ML20062J697
| ML20062J697 | |
| Person / Time | |
|---|---|
| Site: | Dresden  |
| Issue date: | 10/10/1980 |
| From: | Crutchfield D Office of Nuclear Reactor Regulation |
| To: | Abel S COMMONWEALTH EDISON CO. |
| References | |
| TASK-06-07.C1, TASK-07-06, TASK-08-01.A, TASK-08-02, TASK-08-03.A, TASK-6-7.C1, TASK-7-6, TASK-8-1.A, TASK-8-2, TASK-8-3.A, TASK-RR NUDOCS 8011050045 | |
| Download: ML20062J697 (42) | |
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NUCLEAR REGULATORY COMMISSION
- E WASHINGTON, D. C. 20555 5
o October 10, 198G Dockets Nos.: 5021 50-237 Mr. J. S. Abel Director of Nuclear Licensing Connonwealth Edison Company Post Office Box 767 Chicago, Illinois 60690
SUBJECT:
SEP TOPICS VI-7.C.1, VII-6, VIII-1, VIII-2, AND VIII-3, LOSS OF 0FFSITE POWER - DRESDEN 1 & 2
Dear Mr. Abel:
As part of the staff's efforts to obtain reliable information on loss of offsite power in connection with SEP Topics VI-7.C.1, VII-6, VIII-1, VIII-2, and VIII-3, we have prepared the enclosed status report. We are forwarding it to ycu for review and comment regarding the causes and possible remedies for those events described. We request your response within 60 days of your receipt of this letter.
Sincerely, l%,62xluf Dennis M. Crutchfield, Chief Operating Reactors Branch No. 5 Division of Licensing
Enclosure:
As stated cc w/ enclosure:
See next page j
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Mr. J. S. Abel October 10, 1980 cc w/ enclosure:
1 sham, Lincoln & Beale Department of Public Health Counselors at Law ATTN: Chief, Division of One First National Plaza, 42nd Floor Nuclear Safety Chicago, Illinois 60603 535 West Jefferson Springfield, Illinois 62761 Mr. B. B. Stephenson Plant Superintendent Director, Technical Assessment Dresden Nuclear Power Station Division Rural Route #1 Of fice of Radiation Programs Morris, Illinois 60450 (AW-459)
U. S. Environmental Protection Agency Natural Resources Defense Council Crystal Mall #2 917 15th Street, N. W.
Arlington, Virginia 20460 Washington, D. C.
20005 U. S. Environmental Protection U. S. Nuclear Regulatory Commission Agency Resident inspectors Office Federal Activities Branch Dresden Station Region V Office RR fl ATTN:
EIS C0ORDINATOR Morris, Illinois 60450 230 South Dearborn Street Chicago, Illinois 60604 Susan N. Sekuler Assistant Attorney General Resident inspector Environmental Control Division Dresden Nuclear Power Station 188 W. Randolph Street c/o V. S. NRC Suite 2315 Rural Route #1 Chicago, Illinois 60601 Morris, Illinois 60450 Morris Public Library Mr. Richard E. Schaffstall 604 Liberty Street KMC, Incorporated Morris, Illinois 60451 1747 Pennsylvania Avenue, N. W.
Washington, D. C.
20006 Chairman Board of Supervisors of Grundy County Grundy County Courthouse Morris, Illinois 60450 l
s-
3 LOSS OF 0FFSITE POWER SURVEY STATUS REPORT Abstract:
This report describes the method for data analysis and the results of a survey of loss of power events at domestic nuclear power plants.
==
Introduction:==
As a result of the staff efforts on several related Generic Activities (e.g., A-35 and A-44) the staff became concerned about the accuracy of the available loss of offsite power data. This contern, along with the results of the Lewis i
j Study, lead the staff to request that all nuclear power plants provide the information specified in Table 1.
I Of the 69 licensed nuclear power plants,13 did not respond.
These plants are identified in Table 2.
In addition to the survey input, data was also obtained from Licensee Event Reports while evaluating Diesel Generator experience.
Discussion: The steps in data reduction and analysis are summaried below.
1.
The data was sorted into Type A or B data in 'accordance with Table 1.
(No Type C data was received).
2.
For each event a cause code was assigned. The cause codes are presented in Table 3.
3.
A map showing the distribution of the number of each type of-failure as a function of each respondant plant was prepared. This is presented as Table 4.*
4.
The " age" of each plant was determined based on the date of its first reported loss of offsite power until June 3,1980. This date is presented as Table 5.
(Because Crystal River 3 and Duane Arnold reported that no loss of offsite power events have occurred, the age could not be established and all data fields were set to zero.)
Computer output is presented in Appendix A (data) and Appendix B (results).
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2-5.
The data of Table 4 was re-plotted as a function of age to yield loss of power event rates (events / year).*
6.
The data was subjected to several different analyses to determine if it could be characterized on a generic basis. These attempts were not generally successful because of the large scatter in the data. However, all attempts are ioentified in the results below.
7.
Beyond the attempts to characterize the data on a generic basis, each plant was evaluated, for each of the causes, to determine if its failure experience was significantly different from the average. Significant was defined as a " target" value (events / year) greater than or equal to the mean plus three standard deviations.
8.
A draf t report (Revision 1) was sent to the utilities that experienced a high number of events in excess of the target values for coment. As a result of the cotirnents received from one of these utilities, the methods were changed such that Table 4 now presents the total numoer of lines lost per plant per cause and the loss of power rates were calculated on a per line basis by normalizing the data of Table 4 by the numoer of offsite lines shown in TaDie 6.
(Prior to these changes, plants having a relatively large number of lines, e.g. 5, were exceeding the target values much more often than those with two lines. Thus, those plants that, by virtue of redundancy, were least likely to experience a total loss of power haa been shown in a worse light than the smaller grids.)
The following are the numerical results of this sbidy.
Results:
1.
There havc been 1102 reported total and partial losses off offsite power.
This represents a mean event rate of 2.75 events / year.
2.
There have been 105 total losses of offsite power reported by the 66 respondants. This represents an average rate of 0.26 events / year.
3.
The mean duration of a total loss of offsite power is 3.6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> with a standard deviation of 5.71 hours8.217593e-4 days <br />0.0197 hours <br />1.173942e-4 weeks <br />2.70155e-5 months <br />.
4.
The mean time to partial recovery (from a total loss of offsite power) is 2.08 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> with a standard deviation of 4.78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />.
5.
The mean duration of a partial loss of offsite power is 10.66 hours7.638889e-4 days <br />0.0183 hours <br />1.09127e-4 weeks <br />2.5113e-5 months <br /> with a standard deviatiot. Jf 141.57 hours6.597222e-4 days <br />0.0158 hours <br />9.424603e-5 weeks <br />2.16885e-5 months <br />.
.. 6.
An attempt was made to obtain a least squares fit of the mean valve of the time of outage vs. the percentage of offsite power lost (% lines).
No such fit was achieved (confidence level was less than 95%).
7.
The mean duration of outage due to lightening strikes is 0.78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> with a standard deviation of 4.29 hours3.356481e-4 days <br />0.00806 hours <br />4.794974e-5 weeks <br />1.10345e-5 months <br />.
8.
The mean voltage drop is 16.19% with a standard deviation of 29.05%..
9.
The mean frequency drop is 3.75 Hz with a standard deviation of 5.55 Hz.
- 10. The mean frequency decay rate is 1.31 Hz/sec with a standard deviation of 1.8 Hz/sec.
- 11. Palisades has reported the most significant annual event rates as noted below:
(a) Total event rate 3.62 vs. a target of 3.55, (b) Cause 5 event rate 0.25 vs. a target of 0.25, (c) Cause 7 event ate 0.32 vs. a target of 0.21, (d) Cause 22 event rate 0.66 vs. a target of 0.63, and (e) Cause 29 event rate 0.13 vs. a target of 0.08.
- 12. Haddam Neck, Turkey Point 3, Indian Point 3, Pilgrim 1, Maine Yankee, and Calvert Cliffs 2 had a 2 causes each that exceeded the target values.
Conclusions 1.
The loss of offsite power rate is 2.75 events / reactor year for some loss and 0.26 events / reactor year for total loss.
2.
The Palisades station lightening protection and protective relaying system should be further evaluated to determine the causes for the relatively high frequency of trips and to determine if suitable modifications can be made to reduce these rates.
3.
Depending on the results of the Palisades studies, consideration should be given to similar studies of the Haddam Neck lightening protection.
Recommendation Pursue the evaluation of Palisades.
a.
~
e-TABLE 1 REQUEST FOR AG3ITIONAL INFOR.ATION
_USED IN SURVEY A.
For losses of offsite power where less than all offsite power was lost:
1.
How many circuits to the offsite network are normally available and how many were lost during the event?
2.
What was the cause of,,the event?
3.
Why did the other lines not fail when some did fail?
4 Was any voltage increase or decrease experienced just prier to or during the outace? If so, please give details, voltages reached, decay rate, affects on equipmer.: operation, etc.?
6.
How long was power unavailable from the circuit?
L 7.
Date of Event.
B.
For losses of all offsite power:
1.
How long was the Power off? How long for partial recovery?
Please give details.
2.
I'f turbine trip occurred, how soon af ter did loss of o# site power occur?
3.
If power was recovered promptly (10 minutes or less), was it due to automatic or manual actions?
4.
Was any voltage increase or decrease experienced just prior to or during the outage?
If so, please give details, voltages reached, affects, etc.
5..
Was any frequency decay experienced just prior to or during the outage?
If so, please give details, lowest frecuency reached, decay rate, affects on equipment operation, etc.
6.
Date of Event.
C.
Were there any other loss of offsite power events other than we have listed?
If so, please give details of each event.
O
TABLE 2 PLANTS NOT PROVIDING THE DATA REQUESTED IN TABLE 1 ORB #1 ORB #4 50-295 Zion 1 50-346 Davis-Besse 1 50-304 Zion 2 50-269 Oconee 1 50-270 Oconee 2 50-287 Oconee 3 50-312 Rancho Seco 50-289 Three Mile Island 1 50-320 Three Mile Island 2 ORB #3 ORBe5 50-325 Brunswick 1 50-155 Big Rock Point 50-366 E. 1. Hatch 2
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TABLE 3 CAUSE CODES Code Cause
?
Not reported 0
Unknown 3
Circuit breaker trip during relay testing, improper yard switching operations, improperly set relays, maintenance errors, relay testing errors, t6st equipment failure, CT failure, maintenance outages, wiring errors 5
/ault with or without protective relaying failure or with or without manual scram, bolted faults 7
Protective relay or carrier failure 9
Insulator failure (lightening arrester,- transmission line insulator, transformer bushing, pot head, cable insulation) 13 Foreign conducting object l
15 Winter storm 20 Breaker failure 22 Li ghtening 23 System undervoltage 24 Transformer winding failure 25 Forest fires 29 Construction activities 31 Summer storm 32 System collapse 34 Mechanical failure of conductors or stays or supporting structures other than code 36 42 System imballance Misc.
Miscellaneous (i.e. (1) failure is an instrument inverter with a second channe bypassed, (2) turbine generator voltage regulator failure, (10) turoine rumoack due to loss of control roa position indication, (12) inadequate line height, (28) lightening with breaker fatlure, (33) false relay operation with redundant line(s) out of service for maintenance, (35) autamatic scram, (36) motor venicle hitting pole, and (42) system inoallance.
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3.47 272 Salem 1 3.09 335 St. Lucie 1 3.05 277 Peach Botton 2 6.05 336 Millstone 2 4.17 344 Trojan 4.13 346 Davis Besse 0.23 348 Farley 1 2.71 368 Arkansas One 2 5.28 409 La Crosse 9.37 l
TABLE 6 NUMBER OF 0FFSITE LINES DOC NL DOC NL 3
2 304 2
10 4
305 3
29 2
306 2
133 2
309 2
155 2
31 3 4
206 7
31 5 2
21 3 2
31 6 2
21 9 3
31 7 2
220 2
31 8 2
237 7
321 2
244 2
324 2
245 2
331 2
247 2
333 2
249 7
334 2
r 250 7
335 2
251 7
336 2
254 4
338 2
255 5.3*
344 2
259 8
346 2
260 8
348 2
261 6.5*
368 4
263 2
409 2
265 4
266 2
267 2
269 2
270 2
271 5
272 2
277 2
278 2
280 2
- average number available curing study period 281 2
282 2
285 7
i 286 4
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287 2
289 2
293 3
l 295 2
296 8
298 5
301 2
302 2
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l'AIA SHMNARY FHk 9/ 6/H0 lHIAL NilHlif k Of RE PHklLla i Ut N TS t 05' Al 4 244 w
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25 la THI At. R OSS Of HFFS!IE POWEk HAXIHilH HHilkS = 20.00 MININHH llutikS = 0.0 HLAN = 3.6 SIGMA = 5.71 N.= /5 IINE 10 PAk1I Al. RLCilVERY HAXIMON HHilkS = 24.62 e -
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