ML20215B998

Monthly Operating Repts for Jul 1986

ML20215B998
Person / Time
Site:	San Onofre
Issue date:	07/31/1986
From:	Morgan H, Siacor E SOUTHERN CALIFORNIA EDISON CO.
To:	NRC OFFICE OF RESOURCE MANAGEMENT (ORM)
References
NUDOCS 8610100020
Download: ML20215B998 (18)

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i NRC MONTHLY OPERATING REPORT DOCKET NO. 50-361 UNIT SONGS - 2 DATE Aunust 15. 1986 COMPLETED BY E. R. Stacor TELEPHONE (714) 368-6223 OPERATING STATUS

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

2. Reporting Period: July 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 5,087.00 25,896.00

12. Number Of Hours Reactor Was Critical ~

655.10 2,928.70 15,809.62

13. Reactor Reserve Shutdown Hours 0.00 0.00 0.00

14. Hours Generator On-Line 646.20 2,741.02 15,350.77

15. Unit Reserve Shutdown Hours 0.00 0.00 0.00

16. Gross Thermal Energy Generated (MWH) 2,127,171.21 8,467,794.93 49,198,181.06

17. Gross Electrical Energy Generated (MWH) 721,383.50 2,816,637.00 16,510,719.50

18. Net Electrical Energy Generated (MWH) 682,756.00 2,642,145.55 15,565,650.55

19. Unit Service Factor 86.85% 53.88% 59.28%

20. Unit Availability Factor 86.85* 53.88% 59.28%

21. Unit Capacity Factor (Using MDC Net) 85.76% 48.54% 56.18%

22. Unit Capacity Factor (Using DER Net) 85.76% 48.54% 56.18%

23. Unit Forced Outage Rate 13.15% 6.91% 5.80%

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

l NA 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 INITIAL ELECTRICITY NA NA COMMERCIAL OPERATION NA NA l

l 8610100020 860731 l PDR ADOCK0500g

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AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-361 UNIT SONGS - 2 DATE August 15, 1986 COMPLETED BY E. R. Stacor TELEPHONE (714) 368-6223 MONTH July 1986 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net) 1 1051.08 17 1107.88 2 1105.83 18 1103.54 3 1105.88 19 1105.00 4 900.33 20 1107.29 5 1087.42 21 1105.21 6 1098.67 22 1100.42 7 557.67 23 1095.42 8 0.00 24 __

1094.58 9 0.00 25 1066.67 10 7.71 26 1076.13 11 867.29 27 1088.83 12 1105.71 28 1104.79 13 1105.21 29 1096.46 14 381.29 30 1085.17 15 666.83 31 1050.42 16 1108.50 7435u/4

UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-361 UNIT NAME SONGS - 2 REPORT MONTH JULY 1986 DATE August 13. 195b COMPLETED BY E. R. Slacor TELEPHONE ( 7141 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 27 860707 F 77.48 A 3 86-018 AA CHU The reactor tripped from 47% power on XCT Departure from Nucleate Boiling Ratio /

OB Local Power Density (DNBR/LPD) as a SCR result of misalignment penalty factors generated by the Core Protection Calculators (CPC) when Control Element Assembly (CEA) 49 dropped to its fully inserted position in addition to CEA 55 that had dropped previously.

CEA 55 dropped due to electrical shorts in two silicon controlled rec t i f ie rs (SCR) in the power switch assembly caused by failure of an optical i sola tor ca rd. The optical isolator ca rd appa rently fa iled due to over-heating since one of the Control Element Drive Mechanism Control System (CEDMCS) coolers railed and one was out of service for maintenance. The failed CEDMCS cooler was returned to se rvice, failed SCR and optical isolator card were replaced and all other CEA circuitry was inspected for evidence of overheating and checked for proper operation. CEA 49 dropped due to fa ilure of a DC current senser for a CEDM gripper coil causing misoperation of the CEA timer. The fa iled sensor was replaced. Investiga-tion into the design of the DC current sensor and its relationsh:p with the CEA timer microprocessor sof twa re logic to determine appropriate long term corrective action, is planned.

1 2 3 4 F- Fo rced Reason: Method: IEEE Std 803-1983 S-Scheduled A-Equipment Fa i lure ( Expla in) 1-Manual B-Ma intenance or Test 2-Manual Sc ram.

C-Refueling 3-Automa tic Scram.

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

G-Ope ra t i ona l Error (Explain) 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 ( Explain) 7435u/5 e

. . . . - - _ _ . ~ ._- -.__=. . . .

UNIT SHUTDOWNS AND POWER REDUCTIONS REPORT MONTH JULY 1986 (Continued)

Method of Shutting Du ra t i on Down LER System Component Cause & Corrective 1 2 3 4 4 Action to No. Date Type (Hours) Reason Reactor No. Code Code Prevent Recurrence 28 860714 F 20.32 A 3 86-019 JM RLY A reactor trip f rom 100% power occurred when the Reactor Coolant System (RCS) pressure reached the Core Protection Calculators (CPC) Auxilia ry Trip setpoint. Closure of the Main Steam isolation Va lves (MSIVs) caused the pressu e transient which was due to a T ra i n ' B' Containment isolatica Actuation Signal (CI AS) generated by a relay related fa ilure during -

surveil lance testing. Examination revealed contacts on auxiliary relay 3B were pitted, causing a high

. resistance and preventing full current

flow through the circuit. The relay 4

was replaced, tested satisfactorily and returned to service. Inspection and cleaning of the trip path auxilia ry relay contacts will be performed during subsequent refue l ing outages.

1 1

1 4 1 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 ram.

C-Refueling 3-Automatic Sc ram.

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

C-Ope ra t iona l Error (Explain) or greater in the H-Othe r ( 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/6

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SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH DOCKET NO. 50-361 UNIT SONGS - 2 DATE August 15, 1986 COMPLETED BY E. R. Siacor TELEPHONE (714) 368-6223 Date Time Event July 1 0001 Unit is in Mode 1 at 85% reactor power.

Turbine load is 940 MWe gross. Southwest condenser water box cleaning in progress.

0816 Reactor power increased to 100%.

July 4 0435 Control Element Assembly (CEA) 84 dropped into the bottom of the core.

0608 Commenced power reduction to withdraw CEA 84 from the bottom of the core.

0700 Reactor power at 60%.

0715 CEA 84 fully withdrawn and declared operable.

0815 Commenced reactor power increase.

0908 Reactor power at 85%. Condenser water box cleaning in progress.

l 2138 Commenced reactor power increase following completion of condenser water box cleaning.

July 5 0001 Reactor power at 100%.

July 7 1008 CEA 55 dropped into the bottom of the core.

1018 Commenced power reduction in accordance with Technical Specification Action Statements.

l 1105 Reactor power at 70%.

l 1403 Reactor power further reduced to 47%.

j 1408 Reactor tripped when CEA 49 dropped into the bottom of the core. Unit is in Mode 3.

7435u/7

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SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH (Continued)

Date Time Event July 8 0230 Unusual Event (UE) declared due to seismic activity.

0450 UE terminated.

July 10 1222 Entered Mode 2.

1250 Reactor is critical.

1457 Entered Mode 1.

1937 Unit synchronized to the grid.

July 11 1240 Reactor power at 100%.

July 13 0705 UE declared due to seismic activity.

0801 UE terminated.

July 14 0858 Reactor tripped due to failed relay in Train 'B' Containment Isolation Actuation System. Unit in Mode 3.

July 15 0245 Entered Mode 2.

0310 Reactor is critical.

0323 Entered Mode 1.

0517 Unit synchronized to the grid.

1325 Reactor power at 100%.

July 25 1603 Reactor power reduced to 93% due to dropped CEA 83.

1633 CEA 83 fully withdrawn and declared operable.

l 2350 Reactor power increased to 98% for moderator temperature coefficient surveillance test.

l July 27 1520 Reactor power at 100%.

I July 29 2300 CEA 44 dropped into the bottom of the core. Reactor power reduced to 82%.

2345 CEA 44 fully withdrawn and declared operable.

July 30 0415 Reactor power increased to 100%.

7435u/8 1

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SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH (Continued.)

Date Time Event July 31 1045 CEA 45 dropped into the bottom of the core.

1055 Commenced power reduction due to misaligned CEA and for monitoring azimuthal power tilt per Technical Specifications.

1135 Reactor power at 69%.

1218 CEA 45 fully withdrawn and declared operable.

1320 Commenced power increase.

2400 Unit is in Mode 1 at 99% reactor power.

Turbine load is 1145 MWe gross.

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7435u/:s

REFUELING INFORMATION DOCKET NO. 50-361 UNIT SONGS - 2 DATE A,, g,, e is. 1986 MONTH: July 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 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/10

NRC MONTHLY OPERATING REPORT DOCKET NO. 50-362 UNIT NAME SONGS - 3 DATE August 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: July 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 5,087.00 20,447.00

12. Number Of Hours Reactor Was Critical 726.62 4,281.21 13,491.30

13. Reactor Reserve Shutdown Hours 0.00 0.00 0.00

14. Hours Generator On-Line 714.67 3,959.93 12,775.38

15. Unit Reserve Shutdown Hours 0.00 0.00 0.00

16. Gross Thermal Energy Generated (MdH) 2,129,940.65 12,518,257.99 37,663,445.33

17. Gross Electrical Energy Generated (MWH) 751,978.00 4,247,766.00 12,619,171.00

18. Net Electrical Energy Generated (MWH) 712,797.00 3,996,075.00 11,803,420.42

19. Unit Service Factor 96.06% 77.84% 62.48%

20. Unit Availability Factor 96.06% 77.84% 62.48%

21. Unit Capacity Factor (Using MDC Net) 88.71% 72.74% 53.45%

22. Unit Capacity Factor (Using DER Net) 88.71% 72.74% 53.45%

23. Unit Forced Outage Rate 3.94% 16.83% 14.98%

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

Cycle 3 Refueling Outage, November 28, 1986 l

l 25. If Shut Down At End Of Report Period, Estimated Date of Startup: NA l 26. Units In Test Status (Prior To Commercial Operation): Forecast Achieved INITIAL CRITICALITY NA NA INITIAL ELECTRICITY NA NA COMMERCIAL OPERATION NA NA i

7435u/11 l

1 AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-362 UNIT SONGS - 3 DATE August 15, 1986 COMPLETED BY E. R. Stacor TELEPHONE (714) 368-6223 MONTH July 1986 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net) 1 1107.00 17 1062.50 2 1103.79 18 1080.63 3 1088.50 19 962.79 4 1089.29 20 1108.67 5 1096.83 21 1104.42 6 881.63 22 1102.63 7 901.29 23 1075.58 8 899.92 24 1073.29 9 907.08 25 1061.00 10 1053.88 26 306.63 11 1051.58 27 178.88 12 913.79 28 914.50 13 1047.25 29 282.13 14 1099.25 30 932.46 15 1104.92 31 1046.00 16 1061.79 7435u/12 l

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UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-362 UNIT NAME SONGS - 3 REPORT MONTH JULY 1986 DATE August 13. 1956 COMPLETED BY E. R. Siacor TELEPHONE (7141 368-6223 Method of Shutting Dura t ion Down LER System Component Cause & Corrective 1 2 3 4 4 Action to No. Date Type (Hours) Reason Reac to r No. Code Code /revent Recurrence 28 860726 F 29.33 A 2 86-010 SJ P The reactor was manually tripped due to loss of main feedwater, investigation into the cause is continuing. The results of the investigation and appropriate corrective actions to be taken will be addressed in LER 86-010.

29 860729 S 0.00 A 5 N/A SJ SHV Powe r reduct i on to remove ma i n feedwater block va lve 3HV-4051 f rom service for N2 leak repa i r of hydraulic dump va lve.

1 2 3 4 F-Fo rced Reason: Method: IEEE Std 803-1983 S-Scheduled A-Equipment Fa i l u re ( Exp la in ) 1-Manual B-Maintenance or Test 2-Manual Sc ra m.

C-Refueling 3-Automa tic Scram.

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

G-Ope ra t iona l Error (Explain) 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/13

SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH DOCKET NO. 50-362 UNIT SONGS - 3 DATE August 15, 1986 COMPLETED BY E. R. Stacor TELEPHONE (714) 368-6223 Date Time Event July 1 0001 Unit is in Mode 1 at 100% reactor power.

Turbine load is 1152 MWe gross.

July 6 0100 Commenced power reduction for heat treat and condenser water box cleaning.

1025 Reactor power at 85%

July 8 0230 Unusual Event (UE) declared due to seismic activity.

0450 UE terminated.

July 10 0315 Commenced power increase following completion of heat treat and condenser water box cleaning.

0800 Reactor power at 100%.

July 11 1615 Commenced power reduction for condenser water box cleaning and turbine overspeed valve testing.

1859 Reactor power at 85%.

July 13 0515 Commenced power increase.

0705 UE declared due to seismic activity.

0801 UE terminated.

July 15 0950 Reactor power at 100%.

July 16 1707 Commenced power reduction for condenser water box cleaning.

1928 Reactor power at 85%.

7435u/14

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SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH (Continued)

Date Time Event July 17 0451 Commenced power increase following completion of condenser water box cleaning.

0615 Reactor power at 100%.

July 18 1920 Commenced power reduction for weekly main turbine stop/ governor valve testing and circulating water pump P115 cleaning.

July 19 0428 Reactor power at 85%.

1800 Reactor power increased to 100% following completion of turbine stop/ governor valve testing and return of P115 to service.

July 23 2030 Reactor power reduced to 97% to maintain circulating water differential temperature within discharge permit limit.

July 25 2215 Reactor power reduced to 80% for condenser water box cleaning.

July 26 0929 Reactor was manually tripped due to loss of main feedwater. Unit is in Mode 3.

July 27 0157 Entered Mode 2.

0252 Reactor is critical.

1203 Entered Mode 1.

1449 Unit synchronized to the grid.

l July 28 0140 Reactor power at 85%. Repairs to condenser i saltwater leak in progress.

i 1109 Commenced reactor power increase following j completion of condenser saltwater leak repairs.

l 1520 Reactor power at 97%.

l 2000 Commenced power reduction for removal of main feedwater block valve 3HV-4051 from service for nitrogen leak repair on the hydraulic dump valve.

I L

7435u/15 L a

SUMMARY

OF OPERATING EXPERIENCE FOR THE MONTH (Continued)

Date Time Event July 29 0930 Reactor power at 18%.

1145 Commenced power increase following completion of repairs to 3HV-4051 hydraulic dump valve.

July 30 1500 Reactor at 100%.

July 31 1804 Commenced power reduction to 78% for condenser water box cleaning.

2400 Unit is in Mode 1 at 78% reactor power.

Turbine load is 856 MWe gross.

1 l

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7435u/16

REFUELING INFORMATION DOCKET N0. 50-362 UNIT SONGS - 3 DATE August 15, 1986 MONTH: July 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 I

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/17 4

6 e

DESCRIPTION OF CHALLENGE To SAFETY VALVES (UNIT 2) r

ENCLOSURE On July 14, 1986, at 0858, 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 Setpoint. Closure of the Main Steam Isolation Valves (MSIV) caused the pressure transient and was due to a Train 'B' Containment Isolation Actuation Signal (CIAS) generated by a relay failure during surveillance testing.

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. Immediately following the event, the safety valves were examined and verified that all 18 safety valves 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 86-019, 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.

l

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,J"*uY?

Southem Califomia Edison Company SAN ONOFRE NUCLEAR GENERATIPG STATION P. O. Box 128 SAN CLEMENTE, CALIFORNIA 92672 H E. MORGAN TELEPHONE erario= =*=acEa August 15, 1986 mo m eni Director Office of Resource Management U. S. Nuclear Regulatory Commission Washington, D.C. 20555

Subject:

Docket Nos. 50-361/50-362 Monthly Operating Reports for July 1986 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.

Also, enclosed is a description of a challenge to Unit 2 main steam safety valves which occurred on July 14, 1986.

Please contact us if we can be of further assistance.

Sincerely, M k.M Enclosures cc: J. B. Martin (Regional Administrator, USNRC Region V)

F. R. Huey (USNRC Senior Resident Inspector, Units 1, 2 and 3)

Institute of Nuclear Power Operations (INPO)

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