ML20081M727

Monthly Operating Repts for Sept 1983

ML20081M727
Person / Time
Site:	San Onofre
Issue date:	10/17/1983
From:	Haynes J, Morris C SOUTHERN CALIFORNIA EDISON CO.
To:	NRC OFFICE OF RESOURCE MANAGEMENT (ORM)
References
NUDOCS 8311170350
Download: ML20081M727 (13)

Text

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- NRC MJtGLY OPERATING REPORT DOCKET 10. 50-361 UNIT NAME SONGS - 2 DATE 10/17/83 CO@LETED BY C. A. Morris TELEPHONE (714) 492-7700 Ext. 56264 y OPERATING STATUS

1. Unit Name: San Onofre Nuclear Generating Station, Unit 2

2. Reporting Period: 1 September 1983 through 30 Septenber 1983

3. Licensed %ermal Power (MWt): 3,390

4. Nameplate Rating (Gross MWe): 1,127

5. Design Electrical Rating (Net me): 1,087

6. Maxinum Dependable Capacity (Gross MWe): 1,127  ;

7. Maxinum Dependable Capacity (Net MWe): 1,087 l

8. If Changes Occur In Capacity Ratings (Items Nurber 3 Tnrough 7)

Since Last Re;nrt, Give Reasons: 1 o la _

. 9. Power Level 'Io Which Restricted, If Any (Net MWe): NA

10. Reasons For Restrictions, If Any: la This Month Yr.-to-Date Cumulative

11. Hours In Reporting Period 720.0 6,551.0 9,011.2

12. Nurber Of Hours Reactor Was Critical 690.5 3,529.0 4,562.73

13. Reactor Reserve Shutdown Hours 0 0 U

14. Hours Generator On-Line 683.88 3,055.56 3,880.06

15. Unit geserve Shutdown Hours 0 0 0

16. Gross %erraal Energy Generated (!EH) 2,298,585 7,946,160 8,927,710

17. Gross Electrical Energy Generated (MWH) 792,200 2,581,000 2,776,000 o 18. Net Electrical Energy Generated (!EH) 755,500 2,382,000 2,507,000

19. Unit Service Factor NA NA NA

20. Unit Availability Factor NA NA NA

21. Unit Capacity Factor (Using MDC Net) 0 0 0

22. Unit Capacity Factor (Using DER Net) 0 0 0

23. Unit Forced Outage Rate 0 0 0

24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):

18-month surveillance outage, Noverber 15, 1983, 1-ronth duration.

3 25. If Shutdown At End Of Report Period, Estimated Date of Startup: NA

26. Units In 'Iest Status (Prior To Cor,Taercial Operation): Forecast Achieved INITIAL CRITICALITY 07/17/82 07/21/82 INITIAL ELECTRICITY 9/82 09/20/82 00MMERCIAL OPERATION Under Review B311170350 831017 PDR ADOCK 05000361 R PDR

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. . 1 AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-361 UNIT SONGS - 2 DATE 10/17/83 COMPLETED BY C. A. Morris TELEPHONE (714) 492-7700 Ext. 56264 MONTH: September 1983 3 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net) 1 1136.67 17 1112.54 2 896.44 18 1113.33 3 0 19 1105.15 4 495.65 20 1120.00 5 1124.48 21 1107.42 6 1118.75 22 1110.00 7 1127.56 __

23 1090.42 8 1121.27 24 1119.06 g

9 1103.46 25 1131.25 10 1124.58 26 1107.81 11 1176.54 27 1115.83 12 1114.79 28 1117.50 13 1125.42 29 1110.42 14 1115.00 30 1116.88 2 15 1121.67 31 16 1088.02 0565u

UNIT SHITfDOWS MID POWER REDUCTIONS DOCKET No. 50-361 . . -

(Di1T NME _ausus - Z -

REPORT M0tml SEPTEMBER, 1983 I&TE 10/17/83 ,

C0ffLETED BY C. A. -Morris - '

TELEPHCEGE t ng) en-nuu .

Ext. 562tK Method of Shutting Cause & Corrective Duration Down LER System Conponent Action to No. Date Typel (Hours) Reason 2 Reactor 3 No. Code 4 Codes _ Prevent Recurrence 22 830902 F 36.1 H 3 NA HA INSTRU Unit tripped when all of.the governor va2.ves closed while the computers which calculate the position of the high pressure turbine governor valves were being synchronized. As corrective action, outputs of the three computing channels were monitored with simulated inputs, and the channel synchronization operation was tested prior to 554 reactor power.

.1 2 3 4 F-Forced Reason: Method: Exhibit F - Instructions S-Scheduled A-Iquipment Failure (Explain) 1-Manual for Preparation of Data B-Maintenance or Test 2-Manual Scram. ' Entry Sheets for Licensee C-Refueling 3-Automatic Scram. Event Report (LER) File ,

D-Regulatory Restriction 4-Continuation from (NURBG 0161)

E-Operator Training & License Examination Previous Month F-Administrative - 5-Reduction of 20% 5 G-Operational Error (Explain) or Greater in the Exhibit H-Same Source H-Other (Explain) Past 24 Hours 0565u 6-Other (Explain)

SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH DOCKET NO. 50-361 UNIT SONGS - 2

' DATE 10/17/83 COMPLETED BY C. A. Morris TELEPHONE (714) 492-7700 Ext. 56264 September 1 0001 Unit is in Mode 1, at 99.7% reactor power. Turbine load is 1175 MWe gross, e September 2 1900 Decreased turbine load to 1050 MWe gross to perform turbine stop and I governor velve testing.

l September 2 1923 Reactor md turbine tripped due to all governor valves closing while synchronizing the computers which calculate the position of the high pressure turbine governor valves. (

September 4 0055 Entered Mode 2.

September 4 0105 Reactor critical.

September 4 0445 Entered Mode 1.

September 4 0730 Synchronized generator and applied block load.

September 5 0001 Reac'cr power at 100% and turbine load at 1184 MWe gross.

September 9 1915 Decreased turbine load to 1050 MWe gross to perform turbine stop and a governor valve testing.

September 9 2245 Increased reactor power to 100% and turbine load to 1186 MWe gross.

September 16 2000 Decreased turbine load to 1030 MWe gross to perform turbine stop and governor valve testing.

September 17 0135 Increased reactor power to 99.7% and turbine load to 1165 MWe gross.

September 23 1805 Decreased turbine load to 1050 MWe gross to perform turbine stop and s governor valve testing.

• September 23 2102 Increased reactor power to 100% and turbine load to 1169 MWe gross.

September 30 2359 Unit is in Mode 1 at 100% reactor power. Turbine load is 1166 MWe gross.

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REFUELING INFORMATION DOCKET 110. 50-361 UNIT SONGS - 2 DATE 10/17/83 COMPLETED BY C. A. Morris TELEPHONE (714) 492-7700 Ext. 56264

1. Scheduled date for next refueling shutdogg.

Not yet determined.

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2. Scheduled date for restart following refueling.

Not yet determined.

w

3. Will refueling or resumption of operation thereafter require a Technical Specification change or other license amendment?

Not yet determined.

What will these be?

Not yet determined.

4. 3cheduled date for submitting proposed licensing action and supporting information.

Not yet determined.

5. Important Licensing considerations associated with

'- refueling, e.g. new or different fuel design or supplier, unreviewed design or' performance analysis methods, significant changes in fuel design, new operating procedures.

Not yet determined.

6. The number of fuel assemblies, a) In the core. 217 b) In the spent fuel storage pool. O,

7. Licensed spent fuel storage capacity. 800

- Intended change in spent fuel storage capacity. NA

8. Projected date of last refueling that can be discharged to spent fuel storage pool assuming present capacity.

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. NRC FO! GLY OPERATING REPORT DOCKET 10, 50-362 UNIT NA!E SONGS - 3 DATE 10/17/83 COPPIETED BY C. A. Morris TELEPHONE (714) 492-7700 Ext. 56264 y OPERATI!G STA'IUS

1. Unit Name: San Onofre Nuclear Generating Station, Unit 3

2. Reporting Period: 1 Septerber 1983 through 25 Septerber 1983

3. Licensed %ermal Power (MWt): 3,390 -

4. Nameplate Rating (Gross MWe): 1,127

5. Design Electrical Rating (Net We): 1,087

6. Maxinum Dependable Capacity (Gross MWe): 1,127

7. Maxinum Dependable Capacity (New MWe): 1,087

8. If Changes Occur In Capacity Ratings (Items NLLmber 3 'Ihrough 7)

Since Last Report, Give Reasons:

. la

9. Power Level ':0 Which Restricted, If Any (Net MWe): ~

NA

10. Reasons For Restrictions, If Any: NA W is Month Yr.-to-Date Cumulative 7,554.0

11. Hours In Reporting Period 595.0 6,426.0 -

12. Number Of Hours Reactor Was Critical 24u.d 297.8 2:f7 8'-

13. Reactor Reserve Shutdown Hours 0 0 0

14. Hours Generator On-Line 0 0 0 '

15. Unit Reserve Shutdown Hours 0 0 0 -

16. Gross hermal Energy Generated (MWS) 0 0 0

17. Gross Electrical Energy Generated (MWH) 0 0 0

• 18. Net Electrical Energy Generated (MWH) 0 0 0 _

19. Unit Service Factor NA la NA 4-

20. Unit Availability Factor NA NA NA [

21. Unit Capacity Factor (Using MDC Net) 0 0 0

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22. Unit Capacity Factor (Using DER Net) 0 0 0

23. Unit Forced Outage Rate 0 0 0  ;

24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):  ;

l None *t

25. If Shutdown At End Of Report Period, Estimated Date of Startup: la

26. Units In Test Status (Prior 'IO Commercial Operation): Forecast Achieved j h J ?

INITIAL CRITICALITY -

08/29/83 ,

INITIAL ELECTRICITY Under Review '

COFJERCIAL CPERATION Under Review 0565u E

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' NRC M0tmILY OPERATI!G REPOIC DOCKET No. 50-362

t. . UNIT tRIE SONGS - 3 DATE 10/17/83 l

000fLETED BY C. A. Morris TELEPIKNE (714) 492-7700 Ext. 56264 W ERATING STATUS

.1.

tRiit Name: San Onofre Nucl' ear. Generating Station, Unit 3

'2. Reporting Period: 25 Se;tenber 1983 through 30 Septonber 1983

3. Licensed %ermal Power ( Git): 3,390 4; Nameplate Rating (Gross MWe): 1,127

-5. Desi@ Electrical Rating (Net We): 1,087

6. - ' Maximum Dependable Capacity (Gross We): 1,127

-7. Maximum Dependable Capacity (New We): 1,087

'8. If Changes Occur In Capacity Ratings (Items Number 3 Through 7)

-Since IAst Report, Give Reasons:

p NA-

9. Power Level To Which Restricted, If Any (Net MWe): NA

10. Reasons For Restrictions, If Any: NA Wis Month Yr .-to -Date Cuculative

.11. Hours In Reporting Period' 125.0 125.0 _

125.0

12. Nucber Of Hours Reactor Was Critical 89.1 89.1 89.1

13. Reactor Reserve Shutdown Hours 0 0 0

14. Hours Generator On-Line 89.1 89.1 89.1

15. Unit Reserve Shutdown Hours 0 0 0

16. ' Gross %ermal Energy Generated (MWH) 118,958 118,958 118,958

17. Gross Electrical Energy Generated ()tiH) 11,710 11,710 11,710 3~ 18. Net Electrical' Energy Generated (191H) 7,060 7,060 7,060

19. Unit Service Factor NA NA NA

20. Unit Availability Factor NA NA tR

21. Unit Capacity Factor (Using MDC Net) 0 0 0

22. Unit Capacity Factor (Using DER Net) 0 0 0

23. Unit Forced Outage Rate 0 0 0

24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):

None k!- 25. If Shutdown At End Of Report Period, Estimated Date of Startup:

26. Units In Test Status (Prior TO Commercial Operation): Forecast NA Achieved INITIAL CRITICALITY -

08/29/83

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INITIAL ELECTRICITY -

09/25/83 COMMERCIAL TERATION Under Review 0565u

AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-362 UNIT SONGS - 3 I DATE 10/17/83 COMPLETED BY C. A. Morris TELEPHONE (714) 492-7700 Ext. 56264 MONTH: September 1983 D'

DAY- AVERAGE' DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net) 1 0 17 0-2 0 18 0 3 0 19 0 4 0 20 _

0 5 0 21 0 6 0 22 0 7 0 23 0

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8 0 24 0 9 0 25 0 10 0 26 96.35 11 0 27 93.75 12 0 28 79.17 b -

13 0 29 24.17 14- 0 30 0 15 0 31 16 0

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UNIT SHITIDOWNS AND POWER REDUCTIONS DOCKET NO. 50-362 **

UNIT NAME SONGb - J REPORP M0tTTH SEPTEMBER, 1983 DATE 10/17/83 COffLETED BY C. A. Marris TELEPHONE ( M4) 4W -/Iuu Ext. 56264 Method of Shutting Cause & Corrective Duration Down IIR System Component Action to 3 Prevent Recurrence No. Date Typel (Hours) Reason 2 Reactor No. Code 4 Code 5 1 830929 F 35.9 A 2 83-071 CB VALVEX Reactor manually tripped in X accordance with Tedinical Specifica-l B tion 3.4.5.2, Action Statement 'b', l l

when unidentified Reactor Coolant System leakage was found to be greater than one gallon per minute.

The cause of this event was a weep-ing relief valve. PSV 9206 and 9207 are currer.tly being evaluated for their tendency to lift and weep.

Appropriate corrective actions will be taken.

1 2 3 4 F-Forced Reason: Method: Exhibit F - Instructions S-Scheduled A-BIuipment Failure (Explain) 1-Manual for Preparation of Data B-Maintenance or Test 2-Manual Scram. Entry Sheets for Licensee C-Refueling 3-Automatic Scram. Event Report (LER) File D-Regulatory Restriction 4-Continuation from (NUREG 0161)

E-Operator Training & License Examination Previous Month F-Administrative 5-Reduction of 20% 5 G-Operational Error (Explain) or Greater in the Exhibit H-Sane Source H-Other (Explain) Past 24 Hours

@565u 6-Other (Explain) x

SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH u

l' DOCKET NO. 50-362 UNIT SONGS - 3 I DATE 10/17/83 COMPLETED BY C. A. Morris TELEPHONE (714) 492-7700 Ext. 56264 September 1 0001 Unit is in Mode 2 at 5 x 10-3g reactor power. Low power physics y testing is in progress.

September 2 1045 Entered Mode 3 due to a defective resistor causing Control Element Assembly (CEA) #32 to drop.

September 2 1345 Replaced resistor in CEA #32.

September 4 1958 Entered Mode 2.

September 4 2030 Reactor critical.

Septenter 7 1200 Entered Mode 3 following completion of low power physics testing.

September 17 1420 Entered Mode 2.

September 17 1440 Reactor critical.

September 18 0209 Reactor tripped during an increase to

- 10-4% power when CPC's were taken out of trip bypass. Penalty factor was excessive due to CEA deviations.

September 18 0855 Entered Mode 2.

September 18 0915 Reactor critical.

= September 18 1335 Entered Mode 1.

September 18 1630 Entered Mode 2 due to a feedwater transient.

September 18 1740 Entered Mode 1.

September 19 0351 Reactor tripped on high steam generator level due to excessive feedwater flow caused by operation of second feedwater pump during testing.

September 19 0540 Entered Mode 2.

September 19 0557 Reactor critical.

6 September 19 1555 Entered Mode 1.

September 19 1930 Raised reactor power to 12%.

September 21 2140 Manually tripped reactor due to the main feedwater regulating valves'

< inadvertent closure while increasing steam generator level, causing the feedwater pumps to trip on high discharge pressure.

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SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH i

September 22 1210 Entered Mode 2.

September 22 1225 Reactor critical.

September 22 1350 Entered Mode 1.

September 23 0325 Raised reactor power to 10%.

September 25 1900 Synchronized generator and applieG p

block load of 55 MWe gross (first time).

September 25 1940 Raised reactor powe to 20% and turbine load to 140 MWe gross.

September 29 0929 Discovered an unidentified RCS leak rate of 1.19 gpm.

September 29 0930 Declared an Unusual Event in accordance with the Emergency Plan.

September 29 l'05 Manually tripped the reactor concurrently performing a trip in accordance with the startup program.

September 29 1350 Began cooldown to Mode 5 in accordance D with Technical Specifications.

September 29 2003 Implemented an abnormal valve lineup isolating CVCS and sample system.

September 30 0145 Discovered charging was isolated by abnormal valve lineup. Initiated immediate corrective actions.

September 30 0157 Charging flow path restored.

September 30 0820 Terminated Unusual Event following procedure modifications for determining leak rate. Present leak rate is at

.238 gpm.

September 30 2359 Unit is in Mode 3 at 544 0F.

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.' REFUELING INFORMATION DOCKET NO. 50-362 UNIT SONGS - 3 DATE 10/17/83 COMPLETED BY C. A. Morris 9 TELEPHONE (714) 492-7700 Ext. 56246

1. Scheduled date for next refueling shutdown.

Not yet determined.

2. Scheduled date for restart following refueling.

Not yet determined, p

3. Will refueling or resumption of operation thereafter require a Technical Specification change or other license amendment?

Not yet determined.

What will these be?

Not yet determined.

4. Scheduled date for submitting proposed licensing action and

supporting information.

Not yet determined.

l l S. Important Licensing considerations associated with refueling, e.g. new or different fuel design or supplier, unreviewed design or performance analysis methods, significant changes in fuel design, new operating procedures.

Not yet determined.

6. The number of fuel assemblies, a) In the core. 217 b) In the spent fuel storage pool. 0

7. . Licensed spent fuel storage capacity. 800 4

Intended change in spent fuel storage capacity. NA

8. Projected date of last refueling that can be discharged to spent fuel storage pool assuming present capacity.

NA 1

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Southern California Edison Company S AN ONOFRE NUCLE AR GENER ATING ST ATION WE P.O. BO A IS S S AN C LEMEN TE, C A LIFORNI A 92672 October 17, 1983 9

Director Office of Management Information and Program Analysis U. S. Nuclear Regulatory Commission Washington, D.C. 20555

Subject:

Docket Nos. 50-361/50-362 Monthly Operating Reports for September 1983 '

San Onofre Nuclear Generating Station, Units 2 and 3 Enclosed are the Monthly Operating Reports as required by Section 6.9.1.10 of Appendix A, Technical Specifications to Facility Operating Licenses NPF-10 and NPF-15 for San Onofre Nuclear Generating Station, Units 2 and 3, respectively. Two Operating Status forms are included for Unit 3. The first form covers the time period before initial electricity generation, and the second covers the period after initial electricity generation.

Please contact us if we can be of further assistance.

Sincerely, m

MHsys}1%nk J. G. HAYNES STATION MANAGER Enclosures cc: J. B. Martin (Regional Administrator, USNRC Region V)

A. E. Chaffee (USNRC Resident Inspector, Units 1, 2 and 3)

J. P._ Stewart (USNRC Resident Inspector, Units 2 and 3) h 9