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{{#Wiki_filter:'-" I i 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:'-" i OPS~G I
Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 .
Salem Generating Station July 23, 1992 U. s. Nuclear Regulatory Commission Document Control Desk Washington, DC                   20555


==Dear Sir:==
==Dear Sir:==
SALEM GENERATING STATION LICENSE NO. DPR-70 DOCKET NO. 50-272 UNIT NO. 1 LICENSEE EVENT REPORT 92-014-00 July 23, 1992 This Licensee Event Report is a voluntary report being submitted .pµrsuant to the requirements of the Code of Federal Regulations lOCFR Distribution , .... .......,, ,, -. . I. tqt**') ....,. ....
 
... Sincerely yours, c. A Vondra General Manager -Salem Operations 9207310112 PDR ADOCK PDR s The Energy People /,fj:J:Y / vl./ ) (/ 95-2.189 (10M) 12-8
SALEM GENERATING STATION LICENSE NO. DPR-70 DOCKET NO. 50-272 UNIT NO. 1 LICENSEE EVENT REPORT 92-014-00 This Licensee Event Report is a voluntary report being submitted
*,. NRC FORM 366 (6-891 U.S. NUCLEAR REGULATORY COMMISSION APPROVED OMB NO. 3150-0104 LICENSEE EVENT REPORT (LER) EXPIRES: 4/30/92 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-5301. U.S. NUCLEAR REGUL.ATORV COMMISSION, WASHINGTON, DC 20555, AND TO .. THE PAPERWORK REDUCTION PROJECT* (3150-0104), OFFICE OF MANAGEMENT AND BUDGET, WASHINGTON, DC 20503. FACILITY NAME (1)
          .pµrsuant to the requirements of the Code of Federal Regulations 10CFR 50~73.
Station -Unit 1 TITLE (4) Steam Generator feedwater oioina linear indications.
Sincerely yours,
EVENT DATE (5) LEA NUMBER (6) REPORT DATE (71 OTHER FACILITIES INVOLVED (Bl MONTH DAY YEAR YEAR J/:
: c. A Vondra General Manager -
((
Salem Operations Distribution
MONTH DAY . YEAR FACILITY NAMES DOCKET NUMBER(Sl 01s1010101  
      .,....I. ~
*1 I al 6 6 9 2 91 2 -o I 11 4 -o I o o I 1 2 13 9 l 2 o 1510 10 jo1 I *1 OPERATING MODE (9) 5 THIS REPORT IS SUBMITTED PURSUANT TO THE OF 10 CFR §: (Chock on* or moro of rh* following}
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(11) 20.402(b) 20.405(c) 60.73(*1(2lliv) 73:71 (bl 73.71(cl NAME --'--20.405(1)(1  
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)(i) 50.38(c)(1)
9207310112 6;86g~72 PDR ADOCK         PDR s
--20.405(0)(1  
The Energy People
)(Ii) 50.36(c)(21
                                                                                                        /,fj:J:Y )
--20.405(0)(1  
                                                                                                        / vl./
)(ill) 50.73l*ll2llil
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-....._ 20.4ris(o)(1  
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)(Iv) li0.73(11(21(ii)
 
....._ ....._ 20.406(1)(11M 50.73(oll2lliill LICENSEE CONTACT FOR THIS LEA (12) 60.731oll21M 60.73!1)(2)(vii) 50.73(1)(21(viiil(A) 60.73(o)(21(viiil(B) 60.73(o)(211xl AREA CODE -OTHER (S{Hcify in Abstract btJ/ow and in Text, NRC Form 366AI Voluntary TELEPHO.NE NUMBER 1=. In l *q I q I -I? I n I? I ? COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (131 CAUSE SYSTEM COMPONENT TURER SYSTEM COMPONENT MANUFAC* TUR ER I I I I I I I I I I I I I I I I I I I I I I I I I I I I SUPPLEMENTAL REPORT EXPECTED (14) EXPECTED MONTH DAY VEAR SUBMISSION DATE 1151 I YES ilf y6S, EXPECTED SUBMISSION DATE} I -I I ABSTRACT (Limit to 1400 spaces, i.e., approxim11t9/y fifteBn single-space typewritten lines) (161 On June 26, +992, results of radiographic (RT) examinations on Steam Generator (S/G) 13 indicated that the weld between the feedwater nozzle and the elbow {SJ} had a number of unacceptable linear indications as per ASME Code. RT of the second weld did not indicate any evidence of unacceptable indications.
NRC FORM 366                                                                     U.S. NUCLEAR REGULATORY COMMISSION (6-891                                                                                                                                          APPROVED OMB NO. 3150-0104 EXPIRES: 4/30/92 ESTIMATED BURDEN .PER RESPONSE TO COMPLY WTH THIS INFORMATION COLLECTION REQUEST: 50.0 HRS. FORWARD
Results of ultrasonic (UT) *and RT inspections, on S/Gs 12 and 14, indicated that the expander fittings had linear* indications .on both the nozzle to expander and expander to elbow welds. RT of the third weld did not indicate any evidence of unacceptable indications.
*,.                                      LICENSEE EVENT REPORT (LER)                                                              COMMENTS REGARDING BURDEN ESTIMATE TO THE RECORDS AND REPORTS MANAGEMENT BRANCH (P-5301. U.S. NUCLEAR REGUL.ATORV COMMISSION, WASHINGTON, DC 20555, AND TO ..
After discovery of the feedwater pipe weld-nonconformances, additional detailed examinations were conducted which included visual examination, ultrasonic examination; and dye penetrant examination.
THE PAPERWORK REDUCTION PROJECT* (3150-0104), OFFICE OF MANAGEMENT AND BUDGET, WASHINGTON, DC 20503.
Additional linear indications were identified.
FACILITY NAME (1)
The cause of this event is attributed*
Sal 0 ~ r- 0 n°~atina                Station - Unit 1 TITLE (4)
to equipment failure. Investigation into the root cause of the linear indications.is continuing.
Steam Generator feedwater oioina linear indications.
Two (2) S"xlO" weld samples have been sent for laboratory*
EVENT DATE (5)                         LEA NUMBER (6)                           REPORT DATE (71                         OTHER FACILITIES INVOLVED (Bl MONTH       DAY       YEAR       YEAR   J/: SE~~~~~~AL      (( ~~~~~~        MONTH       DAY . YEAR                 FACILITY NAMES                     DOCKET NUMBER(Sl 01s1010101 *1                   I al   6     ~  6 9         2 91 2 -           oI      11 4 -   o Io o I 1               2   13 9 2l                                                      o 1510 10 jo1             I *1 THIS REPORT IS SUBMITTED PURSUANT TO THE R~QUIREMENTS OF 10 CFR               §: (Chock on* or moro of rh* following} (11)
analysis.
OPERATING MODE (9) 5        20.402(b) 20.405(c) 60.73(*1(2lliv)
Based upon results of the root cause analysis, other corrective action will be assessed.
                                                                                                                                                                -    73:71 (bl 20.405(1)(1 )(i) 20.405(0)(1 )(Ii) 20.405(0)(1 )(ill) 50.38(c)(1) 50.36(c)(21 50.73l*ll2llil 60.731oll21M 60.73!1)(2)(vii) 50.73(1)(21(viiil(A) 73.71(cl OTHER (S{Hcify in Abstract btJ/ow and in Text, NRC Form 366AI 20.4ris(o)(1 )(Iv)                          li0.73(11(21(ii)                      60.73(o)(21(viiil(B) 20.406(1)(11M                              50.73(oll2lliill                      60.73(o)(211xl                         Voluntary LICENSEE CONTACT FOR THIS LEA (12)
All linear indications found.have been removed by excavating and blending.
NAME                                                                                                                                                        TELEPHO.NE NUMBER AREA CODE 1=. In l *q     ~ I~  I q I - I? I n I? I ?
Observed pitting was removed. New reducing spool pieces have been installed at the inlet to the S/Gs. All 4 Unit 1 S/G expander-to-feedwater nozzle welds will be examined at the next refueling outage. Additional examinations are being assessed.
COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (131 MANUFAC-                                                                                      MANUFAC*
CAUSE     SYSTEM       COMPONENT                                                                         SYSTEM       COMPONENT TURER                                                                                          TUR ER I         I   I   I         I     I   I                                                 I           I   I     I       I   I   I I         I I       I         I     I   I                                                 I           I I       I       I   I   I SUPPLEMENTAL REPORT EXPECTED (14)                                                                                 MONTH     DAY     VEAR EXPECTED SUBMISSION I       YES ilf y6S, c~mpl*I* EXPECTED SUBMISSION DATE}
DATE 1151 I         I       I -
ABSTRACT (Limit to 1400 spaces, i.e., approxim11t9/y fifteBn single-space typewritten lines) (161 On June 26, +992, results of radiographic (RT) examinations on Steam Generator (S/G) 13 indicated that the weld between the feedwater nozzle and the elbow {SJ} had a number of unacceptable linear indications as per ASME Code. RT of the second weld did not indicate any evidence of unacceptable indications. Results of ultrasonic (UT) *and RT inspections, on S/Gs 12 and 14, indicated that the expander fittings had linear*
indications .on both the nozzle to expander and expander to elbow welds.
RT of the third weld did not indicate any evidence of unacceptable indications. After discovery of the feedwater pipe weld- nonconformances, additional detailed examinations were conducted which included visual examination, ultrasonic examination; and dye penetrant examination.
Additional linear indications were identified. The cause of this event is attributed* to equipment failure.                                                           Investigation into the root cause of the linear indications.is continuing. Two (2) S"xlO" weld samples have been sent for laboratory* analysis. Based upon results of the root cause analysis, other corrective action will be assessed. All linear indications found.have been removed by excavating and blending. Observed pitting was removed. New reducing spool pieces have been installed at the inlet to the S/Gs. All 4 Unit 1 S/G expander-to-feedwater nozzle welds will be examined at the next refueling outage. Additional examinations are being assessed.
NRC Form 366 (6-89)
NRC Form 366 (6-89)
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 1 DOCKET NUMBER 5000272 PLANT AND SYSTEM IDENTIFICATION:
 
LER NUMBER 92-014-00 . PAGE 2 of 5 Westinghouse  
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station       DOCKET NUMBER       LER NUMBER     . PAGE Unit 1                              5000272        92-014-00       2 of 5 PLANT AND SYSTEM IDENTIFICATION:
-Pressurized Water Reactor; Series 51 Steam Generators Energy Industry Identification System (EIIS) codes are identified in the text as {xx} IDENTIFICATION OF OCCURRENCE:.
Westinghouse   - Pressurized Water Reactor; Series 51 Steam Generators Energy Industry Identification System (EIIS) codes are identified in the text as {xx}
steam Generator feedwater piping linear* indications Event Date: 6/26/92 Report Date! 7/23/92 This repbrt was initiated by Incident Report Nos. 92-400, 92-404, 92-405, 92-406, and 92-407. CONDITIONS PRIOR TO OCCURRENCE:
IDENTIFICATION OF OCCURRENCE:.
steam Generator feedwater piping linear* indications Event Date:   6/26/92 Report Date!   7/23/92 This repbrt was initiated by Incident Report Nos. 92-400, 92-404, 92-405, 92-406, and 92-407.
CONDITIONS PRIOR TO OCCURRENCE:
Mode 5 (Cold Shutdown)
Mode 5 (Cold Shutdown)
DESCRIPTION OF OCCURRENCE:
DESCRIPTION OF OCCURRENCE:
On June 26, 1992, results of radiographic (RT) examinations on Steam Generator (S/G) 13 indicated that the weld between the feedwater nozzle and the elbow {SJ} had a number of unacceptable linear indications as per ASME. Code. RT of the second weld did not indicate any evidence of unacceptable indications.
On June 26, 1992, results of radiographic (RT) examinations on Steam Generator (S/G) 13 indicated that the weld between the feedwater nozzle and the elbow {SJ} had a number of unacceptable linear indications as per ASME. Code. RT of the second weld did not indicate any evidence of unacceptable indications. Results of ultrasonic (UT) and RT inspections, on S/Gs 12 and 14, indicated that the expander fittings had linear indications on both the nozzle to ~xpander and expander to elbow welds. RT of the third weid (i.e., the weld between the elbow and the pipe) did not indicate any evidence of unacceptable indications. There were no unacceptable indications identified on S/G 11 nozzle fitting during the RT and UT examinations.
Results of ultrasonic (UT) and RT inspections, on S/Gs 12 and 14, indicated that the expander fittings had linear indications on both the nozzle to and expander to elbow welds. RT of the third weid (i.e., the weld between the elbow and the pipe) did not indicate any evidence of unacceptable indications.
This examination was prompted by recent S/G feedwater nozzle leakage concerns at Sequoyah Generating station.
There were no unacceptable indications identified on S/G 11 nozzle fitting during the RT and UT examinations.
Upon discovery of the S/G feedwater piping linear indications, the Nuclear Reguiatory Commission (NRC) was notified per Code of Federal Regulations 10CFR 50.72(b} (2) (iii).
This examination was prompted by recent S/G feedwater nozzle leakage concerns at Sequoyah Generating station. Upon discovery of the S/G feedwater piping linear indications, the Nuclear Reguiatory Commission (NRC) was notified per Code of Federal Regulations 10CFR 50.72(b} (2) (iii). APPARENT CAUSE OF OCCURRENCE:
APPARENT CAUSE OF OCCURRENCE:
The cause of this event is attributed to equipment failure. Investigation into the root cause of the linear indications is continuing.
The cause of this event is attributed to equipment failure.
Two (2) 8 11 xl0 11 weld samples have been sent for laboratory analysis.
Investigation into the root cause of the linear indications is continuing. Two (2) 8 11 xl0 11 weld samples have been sent for laboratory analysis.
In 1979, similar S/G feedwater nozzle/feedwater piping connection LICENSEE-EVENT REPORT (LER) TEXT CONTINUATION s*alem Generating . Station Unit 1 DOCKET NUMBER 5000272 APPARENT CAUSE OF OCCURRENCE*: (cont Id) LER NUMBER 92...;014-00 PAGE 3 of 5-linear indications were identified and corrected (reference 272/79-46).
In 1979, similar S/G feedwater nozzle/feedwater piping connection
The 1979 examination was in response to NRC Bulletin 79-13. Per a commitment, made in response to the Bulletin, additional S/G examinations were made during the following refueling outage in 1980. One linear discontinuity (approximately 1 11 long) was found.-It was determined to be an unfused area in the-root portion of the butt weld on the elbow side -(reference LER 272/80-:'55).
 
_ I.t is not related to the 1979 linear indication concerns.
LICENSEE-EVENT REPORT (LER) TEXT CONTINUATION s*alem Generating . Station     DOCKET NUMBER     LER NUMBER       PAGE Unit 1                              5000272        92...;014-00     3 of 5-APPARENT CAUSE OF OCCURRENCE*:    (cont Id) linear indications were identified and corrected (reference     LE~
No other unacceptable indications were observed.
272/79-46). The 1979 examination was in response to NRC Bulletin 79-13. Per a commitment, made in response to the Bulletin, additional S/G examinations were made during the following refueling outage in 1980. One linear discontinuity (approximately 1 11 long) was found.- It was determined to be an unfused area in the- root portion of the butt weld on the elbow side - (reference LER 272/80-:'55). _I.t is not related to the 1979 linear indication concerns. No other unacceptable line~r indications were observed.
S/G.exaininations continued through 1984 with no additional observed indications.
S/G.exaininations continued through 1984 with no additional observed linea~ indications.
Investigation of the 1979 linear indications identified the cause as corrosion assisted thermal fatigue. Specifically, a fatigue loading mechanism was induced by thermal stratification and striping during cold low flow, feedwater injections.
Investigation of the 1979 linear indications identified the cause as corrosion assisted thermal fatigue. Specifically, a fatigue loading mechanism was induced by thermal stratification and striping during cold low flow, feedwater injections. Other significant contributing factors included high oxygen-exposure, counterbore geometry, and the number* of times that large temperature differences (stratification) exist during heatup, hot standby and low power operations~
Other significant contributing factors included high oxygen-exposure, counterbore geometry, and the number* of times that large temperature differences (stratification) exist during heatup, hot standby and low power ANALYSIS OF OCCURRENCE:
ANALYSIS OF OCCURRENCE:
After discovery and removal of the 12, 13, and 14 S/G feedwater.pipe  
After discovery and removal of the 12, 13, and 14 S/G feedwater.pipe -
-weld nonconformances, additional detailed examinati0ns were conducted.
weld nonconformances, additional detailed examinati0ns were conducted. They included: 1) visual examination of the four (4) S/G nozzles' internal diameter; 2) ultrasonic examination of the thermal sleeve; and 3) dye penetrant {PT) examination from the counterbore region up to and including the thermal sleeve. Results were:
They included:
11 S/G     np unacceptable indications in the counterbore areas however, visual and PT examination identified linear indications on the nozzle ID surfaces close to the thermal sleeve 12 S/G -   linear indications observed (by PT) in the counterbore area, minor linear indications close to the thermal sleeve, some rounded indiqations close to the thermal sleeve, and vis_ual observation of erosion of the thermal sleeve resulting in larger than design gaps between the thermal sleeve and the S/G feedwater nozzle
: 1) visual examination of the four (4) S/G nozzles' internal diameter;
* 13 S/G     linear indications observed (by PT) near the thermal sleeve and visual observation of minor pitting ~nd erosion in the-area before the thermal sleeve 14 S/G-     linear_indications observed (by PT) at the weld root, in the counterbore area, and near _the thermal sleeve; also, visual observation of erosion of the thermal
: 2) ultrasonic examination of the thermal sleeve; and 3) dye penetrant
 
{PT) examination from the counterbore region up to and including the thermal sleeve. Results were: 11 S/G np unacceptable indications in the counterbore areas however, visual and PT examination identified linear indications on the nozzle ID surfaces close to the thermal sleeve 12 S/G -linear indications observed (by PT) in the counterbore area, minor linear indications close to the thermal sleeve, some rounded indiqations close to the thermal sleeve, and vis_ual observation of erosion of the thermal sleeve resulting in larger than design gaps between the thermal sleeve and the S/G feedwater nozzle
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating station         DOCKET NUMBER     LER NUMBER       . PAGE Unit 1                              5000272        92-014-00       4 of 5 ANALYSIS OF OCCURRENCE:      (cont'd) sleeve resulting in larger than design gaps between the thermal sleeve apd the.S/G feedwater nozzle Per Westinghouse, failure experience with operating plant feedwater nozzles indicate that prior to catastrophic failure at the point of linear indication(s), the pipe/nozzle area will leak (i.e.,
* 13 S/G linear indications observed (by PT) near the thermal sleeve and visual observation of minor pitting erosion in the-area before the thermal sleeve 14 S/G-linear_indications observed (by PT) at the weld root, in the counterbore area, and near _the thermal sleeve; also, visual observation of erosion of the thermal . -
leak-before-break failure). The Sequoyah Plant concern, which initiated the examinations resulting in discovery of this event, was discovered by leakage. Per Technical Specifications, several leakage detection systems including Containment pocket sump level monitoring system and containment Fan Cooler condensate flow rate monitoring system, are maintained in service during plant operations.
"* LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating station Unit 1 ANALYSIS OF OCCURRENCE:
Therefore, since leakage would not go undetected, the health and safety of the public was not affected by this event.
DOCKET NUMBER 5000272 (cont'd) LER NUMBER 92-014-00 . PAGE 4 of 5 sleeve resulting in larger than design gaps between the thermal sleeve apd the.S/G feedwater nozzle Per Westinghouse, failure experience with operating plant feedwater nozzles indicate that prior to catastrophic failure at the point of linear indication(s), the pipe/nozzle area will leak (i.e., leak-before-break failure).
The Code of Federal Regulations 10CFR 50.72 and 10CFR 50.73 reporting requirements do not encompass this event per the interpretations of NUREG 1022, "Licensee Event Report System". However, due to its significance, this voluntary LER has been issued. Also, the original 10CFR 50.72 notification was corrected.
The Sequoyah Plant concern, which initiated the examinations resulting in discovery of this event, was discovered by leakage. Per Technical Specifications, several leakage detection systems including Containment pocket sump level monitoring system and containment Fan Cooler condensate flow rate monitoring system, are maintained in service during plant operations.
Salem Unit 2 S/G expander-to-nozzle welds were examined prior to the Unit 1 examinations. No unacceptable indications were found; however, one localized shadow area was observed, via RT, on 24 S/G.
Therefore, since leakage would not go undetected, the health and safety of the public was not affected by this event. The Code of Federal Regulations lOCFR 50.72 and lOCFR 50.73 reporting requirements do not encompass this event per the interpretations of NUREG 1022, "Licensee Event Report System". However, due to its significance, this voluntary LER has been issued. Also, the original lOCFR 50.72 notification was corrected.
This shadow on RT film could not be confirmed by UT. This shadow area will be reexamined at the next refueling outage.
Salem Unit 2 S/G expander-to-nozzle welds were examined prior to the Unit 1 examinations.
Areas unaccessible wi t.hout removaf of the thermal sleeve, al though not examined, were evaluated by Westinghouse to determine the impact of potential linear indications. This evaluation included comparison
No unacceptable indications were found; however, one localized shadow area was observed, via RT, on 24 S/G. This shadow on RT film could not be confirmed by UT. This shadow area will be reexamined at the next refueling outage. Areas unaccessible wi t.hout removaf of the thermal sleeve, al though not examined, were evaluated by Westinghouse to determine the impact of potential linear indications.
* of Salem to a similar plant on which a detailed fracture mechanici analyses was completed. Westinghouse.concluded that potential linear indications in the unaccessible areas present no safety significant issues up through the end of the next operating cycle (lRll).
This evaluation included comparison
CORRECTIVE ACTION:
* of Salem to a similar plant on which a detailed fracture mechanici analyses was completed.
All linear indications found on the S/G feedwater nozzle*ID's have been removed by excavating and blending with the surrounding area.
Westinghouse.concluded that potential linear indications in the unaccessible areas present no safety significant issues up through the end of the next operating cycle (lRll). CORRECTIVE ACTION: All linear indications found on the S/G feedwater nozzle*ID's have been removed by excavating and blending with the surrounding area. The deepest excavation was in nozzle 13 (0.083").
The deepest excavation was in nozzle 13 (0.083"). The VT and PT observed pitting was removed. New reducing spool pieces have been
The VT and PT observed pitting was removed. New reducing spool pieces have been .installed at the inlet to the Unit 1 S/Gs.
        .installed at the inlet to the Unit 1 S/Gs.
* All four (4) Unit 1 S/G expander-to-feedwater nozzle welds will be examined at the next refueling outage. Additional examinations are being assessed.
* All four (4) Unit 1 S/G expander-to-feedwater nozzle welds will be examined at the next refueling outage. Additional examinations are being assessed.
The Unit 2 apparent 24 S/G indication (shadow on RT film) discussed above, will be reexamined at the next refueling outage. The need to conduct additional examinations is being evaluated.
The Unit 2 apparent 24 S/G indication (shadow on RT film) discussed above, will be reexamined at the next refueling outage. The need to conduct additional examinations is being evaluated.
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating station Unif 1 . CORRECTIVE ACTION: (cont'd) DOCKET NUMBER 5000272. LER NUMBER 92-014-00
 
* The root cause investigation of the linear indications is *'continuing.
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating station         DOCKET NUMBER      LER NUMBER      PAGE Unif 1       .                     5000272.        92-014-00      5 of 5 CORRECTIVE ACTION:   (cont'd)
Two (2) 8 11 x10 11 weld samples have been sent for laboratory analysisw PAGE 5 of 5 Based upon results of the root cause analysis, additional corrective action will be assessed.
* The root cause investigation of the linear indications is
MJP:pc SORC Mtg. 92-086 General Manager -Salem Operations}}
  *'continuing. Two (2) 8 11 x10 11 weld samples have been sent for laboratory analysisw Based upon results of the root cause analysis, additional corrective action will be assessed.
General Manager -
Salem Operations MJP:pc SORC Mtg. 92-086}}

Latest revision as of 06:30, 3 February 2020

LER 92-014-00:on 920626,results of Radiographic Exam on SG 13 Indicated Weld Between Feedwater Nozzle & Elbow Had Number of Unacceptable Linear Indications.Caused by Equipment Failure.Indications removed.W/920723 Ltr
ML18096A859
Person / Time
Site: Salem PSEG icon.png
Issue date: 07/23/1992
From: Pollack M, Vondra C
Public Service Enterprise Group
To:
NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
LER-92-014, LER-92-14, NUDOCS 9207310112
Download: ML18096A859 (6)
v • d • e


Text

'-" i OPS~G I

Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 .

Salem Generating Station July 23, 1992 U. s. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555

Dear Sir:

SALEM GENERATING STATION LICENSE NO. DPR-70 DOCKET NO. 50-272 UNIT NO. 1 LICENSEE EVENT REPORT 92-014-00 This Licensee Event Report is a voluntary report being submitted

.pµrsuant to the requirements of the Code of Federal Regulations 10CFR 50~73.

Sincerely yours,

c. A Vondra General Manager -

Salem Operations Distribution

.,....I. ~

tqt**')

1,_;*-.;*~

9207310112 6;86g~72 PDR ADOCK PDR s

The Energy People

/,fj:J:Y )

/ vl./

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95-2.189 (10M) 12-8

NRC FORM 366 U.S. NUCLEAR REGULATORY COMMISSION (6-891 APPROVED OMB NO. 3150-0104 EXPIRES: 4/30/92 ESTIMATED BURDEN .PER RESPONSE TO COMPLY WTH THIS INFORMATION COLLECTION REQUEST: 50.0 HRS. FORWARD

  • ,. LICENSEE EVENT REPORT (LER) COMMENTS REGARDING BURDEN ESTIMATE TO THE RECORDS AND REPORTS MANAGEMENT BRANCH (P-5301. U.S. NUCLEAR REGUL.ATORV COMMISSION, WASHINGTON, DC 20555, AND TO ..

THE PAPERWORK REDUCTION PROJECT* (3150-0104), OFFICE OF MANAGEMENT AND BUDGET, WASHINGTON, DC 20503.

FACILITY NAME (1)

Sal 0 ~ r- 0 n°~atina Station - Unit 1 TITLE (4)

Steam Generator feedwater oioina linear indications.

EVENT DATE (5) LEA NUMBER (6) REPORT DATE (71 OTHER FACILITIES INVOLVED (Bl MONTH DAY YEAR YEAR J/: SE~~~~~~AL (( ~~~~~~ MONTH DAY . YEAR FACILITY NAMES DOCKET NUMBER(Sl 01s1010101 *1 I al 6 ~ 6 9 2 91 2 - oI 11 4 - o Io o I 1 2 13 9 2l o 1510 10 jo1 I *1 THIS REPORT IS SUBMITTED PURSUANT TO THE R~QUIREMENTS OF 10 CFR §: (Chock on* or moro of rh* following} (11)

OPERATING MODE (9) 5 20.402(b) 20.405(c) 60.73(*1(2lliv)

- 73:71 (bl 20.405(1)(1 )(i) 20.405(0)(1 )(Ii) 20.405(0)(1 )(ill) 50.38(c)(1) 50.36(c)(21 50.73l*ll2llil 60.731oll21M 60.73!1)(2)(vii) 50.73(1)(21(viiil(A) 73.71(cl OTHER (S{Hcify in Abstract btJ/ow and in Text, NRC Form 366AI 20.4ris(o)(1 )(Iv) li0.73(11(21(ii) 60.73(o)(21(viiil(B) 20.406(1)(11M 50.73(oll2lliill 60.73(o)(211xl Voluntary LICENSEE CONTACT FOR THIS LEA (12)

NAME TELEPHO.NE NUMBER AREA CODE 1=. In l *q ~ I~ I q I - I? I n I? I ?

COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (131 MANUFAC- MANUFAC*

CAUSE SYSTEM COMPONENT SYSTEM COMPONENT TURER TUR ER I I I I I I I I I I I I I I I I I I I I I I I I I I I I SUPPLEMENTAL REPORT EXPECTED (14) MONTH DAY VEAR EXPECTED SUBMISSION I YES ilf y6S, c~mpl*I* EXPECTED SUBMISSION DATE}

DATE 1151 I I I -

ABSTRACT (Limit to 1400 spaces, i.e., approxim11t9/y fifteBn single-space typewritten lines) (161 On June 26, +992, results of radiographic (RT) examinations on Steam Generator (S/G) 13 indicated that the weld between the feedwater nozzle and the elbow {SJ} had a number of unacceptable linear indications as per ASME Code. RT of the second weld did not indicate any evidence of unacceptable indications. Results of ultrasonic (UT) *and RT inspections, on S/Gs 12 and 14, indicated that the expander fittings had linear*

indications .on both the nozzle to expander and expander to elbow welds.

RT of the third weld did not indicate any evidence of unacceptable indications. After discovery of the feedwater pipe weld- nonconformances, additional detailed examinations were conducted which included visual examination, ultrasonic examination; and dye penetrant examination.

Additional linear indications were identified. The cause of this event is attributed* to equipment failure. Investigation into the root cause of the linear indications.is continuing. Two (2) S"xlO" weld samples have been sent for laboratory* analysis. Based upon results of the root cause analysis, other corrective action will be assessed. All linear indications found.have been removed by excavating and blending. Observed pitting was removed. New reducing spool pieces have been installed at the inlet to the S/Gs. All 4 Unit 1 S/G expander-to-feedwater nozzle welds will be examined at the next refueling outage. Additional examinations are being assessed.

NRC Form 366 (6-89)

LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER . PAGE Unit 1 5000272 92-014-00 2 of 5 PLANT AND SYSTEM IDENTIFICATION:

Westinghouse - Pressurized Water Reactor; Series 51 Steam Generators Energy Industry Identification System (EIIS) codes are identified in the text as {xx}

IDENTIFICATION OF OCCURRENCE:.

steam Generator feedwater piping linear* indications Event Date: 6/26/92 Report Date! 7/23/92 This repbrt was initiated by Incident Report Nos.92-400, 92-404,92-405, 92-406, and 92-407.

CONDITIONS PRIOR TO OCCURRENCE:

Mode 5 (Cold Shutdown)

DESCRIPTION OF OCCURRENCE:

On June 26, 1992, results of radiographic (RT) examinations on Steam Generator (S/G) 13 indicated that the weld between the feedwater nozzle and the elbow {SJ} had a number of unacceptable linear indications as per ASME. Code. RT of the second weld did not indicate any evidence of unacceptable indications. Results of ultrasonic (UT) and RT inspections, on S/Gs 12 and 14, indicated that the expander fittings had linear indications on both the nozzle to ~xpander and expander to elbow welds. RT of the third weid (i.e., the weld between the elbow and the pipe) did not indicate any evidence of unacceptable indications. There were no unacceptable indications identified on S/G 11 nozzle fitting during the RT and UT examinations.

This examination was prompted by recent S/G feedwater nozzle leakage concerns at Sequoyah Generating station.

Upon discovery of the S/G feedwater piping linear indications, the Nuclear Reguiatory Commission (NRC) was notified per Code of Federal Regulations 10CFR 50.72(b} (2) (iii).

APPARENT CAUSE OF OCCURRENCE:

The cause of this event is attributed to equipment failure.

Investigation into the root cause of the linear indications is continuing. Two (2) 8 11 xl0 11 weld samples have been sent for laboratory analysis.

In 1979, similar S/G feedwater nozzle/feedwater piping connection

LICENSEE-EVENT REPORT (LER) TEXT CONTINUATION s*alem Generating . Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 92...;014-00 3 of 5-APPARENT CAUSE OF OCCURRENCE*: (cont Id) linear indications were identified and corrected (reference LE~

272/79-46). The 1979 examination was in response to NRC Bulletin 79-13. Per a commitment, made in response to the Bulletin, additional S/G examinations were made during the following refueling outage in 1980. One linear discontinuity (approximately 1 11 long) was found.- It was determined to be an unfused area in the- root portion of the butt weld on the elbow side - (reference LER 272/80-:'55). _I.t is not related to the 1979 linear indication concerns. No other unacceptable line~r indications were observed.

S/G.exaininations continued through 1984 with no additional observed linea~ indications.

Investigation of the 1979 linear indications identified the cause as corrosion assisted thermal fatigue. Specifically, a fatigue loading mechanism was induced by thermal stratification and striping during cold low flow, feedwater injections. Other significant contributing factors included high oxygen-exposure, counterbore geometry, and the number* of times that large temperature differences (stratification) exist during heatup, hot standby and low power operations~

ANALYSIS OF OCCURRENCE:

After discovery and removal of the 12, 13, and 14 S/G feedwater.pipe -

weld nonconformances, additional detailed examinati0ns were conducted. They included: 1) visual examination of the four (4) S/G nozzles' internal diameter; 2) ultrasonic examination of the thermal sleeve; and 3) dye penetrant {PT) examination from the counterbore region up to and including the thermal sleeve. Results were:

11 S/G np unacceptable indications in the counterbore areas however, visual and PT examination identified linear indications on the nozzle ID surfaces close to the thermal sleeve 12 S/G - linear indications observed (by PT) in the counterbore area, minor linear indications close to the thermal sleeve, some rounded indiqations close to the thermal sleeve, and vis_ual observation of erosion of the thermal sleeve resulting in larger than design gaps between the thermal sleeve and the S/G feedwater nozzle

  • 13 S/G linear indications observed (by PT) near the thermal sleeve and visual observation of minor pitting ~nd erosion in the-area before the thermal sleeve 14 S/G- linear_indications observed (by PT) at the weld root, in the counterbore area, and near _the thermal sleeve; also, visual observation of erosion of the thermal

LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating station DOCKET NUMBER LER NUMBER . PAGE Unit 1 5000272 92-014-00 4 of 5 ANALYSIS OF OCCURRENCE: (cont'd) sleeve resulting in larger than design gaps between the thermal sleeve apd the.S/G feedwater nozzle Per Westinghouse, failure experience with operating plant feedwater nozzles indicate that prior to catastrophic failure at the point of linear indication(s), the pipe/nozzle area will leak (i.e.,

leak-before-break failure). The Sequoyah Plant concern, which initiated the examinations resulting in discovery of this event, was discovered by leakage. Per Technical Specifications, several leakage detection systems including Containment pocket sump level monitoring system and containment Fan Cooler condensate flow rate monitoring system, are maintained in service during plant operations.

Therefore, since leakage would not go undetected, the health and safety of the public was not affected by this event.

The Code of Federal Regulations 10CFR 50.72 and 10CFR 50.73 reporting requirements do not encompass this event per the interpretations of NUREG 1022, "Licensee Event Report System". However, due to its significance, this voluntary LER has been issued. Also, the original 10CFR 50.72 notification was corrected.

Salem Unit 2 S/G expander-to-nozzle welds were examined prior to the Unit 1 examinations. No unacceptable indications were found; however, one localized shadow area was observed, via RT, on 24 S/G.

This shadow on RT film could not be confirmed by UT. This shadow area will be reexamined at the next refueling outage.

Areas unaccessible wi t.hout removaf of the thermal sleeve, al though not examined, were evaluated by Westinghouse to determine the impact of potential linear indications. This evaluation included comparison

  • of Salem to a similar plant on which a detailed fracture mechanici analyses was completed. Westinghouse.concluded that potential linear indications in the unaccessible areas present no safety significant issues up through the end of the next operating cycle (lRll).

CORRECTIVE ACTION:

All linear indications found on the S/G feedwater nozzle*ID's have been removed by excavating and blending with the surrounding area.

The deepest excavation was in nozzle 13 (0.083"). The VT and PT observed pitting was removed. New reducing spool pieces have been

.installed at the inlet to the Unit 1 S/Gs.

  • All four (4) Unit 1 S/G expander-to-feedwater nozzle welds will be examined at the next refueling outage. Additional examinations are being assessed.

The Unit 2 apparent 24 S/G indication (shadow on RT film) discussed above, will be reexamined at the next refueling outage. The need to conduct additional examinations is being evaluated.

LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating station DOCKET NUMBER LER NUMBER PAGE Unif 1 . 5000272. 92-014-00 5 of 5 CORRECTIVE ACTION: (cont'd)

  • The root cause investigation of the linear indications is
  • 'continuing. Two (2) 8 11 x10 11 weld samples have been sent for laboratory analysisw Based upon results of the root cause analysis, additional corrective action will be assessed.

General Manager -

Salem Operations MJP:pc SORC Mtg.92-086

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