ML20096F020

Monthly Operating Repts for Dec 1995 for Snp

ML20096F020
Person / Time
Site:	Sequoyah
Issue date:	12/31/1995
From:	Holllomon T, Shell R TENNESSEE VALLEY AUTHORITY
To:	NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
NUDOCS 9601230171
Download: ML20096F020 (13)

Text

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l Tennessee Valley Authortty, Post Omce Box 2000, Soddy-Daisy, Tennessee 37379-2000 l

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January 16, 1996 i

U.S. Nuclear Regulatory Commission ATTH: Document Control Desk Washington, D.C. 20555 Gentlemen In the Matter of

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Docket Nos. 50-327 Tennessee valley Authority

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50-328 SEQUOYAH NUCLEAR PLANT (SQN) - DECEMBER 1995 MONTHLY OPERATING REPORT Enclosed is the December 1995 Monthly Operating Report as required by SQN Technical Specification 6.9.1.10.

If you have any questions concerning this matter, please call J. W. Proffitt at (615) 843-6651.

Sincerely, 1

I R. H. Shell Manager SQN Site Licensing Enclosure cc: See page 2 230008 9601230171 951231 PDR ADOCK 05000327 6 AY R

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U.S. Nuclear Regulatory Commission-Page 2 January-16, 1996 y.-

cc (Enclosure):

INPO Records Center

' Institute of Nuclear Power Operations' 700 Galleria Parkway l

Atlanta, Georgia 30339-5957 5

I Mr. D. E. LaBarge, Project Manager i

U.S. Nuclear Regulatory Commission one White Flint, North 11555 Rockville Pike I

Rockville, Maryland 20852-2739 NRC Resident Inspector Sequoyah Nuclear Plant 2600 Igou Ferry Road Soddy-Daisy, Tennessee 37379-3624 Regional Administrator U.S. Nuclear Regulatory Commission Region II 101 Marietta Street, NW, Suite 2900 Atlanta, Georgia 30323-2711 i

.Mr. Joseph Santucci, Manager Advanced Reactor Department Electric Power Research Institute 3340 Hillview Avenue Palo Alto, California 94304 Mr. F. Yost, Director Research Services Utility Data Institute 1200 G Street, NW, Suite 250 Washington, D.C. 20005 l

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TENNESSEE VALLEY AUTHORITY SEQUOYAH NUCLEAR PIJutT MOItTHLY OPERATING REPORT 4

TO THE 4

NUCLEAR REGULATORY COMMISSION DECEMBER 1995 a

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UNIT 1 DOCKET NUMBER 50-327 1

LICENSE NUMBER DPR-77 6

UNIT 2 i

DOCKET NUMBER 50-328 LICENSE NUMBER DPR-79 l

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OPERATIONAL

SUMMARY

j DECEMBER 1995 t

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UNIT 1 Unit 1 generated 618,126 megawatthours (M'#h) (gross) electrical power l

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~during December with a capacity factor of 72.18 percent.

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on December'8, 1995,.at 2156 EST, the Unit I reactor was manually tripped j-after receipt of. low feedwater flow on the No. 4 steam generator. The

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No. 4 main reg. valve had an air leak. Repairs were made, and Unit 1 was 4 -

tied onlir.a on December 10 at 1321 EST.

Unit I reached 100 percent power

.on December 11, 1995.

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i On December 25, 1995, at 0713 EST, the Unit i reactor was manually T

tripped after receipt of numerous indications of electrical problems.

j The unit had received a Generator 1 Exciter Field Overcurrent alarm and was experiencing oscillating meter indications associated with the main generator excitation system, including meter indications that the l

electrical megawatt output on the main generator was fluctuating 100-150 l

megawatts. Control of the generator excitation system was lost and could

.not be regained. The root cause of this event was a field pole failure in the main generator exciter. The corrective action was to replace the exciter. Unit i remained in Mode 3 at the end of December with exciter work continuing.

j UNIT 2 Y

E Unit 2 generated 766,770 megawatthours (MWh) (gross) electrical power during December with a capacity factor of 89.93 percent.

I On December 21, 1995, with the unit operating at approximately 100 percent power, a manual reactor trip was initiated at 0627 EST when the condenser vacuum rose above the turbine trip setpoint. condenser vacuum increased when the three condenser circulating water pumps tripped

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as a. result of a switchyard fault. The cause of the event was a failure j.

of the C phase of a PCB in the switchyard. Examination of the breaker identified a latent defect in the ceramic insulator on the load side of i

l the center head assembly.

Based on the observed defect, it is postulated l,

that failure of this subassembly caused the main chamber porcelain to fail. This resulted in the breaker assembly falling. The plant side connector of the breaker came into contact with the operating rod of the

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I switch, causing a ground fault and electrical perturbation of other lines it in the switchyard. The breaker was isolated, and the unit was returned to service. Unit 2 was tied online on December 23 at 1951 EST.

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On December 23 at 2019 EST, the Unit 2 turbine tripped as a result of the actuation of the gas relay on the 28 main transformer. The gas relay actuation was caused by a low oil level in the transformer. The cause of the event was the failure to maintain proper oil level in the transformer. An evaluation of the transformer was performed, and it was determined that as a result of the low oil level no degradation of the transformer occurred. Oil was added to the transformer, and the transformer was returned to service. Additional corrective actions are being developed. Unit 2 was tied online again on December 24 at 1631 EST.

Unit 2 reached 100 percent power on December 26.

i Unit 2 was operating at near 100 percent reactor power at the end of December.

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AVERAGE DAILY UNIT POlmR LEVEL DOCKET NO.

50-327 UNIT No.

One DATE:

01-04-96 COMPLETED BYs T.

J.

Ho11omon TELEPHONE:

f615) 843-7528 MONTH:

DECEMBER 1995 AVERAGE DAILY POWER LEVEL AVERAGE DAILY POWER LEVEL Rh1 (MWe-Net)

Q&1 (MWe-Net) 1 719 17 1145 2

1123 18 1146 3

1123 19 1147 4

1146 20 1145 5

1148 21 1148 6

1149 22 1151 7

1147 23 1150 8

985 24 1145 9

-35 25 269 10 154 26

-33 11 992 27

-30 12 1144 28

-30 13 1145 29

-30 14 1144 30

-30 f

15 1142 31

-33 16 1146

o AVERAGE DAILY UNIT POWER LEVEL DOCKET No.

50-328 UNIT No.

Two DATE:

01-04-96 COMPLETED BY:

T.

J. Hollomon TELEPHONE:

f615) 843-7528 MONTH:

DECEMBER 1995 AVERAGE DAILY POWER LEVEL AVERAGE DAILY POWER LEVEL Q&1 (MWe-Net) ph1 (MWe-Net) 1 1151 17 1148 2

1148 18 1148 3

1149 19 1148 4

1149 20 1148 5

1149 21 235 6

1150 22

-35 1

7 1149 23

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8 1151 24 309 9

1152 25 480 10 1149 26 1124 i

11 1149 27 1153 12 1150 28 1156 4

13 1148 29 1159 14 1149 30 1158 s

15 1148 31 1158 16 1149

a OP! RATING DATA REPORT DOCKET NO.

50-327 DATE 01/04/%

1 COMPLETED BY T. J. Ho' lomon TELEPHONE (615) 84'.;-7528 1

OPERATING STATUS l Notes l

1.

Unit Name:

Seouovah Unit One l

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Reporting Period:

December 1995 l

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Licensed Thermal Power (Wt): 3411.0 l

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Nameplate Rating (Gross We): 1220.6 l

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Design Electrical Rating (Net We): 1148.0 l

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Maximum Dependable Capacity (Gross We): 1151.0 l

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Maximum Dependable Capacity (Net We): 1111.0 l

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If Changes Occur in Capacity Ratings (Item Numbers 3 Through 7) Since Last Report, Give Reasons:

9.

Power Level To Which Restricted, If Any (Net We):

N/A

10. Reasons For Restrictions, If Any:

N/A This Month Yr-t o-Dat e Cumulative

11. Hours in Reporting Period 744 8.760 127.129

12. Number of Hours Reactor Was Critical 553.7 6.842 4_

68.894

13. Reactor Reserve Shutdown Hours 0

0 0

14. Hours Generator On-Line 543.8 6. 62 2._1_,

67.226.4

15. Unit Reserve Shutdown Hours 0

0 0

16. Gross Thermal Energy Generated (MWH) 1.793.132.8 20.755.415.8 218.331.415

17. Gross Electrical Energy Generated (WH) 618.126 7.114.461 74.165.345

18. Net Electrical Energy Generated (HWH) 591.694 6.820.734 71.084.147

19. Unit Service Factor 73.1 75.6 52.9

20. Unit Availability Factor 73.1 75.6 52.9

21. Unit Capacity Factor (Using HDC Net) 71.6 70.1 50.3

22. Unit Capacity Factor (Using DER Net) 69.3 67.8 48.7

23. Unit Forced Outage Rate 26.9 8.2 34.6

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

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

January 2. 1996

OPERATING DATA REPORT DOCKET NO.

50-328 DATE 01/04/96 COMPLETED BY T. J. Holl omon TELEPHONE (615) 843-7528 OPERATING STATUS l Notes l

1.

Unit Name:

Seouovah Unit Two l

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Reporting Period: December 1995 l

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Licensed Thermal Power (MWt): 3411.0 l

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Nameplate Rating (Gross MWe): 1220.6 l

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Design Electrical Rating (Net MWe): 1148.0 l

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Maximum Deper.dable Capacity (Gross MWe): 1146.0 l

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Maximum Dependable Capacity (Net MWe): 1106.0 l

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If Changes Occur in Capacity Ratings (Item Numbers 3 Through 7) Since Last Report, Give Reasons:

9.

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

N//

10. Reason: For Restrictions, If Any:

N/A l

This Month Yr-to-Date Cumulative

11. Hours in Reporting Period 744 8.760 119.089

12. Number of Hours Reactor Was Critical 719.0 8.237.7 72.594

13. Reactor Reserve Shutdown Hours 0

0 0

14. Hours Generator On-Line 662.4 8.066.5 70.776.2

15. Unit Reserve Shutdown Hours 0

0 0

16. Gross Thermal Energy Generated (MWH) 2.227.837.1 27.014.132.7 224.541.596

17. Gross Electrical Energy Generated (MWH) 766.770 9.216.163 76.223.772 l

18. Net Electrical Energy Generated (MWH) 739.330 8.887.687 73.001.869

19. Unit Service Factor 89.0 92.1 59.4

20. Unit Availability Factor 89.0 92.1 59.4

21. Unit Capacity Factor (Using MDC Net) 89.8 91.7 55.4

22. Unit Capacity Factor (Using DER Net) 86.6 88.4 53.4

23. Unit Forced Outage Rate 11.0 7.9 32.9

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

U2C7 refuelina outaae is scheduled to beain on Aoril 19. 1996. with a duration of 55 days.

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

u_____________.__________.______

DOCKET NO:

50-327 UNIT SHUTDOWNS AND POWER REDUCTIONS IJNIT NAME:

One DATE:

01/03/ %

• REPORT MONTH: DECEMBER 1995 CDMPLETED BY:'

Hollamon TELEPHONE:i 615) 843-7528 Method of Licenste Cause and Corrective Duration Shutting Down Event Systy Comppent Action to I

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No.

Date Type (Hours)

Reason Reactor Report No.

Code Code Prevent Recurrence 9

951208 F

39.4 A

2 50-327/95017 SJ FCY On December 8, a manual reactor trip was initiated on Unit 1 as a result of a low level in the No. 4 steam generator. It was determined i

that an air line on the Loop 4 feedwater regulator valse was leaking and causing the feedwater regulator valve to drif t closed.

J The root cause of this event was a lack of controls for maintenance activities that affect vibration through system configuration changes. The configuration of 6,e four Unit i feedwater regulating valves was changed by installing new tubing and fittings. The appropriate procedures and/or program will he revised to address maintenance activities that affect l

vibrati,n through system configu-ration changes. The appropriate Maintenance pertonnel will be trained on the revised procedures /

program.

10 951225 F

160.8 A

2 50-327/95019 TL EXC On December 25, a manual reactor trip was initiated. The unit had received a Generator 1 Exciter Field Overcurrent alarm and was experiencing oscillating meter l

indications associated with the main generator excitation system, including meter indications that I: Forced Reason:

Method:

Exhibit G-Instructions 2

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F S: Scheduled A-Equipment 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 of Existing Outage (NUREG-1022)

E-Operator Training and License Examination 5-Reduction F-Administrative 9-Other 5

G-Operational Error (Explain)

Exhibit I-Same Source H-Other (Explain)

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DOCKET NO:

50-327-

-UNIT S M DOWNS AND POWER REDUCTIONS IAeIT NAME:

1)ne DATE:

01/33M6 REPORT IONTH: DECEPRER 1995 COMPLETED BY:T. J.

to'

' anon TELEPHONE:t615) 54'.l-7528 Method of Licensee Cause and Corrective Duration Shutting Down Event Systy C y ent Action to No.

Date Type (Hours).

Reason Reactor Report No.

Code Code -

Prevent Recurrence l

10 951225 F

160.8 A

2 50-327/95019 TL EXC (continued) the electrical megawatt output on il' the main generator was fluctuating 100-150 megawatts. The manual reactor trip was directed when the SOS determined that control of the generator excitation system had been lost and could not be regained. The root cause of this event was a field pole failure in the main generator exciter. The corrective action was to replace the exciter.

I: Forced Reason:

Method:

Exhibit G-Instructions 2

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F S: Scheduled A-Equipment 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 of Existing Outage (NUREG-1022)

E-Operator Training and License Examination 5-Reduction F-Administrative 9-Other S

G-Operational Error (Explain)

Exhibit I-Same Source H-Other (Explain)

DOCKET NO:

50-328 UNIT SHUTDOWNS AND POWER REDUCTIONS UNIT NAME:

Two DATE:

01/28/%

REPORT MONTH: DECEMBER 1995 C0FFLETED BY:T. 1.'to'

' anon -

TELEPHONE:(615)

B43-7528 Method of Licensee Cause and Corrective Duration Shutting Down Event Systy C

ent Action to No.

Date Type (Hours)-

Reason Reactor Report No.

Code Code Prevent Recurrence 7

951221 F

61.4 A

2 50-328/95007 FK BKR On December 21, at approximately 0627 EST, a manual reactor trip was initiated when the condenser vacuum rose above the tuttine trip setpoint. Condenser vacuum increased when the three condenser circulating water pumps tripped as a result of a switchyard fault.

The root cause of the event was the failure of the C phase of PCB 974 in the switchyard. Exami--

nation of the breaker identified a latent defect in the ceramic insulator on the load side of the center head assembly. Based on the observed defect, it is postulated that failure of this subassembly caused the main chamber porcelain to fail. This resulted in the breaker assembly falling, causing a ground fault and electrical perturbation of other lines in the switchyard. The breaker was isolated, and the unit was returned to service.

8 951223 F

20.2 A

N/A N/A N/A N/A On December 23, at 2019 EST, the Unit 2 turbine tripped as a result of the actuation of the gas relay on the 2B main transformer. The gas relay actuation was caused by i

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4 I: Forced Reason:

Method:

Exhibit G-Instructions F

S: Scheduled A-Equipment Failure (Explain) 1-Manual for Preparation of Data B-Maintenance or Test 2-Manual Scram Entry sheets for Licensee

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C-Refueling

. 3-Automatic Scram Event Report (LER) File D-Regulatory Restriction 4-Continuation of Existing Outage (NUREG-1022)

E-Operator Training and License Examination 5-Reduction F-Administrative 9-Other 5

G-Operational Error (Explain)

Exhibit I-Same Source H-Other (Explain) t

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DOCKET NO:

50-320 UNIV SHUTDOWS AND POWER REDUCTIONS UNIT NAME:

Two DATE:

01/08/ %

REPORT MONTH: DECEMBER 1995 COMPLEVED BY:T... Ho' lomon TELEPHONE:(615) 843-7528 Method of Licensee Cause and Corrective Duration Shutting Down Event Systp Compgnent Action to

[

No.

Date Type (Hours)

Reason Reactor Report No.

Code Code Prevent Recurrence I

8 951223 F

20.2 A

N/A N/A N/A N/A (continued) a low oil level in the transfonner.

The cause of the event was the failure to maintain proper oli level in the transformer. An eval-uation of the transformer was per-l formed, and it was determined that as a result of the low oil level, no degradation of the transformer occurred. Oil was added to the transformer, and the transfonner was returned to service. Addi-tional corrective actions are being developed.

I I: Forced Reason:

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2 F

Method:

Exhibit G-Instructions S: Scheduled A-Equipment Failure (Explain) 1 -Manual for Preparation of Data B-Maintenance or Test 2-Manual Scram Entry sheets for Licensee t

C-Refueling 3-Automatic Scram Event Report (LER) File D-Regulatory Restriction 4-Continuation of Existing Outage (NUREG-1022)

E-Operator Training and License Examination 5-Reduction F-Administrative 9-Other G-Operational Error (Explain) 5Exhibit I-Same Murce H-Other (Explain)