ML20069A245

Monthly Operating Repts for Jan 1983

ML20069A245
Person / Time
Site:	San Onofre
Issue date:	02/15/1983
From:	Mayweather L SOUTHERN CALIFORNIA EDISON CO.
To:
Shared Package
ML20069A226	List: ML20069A223 ML20069A245 ML20069A302
References
NUDOCS 8303150574
Download: ML20069A245 (14)

Text

'

O AC40 RA k

NRC MONTHLY OPER ATING REPORT DOCKET NO 50-361 DATE February 15, 1983 COMPLETED BY I. Mavweather TELEPHONE 714/492-7700 Ext. 56223 OPERATING STATUS san nnnfro Nuclear (sonoratinn 9tatinn, Unit 2

1. Unit Name:

2. Reportmg Period:

1 January 1983 through 31 January 1983 3390

3. Licensed Thermal Pow er (Mht):

1127

4. Narr.eplate Rating (Gross MWe):

1087

5. Desagn Elcarical Rating (Net MWe):

I

6. Maximum Dependable Capacity (Gross MWe):

1087

7. Maximum Dependable Capacity (Net MWe):

8. If Changes Occur in Capacity Ratings (Items Number 3 Throg 7) Since Last Report. Give Rea>ons:

NA 9 Power Lesel To Which Restricted.lf Any (Net MWer "a

10. Reasons For Restrictiom. lf Any:

This Month Yr..to.Dat e Cumulatise 744 744 3.704_4 II. Hours la Reporting Period 566.8 566.8 1.600.3

12. Number Of Hours Resetor has Critical 0

0 0

13. Renefoe Reserve Shutdown Hows 378.5 378.5 1.202.5

14. Hours Generator On-LW 0

0 0

15. Unit Reserw Shutdown Hours 594,800 594.800 1 491 lan

16. Greis Thennel Emergy Generated (MWH) 1d3.000 la1_nnn no m 7 17 Geom Electrn1 Emergv Generated (MWHy 111.500 111 cnn on con Ill. Net Electncal Energy Generated lMWH)

' NA

~ Ji" NA

19. Unit Semce Factor NA NA NA

20. Umst Avaiinbility Factor 0

0 0

21. Unit Capacity Factor IUsing MDC Net 1 0

0 0

22. Unit Capacity Factor (Uning DER Net)

U 0

0

23. Unit Fernd Outage Rate

24. Sheidewes Scheduled Oser Nest 6 Months IType. Date. sad Duration of Each :

None NA

25. If Shot Doom 4: End Of Report Pened. Estimated Date of Startup 36 Units le Test Status IPrior se Casamercel Operatioal:

Forecast Achse,ed INIT14 L CRITICALITY 9/1982 9/20/1982 INITI AL ELECTRICITY COMMERCIAL OPER ATION Under review B303150574 030215 PDR ADOCK 05000361 R

PDR

\\

o, -

-l AVER AGE DAILY UN!T POWER LEVEL 50-361 DOCKET NO.

UNIT SONGS - 2 DATE February 15, 1983 COMPLETED BY L Maywanthar TELEPHONE 71alaQ9.77nn Ext. 56223 MONTH

.lanuary 1983 DAY AVER AGE DAILY POWER LEVEL DAY AVER AGE DAILY POWER LEVEL (MWe Net 0

204.4 1

,7 2

0 is 0

13.3 0

19 72.3 0

4

,o s

0 0

46.4 0

6 7

1 51.5 0

3 396.0 0

3

,4 9

411.7 25 0

10 405 d 26 11_q is 411.0 263.2 7,

403.9 393.1

s 33 416.3 29 392.1 la 400.4 76,1 3g is 176.6 0

3 394.3 s e,

• sioti) in L-

+

UNIT SMUTDOWNS AND POWER RFIDUCTIONg DOCKET NO.

50-361 UNIT MAteE SONr.S - 2 DATE rahruarv 1A 1983

_ _ %- - + d REPOR T MON TH JANUARY 1983 COMPT.ETED 9Y t

r TER.EP900NE m ano nnn 4

Ext. 56223

~6 t

e s-N"-

938N g,

3. g g

Lkea*cc F.,

g"?

Cover A rwmeioe 8

t og Event

=7 g,6,,,,,,,

$g rep'"8 *

'E 0 0

Ptevent Resverente 6

s 11 821212 F

51 A

4 82-168 IA INSTRU Trip on high LPD/ loc DNBR signal caus ed

~

by faulty reed switch.

Faulty reed s vitch replaced. Unit remained down for rep air of RCP seals and turbine valves.

I 830103 _

F 10.75 A

3 NA HA VALVEX Reactor loss of load trij due to turb' ne stop and governbr valve oscillations.

2

'8'30103 F

1.25 A

NA NA HA VALVEX Turbine trip due to failed resistor 1 i

control circuit for 2HV-2200L.

Failet l

resistor replaced.

3 830104 F

49.5 A

3 NA HA VALVEX Turbine trip due to control valve problems which resulted in reactor trip due to high presurizer pressure.

i 4

830117 F

77.5 A

3 NA HC HTEXCH Reactor trip on high steam generator evel.

Condenser tube leakage.

Leaking tuben rena i red _

~

t 2

.I 4

I Fasced Res m-Meehad

~

Eng, avis F. samswesi. ins 5 $ctiedided A.I,u6pnient Fe61ere(Emplain) t -Maaval ten Prepara 6.

of Dasa R.Meintenance sit Test 2 Manual 5ceam.

Energ Sheres few I krmee l'.Reincling 4 Automatic L ram.

I wen's Meroes eI i MlI de int'MI G

1) Mestul48.ng Restelefl.nl 4 Continuation from previous 01f.11 I.o ceae..e 1 raining A Lkenw Enendnatiem month r

F.Adenennstrein" d

5. Reduction of 20% or greater M.,'j '",',',,',',','" # "I " '

in the past 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> I ' "'"' H 5d"" * ""' '

9.0ther (Explain)

.es.t.i.......,,.

~

Pag 2 of 2 UNIT SHUTDOWN 5 AND POWER REDUCTIONS DOCKEY NO. 50-361 UNIT MAME 50NG5 - 2 DATE Fahruarv 18i; 1983 REPORT MON TH January 1983 (Contd) muito w i h --- m -

m fAh 77 N h t. 56223 TELEFNOME

?

, ~h iE "s

3pi; a t.kensee P,

}

Cause A Coerwth v

lisse E

E2 4

4 i vent s

Ad6em sie S

a'l jgg Rep nl 8' E0 Prevent Reswetente 6

5 830120 F

108.75 A

NA NA WE HTEXCH Manual turbine trip due to saltwater leak.

6 830125 F

25.66 A

NA NA HC HTEXCH Manual turbine trip due to high chloride levels, in condensate system and steam generators.

7 830130 F

41.1 A

3 NA HA VALVEX Turbine manually' tripped'as part of

" controlled" shutdown.

Reactor tripped on high steam generator level..

I 2

1 4

I F.nced Reswn Meihe=1 I.nliMt F. Inunic 6.nu u

5 kheduled A 1quipmens Falluse(Emplain) 1 -Manuel in Preparau.no ol' Dasa R Meinienencei.e Test 1 Manual kram.

Ents) Sheets law I kenece t'.Mcfueling

.e Ausannaisc & ram.

I vesit Nepois il l Mli ele int'NI G al Megul.ii..n Menicial..n 4 Continuation. from previous ost.il 3 tJrre.stus laatsiang A Llienisc 1.nanienseson month F Adnunistesel,c

5. Reduction of 20% or greater

!Ib'Is't",,',','"d'P'"'

in the past 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 14 3"b N b""' """

iila 9.0ther(Explain)

....l.:.......,..

SUMMARY

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

SONGS - 2 UNIT February 15,1983 DATE L. Mayweather COMPLETED BY TELEPHONE 714/492-7700 Ext.56223 January 1, 0001 Unit is in Mode 2. Reactor power is at 1%.

Preparations are in progress to raise reactor power to 50% and resume 50%

power level testing.

January 1, 0403 Entered Mode 1.

January 1, 1215 Reduced reactor power to 1% (entered Mode 2) due to saltwater leak in the southeast condenser.

Feedwater was isolated from the steam generators and cleanup of the condensate feedwater system was effected.

January 2, 2230 Entered Mode 1.

January 2, 2245 Reactor power at 10%.

January 3, 0300 Synchronized generator and applied block load of 100 MWe gross.

~ Reactor loss of load trip initiated when stop)and governor valve January 3, 0502 oscillations were experienced (entered Mode,3.

January 3, 1149 Entered Mode 2.

January 3, 1206 Reactor critical.

January 3, 1433 Entered Mode 1.

January 3, 1547 Synchronized generator and applied block load of 80 MWe gross.

January 3, 1620 Turbine tripped due to incorrect CVOL setting.

l i

January 3, 1735 Synchronized generator and applied block load of 80 MWe gross.

January 3, 1745 Raised turbine load to 140 MWe gross.

n..(il in -s.,r,.

SUMMARY

OF OPERATZNG EXPERZENCE FOR THE MONTH OF JANUARY,1983 Page 2 of 4 January 4, 0110 Received indication of saltwater leak on northwest condenser.

Began reducing turbine load.

January 4, 0605 Turbine tripped due to control valve problems which resulted in a reactor trip due to high pressurizer pressure (entered Mode 3).

January 4, 1305 Commenced RCS cooldown to 350' F to ef fect cleanup of the steam generators and condensate feedwater system due to chloride contamination.

January 5, 1501 Entered Mode 2.

January 5, 1519 Reached the +.5% AK/K CEA position without achieving criticality.

Inserted CEA's to -1.5% AK/K position for estimated critical position (E.C.P.) review.

January 5, 1535 Entered Mode 3.

January 5, 1700 Completed E.C.P. review. Diluted reactor coolant system 1,650 gallons (770 to 750 ppm) to support new E.C.P.

January 5, 1845 Entered Mode 2.

January 5, 1900 Reactor critical.

January 6, 0400 Entered Mode 1.

January 6, 0735 Synchronized generator and applied block load of 80 MWe gross.

January 7, 1845 Reactor power at 501, 9enerator load at M0 MWe gross.

Fifty percent power level testing has resumed.

January 17, 1040 Saltwater leak discovered in the northwest condenser waterbcx.

January 17, 1335 started turbine load reduction due to indication of saltwater leak in the southeast and southwest condenser waterboxes, norttmest hotwell already in overboard mode.

January 17, 1350 Tripped main turbine at 60 We from Control Room.

e 6

~

SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH OF JANUARY 1983 Page 3 of 4 January 17, 1400 Reactor tripped on high steam generator level t

(entered Mode 3).

January 17, 2045 Unit cooled down to 340 F.

January 18, 0432 Entered Mode 4.

January 18, 1440 Entered Mode 3.

January 19, 1225 Entered Mode 2.

January 19, 1335 Reactor critical.

January 20, 1140 Entered Mode 1.

January 20, 1921 Synchronized generator and applied block load of 80 MWe gross.

January 20, 2100 Manually tripped turbine generator due to a saltwater leak in the P-118 waterbox (southwest).

January 20, 2120 Entered Mode 2.

January 21, 1200 Tripped reactor due to a computer outage removing manual and sequential rod movement (entered Mode 3).

January 24, 1530 Entered Mode 2.

January 24, 1550 Reactor critical.

January 25, 0622 Entered Mode 1.

January 25, 0945 Synchronized generator and applied block load of 100 MWe gross.

January 25, 1115 Manually tripped turbine generator due to high chloride levels in the condensate system and steam generators.

January 25, 1145 Lowered reactor power to.5% (entered Mode 2).

January 26, 1016 Entered Mode 1.

January 26, 1255 Synchronized generator and applied block load.

January 27, 0750 Increased reactor power to 50%.

Generator load at 435 MWe gross.

l l

O

SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH OF JANUARY 1983 Page 4 of 4 January 30, 0656 Turbine manually tripped as part of " controlled" shutdown.

Steam bypass was actuated and a water hammer was experienced in the vicinity of the steam bypass valves.

Reactor tripped on high steam generator level (entered Mode 3).

January 30, 1413 Entered Mode 2.

January 30, 1430 Reactor critical.

January 30, 1456 Dropped Control Element Assembly (CEA) #79.

January 30, 1523 Dropped CEA #86.

January 30, 1531 CEA #86 at upper electrical limit.

January 30, 1542 Entered Mode 3.

January 30, 1603 CEA #79 at upper electrical limit.

January 30, 1737 Entered Mode 2.

January 30, 1757 Reactor critical, January 31, 2359 Unit is in Mode 2 at 0.5% reactor power.

L l

l I

1 l

REFUELING INFORMATION

~

DOCKET NO.

SONGS - 2 DATE February 15, 1983 COMPLETED BY L.Mayweather TELEPHONE 714/492-7700 Ext. 56223 1.

Scheduled date for next refueling shutdown.

Not yet determined 2.

Scheduled date for restart following refueling.

Not yet determined 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 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 l

6.

The number of fuel assemblies.

a)

In the core 217 b)

In the spent fuel storage pool.

0 800 7.

Licensed spent fuel storage capacity.

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 l

.... t 3,,,...,.

V 6

AC40- RA f

NRC MONTHLY OPERATING REPORT 50-362 DOCKET NO DATE February 15, 1983 COMPLETED BY L. Mayweather TELEPHONE 714/492-7700 Ext 56223 OPERATING STATUS San Onofre Nuclear Generating Station, Unit 3

1. Unit Name:

I anu

,I n ougn a danua y, M

2. Reporting Period:

3. Licensed Thermal Power (MW ):

ll27

4. Nameplate Rating (Gross MWe):

1087

5. Design Electrical Rating (Net MWe):

1127

6. Maximum Dependable Capacity (Gross MWe):

1087

7. Maximum Dependable Capacity (Net MWe):

8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since last Report. Give Reawns:

NA NA

9. Power Lesel To which Restricted.lf Any (Net MWe):

10. Reasons For Restrictions. lf Any:

Ifnit ic etill in initial etartun nhace nf tacting, This Month Yr.-to.Date Cumulatise 744 7aa 1877

11. Hours In Reporting Period 0

0 0

12. Number Of Hours Reactor has Critical 0

0 0

13. Reactor Resene Shutdown Hour, 0

0 0

14. Hours Generator On.Line 0

0 0

15. Unit Reserve Shutdown Hours 0

0 0

16. Gross Thermal Energy Generated (MWH)

O O

o 17 Gross Electrical Energy Generated (MWHI n

0 0

18. Net Electrical Energy Gserated IMhHI NA NA NA

19. Unit Senice Factor NA NA Na

20. Unit Availability Factor 0

0 n

l

21. Unit Capacity Factor IUsing MDC Netl 0

0 0

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

0

23. Unit Forced Outage Rate

24. Shutdowns Scheduled Oser Nest 6 MonthsIType.Date,and Duration of Eacht:

None i

25. If Shut Down At End Of Report Period. Estimated Date of Startup:

26. Units in Test Status IPrior to Commercial Operationi:

Forecast Achieved Under review INITIAL CRITICALITY Under review INITIA L ELECTRICITY Under review COMMERCIAL OPERATION p...o1 1,,.

...n.

.b

AVER AGE DAILY UNIT POWER LEVEL 50-362 DOCKET NO.

SONGS - 3 WIT DATE Februar_y 15, 1983 COMPLETED BY L_ Mayweather TELEPHONE 714/492-7700 Ext.

56223 MONTH JANUARY 1983 DAY AVER AGE DAILY POWER LEVEL DAY AVER AGE DAILY POWER LEVEL (MWe-Net)

(Mwe.Ne 3 0

0 1

37 0

0 2

,g 3

0 19 0

4 n

20 9

0 o

5 7,

6 0

22 n

7 0

23 o

0 8

24 0

9 0

25 0

10 0

26 0

II 0

22 n.

12 0

7g o

13 0

29 0

0 o

14 3g 15 0

31 0

s e, 0

esso (i) ni ns.en.

s 9'!

UNIT SHUTDOWNS AND POWER REDUCT10NS DOCKET NO.

UNIT NAME

~

DATE February I b, 1983 REPORT MONTH JANUARY 1983 COMPLETED BY L. Mayweather TELEPHONE 714/494-7700 Ext.56223

~.

C P0 Y

g g,'

lhte F

5!

55d

'~"'#'

U-cause a correttive

[*3 4

y.2 fgm Ewns 3,3 Action to o:

E 3 ifi j Repostsr v> v

}O Prevent Recurrente 6

NA NA NA NA

'NA NA NA NA NA I

2 1

4 I Forced Resuin -

Method.

linhihii F. Instructions S Scheduled A.I~quipment Failure (Explain) 1 Manual for Preparati.,n of Data fl. Maintenance of Test 7-Manual Scram.

Entrs Sheets l'or Iitensee C. Refueling

.t Automatic St ram.

I'veni Rep..n il I Ri l ele INi tRi t; D Regul.etors Restriction 4-Continuation from previous Olfill 1 Opes.es n Training & tisense I.xamination month F.Adnunistrative

5. Reduction of 20% or greater

"."oihee il splain tP"'""""'d"I'"'

I N"'"' I I S "" S"" '

li in the past 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 9.0ther (Explain)

...l.:.......i,.

SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH DOCKET NO.50-362 UNIT SONGS - 3 DATE February 15, 1983 COMPLETED BY L. Mayweather TELEPHONE 714/492-7700 Ext.56223 January 1, 0001 Unit is in Mode 5,180 F.

Preparations for entering Mode 4 are in progress.

January 5, 2149 Entered Mode 4.

January 15, 1530 Completed cold rod drop testing.

January 18, 1453 Entered Mode 3 January 23, 0119 Reactor coolant system at 545 F.

January 25, 2030 Discovered nitrogen leak in safety injection tank T-008.

January 25, 2105_

Commenced cooldown of reactor coolant system for Mode 4 entry.

January 25, 2123 Repressurized T-008 to 600 psig, stopped cooldown and exited action statement.

January 30, 0230 Commenced-hot rod drop testing.

January 31, 2359 Unit is in Mode 3 at 545 F.

Hot rod drop testing is in progress.

l esso (s) sei nse e, ire

-l REFUELING INFORMATION DOCKET NO.

50-362 UNIT SONGS - 3 DATE February 15, 1983 COMPLETED BY L. Mayweather TELEPHONE 714/492-7700 Ext. 56223 1.

Scheduled date for next. refueling shutdown.

Not yet determined.

2.

Scheduled date for restart following refueling.

Not yet determined.

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 detemined.

4.

Scheduled 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 l

operating procedures.

Not yet determined.

6.

The number of fuel assemblies, 217 a)

In the core 0

b)

In the spent fuel storage pool.

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.

....t. ), n.... n.

-