ML20041G223
| ML20041G223 | |
| Person / Time | |
|---|---|
| Site: | Sequoyah  |
| Issue date: | 02/05/1982 |
| From: | Dupree D, Eddings M TENNESSEE VALLEY AUTHORITY |
| To: | |
| Shared Package | |
| ML20041G219 | List: |
| References | |
| NUDOCS 8203190413 | |
| Download: ML20041G223 (27) | |
Text
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TENNESSEE VALLEY AITlHORITY DIVISION OF NUCLEAR POWER SEQUOYAH hTCLEAR PLANT MONTHLY OPERATING REPORT JANUARY 1, 1982 - JANUARY 31, 1982 UNIT 1 DOCKET hWIBER 50-327 LICENSE NLSIBER DPR-77
% UNIT 2 DOCKET hWIBER 50-328 LICENSE NUMBER DPR-79
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Submitted By: c Power Plant. Superint.eadent 8203190413 820216 PDR ADOCK 05000327 PDR R
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1 TABLE OF CONTENTS Operations Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 Significant Operational Events . . . . . . . . . . . . . . . . . . . . . . 1-6 PORV's and Safety Valves Summary . . . . . . . . . . . . . . . . . . . . . 6 4
i Licensee Events and Special Reports . . . . . . . . . . . . . . . . . . . 6-7 i
Offsite Dose Calculation Manual Changes . . . . . . . . . . . . . . . . . 7-8 Operating Data Unit 1 . . . . . . . . ....................... 9 ;
Unit 2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12-14 Plant Maintenance Summary . . . . . . . . . . . . . . . . . . . . . . . 15
^
Field Services Maintenance Summary . . . . . . . . . . . . . . . . . . . 15-16 Appendix A . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17-25 4
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Operations Summary .
January 1982 The following summary describes the significant operational activities for the month of January. In support of this summary, a chronological log of significant events is included in this report.
Unit 1 Unit I was critical for 332.9 hours1.041667e-4 days <br />0.0025 hours <br />1.488095e-5 weeks <br />3.4245e-6 months <br />, produced 286,760 MWH (gross) with 6.7 percent station use, resulting in an average. hourly gross load of 878,015 KW during the month. The net heat rate for the month was 10,620 BTU /KWH.
There are 168.7 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 August 17, 1982. The capacity factor for the month was 33.1 percent.
There were two reactor scrams, one manual shutdown, and three power re-ductions during January.
Unit 2 Unit 2 was critical for 336.2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, produced 65,210 MWH (gross) with an average hourly gross load of 25,939 kW during the month. There are 379.86 full power days estimated remaining until the end of cycle 1 fuel. The capacity factor for the month was 7.4 percent.
There were five reactor scrams, no manual shutdowns, and no power reduction during January.
Significant Operational Events Unit 1 Date Time Event 01/01/82 0001 Reactor power 50%, 516 MWe, increasing power slowly.
1/03/82 0600 Reactor power 100%, 1150 MWe.
01/09/82 0927 Began load reduction to E 30%
. reactor power because the steam generator and A Hotwell chemistry were out of specifications.
1400 Reactor power 34%. g,
. 1 Significant Oprrational Events (Continued)
Unit 1 Time Event Date 1658 Taking the reactor to hot shutdown 01/09/82 (mode 4) to correct chemistry problems.
1730 -The reactor entered mode 2.
1731 The turbine tripped off-line, reactor entered mode 3.
0913 The reactor entered mode 4.
01/10/82 1600 The reactor entered mode 5.
01/11/82 2125 The reactor entered mode 4. 1 1820 The reactor entered mode 3.
01/13/82 01/14/82 1430 The reactor taken critical. One percent reactor power and holding for secondary chemistry to come into specifications.
1802 The reactor entered mode 1.
1955 The unit was tied on-line.
0630 Reactor power 30%, 300 MW'e.
01/15/82 1750 Began power ascension.
01/18/82 0600 Reactor power 90%, ~ 1140 MWe.
- 01/19/82 0857 Both MFPT's tripped due to low
' hotwell levels causing a turbine trip and thus a reactor trip.
1054 Reactor taken critical.
1138 The unit tied on line.
1420 Reactor at 30% power.
A fault at the B-Phase transformer P
1941
~ causing a turbine trip and under-voltage on the reactor coolant pump busses. Reactor trip received.
Significant dperational Events (Continued)
Unit 1 Date Time Event 1/20/82 2103 Entered mode 5 for investigation and repairs to the transformer and generator. Commenced ice weighting outage.
1/31/82 2359 Reactor in mode 5, outage continuing.
Unit 2 01/01/82 0001 The reactor in mode 4 at 340 F, 700 psi and cleaning up the steam generator water chemistry.
01/05/82 1130 Condensate system shutdown to drain and flush the hotwells. Main-tain RCS temperature and pressure by using the atmospheric relief valves.
01/06/82 1858 Began refilling the hotwells.
2026 Began pulling a vacuum in the con-denser. ,
01/09/82 0427 Began heat-up to enter node 3.
0521 Entered mode 3.
1811 Reactor taken critical, holding 1%
reactor power until water chemistry meets specifications.
01/11/82 0200 Reduced reactor power to ~ 0.5% to conserve CST water.
01/11/82 1205 Began power ascension.
1215 The reactor entered mode 1.
1320 The reactor at 1% power (mode 2) to '
correct problem with the steam dumps and 2-PT-1-33.
1938 Began power ascension.
Significant Operational Events (Continued)
Unit 2 Date Time Event 01/11/82 2010 The reactor entered mode 1.
2103 Rolled turbine, at 2 1000 rpm's the throttle valves came wide open and the governor valves closed. The throttle valves bouncing open and closed causing Ili steam flow alarms. The valve limits ran to zero and the turbine turbine allowed to coast down.
01/12/82 0005 Rolled the main turbine again.
0014 The turbine manually tripped due due to the turbine control system problems at E 900 rpm's. The speed increased to 2 1100 rpm's and the governor valves are cratic.
0150 Attempted to roll main turbine again, continued to have trouble with the governor and throttle valves. The turbine manually tripped.
0515 The turbine reset and latched. The governor valves opened and the throttle valves closed. Suddenly, the throttle valves went wide open and the governor valves caught speed and the turbine rolled to 2 100 rpm.
The turbine manually tripped. A Hi-steam flow safety injection signal received due to high steam flow and Lo-Lo-Tavg. Reactor tripped.
01/16/82 0305 The reactor taken eritical.
0403 Reactor entered mode 1.
0603 Turbine tied on line.
0650 Reactor tripped on a Lo-Lo steam generator #3 level due to steam flow, feedwater flow mismatch during power ascension.
_ - . - = _ _ _ _ _ . -- __- . . _ . _
Significant Operational Events (Continued)
Unit 2 Time Event Date 1630 The reactor taken critical.
01/16/82 2140 The reactor entered mode 1. :
' 2259 Rolled turbine.
0054 The turbine tripped from reverse 01/17/82 power and switchyard bus 1 tripped on breaker failure while attempting to tie on line.
0356 Rolled turb;ne.
n
' 0450 Turbine tied on line.
0518 Reactor trip at 15% power due to steam flow /feedwater flow mismatch.
0955 Reactor taken critical.
I l
t 1538 Rolled turbine.
1643 Turbine tied on line.
I 0630 Re ctor power 32%, 314 MWe.
01/18/82 l
1153 Turbine tripped on a Hi-Hi S/G #2 01/19/82 level alarm when the condensate booster pumps tripped twice be-cause the MFPT ran wide open in auto.
1157 A Lo-Lo S/G #1 level alarm re-I: '
ceived in association with the turbine trip. Reactor tripped.
1209 A safety injection occurred due to excess cooldown of the steam generators.
' 1503 A safety injection due to instrument 01/21/82 mechanics working on the S/G instru-i mentation.
0014 The reactor taken critical.
01/23/82 0200 The reactor entered mode 1.
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Significant-Operational Events (Continued)
Unit 2 Time Event Date 01/23/82 0357 The turbine tied on line.
0530 The reactor at 30% power.
01/26/82 1640 Excessive S/G blowdown caused a high level in #6 heater causing the LP heaters to isolate. The condensate booster pump and main feedwater pmps tripped causing the turbine to trip.
1644 *he reactor tripped on a Lo-Lo S/G
- 2 level as results of the turbine trip.
1800 Reactor taken critical.
2148 Turbine tied on line.
2359 Reactor power 30%.
01/31/82 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 January 1982, to the Assistant Director if Nuclear Power (Operations) for reporting to the "
Nuclear Regulatory Commission.
SUBJECT LER Containment sump level transmitter 1-LT-63-176 SQRO-50-327/151 reading high due to instrument drift.
RWST level transmitter 1-LT-63-50 inoperable SQRO-50-327/154 due to cables damaged by personnel thawing
- frozen sensing lines.
SQR0-50-327/155 D/G 2A-A would not load past 1.3 mega watts during SI-7 and SI-102 due to bad solder joint on speed control motor plug.
,e _
Licensee Events and Special Reports
~
(Continued)
SUBJECT LER Number 3 turbine stop throttle valve inoperable SQR0-50-327/156 due to sticking limit switch.
SQRO-50-327/157 Pressurizer level transmitter 1-LT-68-335 and
-320 failed to channel check due to ncn-con-densable gases in the condensate reservoirs and sensor bellows.
SQR0-50-327/159 AFW pressure control valve 1-PCV-3-132 failed to respond during SI-166.1 testing. Valve operator hydraulic pump not delivering correct discharge pressure.
SQRO-50-327/160 ERCW line radiation monitor 0-RM-90-134/141 inoperable due to spurious high readings caused by unknown noise source.
SQRO-50-138/153 Flow control containment isolation valve 2-FCV-81-12 inoperable. Failed stroke time SI-166.1 test due to tight packing.
AFW turbine driven pump inoperable due to SQRO-50-138/158
~
failure to develop required speed. Input wires to controller 2-FIC-46-57 incorrectly terminated.
SQR0-50-138/001 Ice condenser intermediate deck doors frozen closed due to humidity.
Special Reports
-There was one special report sent- during the month of January.
82-2 Unit 2 Safety Injection due to the turbine throttle valvez opening causing a reactor trip.
Offsite Dose Calculation Manual Changes Changes in-the Sequoyah Nuclear Plant ODCM are described in this section in accordance with Sequoyah Technical Specification 6.14.2.
Change 1 was officially approved by RARC on November 25, 1981.
See Appendix A at the end of this report for the approved ODCM changes by page.
Offsite Dosa Calculation Manuel Chrnges (Continued)
Chaage 1 Description of Chauge Table's 1.3 and 1.4 are revised to reflect corrected typographical errors with attendant potential misinterpretation by various users. Table 1.3 is cor-rected by the addition of appropriate2 "lessa than" mathematical signs (<).
Table 1.4 is corrected by changing m to m ,
Analysis on Evaluation Justifying Change These changes reflect only identified typographical errors and do not affect previous reports.
Evaluation of Accuracy of Dose Calculations or Setpoint Determinations The described changes do not affect any accuracies or setpoint determina-tions.
f
UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET No. 50-327 -
UNIT NAME Sequoyah one DATE Februarv 5. 1982 '
COMPLETED BY Michael Eddines -
REPORT MONTil January, 1981 TELEPHONE (615) 751-0343 1
~
em n aw3 Licensee $ Cause & Corrective No. Date o 30 E oSM Event @i E*e Action to R yg y jty Report # $3 8.3 Prevent Recurrence b
- I
$5 $ $5e m $"
o c Emg A
l 82/01/09 F 122.4 11 1 Steam generator water chemistry out c,f specifications. Operational error.
6 82/01/19 F 2.7 A 3 j Main feed pumps tripped.
, 7 82/01/19 F 292.3 A 3 Fault at B-phase transformer and ice
'f weighting outage.
I 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-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
OPERATING DATA REPORT DOCKET NO. 50-327 DATE February 5, 1982 COMPLETED BY Michael Eddines TELEPHONE (615) 751-0343 OPERATING STATUS i
- 1. Unit Name: Sequoyah One Notes
- 2. Reporting Period: Janunrv. 1982
- 3. Licensed Thermal Power (MWL):
~
3411
- 4. Nameplate Rating (Gross MWe): 1220.58
- 5. Design Electrical Rating (Net MWe): 1148
- 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 Cunulative
- 11. Hours in Reporting Period 744 744 5185
- 12. Number of Hours Reactor Was Critical 332.9 332.9 3134.2
- 13. Reactor Reserve Shutdown Hours 0 0 0
- 14. Hours Generator On-Line 326.6 326.6 3017
- 15. Unit Reserve Shutdown Hours 0 0 0
- 16. Gross Thermal Energy Generated (MWH) 17.
830,115 830,115 9,725,72/~
Gross Electrical Energy Generated (MWH) 286,760 286,760 2,932,710
- 18. Net Electrical Energy Generated (MWH) 267.612 267,612 2,794,637
- 19. Unit Service Factor 43.9 43.9 58.5
- 20. Unit Availability Factor 43.9 43.9 58.5
- 21. Unit Capacity Factor (Using MDC Net) 22.
31.9 31.9 48.1 Unit Capacity Factor (Using DER Net) 1.9 31.9 48.1
- 23. Unit Forced Outage Rate 36.1 56.1 41.5
- 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: February 6, 1982
- 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)
~ - -. -. -. ..
T 4
AVERAGE DAILY UNIT POWER LEVEL DOCKET No. 50-327
- UNIT One DATE February-5, 1982 COMPLETED BY Michael Eddings-TELEPlf0NE (615) 751-0343 NONTl! _ January,-11982
- DAY AVERAGE DAILY POWER LEFEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (HWe-Net)-
1 997 17 257 2 1101 213 18 3 1102 410 19 4 1102 0-20
, 5 1103 0 21 l
6 1104 0 22 7 1102 0 23 8 1099 0
-t 24 9 526 0 25 10 0 0 26 11 0 0 27 12 0 0 28 13 0 0 29 14 0 0 30 15 253 0 31 16 234
. INSTRUCTIONS i
On this format, list the average daily unit power level in MWe-Net for each day in 4 the reporting month. Compute to the nearest whole megawatt.
f (9/77) 1.
j . _ . . _ . . , . . . _ .-. _ _ _ _ __ __ .
UNIT SIIUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-328 .
UNIT NAME q , n ,, mm.a, r, m l
DATE FohrdErb R.
~
19R?
~
COMPLETED BY David Dunree -
f REPORT MONTH January TELEPHONE (615) 751-0343 I
I i
Q c -s N ou3 Licensee U Cause & Corrective No. Date -( jl $ @ x, C % Event O '$ $"k Action to i R yy y jdy Report # $3 E.3 Prevent Recurrence H
$5 $ U5c N" $"
c xmg a o ;
81-3 81/01/01 F 366.0 A 4 Turbine trip from high level S/G feed water .
valve went open on Auto. Rx Trip due to
- i. Iow S/G 1evel.
82-2 'G l 82/01/16 F 22 3 S/G 1evel indicators are slow in responding and there is no steam flow / feed flow indica-Y tions. Rx Trip: Lo-Lo level #3 S/G.
82-3 82/01/17 F 11.4 A 3 Rx Trip #6: Lo-Lo level #3 S/G.
82-4 82/01/19 F 88.1 A 3 Turbine Trip: 111 -111 S/G IcVel, feed pump valve went open when going to auto.
Rx Trip #7: Lo-Lo level #1 S/G 82-5 82/01/26 F 5.1 A 3 Feed water flow isolated causing turbine trip / reactor trip.
I 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 (LCL) File (NUREG-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) II-Other (Explain) Exhibit 1-Same Source
m_ ,
OPERATING DATA REPORT DOCKET NO. 50-328 DATE January 8, 1982 COMPLETED BY David Dunree TELEPlf0NE (615) 751-0343 OPERATING STATUS
- 1. Unit Name: Sequoyah Two Notes
- 2. Reporting Period: January, 1982
- 3. Licensed Thernal Power (MWt): 3411
- 4. Nameplate Rating (Gross MWe): 199n s
- 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):
- 10. Reasons For Restrictions, If Any:
This Month Yr-to-Date Cumulative
- 11. Ilours in Reporting Period 744 744 2208
- 12. Number of liours Reactor Was Critical 336.2 336.2 593.4
- 13. . Reactor Reserve Shutdown flours 0 0 0
- 14. Ifours Generator On-Line 251.4 251.4 265
- 15. Unit Reserve Shutdown llours 0 0 0
- 16. Gross Thermal Energy Generated (MWil) 244.601 244.601 260.515
- 17. Gross Electrical Energy Generated (NWil)
- 18. Net Electrical Energy Generated (MWil) 65.210 65.210 67.114 48.112 48.112 48.112
- 19. Unit Service Factor 33.8 33.8 12.0
- 20. Unit Availability Factor '
33.8 33.8 12.0
- 21. Unit Capacity Factor (Using MDC Net) s6 5.6 1.9
- 22. Unit Capacity Factor (Using DER Net) 23.
s.s 5.5 1.8 Unit Forced Outage Rate 66.? 66.2
- 24. 88.0 Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):
Ice We!nhing. 5-5-82 per Tech Specs
- 25. If Shut Down At End Of Heport Period, Estimated Date of Startup:
- 26. Units In Test Status (Prior to Ccamercial Operation):
Forecast Achieved INITIAL CRITICALITY 11-5-81 11-5-81 INITIAL ELECTRICITY 12-31-81 12-23-81 COMMERCIAL OPERATION 4-1-82 NA (9/77)
_ . . .. . . - - = _ -. _
m
< AVERAGE DAILY UNIT POWER LEVEL 4
i DOCKET NO. '50-328 UNIT Two DATE Februnrv 8. 1982 COMPLETED BY David Dupree
- TELEPHONE (615) 751-0343 MONTH January, 1982 i
DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net)
(MWe-Net) 17 0
1 0 18 212 2 0 1
19 98 3 0 0
4 0 20 0
5 0 21 0
6 0 22 23 213
'7 0 24 247 8 0 25 123 9 0 26 197 10 0 27 264 11 0 28 167 12 0 29 264 13 o 30 201 14 0 .
219 0 31-4 15 _
j 16 0 INSTRUCTIONS 1'
On this format, list the average daily unit power level in tIWe-Net for each day in the reporting month. Compute to the nearest whole megawatt.
(9/77)
--r - r , - - , , , - . _ . . - * . , - - - , y -
Plant Maintenance Summary' The follcwing significant maintenance items were completed during the month of Janaury 1982:
Mechanical Maintenance
- 1. Weighed 180 baskets in Unit 1 ice condenser and inspected the intermediate deck doors and lower inlet bay doors.
- 2. Repacked valves 2-FCV-63-39 and 2-FCV-63-40.
- 3. Repaired steam generator blowdown valve 2-FCV-1-14.
Electrical Maintenance
- 1. Repaired the neutral ground transformer as results of the explosion.
- 2. Repaired a breaker _ locking out problem on the safety injection system.
Instrument Maintenance None reportabic.
Field Services Maintenance Work continues on the following items.
- 1. A post accident sample 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 - 454 repairs are completed and 59 identi fied repairs remaining.
- 3. To replace the 4-inch piping on the HVAC equipment (Trains A and B).
serving the electric board rooms and main control room, hangers and-piping is being fabricated a^nd installed.
- 4. Exposed cables in areas outside primary containment containing one or both safety related divisions are being coated with Flamastic.
- 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 transmitter.
Field Services Maintenance (Continued)
- 7. A reactor vecsel head venting system is being installed to Unit 1.
- 8. Conduit is being installed to facilitate high range area radiation monitors near effluent release points, Unit I residual heat removal lines and inside containment.
- 9. Solenoids are being replaced on valves in accordance with NUREG 0588.
The following work was completed during the month.
, room chiller 1A has been replaced with stainless steel piping.
- 2. To comply with TVA's SQN radiological emergency plan, the telephones nd radios located in the health physics laboratory, elevation 706', have been moved to the health physics laboratory, elevation 690', service building.
- 3. To ensure the proper operation cf the pressurizer instrumentation system, the Unit 1 pressurizer condensate reservoirs have been replaced with redesigned reservoirs.
- 4. Radiation flow monitor 0-RE-90-212 has been replaced with a monitor-that is more tolerant of crud and debris.
O e
l 4
k APPENDIX A DOCUMENTATION FOR ODCM CHANGES .
1 l
t
-17_
TABLE 1.4
, SEQUOYAH NUCLEAR PLANT LAND SITE BOUNDARY DATth
- f I
..t k Sector Distance (m) X/O (s/ ? D/O (3-2)
N 950 5.13(-6) 1.29(-5)
NNE 2,260 1.94(-6) 5.2d(-9)
NE 1,910 2.33(-6) 6 . 3 3 ( ~-9 )
ENE 1,680 1.12(-6) 2.64(-9)-
E 1,570 7.11(-7) 1.46(-9) i ESE 1,460 7.92(-7) 1.58(-9Y SE 1,460 9.17(-7) 2.41(.9)
SSE 1 , 5 5,0 1.34(-6) 3.23(-9)
S 1,570 2 37(-6) 4 .13 ( -9 )
SSW 1,840 4.51(-6) 9.26(-9)'
SW 2,470 1.38(-6) 2.6 3 ( -9 )
hfl. WSW 910 2.93(-6) 3.66(-9)
W 670 3.63(-6) 3.74(-9)
, WNW 660 2.49(-6) 2.4h(-9) 1 NW 660 2 . 8,5 ( -6 ) 3.67(-9)
NNW 730 3.96(-6) 6.59(-9) 9
'All release points treated as ground level.
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JOINT FERCENTAGE FREOUENCIES OF WIND DIRECi!ON AND WIND SPEED .
FOR DIFFERENT STABILITY CLASSES' STABILITY ASS E '
-0.5 4 DELTA-T (a 1 DEG. C/100M SEQUOYAH NUCLEAR FLANT METE 0BOLOGICAL FACILITY' JAN 1, 72 - DEC 31, 75 WIND WIND SPEED (MPH)
DIPEC~IGN CALM 0.6-1.4 1.5-3.4 3 5-5.4 5.5-7.4 7.5-12.4 12.5-18.4 18.5-24.4 =24.5 TOTAL.
N .017 0.23 1.25 0.83 0.39 0.27 0.0 0.0 0.0 2.9B N!.T .023 0.31 2.83 2.46 1.07 0.92 0.03 0.0 0.0 7.62 NE .011 0.15 1.03 0.71 0.31 0.18 0.01 0.0 0.3 2.39 E!.T .009 0.12 0.48 0.16 0.04 0.0 0.0 0.0 0.0 'O.80 E .010 0.14 0.24 0.05 0.01 0.01 -
0.0 0.0 0.0 0.45 ESE .007 0.09 0.11 0.01 0.01 0.01 0.01 0.0 ' 0.0 0.24 SE .007 0.10 0.37 0.06 0.01 0.01 0.0 0.0 0.0 0.55 SSE .008 0.11 0.58 0.24 0.13 0.23 0.04. 0.02 0.0 1.35 S .013 0.17 1.33 1.49 0.91 1.05 0.03 0.0 0.0 5.03 SSW .007 0.10 1.67 2.32 1.67 1.45 0.11 0.0 0.0 7.32 SW .013 0.17' 1.59 2.07 1.30 0.99 0.10 0.0 0.0 6.22 i W3W .010 0.13 0.87 0.55 0.35 0.40 0.06 0.0 0.0 ' 2.36 U W .007 0.10 0.42 0.28 0.21 0.22 0.03 0.0 0.0 1.26 8 WNW .010 0.14 0.37 0.22 0.19 0.27 0.02 0.0 0.0 1.21 NW .007 0.10 0.50 0.37 0.43 0 33 0.02 0.0 0.0 1.80' N'!W .011 0.15 0.80 0.68 0.57 0.40 0.01 ' 0.0 0.0 . 2.51 SU3:0r.u. - 0.17 2 31 14.45 12.50 7.60 6.79 0.52 0.02 0.G 4 '4. M 14524.,T. 3ILITY CLASS E CCCU3RENCES OUT OF TOTAL 32723 VALID TEltPERATURE I. 'FERENCE READINGS 14146 7ALID WIND DIRECTICS - WIND SFEED READiriCG OtJT CF TOTAL 14624 ST4BI'.lTY CLASS E OCCURREt/GES ALL COLUMS A!.D CALM TOTAL 100 PERCENT CF NET VALID READING 3
'CIILR10GI AL FACILITY LC0ATED .74 MILS 3 SW CF SEQUOYAH NUCLEAR PLANT
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