ML20238D580
| ML20238D580 | |
| Person / Time | |
|---|---|
| Site: | Vogtle  |
| Issue date: | 07/31/1987 |
| From: | Duff W WESTINGHOUSE ELECTRIC COMPANY, DIV OF CBS CORP. |
| To: | |
| Shared Package | |
| ML20238D550 | List: |
| References | |
| NUDOCS 8709110265 | |
| Download: ML20238D580 (169) | |
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- Digital Metal Impact Monitoring System Baseline Data Acquisition Summary for Georgia Power Company Vogtle Unit No. 1 (GAE)
July 1987 , 1
. Approved:
Winslow K. Duff, anager Digital System Services Nuclear Services In gration Division Westinghouse Electric Corporation Nuclear Energy Systems P. O. Box 598 Pittsburgh, Pennsylvania 15230-0598 dss.dssl/gaebdas.rpt
l { l
- l. , -Westinghouse Class 3 Ir
-Table of Contents Executive Summary _ 1 l
Background' 2 < Regulatory Guide Conformance -
. 7
' Data Collection and Analysis 9 Data Analysis Equipment 10' System Operation 13 Alarm Setpoint 14 Conclusions 16
. Diagram 1: Monitored Channels Display 3 Diagram 2: ~ Accelerometer Locations; Steam Generator Primary & Secondary 4 Diagram 3: Accelerometer locations; Reactor Vessel Upper 5 Diagram 4: Accelerometer Locations; Reactor Vessel Bottom 6 Diagram 5: Data Collection and Analysis Equipment 11 Table 1: Plant Signal Assignments 12 Table 2: Steady State Background 15 Table 3: Recommended System Settings 17 Appendix A: Baseline Signatures A-1 Appendix B: Actions in the Event of an Alarm B-1 Appendix C: Regulatory Guide Conformance by Section C-1
, -d l Westinghouse Class 3. Executive Summary This report document's the installation and post-installation testing of the Westinghouse Digital Metal Impact-Monitoring System (DMIMS) for Georgia Power 3 Company, Vogtle Unit 1 (GAE). This installation and Baseline Data Acquisition Report is intended for use by GAE personnel as a reference for.the as-installed ' DMIM System configuration.
'This report contains site specific information and data that:
. Documents system sensitivity in accordance with United Stated Nuclear Regulatory Commission Regulatory Guide 1.133.
- Provides a basis for recommended system settings.
Provides simulated loose part impact data and other background:informa-tion to allow GAE personnel to evaluate suspected impacts, if they occur. Illustrates and tabulates accelerometer signals at the 100% power level for verification of the signal train integrity and to detect any signal degradation. This report is not intended to be a tutorial for the operation of the DMIMS or the interpretation of its output. Rather, it is an engineering report that assumes a level of familiarity with the DMIM System itself as well as acoustic signal propagation and analysis. DMIM System information.is contained in the DMIMS Technical Manual. supplied with the system and is complimented by the vari-ous . training courses offered by Westinghouse Nuclear Services Integration Divi-sion.
Westinghouse Class 3
-Background The Digital Metal Impact Monitoring System detects impacts through the.use of sensors (accelerometers) mounted on the outside of the Nuclear Steam Supply Sysc ;
tem (NSSS) pressure vessels. Normally, two accelerometers are attached at each j monitored location for redundancy and to aid in locating the source of any > impacts detected. Accelerometers'are also placed so as to meet the United States Nuclear Regulatory Commission separation criteria. By positioning the . sensors on each steam generator 30 inches above and below the tubesheet allows y) data analysis techniques to isolate impact sources to either the primary or sec.
'ondary of that steam generator. The DMIMS cabinet circuitry installed at the l Georgia Power Company's Vogtle. Unit 1 is comprised of twelve. channels. See Dia. C gram 1 for the normal display of the system. The DMIMS monitors impact loca-
'tions at the reactor. vessel bottom, reactor vessel head, steam generator pri-mary, and steam generator secondary. See Diagrams 2 through 4 for typical accelerometer locations, and Table 1 for the specific' signal channel assign- 9 ments. q The Baseline Signature Acquisition performed for GAE consists of: f
- Calibrated hammers of various weights are used to impact the primary boundary at a known energy level outside a three-foot radius of each sen-sor location. q
- Background acceleration data recorded at the 100% power level mode 1 l l
plant condition. l
- Reduction of data gathered to demonstrate system performance and sensiti-vity. l Simulated impacts were generated on the NSSS pressure boundary at each of the locations monitored by the DMIM System, to determine the acceleration time ]
response and frequency spectra of a loose part that would strike the reactor coolant system boundary. This is done for two reasons: to produce the frequency signatures characteristic of various masses striking the pressure boundary and to demonstrate system sensitivity. This data also demonstrates that each installed channel consisting of accelerometer, charge preamplifier, signal conditioner, interconnecting cables, and processing electronics is oper-- ating correctly. Steady-state background data at the 100% power level was collected to establish a j baseline signature for each channel. These signatures-(compiled in Appendix A) illustrate time response and frequency spectra of each channel resulting from ; normal NSSS flow-generated background noise at the 100% power level. Table 2 lists the root mean square (rms) voltage and acceleration levels derived from these signatures. In the future, analysis and comparison of the baseline signa-tures with live signals may be used to determine if signal train degradation is I occurring due to aging or component failure. l I l l1
I u Westinghouse Class 3 Diagram 1
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. iy s . Monitored Channels Display }.i
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RVU RVL SGil SG12 SG13 SG14 l j
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750 752 754(P) 756(P) 758(P) 760(P)
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Westinghouse Class 3 United States Regulatcry Guide Conformance The United States Nuclear Regulatory Commission (NRC) Regulatory Guide 1.133 rovides specific guidelines which should be implemented in the loose part detection program for the primary coolant system of light water-cooled reactors. In Section C., " Regulatory Position," criteria are established pertaining to sensor location, system sensitivity, channel separation, alert level, and system
-ain iup.tenance whichstages During initial shouldofbetheincorporated installation,into the systemwas consideration installation given pri-and star-marily to sensor location, channel separation, and ease of system repair. Once installation and testing is completed, alert levels and system sensitivity level are established.
The locations of the sensors in the plant were chosen to maximize the detection capability of acoustic disturbances caused by loose parts. The monitored loca-tions are the steam generator tube sheet on the inlet side, and the top and bot-tom of the reactor vesse.. Because of plant design, these locations are natural collection points. Past loose part monitoring experience has shown this to be the case. Additionally, each monitored location is equipped with one passive ria. one and active channel within the area that satisfies the NRC redundancy crite-If one of the two channels at a location were to fail, the remaining chan-nel would still provide adequate coverage of that location. Not only is redun-dancy achieved, but the sensors have been positioned such that impact signal timing can determine loose part location. This is done on the steam generators by vertically aligning the sensors approximately 30 inches above and below the tube sheet centerline allowing a primary versus secondary side impact source determination. The same redundancy principle applies to the reactor vessel bot-tom, except that the two vessel bottom-mounted sensors are mounted 180 degrees apart. The reactor vessel top-mounted sensors are 120 degrees apart on the ! lifting lugs providing excellent coverage for the entire head region. l Channel separation is maintained by the use of separate electrical conduit and junction boxes from the sensor up to the containment penetration. This section of the Regulatory Guide 1.133 does not imply that conformance with Regulatory Guide 1.75, " Physical Independence for Electrical Systems," is required. Therefore, tainment. complete channel (i.e., train) separation is not required outside of con-The containment penetration provides an accessible point regardless of power level from which maintenance can be performed. Finally, ease of system repair has been achieved by mounting the pre-amp junt-tion boxes in readily accessible locations. The system has the capacity for a communication channel to be installed in each pre-amp box. Holes have been cut in the vessel insulation to allow for easy access to the sensors.
7 4 NestinghouseClass3:
.On-line system sensitivity has been demonstrated by simulated impacts at'loca-
' tions with impact energies as specified by. the Regulatory Guide. , The' simulated impact amplitudes'were compared to background amplitudes at various' plant condi.
tions to determine if the alarm circuity can-distinguish between the two levels. This is-used to determine an alarm setpoint which will.give an indication of an ; 3,
- i impact but will.not cause excessiveLfalse alarms due-to background noise.
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Westinghouse Class 3 Data Analysis Equipment A Nicolet Scientific Corpor,ation Model 660B dual-channel Fast Fourier Transform (FFT) spectrum analyzer, which can also function as a transient recorder, was used in the analysis of background and simulated impact data. The transient capture feature of the analyzer uses digital techniques to record and store an analog signal continuously until sampling is stopped by the crossing of a trig-ger threshold. The selected signal is held in the memory of the instrument until a new event is captured. The stored signal can be viewed on the display of the analyzer or transferred to the analysis and plotting equipment. The spectrum analyzer was used to generate frequency spectra from the background noise and simulated impact signals. The spectra were plotted on linear frequency and amplitude scales, then analyzed in the frequency range of 0-20 kHz with an effective spectra resolution of 50 Hz. The amplitude units on the frequency spectra charts presented in Appendix A are a summation of g's per spectral resolution window. For background levels, 100 (typically) averages were performed with all data points having equal weight. For simulated impact testing, the frequency range and spectral resolutions were the same; and aver-ages wera performed using ten (typically) impacts. For a visual record, a visicorder (or another instrument of similar capability) may be used to provide simultaneous traces of the analog signals. From these traces, signal arrival time differences between channels can be determined. Thus, the source of the impact signal can be localized to the primary or second-ary side of the steam generator. See Diagram 5 for a functional block diagram of data collection and analysis.
l Westinghouse Class 3 ca. Data Collection and Analysis ated ondi. vels- The data is collected in accordance with Westinghouse DMIMS Baseline Signature i f an A isition Procedure, NSID-EIS-82-10. Data collected was recorded on a channel FM magnetic tape recorder set for a minimum bandwidth of 0-20 kHz, per IRIG specifications. See Diagram 5 for data collection and analysis equip-ment. All data from the tests have been evaluated using spectral analysis and tran-ient recording equipment to obtain information on the frequency and time domain characteristics of background signatures and simulated impact data. All the data analyzed was produced from a series of simulated impacts made at each location at a specific distance away from each accelerometer. The impact energy required was determined by dropping the hammers from a known height in our Pittsburgh lab and the voltages recorded there were recreated at GAE. Impacts made on the steam generator's primary and secondary sides were generated at a distance of approximately three feet away from the primary and secondary 'i accelerometers on the tube sheet. Impacts made on the reactor vessel top were generated at l'ast three feet from each sensor. Impacts made on the reactor vessel bottom were generated three feet away from each thimble tube which has an accelerometer mounted on it. Since the distance from the impact site to the > accelerometers varied with each location, the signal amplitudes of each impact generated will vary accordingly. Therefore, all factors, including impact site, distance, and mass, should be taken into account when choosing an alarm setpoint for the OMIM System. The signatures obtained from simulated impacts and steady-state background are presented in Appendix A for the various phases of signature acquisition. Pri- i mary and secondary flow transients for appropriate channels were scanned aurally using an audio amplifier system to detect any audible loose parts in the primary or secondary system. , i
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i i Signal Abbreviated Conditioner i Destination, location 750 RW Reactor Vessel Upper 751 RVU' Reactor Vessel Upper 752 RVL Reactor Vessel Lower 753 RVL Reactor Vessel Lower 754 SG11-P 4 Steam Gen. 11 (Primary) 755 ,f SG11-S Steam Gen. 11 (Secondary) 756 SG12-P Steam Gen. 12 (Primary) 757 SG12-S Steam Gen. 12 (Secondary) 758 SG13-P Steam Gen. 13 (Primary) 759 SG13-S Steam Gen. 13 (Secondary) 760 SG14-P Steam Gen. 14 (Primary) 761 SG14-S Steam Gen. 14 (Secondary)
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Westinghouse class 3 j System Operation
'1 g edic Maintenance. l The United States Nuclear Regulatory Commission Regulatory Guide 1.133 recom-mends that a periodic. check be performed on each of the accelerometer channels ;
f f sensitivity and. stability. This can be done on line by measuring and I ording the rms background acceleration levels of the signals (at the monitor- [n jacks on the connection panel) and comparing them to'the level recorded ! in this baseline' report. See Table 2 for a tabulation of these values for 100% ! ower and Table 3 for maximum background values that enable detection of 0.5 ; ht-lbf. impact. These values are provided for.use in meeting the requirements of l Regulatory. Guide ~ 1.133, Rev.1, Par. C 3a(2)(e)., in addition, background noise frequency spectrum data may be collected period-ically from each accelerometer and compared with the baseline to identify any trend in accelerometer or signal train, degradation and allow appropriate correc- l
'tive action to be planned. Should any accelerometer be replaced, a new signa-
- ture for that channel should be obtained.
i Regular maintenance of the system should be performed to keep the system at its full capability. Regulatory Guide 1.133, Section 8.3, details the functional test requirements for this system. Sicnal Conditioner Full Scale (SCFS)
- l SCFS should normally be set low enough to ensure that normal background noise I has a sufficient voltage level to yield an acceptable signal to noise ratio over l syttem electrical noise. The SCFS setting should also be high enough to ensure i that potential impacts would not be clipped. The recommended setting is 10g full scale, I-toaaino Threshold The logging threshold system value is primarily intended to allow the system to discriminate against low level impacts caused by in core detector vibration. If desired, it may be employed to discriminate against als.rms from a known loose part. Impacts with a maximum amplitude LESJ than ' THRESH 0LD' never appear on any printout or display It is recommended that this value be set near the nor-mal peak value of background noise. See Table 2.
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- gY i < E L A'valde less than or equal to the smallest level generated by the' 0.5
/ "7 a, , j /ft-ib,ispacts' simulated with the 0.25 :2.0 'ib hammers (this information I
> ' 4 can bofcund in Appendix' A)'.
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- A setpoWt'that is as sensitive 4.s possible, relative background icvels, a without caus,ing, spurious alarms.
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. Normal plantioperatIcn can generate smalf.1 increases in;the background level, sounds related to valv'ca;perations, or other innsients; . These signals should .
1, ' ' not generate alarmsFthe l i ' thresholo'can be employed to suppress these
. signals, but should be k. agg ng9pt lov enough to record low 19 vel'imoacts. ' The reco mended rettings in Trhle 3'weto-datermined using the above critoria and practi-
.i cal experience gained .at Georgia fower Company'p Vogtle Unit l'(GAE) and other 1
1 sites. When the fieal setpoints are progrtmme(custhe display, they should also . be programmed into the default setting dwitches on the OMIM circuit-. board 2'as 9 ' detailed in the DMIMS' Technical Manual. Note thit sy inpact less' than ' THRESH-0LD' is never tabulated or displayed and that those between ' THRESH 0LO' and
.- g 'SETPOINT' appear as impacts 'LESS THAN SETPOINT' on the systen display.
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Westinghouse Class 3 Table 2 m. Steady State Background Acceleration
- on plant Him SCFS V* g V* g Conditions Channel (G) (0-p) (0-p) (rms) (rms) s, Temp: 5880F 750 10 .015 .030 .007 .014 Press: 2235 psig 751 10 .043 .085 .032 .064 d power: 100% 752 10 .070 .140 .050 .100 Mode: 1 753 10 .065 .130 .052 .104 im- 754 10 .200 .400 .173 .346
- i- 755 10 .093 .185 .061 .122 tr 756 10 .100 .200 .050 .100 ilso 757 10 .085 .170 .048 .096
- 758 10 .110 .220 .069 .138 ISH- 759 10 .080 .160 .045 .090 760 10 .110 .220 .062 .124 761 10 .070 .140 .051 .102
= At DHIMS Connection Panel SCFS - Signal Conditioner Full Scale rms Root Mean Square 0p - Average Zero to Peak k' westinghouse Class 3 Conclusion It is concluded that the Digital Metal Impact Monitoring System installed at Georgia Power Company's Vogtle Unit 1 (GAE) meets the sensitivity required by United States Nuclear Regulatory Guide 1.133, Rev.1. The sensitivity require-ments are documented in this report by comparing the steady-state background noise with the impact signals. The impacts were made by using calibrated ham- M mers of 0.25 lb. , 0.50 lb.,1.0 lb. ,1.5 lb. , and 2.0 lb. weights. Cha Table 3 details the recommended system settings for Georgia Power Company's Vogtle Unit 1 (GAE). Channels 750, 752, 75.4, 756, 758, and 760 should be pro- 7 grammed into the DMIMS drawer as the monitored channels. Section 5 of the OMIMS Technical Manual outlines these instructions.
[' Table 3 also tabulates the maximum background acceleration levels that ensure ! impact detection of a 0.50 ft-lbf impact. This is the value to be used for the ' quarterly background noise comparison required by United States Nuclear Regula-tory Guide 1.133, paragraph C.3.a(2)(e). C' O Ni I! f 29 3'
I Westinghouse Class 3 Table 3 Unit 1 Recommended Systems Settings d a't ' e b G ou i e. stem Default Maximum Allowable Recommended Setting d ,dam. fwitchSettings Background Threshold Alarm MlH g (rms) g (0-p) g (0-p) Channel S1 52 S3 54 Y' 0 0 0.94 0.31 2.00 e- C C.
- o. 750 C C 0 0 1.49 0.50 2.00 he gg3 75j- C C 0 0 1.43 0.48 2.00-A 0 C C 2.40 0.80 3.00
\ f53 C 0 0 1.72 0.57 nsure 75 C C 2.00 C 0 C C 1.97 0.66 3.00 for\th 755 C C C 0 0.50 0.17 1.00 Regula. {y C C C 0 0.56 0.19- 1.00 758 C C 0 0 1.25 0.42 2.00-759 C C 0 0 1.12 0.37 2.00 760 C C 0 0 1.12 0.37 2.00 761 C 0 C C 2.19 0.73 3.00 C Closed 0 Opened Notes:
- 1) Default Setpoints are based on a signal conditioner full scale (SCFS) set-ting of 10 g's. Therefore, default settings must be recalculated when SCFS is : hanged.
- 2) This value is per the United States Nuclear Regulatory Commission Regulatory Guide 1.133, Rev.1, Paragraph C.3a(2)(e).
- 3) Threshold values should be less than or equal to the recommended settings.
I w -_--
'r Westinghouse Class 3 Appendix A r Baseline Signatures Description h
Simulated Impacts on Reactor Vessel Upper A-1 thru A-20 Simulated Impacts on Reactor Vessel Lower A-21 thru A-40 Simulated Impacts on Steam Generator 11 A-41 thru A-60 i I Simulated Impacts on Steam Generator 12 A-61 thru A-80 ) Simulated Impacts on Steam Generator 13 A-81 thru A-100 ] Simulated Impacts on Steam Generator 14 A-101 thru A-120 l J Mode 1 Conditions - 100% Power A-121 thru A-144
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i CENTER FREQ AVG SPECTRA NORM SPECTRA (Khz) (Grms) (unitless) L 0.5 1.340E-03 0.1929 1.5 6.727E-05 0.0097 ' 2.5 2.708E-05 0.0039 2.5 9.204E-05 0.0132 4.5 8.240E-05 0.0119 5.5 8.876E-05 0.0128 6.5 6.073E-05 0.0087 7.5 4.612E-05 0.0066 8.5 4.310E-05 0.0062 9.5 4.970E-05 0.0072 10.5 1.592E-04 0.0229 11.5 ' .726E-03 0.2484 12.5 1.039E-03 0.1496 13.5 '.298E-04 0.1049 14.5 9.267E-04 0.1334 15.5 2.927E-04 0.0421 16.5 8.764E-05 0.0126 17.5 J.773E-05 0.0040 18.5 i .98 3E-05 0.0027
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j CEN1ER FRE0 AVG SPECTRA NORM SPECTRA d (Khr) (Grms) (unitless) 0.5 2.620E-03 0.2435 J 1.5 1.567E-04 0.0146 2.5 5.978E-05 0.0056 3.5 2.361E-04 0.0219 4.5 1.128E-04 0.0105 5.5 7.602E-05 . 0.0071 6.; 5.775E-05 0.0054 7.5 1.765E-04 0.0164 8.5 5.320E-05 0.0049 9.5 1.568E-04 0.0146 10.5 7.793E-04 0.07:4 11.5 8.340E-04 0.0775 12.5 ' 621E-0c
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. 17.5 9.546E-05 0.0091 i- 1G.5 7.033E-05 0.0065 19.5 4. 95E-05 0.0045
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, (Khz) (Grms) (unitiess) 0.5 1.222E-02 0.5675 1.5 2.123E-04 0.0099 2.5 1.184E-04 0.0055 3.5 1.67tE-04 0.0078 4.5 1.180E-04 0.0055 5.5 1.132E-04 0.0053 6.5 1.129E-04 0.0052 7.5 *
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, 6.5 1.884E-04 0.0244 7.5 1.729E-04 0.0224 8.5 2.093E-04 0.0272 9.5 1.911E-04 0.0248 10.5 2.667E-03 0.3460 It.5 i.205E-03 0.1563 d
12.5 5.411E-04 0.0702 13.5 8.108E-04 0.!052 14.5 7.940E-05 0.0103 15.5 i.517E-04 0.0197 16.5 9.364E-05 0.0122 17.5 2.767E-05 0.0036 i 18.5 6.278E-05 0.0081
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n 4 f TABULATION OF NORMALIZED POWER SPECTRA A b CENTER FREO AVG SPECTRA NORM SPECTRA i (Khz) (Grms) (unttless) 1 0.5 2.206E-03 0.2547
" 1.5 2.329E-04 0.0269 2.5 6.013E-05 0.0069 3.5 6.423E-05 0.0074 4.5 1.165E-04 0.0134 5.5 1.137E-04 0.0131 6.5 1.435E-04 0.0166 7.5 7.993E-05 0.0092 8.5 7.487E-05 0.0086 9.5 6.42:E-05 0.0074 10.5 1.196E-04 0.0136 11.5 1.713E-04 0.0198 12.5 2.553E-04 0.0295 13.5 2.aStE-04 0.0283 i4.5 4.604E-04 0.0532 15.5 ;.:38E-03 0.2469 16.5 6.373E-04 0.0967 17.5 7.318E-04 0.0845 18.5 4.14cE-04 0.0478
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TABULATION OF NORMALIZED POWER SPECTRA CENTER FRED AVG SPECTRA NORM SPECiRA (Khz) (Grms) (unitiess) 0.5 3.131E-04 0.0037 1.5 1.02aE-04 0.0012 2.5 1.646E-04 0.0019 3.5 2.052E-02 0.2409 4.5 4.309E-02 0.5058 5.5 3.020E-03 0.0355 6.5 7.815E-05 0.0009 7.5 5.979E-03 0.0702 8.5 2.911E-03 0.0342 9.5 4.694E-03 0.0551 10.5 1.917E-03 0.0225 11.5 f.369E-03 0.0161 12.5 3.309E-05 0.0004
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CENTER FREQ AVG SPECTRA NORM SPECTRA (Khz) (Grms) (unttless) ' O.5 1.469E-04 0.1510 1.5 3.165E-05 0.0325 2.5 2.615E-05 0.0269 l 3.5 3.109E-05 0.0320 4.5- 9.068E-05 0.0932 5.5 3.404E-05 0.0350 i 6.5 5.687E-05 0.0585 7.5 2.202E-05 0.0226 8.5 c.271E-05 0.0234 9.5 3.393E-05 0.0349 10.5 2.296E-05 0.0236 1 11.5 3.187E-05 0.0328 12.5 ' 855E-05
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0.5 5.581E-05 0.1973 1.5 1.035E-05 0.0366 2.5 9.381E-06 0.0332 3.5 5.760E-06 0.020a 4.5 1.464E-05 0.0517 5.5 3.447E-05 0.1218 6.5 1.824E-05 0.0645 7.5 1.282E-05 0.0453 3.5 9.658E-06 0.0341 9.5 1.66aE-05 0.0659 10.5 9.333E-06 0.0348
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O.5 2.736E-04 0.0036 1.5 : .175E-03 0.0154 2.5 4.674E-03 0.0612 3.5 *
.795E-02 0.2352 4.5 1.056E-01 0.1364 5.5 2.iSOE-03 0.0282 6.5 5.279E-03 0.0692 7.5 2.565E-03 0.0336 8.5 ' 576E-03 . 0.0206 9.5 a.912E-04 0.0064 10.5 8.6R1E-03 0.1137 11.5 2.833E-03 0.037!
12.5 8.704E-03 0.1140 13.5 f.422E-03 0.0186 14.5 . 232E-03 0.0292 15.5 .636E-03 0.0345 16.5 6.767E-OL 0.0115 17.5 :.466E-03 0.0192 18.5 2.966E-04 0.0051 19.5 :. 965E-04 0.0051 M:P CHAN: 76' TAPE: 0'-86070i FOCTAGE: 29*.5 R- 118 --
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I' 4 TABULATION OF NORMALIZED POWER SPECTRA CENTER FREQ AVG SPECTRA NORM SPECTRA (Khz) (Grms) (unitiess) , 0.5 7.130E-05 0.0012 1.5 3.605E-04 0.0058 + 2.5 1.406E-03 0.0227 ; 3.5 5.822E-03 0.0939 4.5 4.826E-03 0.0779 5.5 1.214E-03 0.0196 6.5 1.021E-02 0.1647 7.5 4.575E-03 0.0738 E.5 4.915E-03 0.0793 9.5 1.203E-03 0.0194 10.5 4.323E-04 0.0070 l 11.5 ' 942E-04
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IABULATION OF NORMALIZED POWER SPECTRA CENTER FREQ AVG SPECTRA NORM SPECTRA (Khz) (Grms) (unitiess) 0.5 8.752E 05 0.0017 1.5 5.itSE-04 0.0098 2.5 8.548E-04 0.0163 3.5 1.397E-03 0.0256 4.5 1.484E-03 0.0283 5.5
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( , Westinghouse Class 3 l Appendix B l' I Actions in the Event of an Alarm The following text and flowchart provide guidelines to assist an operating utility in evaluating suspected loose part impacts. I. Acoustic Signal Analysis q A. Observe impact shape in the time domain to qualitatively evaluate signal l path and distance to accelerometers. By examining the impact's rise and decay times and amplitude, its relative proximity to accelerometers may be qualitatively estimated. B. Compare frequency spectra with known impacts (baseline data). The ratio j of particular frequency components present in a metal impact are indi- l cative of the characteristic length or mass of the impact source. The i baseline data may be used to identify the particular characteristic ) ratios. C. Evaluate time delays between channels to determine the direction of the j sound path. This, in conjunction with impact shape, is used to evaluate ' the source of the impact. D. Evaluate the repetition rate of the signal. If the repetition rate is high, it is more likely that a loose part does exist as opposed to the impact being noise generated from a normal plant transient. II. Considerations that Require Corrective Action A. Mass of Object: The loose part mass may be determined by comparison of the impact to baseline data. In general, it has been noted that objects with a larger mass have greater potential to damage some plant compo-nents. If the loose part mass is known, assumptions may be made about its impact velocity; and a more accurate judgment may be made concerning
- the plant safety.
B. Magnitude of Impact: Another good indicator of the potential damage which may be inflicted by a loose part, in addition to the object mass, is the impact magnitude. If the impacts are of relatively large magni- , tude, a ' greater potential for damage exists. This may be determined ' through observation of the impact signal in the time domain. C. Location of Impact Site: Certain areas in the plant are more suscep- , tible to loose part damage than others and have greater potential risk i concerning plant safety. Examples of these areas are the fuel region, the tube sheet, and the secondary side steam generator U-tubes. Loca- f tion of the impact site made by noting which accelerometer exhibits I a B-1 1
e p4 Westinghouse Class 3 i 3 I the highest amplitude for a given impact and by determining the time delays between accelerometers which detected the same impact. It is noted that some impact sites may have safety implications and some sites may result in only commercial considerations. D. Mobility: Mobility is determined by noting whether time delays between accelerometers remain constant, whether the impact signal is detected in different vessels, and noting changes in relative amplitude. The damage potential of a highly mobile loose part is uncertain due to the possi- i bility of the part becoming lodged in, or migrating to, a sensitive : ! location. If a part has limited mobility, a more accurate assessment of l 1 plant safety effects may be made. However, for such a loose part, the j damage may be concentrated in a single area. I E. Repetition Rate: Repetition rate may be determined by timing the rate of occurrence of the impacts. Impacts with a higher repetition rate, or course, have greater potential to cause damage. F. Retrieval Expense vs. Potential Damage: Once a reasonable assessment of l
. potential damage has been made, the retrieval expense should then be { i j estimated. Consideration must be given to the type of retrieval, pro- !
I bability of retrieval, and plant scheduling. Certain types of retrieval i j are more expensive than others and should be weighed differently. Parts i i in a reactor vessel, for example, are more ext ansive to retrieve than in the primary side of a steam generator. A certain amount of uncertainty exists when a determination of impact location is made. Because of this, the possibility exists that, once a retrieval has been attempted, the loose part will not be found in the expected location. This could occur as a result of the part moving after the last impact was detected or inaccuracies in the data analysis. Factors to be considered are the location of the part, whether it likes in an accessible area, the number of impacts available for analysis, and the number of accelerometers which detected the impacts and are usable
' for analysis.
If the plant is scheduled for an outage in the near future, it may be , more cost effective to wait until the scheduled outage before attempting ! the retrieval operation. This, of course, must be weighed against the ! potential damage which may occur in this time period. }
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Westinghouse Class 3 I Appendix C United States Regulatory Guide 1.133 Conformance by Section 1 i i Section B.1.a: The locations of the sensors in the plant were chosen to maximize the detection capability of acoustic disturbances. The monitored loca-tions are the steam generator tubesheets on the inlet side, top of the reactor vessel and the bottom of the reactor vessel. Because of plant design, these l locations are natural collection points. Past loose part monitoring experience ' has shown this to be the case. Additionally, each monitored location is equipped with two channels within an area that satisfies the criteria for redun-dancy. If one of the two channels at a location were to fail, the remaining' , channel would still provide adequate coverage of that location. Not only is j redundancy achieved, but the sensors have been strategically positioned so as to i facilitate impact signal timing to determine a specific loose part location. On 1 the steam generators, this is done by vertically aligning the sensors approxi- j mately 30 inches above and below the tubesheet centerline; thus allowing a pri- i mary vs. secondary side impact source determination. The same principle applies i to the reactor vessel bottom except that the vessel bottom sensors are mounted I
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180 degrees apart. Section 8.1.b: On-line system sensitivity has been demonstrated by dropping weights at locations and impact energies as specified by the Regulatory Guide. The simulata ' impact amplitudes were compared to background amplitudes at vari-ous plant conditions to determine if the alarm circuitry can distinguish between these two levels. This is then used to determine an alarm level which will given an indication of an impact but will not cause excessive false alarms due . to background noise. l Section B.1.c: Channel separation is maintained by utilizing separate l electrical conduit and junction boxes from the sensor up to the containment penetration. This section of Regulatory Guide 1.133 does not imply that confor-mance with Regulatory Guide 1.75, " Physical Independence for Electrical Sys-tems," is required. Therefore, complete channel (i.e., train) separation is not l required outside of containment.
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