ML20154M847

Summary of 880414 Meeting W/Util & BNL in Rockville,Md Re Monitoring Program for Reactor Coolant Pump Shafts.List of Attendees & Related Documents Encl

ML20154M847
Person / Time
Site:	Palo Verde
Issue date:	05/17/1988
From:	Licitra E Office of Nuclear Reactor Regulation
To:	Office of Nuclear Reactor Regulation
References
NUDOCS 8806020097
Download: ML20154M847 (40)

Text

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UMTED STATES

.[g -f ,,. '. ij NUCLEAR REGULATORY COMMISSION WASHINGTON D. C. 20555 May 17, 1988

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Cocket Nos.: 50-528/529/530 Licensee: Arizona Public Service Company Facility: Palo Verde Units 1, 2 and 3

SUMMARY

OF MEETING TO DISCUSS MONITORING PROGRAM FOR REACTOR COOLANT PUMP SHAFTS A meeting was held on April 14, 1988 in Rockville, Maryland between representatives of the licensee and the staff. The purpose of the meeting was to: (1) discuss the RCP vibration monitoring program; (2) provide information regarding the current inspection of the Palo Verde Unit 2 RCP shafts; and (3) discuss proposed changes to the RCP vibration monitoring program.

Enclosure 1 provides the list of attendees and the meeting is sumarized as follows.

SUMMARY

The licensee briefly discussed the development of the vibration monitoring program for the RCP shafts. The licensee also provided vibration monitoring data for Palo Verde. Units 1 and 2, which are included as Enclosure 2. To date none of the Palo Verde data have correlated with positive indications of the presence of any shaft cracks. This result is expected since all of the cracks discovered on Palo Verde. Units 1 and 2 have been much smaller in depth than the size that can be picked up by vibration monitoring (i.e., all were much smaller than 40% of the shaft diameter).

The licensee also provided the status of the shaft inspections currently in progress for Palo Verde. Unit 2. Cracks have been found on 3 of the 4 shafts.

Pump 1B has no indications of a crack. Both pumps 1A and 2B have two cracks with depths of 1.6 m or less. Pump 2A has one crack which is estimated to be about 12.7 m deep. This latter depth is equivalent to the largest depth reported on the Palo Verde, Unit 1 shafts.

All four shafts in Unit 2 will be replaced with new modified shafts. The modified shafts will be the same as those installed in Unit 1, except that the l

Unit 2 shafts will also have a center hole drilled to facilitate ultrasonic j

inspections during shutdowns.

1 l The licensee also discussed proposed changes to the vibration monitoring

! program which are included as Enclosure 3. The staff expressed the following l concerns with the proposed changes.

l l

(1) The changes would eliminate the requirements for orbital monitoring which is considered to be an important element fsr earlier detection of large l

l cracks (Items a and d of Enclosure 3).

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8806020097 080517 PDR ADOCK 05000520 P pop

(2) The changes would allow continued plant operation with pump shaft vibrations up to 15 mils which are significantly greater = than baseline values for the pumps (Item e).

(3) The changes would allow continued plant operation by monitoring with other undefined "equivalent" external equipment in lieu of the established monitoring equipment (Item a).

(4) The changes would allow the plant to stay in hot standby indefinitely even with a large shaft vibration suspected to be due to a cracked shaft (Items a and f).

The licensee stated that it appreciated the staff's coninents and would take them into account in determining to what extent it would formally propose changes, original signed by E. A. Licitra E. A. Licitra, Senior Project Manager Project Directorate V Division of Reactor Projects - III, IV, Y and Special Projects

Enclosures:

As stated cc: See,next page.

DISTRIBUTION '

?~DocketFile ELicitra NRC & LPDR's' MDavis PDV Reading OGC EJordan JPartlow ACRS (10) NRC Participants OFC :DR5P/ V/P -

DR5 / :PDV  :  :  :  :  : :

'NAME :EAli :cw:GW ton  :  :  :  :  :

DATE :05//7/88 :05/l1/88  :  :  :  :  :

0FFICIAL RECORD COPY a

O ,

3 (2) The changes would allow continued plant operation with pum) shaft vibrations up to 15 mils which are significantly greater t1an baseline values for the pumps (Item e).

(3) The changes would allow continued plant operation by monitoring with other undefined "equivalent" external equipment in lieu of the established monitoring equipment (Item a).

(4) The changed would allow the plant to stay in hot standby indefinitely even with a large shaft vibration suspected to be due to a cracked shaft (Items a and f).

The licensee stated that it appreciated the staff's coments and would take them into account in determining to what extent it would formally propose changes.

E. A. Licitra, en Project Manager Project Directorate V Division of Reactor Projects - III, IV, V and Special Projects

Enclosures:

As stated cc: See next page.

---

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ENCLOSURE 1 PALO VERDE MEETING ATTENDEES ON VIBRATION MONITORING PROGRAM Name Affiliation Manny Licitra NRC/NRR/POV Mike Davis NRC/NRR/POV C. Y. Cheng NRC/NRR/EMTB Joseph R. Provasoli APS - Licensing <

Carter' Rogers APS - Licensing Kerry Johnson APS - Unit 2 Lead STA Howard Maxwell APS - Vibration Engineer L. B. Marsh NRC/NRR/EMEB P. T. Kuo NRC/NRR/ EMES Kamal Bandyopadhyay BNL Paul Bezier BNL i

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ANALYSIS OF UNIT 1 AND 2 RCP SHAFT CRACK SIZE VS VIBRATION Page 1 i i := 0 . 7 load U12 CRACK C := A := READPRN(U12 CRACK) 1 RCP i (0) (1) (2) (3) 0 1-1A 15.7 Oxi t= A Oxf := A Oyi := A Oyf := A

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_&_ X2i := A X2f := A Y21 := A Y2f := A

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-initial final initial final X11 X1f Yli Y1f ,

i i i i 1.602 1.237 1.988 1.408 2.287_ _2.397 2.541 2.209 1.966 1.999 2.176 1.668 1.027, 0.718_ 1.165 0.423 1.95 1.823 1.69 1.679 3.249 2.143 3.027 1.745 1.248 0.823 t. 37 0.983 2.563 1.977 2.419 1.701 2/rev-X 2/rev-Y initial final initial final X21 X2f Y21 Y2f i i i i 0.362 0.436 0.251 1 0.344 0.381 0.231 0.45 0.341 0.301 0.464 0.425 0.319 0.181 0.155 0.26 0.098 0.524 0.655 0.527 0.746 '

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0. 4 31 F 0.282 0.338 0.224 I

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. 1 ANALYSIS OF UNIT 1 AND 2 RCP SHAFT CRACK SIZE VS VIBRATION Page 2 dOx  := 0xi -

Oxf dOy  := Oyi - Oyf corr (C,dOx) = -0.167 i i i i i i corr (C,dOy) = 0.257 l

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. i

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2 2 '

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UNIT 1 AND 2 RCP CRACK DATA - CORRELATIONS FROM MATHCAD ANALYSIS UNIT-1 UNIT 2 BOTH 1&2 dOx -0.449 0.441 -0.167 e4 dOy 0.152 0.314 0.257 a0x -0.122 -0.945 -0.589 a0y 0.153 -0.931 -0.335 dX1 -0.13 -0.277 -0.382 dY1 0.274 -0.295 -0.103

- aX1 -0.105 -0.889 -0.459 aY1 -0.082 -0.837 -0.336 dX2 0.171 -0.30? 0.083 dYa -0.346 -0.267 -0.121 aX2 0.578 -0.104 0.023 aYa 0.067 0.08 -0.131 0xi 0.504 -0.88 -0.434 -

Oyi 0.481 -0.815 -0.197 Oxf -0.373 -0.914 -0.63 Oyf -0.058 -0.928 -0.403 X11 -0.089 -0.802 -0.496

- Yli -0.053 -0.692. -0.331 X1f -0.116 -0.962 -0.377 Y1f -0.104 -0.978 -0.307 X2i -0.069 -0.109 -0.314 Y2i -0.111 0.385 -0.078 X2f 0.842 -0.093 0.236 Y2f 0.209 -0.07 -0.148

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ENCLOSURS 3 INSERT APS shall implement au cugmented monitoring program for each of the four reactor coolant pumps that includes the following elements:

a.

i- Each pump will be continuously monitored with at least one of the 3

two channels with associated shaft proximity vibration transducer and a control room alarm. 1 required for the failure of a single channel.No additional equipment is or mon Should a channel fail, a channel check shall be performed within one hour, to verify the failure of the channel. Within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> of the channel failure, excluding equipment inside containment, will be completed to steps correct the failed channel. If a single channel inside containment has failed but spectrum analysis is 2

still obtainable on the other channel, the failed channel will be repaired / replaced at the next outage of sufficient duration.

When the ability to monitor both channels is lost, monitoring will be restored within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> by repair or monitoring with equivalent i external equipment. If monitoring capability is not restored within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, within one hour initiate action to place in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. Thethe unit l affected reactor coolant pump (s) (RCP) will be secured (unless more than two

, pumps are affected) except for testing until corrective action is completed which would allow monitoring on at least one channel.

The Nuclear Regulatory Commission shall be notified, via the Emergency Notification System within four hours, of the time capability to monitor eil channels is lost and again within four hours of commencement of a plant shutdown, should one be required.

b. Every four hours, vibration data on each pump will be monitored and 1

recorded,

c. On a daily basis, an evaluation of the pump vibration data per b. obtained '

individual, above will be performed by an appropriately qualified d.

When vibration of any reactor coolant pump reaches a level of 8 mils or greater the Nuclear Regulatory Commission shall be notified

) within four hours via the Emergency Notification System.

In addition, when the vibration on any pump exceeds 8 mils or greater due to a shaft crack or unknown cause, within four hours the affected pump shall have its orbit (if available) and continuously monitored and evaluated by an appropriately spectrums qualified individual. If the vibration is confirmed to be caused by pump conditions other than a crack or instrumentation malfunctions, appropriate actions commensurate with the cause will be taken per approved plant abnormal operating procedures. Monitoring shall continue on a frequency determined by an individual appropriately qualified in vibrationa*. analysis until the vibration decreases below 8 mils.

e. When vibration of any reactor coolant pump reaches a level of 10 mils or greater due to a cracked shaft, or other unkncvn cause, or 15 mils for any combination of causes, within one hour action shall be initiated to place the unit in at least HOT STANDBY vithin the following six hours. In addition, the affected pump will be secured following entry into Mode 3 (HOT STANDBY) and it vill remain secured, except for the purpose of testing, until corrective action has been completed.

f.

On a daily basis, a spectrum analysis shall be performed on the RCP shaf t vibration and shall be evaluated for trends by using an individual qualified in that technique. The evaluation shall consist of comparing the running speed and twice running speed components to limits computed from the baseline vibration. The current method used is to compute the lovest of:

baseline value; ii) the mean plus three standard1) 1.6 times the deviations of the baseline value; iii) 2 mils for the twice speed component, or iv) 6 mils for the running speed component. In the event new limits or methods are chosen, prior to their implementation they will be evaluated to assure that quality of results vill be equal to or better than those for the current method. The Nuclear Regulatory Commission shall be notified 10 days prior to the implementation of a new spectral analysis method. When the amplitude exceeds any limit, further analysis shall be performed. This analysis shall consist of inspecting the 2mplitude versus time plots for a steadily increasing trend, and review of other plant data which might explain the change. If a trend is confirmed to indicate the presence of a shaft crack, or unknown cause, the trend will be extrapolated to predict the time at which vibration is expected to reach 10 mils. The unit will be brought to HOT STANDBY and the affected pump will be secured per e above at least one week prior to the extrapolated time unless the projected time is within a week in which case the unit vill be shutdown per e. above. The affected reactor coolant pu=p vill remain secured, except for the purpose of testing, until corrective action has been completed.

Attachment A. DESCRIPTION OF THE PROPOSED AMENDMENT ANPP will implement an augmented vibration monitoring program for each of the four elements.

following reactor coolant pumps for all three units that includes the a) Each pump will be continuously monitored with at least one of the two shaft proximity vibration transducers each with a control room alarm.

This section is new and has been added for clarification which allows the unit to re=ain at power while the operability of the affected channel is reviewed. The characteristics of an instru=ent failure are easily distinguishable from those of a cracked shaft by an appropriately qualified individual, e.g.,

rapid rise time pulses (spiking), 60 Hz frequencies and/or 120 variations not confirmed by other sensors.

Hz frequencies. Sap voltage If a channel oecomes inoperable, a channel check shall be performed within one hour, to verify the failure of the channel. Within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> of the channel failure, excluding equipment inside containment, action will be completed to correct the failed channel. If a single channel has failed inside containment but spectrum monitoring is still possible on the other channel, the failed channel will be repaired / replaced at the next outage of suffient duration. In the unlikely event that both channels become inoperable, corrective action shall be implemented to restore monitoring capability within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

During the period vibration monitoring is unavailable, the loose parts vibration monitoring system audio channels and reactor coolant pump seal stage pressures will be monitored every four hours. The NRC shall be notified within four hours if the capability to monitor both channels is lost. I e

b) Monitoring and recording of reactor coolant puep vibration data every four hours.

This section has not been changed.

c) Evaluation of reactor coolant pump vibration data on a daily basis by an appropriately qualified individual.

A change to this section deleted the term "engineering" as it relates to an appropriately qualified individual. Some of the individuals who perform an evaluation of the data are technicians which are. appropriately qualified. This is in accordance with dicussions in our November 22L 1987 meeting and is for clarification purposes.

d) Reporting requirements when the vibration level on any reactor coolant pump is equal to or exceeds 8 mils.

1

. l By adding the term "if available," clarification is made. 2If one ,

channel is inoperable, monitoring of the orbit is not possible.

4 The orbital primary use analysis is not required to detect a cracked shaft, its is to confirm conditions other than a cracked shaft to allow continued operation. Also, a statement is added on actions  :

to be taken if other conditions exist causing vibration, e)

Reactor shutdown requirements when the vibration level on any reactor coolant pump reaches 10 mils or greater due to a cracked

shaft or other unknown cause or 15 mils for any combination of l causes. '

Combustion Engineering guidelines for shutdown due to -excessive vibration on the Reactor Coolant Pumps is 15 mils. Industry data 1

has shown that vibration readings of 20 mils or higher were achieved prior to shaft failures.

If the unit has to be shutdown, entry into Mode 3 (HOT STANDBY)  !

should be sufficient. The reactor is stable and there is no chance of being in an unanalyzed condition. If further testing is needed ,

it can be accomplished, in Mode 5 it cannot.

Entry into lower modes (4 or 5) unless required to affect repairs or maintain compliance with LCO's, is contrary to plant and federal

! policies which require maintenance of personnel radiation exposure '

ALARA pr.d minimizing generation of radwaste.

In addition, the plant would be put through an unnecessary cooldown/

heatup cycle. Finally, further meaningful testing / troubleshooting l cannot be accomplishew with the plant in Mode 5.

i f) Spectrum analysis of the vibration data on a daily basis with 4

! associated reactor shutdown requirements based on the results of the analysis.

• 1 This section has been reworded basically for clarification. Part i of this classification is in accordance with NRC's request at the 1

November Z1, 1987 meeting. Also, the footnote is now incorporated l into this section which allows the NRC staff ten days instead of I five to review new limits or methods of monitoring prior to their implementation. As in section e, above, the unit will be shutdown  !

I and remain in Mode 3 (HOT STANDBY) for the same reasons.

L B. PURPOSE OF THE LICENSE CONDITION The augmented RCP vibration monitoring program has been previously {

incorporated into the Unit 2 and 3 Operating License (s). The NRC staff's

! reasons for imposing the license conditions are summarized in a letter i e

from G. W. Knighton, of the NRC Staff, to E. E. Van Brunt, Jr., of ANPP, dated October 25, 1987. In this letter the NRC Staff states that,

! "...the European data, as well as the information obtained from Palo g i

i Verde Unit 1, indicate an increased probability of a reactor coolant pump shaft failure. 'as well as a potential failure mode which could involve t the failure of more than one reactor coolant pump. The failure of more i l 2 1

than one license pu=p is an unanalyzed condition and thus beyond the current design basis.... This (vibration monitoring) program, which is based upon documented European experience, should provide evidence of impending pu=p shaft failure approximately two days prior to failure, which is sufficient time to place the unit in safe shutdown condition in an orderly manner."

C.

NEED FOR THE OPERATING LICENSE AMENDMENT The need for the rrquested Operating License amendment is the change vill citigate unnecessary plant shutdevns and clarify elements of the augmented vibrrtion monitoring program.

To more fully explain unneesssary plant shutdowns, on March 6, 1988 Unit 1

was in Mode 2 ascending to Mode 1 after its first refueling outage. At 1950 hours0.0226 days <br />0.542 hours <br />0.00322 weeks <br />7.41975e-4 months <br /> an RCP shaft displacement alarm was received on RCP IB.

Readings taken on the loose parts vibration monitoring system (LPVMS) cabinet appeared channel indicated erratic (x) channel to be stable at 2-3 mils, whereas (Y) with general readings at 3 5 mils with spiking up to approximately 12 mils, strongly indicating instrument failure. It was at this time Unit 1 Management, Instrument and Controls Engineering (I&C) and the vibration group was notified. After consultation. Unit 1 operators initiateo action to place the Unit in Mode 3 which was accomplished at 0147 on March 7, 1988. RCP IB was then secured at 0226.

Pursuant to the augmented vibration monitoring program the NRC vas notified within the prescribed time via the Emergency Notification System.

After securing the pump, investigation by I&C found the output lead from '

the amplifier module for the RCP IB (Y) channel to be loose. It eas tightened and all other accessible connections were checked. After further discussions with Unit 1 management and the Resident Inspector, concurrence was given to restart RCP 1B to retest the (Y) channel vibration circuit. The pump was restarted at 0605 and the (Y) channel vibration readings all appeared normal.

D. BASIS FOR NO SIGNIFICANT RAZARDS CONSIDERATION

1. The commission has provided standards for determining whether a significant hazards consideration exists as stated in 10CFR 50'. 92.

A proposed amendment to an Operating License for a facility involves no significant hazards consideration if operation of the

' facility in accordance with a proposed amendment would not: (1) involve a significant increase in the probability or consequences of an accident previously evaluated; or (2) create the possibility of a new or different kind of accident from any accident previously evaluated; or (3) involve a significant reduction in a margin of safety. A discussion of these standards as they relate to the amend =ent request follows:

i 3-

4 Standard 1 -

Involve a significant increase in the probability or the consequences of an accident previously evaluated.

Basis The proposed Operating License amendment does not involve a significant increase in the probability or consequences of an accident previously evaluated. This amendment vill impose an additional restriction on Unit 1 operations by adding a license condition requiring RCP vibration monitoring. The additional RCP vibration monitoring vill not increase the probability of occurrence of any of the previously analyzed accidents. This amendment would also clear up ambiguity in the program.

The additional RCP vibration monitoring program imposed by this amendment and the clarification efforded will not affect the consequences of the previously analyzed RCP sheared shaft event.

Standard 2 -

Create the possibility of a new or different kind of accident from any accident previously evaluated.

Basis - This proposed Operating License amendment does not create the possibility of a new or different kind of accident from any accii .it previously analyzed. The design and operation of FVNCS Units 1, 2 and 3 is not changed by this proposed amendment. The amendment involves the addition of a augmented vibration monitoring program for Unit 1 and a change to Units 2 and 3 programs which clarifies the existing criteria.

Standard 3 Involve a significant reduction in a margin of safety.

• Basis -- This proposed Operating License amendment does not involve a significant reduction in a margin of safety. The proposed change involves the imposition of additional -

restrictions on Unit 1 operations and additional clarification for Units 2 and 3. The augmented RCP vibration monitcring program is designed to provide advance warning of RCP shaft failure. This early warning vill allow the reattor to be safely shutdown prior to the occurrence of a RCP sheared shaft event.

2. The Commission has provided guidance conce rning the de te rmination of whether a significant hazar62 consideration exists by providing certain examples (51TR7751) of amendments that are considered least likely to involve a significant hazards consideration. This proposed Operating License amendment matches example (s) (i) and (ii) of 51FR7751 in that, (i) a purely administrative change in that certain statements are clarified and (ii) a change that constitutes an additional limitation, restriction or control not presently included in the Operating License.

4

~

E. SAFETY EVALUATION FOR THE PROPOSED AMENDMENT This proposed Operating License amendment will not increase the probability or the consequences of previously evaluated accidents nor will it create the possibility of a new or different kind of accident.

The proposed amendment will impose an additional restriction on Unit 1 operations by adding a license condition requiring RCP vibration monitoring. The augmented RCP vibration monitoring program has already been incorporated into the Unit 2 License by confirmatory Order an into the Unit 3 Operating License. This amendment will also provide clarification to ambiguous terminology in the program. The RCP vibration monitoring program is being added to provide an early warning of impending RCP shaft failure due to the shaf t cracking phenomenon found at Unit 1 as well as at several European facilities. The accident analysis of primary concern in this case is the RCP sheared shaft event. The vibration monitoring program imposed on the units will decrease the probability of experiencing a sheared shaft event. Additionally, this proposed amendment will not a f t'ec t the operation of the units.

Therefore, the change will not increase the consequences of previously analyzed accidents nor will it create the potential for a new or different kind of accident.

This proposed Operating License amendment will not reduce the margin of safety as defined in the basis for any Technical Specification. This change adds a license condition to the Unit 1 Operating License and clarifies the Unit 2 and 3 Operating License condition. There are no existing Technical Specifications impacted by the addition of the RCP vibration monitoring program.

F. ENVIRONMENTAL IMPACT CONSIDERATION DETERMINATION The proposed change request does not involve an unreviewed environmental question because operation of PVNGS Units 1, 2 and 3 in accordance with this change would not:

1. Result in a significant increase in any adverse environmental impact previously evaluated in the Final Environmental Statement (FES) as modified by the staff's testimony to the Atomic Safety and Licensing Board (ASLB), Supplements to the FES, Environmental Impact Appraisals or in any decisions of the ASLB; or

2. Result in a significant change in effluents or power levels; or

3. Result in matters not previously reviewed in the liransing basis for PVNCS which may have a significant environmental impact.

G. MARKEDd)P OPERATING LICENSE CHANGE PAGES See revised Attachment 1 of the Unit 1, 2 and 3 Operating License (s);

NPF 41, NPF-5), and NPF 74 5-

.s

. CONTROLLED BY USER iun'e 1 ,

19as ATTACHMENT 1 -

h PALO VERDE NUCLEAR GENERATING , Ut!!T 1 STATI OPERATING LICENSE NPF-41 This attachment identifies items which must be c satisfaction

g. . . . m y e e ,. . in # accordance withe ow.the schedule 1,

Prior to entering Mode 1 for the first time, APS shall

a. ~;

Have the chan completed a review of the surveidance pro the oper;ge bility ofof themode, required and determined systems that the with respect to proced acceptance criteria defined in the Technical

~ all Specificati

b. ons.

Have dispatched written notification egional to the NRC R Administrator, has been completed Region for Mode 1.V, that the action defined i n (a), above, 2-Ad T.nsa ek m - ,

g h h%

s w . m n b w ) , a. ~f k .g\ahowc.vA.M o ow mem\en mm Abu urs aq g u 4

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CONTROLLED BY USER ATTACHMENT 1 PALO VERDE NUCLEAR ,GENERATING UNIT 2 STATION

- OPERATING LICENSE NPF-51 i i

This attachment satisfaction in accordanceidentifies withitemsthe schedule which must bed bcomplete identifi

1. e elow.

' Prior to entering Mode 1 for the first time

, APS shall a.

meets the provisions of NUREG-0737 (II.B.3)H mpling System which

b. .

~

'to the change of mode, and ocedures determined applicable that thH demonstrate the operability of the required e procedures c.

to all acceptance criteria defined in the Tech isystems with respe Have dispatched written notification to the NRC Rn cal Speci Region V has been, thatcompleted the action defined for Mode in 1 entry. (a) and (b) above,egional Adm 2.

(. APS shall perform compensatory measures 36152, dated Novemberwith em the schedule and com in accordance 29, 1985 and April 15 etters 34129 and

3. , 1986, respectively.

APS shall submit the following information concto t and corrmitments November 29, 1985 presented in ANPP and December 5, 1985 ccordance Letters with 34127

, dated and 34174 the schedules

a. , respectively: '

An evaluation of the effects of gas binding an ope pump assuming that the pump has a preexisting crack irating charging

- If deliver to this postulated the required condition flow will lead to anfailure the block

b. evaluation a proposed course,of action u ccee, regarding this o TA An evaluation and implementation schedule regarding the long-term solution which con,sidersfor staff approval, hardware changes that may be necessary alternative to eliminat 4

for venting hydrogen from the suction of e the the need g ng pumps.

char i APS shall implement the resolution of the desig walls in accordance

+

1986.

with the commitments provided in adequacy of mas

5. A R T.ws.a A n ANPP letter 36'301,

% h ggc,sd hAd-c, u.

M*W 7 "b " *" b m.

h \w Ahm ~~h="^r

""'  % w.c.nsa j

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DbN ROLLED 3' usa

, u.

CONTROLLED BY USER ' "Nobber25, 1987

-o ,

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ATTACHMENT 1 .

PALO VERDE NUCLEAR GENERATING STATION OPERATING LICENSE NPF-74 .

This'Aattachment satisfaction ~

in accordance identifies withitems the schedule that must be d bco identifi

1. e elow.

Prior to entering Mode 1 for the firstshall: time APS

a. ,

Have completed a review of the 's'urveillance pr to the change of mode and determined that th ocedures applic the operabiliti o^f the required systems with the procedure e respect to all b[ acceptance criteris defined in the Technical Specifi .

Have dispatched written Regional been co.7pleted for Mode 1. notification ' to th n (a), above, has

2. The post 5t power. accident sampling system shall be opera 3 "

. ! :h:" ' ph=rt r :"; :rt^d '9 t h-th ~ fcui .;;;ter ccchnt prps-th:t in;hd;; r itch cth; pref 1b ;r:- for :::P c4 in; ;knatre

a. .o Very four hours, monitor and record vibration data he four reacter coolant pumps, on ach

b. On a da data obtai basis, perform an evaluation of the engineering i invidual. a above, by using an approp ump vibration

\ ately cualified 4@-

4M c. When any one vibrat indicates a vibration monitor on th reacter coolant pumps Regulatory Commission shasei of6m be r s or greater, the Euclear Emergency Notification Syste. ,

on any pump exceeds 8 mils ce In additien, when the vibratio and spectra continuoucause, a shaft crack or within four unkncwn beurs he affec, a apprcpriately qual y monitored an s orbit ed indivicual. valuated by an

d. When any one ration ronitor on the reactor 1 indicates a sibratien lesel of 10 rais or Iant greater :uros hcur, within in' late action to piace the unit in'ithin ,

at least one the clicviro N heurs.she next six hours, ardtC','il atr lent

" SIAhCEY ui 5 ir.

COLD Shui gsocured af ter entering EDT STA .C?Y.:n accitir,r the a f'ecite ;.u f

A.

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3., .

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CONTROLLED BY USER '

i ., . '.

2~~.

{\

s e.

rea a daily basis a spectrum analysis shall be performed on th for tr r coolant pump shaft vibration data and shall be evated evaluations by using an individual qualified in that tec que. The twice running . eed (2xRPH) spectralinits

. . .- from the baseline components (1xRPM and compu)ted tall con

'" lowest of: (a)1.6 ibration. The limits shall e based on the three standard deviation.es the baseline valu , (b) the mean plus 6 mils for 1xRPM cceponent. ) 2 mils fo -

he 2xRPM component, or-(d)

.- further analysis shall be per When t

e. This amplitude exceeds any limit, -

of an inspection of the amplitu analysis shall consist increasing trend, and a revi of othrsus time plots for a steadily explain the change in am tude. plant data which might is not caused by plan If it

' .;the trend shall be r pump conditions unconfirmed that the trend predict the tim trapolated manually and/orlated to a shaft crack.

mils. If th t which the vibration is expecte computer to less, wit rojected time for reaching 10 mils is oo reach 10 HOT ST one hcur, initiate action to place the Unit week or wit the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.BY within the next sixathours "

least and at leas secured after entering HOT STANDBY.In addition the affected pump sh C The Regional Administrator, Region V may relax org rescind, in writin the cause.

good above vibratien ronitoring conditions upon a showing .anyby of the

~ li

... censees of 4

Within 90 days of the ecmmencement of the P the inspection of the Unit 2 reactor coolant pumps. ng include inspection results, an evaluation of the Unit 1 pump and Unit 2This shaft to Unit 3degradation continued operation. findings ar.d proposed actions to be taken w 5.

APS shall install modified reactor coolant pumpeshafts fi'rst during th DES-3 of the attacheents to the licensees' r.

flovem

in n , . . . "t

-b -

licensee to assure that the new r:retheds # ...w"' they are stall chosesbe 1evC'i m ;f g,e above mothed. t

,..; uvsen. the U-Mt 2..oi s t,c aavised within one wee k( r than the -

i t Ten ;rtt eta

.