ML20030B974
| ML20030B974 | |
| Person / Time | |
|---|---|
| Site: | Sequoyah  |
| Issue date: | 08/03/1981 |
| From: | Eddings M TENNESSEE VALLEY AUTHORITY |
| To: | |
| Shared Package | |
| ML20030B970 | List: |
| References | |
| NUDOCS 8108250271 | |
| Download: ML20030B974 (15) | |
Text
-.
TENNESSEE VALLEY AUTHORITY DIVISION OF NUCLEAR POWER SEQUOYAH NUCLEAR PLANT l
i l
I MONTHLY OPERATING REPORT July 1, 1981 - July 31, 1981 l
[
UNIT 1 DOCKET NUMBER 50-327 i
LICENSE NUMBER DPR-77 UNIT 2 DOCKET NUMBER 50-328 l
l LICENSE NUMBER DPR-79
(
4 8h ktb1 Submitted By:
~
wer Pla5E~ Superintendent t t st
[
8108250271 810814 DR ADOCK 05000327 PDR l
T
I i
i 4
TABLE OF CONTENTS
.i l
I t
1 Operations Summary............................ 1 PORV's and' Safety Valves Summary..
.1 Licensee Events and Special Reports
. 2-3 l
Offsite Dose Calculation Manual Changes
.3 i
Significant Operational Events...
. 3-4 Operating Data Unit 1
. 5-7 i
Unit 2
. 8-10 Plant Maintenance Summary
. 11 Outage Maintenance Summary..
. 11-13 I
i r
l 1
f f
L
Operaticas Summary July, 1981 The following summary describes the significant operational actis. ties for the month of July.
In support of this summary, a chronological log of significant events is included in this report.
Unit I was critical for 585.1 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, produced 558,790 MWH (gross) with 4.16 percent station use, resulting in an average hourly gross load of 1,025,000 KW during the month. The net heat rate for the month was 10,910 BTU /KWH.
There are 256.56 full power days estimated remaining until the end of cycle 1 fuel. With a :apacity factor of 85 percent the target EOC exposure would be reached April 14, 1982. The capacity factor for the month was 63.8 percent.
There were three scrams during July.
Unit 1 At 0001 hrs. on July I the reactor was in mode 3.
Repairs were completed on the main steam intercept valve 1-FCV-1-22, the reactot was taken critical at 0348 hrs., and the unit tied on line at 2313 hrs. The reactor tripped (Reactor trip #81-16) when the control air line to the main feedwater regula-tion valve blew off causing the valve to fail closed creating a Lo-Lo feed-water flow alarm in loop 3 at 1946 hrs., July 9.
The reactor was taken critical again on July 10 at 1924 hrs and the unit tied on line at 0623 hrs.
on July 11.
The reactor tripped (Reactor trip #81-17) at 0643 hrs. because of Lo-Lo steam generator level in loop 3 created by steam flow, feedwater flow mismatch. The reactor was taken critical at 0940 hrs., the unit tied on line at 1150 hrs, and reactor power increased to 30%. The reactor tripped (Reactor trip #81-18) at 1353 hrs, when increased steam generator blow down caused the low pressure heaters to isolate creating Lo-Lo steam generator level alarms. The reactor was taken critical at 0325 hrs. on July 13, the unit tied on line at 0450 hrs. The reactor obtained 100% power at 2010 hrs.,
July 15 after remaining between 80 - 90% power for work on the condensate booster pumps. At 0040 hrs. on July 18 the unit was taken off line to repair the loop 1 main steam check valve. The reactor was taken critical on July 21 at 2225 hrs. and tied on line at 0147 hrs'., July 22 and 100% reactor power obtained at E 2330 hrs. On July 31 at 2359 hrs. the reactor was in mode 1 at 100% power, 1100 mwe.
P Unit 2 l
July 3 at 2205 unit 2 entered mode 6 and initial core fuel loading started. The first fuel assembly was set in the core at 0001 hrs. July 4.
Initial core loading was completed at 1454 hrs. July 7.
The reactor entered mode 5 at 0330 hrs. July 29. July 31 at 2359 hrs. the reactor was in mode 5.
PORV's and Safety Valves Summary No PORV's or safety valves were challenged during the month. -
d Licensee Events and Special Reports The following Licensee Event Reports (LER's) were sent during July,1981, to the Assistant Director of Nuclear Power (Operations) for reporting to the Nuclear Regulatory Commission.
SQR0-50-327/81066 Rad monitor 0-RM-90-212 inoperable on two occasions due to housing wear.
SQR0-50-327/81067 Steam generator level transmitters 1-LT-3-148,
-156, -164, -172, -174, and -175 would fail during LOCA due to incorrect insulation.
SQRO-50-327/81068 Rad monitor 0-RM-90-122 would not source check due to contaminated sample chamber.
SQR0-50-327/81069 Pipe hanger omitted from 3/4" test and fill line from boron injection line to safety injection accumulators.
SQRO-50-327/81070 Containment building lower compartment air monitor valve 1-FCV-90-109 failed to close on isolation signal due to loose screw.
SQRO-50-327/81071 B train Control Building Emergency Air Clean-up 4
System inoperable due to charcoal failing 99%
methyl iodine removal efficiency test.
SQR0-50-327/81072 Pipe hanger removed from ERCW line but not reinstalled following spool piece modification for corrosion study.
SQR0-50-327/81073 Ice condenser intermediate deck doors frorted i
due to damaged tape seals.
SQR0-50-327/81074 Service building rad monitor 0-RM-90-132 inoperable due to sample pump failure.
SQRO-50-327/81075 Sufficient clearance not existing between alternate charging line and pressurizer base.
~
SQRO-50-327/8-1076---
1A-A-safety-injectiom pump-had water -in oil-due to condensation.
SQRO-50-327/81077 RWST level below limits due to valve 1-62-500 left open.
SQR0-50-327/81079 Waste disposal system effluent rad monitor 0-RM-90-122 inoperable due to high background count caused by contaminated chamber.
SQRO-50-327/81080 BWST below limits due to leaking check valve 0-78-564.
SQRO-50-327/81081 RCS temperature below 541 degrees F for 2 minutes..
Licensee Events and Special Reports (Cont.)
SQR0-50-327/81084 RCS water inventory SI-137.2 not performed within time requirements.
SQR0-50-327/81085 Both lower containment personnel airlock doors open due to door being out of adjustment.
Special Reports No special reports were sent during the month of July.
Offsite Dose Calculation Manual Changes There were no changes in the Sequoyah Nuclear Plant ODCM during the month.
Significant Operational Events Date Time Event 07/01/81 0001 Reactor in mode 3, completing repairs on 1-FCV-1-22.
0348 Reactor critical.
2313 Unit on line.
07/09/81 1946 Reactor trip #81-16 when the air line blew off feedwater reg, valve.
07/10/81 1942 Reactor critical.
07/11/81 0623 Unit on line.
0643
__--_ Reactor _. trip #81-17 #3 steam generator Lo-Lo level alarm due to steam flew feedwater flow mismatch.
0940 Reactor critical.
1150 Unit on line.
1353 Reactor trip #81-18 when increased blow down caused the low pressure heaters to isolate causing Lo-Lo steam generator levels 07/13/81 0325 Rsactor critical.
0450 Unit on line. _ _..
._.___.2-
4 Significant Operational Events (Cont.)
Date Time Event 07/18/81 0040 Unit off line - manual shutdown to i
repair the loop 1 main steam check valve.
07/21/81 2225 Reactor critical.
i l
07/22/81 0147 Unit on line.
07/31/81 2359 Reactor in moda i at 100% power-producing 1100 mwe.
s Unit 2 Date Time Event 07/03/81 2205 Entered mode 6 for initial core fuel loading.
07/04/81 0001 The first fuel assembly set in the Core.
07/07/81 1454 Core fuel loading complete.
07/29/81 0330 Entered mode 5.
07/31/81 2359 Reactor in mode 5.
..~
l _....,..... _.., _ _. _.. _ _ _. _..... _ _.. _ _ _ _ _., _. _ _. _, _ _ _ _... _.
4 OPERATING DATA REPORT DOCKET NO.
50-327 DATE 8/3/81 COMPLETED BY M. Eddings TELEPHONE 615-842-0295 OPERATING STATUS 1.
Unit Name:
Sequoyah 1 Notes 2.
Reporting Period:
July 3.
Licensed Thermal Power (MWt):
3411 4.
Nameplate Rating (Gross MWe):
1220.58 5.
Design Electrical Rating (Net MWe):
1128 6.
Maximum Dependable Capacity (Gross IWe):
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
- Cumula tive
- 11.
Hours in Repct:ing Period 744 744 744 l
12.
Number of Hours Reactor Was Critical 582.8 582.8 582.8
- 13. Reactor Reserve Shutdown Hours 0__
0 0
14.
Hours Generator On-Line 545.0 545.0 54570
~~
15.
Unit Reserve Shutdown Hours 0
0 0
16.
Gross Thermal Energy Generated (MWH) 1,703,23c~~
1,703,235 1,703,235 17.
Gross Electrical Energy Generated (MWH) 558,790__
558,790 558,790 18.
Net Electrical Energy Generated (MWH) 535,527 535,527 535,527 19.
Unit Service Factor 73.2 73.2 73.2 20.
Unit Availability Factor 73.]2 73.2 73.2 21.
Unit Capacity Factor (Using MDC-Net-)-
63.8 -
- - 63. 8 -
63.8 22.
Unit Capacity Factor (Using DER Net) 63.8 63.8 63.8 l
23.
Unit Forced Outage Rate 26.7 26.7 26.7 24.
Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):
Sept. 1981 Tech. Spec. Ice Weighing 25.
If Shut Lown 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 CUnit I went NRC commercial operations 7/1/81.
These columns re-zerced at this date.
(9/77) ac a
AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.
50-327 UNIT Seouovah 1 DATE Julv COMPLETED BY Mike Eddings TELEPif0NE 615-842-0295 l
MONTil July DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net)
(MWe-Net) 1 0
17 1050 2
934 18 0
3 1120 19 0
4 1049 20 0
5 1053 21 0
6 1078 22 450 7
1084 23 1067 8
1082 24 1076
.9 868 25 1076 10 0
26 1073 11 0
27 1073 j
1 12 0
28 1073 13 342 29 1077-14 958 30 1075 15 970 31 1074 16 1070 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) m
UNIT SIRITDOWNS AND POWER REDUCTIONS DOCKET NO.
50-327 UNIT NAME S:qusyah DATE 8-3-81 COMPLETED BY Mike Eddings REPORT MONTl!
July TELEP110NE 615-842-0295 o ao 3 Licensee Cause & Corrective cm n
No.
Date
.0 e.5 y Event E*e Action to R
yg y
jdy Report #
%2 8.3 Prevent Recurrence H
05 4
tac m"
8" xmg u
o a
81/07/01 F
23.2 A
4 81/07/09 F
34.6 A
3 Air line to 1-FCV-3-90 Loop 3 broken off.
j Copper line re-soldered back on.
4 81/07/11 F
5.1 A
3 Lo-Lo level #3 S/G due to low FW 1evel.
i 81/07/11 F
38.9 N
3 Low pressure heaters isolated due to exces-j sive S/G blowdown, Lo-Lo S/G 1evels.
81/07/18 F
97.1 A
1 Maintenance on Loop 1 main steam check valve.
e i
1 2
3 4
F: Forced Reason:
Method:
Exhibit G-Instructicas 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-D-Regulatory Rdstriction 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) li-Other (Explain)
Exhibit I-Same Source j
i OPERATING DATA REPORT DOCKET NO.
50-328 DATE 8/1/81 COMPLETED BY M. Eddines TELEPHONE vis o,t vc2s OPERATING STATUS 1.
Unit Name:
Seouovah Two Notes 2.
Reporting Period:
July 3.
Licensed Thermal Power (MWt):
3411 4.
Nameplate Rating (Gross MWe):
1220.58 5.
Design Electrical Rating (Net MWe):
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 NRC 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 Hotrs 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 (MWH)
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 Factsr (UsTng DER' nee)
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:
9/4/81 26.
Units In Test Status (Prior to Commercial Operation):
l Forecast Achieved l
INITIAL CRITICALITY 9/4/81 N/E INITIAL ELECTRICITY 9/14/81 N/A COMMERCIAL OPERATION
- 12/1/81 N/A (9/77) s
AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.
50-328 UNIT Sequoyah Two DATE 8/1/81 CCMPLETED BY Mike Eddings TELEPHONE 615-842-0295 MONTH Julv 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
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
12 0
28 0
13 0
29 a
14 0
30 0
15 0
31 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)
UNIT SHUTD0k'NS AND P0b'ER REDl?CTIONS DOCKET NO. -W328 UNIT NAME DATE _g,quoy A Tec 4
3,g; COMPLETED BY M i b Eddinge REPORT MONTil TELEPl!0NE y.
- 615-842-0295 "u
o ec 3 Licensee Cause & Corrective en N
No.
Date "a
30 E
.o j y Event 8*a Action to R
$5 E
.@ tj j Report #
$3 8.3 Prevent Recurrence H
05 aI t.a c 8"
u xmg o
o 81/07/03 S
649.5 C
9 Initial core loading.
81/07/29 S
69.5 B
9 Preparations for Initial Criticality.
b
~
i l
I M
l l
1 2
3 4
F: Forced.
Reason:
Method:
Exhibit G-Instructions S Scheduled A-Eqripment Fai16re (Explain) 1-Manual for Preparation of Data B-Ma2ntenance or Test 2-Manual Scram.
Entry Sheets for Licensee C-Refueling 3-Automatic Scram.
Event Report (LER) File (NUREG-D-Regulatory Rest.riction 4-Cont. of Existing 0161),
E-Operator Training & License Examination Outage F-Administrative 5-Reduction G-Operational Erbor (Explain) 9-Other 5.
(9/77)
H-Other (Explain)
Exhibit I-Same Source L___ _
n
Plant Maintenance Summary The following significant maintenance items were completed during the month of July, 1981:
Mechanical Maintenance 1.
Repacked main steam check valve 1-CV-1-623.
2.
Replaced a leaking operator diaphragm on 1-FCV-62-70.
3.
Steam generator blowdown pump 1B sustained rotor damage. Pump IB was replaced with a unit 2 pump. The damaged pump will be rebuilt when pa'rts are received.
4.
Installed corner seals on the auxiliary building railroad bay hatch cover doors.
5.
Work continues on the unit 2 airlocks to reduce air leakage requirements as required by SI-159.1.
6.
Rebuilt glycol chiller
'C'.
Electrical Maintenance 1.
Assisted instrument mechanics in electrical checkout of rod position indication and control rod drive coils, unit 2.
2.
Motor replacement on containment radiation monitors is complete.
3.
Performed wajor inspection on PCB 984.
4.
Replaced molly steel key between gear and motor shaft on steam generator #1 isolation valve.
Instrument Maintenance None reportable.
Outage Maintenance Unit 1 1.
Four-hundred-thirty-one hanger repairs are completed as per IE Bulletin 79-14.
This leaves 84 repairs to be completed.
2.
1-PS-81-5A, -5B, -9A, and -9B changeout to pressure differential indicat-ing switches was completed. This work was done to prevent overspeed/
overload operation of the primary makeup water pumps.
Outage Maintenance (Cont.)
Unit 2 1.
To provide access by a UT probe, modifications to the beam on RCP #1 platform was completed.
2.
Gasket replacement on the main steam stop valves is in progrss.
3.
The bladder was replaced on 2-FCV-67-21 and -22, leakrate test for CV-87-562 and -563 was completed.
4.
The steam assembly was replaced on 2-FCV-43-69.
5.
The packing was replaced on 2-FCV-1-108, -110, and -114.
6.
The steam generator blowdown valves, FCV-1-7 and -25 were welded in place replacing the valves removed to be used in unit 1.
7.
Work continues to install a degraded accident radiation monitor near the unit 2 shield building vent.
8.
The UHI hydraulic valve actuators were replaced on 2-FSV-87-24A and -24B.
9.
Repairs were completed on 2-CV-62-662.
10.
The replacement of the flow element and the RCS boron concentration analyzer with a digite' instrument is complete.
11.
The addition of logic to prevent sampling isolation valves 2-FCV-43-55,
-58, -61, and -64 from opening automatically is complete.
12.
The replacement of the disc assembly and valve internals on 2-HCV-32-356 is complete.
- 13. The solenoids on valves 2-FSV-1-7, -14, -32, 61-97, -122, -336, -338, and -128 were replaced with environmentally qualified ASCO NP-1 series solenoids.
14.
2-FCV-68-333 was repacked with Grafoid.
- 15. To resolve calibration problems with the hydrogen analyzer _a pressure regulator was installed on the reagent air line to each unit T analyzer. --
- 16. EGTS room cooler fans AA and BB flow switches 2-FS-30-200 and -207 are being replaced with environmentally qualified flow switches.
17.
2-FCV-1-16 packing was replaced.
- 18. Twenty-four of 27 identified hanger repairs are completed as per IE Bullentin 79-14.
19.
Unit 2 Refuel Floor Work:
a.
The CRDM drive rods have been installed and latched.
b.
The lower and upper internals have been installed.
Outage Maintenance (Cont.)
c.
The head has been set inplace and tensioned.
d.
The stud which was bound was bered out and replaced, The incore detector thimbles have been installed, brushed, flushed e.
and dried.
Indexing of the thimbles is in progress.
f.
The conoseals and UHI connections have been installed.
g.
Installation of the center missle s'.:ield is in progress.
Unit 0 or Items Affecting Unit I and 2 1.
Work continues on coating all exposed surfaces of cable with Flamastic in areas outside primary containment.
2.
The addition of permanent yard security lighting fixtures to satisfy footcandle level dificiencies continues.
3 Work is complete on the Public Safety Services radio repeater system.
4.
Work is in progress to add a temperature monitoring system for the various class IE electrical equipment located throughout the plant.
1 5.
The replacement of the 1-inch carbon steel ERCW piping going to the EGTS room coolers with stainless steel piping is in progress.
6.
Work continues on the modification to lock open the 38 interim ABSOE isolation damper.
7.
The installation of a supplementary battery operatea phone circuit in the main control room is in progress.
8.
The changeout of the present freon leak detection systeiu in the main control room to an electronic, pressure-type system has begun. The new system will provide quicker and more accurate freon detection in the control room.
9.
The niodification to the SSPS and NIS power range drawers N41., N42, N43, y
and N44 to inc~orporate ~P-9 permissivrf turbine /resctor' trip logic -
~
continues. This modification will prevent a reactor trip when the tur-bine trips when the reactor power level is below 50%.
i l ~