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| issue date = 12/10/1992
| issue date = 12/10/1992
| title = LER 92-016-00:on 921114,CR Operator Identified Analog Rod Position Indications for Control Rods 2C3 & 2C4 Greater than Step Deviation from Group Demand Counter.Caused by Sys Design.Sys May Be Replaced w/microprocessor.W/921210 Ltr
| title = LER 92-016-00:on 921114,CR Operator Identified Analog Rod Position Indications for Control Rods 2C3 & 2C4 Greater than Step Deviation from Group Demand Counter.Caused by Sys Design.Sys May Be Replaced w/microprocessor.W/921210 Ltr
| author name = POLLACK M J, VONDRA C A
| author name = Pollack M, Vondra 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: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:OPS~
Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station December 10, 1992 U. s. Nuclear Regulatory Commission Document Control Desk Washington, DC               20555


==Dear Sir:==
==Dear Sir:==
SALEM GENERATING STATION LICENSE NO. DPR-75 DOCKET NO. 50-311 UNIT NO. 2 LICENSEE EVENT REPORT 92-016-00 December 10, 1992 This Licensee Event requirements of the 50. 73 (a) (2) (i) (B). thirty (30) days of Report is being submitted pursuant to the Code of Federal Regulations lOCFR This report is required to be issued within event discovery.
 
MJP:pc Distribution The Energy People 9212220167.921210 PDR ADOCK 05000311 S
SALEM GENERATING STATION LICENSE NO. DPR-75 DOCKET NO. 50-311 UNIT NO. 2 LICENSEE EVENT REPORT 92-016-00 This Licensee Event               Report is being submitted pursuant to the requirements of the               Code of Federal Regulations 10CFR
* PDR Sincerely yours, 1/8t?4r C. A. General Manager -Salem Operations NRC FORM366 (6-89) U.S. NUCLEAR REGULATORY COMMISSION APPROVED OMB NO. 3150-0104 EXPIRES: 4/30/92 LICENSEE EVENT REPORT (LERI 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, WASHINGTON, DC 20503. FACILITY NAME (1) Salem Generating Station -Unit 2 'DOCKET NUMBER (2) I '" 131 01s101010131lP.
: 50. 73 (a) (2) (i) (B).           This report is required to be issued within thirty (30) days of              event discovery.
1loFOl4 TITLE (4) Tech $pee Entry 3.0.3; More Than *one Analog Rod Position Indicator Per Bank Inoperable.
Sincerely yours, 1/8t?4r C. A. e~
EVENT DATE (5) LER NUMBER (6) REPORT DATE (7) OTHER FACILITIES INVOLVED (8) MONTH DAY YEAR YEAR .f}
General Manager -
MONTH DAY YEAR FACILITY NAMES DOCKET NUMBER(S) i I 1 ii 4 9 2 9 I 2 -o I i I 6 -o I o ii 2 i lo .. 9 I 2 OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE OF 10 CFR §: (Cht1Ck on* or more of rh* following/  
Salem Operations MJP:pc Distribution The Energy People 9212220167.921210 PDR ADOCK 05000311 S
(11) --I-MODE (9) 2 1------......L....::..ji--.<
* PDR
Z0.402(b)
 
Z0.405(c) 50.73(1)(Z)(ivl Z0.405(1)(1  
NRC FORM366                                                                   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 (LERI                                                          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, WASHINGTON, DC 20503.
)(i) 50.38(c)(1l 50.73C1l12lM  
FACILITY NAME (1)                                                                                                                     DOCKET NUMBER (2)                 I       '" 131 Salem Generating Station - Unit 2                                                                                                    01s101010131lP.                     1loFOl4 TITLE (4)
--I--I--73.71(b) 73.71Ccl POWER l LEVEL QI Q Q,__ 1101 I Z0.405(1ll1 lWl lrlllllll=
Tech $pee Entry 3.0.3; More Than *one Analog Rod Position Indicator Per Bank Inoperable.
Z0.40li(1)(1  
EVENT DATE (5)                         LER NUMBER (6)                       REPORT DATE (7)                         OTHER FACILITIES INVOLVED (8)
)(iii) Z0.405(1)(1  
MONTH       DAY       YEAR     YEAR   .f} SE~~~~~~AL      ft~~~~~~        MONTH       DAY   YEAR               FACILITY NAMES                     DOCKET NUMBER(S) i I1      ii 4 9         2 9 2 -I             oI i I6    -       oIo      ii 2 i       lo.. 9 I2 OPERATING                 THIS REPORT IS SUBMITTED PURSUANT TO THE R~QUIREMENTS OF 10 CFR             &sect;: (Cht1Ck on* or more of rh* following/ (11)
)(Iv) Z0.40lll1l11 lM ,____ x 50.38Ccll2l
MODE (9)           2 l
-&0.73(1)(2)11) 50.73(1)(2)Cviil 50.73(1)(2)(vilil!Al 1--OTHER (SPlJcify in Absrr1cr b*low ind in T*xr. NRC Form 366AJ ,__ -li0.73(1)(2)(ii) 60.73(1)(2)(vlll)(Bl  
1------......L....::..ji--.< Z0.402(b)                                         Z0.405(c)                           50.73(1)(Z)(ivl                         73.71(b)
--I--50.73(1)(2)(ili) 50.73(1l12llxl LICENSEE CONTACT FOR THIS LER (12) NAME TELEPHONE NUMBER AREA CODE M.J. Pollack -LER Coordinator 6 I 019 31 3 19 1-I 2 IO f2 I 2 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13) CAUSE SYSTEM COMPONENT 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 C14l MONTH DAY YEAR n YES (If y*s, compl*r* EXPECTED SUBMISSION DATE} ABSTRACT (Limit ro. 1400 spoc*s, i.*., opproxim*t*ly fifr**n singlo-spoc*
I--
fyp*wrirr*n  
I-Z0.405(1)(1 )(i)                         50.38(c)(1l                         50.73C1l12lM                             73.71Ccl POWER                                                                                                                                               I--
/inosJ (16) EXPECTED SUBMISSION DATE (151 I I On il/i4/92, at 0001 hours, the Control Room Operator identified that Analog Rod Position Indications  
LEVEL         QI Q I Q,__                                                                                       50.73(1)(2)Cviil                        OTHER (SPlJcify in Absrr1cr 1101                           Z0.405(1ll1 lWl                   ,____  50.38Ccll2l 1--  b*low ind in T*xr. NRC Form lrlllllll=
{ARPis) for Control Rods 2C3 and 2C4 were indicating greater than a +/- 12 step deviation from their group demand counter. The Unit had been removed from service, on 11/12/92, in support of 21 Steam Generator Feed Pump (SGFP) and Heater Drain Pump maintenance.
Z0.40li(1)(1 )(iii)
Tech. Spec. 3.1.3.2.1 addresses the operability requirement of the "Reactivity Control System's" position indicating systems. The actions required if more than one ARPI per bank is inoperable exceeds the Tech. Spec. 3.1.3.2.1 Limiting Condition For Operation; therefore, actions associated with Tech. Spec. 3.0.3 apply (and was entered).
Z0.405(1)(1 )(Iv)
Based on Reactor Engineering assessment, it was determined that the actual rod position was correct and that rod position indication was incorrect.
Z0.40lll1l11 lM                   --
On 11/14/92, at 0153 hours, the 2C3 control rod position indication was adjusted and Tech. Spec. 3.0.3 was exited; however, Tech. Spec. 3.1.3.2.1 Action "a" remained in effect until 11/14/92, at 0633 hours, when calibrations were completed for rod 2C4. The root cause of the ARPis having greater than + 12 step deviation from their group demand counter, for the two (2) control rods, is attributed to system design. The ARPI system electronics settings will have some drift due to the analog stack coils' susceptibility to temperature changes. The ARPI system is being evaluated for replacement with a micro processor based system to eliminate temperature sensitivity of the ARPI coils. NRC Form 366 (6-89) I LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 2 DOCKET NUMBER 5000311 PLANT AND SYSTEM IDENTIFICATION:
x
Westinghouse  
                                                                        ,__    &0.73(1)(2)11) li0.73(1)(2)(ii) 50.73(1)(2)(ili)
-Pressurized Water Reactor LER NUMBER 92-016-00 PAGE 2 of 4 Energy Industry Identification System (EIIS) codes are identified in the text as {xx} IDENTIFICATION OF OCCURRENCE:
I--
Technical Specification 3.0.3 entry; more than one qnalog rod position indicator per bank inoperable due to system design Event Dates: 11/14/92 Report Date: 12/10/92 This report was initiated by Incident Report No. 92-756. CONDITIONS PRIOR TO OCCURRENCE:
50.73(1)(2)(vilil!Al 60.73(1)(2)(vlll)(Bl 50.73(1l12llxl 366AJ LICENSEE CONTACT FOR THIS LER (12)
Mode 2 (Startup)  
NAME                                                                                                                                                   TELEPHONE NUMBER AREA CODE M.J. Pollack - LER Coordinator                                                                                                         6 I 019         31 3 19 1- I 2 IO f2 I 2 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13)
-Rx Power 10-8 amps and stable DESCRIPTION OF OCCURRENCE:
CAUSE     SYSTEM       COMPONENT 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 C14l                                                                           MONTH     DAY     YEAR EXPECTED n                                                                                   ~NO SUBMISSION DATE (151 YES (If y*s, compl*r* EXPECTED SUBMISSION DATE}
I          I        I ABSTRACT (Limit ro. 1400 spoc*s, i.*., opproxim*t*ly fifr**n singlo-spoc* fyp*wrirr*n /inosJ (16)
On il/i4/92, at 0001 hours, the Control Room Operator identified that Analog Rod Position Indications {ARPis) for Control Rods 2C3 and 2C4 were indicating greater than a +/- 12 step deviation from their group demand counter. The Unit had been removed from service, on 11/12/92, in support of 21 Steam Generator Feed Pump (SGFP) and Heater Drain Pump maintenance. Tech. Spec. 3.1.3.2.1 addresses the operability requirement of the "Reactivity Control System's" position indicating systems. The actions required if more than one ARPI per bank is inoperable exceeds the Tech. Spec. 3.1.3.2.1 Limiting Condition For Operation; therefore, actions associated with Tech. Spec. 3.0.3 apply (and was entered). Based on Reactor Engineering assessment, it was determined that the actual rod position was correct and that rod position indication was incorrect. On 11/14/92, at 0153 hours, the 2C3 control rod position indication was adjusted and Tech. Spec. 3.0.3 was exited; however, Tech. Spec. 3.1.3.2.1 Action "a" remained in effect until 11/14/92, at 0633 hours, when calibrations were completed for rod 2C4. The root cause of the ARPis having greater than + 12 step deviation from their group demand counter, for the two (2) control rods, is attributed to system design. The ARPI system electronics settings will have some drift due to the analog stack coils' susceptibility to temperature changes. The ARPI system is being evaluated for replacement with a micro processor based system to eliminate temperature sensitivity of the ARPI coils.
NRC Form 366 (6-89)
 
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station       DOCKET NUMBER    LER NUMBER      PAGE Unit 2                           5000311         92-016-00      2 of 4 PLANT AND SYSTEM IDENTIFICATION:
Westinghouse - Pressurized Water Reactor Energy Industry Identification System (EIIS) codes are identified in the text as {xx}
IDENTIFICATION OF OCCURRENCE:
Technical Specification 3.0.3 entry; more than one qnalog rod position indicator per bank inoperable due to system design Event Dates: 11/14/92 Report Date: 12/10/92 This report was initiated by Incident Report No. 92-756.
CONDITIONS PRIOR TO OCCURRENCE:
Mode 2 (Startup) - Rx Power 10- 8 amps and stable DESCRIPTION OF OCCURRENCE:
On November 14, 1992, at 0001 hours, the Control Room Operator identified that Analog Rod Position Indications (ARPis) for Control Rods 2C3 and 2C4 were indicating greater than a + 12 step deviation from their group demand counter. The Unit had been removed from service, on November 12, 1992, in support of 21 Steam* Generator Feed Pump {SGFP) and Heater Drain Pump maintenance.
On November 14, 1992, at 0001 hours, the Control Room Operator identified that Analog Rod Position Indications (ARPis) for Control Rods 2C3 and 2C4 were indicating greater than a + 12 step deviation from their group demand counter. The Unit had been removed from service, on November 12, 1992, in support of 21 Steam* Generator Feed Pump {SGFP) and Heater Drain Pump maintenance.
Technical Specification 3.1.3.2.1 addresses the operability requirement of the "Reactivity Control System's" {AA} position indicating systems. The indicators are determined operable by verifying that the rod position indication system agrees within twelve {12) steps of the group demand counters.
Technical Specification 3.1.3.2.1 addresses the operability requirement of the "Reactivity Control System's" {AA} position indicating systems. The indicators are determined operable by verifying that the rod position indication system agrees within twelve {12) steps of the group demand counters. The actions required if more than one ARP! per bank is inoperable exceeds the Technical Specification 3.1.3.2.1 Limiting Condition For Operation; therefore, actions associated with Technical Specification 3.0.3 apply (and was entered on November 14, 1992).
The actions required if more than one ARP! per bank is inoperable exceeds the Technical Specification 3.1.3.2.1 Limiting Condition For Operation; therefore, actions associated with Technical Specification  
Technical Specification 3.0.3 states:
 
        "When a Limiting Condition for Operation is not met except as provided in the associated ACTION requirements, within one hour action shall be initiated to place the unit in a MODE in which the specification does not apply by placing it, as applicable, in:
====3.0.3 apply====
: 1. At least HOT STANDBY within the next 6 hours,
(and was entered on November 14, 1992). Technical Specification  
: 2. At least HOT SHUTDOWN within the following 6 hours, and
          . 3. At least COLD SHUTDOWN within the subsequent 24 hours.
Where corrective measures are completed that permit operation


====3.0.3 states====
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station       DOCKET NUMBER      LER NUMBER      PAGE Unit 2                           5000311         92-016-00      3 of 4 DESCRIPTION OF OCCURRENCE:   (cont'd) under the ACTION requirements, the ACTION may be taken in accordance with the specified time limits as measured from the time of failure to meet the Limiting Condition of Operation.
"When a Limiting Condition for Operation is not met except as provided in the associated ACTION requirements, within one hour action shall be initiated to place the unit in a MODE in which the specification does not apply by placing it, as applicable, in: 1. At least HOT STANDBY within the next 6 hours, 2. At least HOT SHUTDOWN within the following 6 hours, and . 3. At least COLD SHUTDOWN within the subsequent 24 hours. Where corrective measures are completed that permit operation 
Exceptions to these requirements are stated in the individual specifications."
' LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 2 DOCKET NUMBER 5000311 DESCRIPTION OF OCCURRENCE: (cont'd) LER NUMBER 92-016-00 PAGE 3 of 4 under the ACTION requirements, the ACTION may be taken in accordance with the specified time limits as measured from the time of failure to meet the Limiting Condition of Operation.
Based on Reactor Engineering assessment, which included a rod position trace for the two (2) rods, it was determined that the actual rod position was correct and that rod position indication was incorrect. On November 14, 1992, at 0153 hours, the 2C3 control rod position indication was adjusted and Technical Specification 3.0.3 was exited; however, Technical Specification 3.1.3.2.1 Action "a" remained in effect until November 14, 1992, at 0633 hours, when calibrations were completed for rod 2C4.
Exceptions to these requirements are stated in the individual specifications." Based on Reactor Engineering assessment, which included a rod position trace for the two (2) rods, it was determined that the actual rod position was correct and that rod position indication was incorrect.
The Nuclear Regulatory Commission was notified of the circumstances surrounding the entry into Technical Specification 3.0.3 on November 14, 1992, at 0153 hours, in accordance with Code of Federal Regulations 10CFR 50.72(b) (1) (i) (a).
On November 14, 1992, at 0153 hours, the 2C3 control rod position indication was adjusted and Technical Specification 3.0.3 was exited; however, Technical Specification 3.1.3.2.1 Action "a" remained in effect until November 14, 1992, at 0633 hours, when calibrations were completed for rod 2C4. The Nuclear Regulatory Commission was notified of the circumstances surrounding the entry into Technical Specification 3.0.3 on November 14, 1992, at 0153 hours, in accordance with Code of Federal Regulations lOCFR 50.72(b) (1) (i) (a). APPARENT CAUSE OF OCCURRENCE:
APPARENT CAUSE OF OCCURRENCE:
The root cause of the ARPis having greater than +/- 12 step deviation from their group demand counter, for the two (2) control rods, is attributed to system design. The ARP! system electronics settings, associated with the Westinghouse Signal Condition Module and Control Rod stack coil, will have some drift. This is due to the analog stack coils' susceptibility to temperature changes. The reactor had reduced power (from full power operation) to Mode 2 operation on 11/13/92 at 0617 hours. ANALYSIS OF OCCURRENCE:
The root cause of the ARPis having greater than +/- 12 step deviation from their group demand counter, for the two (2) control rods, is attributed to system design.
Operability of the ARPis is required to determine control rod positions.
The ARP! system electronics settings, associated with the Westinghouse Signal Condition Module and Control Rod stack coil, will have some drift. This is due to the analog stack coils' susceptibility to temperature changes. The reactor had reduced power (from full power operation) to Mode 2 operation on 11/13/92 at 0617 hours.
This ensures compliance with control rod alignment and insertion limits assumed in the accident analyses.
ANALYSIS OF OCCURRENCE:
Investigation of this event showed that actual rod positions (per group demand) were correct, with only the indication being wrong. This was determined from a Reactor Engineering assessment.
Operability of the ARPis is required to determine control rod positions. This ensures compliance with control rod alignment and insertion limits assumed in the accident analyses. Investigation of this event showed that actual rod positions (per group demand) were correct, with only the indication being wrong. This was determined from a Reactor Engineering assessment. However, had a control rod actually been misaligned, the appropriate Technical Specification Action Statement requirements would have been met.
However, had a control rod actually been misaligned, the appropriate Technical Specification Action Statement requirements would have been met. Actions to shutdown from Mode 2 had commenced in accordance with Technical srecification  
Actions to shutdown from Mode 2 had commenced in accordance with Technical srecification 3.0.3. Reactor power was reduced from 10" 8 amps to 10* amps as of 0059 hours. Upon completion of control rod 2C3 position indication adjustment, at 0153 hours, Technical Specifi~ation 3.0.3 was exited. Reactor power was returned to 10* 8 amps.


====3.0.3. Reactor====
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station           DOCKET NUMBER    LER NUMBER      PAGE Unit 2                               5000311         92-016-00      4 of 4 ANALYSIS OF OCCURRENCE:       (cont'd)
power was reduced from 10" 8 amps to 10* amps as of 0059 hours. Upon completion of control rod 2C3 position indication adjustment, at 0153 hours, Technical 3.0.3 was exited. Reactor power was returned to 10*8 amps.
The false rod positioning indication did not affect the health or safety of the public; however, since Technical Specification 3.0.3 was entered, this event is reportable to the Nuclear Regulatory Commission in accordance with Code of Federal Regulations 10CFR
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 2 DOCKET NUMBER 5000311 ANALYSIS OF OCCURRENCE: (cont'd) LER NUMBER 92-016-00 PAGE 4 of 4 The false rod positioning indication did not affect the health or safety of the public; however, since Technical Specification 3.0.3 was entered, this event is reportable to the Nuclear Regulatory Commission in accordance with Code of Federal Regulations lOCFR 50. 73 (a) (2) (i) (B). Although the ARPI system electronics is a design concern, it does not render the system inoperable.
: 50. 73 (a) (2) (i) (B).
The ARPI design and function performs as required by the Updated Safety Analysis Report (UFSAR). A similar Salem Unit 1 event occurred on August 25, 1992 during plant heatup (reference LER 272/92-021-00) after Unit l's tenth refueling outage. CORRECTIVE ACTION: As stated in the Description of Occurrence section, Technical Specification 3.0.3 was exited on November 14, 1992 at 0153 hours and Technical Specification 3.1.3.2.1 Action "a" (on November 14, 1992 at 0633 hours) upon completion of successful.control rod calibration.
Although the ARPI system electronics is a design concern, it does not render the system inoperable. The ARPI design and function performs as required by the Updated Safety Analysis Report (UFSAR). A similar Salem Unit 1 event occurred on August 25, 1992 during plant heatup (reference LER 272/92-021-00) after Unit l's tenth refueling outage.
The ARPI system is being evaluated for replacement with a micro processor based system to eliminate the temperature sensitivity of the ARPI coils. Implementation is being assessed as part of the Nuclear Department Resource Allocation Program. MJP:pc .. SORC Mtg. 92-121 General Manager -Salem Operations}}
CORRECTIVE ACTION:
As stated in the Description of Occurrence section, Technical Specification 3.0.3 was exited on November 14, 1992 at 0153 hours and Technical Specification 3.1.3.2.1 Action "a" (on November 14, 1992 at 0633 hours) upon completion of successful.control rod calibration.
The ARPI system is being evaluated for replacement with a micro processor based system to eliminate the temperature sensitivity of the ARPI coils.       Implementation is being assessed as part of the Nuclear Department Resource Allocation Program.
                                                ~a:?oL-?,v
                                                  ~~
General Manager -
Salem Operations MJP:pc .
SORC Mtg. 92-121}}

Latest revision as of 06:23, 3 February 2020

LER 92-016-00:on 921114,CR Operator Identified Analog Rod Position Indications for Control Rods 2C3 & 2C4 Greater than Step Deviation from Group Demand Counter.Caused by Sys Design.Sys May Be Replaced w/microprocessor.W/921210 Ltr
ML18096B161
Person / Time
Site: Salem PSEG icon.png
Issue date: 12/10/1992
From: Pollack M, Vondra C
Public Service Enterprise Group
To:
NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
LER-92-016-01, LER-92-16-1, NUDOCS 9212220167
Download: ML18096B161 (5)
v • d • e


Text

OPS~

Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station December 10, 1992 U. s. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555

Dear Sir:

SALEM GENERATING STATION LICENSE NO. DPR-75 DOCKET NO. 50-311 UNIT NO. 2 LICENSEE EVENT REPORT 92-016-00 This Licensee Event Report is being submitted pursuant to the requirements of the Code of Federal Regulations 10CFR

50. 73 (a) (2) (i) (B). This report is required to be issued within thirty (30) days of event discovery.

Sincerely yours, 1/8t?4r C. A. e~

General Manager -

Salem Operations MJP:pc Distribution The Energy People 9212220167.921210 PDR ADOCK 05000311 S

NRC FORM366 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 (LERI 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, WASHINGTON, DC 20503.

FACILITY NAME (1) DOCKET NUMBER (2) I '" 131 Salem Generating Station - Unit 2 01s101010131lP. 1loFOl4 TITLE (4)

Tech $pee Entry 3.0.3; More Than *one Analog Rod Position Indicator Per Bank Inoperable.

EVENT DATE (5) LER NUMBER (6) REPORT DATE (7) OTHER FACILITIES INVOLVED (8)

MONTH DAY YEAR YEAR .f} SE~~~~~~AL ft~~~~~~ MONTH DAY YEAR FACILITY NAMES DOCKET NUMBER(S) i I1 ii 4 9 2 9 2 -I oI i I6 - oIo ii 2 i lo.. 9 I2 OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE R~QUIREMENTS OF 10 CFR §: (Cht1Ck on* or more of rh* following/ (11)

MODE (9) 2 l

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LEVEL QI Q I Q,__ 50.73(1)(2)Cviil OTHER (SPlJcify in Absrr1cr 1101 Z0.405(1ll1 lWl ,____ 50.38Ccll2l 1-- b*low ind in T*xr. NRC Form lrlllllll=

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50.73(1)(2)(vilil!Al 60.73(1)(2)(vlll)(Bl 50.73(1l12llxl 366AJ LICENSEE CONTACT FOR THIS LER (12)

NAME TELEPHONE NUMBER AREA CODE M.J. Pollack - LER Coordinator 6 I 019 31 3 19 1- I 2 IO f2 I 2 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13)

CAUSE SYSTEM COMPONENT 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 C14l MONTH DAY YEAR EXPECTED n ~NO SUBMISSION DATE (151 YES (If y*s, compl*r* EXPECTED SUBMISSION DATE}

I I I ABSTRACT (Limit ro. 1400 spoc*s, i.*., opproxim*t*ly fifr**n singlo-spoc* fyp*wrirr*n /inosJ (16)

On il/i4/92, at 0001 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, the Control Room Operator identified that Analog Rod Position Indications {ARPis) for Control Rods 2C3 and 2C4 were indicating greater than a +/- 12 step deviation from their group demand counter. The Unit had been removed from service, on 11/12/92, in support of 21 Steam Generator Feed Pump (SGFP) and Heater Drain Pump maintenance. Tech. Spec. 3.1.3.2.1 addresses the operability requirement of the "Reactivity Control System's" position indicating systems. The actions required if more than one ARPI per bank is inoperable exceeds the Tech. Spec. 3.1.3.2.1 Limiting Condition For Operation; therefore, actions associated with Tech. Spec. 3.0.3 apply (and was entered). Based on Reactor Engineering assessment, it was determined that the actual rod position was correct and that rod position indication was incorrect. On 11/14/92, at 0153 hours0.00177 days <br />0.0425 hours <br />2.529762e-4 weeks <br />5.82165e-5 months <br />, the 2C3 control rod position indication was adjusted and Tech. Spec. 3.0.3 was exited; however, Tech. Spec. 3.1.3.2.1 Action "a" remained in effect until 11/14/92, at 0633 hours0.00733 days <br />0.176 hours <br />0.00105 weeks <br />2.408565e-4 months <br />, when calibrations were completed for rod 2C4. The root cause of the ARPis having greater than + 12 step deviation from their group demand counter, for the two (2) control rods, is attributed to system design. The ARPI system electronics settings will have some drift due to the analog stack coils' susceptibility to temperature changes. The ARPI system is being evaluated for replacement with a micro processor based system to eliminate temperature sensitivity of the ARPI coils.

NRC Form 366 (6-89)

LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 2 5000311 92-016-00 2 of 4 PLANT AND SYSTEM IDENTIFICATION:

Westinghouse - Pressurized Water Reactor Energy Industry Identification System (EIIS) codes are identified in the text as {xx}

IDENTIFICATION OF OCCURRENCE:

Technical Specification 3.0.3 entry; more than one qnalog rod position indicator per bank inoperable due to system design Event Dates: 11/14/92 Report Date: 12/10/92 This report was initiated by Incident Report No.92-756.

CONDITIONS PRIOR TO OCCURRENCE:

Mode 2 (Startup) - Rx Power 10- 8 amps and stable DESCRIPTION OF OCCURRENCE:

On November 14, 1992, at 0001 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, the Control Room Operator identified that Analog Rod Position Indications (ARPis) for Control Rods 2C3 and 2C4 were indicating greater than a + 12 step deviation from their group demand counter. The Unit had been removed from service, on November 12, 1992, in support of 21 Steam* Generator Feed Pump {SGFP) and Heater Drain Pump maintenance.

Technical Specification 3.1.3.2.1 addresses the operability requirement of the "Reactivity Control System's" {AA} position indicating systems. The indicators are determined operable by verifying that the rod position indication system agrees within twelve {12) steps of the group demand counters. The actions required if more than one ARP! per bank is inoperable exceeds the Technical Specification 3.1.3.2.1 Limiting Condition For Operation; therefore, actions associated with Technical Specification 3.0.3 apply (and was entered on November 14, 1992).

Technical Specification 3.0.3 states:

"When a Limiting Condition for Operation is not met except as provided in the associated ACTION requirements, within one hour action shall be initiated to place the unit in a MODE in which the specification does not apply by placing it, as applicable, in:

1. At least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />,
2. At least HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, and

. 3. At least COLD SHUTDOWN within the subsequent 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

Where corrective measures are completed that permit operation

LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 2 5000311 92-016-00 3 of 4 DESCRIPTION OF OCCURRENCE: (cont'd) under the ACTION requirements, the ACTION may be taken in accordance with the specified time limits as measured from the time of failure to meet the Limiting Condition of Operation.

Exceptions to these requirements are stated in the individual specifications."

Based on Reactor Engineering assessment, which included a rod position trace for the two (2) rods, it was determined that the actual rod position was correct and that rod position indication was incorrect. On November 14, 1992, at 0153 hours0.00177 days <br />0.0425 hours <br />2.529762e-4 weeks <br />5.82165e-5 months <br />, the 2C3 control rod position indication was adjusted and Technical Specification 3.0.3 was exited; however, Technical Specification 3.1.3.2.1 Action "a" remained in effect until November 14, 1992, at 0633 hours0.00733 days <br />0.176 hours <br />0.00105 weeks <br />2.408565e-4 months <br />, when calibrations were completed for rod 2C4.

The Nuclear Regulatory Commission was notified of the circumstances surrounding the entry into Technical Specification 3.0.3 on November 14, 1992, at 0153 hours0.00177 days <br />0.0425 hours <br />2.529762e-4 weeks <br />5.82165e-5 months <br />, in accordance with Code of Federal Regulations 10CFR 50.72(b) (1) (i) (a).

APPARENT CAUSE OF OCCURRENCE:

The root cause of the ARPis having greater than +/- 12 step deviation from their group demand counter, for the two (2) control rods, is attributed to system design.

The ARP! system electronics settings, associated with the Westinghouse Signal Condition Module and Control Rod stack coil, will have some drift. This is due to the analog stack coils' susceptibility to temperature changes. The reactor had reduced power (from full power operation) to Mode 2 operation on 11/13/92 at 0617 hours0.00714 days <br />0.171 hours <br />0.00102 weeks <br />2.347685e-4 months <br />.

ANALYSIS OF OCCURRENCE:

Operability of the ARPis is required to determine control rod positions. This ensures compliance with control rod alignment and insertion limits assumed in the accident analyses. Investigation of this event showed that actual rod positions (per group demand) were correct, with only the indication being wrong. This was determined from a Reactor Engineering assessment. However, had a control rod actually been misaligned, the appropriate Technical Specification Action Statement requirements would have been met.

Actions to shutdown from Mode 2 had commenced in accordance with Technical srecification 3.0.3. Reactor power was reduced from 10" 8 amps to 10* amps as of 0059 hours6.828704e-4 days <br />0.0164 hours <br />9.755291e-5 weeks <br />2.24495e-5 months <br />. Upon completion of control rod 2C3 position indication adjustment, at 0153 hours0.00177 days <br />0.0425 hours <br />2.529762e-4 weeks <br />5.82165e-5 months <br />, Technical Specifi~ation 3.0.3 was exited. Reactor power was returned to 10* 8 amps.

LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 2 5000311 92-016-00 4 of 4 ANALYSIS OF OCCURRENCE: (cont'd)

The false rod positioning indication did not affect the health or safety of the public; however, since Technical Specification 3.0.3 was entered, this event is reportable to the Nuclear Regulatory Commission in accordance with Code of Federal Regulations 10CFR

50. 73 (a) (2) (i) (B).

Although the ARPI system electronics is a design concern, it does not render the system inoperable. The ARPI design and function performs as required by the Updated Safety Analysis Report (UFSAR). A similar Salem Unit 1 event occurred on August 25, 1992 during plant heatup (reference LER 272/92-021-00) after Unit l's tenth refueling outage.

CORRECTIVE ACTION:

As stated in the Description of Occurrence section, Technical Specification 3.0.3 was exited on November 14, 1992 at 0153 hours0.00177 days <br />0.0425 hours <br />2.529762e-4 weeks <br />5.82165e-5 months <br /> and Technical Specification 3.1.3.2.1 Action "a" (on November 14, 1992 at 0633 hours0.00733 days <br />0.176 hours <br />0.00105 weeks <br />2.408565e-4 months <br />) upon completion of successful.control rod calibration.

The ARPI system is being evaluated for replacement with a micro processor based system to eliminate the temperature sensitivity of the ARPI coils. Implementation is being assessed as part of the Nuclear Department Resource Allocation Program.

~a:?oL-?,v

~~

General Manager -

Salem Operations MJP:pc .

SORC Mtg.92-121

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