ML20154Q453
| ML20154Q453 | |
| Person / Time | |
|---|---|
| Site: | Perry  |
| Issue date: | 01/31/1986 |
| From: | James Keppler NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION III) |
| To: | Edelman M CLEVELAND ELECTRIC ILLUMINATING CO. |
| Shared Package | |
| ML20154Q404 | List: |
| References | |
| CAL-RIII-86-01, CAL-RIII-86-1, NUDOCS 8603210169 | |
| Download: ML20154Q453 (3) | |
Text
{{#Wiki_filter:DRAFT ATTACliMEllT I CONFIRMATORY ACTION LETTER CAL-P,III-86-01 8603210169 860317 PDR ADOCK 05000440 G PDR 35
CONFIRMATORY ACTION LETT_E_R hrac UNITED STATES pt NUCLEAR REGULATORY COMMisslON g j' 'g s nEciousii In f 799 ROOSEVELT RO AD g cLEN ELLYN, ILUNOIS 60137
+...+ CAL-RIII-86-01 J AN 311986 Docket No. 50-440 Docket No. 50-441 The Cleveland Electric Illuminating Company ATTN: Mr. Murray R. Edelman Vice President Nuclear Group Post Office Box 5000 Cleveland, OH 44101 Gentlemen:
This letter confirms the telephone conversation between Dr. C. J. Paperiello of this office and yourself on January 31, 1986, related to the seismic event that occurred on January 31, 1986, in the vicinity of the Perry Nuclear Plant. It is our understanding, with regard to this matter, that you will:
- 1. Conduct a thorough review to detennine if the earthquake was within the Design Basis of the plant (FSAR).
- 2. Identify any damage as a result of this seismic event; determine if that level of damage was as expected.
- 3. Determine that all equipment, including snubbers, that actuated during this event returned to normal operating conditions / positions; identify any anomalies.
- 4. Identify any actions required to complete licensing of the plant related to this event.
- 5. Maintain all affected equipment in the "as found" condition. Therefore, take no action such as removing, repairing or replacing equipment which would destroy or cause to be lost, any evidence which would be needed to investigate this event. Routine maintenance may be performed provided that no information related to the event is altered or destroyed.
- 6. Submit a fonnal report of your findings and conclusions to the NRC Region III Office within 30 days.
CONFIRMATORY ACTION LETTER
e . . CONFIRMATORY ACTION LETTER The Cleveland Electric Illuminating 2 JAN 311986 Company Please let us know immediately if your understanding differs from that set out above. Sincerely, James G. Keppler Regional Administrator cc w/ enclosure: J. J. Waldron, Manager, Perry Plant Technical Department M. D. Lyster, Manager, Perry Plant Operations Department L. O. Beck, General Supervising Engineer, Nuclear Licensing and Fuel Management Section DCS/RSB (RIDS) Licensing Fee Management Branch Resident Inspector, RIII Harold W. Kohn, Ohio EPA Terry J. Lodge, Esq. James W. Harris, State of Ohio Robert H. Quillin, Ohio Department of Health CONFIRMATORY ACTI0N LETTER
DRAFT ATTACHMENT II LETTER TO MR. HAROLD R. DENTON February 12, 1986 36
4 ./ 6 THE CLEVELAND ELECTRIC ILLUMIN ATING COMPANY P O. BOX 5000 - CLEVELANO, CHIO 44101 - TELEPHONE (216) 622-9800 - ILLUMINATING BLOG. - 55 PUBLICSQUARE Serving The Best Location in the Nation MURRAY R. EDELMAN VICE P4EStOENT NUCUAR February 12, 1986 PY-CEI/NRR-0437 L Mr. Harold R. Denton, Director Office of Nuclear Reactor Regulation U. S. Nuclear Regulatory Commission Washington, D. C. 20555 Perry Nuclear Power Plant Docket Nos. 50-440; 50-441 Seismic Event Evaluation Report
Dear Mr. Denton:
My letter to you dated February 5, 1986, committed to provide a report on our response and activities related to the earthquake which occurred in the vicinity of the Perry Nuclear Power Plant. Enclosed is the Cleveland Electric Illuminating Company (CEI) report titled " January 31, 1986 Earthquake-Seismic Event Evaluation" for the Perry Nuclear Power Plant. This document has been prepared by CEI and our consultants following a thor-ough and detailed assessment of the plant response to the January 31, 1986 earthquake. This report demonstrates the appropriateness of the seismic de-sign for the Perry Nuclear Power Plant. Although this recent event provides an additional " data point" for historical seismic event activity, it will not alter any of the design criteria or licensing basis.
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I Mr. Harold R. Denton February 12, 1986 Page 2 We believe that this report provides the information necessary to support the staff's review and we are available to meet with your staff as necessary. Should you or your staff have any questions please feel free to call. Very truly yours, Murray R. Edelman Vice President Nuclear Group MRE:L cc: Jay Silberg, Esquire John Stefano J. Grobe D. Eisenhut R. Bernero . W. Butler G. Lainas J. Keppler C. Norelius C. Paperiello R. Knop 9
DRAFT ATTACHMENT III CONFIRMATORY ACTION LETTER CAL-RIII-86-01A i L i i
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i CONFIRMATORY ACTION LETTER CAL-RIII-86-01A I ( CR d& 8 25 FEB 0 41986 l Docket No. 50-440 Docket No. 50-441 The Cleveland Electric Illuminating Company ATTN: Mr. Murray R. Edelman Vice President Nuclear Group Post Office Box 5000 Cleveland, OH 44101 Gentlemen: This letter refers to our earlier Confirmatory Action Letter, CAL-RIII-86-01, dated January 31, 1986. Item 5 of that letter states that all affected equipment will be maintained in the "as found" condition but allowed routine maintenance to be performed. As a result of the inspections by our Augmented Investigation Team (AIT) and the subsequent conversations between the AIT leader, Dr. C. J. Paperiello, and Mr. M. D. Lyster, of your staff, we are amending and clarifying Item 5 as follows. It is our understanding, with regard to this matter, that you will:
- 1. Maintain all seismic monitoring instrumentation in the "as found" condition. Take no action such as removing, repairing, calibrating or replacing instrumentation which would destroy or cause to be lost, any evidence which would be needed to investigate the event. Maintenance, surveillance, and calibration will be performed only with the prior concurrence of NRC Region III management.
- 2. Resume all other activities including work such as, but not limited to, maintenance, training, surveillance, operations and calibrations under the following conditions:
A. All off normal conditions identified during these activities will be documented in accordance with CEI's programs and procedures. B. Off normal conditions will be evaluated to determine if they were potentially earthquake related. CONFIRMATORY ACTION LETTER q L
CONFIRMATORY ACTION LETTER t The Cleveland Electric Illuminating 2 Company C. Equipment identified in an off normal condition will be maintained "as found" until evaluated. Equipment determined to be potentially earthquake affected will be maintained in an "as found" condition until released by the NRC. D. The NRC will be notified of all off normal potentially earthquake related conditions within 24 hours.
- 3. Develop special procedures to implement Item 2.
Please let us know immediately if your understanding differs from that set out above. Sincerely, Original s.1$ned by J.r m s G . Kc n ;e r James G. Keppler Regional Administrator cc: J. J. Waldron, Manager, Perry Plant Technical Department M. D. Lyster, Manager, Perry Plant Operations Department L. 0. Beck, General Supervising Fuel Management Section DCS/RSB (RIDS) Licensing Fee Management Branch . Resident Inspector, RIII Harold W. Kohn, Ohio EPA Terry J. Lodge, Esq. James W. Harris, State of Ohio Robert H. Quillin, Ohio Department of Health l V l RIII Ws RIII y,, R II n RIII RJII RIIp l Sch Knop /pd pyy) Wa'rnick f j, y PL riello N Davis Kpop er 2/ 4 /86 7 q F0 Us N'V/sk y g.j g4 CONFIRMATORY ACTION LETTER
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DRAFT ATTACFMENT IV CONDITION REPORT EVENT INVESTIGTATION CR-86-0106 1 i 38
l 2,l& PA 36l0 Pege 1 of 8 CONDITION REPORT EVENT INVESTIGATION C_R_-8h-010A E v e n t D e a c_r i p.t a o.n On Friday, Jenuary 31, 1986 at approximately 1148 hours, a step increase of approximotely one and one half inches (1 1/2") was level)q observed on both the Suppression Pool wide Each end narrow range instrument loop in recordera, 1G43-ROO93A/B and 1G43-RO73B. totally independent in that they have aeparate power supplica, annaing and reference lega, and are mounted in different locations. This step change won therefore assumed to be related to the meiamic event which was experienced at approximately the came time. In en attempt to ascertain the cause of the observed step change, as found date only was taken on the Suppresalon Pool level instrumenta by the performance of Surveillance Instructions accomplished following prior G43-T1305 A thru F. This work was p approval from both plant management and the NRC resident , inspector. The as found data indicated that there was a measurable positive 2ero shift of approximately three eights to { three quarters of an inch (3/8" to 3/4") of pool level from the previous calibration data taken approximately two months prior. I n ve s t ig o t_ ion o f_fo_t_e n t i a l Caunca The cause of the recorded level increase was investigated at first for possible sources of water being dumped or leakedThe into the atep suppression pool as a result of the aciamic event. increase of 1 1/2 inch corresponda to approximately_5200milona- S of water. Prior to the event there had been indication of a small but continuous pool level increase of approximately 800 gallona per day due to a known source. Engineering evaluation after the event produced an extremely low probability that the level increcee won due to en actual level increase in the suppression pool, aa no potential source showed a corresponding loan of water inventory. The measured instrument zero offset of 3/8" to 3/4" taken from the Surveillance Instruction data did not correspond directly w2th the recorded increase of 1 1/2 inch. Aa a result it was decided to investigate the following arean of potential cause: Potential seismic damage to the Rosemount differential preasure trananittera Inntalletion of the level transmittero Calibrotion procedure or technique
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i n 259 36lD ' Page 2 of 6 Air entrapped in the variable senaing lines due to inadequate filling and venting after the recent suppreanion pool outage Recorder pen aticking To assist in the evaluation, NDLAS celled in factory representatives from Romemount, the manufacturer of the instrumentation. The overall investigation covera from January 31 to February 14,1986.
$na_lyata Several possible causes of the obaerved anomaly were considered, however only those discuneed below d2 epley a reasonable degree of probability or collaborating evidence:
potential Seismic Damage - At first, it was esaumed that thoro could have possibly been come damage to the Rosemount differential transmitter resulting from the seismic event. NDtAS has recoerched the environmental qualifs. cation of the transmitter an compared with the actual sciamic event data, and report that the test response spectre of the Rosemount transmitter enveloped the seismic event. In a further attempt to confirm potential sciamic damage, three almilar differentiel preocure instruments, listed below, were tested by taking so found data only using the corresponding Surveillence Instruction. All of the selected instrumento had been previously calibrated in a time frame similar to that of the suppression pool level transmitters. The resulta of the data taken from thene instrumenta ahowed no seesurable offset, and the os found data compared favorably with the an left dote from the previous calibration. in_atrum9nt Nu_mber Surveillance _N_umbe__ r IE12-N053A E12-T1193 1E12-N053B E12-T1195A lE12-N053C E12-T1195B Cloco observation of the suppresalon pool level transmitter zero offset showed that if the value of the zero shift was subtracted from the data pointo taken, that all values would then fall within the leave-aa-ia zone for the loop celibration. This oboervation eliminated all other loop componente except the level transmitter ao a potential source of deviation. It was then necessary to take o clocor look at the transmitter installation. T r a.n a m i t_t e_r. I n s t a l_1_a t i o_.n. - The Rosemount factory r eprese nte t.i veo could find no probleme with the installation of the transmitter that could potentially cause a zero offset or step change in transmitter output. A review of each instrument's history file showed some previous occurrence of zero offant as a result of
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l 2h %59 3610 Pcga 3 of a changing mounting hardware, but not evident on all transmitters, A trend analysis shous that after the observed shift, subsequent recalibration showed no trend of zero offset, nor any common cause could be identified for the offset. The factory representatives did offer some observations with respect to the calibration technique used and installation of the sensing lines.
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CaJ_1bration. Technique - The supprension pool level instrumenta are l designed auch that they have a " dry" reference leg, vented to containment atmosphere, and a wet variable leg annaing pool icvel. l This configuration requires the une of a "hnad tank" on only the ; variable side. A head tank is used to allow the inatrument to be , I calibrated with water. It is crucial that the head tank be it the acme elevation each time the calibrotion la performed. The methods to accomplish this are for the most part left up to the technician with the probable result being that the reproducibility of the calibration la questionable. Dry calibration techniques cennot be used because not all water can be removed from the An instrument, and as a result, an offset would be experienced. additional problem occurs in that if the instrument bypeaa valve in opened, water would be admitted to the reference leg. Water in the reference leg would result in a positive offset. During the taking of as found date, no water was observed in the reference leg. Additionally, it is relatively impossible to cause water to enter both reference legs at the some time, unless the containment to flooded to above the 674.0 foot elevation. When calibrating with one head tank, extreme core must be observed when adgusting the elevation of the tank. The current procedure is to match the elevation of the head tank with the center of the vont screw on the transmitter. If the tank is above the center line, a negative offset will occur, and below the center will result in a positive offset. It should be noted that there is no mounting mechanism currently provided to align and hold the position of the head tank assembly during calibration. TYMcM$5w 5- way V'4 f v<. 9 i To Press
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I Sllo 2,59 36lb Page 4 of 8 S.ensing Line_ Ins _tallation.- The sensing lines for the narrow range trenamittere are extremely long es compared with the wide range. There are neveral high pointa that have installed. There are et least three high points in common with both narrow and wide range transmittora, but only one of these pointo la vented. The supprecelon pool transmitters had been filled and vented after the suppression pool outage, approximately two weeks prior to the event. Our current program does not require a formel procedure for filling and venting every instrument in the plant. There are ' however, generic Instrument Maintenance Inatructions (IMI's) providing methodology for the filling and venting of various types of instruments. It was pic- tously observed that the filling and venting of the suppresolon pool lines was difficult due to the short section of three quarter inch pipe followed by a long acetion of small instrument line. The method used was to open the instrument vent linee, and allow the water to flow until the verlable line no longer shawed signs of air. The other high points would be vented in a himilar manner. This method does appear to be inadequate in that it remains uncertain that the variable sensing line may not I be fully vented of all entrapped air due to the low maas flow rate of the water through the instrument linea and vent valves. The geometry of the acnuing lines to auch that the amount of residual entrapped air would be roughly equal in both loops in the section upstream of the narrow range top. Recorder Pen Movement - It han been conerved that when a recorder pen receives little or no movement, the pen may tend to " stick" in place until a force, such so a shake or tap, causes the pen drivers to overcome the slidewire resistance (friction). At first, it was assumed that this may have been a major contributing cause of the observed step increase. The momentary shake, combined with the actual momentary change in pool level could have contributed to the discontinuity of the chart trace. Further investigation shows that no other active chart recordere showed a similar pen movement at the time of the event. Additionally, the expected step change would be much less than observed at the current gain netting of the recorder amplifier. It may then be aurmised that the observed change in level was not a result of a
" stuck" recorder pen.
Prgbable_ Q usy ND&AS has performed an analyala of the earthquake and how it should have affected the Rosemount differential transmittera. They have found that the event wee within the environmental qualification of the instrument, and that they responded as expected. This evaluation is substantiated in that there were no other inotruments other then the suppreselon pool level that showed an abnormel indication during or after the event. No other recorders or differential pressure instruments were observed to i
b blo M9 3hlo Pcga 5 of 8 oxhibit similar or any other anomalies. The actual level of the suppression pool was surveyed, and the resulta show that all of the instruments are currently indicating approximately thirteen sixteenths inch (13/16") lower then actual level. The instrumente do have a 3/8-5/4 inch positive zero offact which make the instrumente acnaing actually about an inch to inch and one half (1 - 1/2") lower then octual icvel. This difference la most likely due to nome amount of air atill being j ontrapped in the annaing lines. The air entrapment la due to the . Inability to completely fill and vent the existing lines from the l sensing tap to the inntrument. Aa mentioned earlier, there currently existe three points in the censing line, between the sensing tap and the toe where the narrow range instrument line tops off, where the high points cannot be vented. Two of these points are in the three quarter inch line, where a high moes flow rate would be required in order to completely remove any entrapped air. Most important to note la ' that the seneing line inside the suppression pool has en elevated offset just prior to the elbow which directs the sensing line down j towards the pool floor (see sketch below). The opening is directed towards the floor to minimize the turbulent effects when RHR in running, as both the RHR auction line and the level sensing line chare the came penetration. $Wffit'sslu) I , Myj' A / wa/ Entearmeut gr -- l0
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[ k / b t., [ / n/c 1A J Alof Ts Scale W This offset can, and is expected to at111 contain some entrappuu cir. Entrapped air in thie location will have equal effect on both the wide and narrow range level channele. Both the A and B instrument loops are installed on a similar manner. Anauming that the eeneing line contained air in the location described, prior to the event all of the suppression pool level inntrumente may have been indicating about two and one half inches (2 1/2") lower then actual pool level. At the time of the carthquake, the pool was upset, causing a " wave" effect. This upset con be clearly seen on the suppression pool level recorder charte. When the level went momentarily low at the manalng tap,
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there woe a momentary vacuum sensed at the end of the pipe tap. 1 Thia low pressure caused some of the entrapped air to be pulled out the end of the pipe, reaulting in a restoration of about 1 1/2
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l ?uilo $M 36lb Page 6 of 8 inch of level. As mentioned before, it la expected that there still may be as much as one inch of air still entrapped in the senaing lines. This phenomena occurred at both senajng tapa in nearly equal magnitude, and almost simultaneously. It la not expected that the zero shift had anything to do with the vbaetve.d atep change in level, but existed prior to the event, and was due to the improper elevation of the water head tank during calibration. Similar zero shifts were observed prior to the event on the suppreaalon pooi level channela and the condensato atorage tank level instruments which utilize a similar installation of both a wet and a dry eenuing line. At this time, the spontaneous venting of some entropped air in both of the suppression pool level instrument eenalng linea la the only suspected cause for the obaerved pool level change at tho imc of the aciamic event. Several corrective actiona are therefore recommended. p r.o,p o s e d Cor_rective A c t_i o n rt S e n.e.1_n t L i n_e._ E1_1_11 net e n_d_ Ven_t i n_q - The facilitica currently installed are inadequate to provide complete filling and venting of tne senalng lines. Additionally, due to the complex nature of the process being measured and the difficulty in assuring the proper and repeatable venting and filling, the following actions will be taken: Installation of Sensing Lines - An EDCR hoe been prepared to provide at least two additional high point vents. One of the vents shall be in the three quarter inch line upstreen of the containment isolation valve to ceaure adequate flow rete through the unventable high point inside the suppression pool. Installation of the high point vente should be completed prior to entering Operational Mode 3 CA-86-106-Ol To approve EDCR, Instrument & Controla Section. Duc dato March 1, 1986 Ei_ll i nq _a n_d_ V e_nt i ng Pro _cedure - A detailed Instrument Maintenance Instruction will be prepared to provido step by step instruction to assure the adequate and repeatable filling and venting of the sensing lines. The I&C supervisors will assure that personnel who are easigned the task of filling and venting the suppresalon pool level sensing linea w111 have been properly treined in thia activity prior to st arting . CA-86-lO6-02 To prepare and apporve IM1 for filling and venting sensing lines. Instrument & Control Section. Due date March 15, 1986. l m
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._natrument Collbration - The methodology used for the calibration I
of differential precaure instruments with one wet and one dry senaing line 10 difficult to implement. portable tent equipment is difficult to adjust to assure proper repeat _ob.l_e_ positioning of the head tank assembly. The following corrective actions will be taken to assure future calibrations do not introduce zero offoot 91 tors: H o.o_d_ Tk a_ri . A s s e m b l i e s - An EDCR has been submitted to provide for the installation of permanently head tank assemblica on all instruments which have one wet and one dry conoing line. This will include the suppression pool and condensate storage tank level transmittera. Use of permanently inatalled head tanks will assure repeatable resulto due to the occurate pooitioning of the test equipment. The head tenk assemblien ahot:ld be installed prior to the end of the first refueling outage. CA-86-106-03 To approve EDCR for head tonk assemblies, Instrument & Control Section. Duc dato March 1, 198b. Instrument Calibration Instructions - The Surveillance Instruction for tho suppression pool level channel calibration will be revised to incorporate appropriate changes to the calibration methodology so se to assure proper positioning and use of portable head tanks untti permanent tanks are installed. When permanent tanks are installed, the procedure will be revised accordingly as pert of the DCP proceas. Additionally, a generic Instrument Calibration Instruction will be written to provide specifically for transmitter calibration when there are dissimilar fluid sensing lines. CA-86-106-04 To prepare and approve TCH for Surveillance Instructions, Technical Section. Due date February 26, 1986. CA-86-106-05 To prepare and approve ICI for transmitter cellbration, Instrument & Control Section. Due dote April 1, 1986. Instrument Calibration F r e_qu ency - The Technical Specifications require that the suppression pool level instruments be calibrated on a frequency of once per le months (ref. 4.3.7.4 Table 4.3.7.4-1 & 4.3.7.5 Table 4.3.7.5-1). Ao e conservative measure, the frequency for Surveillance Instructione G4Q-T1,3,05 A thru F will be accelerated to once per 9prdays until such time as three consecutive as-found data measuremente are within the currently established leave-as-is zone. At that time the Lead Engineer E/I&C may relax the frequency concurrent with technical specifications. l l l i
L 216, PA9 3 610 Fsgo 6 of 8 CA-86-106-06 To revise the frequency of SVI G43-T1305 A thru F to once per 9f days, Technical Section. Due date March 1, 1986. 7 vu 2 2i r6 ATTACHMENTS
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Plant Manager 04te 1 3C/f(, 84 ENGINEERING FESP0r6E V O accterco o $1ca tea 2m r'er=> =t caaretaator REXCTED - PIASON Lead Engineer Date l Senior Project Engineer Date
- 15. DOGM.NT(s) TO DEVELOP EDCR . j
DRAFT ATTACHMENT V PRELIMINARY REPORT ON KINEMETRICS DATA 39
TELECOPY REQUEST KINEMETRICS, INC, - PASADENA, CA TELECOPY TELEPHONE (818) 795-0858 TELECOPY NO: 66,9 DATE: _F+o (I4SG _ TELECOPY TELEPHONE TO WHICH THIS MESSAGE SHOULD BE SENT: b 312_) 79 O 6% i TO: _ N R C._- C him e o _ . . Ann ; Jim W u% c e.i!- FROM: be b 164 6 , cur 61r Service Deof-DOCUMENT: kneh . DaA ham ' EadNp'4 , N dd>1 3 I F36 6 I PEJYV
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t . DRAFT 1 f . ATTACHMENT VI l i NRR TRIP REPORT FR0ll T. Y. Chang Leon Reiter i e i n J J' i j I i l 40 i
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UNITED STATES NUCLEAR REGULATORY COMMISSION
; y WASHINGTON, D. C. 20555 % 5 %,,,,,# FEB 2 5 WE MEMORANDUM FOR: Robert J. Bosnak, Chief Engineering Issues Branch DSRO, NRR Frank J. Congel, Chief Reliability and Risk Assessment Branch DSR0, NRR FROM: T. Y. Chang, Task Manager Leon Reiter, Sr. Reliability and Risk Analyst DSRO, NRR
SUBJECT:
REPORT OF QUICK RESPONSE TRIP TO OBSERVE EFFECTS OF THE NORTHERN OHIO EARTHQUAKE ON THE PERRY NUCLEAR POWER PLANT
Background
An earthquake occurred at 11:48 a.m. on January 31, 1986 near the Perry Nuclear Power Plant in Northern Ohio. Preliminary information from USGS indicated that the earthquake had a body-wave magnitude (m h
) of 5.0, and the epicenter is located approximately 12 miles south of the Perry site.
The Perry Plant is a General Electric BWR-6 with a Mark III containment. It is not yet licensed. Nuclear fuel is on site but has not been loaded into the reactor core. The owner of the plant is Cleveland Electric and Illuminating Company (CEI). The utility was performing pre-operational tests and according to CEI, most of the safety related systems were running when the earthquake occurred. Although Perry is not an operating plant and is not required to do so, CEI immediately activated the emergency plan in order to assess facility damage and personnel injuries. No injuries occurred. In addition, NRC and other relevant federal and local agencies were notified of this event. The plant was switched to the recovery mode in the afternoon of January 31, 1986. The recovery organization is shown in enclosure 1. A detailed walkdown inspection involving about 40, and at times 65, people was conducted for the whole plant, which covered buildings, equipment, instrumentation, piping systems, etc. Only minor damage was found (see preliminary findings below). The inspection was completed at 2:00 a.m. on February 1, 1986. An Augmented Inspection Team (AIT) from NRC Region III and staff from NRR were sent to the Perry site on the morning of February 1. The team from NRR consisted of John Stefano (Perry Project Manager), Leon Reiter and T. Y. Chang (both from DSRO). They left Perry on the evening of February 2. The Region III group was led by Carl Paperiello (Director of the Region III Reactor Safety Division). The NRC team held several meetings with the CEI engineering and licensing staff, the Architect / Engineer (Gilbert Associates), CEI consultants (Weston Geophysical) and suppliers of the seismic monitoring instrumentation (Kinemetrics, and Engdahl Enterprises). A list of meeting m A 13 , , , MAR a 1986 g n , y y) Jt ) J4' g+- ,
O attendees is attached as enclosure 2. The NRC team members reviewed 4 preliminary seismic recordings and conducted a walk-through inspection of
; buildings and equipment.
PRELIMINARY FINDINGS
- 1. Seismic Records:
The plant had nine sets of seismic monitoring instrumentation on the site when the earthquake occurred. All but one were operating and recorded the earthquake. They are of three different types: triaxial time-history accelerographs (made by Kinemetrics), triaxial peak response spectra recorders, and triaxial peak accelerographs (both made by Engdahl Enterprises). A list of these instruments and their locations is attached as enclosure 3. There were some difficulties in interpreting data obtained from the Engdahl peak response recorder. Each of these instruments has 12 tuned reeds, each tipped with a diamond stylus which makes scratches on a recording plate. Some of these instruments are wired to annunciators in the control room. Each annunciator has one set of 12 amber lights and one set of 12 red lights, with each set of lights marked with the corresponding 12 tuned reed frequencies. These amber lights and red lights are pre-set to be activated at FSAR values of 2/3 OBE spectral accelerations and full OBE spectral 1 accelerations respectively for the corresponding tuned reeds. The recording plates have been in these instruments for about a year, and spurious annunications have occurred previously when there were no earthquakes. Paul Engdahl, President of Engdahl Enterprises, was present at Perry during the visit and helped interpret the data obtained from the scratched plates. Enclosure 4 shows the preliminary data from the Engdahl instruments in the reactor building and the auxiliary building as plotted on the FSAR spectra. The 2% damping spectra curves should be used for comparison since the reeds ' have a built-in 2% damping. There were some concerns about the way the Kinemetrics instruments were installed at the reactor base mat level. The instruments are not located on the mat, rather they are positioned on brackets bolted on the containment wall 9" above the mat. A " ring" test done by Kinemetrics proved that the brackets are rigid enough to render the data valid. Partial preliminary time history data obtained from the Kinemetrics instruments located at the reactor building foundation (575') and on the containment vessel annulus (682') and the associated response spectra generated by Kinemetrics are shown in enclosure 5. Note that the grade level j of the plant is at 620'. Enclosures 4 and 5 indicate that there is a strong possibility that both OBE and SSE design response spectra may have been exceeded in the frequency range of approximately 16 Hz and above. The design basis for SSE is a Regulatory Guide 1.60 design response spectra anchored at 0.159 , with the OBE spectra
anchored at 0.075g. Preliminary data indicated a Zero Period Acceleration (ZPA) value of 0.18g at the reactor base mat. These recorded data are being further studied.by the NRC and CEI consultants and instrument suppliers.
- 2. Results of Preliminary Plant Inspection Damage to the Perry Plant was assessed by CEI and found to be limited to hair line cracks in rad waste and auxiliary building walls and a pipe flange leak in a hot water heater in the rad waste building. In most cases CEI was not able to determine whether or not these cracks were there before the earthquake. The hot water heater supplies clean non-radioactive steam to an evaporator, and the leakage rate was estimated to be about 20 drops per minute. In addition, a rotating disc type protective relay for the turbine generators tripped, which in turn caused an auxiliary boiler to trip. Since the turbine generators were not in operation at the time of the earthquake, i there was no voltage across the relay and, therefore, the rotating disc was hanging loose there. It tripped due to the earthquake motion which would be expected. An instrument air compressor tripped; however, one of the three other instrument / service air compressors in the plant automatically started.
There was also an indication that suppression pool water level indicators might have malfunctioned during and after the earthquake. CEI is still looking into this matter. Seepage of ground water through the junction of wall and floor and through cracks in the wall was also observed in the rad waste building after the earthquake. The seepage was not considered severe. The NRC staff participated in a walk-down of the plant to inspect for damage and anomalies. The NRC staff walk-down observations are recorded in enclosure 6. CONCLUSIONS
- 1. No damage of any significance was observed at the Perry plant by the NRC staff during the trip.
- 2. Based on the preliminary records of seismic monitoring instruments at the plant, the staff concluded that there is a strong possibility that the OBE and SSE design response spectra (FSAR values) may have been exceeded in the frequency range above approximately 16 Hz. It has been pointed out that the high frequency range of Regulatory Guide 1.60 spectra is not as conservative as the lower frequency range. However, the records obtained at Perry are still puzzling since the seismic instrumentation on the containment wall at 682 (about 107' above base mat) still shows exceedance of FSAR floor spectra in the frequency range higher than approximately 16 Hz. One would normally expect that the responses in the frequency ranges higher than the building fundamental frequency would be filtered out by the building.
Further analyses and study of the seismic data by CEI staff engineers and consultants may yield new information on this matter. It should be kept in mind that response spectra do not present all the information
I about an earthquake. The energy content as a function of frequency is better represented by the Power Spectral Density (PSD), which is an important indicator of damage potential. Another damage potential indicator is the duration of the earthquake. On both accounts, the effects of the earthquake on the Perry plant were observed to be minimal. Normally responses in the high frequency range do not have
, much energy content. Furthermore, the peak time history reading at the ! base mat lasted for only about one half second.
NRC AND SQUG FOLLOW-UP ACTIONS
- 1. The location, aftershocks and travel mechanism of the earthquake sequence will have to be examined and compared with previous seismicity so as to determine if there is any impact upon the adequacy of assumptions made in the Safety Evaluation Report. .
- 2. DSR0/NRR had a meeting with representatives of the Division of BWR Licensing on 2/3/86 to brief them of the findings at Perry. It was decided that since the investigation of the effects of this earthquake on Perry is plant-specific, the BWR Licensing Divsion should take the lead. DSR0 will perform an oversight function and provide technical j assistance if needed. R. Hermann and L. Reiter were appointed as team leaders in the structural / mechanical and geoscience areas respectively.
1 A permanent review team is being formed to review the effects of this earthquake on the structural, equipment and geoscience aspects of the Perry plant.
- 3. A BWR site investigation team was sent to Perry on 2/6/86. This team consists of A. Lee (Engineering Branch /BWR Licensing Division /NRR) and j
J. Singh (INEL contracter), and will perform an independent review of safety related equipment. ' 4 Seismic Qualification Utility Group (SQUG) will send a team to Perry on '
- 2/10/86 to collect seismic experience data. This information could be useful for the on-going Unresolved Safety Issue (USI) A-46, " Seismic Qualification cf Equipment in Operating Plants."
4
- 5. As the analysis and review of the earthquake, and recorded data proceed, i additional recommendations to specific generic issues may be forthcoming. among these presently being considered include increased
! use of parameters other than peak accelerations and response spectra to better reflect the damage potential of earthquake ground motion and a clearer definition of OBE and/or SSE exceedance and their imolications.
b ~ 75ll;F / T. Y. Chang Leon Reiter
- Task Manager Sr. Reliability and Risk Analyst cc: See Page 5.
)
1 l l 1 cc: H. Denton S. Brocoum D. Eisenhut L. Heller R. Bernero N. Chokshi W. Butler L. Shao, RES G. Lainas G. Bagchi J. Stefano G. Giese Koch S. Stern P. T. Kuo T. Speis R. Rothman B. Sheron A. Lee N. Anderson P. Sobel Lic. Div. Directors R. Hermann Lic. Div. A/Ds C. P. Tan G. riotto, RES J Richardson, RES C. Paperiello, Reg. III
Osciosume / 9 RECOVERY ORGANIZATION IEC0VERY : IEWINER :
- N. R. EDELMAN
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.si M. W. SMYREN N. C(HEN L. O. BECK R. L. FAARELL I
- 6. R. LEIDICH I
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enc &osuy p_ MEETING ATTENDANCE February 1, 1986 - TEC NAME COMPANY POSITION N. J. Lehman CEI - Staff Analyst J. J . Waldron CEI Manager, Technical Dept. K. A. Connaughton NRC Resident Inspector J. W. Muffett NRC, Region III Plant System Section Section Chief J. J. Harrison NRC, Region III Chief, Eng,. Branch, DRS C. J. Paperiello (Tea , leader) NRC, Region III Director, Div. Reactor Safet C. R. Angstadt CEI L ead Structural Engineer E. M. Buzzelli CEI Sr. Licensing Engineer K. R. Pech CEI Gen. Sup. Eng. , Nuc1 Constr. M. N. Gmyrek CEI Sr. Operations Coordinator R . A . S tratman CEI Gen. Supervisor, Operations H. L. Williams CEI Executive Vice President A. Kaplan CEI V.P. Nuclear Operations Div. M. D. Lyster CEI Manager, PPOD F. R. Stead CEI Manager, NED B. A. Stiles CEI Community Relations Asst. John J. Stefano NRC/NRR Perry Project Manager Leon Reiter NRC/NRR Sr. Reliability & Pipe Analyst T . Y . Chang NRC/NRR Task Manager W. E. Coleman CEI GSE, Community Relations G. R. Leidich CEI GSE, Outage Management D. J. Takacs CEI Gen. Sup., Maintenance J. A. Grobe NRC Sr. Resident Inspector M. J. Hayner CEI Licensing Engineer
-2 Attendance - February 1, 1986 - TEC NAME COMPANY POSITION M. H. Minns CEI Licensing Engineer R. G. Schuerger CEI Chairman, NSRC E. N. Levine Weston Geophysical Seismologist, Consul-tant to CEI Gabriel Leblanc Weston Geophysical Seismologist, Consul-tant to CEI Steve Kensicki CEI Technical Superintendent Bill Kanda CEI GSE, Technical Dan Hulbert CEI Emergency Planning Sup.
George Siegel Kinnenetrics Field Operations Sup. Vince Concel CEI PPTD System Engr. Lead Paul Engdahl Engdahl Enterprises President Roger Alley Gilbert, Inc. Project Structural Eng. Frank Kocsis CEI Independent Safety Eng. Cyril Shuster CEI Manager, CA Ronald L. Farrell CEI Manager, PPSD Murray R. Edelman CEI V.P., Nuclear Group 3 ; i I l l i
Enctosup6- 3 TABLE 3.3.7.2-1 g} SEISMIC MONITORING INSTRUMENTATION .
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