thus, with the exception of the current refueling outage, it is likely that the Unit 2 Containment Purge and Pressure-Vacuum Relief manual initiation function was never tested prior to or during core alterations. The most recent period of non-compliance was during the last core reload in late November through early December 1994. A similar issue of non-compliance did not exist at Unit 1. The cause of this occurrence was a lack of adequate controls for the development and revision of Technical Specification surveillance procedures. Corrective actions will verify the adequacy of Technical Specification surveillance procedures and will ensure that adequate controls are in place to maintain the adequacy of the procedures.
This event is re~ortable in accordance with 10 CFR 73 (a) (2) (i) (B) I any condition prohibited by the plant's Technical Specifications NRC FORM 388 (4-95)
NRC FORM 366A U.S. NUCLEAR REGULATORY COMMISSION (4-95)
LICENSEE EVENT REPORT (LER)
TEXT CONTINUATION FACILITY NAME (1)
SALEM GENERATING STATION - UNIT 2 DOCKET NUMBER (2) 05000311 LER NUMBER (6)
YEAR I SE3JIJ':J~AL I== 2 PAGE (3)
OF 4 95 - 008 - 00 TEXT (If more space i* required, ulle additional copies of NRC Form 366A) (17)
PLANT AND SYSTEM IDENTIFICATION Westinghouse - Pressurized Water Reactor Containment Purge and Pressure-Vacuum Relief {BF/-}*
- Energy Industry Identification System (EIIS) codes and component function identifier codes appear in the text as {SS/CC }
IDENTIFICATION OF OCCURRENCE Discovery Date: December 15, 1995 Event Dates: The most recent period of non-compliance was during the las*t core reload in late November through early December 1994. Prior to November 1994, it is l~kely that the same event occurred on each entry into core alterations and every seven days during core alterations since plant startup.
CONDITIONS PRIOR TO OCCURRENCE The plant would have been in Mode 6 or defueled prior to each' event.
There were no structures, components, or systems that were inoperable at the start of each event that contributed to the event.
DESCRIPTION OF OCCURRENCE On December 8, 1995, Unit 2 operators were making preparations for core alterations. A reactor operator was reviewing the Technical Specifications and identified a Unit 2 surveillance procedure that did not adequately address one of the tests required prior to core alterations. Specifically, Technical Specification 4.9.9 states, ~The Containment Purge and Pressure-Vacuum Relief isolation system shall be demonstrated OPERABLE within 100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br /> prior to the start of and at least once per 7 days during CORE ALTERATIONS by verifying that Containment Purge and Pressure-Vacuum Relief isolation occurs on manual initiation and on a high radiation test signal from each of the containment radiation monitoring instrumentation
- channels." The surveillance procedure that has been used to implement Technical Specification 4.9.9 did not direct testing of the Containment Purge and Pressure-Vacuum Relief manual initiation function. Additional testing was performed on December 8 that demonstrated the operability of the Unit 2 Containment Purge and Pressure-Vacuum Relief manual isolation function. Core alterations subsequently commenced with all required tests complete.
NRC FORM 366A (4-95)
-~ -
NRC FORM 366A . U.S. NUCLEAR REGULATORY COMMISSION (4-96) -
LICENSEE EVENT REPORT (LER)
TEXT CONTINUATION FACILITY NAME (1) DOCKET NUMBER (2) _ LER NUMBER 6) P_AGE (3) 05000311 YEAR I SEQUENTIAL NUMBER REVISION NUMBER 3 OF 4 SALEM GENERATING STATION - UNIT 2 95 - 008 - 00 TEXT (If more space is required, use additional copies of NRC Form 366A) (17)
DESCRIPTION OF OCCURRENCE - (cont'd)
A Containment Purge and Pressure-Vacuum Relief surveillance procedure history review for both units was performed. It revealed that testing of the manual initiation function had never been proceduralized at Unit 2.
Thus, with the exception of the current refueling outage, the Unit 2 Containment Purge and Pressure-Vacuum Relief manual initiation function most likely was never tested prior to or during core alterations. This noncompliance issue wa_"s identified on December 15, 1995. The most recent period of non-compliance was during the previous refueling outage, which occurred in late November through early December, 1994. The Unit 1 procedure history review further revealed that only the most recent revision of the pre-core alterations Containment Purge and Pressure-Vacuum Relief surveillance procedures, Sl.IC-FT.RM-0014(Q)-~lrlla Containment or Vent Air Particulate Proc~ss Radiation Monitor" and Sl.IC-FT.RM-0016(Q)-
"lrl2a Containment or Vent Gas Effluent Process Radiation Monitor", did not contain manual initiation testing requirements. These particular procedure revisions were never used.
CAUSE OF OCCURRENCE The cause of this occurrence was that the program which implemented Technical Specification test requirements in the late l970's did not have adequate controls to ensure that all testing requirements were properly addressed. In addition, the current programs do not have sufficient controls to identify similar existing deficiencies, or to prevent removal of steps from-procedures which are required to comply with existing Technical Specifications.
PRIOR SIMILAR OCCURRENCES Though there have been six previous missed surveillances over the last six years, a review of LERs for Salem Units 1 & 2 identified one LER related to missed surveillances due to procedural deficiencies during the last two years. This is:
LER 272/94-008 ~Quarterly Channel Ftinctional Testing of Position Indication For Power Operated Relief Valves Missed On Both Units" identified an occurrence where a procedure was revised in response to Generic Letter 90-06 without a revision to Technical Specifications which resulted in missed surveillance testing of Power Operated Relief Valves while in modes 1 & 2.
NRC FORM 366A (4-95)
.Q.... ..... ..
NRC FORM 368A . U.S. NUCLEAR REGULATORY COMMISSION i (4-95)
LICENSEE EVENT REPORT (LER)
. TEXT CONTINUATION.
FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER 6) PAGE (3) 05000311 YEAR I SEQUENTIAL NUMBER REVISION NUMBER 4 OF 4 SALEM GENERATING STATION - UNIT 2 95 - 008 - 00 TEXT (If more space is required, use additional copies of NRC Form 366A) (17)
SAFETY SIGNIFICANCE The safety significance for this incident is considered minimal since isolation bf the Containment Purge and Pressure-Vacuum Relief valves on a simulated high radiation signal is demonstrated as required by Technical Specification 4.9.9. The individual valves are routinely manipulated while in.Modes 5 and 6, which demonstrates proper manual circuit operation.
In adqition, Containment Purge and Pressure-Vacuum Relief isolation on the Phase A and Phase B manual isolation signals are also demonstrated to occur as required by Technical Specification 4.6.3.2.d on an 18 month frequen~y.
CORRECTIVE ACTIONS The immediate corrective action taken*was to verify the ability to manually close ~ach of the Containment Purge and Pressure-Vacuum Relief isolation valves from the Control Room.
The task specific procedure for Unit 2, Procedure S2.IC-FT.RM-0088(Q)-
"High Radiation Signal and Manual Initiation for Containment Isolation",
was revised to address the requirements of Technical Specification 4.9.9.
This procedure is now approved for use.
A task specific procedure for Unit 1 will be developed to address all the requirements of Technical Specification 4.9.9. This will be completed pribr to core alterations on Unit 1.-
A Technical Specification Surveillance Improvement Project (TSSIP) has been initiated for Salem station. As part of the TSSIP, a review will be performed to ensure that each Technical Specification surveillance requirement is adequately proceduralized. The review will be completed in two stages. The first stage will involve verification that each Technical Specification surveillance requirement has an associated procedure which is listed in the Technical Specifications matrix. These reviews will be prioritized such that Mode change requirements are verified prior to the applicable Mode change~ Administrative processes will also be. revised, as necessary, to ensure adequate controls are established for the revision of Technical Specification surveillance procedures. The first stage of the TSSIP will be complete prior to unit restart. The second stage of the TSSIP will, with exceptions, involve validation of the technical accuracy of the Technical Specification surveillance procedures. The exceptions will include inservice testing and inspection procedures, snubber inspection procedures and any procedures that will change significantly when Improved Technical Specifications are implemented. The second stage of the TSSIP is expected to be completed during 1997.
NRC FORM 366A (4-95)
