ML20087M668
| ML20087M668 | |
| Person / Time | |
|---|---|
| Site: | Sequoyah  |
| Issue date: | 02/29/1984 |
| From: | Eddings M, Mason C TENNESSEE VALLEY AUTHORITY |
| To: | NRC OFFICE OF RESOURCE MANAGEMENT (ORM) |
| References | |
| NUDOCS 8403300154 | |
| Download: ML20087M668 (51) | |
Text
_
i TENNESSEE VALLEY AUTHORITY
[
DIVISION OF NUCLEAR POWER SEQUOYAH NUCLEAR PLANT 4
MONTHLY OPERATING REPORT TO THE NUCLEAR REGULATORY COMMISSION FEBRUARY 1, 1984 - FEBRUARY 29, 1984 UNIT 1 DOCKET NUMBER 50-327 LICENSE NUMBER DPR-77
. UNIT 2 DOCKET NUMBER 50-328 LICENSE NUMBER DPR-79 i
Submitted By:
j Power Plant Superintendent 8403300154 840229 g gg PDR ADOCK 05 y
R
TABLE OF CONTENTS Operations Summary.
.1 Significant Operational Events.
1-3 PORV's and Safety Valves Summary.
.4 Reports L
Licensee Events.
.4 Diesel. Generator Failure Reports 5
Special Reports.
.5 Offsite Dose Calculation Manual Changes
.5 Operating Data Unit 1
. 6-8 Unit 2
. 9.........................
Plant Maintenance Summary
. 12-30 Appendix A.
. 31.........................
M 1
Operations Sumnsry February, 1984 The following summary describes the significant operational activities for the month of February.
In support of this summary, a chronological log of significant events is included in this report.
Unit 1 Unit I was critical for 479.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />, produced 501,810 MWH (gross), resulting in an average hourly gross load of 1,046,528 kW during the month.
There were no reactor scrams, 1 manual shutdown and no power reductions during February. The reactor entered mode 5 at 0315 hours0.00365 days <br />0.0875 hours <br />5.208333e-4 weeks <br />1.198575e-4 months <br /> on February 22, 1984 beginning the refueling / modification outage.
Unit 2 Unit 2 was critical for 635.8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, produced 716,270 MWH (gross),
resulting in an average hourly gross load of 1,134,056 kW during the month.
There are 169.3 full power days estimated remaining until the end of cycle 2 fuel. With a capacity factor of 85 percent, the target EOC exposure would be reached September 15, 1984. The capacity factor for the month was 87.0 percent.
There were no reactor scrams, one manual shutdown, and no power reductions during February.
Significant Operational Events Unit 1 Date Time Event 02/01/84 0001 The reactor was in mode 1 at 30% power producing 330 MWe and was holding for steam generator chemistry requirements.
02/03/84 0650 Began power ascension.
02/04/84 0404 The reactor obtained 100% power, producing 1175 MWe.
02/19/84 2257 Began reducing power to manually shut the reactor down for the refueling /
modification outage.
02/20/84 2326 The reactor entered mode 2.
2330 The turbine was taken off-line. The reactor entered mode 3.
i 02/21/84 1540 The reactor entered mode 4. -
l Significant Operational Events (Continued)
Unit 1 (Continued)
Date Time Event 02/22/84 0315 The reactor entered mode 5.
The refueling / modification outage in progress.
02/29/84 2359 The reactor was in mode 5 and the refueling / modification outage continues.
Unit 2 02/01/84 0001 The reactor was in mode 1 at 100% power,-
producing 1186 MWe.
02/07/84 1132 Began reducing load due to the steam generator chemistry going out of specification.
1441 The reactor was at 30% power producing 300 MWe and was holding because of the steam generator chemistry.
1620 Began reducing power to take the unit off-line to fill and flush the. steam generators.
1719 The unit was taken off-line.
02/08/84 0125 The reactor entered mode 4.
0850 Began increasing reactor temperature and pressure. Reactor entered mode 3.
02/10/84 0535 Reactor taken critical.
0942 The unit was tied on-line.
1343 The reactor was at 30% power, producing 301 MWe and holding due to steam generator chemistry.
02/11/84 0248 Began power ascension.
0615 The reactor was at 48% power, producing 520 MWe and was holding due to heater drain tank chemistry.
1140 Began power ascension.
r
~
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Significant Operational Events (Continued)
Unit 2 (Continued)
Date Time Event 02/11/84 2330 The reactor was at 93% power, producing 1114 MWe and was holding due to an E.H.C. oil leak on the
- 4 governor valve.
02/12/84 0215 Began power ascension.
0345 The reactor obtained 100% power, producing 1184 MWe.
02/29/84 2359 The reactor was in mode I at 100% power and producing 1184 MWe.
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 February 1984, to the Nuclear Regulatory Commission.
LER DATE TIME UNIT MODE DESCRIPTION OF EVENT SQRO-50-327/1-84002 01/12/84 0700 1
3 Inadvertent ABI's was received due to electromagnetic interference (EMI) generated due to switching and voltage surges wit *in RM-90-101.
SQRO-50-327/1-84003 01/20/84 1939 1
1 An inadvertent CVI's occured due to 01/29/84 1015 1
1 EMI generated by switch actuation on RM-90-106.
SQRO-50-327/1-84004 01/14/84 0055 1
.1 An inadvertent CRI occured due to 01/14/84 0120 1
1 EMI generated by switch actuation
-on RM-90-125.
SQRO-50-327/1-84005 01/09/84 0045 1
1 Cold leg accumulator 3 was found to have a high boron concentration',
l SQRO-50-327/1-84006 01/10/84 0204
.1 1
The reactor tripped due to a Lo-Lo steam generator, !
Licensee Events and Special Reports (Continued)
LER DATE TIME UNIT MODE DESCRIPTION OF EVENT SQRO-50-327/1-84007 01/10/84 1610 1
1 The reactor tripped due to a Lo-Lo steam generator level caused by the operator closing the feedwater regulator by pass valves too early.
SQRO-50-327/1-84008 01/24/84 1550 1
1 High radiation ala rm on RM-90-101 01/27/84 1000 1
1 caused five seperate ABI's.
The 01/27/84 1020 1
1 investigation revealed two-seperate 01/30/84 1116 1
3 causes:
the relieving of pressure 01/30/84 1147 1
3 (burping) the VCT and the over-flowing of the condensate demin-erlizer waste evaporator (CDWE).
SQRO-50-327/1-84009 01/28/84 0550 1
1 Pressurizer level transmitter root valve 68-443A leaked through the packing which increased the radiation level in containment.
RM-90-106 alarmed high when the levels exceeded the set points resulting in a CVI.
SQOR-50-327/1-84010 01/28/84 2130 1
1 An inadvertent ABI occured due to EMI generated by switch actuation on RM-90-101.
SQRO-50-327/1-84011 01/25/84 1
1 NCR SQNP WP8315 identified a 2
1 potential leak path which would cause loss of control room pressurization during a LOCA seismic event, due to broken floor and equipment piping.
SQRO-50-327/1-84013 01/30/84 1930 1
1 The reactor tripped due to a Lo-Lo steam generator level ~ caused by difficulity in controlling levels while in manual control following a turbine trip due to a Hi-Hi level in #4 steam generator.
SQRO-50-328/2-84001 01/10/84 1535 2
1 Inadvertent CVI's occured due to 01/15/84 0241 2
1 EMI caused by switch actuation 01/16/84 0829 2
-1 and_one by not allowing a source 01/17/84 2335 2
1_
check to decay below setpoint.
01/21/84 1950 2
1 SQR0-50-328/2-84002 01/27/84 0123 2
1 Inadvertent CVI's occured due to 01/27/84 1538 2
1 EMI caused by switch actuation 01/27/84 2025 2
1 and vibration.
01/29/84 0117 2
1 02/01/84 1714 2
1 02/08/84 2048 2
3
' 4-
Diesel Generator Failure Reports There were no diesel generator failure reports transmitted during the month.
c.
Special Reports There were no special reports transmitted during the month.
j Offsite Dose Calculation Manual Changes
[
Changes in the Sequoyah Nuclear Plant' ODCM are described in this section in accordance with Sequoyah Technical Sepcification 6.14.2.
3 l
These changes were officially approval by RARC on December 16,_1983.
See Appendix A at the end of this report for the approval changes, f
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OPERATING DATA REPORf DOCKET iwO. 50-327 DATE MARCH 3, 1984 COMPLETED BY M G EDDINGS TELEPHONE (615) 870-6248 OPERAT ING ST AT US 1.
UNIT NAME: SEQUOYAH NUCLEAR PLANT, UNIT 1
NOT ES:
2.
REPORT PERIOD: FEBRUARY 1-29, 1984 3.
LICENSED THERMAL POWER (MWT):
3411.0 4.
NAMEPLATE RA f LNG (GROSS MWE):
1220.6 5.
DESIGN ELECTRICAL RATING (NEl MWE):
1148.0 6.
MAXIMUM DEPENDABLE CAPACITY (GROSS MWE):
1183.0 7.
MAXIMUM DEPENDABLE CAPACITY (NET MWE):
1148.0 8.
IF CHANGES OCCUR IN CAPACIlY RATINGS (ifEMS NUMBERS 3 THROUGH 7)SINCE LAST REPORT, GIVE REASONS:--__-_----..-
9.
POWER LEVEL TO WHICH RESTRICTED,IF ANY(NET MWE):_-----_-
'10.
REASONS FOR RESTRICTIONS,IF ANY:____-_-------__--
THIG MONTH YR.-TO-DATE CUMULATIVE
-11.
HOURS IN REPORTING PERIOD 696.00 1440.00 23377.00 l 1:2. NUMBER OF HOURS REACTOR WAS CRITICAL 479.50 1014.90 15456.46 l13. REACTOR RESERVE SHUTDOWN HOURS O.00 0.00 0.00
- 14. HOURS GENERATOR ON-LINE 479.50 961.30 15074.45
- 15. UNIT RESERVE SHUT 1 TOWN HOURS 0.00 O.00 O.00 116. GROSS THERMAL ENERGY GENERATED (MWH)
.1494484.63 28/0307.71 48362158.01
- 17. GROSS ELECTRICAL ENERGY GEN. (MWH) 501810.00 956150.00 16335286.00
- 18. NET ELECfRICAL ENERGY GENERATED (MWH) 480444.00 915067.00 15691995.00
- 19. UNIT SERVICE FACTOR 68.09 66.76 64.48
- 20. UNIT AVAILABILITY FACTOR 68.89 66.76 64.48
- 21. UNIT CAPACITY FACTOR (USING MDC NET) 60.13 55.35 58.47
- 2'2. UNIT CAPACITY FACTOR (USING DER NET) 60.13 55.35 58.47
- 23. UNIT FORCED OUTAGE RATE O.00 21.43 18.18 C24. SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE, AND DURATION OF EACH)
- 25. 1F SHUTDOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF_STARTUP:
ePlil Lh_[18_4_______________________________________________,______
NOTE THAT THE THE YR.-TO-DATE AND CUMULATIVE VALUES HAVE BEEN UPDATED.
1 -
t UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO.
50-327 UNIT NAME SEQUOYAll ONE DATE March 3, 1984 COMPLETED BY M. C. Eddines REPORT MONTH FEBRUARY TELEPHONE (615) 870-6248 q
W O
@g
.-"e c yy Licensee y
Cause & Corrective No.
.Date.
8,
- j $
]tg Event 8%-
8%
Action to p
&j
$y" Report #
g'8 8.]
Prevent Recurrence S#
$5$
N"
.0" e
5 840220.
S 216.5 C-1 Refueling Outage
/
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 M
o AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.
50-327 UNIT ~ SEOUOYAH ONE DATE March 3, 1984 COMPLETED BY M. G. Eddings TELEPHON'E (615) 870-6248 MONTH FEBRUARY 1984 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net)
(MWe-Net)-
1 0298 17' 1132 2
0325 is
- 1130 4
3 0654 19' 1124 i
4 1126 20 0844 I
5 1130 21 Refuel Qutage 6
1127 22 Refuel'OuYage 7
1101 23 Refuel' Outage 8
1129 24 Refuel Outage 9
1122 25 -
Refuel Ournee 10 1126 26-Refuel Outage j
11 11'25 27 Refuel Outage 12 1127 28 Refuel Outage 1
i 13 1129 '
29 Refuel Outage 14 1124
-30 N/A 15 1127 31 N/I 16 1126 INSTRUCTIONS 4-On this format, ' list the average ' aily unit power level in'MWe-Net for each day. in d
h i
.t e report ng month.
Compute to the nearest _whole megawatt.
(9/77)
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,r e
m4r s.
y-r,
d OPERAflNG DAfA REPORT DOCKET NO. 50-328 DATE MARrH 3,1984 COMPLETED BY D.C.DUPREE TELEPHONE (6151870-6248 OPERATING STATUS 1.
UNIT NAME: SEQUOYAH NUCLEAR PLANT, UNIT 2
NOTES:
2.
REPORT PERIOD: FEBRUARY 1-29,1984 3.
LICENSED THERMAL POWER (MWT):
3411.0 4.
NAMEPLATE RATING (GROSS MWE):
1220.6 S.
DESIGN ELECTRICAL RA11NG (NET MWE):
1148.0 6.
MAXIMUM DEPENDABLE CAPACITY (GROSS MWE):
1183.0 7.
MAXIMUM DEPENDABLE CAPACITY (NET MWE):
1148.0 8.
IF CHANGES OCCUR IN CAPACITY RATINGS (ITEMS NUMBERS 3 lHROUGH 7)SINCE LAST REPURT, GIVE REASONS:-_---_______
9.
POWER LEVEL TO WHICH RESTRICTED,IF ANY(NET MWE):--____--
1 110. REASONS FOR RESIRICTIONS,IF ANY:________-----_-_-__-_-_
THIS MONTH YR.-10-DA'lE CUMULAT1VE
.11.
HOURS IN REPORTING PERIOD 696.00 1440.00 15337.00
} 1:2. NUMBER OF HOURS REACTOR WAS CRITICAL 635.GO 1379.80 11740.87
- 13. REACTOR RESERVE SHUTDOWN HOURS 0.00 0.00 0.00
- 14. HOURS GENERA'IOR ON-LINE 631.60 1375.60 11529.92
!15. UNIT RESERVE SHUTDOWN HOURS 0.00 0.00 0.00 116. GROSS THERMAL ENERGY GENERATED (MWH) 2077520.26 4613056.89 37031124.70
' 1 '7. GROSS ELECTRICAL ENERGY GEN. (MWH) 716270.00 1597750.00 12629690.00
- 18. NET ELECTRICAL ENERGY GENERATED (MWH) 691337.00 1541099.00 12158836.60 i 19. UNIT SERVICE FACTOR 90.75 95.53 75.18
- 20. UNIT AVAILABILITY FACTOR 90.75 95.53 75.18
- 21. UNIT CAPACITY FACTOR (USING MDC NET) 86.52 93.22 69.06 2:2. UNIT CAPACITY FACTOR (USING DER NET) 86.52
'93.22 69.06
- 23. UNIT FORCEO OUTAGE RATE 9.25 4.47 8.72 L24. SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE, AND DURATION OF EACH):
i25. IF SHUTDOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP:
NOTE THAT THE THE YR.-TO-DATE AND CUMULATIVE VALUES HAVE BEEN UPDATED.
- y
I UNIT SHUTDOWNS AND POWER REDUCTIONS' DOCKET NO.
50-328 l
UNIT NAME SEQUOYAH TWO I
DATE March 4.
1984 COMPLETED BY n_ c. nupree b
REPORT MONTH FEBRUARY TELEPHONE (615) 870-6248 L
q W
O
@g N
C y tj Licensee y
Cause & Corrective e
No.
Date 8,
t8 8
'8 t g Event 5%
8%
Action to 2e g
5y" Report !
g'8
&]
Prevent Recurrence
$55 8"
8 1
840207
'F 64.40 A
1 Steam generator chemistry out of specifications.
1 1
2 3
4 Fr 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-Cperator Training & License Examination Outage F-Administrative 5-Reduction G-Operational Error (Explain) 9-Other 5
(9/7.7)
H-Other (Explain)
Exhibit I-Same Source t
AVERAGE DAILY UNIT POWER LEVEL DOCKET No.
50-328 UNIT SEOUOYAH TWO DATE March 4,1984 COMPLETED BY D. C. Dupree TELEPHONE (615) 870-6248 MONTH FEBRUARY 1984 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net)
(MWe-Net),
1 1146-17 1157 2
1144 33 1160 3
1145 19 1147 4
1147 20 1145 5
1146 21
~
11/19 ;
6 1138 22 1143
7 0904 23 1144 8
unit uns cinun 24 1145 9
Unit was ' dorm 25 1146 10 01-47 26 1146
~
11 0542 27 1147 12 1136 28 1148 13 1146' 29 1148 14 1155
'30 N/A 15 1145 31 N/A 16 1159 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)
(.-
l
Plent Maintentnce Summtry The following significant maintenance items were completed during the month of February 1984:
Mechanical Maintenance 1.
Reparied the burnable poision rod assembly tool.
2.
Repaired the unit I fuel transfer basket.
3.
Cut the CVCS mixed bed 2A in half to inspect the resin screen.
4.
Repacked the 2A-A & 2B-B auxiliary feedwater pumps.
5.
Repaired the damaged stem on 2-LCV-6-106B.
6.
Balanced reactor coolant pump 2-2.
7.
Furmanited 2-FCV-1-150.
8.
Installed a new drum in the "A" ice machine.
9.
Repaired the bursted N line t steam generators 2 & 3 (unit 1).
2 10.
Began repairs of the turbine building sump line at the temporary DI.
11.
Inspect =d RHR suction valves 1-FCV-74-1,
-2.
12.
Began ice condenser servicing during the unit I cycle 2 refueling outage.
13.
Began installing the flexitallic gasket in 1-FCV-3-67.
14.
Began replacing "dogbone" seal in the unit 1 main condenser.
15.
Began inspected the #4 reactor coolant pump seals (unit 1).
Electrical Maintenance 1-Shutdown board room chiller A-A, 0-CHR-313-D0/5D-A, was found inoperable.
The investigation found the load sequencer defective. The load sequencer was replaced. The system was cleaned and new valves installed. A vacuum was pulled and the system charged with R22 and check for proper operation.
2.
ERCW strainer A2A-A would not operate on demand due to a blown control fuse caused by a stuck back flow valve. The control fuse was. replaced and the back flow valve was freed. The system was checked for proper operation.
3.
A visual alarm indicated that steam generator.#3 main steam isolation valve 1-FCV-1-22 would not operate. The limit switch was not making up causing the j
light in the MCR not to come on.
The limit switch was cleaned, lubricated, l
and functionally checked.
4.
Performed the 10 year inspection and preventive maintenance on PCB 5064. _
Plent M:inten nce Summery (Continued)
Electrical Maintenance (Continued) 5.
A visual alarm on 2B-B purge exhaust fan discharge damper 2-FCO-30-4B indicating improper damper position. The limit switch was readjusted and checked for proper operation.
6.
Glycol circulation pump B would not start due to a defective circuit in the controller on 0-MTRB-61-84.
The controller was replaced.
7.
The 125V DC Vital Battery Charger II, 0-CHGB-250-QG voltage meter would not operate due to a defective meter circuit. The meter was replaced.
8.
0-BCTC-62-167 would not reset preventing concentrate pump B from starting.
The breaker was replaced and functionally checked.
9.
A visual alarm indicating both limits were made-up on 2-LCV-62-118 causing the vaive not to operate. Adjusted the limit actuator and functionally checked the system.
10.
The pressurizer control heater D bank would not operate on demand. The contacts on the auto transfer relay weere not making up.
They were adjusted and checked for proper operation.
11.
2-FCV-1-98 was found out of limits due to the acutator arm being loose on the shaft preventing the limit switch from making up.
12.
During a special investigation the #1 main steam header isolation valve 1-FCV-1-4 would not operate due to the actuator arm being loose on the shaft prevonting limit switch ZS-1-4 from making up.
13.
During the performance of an SI #3 main steam header isolation' valve 1-FCV-1-22 position limit switch would not operate due to the actuator arm being loose on the shaft preventing limit switch ZS-1-22 from making up.
14.
Inspected the unit 1 polar crane, the turbine building R/C cranes and the AB cranes with the TVA crane inspector.
15.
A visual alarm ou 1-II vital 120V AC inverter, 1-INVB-250-QN-E, indicated no synchronization for transferring feeds on the power board. Replaced the inverter and various components and returned to service.
16.
Repaired the unit 2 incore detectors. Replaced the slip clutch and the encoder on "A" detector and repaired D and E ten path transfer swtiches.
Repaired the Unit 1 D incore detector. Adjusted the withdraw limit switch which was causing the K25 relay to chatter.
17.
During testing CB PMP IB tt suction isolation valve 1-FCV-2-87 would not open on demand. The oil pump start relay contacts on 1-FCV-2-87 were found dirty causing the contact not to make-up.
18.
An alarm indicated the heat-trace on the unit 2 upper ice condenser not operating on demand. The heat trace on 2-MTRE-61-715B was found to have a defective connection. -
Plant Maintenence Summary (Continued)
Instrument Maintenance 4
Unit _1 1.
Charging pump 1A-A auxiliary oil pressure switch was inoperable, the micro-switch housing was broken. Replaced the micro-switch and calibrated the pressure switch.
2.
Modified the Inplant DI conductivity cells for the caustic, acid and mixed bed conductivity analyzers.
3.
The control rod drive system would not move the rods in or out.
The master pulser circuit card was found bad and replaced.
4.
Rod position indicator C-11 was erratic indicating a high resistance in the connector. Reliable contact was achieved by applying voltage to the field cable and connector.
5.
While performing SI-188,1-PDM-65-82 was found inoperative. The shunt assembly was broken and was replaced.
6.
The "B" train EGTS humidity control heater high temperature cut out control switch was malfunctioning. The location of the sensing element was aligned to agree with the location of the low temperature control switch's sensing element.
7.
During shut down of unit I for the refueling outage NIS intermediate range detector N-36 failed. The detector has been scheduled for replacement during this refueling outage.
8.
The waste gas hydrogen analyzer was inoperative, water was found in the analyzer. The drain valve from the moisture trap to the drain header was closed. The valve was tagged opened, the analyzer was cleaned, dried and repaired.
Unit 2 1.
The unit 2 backup source range detector developed a noise problem. There was a search for the source of the noise however, it ceased prior to being found.
2.
Containment sump level transmitter 2-LT-63-179 drifted high by 1%.
Investigation found no problems except a 1% zero shift.
3.
The low voltage power supply in power range channel N-41 failed. The power supply was replaced and the channel returned to service.
4.
Auxiliary feedwater control valve 2-LCV-3-148 was lifting off the seat when the pump was started. The level controller, 2-LIC-3-148, setpoint indicator was misaligned by 6%. An alignment was done on the controller.
5.
Main feedwater regulator valve 2-FCV-3-48 went closed with the unit at 100% power. Automatic control was lost but was reinstated when the loop power fuse for 2-LT-3-51 was replaced.
INSTRLi'ENT MAINTENANCE MONTHLY SUNNARY 03-06-84 PACE 1 CCMP MR 2.... U FUNC SYS ADDRESS. DAT E.... DESCR IP T ION............................. CC4 R ECT I VE AC T IC; t.......................
A083467 2 101 090 112 02/07/84 2-RM-090-112, PLACE AN C-RIrG IN THE RE0 LACED 0-RItC IN PRE-FILTER. LEFT IN PREFILTER PLATE CONTACT CFEM LAS 6347 OR SERVICE.
JOHN DILLS 6277 PRICR TO UCRKItc.
A083484 1 Fn 090 100C 02/25/84 1-RM-090-100C,10 DINE FLOW LOU.
PLEA 5E FLTR PAPER UAS CBSTRUCTING FLDU. ADVNCED READJUST FLOW TO BETUEEN 1.8 AND 2.2 FLTR PAPER, ALARt1 CLEARED, PERFORMED FUNCT CFM.
TEST.
A100236 2 FM 090 106A 02/07/84 2-RM-090-1C6A. MONITOR SPIKItG (OP90V.
REDLACED 20 MIN TINEF. RETL*RbED MONITOR 5-6 MIN DETERMItE CAUSE A'O CORRECT.
TO SERVICE.
A101833 1 PIS 087 22 02/25/84 1-PIS-087-22, nDICATCR GIWS ERRATIC FEPL ACEO METER, VERIFIf J PROPER ItOICATION.
OPEPATION.
A101834 1 PIS 087 24 02/25/841-PIS-037-24, INDICATOR GIVES ERRATIC REPLACED MEIER, VERIFIED FRCPER INDICAT ION AtO ALARM LIGNT IS B'JRNED OPERATION.
DUT.
i A106887 2 HIC 062 938 02/03/84 2-HIC-062-938, RNPRDu REPAIR LEAR AS THERE IS NO LEAK.
l NECESSARY.
A106935 1 FT W3 903 02/06/84 1-FT-003-908, FLCU INDICATOR CONTROLLER FU PRESS UAS SUINGIFC. FIELD TURFED THE ERRATIC UHEN IN AUTO CA'J3ING SOURCE RECORDER RO LEFT IN SERVICE.
FLUCTUATION. INVESTIGATE ANC t1AKE NECESSARY REPAIRS.
ClA106945 2 FIS 074 24 02/08/84 2-FIS-074-24, NC-ZONEN 4t#RD4 TIGHTEN TICHTENED ALL FITTINGS. LEFT IN LEAKIt0 FITTING.
SERVICE.
A241737 i FI 003 170A 02/23/84 1-FI-003-170A, THIS INDICATCR UILL NJT REDLACED RIEBON CONNECTOR CH SGUARE FOOT ItOICATE FLOU UHEN IN USE, MODIFIERS. VERIFIED PRCPER @ERATION, A243344 0 RM 090 225 02/04/84 0-RM-090-225, REPLACE ROTOTTER FLOu REPLACED ROTCNETER CLASS TUBE. LEFT IN COLUMN INSIDE RAD MONITOR.
SERVICE.
A243707 1 LCV 003 156 02/06/84 1-LCV-003-156,LCV 156 IS OPEN P O CiLL RE0 LACED THE V/I BOARD & RAN CAL CHK ON l
NOT CLOSE FULLY IN AUTO CR MANUAL.
CONTROLLER, FIELD TUNED CONTROLLER,LEFT I
IN SVS.
j A245387 2 XI 092 50028 02/23/84 2-XI-092-50028, CPS METER READING LDU, READJUSTED ZERO ON REMOTE CPS METER, ISCLATION (41PLIFIER IN SFM DRACER NEEDS LEFT IN SERVICE.
TO BE CHECKED FCR CALIBRATICN.
)
A245453 0 FM 090 122 02/04/84 0-RM-090-122, MONITOR IS NJT RESPONDItC ALIGNED CHECK EDURCE TO DETECTOR. LEFT TO SOURCE CIECK.
IN SERVICE A245501 0 PS 082 5025/4 02/26/84 0-PS-082-5025/4, THE CR ANK CAST. PRESSURE VERIFIED CAL, PETURtED TO SERVICE.
i SUITCH HAS ACTUATED, UAS RESET. THE PS NED TO BE VERIFIED OPERASLE.
A245599 0 RM 090 122 02/26/84 0-RM-090-122, TRIP POINT FLUCTUATES.
EXERCICED ADJ. POTS 1 INDICATIONS TRIP REF VOLTAGE FLUCTUATES CHILE STABLIZED. REr*0VED RP-30 MOCULE 1 fURNItC TRIP REF POT.
TEST POINT 3 IS VERIFIED PR09ER CPERATION.
LOOSE.
pn250460 2 TS 061 131 02/09/84 2-TS-061-131, I.B. TEMP SU'S HI ALARM IS SUITCH UAS OUT CF CAL. RECALIBRATED AND
~
e ne INSTRtl1ENT FIAINTEr' CE r10NTHLY SUtT1ARY 03-06-04 PAOE 2 N
COnP r:2 2.... U fl#C SYS ADDRESS. DATE....
DESCRIPTION.............................
CORRECTIVE ACTION.......................
\\
IN, WINDOW NI8 XA-55-6D, SU5PECT BAD (IFT IN SERVICE.
ANN. CARD AND/OR TEr1P SU'S IN ICE CONCENSER.
i 16 records listed.
i J
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I
APPENDIX A Changes to Sequoyah Nuclear Plant (SQU) Offsite Dose Calculation Manual (ODC11)
Change 1 Description of Change Wording corrections were made on pages 7 and 30.
No model changes are reflected in these changes; therefore, no evaluations are necessary.
Change 2 Description of Change Wording was added to the gaseous and liquid sections describing how cummulative quarterly anda nnual_ doses are estimated based on monthly calculations and how dose projections are performed (pages 16 and 25). The additions do not repre-sent a model change, but an explanation of the methodology already in use.
Therefore, no evaluations are necessary.
Change 3 Description of Change Three locations for sampling. milk were added to table 3.1-2.
One location was deleted.
Analysis or Evaluation Justifying Change The most recent land-hse survey identified 3 near site farms where goats are milked. Because goats have a higher concentration factor for iodine than do cows, these locations were added. As partial coropensation for the addition, one site which consistently had low measured concentrations was deleted.
s.
Evaluation of Accuracy of Dose Calculations or Set Point Determinations Although this chadge will not affect dose calculations or set point deter-minations, it will improve the usefulness of the environmental monitoring program by' decreasing the likelihood that any elevated environmental con-centration will be missed.
SEQUOYAH NUCLEAR PLANT 0FFSITE DOSE CALCULATION MANUAL EFFECTIVE PAGE LISTING REVISION 8 Page Revision
~
TOC 1 through TOC 2 Revision 5 TOC 2 Revision 7 1 through 2 Revision 6 3 through 4 Original 5
Revision 3 6
Revision 4 7
Revision 8 8 through 9 Revision 5 10 Original 11 through 13 Revision 5 14 Revision 7 15 Revision 5 15a Revision 7 1
16 through 16a Revision 8 Table 1.1 (2 pages)
Revision 4 Table 1.2 (2 pages)
Original Table 1.3 (8 pages)
Revision 4 Table 1.4 Revision 4 Table 1.4A Revision 5 Table 1.5 Revision 4 Tables 1.6 and 1.7 Revision 5 Table 1.8 Original Figures 1.1 and 1.2 Original Figure 1.3 Revision 3 17 Original 18 Revision 2 19 Revision 7 20 Revision 6 21 Revision 7 22 Revision 5 23 through 24
-Revision ~7 25 through 29 Revision 8 Table 2.1 (3 pages)
Revision 7 Tabla 2.2 Revision 5 Tabla 2.3 (3 pages)
Revision-5 Table 2.4 a-c Revision 5 30 Revision 8 Table 3.1-1 (4 pages)
Revision 4 Table 3.1-2 Revision 8.
Table 3.1-3 Revision 4.
Table 3.2-1 (3 pages)
Revision 4 Figure 3.1-1 through~3.1-2.
Revision 4 Figure 3.1-3 Revision 8 Figure 3.1-4 through 3.1-5 Revision 4 Figure 3.1-6 through 3.1-7 Revision 8
~
f
Sequoyah-Nuclear Plant Offsite Dose Calculation Manual i
Dates of Revisions Original ODCM 2/29/&0*
Revision 1 4/15/80**
Revision 2
'10/7/80**
Revision 3 11/3/80, 2/10/81 4/8/81 and 6/4/81**
Revision 4 11/22/82 (10/22/81,
+
11/28/81 and 4/29/82*:
Revision 5' 10/21/82**
a Revision 6 1/20/83**
l Revision 7 3/23/83**
Revision 8 12/16/83**
1
.~
}
1 t
t i
i t
i l
i
- Low Power license ' for Sequoyah.' unit 1-l.
- RARC Meeting date'
)
,i-
+
i
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i I
TABLE Ol' CONTENTS Introduction t
1.
Gaseous Effluents.
1.1 Alarm / Trip Setpoints 1
l 1.1.1 Release Rate Limit Methodology -
Ci/s 1
l Step 1 1
i A.
Noble Gases 1
B.
Iodines and Particulates 4
Step 2 10 1.2 Monthly Dose Calculations 10 q
1.2.1 NoblF Gases 11-Step-1 11 Step 2 13 5
1.2.2 Iodines and Particulates 14 Step 1 14 I
Step 2 16-5 i
j 1.3 Dose Projections 16 j
1.4 Quarterly and Annual Dose Calculations 16 t
)
1.5 Gaseous Radwaste Treatment System Operation
.16~
.I 8
1.5.1
System Description
16 1.5.2 Dose Calculations 16a i
}
1
+
j i
I TOC-1'
^
l,
' 34 _
t
TABLE OF CONTENTS (cont'd) 2.
Liquid Effluents 17 17 2.1 Concentration 2.1.1 RETS Requirement 17 2.1.2 Prerelease Analysis 17 2.1.3 MPC - Sum of the Ratios 18 2.2 Instrument Setpoints 19 2.2.1 Setpoint Determination 19 2.2.2 Post-Release Analysis 20 1
2.3 Dose 20~
2.3.1 RETS Requirement 20 2.3.2 Monthly Analysis 21 2.3.2.1 Water Ingestion 21 2.3.2.2 Fish Ingestion 23 2.3.2.3 Recreation 23 2.3.2.4 Monthly Summary 25 2.3.2.5 Dose Projections 25 8.,-.
2.3.3 Quarterly and Annual Analysis 25' 2.3.3.1 Individual Doses 25 2.3.3.2. Population Doses 28 7
2.4 Operability of Liquid Radwaste Equipment 28 5
3.
Radiological Environmental Monitoring-30 8
3.1 Monitoring Program 30 3,2 Detection Capabilities 30 i
i
~_
l l
. TOC-2 i
s
a-3.
Milk Ingestion For determining the concentration of any nuclide (except H-3) in and 3i on vegetation:
(1.7) 7 k
i Ei e)l E
9 DR r [1-exp
(-A E
}
CV = 3,600 2nx/n YA i
k=1 y Ei iy t
b)I B
[1-exp (-A t
.1 i.
where:
CV. = concentration of radionuclide i in and on vegetation, 1
pCi/kg.
k'= stability class. -
~ ~ ~
fk = frequency f this stability class and wind direction combination, expressed as a fraction.
Qi = average release rate of radionuclide i, pCi/s.
4 relative deposition rate, m-1 (Figure 1.2).
DR
=
downwind distance, m.
x
=
l number of sectors,16.
n
=
2nx/n sector width at point of interest, m.
=
fraction of deposited activity retained. on vegetation, 0.47 r
=
(table 1.6).
effective removal rate constant, A
= A.+A A
=
where A. is the radioactive decay bdeffidle$t, ht E1 and A is a' measure of physical loss by weathering y
i (A
= 0.0023 h 1) for particulates and 0.0017 for iodines.
y period over which deposition occurs, 720 h.
]
t e
I 2
agricultural yield, 1.18 kg/m,
Y
=
y B.
= transfer factor from so'il to vegetation of lV radionuclide i (Table 1.6).
Af = radioactive decay coefficient'of radionuclide i, h 1 4
time for: buildup of radionuclides on 'the ground, tb = 3.07 x 105 h (35yr).
l t
I lll
.- 1 r l- -Revision S-
~, _ _.
i i
l Step 2 l
This methodology is to be used if the calculations in stegsl yield doses that exceed applicable limits.
s s Doses for releases of iodines and particulates shall be calcu. lated' using the methodology in Section 1.1.1, step 1, part B, with the following exceptions:
1.
All measured radionuclide releases will be used.
2.
Dose will be evaluated at real cow locations and will consider actual grazing information.
s The receptor having the highest total dose is then used to check compliance with specification 3.11.2.3.
Calendar quarter doses are first estimated by summing the doses calculated for each month in that quarter.
Calendar year doses are first estimated-by summing the doses calculated-for each month in that year.
However, if the annual doses determined in this manner exceed or approach the specification limits, doses calculated for previous I
quarters with the methodology of section 1.4 will be used instead of the doses estimated by summing monthly results.
8 1.3 Dose Projections In accordance with specification 3.11.2.4, dose projections will be performed.
This will be done by averaging the calculated dose for the most recent month and the calculated dose for the previous month and assigning that average dose as the projection for the current month.
1.4 Quarterly and Annual Dose Calculations A complete dose analysis utilizing the total estimated gaseous releases for each calendar quarter will be performed and reported as required in Specifications 6.9.1.8 and 6.9.1.9.
Methodology for this analysis is the same as that described in Section 1.1.1, except that real pathways and receptor locations (Table 1.4A) are considered.
In addition, meteorological data representative of a ground level release for each corresponding calendar quarter will be used.
This analysis will replace the estimates in Section 1.2.
At the end of the year an annual dose analysis will be performed by calculating the sum of the quarterly doses to the critical receptors.
1.5 Gaseous Radwaste Treatment System Operation The gaseous radwaste treatment system (GRTS) described below shall be maintained and operated to keep releases ALARA.
1.5.1
System Description
A flow diagram for the GRTS is given in Figure 1.3.
The system consists of two waste-gas compressor packages, nine gas decay tanks, and the associated piping, valves, and instrumentation.
Gaseous
~ Revision 8 3
i wastes are received from the following:
degassing of the reactor coolant and purging of the volume control tank prior to a cold shutdown, displacing of cover gases caused by liquid accumulation in the tanks connected to the vent header, and boron recycle process operation.
1.5.2 Dose Calculations Doses will be calculated monthly using the methodology described in Section 1.2.
These doses will be used to ensure that the GRTS is operating as designed.
1 t
-16a-8 Revision 8
i The dose equation then becomes D=f(0.0823Aco-60 + 0.0013 Aco-58 + 0.0218 ACs-134 +
(2.18) 0.0356 ACs-137) 2.3.2.4 Monthly Summary Calendar quarter doses are first estimated by summing the doses calcu-lated for each month in that quarter.
Calendar year doses are first estimated by summing the doses calculated for each month in that year.
However, if the annual doses determined in this manner exceed or approach the specification limits, doses calculated for previous quarters with the i
methodology of section 2.3.3 will be used instead of those quarterly doses estimated by summing monthly results.
An annual check will be made to ensure that the monthly dose estimates account for at least 95 percent of the dose calculated by the method described in Section 2.3.3.
If less than 95 percent of the dose has been estimated, either a new list of principal. isotopes wi_ll.be prepared or a new correction factor will be used.
The latter option will not be used if less than 90 percent of the total dose is predicted.
2.3.2.5 Dose Projections In accordance with specification 3.11.1.3, dose projections will be performed.
This will be done by averaging the calculated dose for the most recent month and the calculated dose for the previous month and assigning that average dose as the projection.for the current month.
.j 2.3.3 Quarterly and Annual Analysis A complete analysis utilizing the total estimated liquid releases for each calendar quarter will be performed and reported as required in section 6.9 of the technical specifications.
This analysis will replace values calculated using section 2.3.2 methodology and will also include an approximation of population doses.
2.3.3.1 Individual Doses th The dose to the j organ of the maximum individual from m nuclides, D.,
is described by J
5 m
j=
ij k ',
I2*19)
D D
k=1 i=1 m
2 5
[(IDCF)f3 xl i+
[(RDCF)tj
- (ik Tk
$]
(2.20;
=
ik i=1 k=1 k=3
- Revision 8-
where:
th th ijk dosetotgg j organ from the i radionuclide, D
=
via the k exposure pathway, rem.
the organ of interest (bone, GI tract, thyroid, liver, j
=
total body, and skin.)
exposure pathway of interest:
(1) water ingestion, (2) k
=
fish ingestion, (3) shoreline recreation, (4) above-water recreation, (5) in-water recreation.
th (IDCF)13 inges{gondosecommitment factor for the j organ from
=
the i radionuclide, rem /pCi.
For the combination of pathways considered and the nuclide mix expected, the maximum exposed individual will be an adult or child.
Table 2.1 is a list of ingestion dose factors for the two age groups.
th the activ radionuclide, ik='viathe-k{gyingestedofthei l
exposure pathway, pCi.-
(
Igy=CVfn For the fish pathway li2 = C B M (2.22) if th C. =
concentration of the i radionuclide in the 1
Tennessee River, pCi/mL 1 = A /(F d)
(2.23)
C 1
g th activity released of i
.radionuclide during the A. =
1 rel' ease period, pCi.
Fg = total river flow at location a during period, mL.
A = location of interest (for dose to the maximum individual the first down-river exposure point is used.
For the population dose, various down-river locations are used to account for the total exposed population.
Table 2.4a gives the river location of public water supplies; tables 2.4b and 2.4c give the boundaries of the.various reaches in which concentrations are calculated for the fish and recreation pathways.)
d = fraction of river flow available for dilution (1/5labove Chickamauga Dam, 1 below the dam).
V. = average rate of water consumption per Regulatory Guide 1.109.
~
For maximum individual:
Adult -
2000 mL/d Child -
1400 mL/d 26-8' Revision 8
For average individual (population):
Adult -
1010 mL/d Child -
710 mL/d n = nun ber of days during the release period, day.
I I
~
th Bi = bioaccumulation factor for the i radionuclide in I
fish. pCi/g per pCi/mL, from table 2.2.
M = amount of fish consumed during the period (fraction i
of year times the annual consumption rate per Regulatory i
Guide 1.109.)
For maximum individual:
Adult -
21 kg/yr Child -
6.9 kg/yr For average individual (population):
6.9 kg/yr Adult Child -
2.2 kg/yr th (RDCF)IJ..k=recreationgsecommitment factor fgg the j organ t
from the i radionuclide via the k pathway; mrem /yr per concentration (&ik) in medium; from table 2.3.
I th ik = the concentration of the i radi2Ru lide in the environ-mental medium pertaining to the k pathway.
For above-water and in-water pathways I ik
- Ii5 1
(2.24),
=C For the shoreline pathway, a 15-year buildup in the sediment of the lake is-assumed (per Regulatory Guide 1.109 equation A-5).
(i3 = 100 RHL1 1
C W [1-exp (-A1-t)]
(2.25) where
- 100 = transfer constant as defined in Regulatory Guide 1.109.
th RHL. = radiological' half-life of the i isotope, days, 1
from table 2.1.
1 W = shoreline width factor (0.3 for a lake. shore, per table A-2 of Regulatory Guide 1.109.)
th A. = decay constant of the i radionuclide 1 = 0.693/RHL.
j 1
t: buildup time.in sediment, assumed 15 years, per Regulatory Guide 1.109.
-27 8
Revision 8
Tk=assumpgexposuretimeofmaximumindividualfor the k pathway
- 3) shoreline 500 h/yr
(~10 h/ week)
- 4) above-water.
1800 h/yr (6 h/d, 300 d/y'r)
- 5) in-water 920 h/yr (6 h/d, for five summer months)
Q = fraction of annual exposure for each quarter 1st Quarter Jan.-March 0.1 2nd Quarter April-June 0.3 3rd Quarter July-Sept.
0.4 4th Quarter Oct.-Dec.
0.2 2.3.3.2 Population Doses th The total-dose-from-all-5 -pathways to the j organ of the population, a,
j from m nuclides at n locations is described by n
5 m
d
^j ijkt (2.26) 5 2=1 k=1 i= 1 n
5 m
P (2.27)
=
D ijkt kt 2=1 k=1 i=1 where
~
th A
= dgge to the j organoftggtotalpopulationfromthe ij kt i
radionuclide via the k pathway _at location 2.
D
= dose to ind'ividual as described in section 2.3.3.1 ij kt at location 2.
P th kt number of people exposed via the k pathway at location 2,~from table 2.4.a-c.
The population is assumed to consist of 71 percent-adults and 29 percent children ( from Appendix D,- Regulatory Guide 1.109 - the-value for children includes teenagers).
2.4 operability of Liquid Radwaste Equipment-Specification 3.11.1.3 of the' Radiological Ef fluent Technical Specifications requires that the liquid radwaste system shall be used to reduce the radioactive materials in liquid wastes. prior.to their Revision 8
' 8
discharge when the projected dose due to liquid effluent releases to unrestricted areas (see Figure 2.1.1-1) when averaged over 31 days would exceed 0.06 mrem to the total body or 0.21 mrem to any organ.
Doses will be projected monthly to assure compliance.
. - 8 Revision 8
1-3.0 Radiological Environmental Monitoring 3.1 Monitoring Program l
An environmental radiologi. cal monitoring program shall be conducted in accordance with Technical Specification 3.12.1.
The monitoring i
program described in Tables 3.1-1, 3.1-2, and 3.1-3, and in Figures i
3.1-1, 3.1-2, 3.1-3, 3.1-4, 3.1-5, 3.1-6, and 3.1-7 shall be conducted.
4 l8 j
Results of this program shall be reported in accordance with Technical j
Specifications 6.9.1.6 and 6.9.1.7.
The atmospheric environmental radiological monitoring program shall consist of 12 monitoring stations from which samples of air j
particulates, atmospheric radiciodine, rainwater, and heavy particle fallout shall be collected.
l The terrestrial monitoring program shall consist of the collection of milk, soil, ground water, drinking water, and food crops.
In addition, direet gamma radiation levels will-be-measured in the i
vicinity of the plant.
The reservoir sampling program shall consist of the collection of samples of surface water, sediment, and fish.
l Deviations are permitted from the required sampling schedule if specimens are unobtainable due to hazardous conditions, sample unavailability, or to malfunction of sampling equipment.
If the latter, every effort shall be made to complete corrective action prior to the end of the next sampling period.
3.2 Detection Capabilities Analytical techniques shall be such that the detection capabilities listed in Table 3.2-1 are achieved.
i i
i i
I i
4 l
1 l
2
?
. 8 Revision 8
_ - ~. - _, _..._
SNP TABLE 3.1-2 Atmospheric and Terrestrial Monitoring Station Locations Sequoyah Nuclear Plant Location Approximate Distance and Sample Station Direction from Plant LM-1 S 1/4 mile SW LM-2 S 1/4 mile N PM-1 S (Northwoods) 10 miles WSW PM-2 S (Hamilton County Park) 3-3/4 miles WSW PM-3 S (Daisy) 5-1/2 miles WNW PM-4 S (Sale ereek) -- - --
10-1/2 miles N PM-5 S (Georgetown) 9 miles ENE PM-6 S (Work).-
5 miles NE PM-7 S (Harrison Bay) 3-1/2 miles SE PM-8 S (Harrison) 8-1/2 miles SSW RM-1 S (Chattanooga, Riverside) 16 miles WSW RM-2 S (Dayton) 17-1/2 miles NNE (Identical with RM-2 WB, Watts Bar Nuclear Plant)
Farm L 2-3/4 miles NNE.
Farm M 3-1/2 miles NNE Farm J 1-1/4 miles W Farm HW 1-1/4 miles NW Farm EM 2-1/2 miles N 4
Farm BR 2-1/4 miles SSW-
-Farm LE 3-1/2 miles S Farm SM l-3/4 miles SE 8
Farm SU 3-1/4 miles SSE Farm C (control) 16 miles NE Farm B (control) 43 miles NE Farm S (control) 12 miles NNE Revision.8
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- Revision 8-
2-TENNESSEE VALLEY AUTHORITY Sequoyah Nuclear Plant P. O. fox 2000 Soddy-Daisy, Tennessee 37379 tudt 151984 Nuclear Regulatory Commission Office of Management Information and Program Control Washington, DC 20555 Gentlemen:
Enclosed is the February 1984 Monthly Operating Report to the NRC for Sequoyah Nuclear Plant.
Very truly yours, TENNESSEE VALLEY AUTHORITY f
C. C. Mason Power Plant Superintendent Enclosure cc (Enclosure):
Director, Region II Director, Office of Management Nuclear Regulatory Commission Information and Program Control Office of Inspection and Enforcement Nuclear Regulatory Commission 101 Marietta Street Washington, DC 20555 (2 copies)
Suite 3100 Atlanta, GA 30303 (1 copy)
INPO Records Center Suite 1500 Director, Office of Inspection 1100 circle 75 Parkway and Enforcement Atlanta, GA 30339 Nuclear Regulatory Commission Washington, DC 20555 (10 copies)
Mr. A. Rubio, Director Electric Power Research Institute g[
P. O. Box 10412 Palo Alto, CA 94304 (1 copy)
I g l Mr. R. C. Goodspeed MNC 461 Westinghouse Electric Corporation P. O. Box 355 Pittsburgh, PA 15230 (1 ccpy)
An Equal Opportunity Employer