ML20053B782
| ML20053B782 | |
| Person / Time | |
|---|---|
| Site: | Sequoyah  |
| Issue date: | 05/14/1982 |
| From: | Mason C TENNESSEE VALLEY AUTHORITY |
| To: | |
| Shared Package | |
| ML20053B780 | List: |
| References | |
| NUDOCS 8206010229 | |
| Download: ML20053B782 (24) | |
Text
I TENNESSEE VALLEY AUTHORITY
}-
DIVISION OF NUCLEAR POWER SEQUOYAH NUCLEAR PLANT a
(
i MONTHLY OPERATING REPORT APRIL 1, 1982 - APRIL 30, 1982 s
UNIT 1 DOCKET NUMBER 50-327 i '
LICENSE NUMBER DPR-77
. NIT 2 DOCKET NUMBER 50-318 LICENSE NUMBER DPR-79 r
Submitted By:
[
[40(V Power Plant Superintendent 8206010267
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i TABLE OF CONTENTS 1
Operations Susunary.
1 Significant Operational-Events.
1-7 1
PORV's and Safety Valves Susanary.
7 t
Licensee Events and Special Reports 7-9 1
Offsite Dose Calculation Manual Changes 9
Operating Data i
n Unit 1
. 10-12 4
Unit 2
. 13-15.
1 i
Plant Maintenance Sununary
. 16 Field Services Maintenance Sununary.
. 16-17 Appendix A.
. 18-22 I
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Operations Summary April, 1982 The following summary describes the significant operational activities for the month of April.
In support of this summary, a chronological log of significant events is included in this report.
Unit 1 Unit I was critical for 671.4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, produced 680,790 MWii (gross) with 4.16 percent station service use resulting in an average hourly gross load of 1,113,129.5 KW during the month. The net heat rate for the month was 10,590 BTU /KWII. There are 123.63 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 September 22, 1982. The capacity factor for the month was 81.4 percent.
There were three reactor scrams, one manual shutdown, and two power re-ductions during April.
Unit 2 Unit 2 was critical for 593.27 hours3.125e-4 days <br />0.0075 hours <br />4.464286e-5 weeks <br />1.02735e-5 months <br />, produced 537,900 MWil (gross) with 5.02 percent station service use, resulting in an average hourly gross load of 924,862.4 kW during the month. The net heat rate for the month was 10,790 BTU /KWii. There are 341.89 full power days estimated remaining until the end of cycle 1 fuel. With a capaci.ty factor of 85 percent the target EOC exposure would be reached June 6, 1983.
The capacity factor for the month was 63.24 percent.
There were four reactoc scrams, no manual shutdowns, and five power reductions during April.
Significant Operational Events Unit 1 Date Time Event 04/01/82 0001 Reactor in mode 1 at 100% power pro-ducing 1140 MWe.
04/03/82 0900 Cooling Tower 1 placed in helper mode.
1200 Cooling Tower 1 taken out of helper mode. l
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Significent Operationel Evsnts (Continued)
Unit 1 Date Time Event 04/05/82 0230 Cooling Tower 1 placed in helper mode.
0630 Cooling Tower 1 taken out of helper mode.
04/12/82 0430 Cooling towers in helper mode.
0812 Began load reductions to perform SI's on Tavg and AT loops.
0910 Reactor at 90% power and holding.
1411 Began power increase.
2220 Reactor at 100% power, 1130 MWe.
04/16/82 0124 Cooling towers taken out of helper mode.
0600 Reactor at 100% power with load swing between 1110-1144 MWe.
04/20/82 2004 Reactor at 100% power producing 1125 MWe. The current limiting resistor on C $ metering pot transformer was found burning. This was determined j
to be the load swing problem.
2005 Began load reduction to replace the burnt resistor.
04/21/82 0044 The turbine was manually tripped.
0105 NFPT tripped on Hi-Hi #4 steam generator level. The loss of feed-water flow caused a Lo-Lo #1 steam generator level thus the reactor tripped.
0700 Reactor was taken critical.
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0850 The reactor entered mode 1.
0857 Reactor tripped when a first out Hi flux rate alarm was received while testing the M/G set breakers. While paralleling A M/G back with B the output breaker tripped. IL
Significant Operational Events (Continued)
Unit 1 Date Time Event 1300 The reactor was taken critical.
1918 Unit tied on line.
04/23/82 0220 Reactor at 100% power producing 1160 MWe.
04/25/82 2330 Began controlled shutdown due to arcing in the bus duct.
04/26/82 0248 Manually tripped the turbine.
0435 Reactor in mode 2 at 4% power.
2130 Work on the control rod circuit began.
(
04/27/82 0700 Reactor tripped from 1% power due to control rod M/G set problems.
04/29/82 0202 Reactor taken critical.
0225 Reactor in mode 2 at 2% power and holding for work on letdown valve FCV-62-70.
1713 Reactor entered mode 1.
1850 The main turbine and B MFP tripped due to Hi-Hi #4 steam generator level. Reactor dipped to 2% power.
1 1925 Reactor entered mode 1.
1937 Unit tied on line.
04/30/82 0510 Reactor at 100% power producing 1157 MWe.
2359 Reactor in mode 1 at 100% producing 1160 MWe.
I Unit 2 04/01/82 0001 Reactor in mode 1 at E 75% increasing to 100%.
1 Significant Operational Events i
(Continued)
Unit 2 Date Time Event 04/01/82 0537 Reactor at 100% power producing 1125 MWe.
I 0955 Began reducing load to 65% for chemistry and work on NFPT B governor valve.
1400 Reactor at 65% power producing 740 MWe.
04/02/82 0020 Began power ascension.
2010 Reactor at 100% power producing 1131 MWe.
04/03/82 0900 Cooling tower in helper mode.
04/05/82 1357 Reactor tripped due to loop 1 low flow while IM's were working on 2-FIT-68-8B.
IM's picked up 2/3 bistables initiating the trip.
l 04/06/82 0729 Began cooling down to mode 5 to replace the steam generators pres-sure transmitter root valves with qualified valves.
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1334 Reactor entered mode 4.
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2135 Reactor entered mode 5.
2150 Cooling tower out of helper mode, f
2200 Began draining #2, 3 and 4 steam generators.
04/08/82 0430 All steam generators are filled.
i 1320 Began heatup.
1445 Reactor entered mode 4.
2117 Reactor entered mode 3.
04/09/82 0130 Began cooling down to 205 F to replace a plug on auxiliary feedwater check valve 2-3-92..
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Significent Operational Events (Continued)
Unit 2 Date Time Event 04/09/82 0355 Reactor entered mode 4.
l 1700 Maintenance completed on auxiliary feedwater check valve - began heatup.
04/10/82 0305 Reactor entered mode 3.
1204 Reactor taken critical.
2008 Unit tied on line.
2325 Reactor at 30% power, producing 300 MWe and holding for secondary chemistry.
04/11/82 1000 Decreased load to 20% for turbine overspeed test.
1129 Unit off line for overspeed test.
i 1205 Unit on line.
I 1253 Reactor at 30% power producing 300 MWe.
1500 Began power ascension.
04/12/82 0559 Reactor at 100% power producing 1130 MWe.
04/13/82 0238 2A condensate booster pump tripped reduced load to 85%.
1237 2A condensate booster pump back in service.
1320 Began power ascension.
1508 Reactor at 100% power producing 1139 MWe.
04/14/82 1237 A thrust bearing Hi wear alarm caused MFPT A to trip causing Lo-Lo #2 steam generator level thus the reactor tripped.
1622 Reactor taken critical.
Significant Operational Events (Continued)
Unit 2 i
Date Time Event i
04/14/82 1650 Unit on line increasing power slowly due to vibration problems on A MFPT.
04/16/82 2330 Reactor at 67% power, producing 769 MWe. Began load reduction to 60%
due to #2 governor valve moving on and off seat.
j 2400 Reactor at 60% power producing 694 MWe.
04/17/82 0700 Reducing load to 58% due to A MFPT i
vibration.
0759 Reactor at 58% power producing 650 MWe.
04/21/82 0518 Began power ascension.
1040 Reactor at 79% power producing 910 MWe and experienced an = 4% turbine roll back.
1135 Experienced turbine roll back again.
1646 Reducing power, loops 2 and 4 OP AT bistables were determined to have the wrong setpoints.
1700 Reactor at 77% power producing 869
- MWe, 1722 Loop 2 OP AT returned to service and began increasing power.
1816 Loop 4 OP AT returned to service.
2108 Reactor at 100% power producing 1110 MWe.
04/29/82 2353 Overspeed turbine trip and other alarms came in apparently on annunciator indication only.
04/30/82 0422 Received annunciator false alarms again.
Significant Operational Events (Continued)
Unit 2 Date Time Event 04/30/82 1010 B MFPT tripped due to a ground on the 250V DC trip bus. Reactor tripped on Lo-Lo #2 steam generator level.
1213 Reactor taken critical.
1246 Reactor tripped on Lo-Lo steam generator level during start-up.
1457 Reactor taken critical.
1615 Reactor entered mode 1.
1644 Unit tied on line.
2359 Reactor at 30% power producing 280 MWe and holding for secondary chemistry.
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 April 1982, to the Assistant Director of Nuclear Power (Operations) for reporting to the Nuclear Regulatory Commission.
Unit'l LER SUBJECT SQRO-50-327/82036 AFW automatic control valve 1-LCV-3-164 failed to open during SI-276 due to faulty electro-pneumatic positioner.
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SQR0-50-327/82036 Excore neutron instrumentation power range channel N-41 failed low due to inoperable high voltage power supply.
SQRO-50-327/82040 RCS loop 2 temperature. indicator.1-TI-68-25 inoperable due to setpoint out of spec caused by temperature modifier zener diode failure. _
Licenzee Events and Special Reports Unit 1 LER SUBJECT SQRO-50-327/82041 Pressurizer level transmitter 1-LT-68-335 failed surveillance test due to reference leg being drained.
SQRO-50-327/82043 Westinghouse qualification tests shown RCS wide range pressure channels 1-PT-68-66, 68, 2-PT-68-66, 68, and 69 not qualified for high energy line break invironment.
SQRO-50-327/82046 Post maintenance test SI-166.6 not performed on S/G blowdown isolation valve 1-FCV-1-184 due to personnel error.
I Unit 2 SQRO-50-328/82037 UHI isolation valves 2-FCV-81-21 and 23 closed on low level signal from accumulator tank caused by pressure drop due to samples being taken.
SQRO-50-328/82038 AFW automatic control by-pass valve 2-LCV-2-171A failed to open because the to electro pneumatic valve transducer failed to actuate properly.
SQRO-50-328/82042 AFW automatic control valve 2-LCV-3-171 failed to open on command due to improperly functioning electro-pneumatic positioner.
SQRO-50-328/82044 Containment purge air rad monitors RM-90-130/131 were found with inadequate sample points because there were not any sample lines from the train 'B' filter exhaust.
l SQRO-50-328/82045 Power operated relief block valve 2-FCV-68-333 would not close completely from the control room due to improne torque switch setting.
I SQRO-50-328/82047 During SI-566 ERCW flow through containment spray l
heat exchanger 2B found to be 800 gpm due to valve j
2-FCV-67-537B improperly positioned.
l SQR0-50-328/82049 Op e r containment airlock door found jammed closed dn to failure of a cam roller bearing in the i
eating mechanism.
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W Special Reports t
There was one special report sent during the conth of April.
n Spr:cial Report
)y Number Deacription
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N 6202 Unit 1 fire barrier penetration was inoperable for more thin seven days.
Offsite Dose Calculation Manual Changes l),
Changes in the Sequoyeh Nuclear Plant ODCM are described in this 6
section in ceterdance with Sequoyah Technical Specification 6.14.2.
These et srges were officially approved +by RARC on October 22, 1981.
See appendix b at the eed of this ' report of this a.pproved ODCM page changes.
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OPERATING DATA REPORT 50-327 DOCKET No.
DATE May 6, 1982 4
COMPLETED BY M. Eddings j
TELEPHONE (615) 751-0343 OPERATING STATUS 1.
Unit Name:
Sequ yah One 2.
Reporting Period:
April, l')S Z
~~
Notes
+
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):
1163 7.
Maximum Dependable Capacity (Net MWe):
1148 8.
If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasone:
9.
Power Level To Which Restricted, If Any (Net MWe):
10.
Reasons For Restrictions, If Any:
This Month Yr-to-Date Cumulative 11.
Hours in Reporting Period 719 2,879 7,296 12.
Number of Hours Reactor Was Critical 6/1.4 1,304-4,303 3 13.
Reactor Reserve Shutdown Hours 0
0 0
14.
Hours Generator On-Line 611.6 1,462 4,152.4 15.
Unit Reserve Shutdown Nours 0
0 0
16.
Gross Thermal Energy Generated (MWH) 2,016,499 4,520,633 12,585,587 17.
Gross Electrical Energy Generated (MWH) 680,790 1,526,980 4,172,930 18.
Net Electrical Energy Generated (MWH) 652,435 1,448,320 3,975,345 19.
Unit Service Factor 85.1 50.8 56.9 20.
Unit Availability Factor 85.1 50.8 56.9 21.
Unit Capacity Factor (Using MDC Net) 80.5 44.6 48.3 22.
Unit' Capacity Factor (Using DER Net) 80.5 44.6 48.3 23.
Unit Forced Outage Rate 14.9 39.1 27.3 24.
Shutdowns Scheduled Over Next 6 Months (Twe, Date, led) 6 Months and Duration of Each):
Refueling / Modification Outage September 21 (Schedu 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 7-4-30 7-5-80 INITIAL ELECTRICITY 8-21-80 7-22-80 COMMERCIAL OPERATION 7-1-81 7-1-81 (9/77) l aa'
UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET No.
50-327 UNIT NAME Sequovah one DATE May 6. 1982 COMPLETED BY M. Eddines REPORT MONTH April _
TELEPIl0NE (615T 751-0143 a
yw3 Licensee gn Cause & Corrective em u
g No.
Date
.S $
y.5 Event 3.g g.g Action to R
y8 g
juy Report #
gg o.g Prevent Recurrence f6 M
$5
- n v. {c 12 82/04/21 F
18.6 A
3 Lo-Lo #1 S/G Level - Feedwater Controls Failed to Cor. trol in Auto Rx Tripped 8%
Power 13 82/04/26 F
88.8 A
3 Control Rod M/G Set Problems 3
I 4
d 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-D-Regulatory Restriction 4-Cont. 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 1
DOCKET NO.
50-327 UNIT Sequoyah One DATE May 6, 1982 COMPLETED BY M. Eddings TELEPIIONE (615) 751-0343 MONTil April DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net)
(MWe-Net) 1 1111 17 1100 2
1106 18 1096 3
1104 19 1091 4
1107 2n 1009 5
1101 21 48-6 1099 22 593 7
1078 23 1120 8
1096 24 1120 9
1099 25 1074 10 1095 26 79 11 1098 27 0
12 1071 28 0
13 1092 29 408 14 1096 30 1070 15 1090 31 16 1088 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).
.V G&
OPERATING DATA REPORT DOCKET NO.
50-328 DATE May 6, 1982 COMPLETED BY David Dupree TELEPHONE (615) 751-0343 OPERATING STATUS 1.
Unit Name:
Sequoyah Two Notes 2.
Reporting Period:
April 1982 3.
Licensed Thermal Power (MWt):
3411 4.
Nameplate Rating (Gross MWe):
1220.5 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.
Hours in Reporting Period 719 2,879 4,343 12.
Number of Hours Reactor Was Critical 393 3 1,881 Z,138.2 13.
Reactor Reserve Shutdown liours 0
0 0
~~
14.
Ilours Generator On-Line 581.6 1,748 1,761.6 15.
Unit Reserve Shutdown llourn 0
0 0
16.
Gross Thermal Energy Generated (MWH) 1,611,435.6 3,352,788.9 3,368,702.9 17.
Gross Electrical Energy Generated (MWH) 537,900 839,840 1,077,204 18.
Net Electrical Energy Generated (MWII) 510,873 986,343 986,293 19.
Unit Service Factor 80.9 60.7 40.6 20.
Unit Availability Factor 80.9 60.7 40.6 21.
Unit Capacity Factor (Using HDC Net) 61.9 29.8 19.8 22.
Unit Capacity Factor (Using DER Net) 61.9 29.8 19.8 23.
Unit Forced Outage Rate
. ].1 39.3 59.4 i
24.
Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):
Ice weighing per Tech Specs 5/15/82.
25.
If Shut Down At End Of Report Period, Estimated Date of Startup:
N/A 26.
Units In Test Status (Prior to Commercial Operation):
Forecast Achieved INITIAL CRITICALITY 11-5-81 11-5-81 INITIAL ELECTRICITY 12-31-81 12-31-81 COMMERCIAL OPERATION 6-1-82 NA t
(9/77) '
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UNIT SHUTDOWNS AND P0kT.R REDUCTIONS DOCKET NO.
50-328' UNIT NAME Sequovah Two DATE May 4, Im COMPLETED BY David Dupree REPORT MONTH April TELEPHONE (615) 751-0343 u
jw3 Licensee g,
Cause & Corrective e,
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.S $
E y5g Event 3.g gg Action to R
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,8 u y Report #
gg g-g Prevent Recurrence 05 a
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82/04/01 F
0 F
5 Derate for Steam Generator Chemistry.
17 82/04/05 F
126 B
3 Instrumentation Working on Sense Line (#1 Loor )
Caused All Three F.T.'s to Pick Up Low Flow,
,Rx Trip 5'
18 82/04/11 S
.6 B
5 Perform Turbine Overspeed Test, Rx @ 20%
(Off Line) 19 82/04/14 F
4.2 A
3 Thrust Bearing Tripped Caused Turbine Trip, Rx Trip (Lo-Lo S/G Level) 20 82/04/30 F
6.6 A
3 2 'B' MFPT Tripped Due to Bad Coil in Rack 2-R-72, Caused Turbine Trip, Rx Trip 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-D-Regulatory Restriction 4-Cont. 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
(
)
AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.
50-328 UNIT.
Seauovah Two DATE May 6,1982 COMPLETED BY David Dupree TELEPHONE (615) 751-0343 MONTH April, 1982 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (HWe-Net)
(MWe-Net) 1 870 17 627 906 612 3
1107 19 603 4
1107 20 619 5
644 21 849 6
0 22 1098 7
0 23 1103 8
0 24 1105 9
0 25 1063 10 30 26 1085 11 401 27 1101 12 1082 28 1098 13 1047 29 1100 14 636 30 542 15 431 31 16 650 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)
~
Plant Maintenance Summary The following significant maintenance items were completed during the month of April 1982:
Mechanical Maintenance 1.
Changed out the diaphragm in the radwaste DI pump.
2.
Repaired a leak on 2A MFPT stop valve.
3.
Balanced and aligned 2A MFPT.
Electrical Maintenance None reportable on CSSC equipment.
Instrument Maintenance None reportable on CSSC equipment.
Field Services Maintenance Work continues on the following items:
1.
The auxiliary instrument room floors must be painted before the power cabinets for the reactor head venting system can be mounted.
2.
Conduit installation and inspection continues for the high range area radiation monitors for the residual heat removal lines and containment spray heat exchanger room 1A.
3.
Alarms are being installed on the containment hatches and doors. Cable pulling, termination and functional testing is all that remains to be done.
4.
Door A-183 is being replaced and a card reader installed.
5.
Security barriers are being installed on 28 vented grills and ducts.
I 6.
The steam generator preservation modification will be tied in during the Unit 2 outage.
7.
A post-accident sample system for Unit 1 is being installed. The installa-tion of the demineralizer water lines is in progress.
8.
EN DES is evaluating the hanger inspection for deficiencies.
9.
Changing the ERCW carbon steel piping to stainless steel piping continues.
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Field Services Maintenance The following work was completed during the month.
1.
All exposed cables in areas outside primary containment containing one or
]
both safety related divisions ~have been coated with Flamastic.
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2.
The flow switches on radiation monitor-1-RE-90-170 have been replaced.
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APPENDIX A Change 1 Description of Change Page 22, the definition of "v" in equation 2.12 is changed to read, "v =
maximum individuals water consumption rate (2,000 mL/d)." This thange also results in a changg in equation 2.13.
The constant in the equation changes from 1.57 x 10 to 4.30 x 10 3 8
Analysis or Evaluation Justifying Change A daily water ingestion rate for maximum individuals of 2,000 milliliter (mL) replaces the previously used 730 mL.
The value of 2,000 is recommended in Regulatory Guide 1.109 and is mandated in 40 CFR 141, " National Interim Primary Drinking Water Regulations." The previously used value of 730 mL is the aveage individual consumption rate and will continue to be used for calculating quarterly population doses.
Evaluation of Accuracy of Dose Calculations or Setpoint Determinations This change increased the similarity to the model in Regulatory Guide 1.109.
liigher doses per unit release are calculated for the maximum individual. No change is made in setpoint determinations.
Chaage 2 Description of Change Page 25, the definition of "v" in equation 2.18 is changed to read, v = water consumption rate:
maximum individual - 2,000 mL/d average individual - 730 mL/d l
Analysis or Evaluation Justifying Change See change 1.
Evaluation of Accuracy of Dose Calculations or Setpoint Determinations See change 1. N
~
APPENDIX A Change 3 Description of Change Table 2.1, the biological and effective half-life for I-130 is changed to 138 and 0.517 respectively. For Cs=135 both the biological and effective half-lives are changed to 70.
Analysis or Evaluation Justifying Change Previous values were incorrect.
Evaluation of Accuracy of Dose Calculation and Setpoint Determination Dose calculations involving I-130 and Cs-135 will be more accurate. No effect on setpoint determination.
Change 4 Description of Change Table 3.1-1 (4 pages), clarifying changes are made in the description of sample collection and analysis frequencies.
Analysis or Evaluation Justifying Change Changes were made to guarantee a minimum time between sample collections. The following is an example of the changes made: " Monthly" was changed to "once per 31 days."
These changes should better ensure that any significant environ-mental radioactivity levels will be detected.
Evaluation of Accuracy of Dose Calculations or Setpoint Determinations No effect.
Change 5 Description of Change Table 3.1-1, 3.e on page 3 of 4; semiannual collection of river sediment at Tennessee River Miles 485, 476, and 477 is added. Figure 3.1-4 is modified j
to indicate sample points.
l l
Analysis or Evaluation Justifying Change l
Predicted doses to man identified external exposure due to buildup of radio-activity in river sediment as a dose pathway.
[
Evaluation of Accuracy of Dose Calculations or Setpoint Determinations l
No effect. i
s APPENDIX A Change 6 Description of Change Table 3.1-1, 4.d on page 4 of 4; add collection of vegetation samples at locations of milch animals if a sample of milk is not available. Figure 3.1-6 is added to indicate sample points.
Analysis or Evaluation Justifying Change Because the relationship of activity ingested to activity in milk is fairly well known for milch animals, collection of vegetation samples allows evaluation of milk from nearby producers who are unwilling or unable to supply sufficiently large samples.
Evaluation of Accuracy of Dose Calculations or Setpoint Determinations No effect.
Change 7 Description of Change Figures 3.1-1, 3.1-3, 3.1-4, 3.1-5, and 3.1-6 have been changed to identify current monitoring locations. Both changes and additions have been made.
Analysis or Evaluation Justifying Change A thorough evaluation of monitoring locations were made to determine the locations most likely to provide measurable radioactivity levels as a result of plant releases. The locations chosen should provide results for any significant plant release.
Evaluation of Accuracy of Dose Calculations or Setpoint Determinations No effect.
Change 8 The following typographical errors were corrected. No model changes are reflected in these corrections and, therefore, no evaluations are necessary.
a.
Page 22, third line, the definition of "k" is deleted. This factor no longer appears in equation 2.11.
b.
Page 25, first line, "jth" should be "ith".
2 c.
Page 6, the units for "G " should be pCi/m,
g i
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9 APPENDIX A d.
Page 7, the term in brackets in equation 1.7 should be
+
Il - eXP(-A t )]
r[1 - exp(- AEi e}
iv i3 v Ei i
Page 7, the unit for "DR" sould be m' e.
3 f.
Page 8, the units for."X " should be pCi/m.
T g.
Page 9, the units for "CM " should be pCi/1.
g 8
h.
Page 15, the units for "DF " should be pCi/cm.
14 1
4 4
4 4
6 3
4 b
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a APPENDIX A SEQUOYAH NUCLEAR PLANT OFFSITE DOSE CALCULATION MANUAL EFFECTIVE PAGE LISTING Page Revision
Revision 3 6
Original 7
Revision I l
8 Original 9
Revision I l
10 Original 11 through 16 Revision l
Table 1.1 (2 pages)
Original Table 1.2 (2 pages)
Original Table 1.3 (8 pages)
Original Table 1.4 Original Table 1.4A Revision 3' Table 1.5 through 1.8 Original Figures 1.1 through 1.2 Original Figure 1.3 Revision 3 17 Original 18 through 19 Revision 2 20 through 21 Revision 3 22 New 23 through 24 Revision 3 25 New Table 2.1 (3 pages)-
New 26 Original Table 2.1-1 (4 pages)
New Table 3.1-2 through 3.1-3 Original Table 3.2-1 (3 pages)
Original Figures 3.1-1 New Figure 3.1-2 Original Figures 3.1-3 through 3.1-6 New
- Substantive revisions discussed in this report are referred to as "new."
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