ML20133K719

Forwards Supplemental Info Re 851002 Transient,Per NRC Request During 851016 Meeting.Info Includes Main Feed Pump Trip Determination,Hpi a Flow Anomaly,Cooldown of RCS, Cooldown Rate,Tech Specs & Revised Action List

ML20133K719
Person / Time
Site:	Rancho Seco
Issue date:	10/18/1985
From:	Reinaldo Rodriguez SACRAMENTO MUNICIPAL UTILITY DISTRICT
To:	Thompson H Office of Nuclear Reactor Regulation
References
RJR-85-520, TAC-59691, NUDOCS 8510220266
Download: ML20133K719 (22)

Text

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esuun SACRAMENTO MUNICIPAL UTILITY DISTRICT 6201 S Street. P O Bow 15830. Sacramento. CA 95813. (916) 452 3211 AN ELECTHic SYSTEM SERVING THE HE ART OF CALIFOHNIA RJR 85-520 October 18, 1985 DIRECTOR OF NUCLEAR REACTOR REGULATION ATTENTION HUGH L THOMFSON JR DIREC10R DIVISION OF LICENSING k U S NUCLEAR REGULATORY COMMISSION 3

WASHINGTON D C 20555 DOCKET NO 50-312 LICENSE NO DPR-54 NRC REQUESTED SUPPLEMENTAL INFORMATION FROM TRAN51EN1 0F OCTOBER 2, 1985 During the October 16, 1985, meeting at Rancho Seco with our staffs and NRC Region V, the District agreed to provide the NRC with supplemental information concerning the transient of October 2,1985. The attachments provide the District's assessment and conclusions to date in the four areas highlighted by the NRC review team. Also included as an attachment is the latest revision of the District's " Action List" sent to you on October 14, 1985 (RJR 85-514).

The District supplied this list as part of its program plan ". . . to investigate and correct the causes associated with . . . " the October 2nd event. The attachemnts are:

1 MAIN FEED PUMP TRIP DETERMINATION: Results of the District's deternIInation of the probable cause of the main feed pump trip event.

II HPI "A" FLOW AN0MALY: Analysis and investigation of the mechanisms creating the apparent flow anomaly upon initiation of high pressure injtetton in "A" line.

III COOLDOWN OF THE RCS: A quantitative discussion of the cooldown rate experienced by the RCS during the transient.

IV C00l.00WN RATf m AND TECH SPEC 1: The District's interpretation of the RCS cooldown vs. Tech Spec limits and t.ooldown curves.

V ACTION TIS _T: Latest revision which provides the current status of the District's program plan to resolve issues of the October 2,1985, transient.

If you require additional information or have any questions concerning any of

}heaboye,contactJerryDelezenskiofmystaff.

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R. J. RODRIGUEZ \ 5 ,

ASSISTANTGENERAL)fANAGER, NUCLEAR Attachments l

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ATTACHMENT 1 TOOCTOBER 18, 1985, NRC LETTER I. MAIN FEE 0 PUMP TRIP DETERMINATION During the October 2,1C35, trcnsient.

A. SYMPTOM:

The control panel A main feed pump trip indicator and the plant computer system indiceced the A main feed pump was tripped shortly after loss o' condenser vacuum and 19 seconds before the mactor trip. The 3 main feed pump was indicated tripped 30 seconds af ter '.no A main feed pump trip indication. The cause of these r,ain feed. pump trips was not immediately apparent.

B. INVESTIGATION:

Positive indication enabling conclusive identification of the cause, or causes, of the trip of both main feedwater pump-drive turbines was not available. Therefore, the investigation plan consisted of an examination of the "as found" condition of tne feedwater pumps / drive turbines including controls, analysis l of the data recorded during the event, consideration of Operator l statements about transient events, review of drawings and vendor equipment manuals, review of certain modifications and assistance of manufacturers' field engineers. The investigation plan was composed of the following steps:

1. Identification of main feed pump / drive turbine trip devices.

2. Examination of trip device "as found" conditions for clues about trip causes.

3. Proposal of several trip hypotheses.

4. Proof or disproof of hypotheses.

5. Development of conclusions.

In order to identify all main feed pump / drive turbine trip devices, an engineering review of drawings, schematics, vendors' manuals, manufacturers' records, and plant records was conducted. An angineer from Westinghouse (manufacturer of the drive turbine) examined the physical installation at Rancho Seco to identify any trip devices not documented, looking specifically for a low vacuum trip device. None were found. The following is a list of

r

[

e 2

trip devices:

1. Bearing Lube Oil Pressure Low

2. ThrustBearingWear(ForwardandReverse)

3. PumpDischargePressureHigh(InstantaneousTrip) 4 Pump Discharge Pressure High (Delayed Trip)

5. Overspeed

6. Manual

7. Governor Oil Pressure Low (This device initiates feed pump trip alarms and causes the throttle and stop valves to close.

The pump / turbine is not tripped by this device.)

Examination of trip device "as found" conditions was performed and the set point of each device identified above, The trip devices were also examined for proper interconnection in the control system and for any degradation. The trip devices for both pumps were found to be in the " normal" (not tripped) state.

The B MFP Discharge Pressure High (Delayed Trip) trip device set point was found set 35 psi lower than the normal set point. Wiring for the trip devices was found to conform to the drawlags and no undocumented trip devices were found.

The Operators on shift during the transient were pooled by the Plant Superintendent concerning actuation of a manual trip. The findings of this poll were:

1. The A MFP was definitely not tripped by actuation of the manual trip.

2. Manual trip of the 8 MfW is still under study.

Five hypotheses have been proposed and evaluated as discussed below:

1. Pump Discharge Pressure High Trip actuated by a pressure spike in the pump discharge. The pressure spike was attributed to pressure oscillations Induced by loss of condenser vacuum, increased pump discharge pressure from increased pump speed, and water hammer caused by closure of a feedwater block valvo.

This hypothesis was disproved by engineering analysis and evaluation. The maximum pressure attributable to the afore.

3 mentioned pressure components was determined to be about 1300 psig, the trip is set at 1650 psig. Pump speed necessary to attain the pressure trip setpoint was deter-mined to be about 5200 RPM. Actual maximum pump '.pced attained by the A MfP (determined by interpolating available data) was about 4100 RPM.

2. Thrust Bearing Wear Trip actuated by movement of the pump / turbine shaft. Shaft movement was attributed to flow and pressure oscillations causing unbalanced resultant forces from the turbine rotor and pump impeller. This should have caused the thrust bearing wear signal to " seal in". The thrust bearing wear trip did not require reset prior to resetting the MfP turbine. This investigation con-tinues.

3. Overspeed Trip actuated by excessive pump / turbine speed. The overspeed was attributed to unloading of the pump impeller caused by steam entering the pump suction, or reduced flow through the pump. Heat for vaporizing feed-water liquid was supplied by condensation of pegging steam.

This was evaluated by an engineering calculation. The calculation concluded that feedwater would remain a compressed liquid after heating attributed to desuperheating and con-densing pegging steam. Evaluation of other overspeed phenomenon, including proper trip of the device, is continuing.

4 Low Vacuum Trip actuated by loss of condenser vacuum.

A low vacuum trip device has not been identified. Investigation of transient effects on the pump / turbine assembly is continuing.

5. Governor Oil Pressure Low switch actuated by causing the throttle and stop valves to close and generation of a computer

" pump tripped" signal. This apparent trip of the A MfP is attributed to a decay in turbine governor oli pressure.

Actuation of the governor low oil pressure switch does not cause actuation of the AUTO STOP oil dump solenoid, thus, the A MfP drive turbine was not, in fact, tripped. This hypothesis is supported by the following:

1. Pump speed momentarily increased about 400 RPM about two minutes after the pump was indicated to have tripped.

2. The Operators were not abic to reset the puup.

3. Two lub oil pumps for the A MfP were found running after the plant was stabilized.

4 C. CONCLUSION:

At this time we are not proposing a conclusion to the cause of the trip of the main feed pump turbines. Investigations are continuing as described above and additional phenomenon are being explored with assistance from INPO dnd other utilities that have similar pump drives and controls. We util comunicate to NRC any new findings that develop from our continuing investigation.

l

ATTACHMENT 11 IIPI "A" FLOW ANOMALY following the transient of October 2nd, Control Room operators reported that indicated flow through the "A" High Pressure Injection (HPI) line had dropped to zero when the control valves for the other three HP! lines were opened in unison, Review of the data gathered by one of the plant computers confirmed the report and showed that the condition lasted for about 30 seconds. Post transient investigation also revealed that this same phenomenon occurred during a trip in 1984 involving a shorted inverter. At that time Control Room operators assuned that the abnormal indication was related to the inverter problem.

Troubleshooting of the phenomenon has proceeded in six distinct phases. ,

in Phase 1, proper function of all devices in the instrumentation loop was verified.

In Phase 2, a test was written and performed which duplicated the phenomenon and allowed for collection of additional data under controlled conditions, in Phase 3, calculations, based on the data collected in Phase 2, showed that a large reduction in flow would be expected as a result of the transient flow conditions and piping system geometry. However, this calculated flow drop was not as large as that which was actually experience, it should be noted that tha system alignment at the time the abnormal condition occurred was for normal Reactor Coolant System Make-up with post trip HP! addition and not in the line-up that the system would automatically assume during a Safety features Actuation.

Phase 4, consisted of examination of the affccted control valve and flow element by radiography in order to provide additional assurance that an intermittent, partial flow blockage in the valve or erosion of the flow elements did not exist. These examinations showed the 1 equipment to be in good condition.

Phase 5, consists of another test procedure, approved by the Plant Review Committee but not yet performed, that will demonstrate again that this flow phenomenon occurs only during nanual HPl and not during Safety features Actuated HPl. Proper HPl flow under Safety features condition was demonstrated in June of this year during routine refueling interval surveillance testing. flow resistance of this flow path and a parallel HP! flow path will be compared.

Phase 6, consists of further refining the calculations performed in Phase 3 using data collected in Phase 5 testing.

The compiled results from the exhaustive investigation detailed above will demonstrate that a transient hydraulic pht:nomenon resulting from the "as built" piping configuration occurs during manual HPI but does not af fect balanced Safety features initiated HP! flow.

ATTACllMENT Ill C00LDOWN Of Tile RCS A quasi steady state energy balance has shown good agreement between the RCS heat removal based on the observed cooldown, and the heat removal from the OTSGs based on Auxiliary Feedwater Flow and 0TSG level.

Additionally, good agreement was found between the heat removal from the OTSGs based on Auxiliary Feedwater flow and 0TSG 1evel, and the assumed steam loads. The assumed steam loads include the ,

Auxiliary feedwater Pump Turbine and the 4A Feedwater Heater relief I valves as the major steam loads.

Preliminary results are attached. The results will be checked in accordance with our calculation procedures before finalization.

Final results should be available before October 22, 1985. This calculation will formalize the rough calculations done inmediately following the transient,

1 CALCULATION SHEET

$~ SSACRAMENTO M U DMUNICIPAL UTILITY DISTRICT C 6201SStreet.P,0 Bo=15830.SacramentoCA950521830(9161452 3211 l ORIGINATOR *^

- t**:

- C DATE

! / Y 'b C ALC. NO. 3 ~ f ~ l i I ^ l E SUBJECT * '#

- ('I

• a' CHECKED I< / 7 \' SHE E T l_ OF __2 I

PRELIMINARY RESULTS s .

o Average AFW flows between 01:36 and 01:43

. A 172,000 lb/hr

> B 186,000 lb/hr - -

e o OTSG Water Inventory Change between 01:36 and 01:43

~~

A 3,120 lb 19 8 3,570 lb '

Steaming Rate W 1 = WA ry ut, A 145,000 lb/hr

'o 77 8 155,000 lb/hr

'I

_ _ _ , , _. ,n .w , -- , . - - * -- - - - * * - * ' '

,e Change in steam mass between 01:36 and 01:43 l, (Pressure 945 4 622 psig) . .

}z-

" uts = 9,260 lb ao -

si Total steam usage W2 " W1 + />Ms -

s' ' '

t>t 23

,o W2 = 379,000 lb/hr , ,

t is

,, kNOWN Steam Loads se

,g Hoggers, Air ejectors Gland Steam, Aux Feed Pump Turb, Pegging Steam to 4A ~

to 370,000 lb/hr (85% of this is pegging steam). . . l Unaccounted for steam losses , ,

"I 9,000 lb/hr 34{

Sl

,, This is within the uncertainty of the calculation.

i .

two teac ie se

CALCULATION SHEET

$SMUD SACRAMENTO MUNICIPAL UTILITY DISTRICT ( i 6201SStreet.P O Bon 15830.SacrameentoCA9585218301916) 452 3211 ORIGIN A TOR ________________.__._______DATE _ _ _ _ _ _ _ _ _ _ _ . _ CALC. NO _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _

SUBJECT _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . . _ . _ . . . _ _ _ _ _ - CHECKED _ _ . . _ . _ _ _ _ _ . _ _ . _ _ _ _ . . . . _

__ __ _ .___ _ _ . _ _ _ _ . . . _ _ _ - _ . . _ _ _ _ . _ _ _ . _ SHEET _2 _

_ OF _ 2 _ __ ._ _ .

2 3

PRIMARY SIDE HEAT BALANCE

. All numbers for 7 minute period from 01:36 to 01:43

, Heat removed from OTSG's (based on AFW flows and 0TSG level change)

'l 0

sg

= 42.5 MBtu

,,l Decay Heat Input =7.4 MBtu Pump Heat Input =9.6 MBtu l

,)l

j Heat from cooling RCS water =16.35MBtu is: ,

i.! Heat from immersed metal =7.85MBtu

,a

,,! Heat frcn pressure boundary metal ~4 MBtu Net Heat removed from RCS ry ai! Q= 45.2 MBtu l

[( This agrees within 6%

J4 25 28; 27 2RI 2S Jo 11 12 11 14 1%

3e SM'/O ,419e to 64

ATTACHMENT IV C00LD0WN TECHNICAL SPECIFICATION The Rancho Seco Technical Specifications contain two limits on cooldown of the primary system. Technical Specification 3.1.2.4 states, "The pressurizer heatup and cooldown rates shall not exceed 100* F. in any 1-hour period." This limit applies only to the pressurizer and is based on an ASME Code fatigue analysis performed on that vessel. This specification was clearly not exceeded during the October 2, 1985, transient.

Technical Specification 3.1.2.2 provides a curve (Figure 3.1.2-2) of allowable system pressure as a function of temperature for normal heatup and cooldown operation. Operation in accordance with this curve ensures the requirements of 10 CFR 50 Appendix G are satisfied. Technical Specification 3.1.2.2 also states that the cooldown rate stated on the above figure (100* F/ hour when T > 270* F) shall not be exceeded. Information from the Babcock & Wilcox Company indicates that this cooldown rate is applicable only below 550' F. This information is being provided to the Rancho Seco Operators as guidance for interpreting this Technical Specification. The G;tober 2, 1985, transient involved a cooldown from 550' F of approximately 70* F in about 20 minutes. This equates to a cooldown rate in excess of the Technical Specification limit and the District will satisfy the reporting requirements of 10 CFR 50.35.

The extension of the 100* F/ hour requirement of beyond the temperature range (363' F) indicated on Figure 3.1.2-2 is to maintain consistency between reactor coolant system operation and the original design functional requirements. The October 2, 1985, transient did not result in the reactor cold leg temperature entering the range of the pressure limitations on Figure 3.1.2-2. Therefore, the requirements of 10 CFR 50 Appendix G were not violated. The violation of the 100* F/ hour limit has an insignificant effect on the current fatigue life of the plant but has been logged for consideration in future accumulative cycle fatigue analysis.

In accordance with current Rancho Seco Emergency Operation Procedures, this transient resulted in operator action to reduce primary system pressure in accordance with Figure 1 of Procedure E05. The trainstent was evaluated by the Babcock and Wilcox Company and determined not to meet the conditions of possible pressure boundary degradation and the system was returned to normal Hot Standby status.

LEGEND: SU-. Startup R: quired LT = Lcng T rm STATUS DATE 10-18-85 -

PE = Power Escalation OCTOBER 2, 1985 TRANSIENT TIME 1600 NA = Not Applicable ST = Short Term - ACTION LIST -

DESCRIPTION RESPONSIBILITY SCHEDULE STATUS jWR No./NCR/ COMRENTS ETC.

'I Post Trip Report J. Field SU In Progress NA Draf t completed. In Review to be finalized 10/21.

II Root Cause Analysis S. Crunk SU Completed NA' Reviewed by Management Review Team.

III Aux FW ICS Control

a. Verify calibration of N. Brock SU Completed 104969, 104972 Completed 10/07/85 appropriate modules. 104973, 104974 104975

b. Reset of Aux FW Valves- B. Spencer SU Completed NA Crews were trained.

On MFWP Reset.

c. Revise procedures for B. Spencer SU Completed NA Temporary change to III.b. Operating Procedure A.51 done 10/13/85. .

t

d. Evaluate design of AFW V. Lewis ST In Progress NA valve reset on restart of MFW Pump or RCP.

4 I

J

~- . . _ . , . - . . , , . . , . _. -

LEGEND: SU = Startup R: quired LT = Lcng Term STATUS DATE 10-18-85 -

PE = Power Escalation DCTOBER 2, 1985 TRANSIENT TIME 1600 NA =.Not Applicable ST = Short Term - ACTION LIST -

DESCRIPTION RESPONSIBILITY SCHEDULE STATUS WR No./NCR/ COMMENTS

- ETC'.

IV HPI "A" Inject Line flow indication

-a. Write and perform J. Field SU Results NA Results to be approved Special Test Procedure. Approval 10/18.

Required

b. Perform calibration N. Brock SU Completed 105228 Completed 10/04/85.

check of FT-23807. Found OK.

c. Resolve flow anomaly and J. Field SU Requires S-5103 NCR assigned to D. Abbott.

prepare Summary Report. Disposition (To be completed 10/22.)

V Pegging Steam Controls

a. Determine adequacy of J. Field SU Completed NA Nuclear Engineering pegging steam setpoints (S. Rutter) Support and FW heater relief valve setpoints.

b. 1. Verify setpoints of R. Lawrence SU Completed 104541, 104544 All setpoints as per 2nd and 4th Point 104542, 104543 Process Standards.

heater shell. relief 104562, 104563 valves.

2. Reset 4th point R. Lawrence SU 104581, 104583 Revised setpoint values heater shell reliefs 104582, 104584 per V a.

to new setpoint values.

L _

LEGEND; SU = Startup Required LT = Lcng Term STATUS DATE 10-18-85 -

PE = Power Escalation OCTOBER 2, 1985 TRANSIENT TIME 1600 HA = Not Applicable ST = Short Term - ACTION LIST - '

DESCRIPTION RESPONSIBILITY SCHEDULE STATUS WR No./NCR/ COMMENTS ETC.

Y c. Verify setpoints of all R. Lawrence PE Planning Will require use of hydro secondary system relief assist on valves without valves which could recent setpoint history.

cause rapid cooldowns/

other FW heater shell rel ief s.

d. Determine appropriate R. Lawrence LT To be done as part of PM periodic test program program upgrade.

(i.e., either PM or SP Program) and implement same for all secondary relief valves.

e. Resolve report of MSR J. Field SU Completed NA Resolved that MSR Reliefs Reliefs lifting after did not lift.

Rx/ Turbine trip.

f. Establish criteria for V. Lewis LT process setpoint -

determination.

g. Review plant for proper V. Lewis LT application of criteria.

h. Add setpoints for R. Colombo LT AP.152 FSL-32243, 32244, and 32453 to Process Standa rds.

L- .-_.,_ _ ._._. . . . _

LEGEND: SU = Startup R; quired LT = Leng Term STATUS DATE 10-18-85 PE = Power Escalation OCTOBER 2, 1985 TRANSIENT TIME 1600 NA = Not Applicable ST = Short Term - ACTION LIST -

DESCRIPTION RESPONSIBILITY SCHEDULE STATUS WR No./NCR/ COMMENTS ETC.

VI "A" Main Feedwater Pump seal water and controls

a. Repair linkage on N. Brock SU Completed 104965 Completed "immediate" controller. repairs 10/02/85.

Completed 105378 Proper pin installed.

b. Check common mode N. Brock LT Reviewing NA Looking for common mode failure possibility on relations to VI a.

controller linkage.

VII Main Feed Pump Trip Event

a. Perform test to duplicate J. Field SU Written NA Deferred pending results of low vacuum condition. Other investigations.

b. Install monitoring N. Brock SU Planning NA See X.a.

instrumentation.

c. Verify "as built" wiring C. Linkhart SU Completed 102722 Plant drawings accurately of "A" FWP trip circuits. show "as built" configuration.

d. Check setpoints of trip N. Brock PE Hold 102716, 102721 Requires WR 102716 to be devices. 102718, 103272 closed out.

102720, 103273 u _ _ _ _ _ _

LEGEND: SU = Startup R2quir:d LT = Lcng Tcrm STATUS DATE 10-18-85 -

PE = Power Escalation DCTOBER 2, 1985 TRANSIENT TIME 1600 NA = Not Applicable ST = Short Term - ACTION LIST.-

DESCRIPTION RESPONSIBILITY SCHEDULE STATUS WR No./NCR/ COMMENTS ETC.

VII e. Compile history of FW N. Brock ST Completed NA pump control problems.

f. Check end play on main R. Lawrence SU Completed 102719 Acceptable.

shaft of "A" MFW Pump.

g. Obtain L0 sample from R. Lawrence SU Completed 103269, 102719 Normal.

"A" and "B" MFW Pump and have analysis performed.

h. Verify "as built" wiring C. Linkhart SU Completed 105686 Acceptable; elementaries of "B" FWP trip circuits. are correct. S-5119 written.

i. Install Trip Circuit C. Linkhart LT Preparing Requires pump out of

, Alarm Lights. ECNs service.

VIII Main Condenser Loss of Vacuum Event

a. Update drawings to R. Lawrence SU Completed R-0177 reflect "as built" conditions of MSR relief sealing steam.

b. Revise procedure (s) to B. Spencer SU Completed NA Temporary change to show MSR relief sealing Operating Procedure A.49 steam valves, written.

L

LEGEND: SU = Startup R:quirzd LT = Lcng Tcrm STATUS DATE 10-18-85 -

PE = Power Escalation DCTOBER 2, 1985 TRANSIENT TIME 1600 NA = Not Applicable ST = Short Term - ACTION LIST -

DESCRIPTION RESPONSIBILITY SCHEDULE STATUS WR No./NCR/ COMMENTS ETC.

VIII c. Determine whether B. Spencer SU Completed NA Temporary change to sealing steam procedures Operating Procedure A.49 are adequate and usable. written.

d. Review / analyze perform- J. Field LT Holding NA Long term item.

ance of the gland steam condenser.

e. Investigate when/why MSR B. Spencer SU Completed NA Investigation unable to sealing steam valve was to ascertain when/why closed. valve was closed.

f. Determine whether MSR R. Lawrence LT Complete NA Review shows adequate Relief Sealing Steam for restart.

System works as designed. .

g. Initiate WR for rework R. Lawrence LT Schedule 104113 Next refueling.

of leaking MSR relief valve.

h. Resolve setpoint error S. Carmichael SU Work 105116 of main turbine low vacuum trip.

1. Correct / upgrade docu- R. Lawrence LT mentation for maintenance on turbine trip block.

L

t LEGEND: SU = Startup R quired LT = Lcng Tcrm STATUS DATE 10-18-85 -

PE = Power Escalation OCTOBER 2, 1985 TRANSIENT TIME 1600 NA = Not Applicable ST = Short Term - ACTION LIST -

DESCRIPTION RESPONSIBILITY SCHEDULE STATUS WR No./NCR/ COMMENTS ETC.

VIII j. Include placement / B. Spencer SU In Progress removal of MSR relief valve covers in procedures,

k. Fabricate new MSR relief R. Lawrence ST Being Designed valve covers.

1. Include main turbine R. Colombo ST trip setpoints in Process Standards.

m. Develop design improve- V. Lewis LT ment to reduce leakage of MSR relief valves.

IX Condensate /FW Oscillation J. Field SU Completed NA Input to Event Report.

X ICS Tuning

a. Prepare ICS/Feedpump N. Brock PE In STP to PRC 10/18/85.

tuning STP. Preparation

b. Perform tuning as plant N. Brock PE Engineering conditions permit. Required

c. aTc Control N. Brock LT Engineering L

LEGEND: SU = Startup R:quir:d LT = Lcng Tcrm STATUS DATE 10-18-85 -

PE = Power Escalation OCTOBER 2, 1985 TRANSIENT TIME 1600 NA = Not Applicable ST = Short Term - ACTION LIST -

DESCRIPTION RESPONSIBILITY SCHEDULE STATUS WR No./NCR/ COMMENTS ETC.

XI Valve Identification Program

a. Develop list of selected B. Spencer SU Completed To include Operating systems for Operations ,

Procedures A.37, walkdown. A.49,A.41, A.42, A.50, A.46, A.34, A.38, A.40, A.51, A.47, A.28, A.39, A.53, A.6. ___.

b. Operations crew to walk B. ' Spencer SU Completed down systems to identify valves not on prints.

c. Prepare NCRs on findings B. Spencer SU In Progress NCRs written. Temporary and revise procedures as changes to procedures to be necessa ry. completed 10/18.

d. Update drawings and B. Spencer LT In Progress DCNs to be generated.

place ids on valves.

e. QA Surveillance H. Canter SU Completed No's. 492, 488 XII "B" Feedwater Line Leak R. Lawrence SU Completed 104548, 104564 Report addressing the Reactor Building. 104560, 104572 cause and the repair done.

102095, 104569 Material meets applicable 104567, S-5090 code.

S-5111 L

i LEGEND: SU = Startup R: quired LT = Lcng Term STATUS DATE 10-18-85 -

PE = Power Escalation OCTOBER 2, 1985 TRANSIENT TIME 1600 NA = Not Applicable ST = Short Term - ACTION LIST -

DESCRIPTION RESPONSIBILITY SCHEDULE STATUS WR No./NCR/ COMMENTS ETC.

XIII P-319 Bearing Failure

a. Pump Repair R. Lawrence SU Completed SP run and passed on 10/10/85.

b. Maintenance History R. Lawrence SU Completed Surveillance History and Cause of Failure / Post Repair Test Corrective Action

c. QA Surveillance J. Jewett SU Completed No. 485

d. Provide oiling B. Rausch SU Completed TS 85-1033 To include safety related instructions pumps. How to determine level . How to maintain oil level . Pump specific instructions.

e. Past practice on LO B. Spencer SU In Progress Level.

f. Investigate whether R. Lawrence SU Completed

" Normal" level was changed.

g. 48-Hour Endurance Run J. Field SU 48 Hr. Run Awaiting performance of SP.

Completed 4

. h. Identify all safety R. Lawrence SU Completed NA related pumps which utilize slinger rings.

L

r LEGEND: SU = Startup Required LT = Lcng Tcrm STATUS DATE 10-18-85 -

PE = Power Escalation DCTOBER 2, 1985 TRANSIENT TIME 1600 NA = Not Applicable ST = Short Term - ACTION LIST -

DESCRIPTION RESPONSIBILITY SCHEDULE STATUS WR No./NCR/ COMMENTS ETC.

XIII 1. Oil level indication for V. Lewis SU Completed Determine proper P-318, 319 configuration.

J. Root Cause S. Crunk SU Completed- Included as subsection of Item II.

k. Inspect rings in pumps R. Lawrence SU In Progress which have been previously disassembled.

XIV Loss of Aux Steam Event

a. Prepare Report M. Nickerson .:0 Completed TS 85-1021

b. Root Cause S. Crunk LT To be NA RC 85-021 Completed .

11/30/85

c. Investigate Aux Boiler C. Linkhart SU Completed NA Power Supply.

d. I and C analysis of N. Brock LT To be XIV c. Completed 11/15/85 L

LEGEND: SU o Startup Requir:d LT = Leng Tcra STATUS DATE 10-18-85 -

PE = Power Escalation DCTOBER 2, 1985 TRANSIENT TIME 1600 ,

NA = Not Applicable ST = Short Term - ACTION LIST -

DESCRIPTION RESPONSIBILITY SCHEDULE STATUS WR No./NCR/ COMMENTS ETC.

XV Training

a. Lessons Learned F. Thompson LT Reviewing NA

b. Training on Item III.b B. Spencer SU Completed NA SO 20-85 (Instructions /

Recommendation)

c. Training on pumps / motor M. Hieronimus SU In Progress NA oiling

~

XVI Procedure Adequacy 1

a. E0Ps D. Comstock SU In Progress NA

b. Normal Procedures D. Comstock LT In Progress NA

c. Identify operator actions M. Hieronimus LT Active NA Requires input / feedback

, not specifically Program from A0's, EA's, etc.

addressed in procedures. Memo to SS of 10-10-85

" Problem Feedback Report."

d. Monitor operation D. Comstock PE Prepared NA QA surveillance planned.

procedures during SU. Validation of procedures will be performed.

I~

e. Evaluate operator D. Comstock SU Completed NA performance during the

trip.

t

1

-LEGEND: SU = Startup Required LT = Lcng Term STATUS DATE 10-18-85

• PE = Power Escalation OCTOBER 2, 1985 TRANSIENT TIME 1500 NA = Not Applicable ST - Short Term - ACTION LIST -

DESCRIPTION RESPONSIBILITY SCHEDULE STATUS WR No./NCR/ COMMENTS ETC.

XVII Health Physics / Emergency Plan

a. Health Physics aspects. F. Kellie SU Completed FWK 85-202 No Health Physics impact.

b. Emergency ~ Plan B. Spencer SU Completed NA Emergency Plan did not utilization. M. Heironimus require activation.

to B. Spencer memo XVIII RCS Overcooling

a. Tech Spec Review R. Colombo SU Completed NA

b. B and W Evaluation J. Field SU Completed NA B and W letter, SMUD-85-222, dated Oct. 4, 1985, " Structural Integrity of Pressure Boundary Components are Suitable for Continued Power Operation.

XIX Preventive Maintenance Program for Non-safety Related Equipment

a. Description of existing R. Lawrence SU Completed NA N. Brock'and C. Linkhart program. to provide IC/ Elect input.

b. Planned improvements. R. Lawrence LT Requires NA N. Brock and C. Linkhart 11/30/85 to provide IC/ Elect input.

response to NRC.

l