ML20066C713

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Monthly Operating Repts for Dec 1981.Narrative Summary Encl
ML20066C713
Person / Time
Site: Sequoyah  Tennessee Valley Authority icon.png
Issue date: 01/06/1982
From: Dupree D, Eddings M, Mason C
TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML20066C712 List:
References
NUDOCS 8211100285
Download: ML20066C713 (16)
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TENNESSEE VALLEY AUTHORITY DIVISION OF NUCLEAR POWER SEQUOYAH NUCLEAR PLANT i

MONTHLY OPERATING REPORT DECEMBER 1, 1981 - DECEMBER 31,.1981 UNIT 1 DOCKET NUMBER 50-327 LICENSE NUMBER DPR-77 i UNIT 2 DOCKEI NUMBER 50-328 LICEhSE NUMBER DPR-79 Submitted By: _. Power Plant Superintendent

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I 8211100285 820128 PDR ADOCK 05000327 R PDR

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i TABLE OF CONTENTS I

Ope ra tion s S umma ry . . . . . . . . . . . . . . . . . . . . . . . . . . . .

1 Significant Operational Events . . . . . . . . . . . . . . . . . . . . . . 1-4 PORV's and Safety Valves Summary . . . . . . . . . . . . . . . . . . . . . 4 Licensee Events and Special Reports ................... 4-6 Offsite Dose Calculation Manual Changes ................. 6 Operating Data Unit 1 ............................... 7-9

' s Unit 2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-12 Plant Maintenance Summary . . . . . . . . . . . . . . . . . . . . . . . 13 Outage Maintenance Summary . . . . . . . . . . . . . . . . . . . . . . . 13-14 k

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i Operatiens Summary December 1981  :

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

Unit 1 Unit I was critical for 692.1 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, produced 636,290 MWH (gross) with 2.8 percent station use, resulting in an average hourly gross load of 965,026 KW during the month. The net beat rate for the month was 10,280 BTU /KWH.

There are 178.9 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 July 29, 1982. The capacity factor for the month was 73.5 percent.

There were no reactor scrams, one manual shutdown, and six power re-ductions during Deceaber.

Unit 2 Unit 2 was critical for 43.7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />, produced 1,904 MWH (gross) with an average hourly gross load of 136,829 kW during the month. There are'382.6 full power days estimated remaining until the end of cycle 1 fuel. The capacity factor for the month was 7.5 percent.

There was one reactor scram, no manual shutdowns, and no power reductions during December.

Significant Operational Events Unit 1 Date Time Event 12/01/81 0001 Reactor power 98% - 1044 MWe.

0600 Reactor power 96%, 1023 MWe, load was reduced to remove B-1 water box from service for condenser tube leak testing. All water boxes l

to be tested.

12/03/81 1720 Reactor power 100%, 1140 MWe, all water boxes back in service.

12/04/81 0640 C2 was taken out of service for retest. Reactor power 99%, 1111 MWe. C1 water box to'be retested

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also.

Significtet Optratienal Events 'l 4 i

(Continued)

Unit 1 A'% ', b w

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Event ' '

Date Time 12/05/81 0640 C1waterboxplacedbackinservice after retesting was completed on C1 and C2 water boxes. he: actor power 100%,1150 We. p ,

g, 12/07/81 1615 Reactor power 25%, 275 We for repairs on reactor coolant pump #3.

12/08/81 1130 Began load reduction to take\ the unit off line and the rea~ccor io' mode 3.

1243 The generator was taken off line.' \'

1310 Reactor entered mode 3. s.

12/10/81 1402 The reactor was taken critical. -

J 1637 The generator was tied on line.

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1900 Reactor power 30% and holding fo ,N' i stea:n generator chemistry. .

12/11/81 2108 Began load increase. , ,

. 2150 Reactor power 36% and holding due to electrical problems on MFPT B.

2312 Increased reactor power to 48% and holding because governor valve positioner on MFPT B was inoperable.

12/12/81 0305 Began load increase.

e 0600 Reactor power 84%, 1080 We, - Began load reduction due to main turbine

  1. 11 bearing.

0900 Load decrease stopped at 2! 65%

turbine load.

1620 Started power increase.

2110 Reactor power 94% reducing power to 80% due to a casing leak o2 condensate booster pump A.

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Signific5st Optretien91 Evinto l-a I k V

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k s Unit 1 Date Time Event l

2200 Reactor power at 76% and holding.

, [12/12/81 '

., s , 2118 Began power increase.

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.22/13/81 0620

, Reactor power 97%,1050 We.

2220

' Reactor,pou r 99%,1114 We.

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% 12/27/81 1210 Regan'loi.d reduction to take the reactor.to mode 2 due to the sump q,,i'

' , level transmitter out of limits.

. i 1433 Turbine trip off line.

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2318- Turbine tied on line and reactor power

.. 12/28/81' '

- increased to 30%, 320 We and holding c

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for steam generator chemistry.

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'12/31/81 ' 2105 Began power ascension, g e,

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2359 - Reactor power 50%, 516 We.

s Unit 2 12/01/81 _

0001 _ ,, Reactor in mode 4, 205' and 325 psi.

7. 'L The exciter is off-site for repairs.

12/08/81 1530 Began cooldown to 145' for weld m.

inspection of reactor pressure vessel nozzels.

'C 1600 The reactor entered mode 5. ,

12/09/81 2143 A safety injection occurred while the SI-247.6 series SI's were being

- performed (response time testing

- engineering safety feature actuation

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s slave relays) as the result of a mis-communication between the instrument mechanic and unit operator.

12/11/8i '

1750 The reactor entered mode 4.

12/16/81 1530 The exciter is back on site.

12/21/81 1857 The reactor taken critical.

Significent Operr.tient1 Events (Continued)

Unit 2 Date Time Event 12/22/81 1821 Reactor entered mode 1.

0010 Unit tied on line - initial generation.

12/23/81 0230 Reactor power 20%,125 MWe.

1346 A feedwater valve opened an automatic signal creating a Hi-Hi level alarm in #4 steam generator and caused the turbine and hotwell pumps to trip.

P-9 circuit was transferring the steam from the turbine to the steam dumps. Operators were unable to get a hotwell pump started in time to prevent a Lo-Lo level alarm in another loop and therefore a reactor trip occurred.

2000 Began cooldown to flush the steam generators because of bad' water chemistry.

12/26/81 0622 Reactor entered mode 4.

12/31/81 2359 Reactor in mode 4, 340*F, 700 psi cleaning up steam generator water chemistry.

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

Licensee Events and Special Reports i

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

LER SUBJECT SQR0-50-327/132 RCS water inventory not performed within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

SQRO-50-327/142 AFW pressure control valve 1-PCV-3-122 would not operate due to servo valve hydraulic fluid con-tamination. 'y

,w. op.

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Licenten Ev:nts cad Spscial R: parts (Continued)

LER SUBJECT SQRO-50-327/145 Hotor leads to 1-FCV-63-6 discovered lifted.

SQR0-50-327/146 EGTS inoperable when dampers 1-65-81 and -86 would not stay open due to failing latching system.

SQRO-50-327/147 Loop 2 cold leg injection accumulator inoperable due to low boron concentration with cause unknown.

SQRO-50-327/148 Pressurizer steam containment isolation valves 1-FCV-43-2 would not close due to binding or broken actuator spring.

SQRO-50-327/149 Steam generator blowdown effluent line rad mouitor RM-90-120/121 inoperable due to erratic readings caused by air trapped in sample chambers.

SQR0-50-327/150 Feedwater flow loop 1-FI-3-35B inoperable due to low readings caused by air in sensing lines.

SQR0-50-328/134 Relay contacts for RCP #3 fire zone found improperly wired.

I SQR0-50-328/136 Valves 2-68-548and-578closedtoisolateleakin instrument piping for 2-PI-68-69 RCS pressure loop 3 hotleg.

i SQRO-50-328/140 Overpower delta T reactor trip instrumentation inoperable due to defective logic in the solid state protection system.

SQRO-50-328/141 AFW pump A pressure control valve 2-PCV-3-122 would not operate from control room due to servo valve inoperable due to contaminated hydraulic fluid.

l l SQRO-50-328/143 2-LCV-3-171 failed due to dirty solenoid causing reactor trip.

SQRO-50-328/144 RCS average temperature fell belcw 541*F.

Control rod withdrawal limit exceeded during SQRO-50-328/152 start-up causing possible positive MTC.

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Special Rrp:rts There were two special reports sent during the month of December.

81-8 Unit 2 positive moderate temperature coefficient per Tech Spec 3.1.1.3.

81-9 Unit 2 report failure to submit report to NRC required by License 2.C.(16).5.

Offsite Dose Calculation Manual Changes There were no changes to the Offsite Dose Calculation Manual during the month of December 1981.

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OPERATING DATA REPORT d

DOCKET NO. 50-327 g ,. , DATE l-4-82 COMPLETED BY M. Eddings

, TELEPHONE (61si 751-0343 OPERATING STATUS '

1. Unit Name: Sequoyah One _

Notes ,

2. Reporting Period: December 1981 .-
3. Licensed Thermal Power (MWt): 3411'
4. Nameplate Rating (Gross MWe): i990.sg
5. Design Electrical Rating (Net MWe): 1148 -
6. Maximum Dependable Capacity (Gross SWe): 1163
7. Maximum Dependable Capacity (Net MWe): 119g
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:

s This Month Yr-to-Date Cumulative

11. Hours in Reporting Period 744 k V 4
12. Number of Hours Reactor Was Critical 692.1 692.1 2801.3
13. Reactor Reserve Shutdown Hours 0 0 0 i
14. Hours Generator On-Line 659.3 659.3  ! 2690.4 \

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15. Unit Reserve Shutdown Hours 0 0 i 0 )
16. Gross Thermal Energy Generated (MWH) 1909779 1909779 i 8895612 I
17. Gross Electrical Energy Generated (MWH) 636290 636290 t 2645950
18. Net Electrical Energy Generated (MWH) 618613 618613 ' 1527025  !
19. Unit Service Factor , 88.6 88.6 60.9 /

l 20. Unit Availability Factor 88.6 88.6 i 60.9 /

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21. Unit Capacity Factor (Using MDC Net) 73.7 73.7 i 50.8 1
22. Unit Capacity Factor (Using DER Net) 73.7 73.7 s 50.8 /

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23. Unit Forced Outage Rate 11.4 11.4 t 39.1 -

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

Tech. Spec. Ice Weighing February 19, 1982

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 l

(9/77)

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UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-327 UNIT NAME Seouovah One

[ DATE 1-4-82 COMPLETED BY M. Eddings REPORT MONTH December 1981 TELEPHONE (615) 731-0343 S

, c- m  % w3 Licensee $ Cause & Corrective No. Date  %.

S0 @ ajy Event 0% E4 Action to H

R %5 E ,@ $ g Report # %3 {l* Prevent Recurrence I

$5 N YE N* o a

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6 81/12/08 F 51.9 A 1 Maintenance on #2 R.C.P.

81/12/12 0 - 5 23% Load Decrease Due to Excessive Main Turbine #11 Bearing Vibration

' 32.8 7 81/12/27 F A 5 Containment Sump Level Out of Limits Reactor q Remained Critical 1 to 3% Pwr. Turbine was Tripped.

l 1 2 3 4 F:/ Forced Reasoc: Method:

S: Scheduled Exhibit G-Instructions -

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-

, D-Regulatory Restriction 4-Cont. of Existing 0161) e, E-Operator Training & License Examination Outage T. ' F-Administrative ~

5-Reduction .

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G-Operational Error (Explain) 9-Other 5 I '

(9/?7) H-Other (Explain) Exhibit I-Same Source

' $ },,_]iy) g.,

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AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-327 UNIT seauoyah One DATE 1-4-82 COMPLETED BY M. Eddings TELEPHONE (615) 751-0343

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MONTH December 1981 DAY AVERAGE DAILY POWER LEVEL DAi* AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net) 1042 1070 1 37 2 1057 18 1117 3 1088 19 1113 4 1077 20 1101 5 1097 -

21 1097 6 1108 22 1099 7 743 23 1114 8 117 24 1111 9 0 1105 25 10 68 26 1105 j

11 288 27 590 12 786 28 0 13 1078 29 262 14 1108 30 259 15 1123 31 292 16 1114 i

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INSTRUCTIONS On this fonmat, list the average daily unit power level in MWe-Net for each day in

, the reporting month. Compute to the nearest whole megawatt. ,

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4 OPERATING DATA REPORT DOCKET NO 50-328 DATE 1-6-82

COMPLETED BY David Dupree TELEPHONE (615) 751-0343 OPERATING STATUS
1. Unit Name: Sequoyah Two Notes
2. Reporting Period necember. 1981 -

3.

Licensed Thermal Power (MWt): 3411'

4. Nameplate Rating (Grcss MWe): i??n.s
5. Design Electrical Rating (Net MWe): iita
6. Maximum Dependable Capacity (Gross MWe): 1183
7. Maximum Dependable Capacity (Net HWe): i148
8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Repcrt, Give Reasons:
9. Power Level To Which Restricted, If Any (Net MWe):
10. Reasons For Restrictions, If Any:

s This Month Yr-to-Date Cumulative

11. Hours in Reporting Period 744 1464 1464
12. Number of Hours Reactor Was Critical 43.7 257.2 257.2
13. Reactor Reserve Shutdown Hours 0 0 0
14. Hours Generator On-Line 13.6 13.6 13.6
15. Unit Reserve Shutdown Hours 0 0 0
16. Gross Thermal Energy Generated (MWH) 12713 15914 15914
17. Gross Electrical Energy Generated (MWH) 1904 1904 1904
18. Net Electrical Energy Generated (MWH) 0 0 0 l
19. Unit Service Factor 6.3 6.3 6.3 1
20. Unit Availability Factor 6.3 6.3 6.3
21. Unit Capacity Factor (Using MDC Net) 0 0 0
22. Unit Capacity Factor (Using DER Net) 0 0 0
23. Unit Forced Outage Rate 98.2 98.2 98.2
24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):

Ice Weinhing (5-5-82) Requirement Per Tech Specs f

25. If Shut Down At End Of Report Period, Estimated Date of Startup: 1-11-82
26. Units In Test Status (Prior to Commercial Operation):

l Forecast Achieved INITIAL CRITICALITY 11-5-81 . 11-5-81

- INITIAL ELECTRICITY 12-31-81 12-23-81 l COMMERCIAL OPERATION __3-1-81 N NA (9/77) l' t

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),e UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-328 '

UNIT NAME Sequoyah Two y '

DATE 1-6-82

[' COMPLETED BY David Dupree REPORT MONTH _ December 1981 TELEPHONE (615) 751-0343 1

, em n y eo 3 Licensee U Cause & Corrective No. Date "o OO E ejM Event @% E*e Action to R %8 E .8 tj y Report # $l 8.3 Prevent Recurrence M5 e & @'

o %35 xm, o a

81/12/01 S 528.2 A 1 Initial Criticality Testing 81-1 81/12/23 F 202.2 'A 3 Turbine Trip from High Level #4 S/G Feedwater Valve went open on Auto. Rx Trip due to low 1 S/G level.

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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-v D-Regulatory Restriction 4- Cont . of Existing 0161) g E-Operator Training & License Examination Outage

i. F-Administra tive 5-Reduction S. G-Operational Error (Explain)

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9-Other 5 s (9/77) H-Other (Explain) Exhibit I-Same Source

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AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-328 UNIT ggn,,nynn Two DATE _ _ _ _ _

1-6-82 COMPLETED BY .s navid Dupree TELEPHONE (615) 751-0343 MONTH December 1981 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net) 1 0 17 0 2 0 18 0 3 0 19 0 g 4 0 20 0 5 0 - 0 21 6 0 0 22 0 0 7 23 8 0 0 24 0 0 9 25 0 0 10 26 0 0 11 27 12 0 28 0 0 '

< 13 0 29 14 0 30 0 l

0 0 15 31 16 0 INSTRUCTIONS i

l 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. i

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O Plant Maintentnca. Summary The following significant maintenance items were completed during the month of December 1981:

r Mechanical Maintenance y 1. The steam dump sparger has been installed on Unit 2 condenser.

2. The steam dump modifications have been completed on all three condensers on Unit 2.
3. The mechanical seal on hotwell pump IC has been replaced.

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4. 2-FCV-1-18 was rebuilt. _

i i Ilectrical Maintenance

1. Repairs were made to the 2B hotwell pump motor.
2. The Unit 2 exciter was received back on site and installed.
3. The Technical Support Center ' Dimension' phone system modifications were completed.

i t Instrument Maintenance

1. Containment sump level transmitters 1-LT-63-176 and -177 required special calibration due to drifting.

I 2. Due to the accumulation of non-condensibles, the pressurizer level channel condensate pots required to be vented are: L-63-320, 5 times; L-68-335, 2 times, and L-68-339, I time.

I Field Services Maintenance a

Work continues on the following items. /

1. A post accident sampling system for Unit 1 is being installed to obtain designated liquid and gas samples during and after a postulated event.
2. IE Bulletin 79 Hanger Repairs - 448 repairs are completed and 65 identified repairs remaining.
3. The 4-inch train B piping to HVAC equipment serving the electric board rooms and main control roam is being replaced.
4. Exposed cables in areas outside primary containment containing one or both safety related divisions are being coated with Flamastic.

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Field S rvices Mainten:nce (Continued)

5. To achieve positive access accountability door A-183 is being replaced and a card reader is being installed.
6. Conduit is being installed for response time testing of the Unit 2 refueling water storage tank level transmitters.
7. A reactor vessel head venting system is being added to Unit 1.
8. An oxygen analyzer is being installed on the auxiliary boilers.
9. To comply with TVA's SQN radiological emergency plan the telephone and radios located in the health physics laboratory,_ elevation 706', are being moved to the health physics laboratory, elevation 690', service building.
10. Three pressurizer condensate reservoirs are being fabricated for Unit I to ensure proper operation of the pressurizer instrumentation.

The following work was completed during the month.

1. Cables, junction boxes and conduit has been removed from the ABSCE dampers that were blocked open. g
2. Environmentally qualified solenoids have been installed on various dampers.
3. A fuel transfer canal ladder has been installed to provide access from elevation 734' to elevation 686'.
4. A 3' by 3' opening in the Al line wall in the auxiliary building has been closed with a 3-hour rated fire barrier.
5. The carbon steel supply and return lines to the incore instrument room chillers 2A and 2B have been replaced with stainless steel piping.
6. Block walls on elevation 690' auxiliary building have been modified by installing a steel plate on the walls in accordance with NCR SQNSWP8119.
7. An isolation valve has been installed in the 3 inch blowdown line'to the cooling tower blowdown ahead of 1-FCV-15-8 to ensure that the steam generator blowdown to the cooling tower blowdown can be isolated in the event the valve is required to be closed.
8. Additional test connections have been installed on the Unit 2 feedwater taps.
9. The Unit 2 pressurizer level condensate pot vent lines have been extended to enhance maintenance. ,
10. A missing support on the Unit 2 reactor coolant pump #4 pil cooler line has been installed.
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