IR 05000272/1980001
| ML18082A239 | |
| Person / Time | |
|---|---|
| Site: | Salem  |
| Issue date: | 02/27/1980 |
| From: | Baunack W, Blumberg N NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION I) |
| To: | |
| Shared Package | |
| ML18082A231 | List: |
| References | |
| 50-272-80-01, 50-272-80-1, NUDOCS 8004280147 | |
| Download: ML18082A239 (12) | |
Text
U. S. NUCLEAR REGULATORY COMMISSION OFFICE OF INSPECTION AND ENFORCEMENT
REGION I
Report N /80-0l Docket N License N DPR-70 Priority -----
Licensee:
Public Service Elec:tric. and Gas Company 80 Park Place Newark, New ~ersey 07101 Facility Name:
Salem Nuclear Generating Station, Unit 1 Inspection At:
Hancocks Bridge, New Jersey Inspection Conducted:
Inspectors:
,~.....,,...__,
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N. J. Blumb Approved by: kJ. f6a~.
W. Baunack, Acting Ch1 ef, Nuclear Support Section No. 2, RO&NS Branch Inspection Summary:*
Category
- Inspection on January 22-25, 1980 (Report No. 50-272/Bff-Ol)
c
- 2/21/go dat~ *
date date Areas Inspected:
Routine unannounced inspection by a regional based inspector of licensee action on previous inspections findings; administrative control of safety related calibrations; surveillance calibrations of safety related compo-nents and equipment required by Technical Specifications; calibrations required by Technical Specifications of components and equipment association with safety related systems and/or functions; calibration and control of test equipment; witnessing of calibrations; technician qualifications; and facility tou The inspection involved 29 inspector-hours onsite by one regional based inspecto Results:
Of the eight areas inspected, no items of noncompliance were found in seven areas, one item of noncompliance was found in one area (Deficiency - failure to properly review calibration data, paragraph 4.c.(l)).
Region I Form 167 (August 1979)
- DETAILS Persons Contacted G. Giangi, Senior Performance Supervisor Chemistry
- H. Lowe, Public Service Quality Assurance Engi.neer F. McKulsia, Instrument and Control (I&C) Supervisor T. Merkle, Westinghouse Instrument Service Company (WISCO)
- H. Midura, Manager, Salem Nuclear Generating Station
- L. Miller, Station Performance Engineer M. Murphy, Associate Engineer, Operations A. Orticelle, Staff Engineer, I&C
- T. Robbins, I&C Supervisor J. Ronafalvy, Senior Performance Supervisor
- J. Stillman, Station Quality Assurance Engineer USN RC
- L. Norrholm, Resident Reactor Inspector The inspector interviewed other licensee employees, including QA personnel, chemistry personnel, and I&C technician *Denotes those present at the exit interview.
Licensee Action on Previous Inspection Findings (Open) Inspector Follow Item (272/79-08-03):
Six procedures required by Regulatory Guide 1.33 have not been reviewed by SOR The inspector veri-fied that three of the procedures have been reviewed by SORC and that the following procedures still required SORC r~view:
QI III-1.3~1, Turbine Generator Operation OI III-9.3.2, Feed Pump Operation OI IV-1.1.3.A, 500 KV Bus Normal Operations No. 1 Main Generator Synchronize.
Administrative Control of Safety Related* Calibrations The inspector performed an audit of the licensee's administrative controls in this area by conducting a sampling review of the below listed administra-tive procedures with respect to the requirements of the Technical Specifica-tions, Section 6, "Administrative Controls 11, ANSI 18.7, 11Administrative Controls for Nuclear Power Plants 11 and Regulatory Guide 1.33, 11Quality Assurance Program Requirements 11 *
Administrative Procedure (AP) No. 3, Station Documents, Revision 9, March 26, 197 *
AP, 22, Calibration of Measuring and Test Equipment, Revision 4,
. February 27,. 197 AP, 23, Qualification of Inspection, Examinati6n, and Test Personnel,_
Revision 3, January 2, 197 Performance Department Manual, Revision 9, March 197 No items of noncompliance were identifie. * S.urvei 11 ance Cali brat ion of Safety Related Components and Equipment Regui red by Techni'cal Specifications
- The inspector reviewed calibration procedures and associated data sheets on a sampling basis to verify the following:
Calibration frequency requirements have been met; Applicable system status during component calibration was in con-formance with Technical Specification limiting condition for operations;
_Procedure format provided detailed stepwise instructions; Procedure review and approval were as required by Technical Specifications; and
Technical content of procedures was sufficient to result in satisfactory component calibratio The following calibration procedures and associated data were selected for the above review:
lPD-2.2.. 003, Channel Calibration Check-:- lFT-415, Reactor Coolant Flow - Loop 1 - Channel II, Revision 1, February 197 Test performed - June 19, 197 lPD-2.2.005, Channel Calibration Check - TE-421 A/8 No. 12 Reactor Coolant Loop Delta T/Taverage Protection Channel II, Revision 6, August 23,. 1978. _ Test performed August 30, 197 lPD-2.2.007, Channel Calibration Check - IFT-425 Reactor Coolant Flow Loop 2, Channel II, Revision 1, September 197 Test per-formed July 3, 197 lPD-2.2.020, Channel Calibration Check - ILT-459 Pressurizer Level Protection Channel I, Revision 2, February 197 Test performed March 27, 1979.
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lPD-2.2.024, Channel Calibration Check - lPT-505 First Stage Turbine Impulse Pressure, Revision 4, February 197 Test per-formed Apri 1 30, 1979..
lP0-2.2.027, Channel Calibration Check - lFT-511 No. 11 Steam Generator Feedwater Fl ow Protect ion, Channel I I. Test performed May 7, 197.
lPD-2.2.029, Channel Calibration Check - lFT-513 No. 11 Steam Generator Steam Flow Protection, Channel II. Test performed March 22, 197 lPD-2.2.031, Channel Calibration Check - lPT-515 No. 11 Steam Generator Steam Pressure Protection Channel II, Revision 2i June 197 Test performed July 10, 197 lPD-2.2.069, Channel Calibration Check - PT-9480, Containment Pressure Protection - Channel Revision 1, March 197 Test performed March 29, 197 lP0-2.5.020, Channel Sensor Calibration, lLT-459 Pressurizer Level Protection - Channel I, Revision l, September 1, 197 Test performed August 24, 197 PD~2.5.024, Channel Sensor Calibration, 1 PT-505 First Stage Turbine Impulse Pressure-Channel I, Revision 3, February 1979, Test performed April 26, 197 lPD-2.5.027, Channel Sensor Calibration, lFT-511 No. 11 Steam Generator Feed Water Flow Protection - Channel I, Revision 2, April 197 Test performed August 10, 197 lPD-2.5.029, Channel Sensor Calibration, lFT-513 No. 11 Steam Generator Steam Flow Protection, Channel II, Revision No. 2, February 197 lPD-2.5.031, Channel Sensor Calibration, lPT-515, No. 11 Steam Generator Pressure Protection, Channel II, Revision No. 2, September 197 Test performed May 8, 197 lPD-2.6.005, Channel Functional Test, TE-421 A/B No. 12 Reactor Coolant Loop ~T/Tavg Protection, Revision 7, August 9, 197 Tests performed November 6, 1979; December 3, 1979; October 11, 1979; September 11, 1979; and August 13, 197 IPD-2.6.070, Channel Functional Test, lLT-459, Pressurizer Level Protection, Channel I, Revision No. 2, August 16, 197 Tests performed November 29, 1979; October 31, 1979; October 4, 1979; and September 4, 1979.
- lP0-2.6.024, Channel Functional Test, lPT-505, First Stage Tur-bine Impulse Pressure, Channel I, Revision No. 4, January 19 Tests performed November 30, 1979; October 31, 1979; October 4, *
1979; and September 7,"197 lPD-2.6.027, Channel Functional Test, lFT-511 No. 11 Steam Generator Feedwater Flow Protection, Channel II, Revision l, November 197 Tests performed December 4, 1979;* November 9, 1979; October 10, 1979; and September 13, 197 lPD-2.6.029, Channel Functional Test, lFT".'513 No. 11 Steam Generator Steam Flow Protection, Channel II, Revision No. 3, February 197 Tests performed December 6, 1979, November 8, 1979; October 11, 1979; and September 12, 197 lPD-2.6.031, Channel Functional Test, lPT-515, No. 11 Steam Generator Pressure Protection Channel II, Revision No. 1, January 197 Test performed December 4, 1979; November 6, 1979; October 10, 1979; and September 13, 197 P0-4.l.006, Channel Calibration, 1-RS Fuel Handling Building Area Radiation Monitor, Revision 5, June 28, 197 Test per-formed May 15, 197 lP0-4.1. 011, Channel Calibration, l-R9, Fuel Storage Area Radia-tion Monitor, Revision 5, October 11, 197 Test performed May 11, 197 lPD-4.2.003, Channel Functional Test, l-R5 Fuel Handling Build-ing Area Radiation Monitor, Revision 5, Tests performed November 1976. Test performed November 26, 1979; October 30, 1979; September 28, 1979; September 4, 197 lPD-4.2.004, Channel Functional Test, l-R9 Fuel Storage Area Radiation Monitor, Revision 5, November 197 Tests performed November 26, 1979; October 30, 1979;. September 28, 1979; and September 4, 197 lP0-6.1.001, Channel Functional Test Turbine Trip Auto Stop Oil Pressure, Revision 3, J.une 7, 197 Tests performed on November 29, 1979 and March 24, 197 lPD-6.1.002, Channel Functional Test, Turbine Stop Valve Closures (Turbine Out of Service), Revision 1, June 9, 197 Tests per-formed November 29, 1979 and March 24, 197 lPD-13.1. 003, Channel Calibration - Seismic Instrumentation, Revision 0, July 14, 197 Test performed May 5, 197 **
lP0-13.. 2.002, Functional Test Seismic Strong Motion Instrumen-tation, Revision!, November 12, 197 Tests performed May 5, 1979 and November 8,. 197.
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lPD-13.2.003, Channel Check, Seismic Strong Motion Instrumention, Revision No. 2,. August 18,.1978. * Tests performed November 9, 1979; October 12, 1979; September 13, 1979; and August 16, 197.*
lPD-16.LOOl, Source Range Channel Calibration (Channels N32 and
.* N31), Revision 2, October 18, 1977 *. Test performed March 27, 197 lPD.:.16.2.001:, Source Range Channel Functional Test (Channels N31.
and N32), Revision 2, August 16, 197 Tests performed December 18, 1979; December 7, 1979; and November 15, 197 *
lPD-18.1. 001, Sol id State Protection System (ESF) - Periodic Test, Revision 6, October 1977. Test performed November 23, 1979; *
September 28, 1979; August.2, 1979;*and June 14, 197 Findings (1) During channel calibration check of TE-421 A/B No. 12 Reactor Coolant Loop Delta T/Tavg Protection Channel II (lPD-2.2.005)
performed August 30, 1979, data for two output monitor points required to be at 3.000 volts +/- 20 millivolts, were recorded as 3.988 and 3.989 vo1ts respectively; and, during channel func-tional test of lPT-505 First Stage Turbine Impulse Pressure -
Channel I (lPV-2.6.024) performed April 30, 1979, data recorded for 185-512-Steam Flow greater than Reference Flow to Safety Injection required to be at 3.169 volts +32, -22 millivolts was recorded as 2.178 volt Both completed procedures were reviewed and signed by a supervisor and, in addition, the data sheet for the Reactor Coolant loop Delta* T/Tavg. was stamped and verified as-correct by a quality control inspecto In neither instance were the errors observed nor corrective action taken as a result of _the sup~rvisory or quality control revie Based on observation of other data in the above procedures and of data in other similar procedures, it appeared to the inspec-tor that the data had been improperly recorded by the technician rather than being out of specificatio Failure of supervisors and quality control personnel to ade-quately review or take appropriate corrective action concerning incorrect calibration data is contrary to Technical Specifica-tion 6.8.1 and Salem Performance Department Manual paragraphs 3.4.5.5 and 3.4.5.7 and constitutes a defici~ncy level item of noncompliance (50-272/80-01-01).
..
(2) PD-18.1.001, Solid State Protection System - periodic Test~
paragraph 10, sta,tes Connect the vo 1 tmeter (AC seal e) between TDI-1 and TDI-The meter should indicate 0 VAC 11 *
Data
. recorded.for.four procedures reviewed were between 13 and 19 volts A The licensee. representative stated that these volt- *
ages were considered a 11 nominal 11 zero and were induced voltage cause by 11antenna effect 11 *
The inspector stated that the volt-ages Y'e<::orded were well in excess of what could be considered a
"nominal zero
- appeared to be in excess what might be indl,lced by'
11antenna effect
- and, that if these voltages are to be expected, then the procedure should be changed to reflect thi The licensee representative stated a revision to the procedure is under evaluatio This item is unresolved pending licensee action and subsequent NRC
- RI review (50-272/80-01-02). Calibrations Required by Technical Specifications of Comeonents and Equip-ment Associated With Safety Related Systems and/or Functions
- The inspector reviewed, on a sampling basis, the program established for calibration of components associated with safety related systems required by ANSI 18.7-197 These components are used to monitor sys-tem parameters to comply with safety. limits, limiting conqitions of '
operation, and/or meet the surveillance requirements of Technical Speci fi cat i ans.
The following were verified:
Calibration schedule and frequencies established.by the licensee are being adhered to; Procedures have been reviewed and approved in accordance with the Technical Specifications, contain acceptance criteria. consis-tent with the Technical Specifications, and contain detailed instructions commensurate with the complexity of the calibration; and, Technical content of procedures are adequate to perform satisfac-tory calibratio The following components identified in facility surveillance test pro-cedures were selected at random and the specific requirements estab-lished for their calibration were verified:
lPD 1.4.003, (No. 1 Refueling Water Storage Tank Outlet Tem-perature), General Calibration Procedure for Field Devices, Revision 3, October 3, 1975. Test performed July 20, 1979.
- lPD l.4~003, (No.. 12 Safety Injection Punip Discharge Pressure Calibration - P.S. 1PL1682), General Calibration Procedure for
.*Field Devices, Revision 3, October 3; 197 Tests performed
- . October. 3, 1978 and September 29, 197 lPD 1.4.003, (Fire Protection Heade*r Pressure at Fire Pump Out-let Area, North Wall Fire Pump Hose), General Calibration Proce-dure for Field Devices, Revision 3, October 3, 197 Tests per-
.formed.March 12, 1976. and August 24, 197 *
lPD 1.4.003, {No.* lA Diesel Generator RPM Meter Local), General Calibration Pro.cedure for Field Devi.ces, Revision 3, October 3,
- 1975. Test performed July 13, 197 *
lPD-2.10.080, Channel Calibration Procedure, ITE-453A Pressurizer Liquid Temperature Indication, Revision 1, June 21, 197 Test performed March 12, 1979. *
lP0-2.10.176, Channel Calibration Procedure - 1FT918 No. 12 Safety
.Injection Pump Discharge Flow, Revision 0, April 4, 197 Test performed March 17, 197 lPD-8.1. 002, Rod Position Indication Signal Condi ti oni ng Module Calibration, Revision 3, June 25, 197 Test performed November 30, 1979 *
lPV-8.1.003, Rod Position Indication System.Calibration, Revision 2,
- June 20,. 197 Test performed November 30, 197 lPD-16.1.007, lQM-200 Axial Flux Difference Monitor, Revision 3, July 197 Test performed.November 24, 197 PD"'l.4~oo3, (84 ft. Auxilliary 10.Ton Cardox Unit U.S. Gauge 176n, Instrument No. P21177, Calibration 1, General Calibrati-0n Procedure for Field. Devices, Revision 3, October 3, 197 Test performed February 13, 1979 *.
lPD-1.4.003, (No. 11 Diesel Fuel Oil Storage Tank Level (Calibra-tion)), General Calibration Procedure for Field Devices, Revi-sion* 3, October 3, 197 Test performed April 28,.1975 and April 21, 197.
Instrument Calibration Data Sheet, No. 11 Steam Generator Blow-d.own pH Electrode HA325 Test performed January. 20, 197 lPD 1.4.003, (Boric Acid Flow Path Heat Traces Temperature Calibration Check - Instruments IT-107P, IT-1075, IT-I08P, IT-1085, IT-109P, IT-1095), General Calibration Procedur~ for Field Devices, Revision 3, October 3, 197 Test performed January 2, 198 *
- 9 Findings (1)
(2)
During calibration of iTE-453 pressuriier liquid temperature indicator per IPD-2. 10.080 performed on March 12, 1979, data points recorded for the l00°F and 700°F indications were recorded as less than l00°F and greater than 700°F respectively; and no actual temperature values were recorde The inspector noted that by using 11less than" and 11greater than 11 symbols for data entries, the acceptability of calibration could not be verified at these points. Since the last two data points were 555°F and 700°F, acceptability of the temperature element in the tempera-ture range for normal pressurizer operation could not be deter-.
mine The licensee representative concurred ~ith the inspector and, during the inspection, issued a memorandum to all Performance Department personnel stating that the use of 11greater than 11 and
"less than" symbols were inacceptable for calibration and that data points that exceed the extremes of the printed scale must be recorded as an actual valu The inspector questioned the acceptability of data points plus tolerance which could cause off scale readings during a calibra-tion and requested further licensee evaluation in this are During telephone discussion of inspection findings subsequent to the. inspection, the licensee representative stated that the
- resu.lt of this evaluation was that procedure change was not required and that extrapolation could be used at scale end points as long as readings were not pegge The inspector concurred and had no further questions in this are In addition, subse-quent to the.above telephone discussion, the licensee recali-brated the pressuri ze.r 1 i quid temperature indicator and sub-mitted the data to the inspecto Recalibration data was satisfactor T. S. 4. 7.10. 3 requires verification of the C02 (cardox) storage tank level and pressur The licensee was unable to provide any calibration data for the C02 storage tank level indicato The licensee representative stated that level indicators had not been assigned an instrument number; this ca~sed calibration of these instruments to be overlooke An Operational Design Change Notice (ODCN) dated January 18, 1980 to assign instrument numbers*
to the C02 level instruments indicated the discrepancy was dis-covered by the licensee prior to the inspectio During the inspection, Work Order 929360 was submitted to calibrate the Cardox system level gag This item is unresolved pending com-pletion of licensee action and subsequent NRC:RI review (50-272/
80-01-04).
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(3) T.S. 4. 1.2. l.a requires verification that the temperature of heat
- traced portion of the boron injection flow path is greater than or equal to 145°F; and T.S. 4.5.5.b requires verification of Refueling Water Storage Tank temperature when outside air tem-perature iS less than 35° Data sheets for the RWST tempera-ture thermocouple and a sampling of data sheets for several*.
- boron injection heat trace thermocouples were reviewed by the inspecto In each case the data sheets indicated that the functional *tests were satisfactory, however, no data was recorded nor were any tolerances given on the data sheet.* For the heat tracing, the work order card did specify a toleranc The inspec-tor stated that without the recording of data, the acceptability of the functional checks of the thermocouples could not be
.
reviewed or independently verifie The. licensee representative stated that data would be recorded for future functional tests of thermocouples and that tolerances would be specified. This item is unresolved pending licensee action and subsequent NRC:RI review (50-272/80-01-05).
(4} The diesel generator 11overcrank11 trip is specified as 550 RPM increasing in Westinghouse Drawing 22666 During a functional te$t performed on July 13, 1979 this trip setpoint was recorded
- as 530 RPM increasing with a notation by the technician that no further adjustment could be made on the trip setpoint. The data sheet was signed by a supervisor and no further action appears to have been take The inspector observed, that although this setpo.i nt does not effect emergency opera ti on of the di ese 1 generator in that it is bypassed during emergency initiation of the diesel,.that action should be taken to either correct the trip setpoint or obtain an eng.irieering evaluation to change th setpoint to its current level. The licensee representative con-curred and stated appropriate corrective action will be taken concerning this setpoint. This item will be reviewed on a
$Ubsequent NRC:RI inspectio *
6. * Calibration and Control of Test Equipment The inspector reviewed the calibration and control of eight pieces of test equipment used as standards* in the calipration of components identified in paragraphs 4 and *
Results of the review indicated measuring and test equipment are being main-tained as required by administrative procedure. * Items verified included:
Establishment and maintenance of a master test equipment list; Establishment and adherence to a calibration schedule;
Maintenance of calibration records identifying standards used which havE{ traceabi1 ity to the National Bureau of Standards Qr other test-ing.organization;
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.
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- Test equipment custody control records; and, Storage and labeling of test equipmen No i tams of nonct;>mp l i a*nce we re i den ti f i e *. 7~ *.. Inspector Witnessing of Cal ibratio~s The inspector witnessed the performance of the following tests on January 22, 1980:
.
--. Channel Functional Test - lFT-532, No. 13 Steam Generator Steam Flow Protection Channel I, lP0-2.6.048, Revision 3, February 2, 197 Channel.Calibration Check - LT-538, No. 13 Steam Generator Flow Pro-tection Channel I, lPD-2.2.054, Revis.ion 2, Nov.ember 2, 1979.
. Each test was performed and data recorded as required by the procedure The procedures were adequately detailed to assure performance of a satis-factory test. During performance of lP0-2.2.054, the steam generator low level setpoint was out of specificatio In accordance with the procedure a work order was submitted and the setpoint readjusted and a satisfactory
. calibration obtaine No.items of noncompliance-were identifie.
Technician Qualifications The inspector reviewed.the qualification*records of eight currently assigned technicians having responsibility for calibration testing of safety related systems and component This review was performed to verify that the individuals experience level and training were in accordance with ANSI Nl8. 1, "Selection and Training of Nucleat" Power Plant Personnel".
No items of noncompliance were identifie.
Facility Tours During the inspection, tours of the turbine building, auxiliary building, and control room were conducte The inspector observed plant operations, housekeeping~ radiation, monitoring instrumentation, and control room operations for Technical Spedfication and administrative r*equirement No items of noncompliance were identifie *
1 Unresolved Items Unresolved items are matters about which more information is required in order to ascertain whether they are acceptable items, items of noncompli-ance, or deviation Unresolved items identified during this inspection are discussed in paragraphs 4:.C.(2) and 5.C.(l), (2), and (3).
1 Exit Interview The inspector met with licensee repres~ntative~ (denoted in paragraph l)
at the conclusion of the inspection on January 25, 1980; The inspector summarized the scope and findings of the inspectio Subsequent tele-phone discussions concerning inspection findings was held between Mr. Miller and Mr. N. Blumberg on February l, 1980 and February 15, 1980; and between Mr. T. Merkle and Mr. N. Blumberg on February 15, 1980.