ML20207D628

Monthly Operating Repts for Aug 1986

ML20207D628
Person / Time
Site:	San Onofre
Issue date:	08/31/1986
From:	Siacor E SOUTHERN CALIFORNIA EDISON CO.
To:
Shared Package
ML20207D636	List: ML20207D628 ML20207D833
References
NUDOCS 8612310128
Download: ML20207D628 (14)

Text

E NRC MONTHLY OPERATING REPORT DOCKET NO. 50-361 UNIT SONGS - 2 DATE s,ncoms , is. ions COMPLETED BY E.'R. Siacor~

TELEPHONE (714) 368-6223 OPERATING STATUS

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

2. Reporting Period: August 1986

3. Licensed Thermal Power (MWt): 3390

4. Nameplate Rating (Gross MWe): 1127

5. Design Electrical Rating (Net MWe): 1070

6. Maximum Dependable Capacity (Gross MWe): 1127

7. Maximum Dependable Capacity (Net MWe): 1070

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

Since Last Report, Give Reasons:

NA

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

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

11. Hours In Reporting Period 744.00 5,831.00 26,640.00

12. Number Of Hours Reactor Was Critical 712.38_ 3,641.08 16,522.00

13. Reactor Reserve Shutdown Hours 0.00 0.00 0.00

14. Hours Generator On-Line 707.57 3,448.59 16,058.34

15. Unit Reserve Shutdown Hours 0.00 0.00 0.00

16. Gross Thermal Energy Generated (MWH) 2,322,090.63 10,789,885.56 51,520,271.69

17. Gross Electrical Energy Generated (MWH) 800,421.50 3,617,058.50 17,311,141.00

18. Net Electrical Energy Generated (MWH) 761,797.00 3,403,942.55 16,327,447.55

19. Unit Service Factor 95.10% 59.14% 60.28%

20. Unit Availability Factor 95.10% 59.14% 60.28%

21. Unit Capacity Factor (Using MDC Net) 95.69% 54.56% 57.28%

22. Unit Capacity Factor (Using DER Net) 95.69% 54.56% 57.28%

23. Unit Forced Outage Rate 4.90% 6.51% 5.76%

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

NA

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

26. Units In Test Status (Prior To Commercial Operation): Forecast Achieved INITIAL CRITICALITY NA NA INITIAL ELECTRICITY NA NA COMMERCIAL OPERATION NA NA 8612310128 DR 860e31 ADOCK 05000361 PDR 7435u/3 gj

m-

., ' AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-361 UNIT SONGS - 2 DATE September 15, 1986 COMPLETED BY E. R. Siacor TELEPHONE (714) 368-6223 MONTH August 1986 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net) 1 1100.21 17 976.38 2 1104.83 _ _ _

18 1106.63 3 1104.50 19 1106.38 4 1105.54 20 1106.92 5 1103.54 21 1105.25 6 1097.21 22 1095.13 7 1096_.42 23 1103.71 8 1092.75 24 1103.75 9 1095.88 25 1103.67 10 1093.58 26 1104.50 11 1091.75 27 1103.67 12 591.00 28 1102.88 13 0.00 29 1092.00 14 661.96 30 1097.58 15 1094.54 31 937.67 16 1107.67 7435u/4

UtilT SHUTDOWIIS AIIO POWER REDUCTIONS DOCKET 100. M-361 0011T NAIGE SMatts - 2 REPORT M00lTH AUGUST 1986 DATE sent =h r 15. 1986

. C000PLETED BY E. R. Slacor TELEPHOIIE f7141 Ma-Assa 1

i Method of Shutting -

3 Durat ion Down LER System Componens Cause & Corrective 1 1 2 3 4 4 Action to i No. Date Type (Hours)- Reason Reactor 10 0 Code Code. Prevent Recurrence 29 860812 F 36.43 A 3 86-022 JE N/A A reactor trip from 1005 power occurred when the floactor Coolant System (RCS) pressure reached the Core

• Protection Calculators (CPC) Auxillery Trip setpoint. The RCS pressure t rans ient resul ted f ree Ste i n Steam isolation Valve (MSIV) closure when a Main Steam Isolation Signal (MSIS) was genereted due to en apparent circuit 4

failure during surveillance testing of the MSIS Automatic Actuation Logic.

Extensive inspection and testing of" i

the Engineered Safety Features Actuation System (ESFAS) circuitry was l

Conducted, however, the condition I

could not be duplicated and a failed component could not be identified.

] Subsequently, siellar partial e

initiation of other ESFAS functional

) units with identical circuitry have j

occu rred, in these instances, replacement of coincidence logic relay ca rd s have rect i fied the pa rt ia l initiation condition. Since the cause of the actuation has not been identified, surveillance testing procedures and the design of the actuation circuitry are being reviewed to determine the cause and corrective action.

1 2 3 4 F-Fo rced Reason: Method: IEEE Std 803-1983 l S-Scheduled A-Equipment Failure (Explain) 1-Manual B-Maintenance or Test 2-Manual Scree.

C-RefueIing 3-Automatic Scram.

D-Regulatory Restriction- 4-Continuation f rom E-Operator Training & License Examination Previous Month F-Admin i st ra t ive 5-Reduction of 20%

i C-Ope ra t iona l Error (Explain) or greater in the

! H-Other (Explain) past 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

, 6-Other (Cxplain) i 7435u/5 i

+ - ,--r- -

e , 3 l

SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH I DOCKET NO. 50-361 1 UNIT' SONGS - 2 l

\

DATE September-15, 1986 COMPLETED BY E. R. Siacor s' TELEPHONE (714) 368-6223

t

-1.-

, -Date Time Eient August 1 0001 Unit is in Mode 1 at 99% reactor power.

Turbine load is 1145 MWe gross.

0512 Reactor power increased to 100%.

August 12 1330 Reactor tripped due to Reactor Coolant System pressure reaching the Core 1 Protec". ion Calculater Auxiliary Trip

' Setpoint. Unit is in Mode 3.

August 13 2025 Entered Mode 2.

, 2107 Reactor is critical.

2244 Entered Mode 1.

August 14 0153 Unit synchronized to the grid.

1855 Reactor power at 100%.

August 17 0830 ' Commenced power reduction for circulating water box P117 and P118 cleaning.

1130 Reactor power at 80%.

2130 Commenced power '9 crease to 100% following

-- completion of P117 and P118 circulating water box cleaning.

August 18 0020 Reactor power at 100%.

August 31 0400 Commenced power reduction to 85% for heat treating of the circulating water system.

0515 Reactor power at 85%.

s 2400 Unit is in Mode 1 at 85% reactor power.

Turbine load is 957 MWe gross. Heat treat operation in progrr.ss.

7435u/6

o REFUELING INFORMATION ,

DOCKET NO. 50-361 UNIT SONGS -- 2 DATE september 15, 1986 MONTH: August 1986 COMPLETED BY E. R. Siacor TELEPHONE ~(714) 368-6223

1. Scheduled date for next refueling shutdown.

January 1988

2. Scheduled date for restart following refueling.

April 1988

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 Applicable

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.

None

6. The number of fuel assemblies, a) In the core. 217 b) In the spent fuel storage pool. 160

7. Licensed spent fuel storage capacity. 800 Intended change in spent fuel storage capar.ity. Under Review

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

Approximately 1997 (refueling only)

Approximately 1993 (full offload capability) 7435u/7 i

NRC MONTHLY OPERATING REPORT DOCKET NO. 50-362 UNIT NAME SONGS - 3 DATE september 15. 1986 COMPLETED BY E. R. Siacor TELEPHONE (714) 368-6223 OPERATING STATUS

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

2. Reporting Period: August 1986

3. Licensed Thermal Power (MWt): 3390

4. Nameplate Rating (Gross MWe): 1127

5. Design Electrical Rating (Net MWe): 1080

6. Maximum Dependable Capacity (Gross MWe): 1127

7. Maximum Dependable Capacity (Net MWe): 1080 .

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

Since Last Report, Give Reasons:

NA

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

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

11. Hours In Reporting Period 744.00 5,831.00 21,191.00

12. Number Of Hours Reactor Was Critical 744.00 5,025.21 14,235.30

13. Reactor Reserve Shutdown Hours 0.00 0.00 0.00 14 Hours Generator On-Line 744.00 4,703.93 13,519.38

15. Unit Reserve Shutdown Hours 0.00 0.00 0.00

16. Gross Thermal Energy Generated (MWH) 2,221,739.30 14,739,997.29 39,885,184.63

17. Gross Electrical Energy Generated (MWH) 743,448.00 4.991,214.00 13,362,619.00

18. Net Electrical Energy Generated (MWH) 703,714_.00 4,699,789.00 12,507,134.42

19. Unit Service Factor 100.00% 80.67% 63.80%

20. Unit Availability Factor 100.00% 80.67% 63.80%

21. Unit Capacity Factor (Using MDC Net) 87.58% 74.63% 54.65%

22. Unit Capacity Factor (Using DER Net) 87.58% 74.63% 54.65%

23. Unit Forced Outage Rate 0.00% 14.56% 14.27%

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

Cycle 3 Refueling Outage, December 1, 1986 l

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

26. Units In Test Status (Prior To Commercial Operation): Forecast Achieved i INITIAL CRITICALITY NA NA l lNITIAL ELECTRICITY NA NA COMMERCIAL OPERATION NA NA I ,

! 7435u/8 l

. AVERAGE DAILY UNIT. POWER LEVEL DOCKET NO. 50-362 UNIT SONGS - 3 DATE september 15, 1986 COMPLETED BY E. R. Siacor-TELEPHONE (714) 368-6223 MONTH August 1986 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL '

-(MWe-Net) (MWe-Net) 1 1046.08 17 772.79 2 ___

844.54 18 1010.04 3 942.96 19 1035.42 4 1085.33 20 1028.58 5 1011.21 21 1032.67 6 781.17 22 1046.17 7 1051.46 23 1010.83 8 1013.29 24 1097.96 9 454.46 25 1096.71 10 376.08 26 1097.92 11 757.96 27 1060.25 12 1048.58 28 941.79 13 1013.33 29 916.46 14 1042.79 30 958.58 15 1017.17 31 958.46 16 770.38 7435u/9

UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-362 UNIT NAME SONGS - 3 REPORT MONTH AUGUST 1986 DATEBYSa L.premhar 15,_,,1986 COMPLETED R. Siacor TELEPHONE (714) 368-6223 Method of Shutting Du ra t ion Down LER System Component Cause & Corrective 1 2 3 4 4 Action to No. Date Type (Hours) Reason Reactor No. Code Code Prevent Recurrence 30 860806 S 0.00 0 5 N/A SG TBG Power reduction for condenser water box cleaning.

31 860809 S 0.00 B S N/A SG TBG Power reduction due to i nc rea s i ng condensate chlorides.

32 860816 S 0.00 B 5 N/A SG TBG Power reduction for condenser water box cleaning.

I 2 3 4 F - Fo rced Reason: Method IEEE Std 803-1983 S-Scheduled A-Equipment fa ilure ( Expla in) 1-Manual B-Ma intenance or Test 2-Manual Sc ra m.

C-RefueIing 3-Automatic Sc ram.

D-Regulatory Restriction 4-Continuation f rom E-Operator Tra ining & License Examination Previous Month F- Adm i n i s t ra t i ve 5-Reduction of 20%

G-Ope ra t i ona l Error (Expla in) or greater in the H-Other ( Expla in) past 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 6-Other ( Expla in) 7435u/10

1 .

SUMMARY

OF OPERATING-EXPERIENCE FOR THE MONTH DOCKET NO. 50-362 UNIT SONGS'- 3 DATE september is. 1986 COMPLETED BY E. R. Siacor TELEPHONE (714) 368-6223 Date Time Event August 1 0001 Unit is in Mode 1 at 78% reactor power.

Turbine load is 856 MWe gross.

2330 Reactor power increased to 100%.

' August 2 0100 Commenced power reduction to heat treat circulating water system.

0415 Reactor power at 80%.

August 3 Reactor power increased to 100% following 1715 completion of heat treating.

August 5 1727 Commenced power reduction to 80% for condenser water box cleaning.

2330 Reactor power further reduced to 62% for investigation of salt leak in pump P118.

August 6 2330 Reactor power increased to 80% following completion of salt leak investigation.

Condenser water box cleaning in progress.

August 7 0242 Commenced power increase following completion of condenser water box cleaning.

0615 Reactor power at 100%.

August 8 1130 Commenced power reduction to 97% power for operation within the condenser circulating water differential temperature limits.

2000 Reactor power reduced to 75% condenser water box cleaning.

August 9 0545 Reactor power reduced further to 65% due to increasing condensate chloride concentration.

0845 Reactor power increased to 75% following decrease in condensate chloride concentration.

1155 Reactor power reduced to 30% due to increasing condensate chloride concentration.

l 7435u/11 E.

s

SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH l' (Continued)

Date Time Event August 10 1820 Commenced power increase'following decrease in condensate chloride concentration.

August 11 0533 Reactor power at 76.5%.

0820 Commenced power reduction to 67% for northwest hotwell saltwater leak repair.

1720 Reactor power increased to 75% following repair of saltwater leak.

2025 Reactor power increased to 85%.

August 12 0700 Reacter power increased to 100%.

August 13 1700 Commenced power reduction for condenser water box cleaning.

1925 Reactor power at 80%.

August'14 0431 Commenced power increase following' completion of condenser water box cleaning.

0700 Reactor power at 100%.

August 15 1704 Commenced power reduction for condenser water box cleaning.

1948 Reactor power at 75%.

August 18 0001 Commenced power increase following completion of condenser water box cleaning.

0427 Reactor power at 100%.

1719 Commenced power reduction for condenser water box cleaning.

1845 Reactor power at 80%.

August 19 0500 Commenced power increase following condenser water box cleaning.

0646 Reactor power at 100%.

7435u/12

SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH (Continued)

Date Time Event August 20 1700 Commenced power reduction for condenser water' box cleaning.

1925 Reactor power at 75%.

August 21 0345 Commenced power increase following condenser ,

water box cleaning.

0621 Reactor power at 100%.

August 22 1730 Commenced power reduction to 80% for condenser water box cleaning and saltwater leak repair.

August 23 0100 Reactor power at 80%.

0610 Commenced power increase following condenser water box cleaning and saltwater leak repair.

l 0955 Reactor power at 100%.

. August 27 1725 Commenced power reduction to 90% power per Technical Specification for operation with main steam safety valve 3PSV-8408 gagged-shut.

August 28 1900 Reactor power further reduced to 80% for condenser water box cleaning.

August 29 1030 Reactor power increased to 90% following condenser water box cleaning.

August 31 2400 Unit is in Mode 1 at 90% reactor power.

Turbine load is 1006 MWe gross. Main steam safety valve 3PSV-8408 remains gagged shut until an outage of sufficient duration.

7435u/13

(

,- REFUELING INFORMATION DOCKET NO. 50-362 UNIT SONGS - 3 DATE September 15, 1986 MONTH: August 1986- COMPLETED BY E.'R. Stacor TELEPHONE (714) 368-6223

~

1. Scheduled date for next refueling shutdown.

November 28, 1986

2. Scheduled date for_ restart following refueling.

February 1987

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

No. All required Cycle 3 Amendments have been approved.

What will these be?

Not Applicable

4. Scheduled date for submitting proposed licensing action and supporting information.

Not Applicable

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.

None

6. The number of fuel assemblies, a) In the core. 217 b) In the spent fuel storage pool. 72

7. Licensed spent fuel storage capacity. 800 Intended change in spent fuel storage capacity. Under Review

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

Approximately 1997 (refueling only)

Approximately 1993 (Full offload capability) 7435u/14

q O

DESCRIPTION OF CHALLENGE TO MAIN STE#4 SAFETY YALVES (UNIT 2) l

ENCLOSURE On August 12,1986, at 1330, with Unit 2 in Mode 1 at 100% power, a reactor trip occurred when Reactor Coolant System (RCS) pressure reached the Core Protection Calculator (CPC) Auxiliary Trip Setpoint. The RCS pressure transient resulted from Main Steam Isolation Valve (MSIV) closure when.a Main Steam Isolation Signal (MSIS) was generated due to an apparent circuit failure during surveillance testing of the MSIS Automatic Actuation Logic.

Pressure in the secondary side of the Steam Generators (S/G) reached the setpoints of the safety valves causing the valves to open as designed. There are nine safety valves per main steam line, for a total of 18 safety valves.

The first safety valve is set to open at 1100 psia with succeeding valves opening one per additional 7 psia. Following the event, all 18 safety valves were examined and verified to have opened and closed as designed. The trip recovery proceeded normally and there were no safety consequences associated with this event. Additional information regarding this event is described in Licensee Event Report 86-022, Docket No. 50-361.

This report is submitted pursuant to 6.9.1.10 of Appendix A, Technical Specifications to Facility Operating License NPF-10 for San Onofre Unit 2.

7435u

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