ML20050C769

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Monthly Operating Repts for Aug 1981
ML20050C769
Person / Time
Site: Sequoyah  Tennessee Valley Authority icon.png
Issue date: 09/03/1981
From: Eddings M
TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML20050C768 List:
References
NUDOCS 8204090341
Download: ML20050C769 (16)
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9 TENNESSEE VALLEY AUTHORITY DIVISION OF NUCLEAR POWER

) SEQUOYAH NUCLEAR PLANT MONTHLY OPERATING REPORT

) AUGUST 1, 1981 - AUGUST 31, 1981 l

UNIT 1 DOCKET NUMBER 50-327 LICENSE NUMBER DPR-77 h

UNIT 2 DOCKET NUMBER 50-328 LICENSE NUMBER DPR-79 Submitted By: ,s O A h b bl Nr Pfwer Plant Superintendent.V

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8204090341 810911 PDR R

ADDCK 05000327 PDR

b TABLE OF CONTENTS i J

Operations Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 Significant Operational Events . . .... . . . . . . . . . . . . . . . . 1 l PORV's and Sa fety Valves Summa ry . . . . . . . . . . . . . . . . . . . . . 3 Licensee Events and Special Reports ... ...... . . . . . . . . . . 3-4 4

Offsite Dose Calculation Manual Changes ...... . . . . . . . . . . . .

5 Operating Data 6-8 4

Unit 1 . . . . . . . . . .. ..... . . . . . . . . . . . . . . .

! Unit 2 . . . . . . . . . .. .... . . . . . . . . . . . . . . . . 9-11 j Plant Maintenance Summary . .. . .... .... . . . . . . . . . . . . . 12

! Outage Ma intenance Summa ry . . . . . . . . . . . . . . . . . . . . . . . 12-14 i

s 5

4 i

I 5

a 4

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,y, _ , . . - , , - . , , , . , - - - . , . . . - --m-- ,- - - -- -., - - - --- - _ ,.- .-, _ _ , . . - . . . - , - - - -

Operations Summary AUGUST, 1981 The following summary describes the significant operational activities for the month of August. In support of this summary, a chronological log of significant events is included in this report.

Unit 1 Uni". I was critical for 496.6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, produced 501,970 MWH (gross) with 4.98 percent station use, resulting in an average hourly gross load of 1,038,845 KW during the month. The net heat rate for the month was 11,100 BTU /KWH.

There are 237.6 full power days estimated remaining until the end of cycle 1 fuel. With a capacity factor of 85 percent the target EOC exposure would be reached June 6, 1982. The capacity factor for the month was S7.0 percent.

There was one reactor scram, one manual shutdown, and three power reductions during August.

Unit 2 Preoperational and pre-criticality testing continued during the month.

Significant Operational Events Unit 1 Date Time Event 08/01/81 0001 Reactor in mode 1 at 100% power producing 1100 MWe.

08/07/81 2000 Began manual shutdown to repair steam Icaks.

2214 Turbine tripped off line.

2230 Reactor entered mode 2.

08/08/81 2220 Reactor entered mode 5.

08/16/81 2348 Reactor entered mode 4.

_1

- Significant Operational Events Unit 1 (Continued) l i

Date Time Event j 08/18/81 0202 Reactor taken critical.

1155 Reactor tripped when FCV-3-103A failed close, resulting in a low steam generator level in loop 4.

The reactor was at 1% power.

1 1530 Reactor taken critical.

3 1902 Turbine tied on line.

l I 2200 Reactor holding at 30% for steam generator chemistry to come into specification.

l 08/19/81 1530 Reactor at 100% power producing l 1100 MWe.

, 08/23/81 1520 Turbine load reduced to 50% when i letdown was lost due to valve 62-81 closing causing RV-62-662 to lift.

08/24/81 0550 Starting increasing load - repairs j completed on letdown.

! 1420 Reactor at 100% power.

08/29/81 2030 Turbine load reduced to E 70% power for repairs on Condensate Booster Pump 1B.

08/30/81 0730 Repairs to CBP IB completed.

4 1100 Reactor at 100% power.

08/31/81 1002 Two condenser circulating water pumps out of service - reactor power reduced to 30%.

1010 Condenser backpressure satisfactory.

Reactor power increased to 90%.

2359 Reactor in mode 1, 90% power pro-l ducing 971 MWe.

l

Significant Operational Events Unit 2 (Continued)

Date Time Event 08/01/81 0001 Reactor in mode 5.

08/06/81 0854 Containment sump suction valve FCV-74-72 inadvertently opened while RJIR pump suction valve closed. Approximately 5 inches water dumped into lower containment.

08/23/81 0100 Reactor entered mode 4.

08/25/81 0440 Reactor entered mode 3.

08/31/81 2359 Reactor in mode 3 at 547 F and 2235 psig.

PORV's and Safety Valves Summary No PORV's or safety valves were challenged during the month.

Licensee Events and Special Reports The following Licensee Event Reports (LER's) were sent during August, 1981, to the Assistant Director of Nuclear Power (Operations) for reporting to the Nuclear Regulatory Commission.

SQRO-50-327/078 D/G 1A-A inoperable when two relief valves were removed from service in the ERCW system.

SQRO-50-327/082 Ice condenser ice bed temperature excceded 27'F.

SQR0-50-327/083 Control building emergency air clean-up system train A inoperable due to failure to meet 99% methyl iodine removal efficiency.

SQRO-50-327/086 Pressurizer pressure transmitter 1-PT-68-354 out of calibration.

SQRO-50-327/087 Shield building exhaust rad monitor inoperable due to failed shaft on moving filter.

Licensee Events and Special Reports (Continued)

SQRO-50-327/088 Ice condenser inlet doors open due to high differential pressure.

SQR0-50-327/089 Rod position indicator for shutdown rod G13 and B12 indicated fully inserted with rods fully withdrawn.

SQRO-50-327/090 Rad monitor 0-RM-90-122 inoperable due to contaminated chamber.

SQR0-50-327/092 AFW level' control valve 1-LCV-3-164 in-operable due to clogged metering orifice.

SQRO-50-327/093 1-LCV-3-164A failed to respond rendering 1A-A AFW train inoperable.

SQRO-50-327/095 Shaft seal on ERCW strainer IB-B failed.

SQRO-50-327/096 Containment purge isolation valves 1-FCV-30-56, -57, -37, and -40 not tested within time requirements.

SQR0-50-327/097 Main steam line hanger could damage ERCW piping during line break.

SQRO-50-327/098 Ice condenser temperature recorder inoperable due to faulty selector switch.

SQR0-50-327/099 RHR check valve 1-74-514 and -515 not tested within 92 day requirements.

SQR0-50-327/100 RCS average temperature dropped below 541*F due to secondary side steam load during controlled shutdown.

SQRO-50-328/091 Train A and Train B source range detectors inoperable.

SQR0-50-328/094 During SI-9, primary water drained into sump due to reversed relay contacts.

Special Reports No special reports were sent during the month of August.

/

Offsite Dose Calculation Manuel Changes There were no changes in the Sequoyah Nuclear Plant ODCM during the month.

4 AVERAGE DAILY UNIT POWER LEVEL DOCET NO. 50-327 UNIT SEQUOYAH 1 DATE AUGUST, 1981 COMPLETED BY MIKE EDDINGS

- TELEPHONE (615) 842-0295 I

MONTH AUGUST, 1981 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net)

I 1074 17 0 2 1078 18 23 3 1077 19 685 4 1078 20 1069 5 1078 21 1070 6 1078 22 1071 4.

i 7 939 23 910

) 8 0 24 849 I

9 0 25 1062 _

10 0 26 1068 11 0 27 1059 12 0 28 1046 13 0 29 1013 14 0 30 958

15 0 31 807  !

16 0 INSTRUCTIONS

! On this format, list the average daily unit power level in MWe-Net for each day in the reporting month. Compute to the nearest whole megawatt.

(9/77) t  :

1 i

. OPERATING DATA REPORT DOCKET NO. 50-327 DATE 9/1/81 COMPLETED BY MIKE EDDINGS

~

TELEPIIONE (615) 842-0295 OPERATING STATUS

1. Unit Name: Sequoyah One Notes
2. Reporting Period: August, 1981
3. Licensed Thermal Power (MWt): 3411
4. Nameplate Rating (Gross MWe): 1220.58
5. Design Electrical Ratir.g (Net R9e): 1128
6. Maximum Dependable Capacity (Gross MWe): 1163
7. Maximum Dependable Capacity (Net MWe): 1128 ~
8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons:
9. Power Level To Which Restricted, If Any (Net MWe):
10. Reasons For Restrictions, If Any: ,

This Month Yr-to-Date Cumulative

11. Ilours in Reporting Period 744 1488 1488
12. Number of Ilours Reactor Was Critical 496.6 1079.4 1079.4 0 0 0
13. Reactor Reserve Shutdown liours
14. Ilours Generator On-Line 483.2 1028.2 1028.2 0 0 0
15. Unit Reserve Shutdown llours
16. Gross Thermal Energy Generated (MWil) 1,549,085L ~~3,252,320_ 3,252,320
17. Cross Electrical Energy Generated (MW11) 501,970_ 1,060,760 1,060,760
18. Net Electrical Energy Genc rated (MWII) 478,176 1,013,703 1,013,703
19. Unit Service Factor 64.9 69.1 69.1
20. Unit Availability Factor 64.9 69.1 _

69.1

21. Unit Capacity Factor (Using MDC Net) 57.0 60.4 60.4
22. Unit Capacity Factor (Using DER Net) 57.0 60.4 60.4
23. Unit Forced Outage Rate 35.1 30.9 30.9
24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):

Sept., 1981 Tech. Spec. Ice Weighing & Containment Isolation Valve Testing 27 Days

25. If Shut Down At End Of Report Period, Estimated Date of Startup:
26. Units In Test Status (Prior to Commercial Operation):

Forecast Achieved INITIAL CRITICALITY 7/4/80 7/5/80 INITIAL ELECTRICITY 8/21/80 7/22/80 COMMERCIAL OPERATION 7/1/81 7/1/81 (9/77)

UNIT SIIUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-327 -

UNIT NAME sequoyah one DATE __ August, 19s1 COMPLETED BY nike Eddings REPORT MONT11 August, 1981 TELEPHONE b15-542-029) _

i e ,,, u o ec 3 Licensee $ Cause & Corrective No. Date "a f. 5 o .5 g Event @% 8"o g

H yg y j$j Report # %3 8.3 Action to Prevent Recurrence

$5 $ U5c N" $"

c zmg u a

2 81/08/07 F 260.8 B 1 Repair Steam Leaks 1 81/08/23 F 0 A 4 Letdown Relief Valve Replaced 2 81/08/29 F 0 A 4 Maintenance on Condensate Booster Pump c'n 3 81/08/31 F 0 A 4 (2) Condenser Circulating Water Pumps Taken Out of Service for Maintenance 6

1 1 2 3 4 F: Forced Reason: 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 C-Refueling 3-Automatic Scram. Event Report (LER) File (NUREG-i D-Regulatory Restriction 4- Con t , of Existing 0161)

E-Operator Training & License Examination Outage F-Administrative 5-Reduction G-Operational Error (Explain) 9-Other 5 (9/77)'- H-Other (Explain) Exhibit I-Same Source

i AVERAGE DAILY UNIT POWER LEVEL

! DOCKET liO. 50-328 UNIT SEQUOYAll 2 DATE 9/3/81 COMPIETED BY MIKE EDDINGS TELEPHONE (615) 842-0295 i

NONTH AUGUST, 1981 i

DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net)

J ,

1 0 17 0

, 2 0 18 0 3 0 19 0 i -

4 0 20 0 5 0 21 0 6 0 22 0 7 0 23 0 8 0 24 0 9 0 25 0 10 0 26 0 11 0 27 0 i

12 0 28 0 13 0 29 0 14 0 30 0 15 0 31 0 16 0 i

INSTRUCTIONS On this format, list the average daily unit power level in MWe-Net for each day in the reporting month. Compute to the nearest whole megawatt.

(9/77) q.

OPERATING DATA REPORT DOCKET NO. 50-328 DATE 9/3/81 COMPLETED BY MIKE EDDINGS TELEPHONE (615) 842-0295 OPERATING STATUS

1. Unit Name: Sequoyah Two Notes
2. Reporting Period: August, 1981
3. Licensed Thermal Power (MWt): 3411
4. Nameplate Rating (Gross MWe): 1220.58
5. Design Electrical Rating (Net NWe): 1148
6. Maximum Dependable Capacity (Gross MWe): 1183
7. Maximum Dependable Capacity (Net MWe): 1148
8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons:
9. Power Level To Which Restricted, If Any (Net MWe): Five Percent Power
10. Reasons For Restrictions, If Any: Low Power License (5%) Granted By The FRC ,

for Start-Up and Low Power Testing This Month Yr-to-Date Cumulative

11. Hours in Reporting Period N/A N/A N/A
12. Number of Hours Reactor Was Critical N/A N/A N/A
13. Reactor Reserve Shutdown Hours N/A N/A N/A
14. Hours Generator On-Line N/A N/A N/A
15. Unit Reserve Shutdown Hours N/A N/A N/A
16. Gross Thermal Energy Generated (MWH) N/A N/A N/A
17. Gross Electrical Energy Generated (MWH) N/A N/A N/A
18. Net Electrical Energy Generated (HWH) N/A N/A N/A
19. Unit Service Factor N/A N/A N/A
20. Unit Availability Factor N/A N/A N/A
21. Unit Capacity Factor (Using MDC Net) N/A N/A N/A
22. Unit Capacity Factor (Using DER Net) N/A N/A N/A
23. Unit Forced Outage Rate N/A N/A N/A
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:
26. Units In Test Status (Prior to Commercial Operation):

Forecast Achieved INITIAL CRITICALITY 9/4/81 --N/A INITIAL ELECTRICITY 9/14/81 N/A COMMERCIAL OPERATION 12/1/81 N/A (9/77)

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

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UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-328 s UNIT NAME sequoyen Iwo DATE 9 i-51 '

COMPLETED BY mRe taaings '

REPORT MONTit August, 1981 TELEPIIONE 613-54Z-ve93 ,

1 em N o oc Licensee $ Cause & Corrective No. Date  % 3$ $ ej% Event $$ E*o Action to g yg y j"y Report # $3 8.3 Prevent Recurrence H *

$5 $ USc m"  !"

a xmg u c

31/08/01 S 744 B 4 Pre-Criticality Testing & Maintenance 4

e i

r

! 1 2 3 4 i F: Forced Reason: Method: '

Exhibit G-Instructions a

S: Scheduled A-Equipment Failure (Explain) 1-Manual for Preparation of Data B-Haintenance or Test 2-Manual Scram. Entry Sheets for Licensee C-Refueling 3-Automatic Scram. Event Report (LER) File (NUREG-4 D-Regulatory Restriction 4-Cont. of Existing 0161)

E-Operator Training & License Examination Outage -

F-Administrative 5-Reduct' ion i G-Operational Error (Explain) 9-Other 5 (9/77) H-Other (Explain) Exhibit I-Same Source

Plant Maintenance Summary The following significant maintenance items were completed during the month of August, 1981: .

{

Mechanical Maintenance i 1. Repacked Unit 1 main steam check valves and set the counterweights.

2. Completed the Masonielon valve stem rotation inspection.

j 3. Replaced the defective governor to control rod level assembly on l 1A-A diesel generator.

Electrical Maintenance

1. Inspected all cooling tower lift pump motors. Replaced upper guide bearing on pump 1A.
2. Replaced the main feedwater pump turbine coil 1-FSV-46-15A.
3. Repaired the control circuit on MSIV 1-FCV-1-22A.
4. Installed Unit 2's generator buss links.

Instrument Maintenance None reportable.

^

Outage Maintenance Unit 1 i

1. Completed repairs of steam cuts on #3 steam generator inboard manway cover.

, 2. Removed the safety injection input signal to the centrifugal charging pump mini-flow valves 1-FCV-62-98 and -99.

l i 3. Four-hundred-thirty-one hanger repairs are completed as per IE Bulletin 79-14. This leaves 84 repairs to be completed.

4 Unit 2

}

1. To prevent overspeed/ overload operation of the primary water pumps, PS-81-5A, -5B, -9A, and -9B were changed from pressure switches to

! pressure differential indicating switches.

I 1

Outage Maintenance Unit 2

(Continued)
2. A degraded accident radiation monitor was installed near the Unit 2 shield building vent.
3. EGTS room coolers fans AA and BB flow switches 2-FS-30-200 and -207 were replaced with environmentally qualified flow switches.
4. A crack in the seal on the divider barrier seal was repaired.
5. A visual inspection of the containment vessel and shield bqilding was perio rmed .
6. Fabrication of lifting rig platforms to facilitate safer handling of the reactor head and internals is in progress.
7. Refuel floor work:

A. Indexing of the flux mapping probe system was completed.

B. The six incore detectors have been installed.

C. Fif ty-nine of 65 incore thermocouples have been terminated.

Unit 0 or Items Affecting Unit I and 2 -

4

l. Wcrk continues on coating all exposed surfaces of cable with Flamastic in areas outside primary containments.
2. Work is in progress to add a temperature monitoring system for the o various class IE electrical equipment located throughout the plant.
3. Work continues on the replacement of the 1-inch carbon steel ERCV piping going to the EGTS room coolers with stainless steel.
4. The installation of a supplementary battery operated phone circuit in the main control room is in progress.
5. The changcout of the present freon leak detector system in the main control to an electronic, pressure-type system continues.
6. Twenty of twenty-nine fire deluge valves have been replaced with 3-way alarm test valves.
7. To allow response time testing of the level transmitters sensors with a hydraulic ramp generator, response time testing cables to the re-fueling water storage tank level transmitters LT-63-50, -51, -52, and

-53 are being installed.

- . - , - - , . , ,- , ,, -n ---

Outage Maintenance Unit 0 or Items Affecting Unit 1 and 2 (Continued)

8. To meet the requirements of 10CFR50, Appendix A, Criteria 3, ceiling panels in the control room are being replaced.
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