IR 05000272/1993025
| ML18100A736 | |
| Person / Time | |
|---|---|
| Site: | Salem  |
| Issue date: | 11/23/1993 |
| From: | Modes M, Patnaik P NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION I) |
| To: | |
| Shared Package | |
| ML18100A734 | List: |
| References | |
| 50-272-93-25, NUDOCS 9312070046 | |
| Download: ML18100A736 (8) | |
Text
U.S. NUCLEAR REGULATORY COMMISSION
REGION I
REPORT/DOCKET NO /93-25 LICENSE N DPR-70 LICENSEE:
Public Service Electric and Gas Company INSPECTION AT:
Hancocks Bridge, New Jersey FACILITY NAME:
Salem Nuclear Generating Station, Unit 1 INSPECTION DATES:
October 25 - October 29, 1993 INSPECTOR:
_ APPROVED BY:
Prakash Patiiaik, Reactor Engineer Materials Section, EB, DRS
~~
Materials Section, EB, DRS
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9312070046 931126 -
PDR ADOCK 05000272 B
PDR r
N'oV..2.3* 93 Date I
Date
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Areas Inspected: The review of inservice inspection (ISi) program, scope of ISi work, eddy current examination program for steam generator tubes, erosion/corrosion monitorin program for high energy systems, and steam generatOr leakage _monitoring program were reviewe Results: The licensee's ISi program, and the scope of ISi work, for the eleventh refueling outage complied with the 1983 edition of the ASME Code,Section XI, including the summer '83 addenda. The steam generator tube examination met the requirements of the tecbnlcal specification. For those areas reviewed, in the long-term erosion/corrosion program, the. estimates of wear rates and remaining life of components, examined during the outage, were conservative. The steam generator leakage monitoring is comprehensive, and the procedures for detection of primary to secondary leakage and the actions to be taken in \\
the event of a leak are systematically presented. However, the operation's procedure does not address operator's actions against step increases in leak rate below the shutdown margin, as Seen in some of the recent tube failures at other plants. The administrative limit for power reduction for shutdown is acceptabl DETAILS INSERVICE INSPECTION (ISi) (73753) Scope The conduct of inservice inspection using ultrasonic, magnetic particle and liquid penetrant
- examination ensures integrity of the pressure boundary. During this inspection, reviews of the ten-year ISi plan, the scope of work for the outage, a sampling of inservice inspection data, and observation of work activities were performed to ascertain if the requirements of the applicable ASME Code,Section XI, and the technical specifications were me.2 Findings Public Service Electric and Gas Company (PSE&G), the licensee for SaleinUnit 1, conducted an inservice inspection during the eleventh outage (lRll) of the unit, in accordance with the ASME Code,Section XI, 1983 edition, including the summer.1983 addendum. The unit is in the second inspection period of the second inspection interval, and the ongoing outage is the second outage of the inspection period. The unit will have another refueling outage during the second inspection period. The inspector reviewed the ten-year
- ISi plan and the relief requests to the NRC on welds which are impractical to examine in accordance with the applicable code. Within the scope of the review, the inspector did not find any discrepanc *
The inspector reviewed the scope ofinservice inspection work fot the outage. The components* listed in the work scope were identifiable from the ten-year plan;.The examination requirement for each component complied with that of the applicable ASME Code,Section X The inspector* performed surveillance of the storage area for the ultrasonic calibration block The *storage facility appeared to be adequate. The general condition of the calibration blocks, with regard to corrosion, is good; The station quality assurance personnel performed routine surveillance of ISI activities during the outage. The level of staffing to implement the inservice inspection program was found to be adequat The inspector witnessed ultrasonic examination of the folloWing welds in the chemical an volume control system piping:
3-CV-2163-6 3-CV-2163-7 3-CV-2163-8 3-CV-2160-42 3-CV-2160-43 3-CV-2160-44
The examiners used the calibration block No. 30-SAM, designated for use on the piping and listed in the program plan. The examination was performed in accordance with licensee's procedures. The inspector verified from the certifications of ~rsonnel performing the examination that the personnel were appropriately qualifie *
The following *data sheets on ultrasonic examiilations, conducted during the outage, were reviewed to verify the licensee's resolution of indications. The inspector did not find any discrepanc I Line N I Weld N I Scan I
Indication I Disposition 12-CV-1143
Profile UT 45 °,
Geometric Acceptable 45°T 45° indication from Tangential weld root and counterbore 2-CV-1175
UT 45°, 45° T, No Acceptable 70° 8-SJ-1162
Profile, UT Two indications Acceptable 45°, 45°T, and * due to root
..
45° Tangential geometry 8-SJ-1152
Profile, UT Geometric Acceptable 45°, 45°T, and indications
,
45° Tangential 4-SJ-1172
Profile, UT, Geometric Acceptable 0°,45°,45°T, indications 45° Tan The inspector reviewed data sheets on_ VT-3 visual examination of all supports on the pressurizer* surge line. There was no discrepancy noted in the review of data. All personnel
- conducting visual examinations were appropriately qualifie.3 Conclusion The licensee exercised adequate control over inservice inspection activities dutjrig the
- eleventh refueling outage of Salem Unit 1. The inservice inspection prqgram during the outage was found to be in compliance with the applicable ASME Code,Section XI, and the regulatory requirement I STEAM GENERATOR EDDY CURRENT EXAMINATION AND SHOT
.PEENING
.. During the eleventh refueling outage, the licensee applied shot peening to the hot leg side of the steam generator tube bundle to increase the margin of resistance in areas of the ~bes within the tubesheet and transition region that are susceptible to primary water stress corrosion cracking (PWSCC). The inspector witnessed the shot peening operation in *
progress on No. 12 and No. 14 steam generators. The following critical parameters, identified in the PSE&G procedure, were verified:
Mass flow rate of shot peening material e
Speed of travel of the nozzle within the tube sheet The material certification and the heat treatment charts of the shot material was reviewed and found to conform to the engineering specificatio During the inspection, the inspector also reviewed a detailed 50.59 safety evaluation of the shot peening operation. and a technical description of the process. The safety evaluation did
. not identify. any unreviewed safety question The steam generator eddy current examination of Saleni Unit 1 was in progress during the inspection. The licensee performed a tWenty percent bobbin coil examination for the full length of tubes and also twenty percent rotating pancake coil (RPC) on the hot leg side
. Westinghouse Explosive Tube Expansion (WEXTEX) transitions for all four steam *
generators. The RPC was performed on tube expansions located in the region which had a.
greater potential for an active degradation mechanism. In addition, an inspection was also*
performed on previous indications greater than twenty percent throughwall. The licensee expanded the sample of tubes examined in accordance with the requirements of Section 4.4.5.2 of the Salem Unit 1 technical specification. As a result of sample expansion, the licensee performed one hundred percent bobbin coil examination of all four steam generators, and one hundred percent RPC examination of No. 13 steam generator. The inspector*
witnessed dara acquisition for No. 11 and No. 13 steam generators and did not find any discrepanc.1 Conclusion The shot peening operation and the eddy current examination of Salem Unit 1 were well planned and controlled. For those areas inspected, the eddy current examination program met the industry standards and the regulatory requirements. *
- WNG-TERM EROSION/CORROSION (E/C) MONITORING OF IDGH ENERGY PIPING (49001)
The inspector reviewed the scope of work during the eleventh refueling outage as regards EiC monitoring of components in the high energy systems. The licensee selected 147 components initially from the following systems and expanded the scope by 9 additional components:
Heater Drains
Gland Seal Steam
Moisture Separator Reheater Drains
Miscellaneous Drains
Heating Water
- Condensate System
Bleed Steam
Cold Reheat
Steam Generator Blowdown
Heater Vents
.,
Turbine Drains
Feedwater Recirculation
Feedwater System The selection of components was based on predictive methodology using CHECMA TE computer model, industry experience, station experience, past ultrasonic test data, Salem Unit 2 E/C results, and engineering judgment. The inspector reviewed the licensee's evaluation of components based on the thickness data obtained during the outage. It was.
concluded that the licensee's estimates of the wear rate, the remaining life, and the predicted remaining wall thickness at the end of the next operating cycle were generally conservativ.0 STEAM GENERATOR LEAKAGE MONITORING PROGRAM
_ The licensee's primary-to-secondary leakage monitoring, as outlined in Salem Chemistry Procedure SC.CH-AB.ZZ-llOl(Q), Rev. 0, dated June 26, 1992, "Detection and Determination of Primary to Secondary Leakage," was reviewed. This procedure provides necessary sampling, analysis and reporting requirements, along with methods for calculating and projecting primary-to-secondary leak rates. Radioactivity in the secondary system is usually detected initially by a continuous monitoring system at the condensate air ejector, and *
then by the steam generator blowdown monitor. A large leak rate may be detected initially by the blowdown monitor as well as the air ejector monitors. The leak rate is estimated by measuring the activity level of a selected nuplide in primary and secondary systems. The inspectc>r reviewed logs pertaining to radiochemical analysis for gross beta and gamma of steam generator blowdown sample taken three times a week for September 1993. The logs were up to date and contained pertinent data. The inspector subsequently reviewed the
"
channel calibration check, the channel functional test and the source check of the steam.
generator blow down monitors (R-19), and the condenser air ejector monitors (R-15)
. performed in accordance with the surveillance requirements of ~e technical specificatio The log~ were up to date and the surveillance was performed in a timely.manne The inspector also reviewed the Abnormal Operating Procedure (S2.0P-AB.SG-0001 Q) o the steam generator tube leak to determine the operator's action in the event of an indication of steam generator tube leakage. This procedure clearly addresses the entry conditions and the subsequent actions systematically. Further, the administrative limit to initiate a power reduction (if at anytime a 24-hour projected leak rate reaches or exceeds 140 gallons per day)
or shut down (when the leak rate reaehes 140 gallons per day) is within Technical Specification limits._ Notwithstanding the limits on power redl,lction and/or shutdown, the operations procedure d<>es not address appropriate actions.against step increaSes in primary-to-secondary leak rate below the shut down margin, which have been experienced in* case of some of the recent tube failures at other plant.0 EXIT :MEETING The findings of the inspection were presented to and discussed with members of the licensee's management at the exit meeting on October 29, 1993. The licensee concurred with the findings of the inspection and did not voice any objections. A list of attendees* of the exit-meeting on October 29, 1993, is attached to this report as Attachment 1. *
ATTACHMENT 1 Public Service Electric and Gas Company M. Alpaugh C. Connor M. Morroni J. Nichols Licensing Supervising Engineer Technical Dept. Manager Reliability and Assessment Manager U. S. Nuclear Regulatory Commission C. Marschall P. Patnaik Sr. Resident Inspector Reactor Inspector