ML20090J202
| ML20090J202 | |
| Person / Time | |
|---|---|
| Site: | Sequoyah  |
| Issue date: | 06/30/1984 |
| From: | Nobles L, Wallace P TENNESSEE VALLEY AUTHORITY |
| To: | NRC OFFICE OF RESOURCE MANAGEMENT (ORM) |
| References | |
| NUDOCS 8407270438 | |
| Download: ML20090J202 (35) | |
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. g-TENNESSEE VALLEY AUTHORITY DIVISION OF NUCLEAR POWER SEQUOYAH NUCLEAR PLANT ModTHLY OPERATING REPORT TO THE NUCLEAR REGULATORY COMMISSION JUNE 1, 1984 - JUNE 30, 1984 UNIT 1 DOCKET NUMBER 50-327 LICENSE NUMBER DPR-77 UNIT 2 DOCKET NUMBER 50-328 LICENSE NUMBER DPR-79 p ~. - ..
4 8407270438 840630 PDR ADOCK 05000327 PDR p . , _
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1 TABLE OF CONTENTS Operations Summary . . . . . . . . . . . . . . . . . . . . . . . 1-Significant Operational Events . . . . . . . . . . . . . . . . . 1-3 PORV's'and Safety Valves Summary . . . . . . . . . . . . . . . . 3 Reports Licensee Events . . . . . . . . . . . . . . . . . . . . . . 3-7 Diesel Generator Failure Reports . . . . . . . . . . . . . 7 Special Reports . . . . . . . . . . . . . . . . . . . . . . 7 n
Offsite Dose Calculation Manual Changes . . . . . . . . . . . . 7 Operating Data Unit 1 . . . . . . . . . . . . . . . . . . . . . . . . . . 8-10
, Unit 2 . . . . . . . . . . . . . . . . . . . . . . . . . . 11-13
.- Plant Maintenance Summary . . . .. . . . . . . . . . . . . . . 14-25 Appendix A . . . . . . . . . . . . . . . . . . . . . . . . . . . 26-33 i
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Operations Summary C
!" June, 1984 o
The following summary describes the significant operational activities for the month of June. In support of this summary, a i chronological log of significant events is included in this report.
Unit 1 Unit I was critical for 571.2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, produced 528,320 MWH (gross),
resulting in an average hourly gross load of 1,009,593 kW during the month.
There are 342.75 full power days estimated remaining until the end of cycle 3 fuel. With a capacity factor of 85 percent, the target EOC exposure would I:
be reached August 8, 1985. The capacity factor for the month was 62.0 percent.
There were 2 reactor scrams, no manual shutdowns, and no power
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reductions.
Unit 2 i-Unit 2 was critical for 720.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />, produced 799,740 MWH (gross),
resulting in an average hourly gross load of 1,139,848 kW during the month.' There are 51.59 full power days estimated re,maining until the end of cycle 2 fuel. The cycle 2 refueling outage is scheduled to begin on September 17, 1984. The capacity factor for the month ~was 93.9 percent.
There were no reactor scrams, one manual shutdown, and one power reduction during June. .
Significant Operational Events Unit 1
, -Date Time Event 1
06/01/84 0001 The reactor was in mode 1 and holding at 30% power due to steam generator chemistry. The unit was producing 289 MWe, 06/02/84 ~1315 Began power ascension.
1 2030 Stopped the power ascension'at 75%
p so a calorimetric could be performed.
2051 The unit operator manually tripped the turbine'and reactor when it was discovered that the No. 11 bearing.
was arcing to the shaft.
'06/08/84 1238 .The reactor was t ken critical.
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,- .c Significant Operational Events Unit 1 (Continued)
Date Time Event 06/09/84 1103 Tied the unit on-line.
1350 The reactor was at 30% power and holding due to steam generator chemistry.
I 1420 Began power ascension.
06/10/84 2115 The reactor obtained 100% Power producing 1134 MWe.
06/18/84 2115 The reactor tripped ' following a turbine trip due to electrical generator problems.
06/19/84 1230 The reactor was taken critical.
06/20/84 1145 Tied the unit on-line.
1308 The reactor was at 30% reactor power, producing 300 MWe and holding. Steam generator chemistry was within specif-ication. The equipment diagnostic group was checking the main turbine vibration.
2241 Began power ascension.
06/21/84 0237 The reactor was holding at 72% power while maintenante was being performed on a No. 3 heater drain tank bypass valve.
0617 Began power ascension.
0940 .The reactor obtained 100% power.'
06/30/84' 2359 The reactor was in mode 1 at 100%
, power producing 1126 MWe, Investi-
.gations were in progress to determine the loss of megawatts.
Unit 2 Date ' lime Event 06/01/84 0001 The reactor was in mode 1 at 100%
reactor power producing 1160 MWe.
06/13/84 2255 Began a load' reduction to repair a leaking tube in feedwater heater A-4.
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j Significant Operational Events Unit 2 (Continued)
Date Time Event 06/14/84 0340 The reactor was at 75 power producing 884 MWe.
0425 Began power ascension.
1700 The reactor obtained 100% power producing 1155 MWe.
06/27/84 2240 Began a load reduction for incore/
excore calibration.
06/28/84 0156 The reactor was at 90% reactor power producing 1040 MWe. Incore/excore calibration was in progress.
1730 Began power ascension.
2000 The reactor obtained 100% power producing 1140 MWe.
06/29/84 1500 Began a load reduction to repair VLV-3-526.
06/30/84 0537 The unit was removed fron service.
?.359 The reactor was in mode 2 at 2%
reactor power. The repairs to
, VLV-3-526 continue.
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 June 1984, to the Nuclear Regulatory Commission.
LER DESCRIPTION OF EVENT 1-84032 On May 10, 1984 at 2225 CST, the number 2 steam generator feedwater flow transmitter 1-FT-3-48A, was declared inoperable and its associated bistables were tripped at 2309 CST as required by technical specifications. The low pressure feed-water heaters later isolated due to high level resulting in low pressure suction to the 1A main feedwater pump. With the bistables to 1-FT-3-48A tripped, one-half of the automatic trip logic for low feedwater flow coincident with low steam generator level was already made up on the number 2 steam generator.
With. unit 1 in mode 1 at 30% reactor power (553 degrees F, 2240 psig), the reactor tripped on low feedwater flow coincident with low steam generator level at 2322 CST when the number 2 steam generator level fell to 25%.
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! ' Licensee Events and Special Rrports (Continued)
LER DESCRIPTION OF EVENT 4
1-84033 During a normal reactor startup following a reactor trip on
- May 10, 1984 (see SQRO-50-327/84032), unit 1 experienced another reactor trip. Just prior to the event which occurred at 1400 CST on May 11, 1984, unit I was in mode 1 (554 *7, 2235 psig) at 21% reactor power with steam generator level controls in manual.
Steam dump valve 1-FCV-1-107 spuriously opened resulting in swell of steam generator levels. _This action resulted in a high-high-level in the number 3 steam generator which caused
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a turbine _ trip and main feedwatcr isoiation to all four steam generators. The transient then resulted in shrink of steam generator levels causing a reactor trip on low-low level in 4 steam generator number 2.
1-84034 On May 9, 1984 with unit 1 in mode 4 operation with RCS temperature at 325 *F, SI-566, "ERCW Flow Verification Test,"
was in progress. The unit operator was requested to open 1-FCV-67-123 and 1-FCV-67-124 (inlet and outlet ERCW MOVs for IB containment _ spray heat exchanger) . The operator observed no flow indication on 1-FI-67-1 or a decrease in 'B' ERCW header pressure as would be expected. Two assistant unit operators were dispatched to throttle valve 1-67-537B closed.
-The valve was immediately throttled to proper position per
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SI-682. -Investigation revealed that the valve was apparently
- 1. closed since April 24, 1984, a time' period which included mode changes from 5 to 4 at 2040C on May 4, 1984;-mode 4 to mode 3 at 0526C on May 5, 1984; and mode 3 to mode .4'at 0010C.on May 9, 1984.
1-84035 A 2234C'on May 21, 1984, unit.1' experienced a reactor trip.
Unit I was in mode 1 (2235 psig,-578*F) at 100% reactor power just prior to the event. A turbine trip occurred due to the failure of the number eleven bearing which caused the permanent magnet generator to fail. The electrical trouble alarm caused the turbine to trip and-the P-9 interlock caused the reactor to trip.
At 2050C on June 2, 1984, unit 1 had another reactor trip due- ~
to the number eleven bearing. Unit I was in mode l'(2235 psig, 568*F) at 75% reactor power just prior to the event. The
- turbine and reactor were manually tripped when sparks were seen coming from the bearing and excessive bearing vibration-was indicated in the control coom. Unit-1' stabilized at~
547 *F following the reactor trips.
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Licensze Events and'Special Reports (Continued)
LER' DESCRIPTION OF EVENT 1-84037 This UsR involves three separate incidents. The first auxiliary building isolation (ABI) occurred at 0444C on May 31, 1984 while unit I was in mode 3 (0% power, 2235 psig, 547'F) and unit 2 was in mode 1 (100% power, 2235 psig, 578*F).
The second ABI occurred at 1550C on June 2, 1984 while unit I was in mode 1 (50% power, 2235 psig, 563 F) and unit 2 was in mode 1 (100% power, 2235 psig, 578*F). The third ABI occurred at 2253C on June 4, 1984 while unit I was in mode 3 (0% power, 2235 psig, 520'F) and unit 2 was in mode 1 (100% power, 2235 psig, 578 F). A high radiation alarm was actuated which caused an auxiliary building ventilation isolation (ABI) to occur. Investigation-revealed that a spike occurred on the
- spent fuel pool (SFP) radiation monitor. The background radiation level is so close to the setpoint that normal l fluctuations of the detector can trip the alarm. Radiation levels were not above normal during this time.
1-84038 Sequoyah technical specifications require two reactor coolant pumps operable with one pump in operation for mode 3 operation.
A Westinghouse review has determined that with only one reactor coolant pump operating, the DNB design basis may not be met during a bank withdrawal from subcritical accident.
1-84039 This LER involves two separate incidents. .The first control room isolation (CRI) occurred at 1950C on May 27, 1984 while unit 1-was'in mode 3 (0% power, 1800 psig, 450*F) and unit 2 was'in mode 1 (100% power, 2235 psig, 578'F). The second CRI occurred at 0543C on June 11, 1984 while unit I was in i
mode 1 (100% power, 2235 psig, 578'F) and unit 2 ws in mode 1
_(100% power,-2235 psig, 578*F).
A'high ra'diation alarm was actuated which caused a control room ventilation isolation (CRI) to occur. Investigation
[ revealed that in one incident, a vacuum pump failed and e
generated a spurious high radiation spike which actuated the "
alarm. In another incident, while-the chart paper.in the recorder was being changed, a spurious spike (electromagnetic interference.- EMI) was inadvertently generated which caused the high radiation alarm to actuate. Radiation levels were not above normal during this time.
2-84007' This' event occurred at 0250C on May 19, 1984-wh'ile unit-2 was in mode 1 (70%~ power, 2235 psig,~ 570'F), and its undervoltage bistable was tripped at.0431C on May 19, 1984.
, The bus undervoltageitiming relay for reactor coolant pump
- (RCP) number 'two was discovered failed after the undervoltage alarm was investigated. ; Technical specifications require the undervoltage bistable to be tripped'within one hour,-but
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.it was not. The " motherhood clause",was entered.one hour after the' relay failed. The bistable was tripped 50 minutes after
'the " motherhood clause" was entered.
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1 Licensee Events'and Special Reports (Continued)
LER- DESCRIPTION OF EVENT 2-84007 (Continued)
The " motherhood clause" was exited and the unit did not have to be shut down due to the failed relay. The. bus was not actually in an undervoltage cendition during this event.
2-84008 Unit 2 had been reduced to 30% reactor power for addition of oil to reactor coolant pumps. During the. reduced power level condition, various maintenance activities were being performed which included repairing oil leaks on both the 2A and 2B main feedwater pumps. The - 2A main feedwater pump was removed from service, all of its oil pumps stopped, and the leaks repaired.
The 2A main feedwater pump was returned to service and the 2B main feedwater pump removed from service. When it came time to stop the 2B main feedwater pump oil pumps, the balance of plant reactor operator inadvertently stopped the 2A main feedwater pump oil pumps. This action caused the 2A main feedwater pump to trip resulting in a subsequent reactor-trip on low-low level in the number 2 steam generator. Unit 2 was in mode 1 (556*F, 2235 psig) at 30% reu, a <.-er just prior to the reactor trip which occurred at 1157 Lo! on May 19, 1984.
Diesel Generator Failure Reports ,
. There were no diesel generator failure reports transmitted during the l- month.
Special Reports There were no special reports transmitted during the month.
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.
These changes were officially approved by RARC on June 12, 1984. See-Appendix A at the end.of this report for the approved ODCM changes.
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OPERATING DATA REPORT I l
4 DOCKET NO. 50-327 :
DATE JULY 10, 1984 l COMPLETED BY M. G. EDDINGS TELEPHONE (615) 870-6248
' OPERATING STATUS
- 1. UNIT NAME: SEQUOYAH NUCLEAR PLANT, UNIT 1 NOTES:
- 2. REPORT PERIOD: JUNE 1994
- 3. LICENSED THERMAL POWER (MWT): 3411.0 4.' NAMEPLATE RATING (GROSS MWE): 1220.6
- 5. DESIGN. ELECTRICAL RATING (NET MWE): 1148.0
- 6. MAXIMUM DEPENDABLE CAPACITY (GROSS MWE): 1183.0 7.' MAXIMUM DEPENDABLE CAPACITY (NET MWE): 1148.0 C. IF CHANGES-OCCUR IN CAPACITY RATINGS (ITEMS 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:------_ --- --
_ _ - =---
=----------------__---
THIS MONTH YR.-TO-DATE CUMULATIVE t
ill. HOURS IN REPORTING PERIOD 720.00 4367.00 26304.00
'12. NUMBER OF HOURS REACTOR WAS CRITICAL 571.20 1932.10 16373.66
- 13. REACTOR RESERVE SHUTDOWN HOURS 0.00 0.00 0.00
' 14. HOURS GENERATOR ON-LINE 523.30 1777.80 15890.95
- 15.' UNIT RESERVE SHUTDOWN HOURS O.00 0.00 0.00
- 16. GROSS THERMAL ENERGY GENERATED (MWH) 1621013.62 5101461.90 50593312.20 117. GROSS ELECTRICAL ENERGY GEN. (MWH) 528320.00 1668240.00 17047376.00
- 10. NET ELECTRICAL. ENERGY GENERATED (MWH) 506344.00 1588525.00 16365453.00
<19. UNIT SERVICE FACTOR 72.68 40.71 60.41
- 20. UNIT AVAILABILITY FACTOR 72.68 40.71 60.41
- 21. UNIT CAPACITY FACTOR (USING MDC NET) 61.26 31.69 54.20
!22. UNIT CAPACITY FACTOR (USING DER NET) 61.26 31.69 54.20
=23. UNIT FORCED OUTAGE RATE 27.32 40.85 21.36
- 24. SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE. AND DURATION OF EACH):
'25. IF SHUTDOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP:
NOTE THAT THE THE YR.-TO-DATE AND CUMULAT.'VE VALUES HAVE BEEN UPDATED.
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UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-327.
UNIT NAME Sequoyah one -
DATE July 10. 1984 COMPLETED BY M. Eddings
,. REPORT MONTH JUNE TELEPHONE (615) 870-6248
.I e e u e
. . - 57 "a c E[ t Licensee $ Cause & Corrective Noa Date [ Zy 8 ~5 0 @ Event gi E% Action to N 2S 2 5y* Report 8 g'8 El Prevent Recurrence b~ ? 5 N" 5" G
E 11 840602 F 158.2 A 2 -
Nuinber 11. generator bearing arcing to shaf t.
12 840618 F 38.5 A 3 Turbine first out electrical trouble.
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 Hestriction 4-Cont. of Existing 0161)
E-Operator Training & License Examination Outage F-Administrative 5-Reduction G-Operatienal Error (Explain) 9-Other 5 (9/77) H-Other (Explain) Exhibit 1-Same Source
AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-327 UNIT sequoyah One DATE July 10. 1984
, COMPLETED BY M. Eddings TELEPHONE (615) 870-6196 MONTH JUNE DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY P'0WEP VEL (MWe-Net) (MWe-Net) ,
1 259.5 17 .
1121.2 r
2 N/A 18 669.0
. 3 N/A 19 N/A 4 'N/A 20 337.1 5 N/A 21 '965.5 6 n/A 22 109N'. 7 7 N/A 23 l'92.8 0
8 N/A 24- 1092.3 9 578.5 25 1072.7 10 877.6 26 1082.2
- 11 1098.7 27 1079.7 12 Id95.' 7 28 1013.0 13 1078.7 29 1081.0 14 1110.3 30 1023.3 15 868.'O 31 .
16 1121.2 INSTRUCTIONS ,
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On this-format,. list the average daily unit power level in MWe-Net for each day in i the reporting month. Compute to the nearest whole megawatt, l j , ,
-(9/77)
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6 OPERATING DATA REPORT DOCKET NO. 50-328 DATE JULY 10~, 1984 COMPLETED BY D.C.DUPREE TELEPHONE (615)870-6248 OPERATING STATUS
- 1. UNIT NAME: SEQUOYAH NUCLEAR PLANT, UNIT 2 NOTES:
- 2. REPORT-PERIOD: JUNE 1-30,1984
- 3. LICENSED THERMAL POWER (MWT): 3411.0
- 4. NAMEPLATE RATING (GROSS MWE): 1220.6 5.~ DESIGN ELECTRICAL RATING (NET MWE): 1148.0
- 6. MAXIMUM DEPENDABLE CAPACITY (GROSS MWE): 1183.0
- 7. MAXIMUM DEPENDABLE CAPACITY (NET MWE): 1148.0 C. IF CHANGES OCCUR IN CAPACITY RATINGS (ITEMS NUMBERS 3 THROUGH 7)SINCE LAST REPORT, GIVE REASONS:_-- - - - = -
_------ .==_= __ _ - _ - - - - = . -
_= - = _ = _ _ _ _ _ _---------
- 9. POWER LEVEL TO WHICH RESTRICTED,IF ANY(NET MWE):-___
- 10. RbASONS FOR RESTRkCTIONS,IF ANY:_ 5--___--- __-__----
_ _ - = _ -.
. _ _ _ _ = = - - - - - - _ _ _ _=
__ - .__=---- _ __
_. .___ = _ - - - - - - _ - - -=
THIS MONTH YR.-TO-DATE CUMULATIVE
- 11. HOURS IN REPORTING PERIOD 720.00 4367.00 18264.00
- 12. NUMBER OF HOURS REACTOR WAS CRITICAL 720.00 4291.40 14652.47
- 13. REACTOR RESERVE SHUTDOWN HOURS O.00 0.00 0.00 114. HOURS GENERATOR ON-LINE 701.62 4254.22 14408.54
.15. UNIT RESERVE SHUTDOWN HOURS O.00 0.00 0.00
- 16. GROSS THERMAL ENERGY GENERATED (MWH) 2360139.54 14246094.53 46664162.34
,17. GROSS ELECTRICAL ENERGY GEN. (MWH) 799740.00 4900650.00 15932590.00 2
- 18. NET ELECTRICAL ENERGY GENERATED (MWH) 772002.00 4723799.00 15341536.60
'19. UNIT SERVICE FACTOR 97.45 97.42 78.89
- 20. UNIT AVAILABILITY FACTOR 97.45 97.42 78.89
~21. UNIT CAPACITY FACTOR (USING MDC NET) 93.40 94.23 73.17
- 22. UNIT CAPACITY FACTOR (USING DER NET) 93.40 94.23 73.17 t23. UNIT FORCED OUTAGE RATE 2.55 2.58 7.39
- 24. SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE, AND DURATION OF EACH):
- Enf.unling/Modiff cal 1_9D_s_e.pfsd;.ey_12,. 1984 51 days _
- 25. IF SHUTDOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP
hd3_lu)SH4 - -== - - _ - - - _ -----_--_--____-----_____
NOTE THAT THE THE YR.-TO-DATE AND CUMULATIVE VALUES HAVE BEEN UPDATED.
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UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-328 UNIT NAME Seanovah Two
- DATE July 10. 1984 COMPLETED BY D. Dunree REPORT MONTl! JUNE TELEPHONE (615) 870-0248
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[g "b C yg Licensee y Cause & Cor'rective No. Date E O$ 8 ]t~g Event $*e 8'^o Action to R Ej 2 5y" Report # #7 &T Prevent Recurrence 5~ ?l5 N" $"
4 840612 F .0 A 5 . Tube leak in A-4 feedwater heater.
t 5 840629 S 18.38 B 1 Manually shutdown to repair feedwater drain valve 3-526.
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-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
e AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-328 UNIT Sequoyah Two DATE July 10, 1984 COMPLETED-BY D. Dupree TELEPHONE (615) 870-6248 MONTH JUNE DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MVe-Net) (MWe-Net) ,
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1 1132 17 -
1115 t 2 1131 18 1114 3 1131 19 1112 4 -
1131 20 1112
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5 1131 21 N13 6 1125 22 11N 7 1124 23 1110 8 1122 24 1109 9 1122 25 1109 j 10 1121 26 1109 11 1123 27 1108 12 1120 28 1032 13 1115 29 985 14 1039 30 -393 15 1112 31 .
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INSTRUCTIONS
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On this format,, list the average daily unit power level in MWe-Net for each day in the reporting month. Cor.pute to the nearest whole megawatt. .
(9/77)-
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Plant Maintenance Summary
.The following significant maintenance items were completed during the
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- month of June 1984: l Mechanical Maintenance
- 1. Replaced two bad bearings in the "B-B" fuel handling exhaust fan.
- 2. Repaired number 11 bearing sparking problem on the unit 1 main generator exciter. The damaged bearing and rotor were sent to Muscle Shoals for repair and machining. Two coupling bolts were found gauled and were replaced.
- 3. The "1A" main feedwater pump turning gear motor locked up. A gear for the 5
gearbox on the gear. reduction unit was fabricated and installed.
- 4. Leaking tubing in the unit 1 gross failed fuel detector heat exchanger was repaired.
- 5. A broken crankshaft was replaced on the "A-A" Auxiliary control air compressor.
- 6. A bonnet assembly was replaced on 0-VLV-62-1057.
- 7. Snubber number 1-CCH-845 was found to be leaking at the sightglass. The sightglass broke during repair. Another snubber was tested and installed.
!. 8. Retrieved a plastic bottle, TLD badge,' and dosimeter from the unit 2 refueling water _ storage. tank. They were dropped during sampling of the RWST.
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- 9. Made. repairs'to the-2A mixed bed demineralizer tank. Prepped the tank for welding and welded the tank. PT'd and x-rayed the welds and are presently grinding out small indications in the weld.
- 10. Furmanited several CSSC and non-CSSC valves on various systems. Attempted
- to furmanite- the bonnet leak on 2-VLV-3-526 a loop 4 drain valve in the 7 west valve' room, but were unable to do so.
i 12. Performed SI-102 ~on diesel generator 2B-B (monthly / quarterly inspection) and diesel generator IB-B (annual inspection).
i 13. Replaced leaking lube oil cooler-#2B2 on diesel generator 2B-B.
- 14. ' Removed the traverse locking assembly from the fuel transfer cart which had caused problems during previous refueling outages.
- 15. ' Cooling tower _ lift pump "2D" was reported to have no flow through the bearings.
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Divers from Muscle' Shoals set the stoplogs so the pit can be pumped down to repair,the pump. Attempts are now being made to pull the pump.
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- 16. .Five tubes.were found leaking in 2A4 feedwater heater. After inspecting
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, the -heater,' a total of 21 tubes were plugged.
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- 17. . Replaced the solenoid valve.on 1-FCV-61-191 and it passed the post-maintenance c
stroke test.
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Plant Meintentnca Summary .
Pag 3 1 of 3 Electrical Maintenance DATE. C0rFONENT. . . . . FAILURE DESCRIPTION...... CAUSE OF FAILURE......... CORRECTIVE ACTION........ PR04t. . . . -
06-01 1-FEV-062-0144 MAKE UP INJECTION VALVE CCHTACTS ON RELAY DID NOT PLACED JUTiPER ON FB111AX NONE-DID HOT OPEN WEN OPEN C#JSING VALVE TERMINAL 132 CHECKED s ENGERIZED 1-FSV-144 TO STAY CLOSED OPERATIDH OF VALVE WORED GOOD CHECKED CONTACTS 04.
RELAY GOOD CONDITION 06-01 1-TCV-067-0199 ELECTRIC BOARD ROOM AIR WEN VALVE WAS REBUILT REPLACED ADJUSTING PLATE N0iE C0FOITION SUPPLY CONTROL THEY LEFT DUT THE ADJUSTED VALUE TESTED VALVE WOULD NOT ADJUST ADJUSTING PLATE FOUND IN GOOD CONDITION 06-03 1-INVB-250-00G THIS TEST WAS TE RESULTS NO FAILURE AT THIS TIME TESTED INVERTER 1-II NONE N-T OF THE INVERTER BLOWING CURING A 6.9KV BD.
FUSES WHEN TE UNIT TRANSFER MONITORED 480VAC TRIPPED INPUT RECTIFIER DUTPUT INVERTER OUTPUT 06-01 2-HTRA-061-009 ICE CONDENSER FLOW SELECTCR SWITCH AND REPAIRED SELECTOR SWITOi FUE 3 DEFROST HEATER 18 WOULD TERMINAL BLOCK WOULD NOT AND TERMINAL BLOCK NOT DEFROST FUNCTION LOOSE CONNECTI0tG COFNECTIONS ,
06-01 2-HTRA-061-000 ICE BUILD UP IN BOTTON OF HEAT TRACE WIRE BURED REPLACED HEAT TRACE UITH Note 4B PAN UNDER MOTOR ON UNIT 2 INTO NOT WORKING DIFFERENT TYPE OF WIRE ICE C0tOENSER UPPER CHIPPED ICE AWAY CHECKED PLErfiUN FCR HEATING RETURNED TO SERVICE 06-01 2-HTRA-061-000 ICE BUILD UP IN PAN UNDER HEAT TRACE WIRE SHORTED REPLACED HEAT TRACE UIRE N0tE 4A MOTOR ON UNIT 2 ICE CUT NOT WORKING WITH DIFFERENT TYPE WIRE C0f0ENSER UPPER PLEr81UM CHECKED AND RETURNED TO SERVICE 06-05 1-FSV-062-0144 RED LIGHT WILL NOT CLEAR VALVE STEM STICKING OPERATOR STROKED VALVE TOE
-A ON F1AKE UP INJECTION SEVERAL TIMES AND SAID IT VALVE WAS OK THIS PROBLEM UAS PROBABLE SOLVED WITH MR A292089 04-05 1-FSV-062-0144 RED LIGHT WOLLD NOT CLEAR TOO MUCH PACKING ROPE REMOVED SOME OF THE NONE
-A DN MAKE UP INJECTION Ut0ER STEM PAJT OF VALVE PACKING R0PE HAD i VALVE LIMIT SWITCH CPERATION STROKE VALVE SEVERAL TIMES WORKED FINE
Plant Mainten'nce Summary (Continued)
, Electrical Maintenance Pag: 2 of 3 DATE. C0rP0 LENT. . . . . FAILURE DESCRIPTION...... CAUSE OF FAILURE......... CCRRECTIVE ACTICH........ PRON.... -
06-05 0-MTRD-260-011 FIRE PUMP AT CCW PUMPING WHEN MAINTANCE REPLACED REPAIRED CABLE JACKET 01 NONE A-B STATION STOPPED PUMPING THE PUMP THEY DAMAGED CABLE 2PL50189 AT CCW PUMP WORN OUT 28-8 POWER SUPPLY CABLE PUMPINC STATION THAT FED THE FIRF. PLFIP 84-06 2-MTRB-313-110 AIR CC+0ITI0tER IN 2A-490 FREON IN 2.1 ADDED FREON AS REGUIRED FDE VOLT BOARD ROOM ON UNIT AIRC0f0ITI0tER LOW CHECKED FOR PROPER 2 SIDE BLOWING WARM AIR CPERATION RETL'RtED TO AtO NOT COOLING SERVICE 06-23 1-ECTA-074-001 HAND WHEEL WOULD HOT TORQUE SWITCH SET SCREWS TIGHTENED SET SCREWS NONE 0-A DISENGAGE WHDI RUN WERE LOOSE ADJUSTED LIMITS RETURNED ELECTRICALLY TO SERVICE 06-23 1-9ATB-082-00C NO FAILURE WORK HEEDS TO 18-B DIESEL GENERATOR CLEAMED DER MI 10.27 Note B-D BE DONE BEFORE SI 238 BATTERIES CORRODED CONNECTIONS AND DIRTY 06-23 1-ECTB-070-004 HAND SWITCH FAILS TO FAULITY HAND SWITCH REPLACED HAND SWITCH aid NONE 6-A INDICATE PMP EITHER DN OR CHANGED OUT It0ICATOR OFF ON COND0 TENT COOLING LIGHT CHECKED AND PUMP 1A-A RETURNED TO SERVICE 06-27 2-FSV-313-0485 BOARD ROOM COND 2A-AAIR VIBRATION PROSABLY INSTALLE0 SOLEHOID COVER NONE
-B TO DAMPER SOLINOID VLV RESULTING FR0tt SOLONIDE PUT FLEXIBLE CONDUIT BIEK VIRBRATING ALSO COVER BEING ENERGIZED TOGETHER LOOSE 06-27 2-MTRE-030-044 DIESEL GDERATOR 2A-A MOTOR HAS DEAD GROUT 0 REPLACED MOTOR ON DAMPER TOE 08-A ROOM EXHAUST FAN 1A KEEPS ESHORTJ BLOWING FFUEES 06-Z/ 1-FSV-067-03 0 PD.ETRATION ROOM CONTROL SIGNAL WAS NOT GIVEN STROKED ALL FOUR NDHE
-A A2 SUPPLY CONTROL VLV DID PROPERLY PDETRATION ROOM C0tiTRG_
NOT OPEN WHEN AN AUX BLDG VLVS AND THEY ALL WOR'.ED ISOLATICH SIGNAL WAS PROPERLY AT THIS TIME GIVEN PER SI 83 06-27 2-FSV-067-0349 PENETRATION ROOM CONTROL LIMIT SWITCH WAS OUT OF A0 JUSTED LIMIT SUITCH TOE
-B B1 SUPPLY CONTROL VLV DID ADJJSTMENT VERIFIED LIGHT ON 0-N-27A i NOT OPEN WHEN AUX BLDG PANEL IN CONTROL RCOM E
i
Pitnt Mainttnanca Summary (Continued)' ,
j Electrical Maintenance . Peg 2 3 of 3
.DATE. C0r90 ENT. . . . . FAILURE DESCRIPTION...... CAUSE OF FAILLRE. . . . . . . . . CORRECTIVE ACTION........ ' PR041. . . .
ISOLATION SICNAL WAS GIVEN PER SI 83.
- 06-27 2-FSV-067-0350 PEETRATION ROOM CONTROL SIGNAL WAS NOT GIVEN CHECKED VLV WORKING NONE
! '-A A2 SLPPLY CONTROL VLV PROPERLY PROPERLY AT THIS TIME WOLLD teT OPEN LAEH AUX BLDG ISOLATION SIGNAL WAS GIVEN PER SI 83 l
! 06-27 1-LCV-062-0118 DIVERSION VLV THAT SET SCREWS IN ARM OF TIGHTENEO SCREWS IN ARM NONE
! CONTROLS FLOW TO HOLD LP LIMIT SWITCH LOOSE ADJUSTED LIMIT SWITCH
! TAl4(S LIGHT STAYS ON RETUPJED TO SERVICE l REGARDLESS OF SWITCH l -POSITION l
l 06-23 1-16-003-0179A BASE OF LIGHT BLLB BROKEN OPERATIONS WAS CHANGING REr10VED BASE OF BULB Note
-B 0FF IN SOCKET NO LIGHT OUT LIGHT BlLB IN TE REPLACED WITH NEW BLLB HALO BOTTOM OF ERCW FOR CHECKED WITH OPERATOR 1B ISOL VLV POSITION LIGHT GLOWING OK SWITCH WEN BLLB BRG(E i LEAVING BASE OF BULB IN SOCKET 06-27 2-ffTRS-313-048 C0f0ENSATION ACCLA1ULATION CLOGGED DRAIN LINE UNCLOGGED DRAIN LINE NONE 8-A IN TE 400V B0 Rf1 ANJ 2A-A l84-06 0-BCTB-201-CSJ INSPECT NORf14L SUPPLY FOR FAULTY WELDS HAVE BEEN WELDS WERE FOUND TO BE NONE
/5C 400V AUX BLDG C0tti BD BUS FOUND IN OTER BRACHETS ACE 30 ATE WITH NO VISIBLE A SEC0 LEARY DISCO >BECT CRACKS SUPPORT BRACHETS FOR POSSIBLE BRONEN LELDS l 84-06 0-BCTB-201-CCK INSPECT NORf14L SLPPLY FCk FAULTY WELDS HAVE BEEN' FOUND ONE WELD WITH NONE I /9C 400V AUX BLOG C0111 BD BUS FOLAO IN OTER BRACKETS VISIBLE CRACK REPORTED ON l 8 SEC0tOARY DISCO >*ECT MR
! SUPPORT BRACMETS FOR POSSIBLE BRCEN LELDS L
-~ -
\
l Plant Maintenance Summsry (Continued) )
i Instrument Maintenance '
I l.
- 1. During' monthly testing of UNI level switches, all unit 1 instruments were found within tech spec' tolerance arid unit 2 had one switch out of tech spec tolerance. DCR P-2111 is being processed to replace the Barton 288A with a more reliable instrument.
1 l 2. There were three (3) failures of the containment sump level transmitters
, during the month of June, 1984. All three failures were due to indicator
, drifting out of tolerance and. the unit operator declaring the channels inoperable. .The failures were'as listed below:
6/12/84' 1-LT-63-179 .Iodicator reading high - transmitter was re-calibrated with no " top' off" of filled sense line. MR #A292186 6/21/84 1-LT-63-179' Indicator reading low - MR #A282978. Transmitter sensor bellows shows signs of damage - bellows is being replaced and sense lines refilled with oil. Work is'in progress.
6/26/84 2-LT-63-179 . Indicator readinF.high.- declared inoperable.
MR #A281656,_ PRO #2-84-102. Transmit'ter sensor bellows showed signs of damage. Sensor' bellows was replac'ed and system re-filled with new oil, re-calibrated, response ti:ne tested and returned to service on 7/2/84.
- 3. During the month thern were two.(2) control room isolationn due to high rad-spike signals on the 101-90-125 monitor. The first was caused by the sample pump locking up and. spiking the monitor. The other isolation occurred when the monitor spiked while the chart paper on the recorder war. being changed.
There were three (3) ' ABI's due to RM-90-103 fuel pool monitor,'all of which were attributed to spurious signals.
The, time delay relays for high radition trip circuits on auxiliary building, containment and control room monitors werb receiv'ed and are 'due to be changed out in July. Th'is? mod is not approved on the' fuel pool monitorr. due to USQD problems. The upper level discrimator modification is' due - to start' in August.
ECN 6161 has behu~ issued ned material is presently on order.
Unit 1- .. -
metal thermocouple and. connect t A re. trder point to the ' oil drain thermocouple'which was're-loett ; cc e isolated side of the bear.ing housing. Assisted in making . ' . ny t . . ' !ications ,to,ininimize ' the change ;
-of gounding theJnumber,11; bearing.
, 2. A l% correction vac' aude. to the feedwater flow constant usedf f r. calorimetric -
. data on the P-250 pr6 cess computer. It'is suspectedfthe error'is due to the feedwater flow. nozzles. i
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7-Plant Maintentnce Summary
[ (Continued)
Instrument Maintenance Unit 1
- 3. The gland seal steam pressure relief valve lifted causing IM's to investigate the new controller PIC-47-183 installed during the unit I refuel outage. We
.. found_ no problem with the controller but it- did require field tuning during It is suspected that PCV-47-183 is leaking through which caused the startup.
problem.
- 4. Data was collected for two.STEARS this month.
A. INST-83-18, Reliability Test of Weed Inst. Co. Model N900 Series Narrow Range RTD was written to test the RTD as a possible replacement for the existing Rosemount Reactor Coolant NR RTD's.
- B. INST-83-20, Steam and Feedwater flow Instrumentation Problem Investi-gation was written to gather data which will help to determine the 1
reason for the steam flow delta pressure increase which has occurred every cycle since initial plant startup. Data will be collected 1
throughout this operating cycle for evaluation by NCO.
Unit 2 4
- 1. Received a Part 21 notification from Westinghouse on Barton Lot I differ-ential pressure transmitters exhibiting thermal non-repeatability. Three of the five transmitters listed were currently installed on Unit 2. It was decided to replace them immediately since this was the best option to correct the problem and they were scheduled to be replaced during the unit 2 cycle 2 refuel outage. One additional lot I transmitter was replaced during the feedwater drain line leak forced outage which completed all required replacements of the Barton lot 1 transmitters.
- 2. Re-calibrated the-NIS power range channels to new values obtained during the TI-36'incore-excore cross calibration.
- 3. Number 3 main ~ turbine throttle valve drifted partially closed and'was
. isolated. The servo valve and dmnp valve was replaced along with the_LVDT,
' and circuit card. The valve was calibrated and . returned to service after the forced outage.
~4. PCV-3-122 was declared inoperable. .The moog (servo) valve was found defective, repir.ced and returned to service.
- 5. ~ A re-calibration of the steam generator level. deviation -alarm was made -.
g due to.the excessive number.of. alarms-being= received. This was suspected.
to be' caused by the number l3 HTR Dr Tk' flow control valve being erratic.
The: setpoint was. increased from' 15% to. i ' 7.5% level deviations. FCV-6-106A was-.found to'have;a benti stem and repaired'during the forced outage.
- 6. DThe' main feed pump turbine "B" was. worked on during_the forced outage
"^
due-to speed problems. The orifices were cleaned, the EH converter:
1and speed governor was:found to have trash in the cup valve which would cause the pump.to run at less,tha'n full speed. The controls were calibrated
. and .the pump returned -to service.
1
/~ Plant Maintenance Summaryj(Continued) ,
'~
INSTRlf1ENT HAINTEtiANCE MONTHLY SUIT 1ARY. J07-03-8'4 .
Page'1;of.2;
- f. .
, COMP.
~
. MR. COW ' U ~ FUNC SYS ADDRESS. DATE. . . . DESCR IPTION. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . CORRECTIVE ACTION. . . .. . . . . ,
,~f :A092989 1 )X ~092 5004 06/20/84 1-XX-092-5004,0BTAIN INTERMEDIATE POWR RANGE - 11R WAS INITIATED TO ERIFY INPUTS VERSUS CtRRD4T/ VOLTAGE READINGS AT 20%, 25L AND 30% OUTPUT. NO CORRECTIE ACTION REGUIRED.
POWER T A233269 2 099 ' 06/12/84 2-099 ,POS.12113 DN CU. C HAS BAD LOGIC UPON ItNESTIGATION A UNIVERSAL CIRCUIT (FOUND WHILE PERFORMING SI-90.82) CARD WAS FOUND DEFECTIVE. - THE CARD WAS REPLACED, LOGIC PROVED, AfD RETURNED TO
(~ SERVICE.
A233329 1 FT 063 72C 06/04/841-FT-063-92C, REPLACE TUSE FITTINGS, VENT PLUGS, THE TL'BE FITTING ROUTED TO THE
- O TUBING AS REGUIRED TO ELErIINATE LEAKS TRANSMITTER WERE FOUt0 LOOSE CAU3ING THE
!C LEAKS. THE FITTINGS WERE TIGHTENED AND TFE TRANSl1ITTER WAS RETURNED TO SERVICE.
I A233330 ,l'FT 063 91C 06/04/84 1-FT-063-91C,1-FT-63-91C, REPLACE TUBE F1 'ING THE TU8E FITTINGS ROUTED TD THE C.
- D VENT PLUGS AND TUBINC AS REQUIRED TO . TRANSMITTER UERE FCUiD LOOSE CAUSING THE ELIMINATE LEAKS LEAKS. THE FITTINGS WERE TIGHTENED AND THE TRANSl1ITTER WAS RETURNED TO SERVICE.
LC A238671- 0 RE 090 102 06/12/84 0-RE-090-102, REPLACE RM-90-102 HIGH RAD ALARM TFE RAD ALARM RELAY WAS REMOVE 0 DUE TO RELAY KV-R102 WHICH WAS REMOVED PER TACF FUEL RELOADING OCCURRING IN THE AREA.
0-84-71-90 AlO CLEAR TACF 0-84-71-90 RESTORED RELAY KU-R102, VERIFIED D: OPEWATION/ AND RETUR;ED TO SERVICE.
i- .A242346 2 099 S/N0697 06/14/84 2-099-S/N0697, BOARD HAS BAD LOGIO BAORD HAD A BAD Z3 CHIP. REPLACED CHIP h AND LOGIC TESTED AND STORED FOR SPARE.
f? "A246254 0 RN 090 225 06/13/84 0-Rn-090-225,110NITOR NEEDS TO DE CHANGE 0. THE RADIATION MONITOR WAS BRINGING IN AN ALARMS WEN RELEASE IS STOPPED. ALARl1 WHEN NO FLGJ W6 BEING INPUTTED.
NO PROBLEM FOUND.
I.. f' A261382 2 LEV 003 104 06/09/84 2-LCV-003-104,THE VLV WILL NOT REMAIN CLOSED THE VutTAGE TO CURRECT BOARD WAS FOUPD WEN IN AUTO & LVL SETPOINT AT 33% OR 15L YOU BAD CAUSING THE VALVE NOT TO OPERATE STILL HAVE A. RED & GREEN LIGHT, THE VLV UAS PROPERLY. THE CONTRCLLER WAS REPLACED,
,D STACKED N O LIMIT SW'S ARE O CALIBRATED, AND RETURNED TO SERVICE.
l A281383. 2 TI '.068 319 06/10/84 2-TI-068-319,2-TI-68-319 PZR LIQUID TEMP. THE TEMPERATURE n0DIFIER WAS FOUND OUT ItOICATOR FAILED LIGH. ItNESIIGATE A.'O REPAIR OF CALIBRATION DUE TO SETPOINT DRIFT l (';
CAUSING THE ERRCHEDUS INDIi TTION. THE TEMPERATURE MODIFIER WAS RECALIBRATED, OPERATION VERIFIED, #10 RETURNED TO C SERVICE.
A282964 1 TI 068 378 - 06/20/841-TI-068-398,RX. EAD VDir TEMPERATURE INDICATOR THE REACTOR HEAD VENT TEMPERATURE I
'HAS FAILED LOW INDICATOR HAS FAILED LOW DUE TO NATURAL
'N CAL DRIFT. RECALIBRATED INDICATOR #1D RETURNED TO SERVICE.
.A292063 0 PDC 0 31A 14 06/14/84 0-PDCD-31A-14,"A" CONT. BLDG. PRESS FAN HOT THE LINXAGE FOR THE DANENER OPENING WAS
- O f1AINTAINING PROPER PRESSORE OUT OF ADJUSTMENT CAtSING PRESSURE TO BE LOWER THAN REGUIRED. READJUSTED TE
)
Plant Maintenance Summary (Continued) -
INSTRLMENT MAINTEtMNCE MONTILY SUIT 1ARY 07-03-84 J-~c 2 Page 2 of 2 C~ COMP
(
MR. COMP U FUNC SYS ADDRESS. DATE. . . . DESCRIPTION. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . CORRECTIVE ACTION. . . .. . . . . . . . . . . . . . . . . . .
I LINKAGE AND RETURNED TO SERVICE.
A292089. 1 FCV 052 144 06/02/841-FCV-062-144,THIS VALVE HAS A LIMIT SWITCH TOO MUCH PACKING ROPE UFOER STEM HUT OF
_ . PROBLEM, RED LIGHT WON'T CLEAR-PLEASE REPAIR OR VALVE. REMOVE 0 SOME OF THE PACKING R0PE I ADJUST AS HEEDED. HAD OPERATIONS STROKE VALE SEVERAL TIf1ES WORKED FINE.
A292100 1 FI '003 155A 06/07/84 1-FI-003-155A, FLOW INDICATOR FAILED OFF SCALE THE POWER SUPPLY 'WAS FOUte BAD CAUSING I LOW TFE LOW CONDITION. REPLACED THE ZENEf:
DIODE, VERIFIED PROPER OPERATION, M O-RETURNED TO SERVICE.
C A292186 1 LI 063 170 06/13/84 1-LI-063-170, INDICATOR READING 6% WITH SUMP CRY THE LEVEL TRANSMITTER WAS FOUND OUT OF PLEAFE REPAIR CALIBRAION DUE TO NA1 URAL DRIFT.
RECALIBRATED THE TRAMMITTER, VERIFIED D OPERATION, AND RETURED TO SERVICE.
A292206 2 TI 060 309 06/10/84 2-TI-068-309,PRT TEMP. It!0ICATOR FAILED - REPAIR THE TEMPERATURE MODIFIER WAS F0lto OUT OF CALIBRATION DUE TO SETPOINT DRIFT C CAUSING ERRDNEDUS RE/CINGS AT THE It01CATOR. THE NODIFIER WAS RECALIBRATED, VERIFIED PROPER OPERATION P AND RETURNED TO SERVICE.
b A292226' 2 FDS 070 81E 06/08/84 2-FDS-070-81E, CHECK SWITCH CALIERATION SWITCH TFE TRANSMITTER WAE FDUto OUT OF ,
I CAUSES UNNESSARY CLOSING OF FCVS 70-90 1 133. CALIBRATION DUE TO NATURAL CRIFT CAUSING C FAULTY VALVE OPERATIG4. THE TRANSMITTER WAS RECALIBRATED AND RETURNED TO SERVICE.
O A293039 1 TI 068 2E 06/19/84 1-TI-068-2E, INDICATED T/ AVE HAS FAILED LOW. WHEN THE REACTOR CGOLANT PUMP STOPPED INVESTIGATE AND REPAIR. .THE CHANNEL WAS OK THE CHANNEL FAILED DLE TO AIR INTRUSION.
UNTIL THE RCP WAS STOPPED CHECKE0 RESISTANCE FEADINGS EVERYTHING P LOOKED FINE EXCEPT WFEN RCP IS SHUT OFF.
A293146 1 Pfl 090 119 06/13/841-ftN-090-119, SIGHT GLASS IS HARD TO READ, PLEASE THE SIGHT GLASS WAS DIRTY ON THE i
CLEAN OR REPLACE RADIATION MONITOR MAKING READINGS HARD
& TO TAKE. CLEANED THE SIGHT GLASS, VERIFIED PRODER OPERATION, AND LEFT IN i SERVICE.
ir 18 records listed.
C; ,
i'C i
Plant Maintenance Summary (Continued)
Modifications Group
- 1. DCR 569 - Air Compressor Intake CO2 Monitor All work including functional test has been conpleted.
- 2. DCR 1743 -' Relocation of the Power Source for the Rusco MA-540 Computer All work including fuuctional test has been completed.
- 3. DCR 1934 - Installation of Lights, Fan, and a Fire Alarm in the Modification Paint Storage Building All work including functional test has been completed.
- 4. DCR 2027 - Relocation of the Field Toolroom All work including checkout of monorail and phone service has been completed.
- 5. ECN 5237 - Laundry Facility Work continued in the ventilation fire protection, rad monitor and power systems. Overall the work is 65% complete.
- 6. ECN 5502 - Interlock Doors A-110, A-111 The functional test has been stopped pending repair of the door strikes.
- 7. ECN 5560 - Removal of Fire Detectors in Manholes All work has been corapleted for this modification.
- 8. ECN 5596 - Batch Neutralization System The required heat trace has been installed. The auto sequencer has been installed. Work remaining includes insulation of piping and the sequencer cams.
- 9. ECN 5645 - Steam Generator Blowdown System Unit 2 Conduit work has progressed to 73% of completion.
10 .' Replace Relays and Rewire Wells-Fargo Tamper Switch Work has progressed to 32% of completion.
- 11. ECN 5712 - Installation of Additional Evacuation Alarm Work commenced mid period with the installation of new conduit and some strebe_ lights. Estimated completion is' October 15, 1984.
l Plant Maintenance Summary (Continued)
Modifications Group (Continued)
- 12. ECN 5753 - Change Setpoint and Logic for Control Room Annuciators - Unit 1
. The four remaining annulus splices were completed this period. Two of four functionals have been completed.
- 13. ECN 5755 - Annuciator Removal From the Control Room Work has been in hold pending receipt of new annuciator windows. Windows arrived the last week of the period. Work is expected to be completed the first week of July.
- 14. ECN 5770 - Installation of a New Rad Monitor in the Condenser Exhaust Cable pulling progressed to 83% of completion.
- 15. ECN 5867 - Unit 2 Spent Fuel Transfer System The old control cabinet has been replaced. All field conduit and cable has been completed. Panel wiring has commenced.
- 16. ECN 5871 - Relocation of the ERCW Rad Monitor The "B" train ERCW monitor has been relocated and turnover to instrumentation to verify calibration.
- 17. ECN 2768 - Reactor Pressure Vessel Level Indication System (RVLIS) (Unit 2)
The preparations of the mechanical workplans is continuing. Several have already.been prepared and submitted for approval. Remaining workplans should be compelted by end of month.
ENDES has. released several hanger drawing with the rest due by the end of the month. All remaining drawings are due at that time also.
All major. material has been ordered or is on site. Some minor items are still to be ordered. Instruments and valves that Westinghouse is to provide have not been received. . Westinghouse is expediting,
, During the recent maintenance outage (mode 3) on unit 2 a team of. mechanical engineers entered containment to map out the RVLIS capillary routing. 'Several areas'have been laid out now so that the craft will be able to start at the beginning of the next outage.
The workplan for conduit outside containment is in'the approval cycle.
The preparation of the work plan for cable pulling and cable termination has begun. The procurement of all electrical materials is underway.
. - . . .. - - ~ .
Y
,a C
Plant Maintenance Summary (Continued)
Modifications Group d
(Ccntinued) i .
- 18. ECN 2780 - Post Accident Sampling Facility (Unit 2)
, Portion of field ordered mechanical materials have been received and the electrical equipment procurement process is continuing. The conduit work outside containment is approximately 90% complete. Cable pulling commenced this period with 78 of 141 cables pulled. The follcwing mechanical work is complete: HVAC system dact hangers, tubing panels, and core drilling. The fire protection workplan is in work. Tubing installation in the room as well as in the' annulus is continuing.
l- 19. ECN 5198 - Technical Support Center (TSC) (Unit 2)-
The modification of the status monitoring system (SMS) cabinets continued for the interface equipment. The control building conduit installation on elevation 685 continued. Both the SMS and elevation 685 conduit work should be completed by mid July, the conduit in the annulus is complete.
( - The DPM50 and P250 tie-in work has begun. Cable pulling has begun.
- 20. ECN 6055 - Wide Range Pressure Transmitter to the RVLIS Panel The mechanical workplan investigation and preparation is in progress. The electrical conduit installation in the anFiliary building is Continuing.
- 21. ECN 5194 --Iodine Monitoring Building i
The electrical workplan for unit 2 conduit installation has been approved-and work has begun. The. termination of the unit I sample room air conditioning cable was completed. The mechanical workplan has been approved.
~ Tubing installation in annulus is complete. Remains is to run 1" tubing in
. PING; room, leak check, then install the probe. This-work should be completed
-by-mid July. Control air tie-in will be done during the unit 2 cycle 2 outage.
- 22. NuReg 0588 Items I
The1 unit' 2' vent motor replacement is continuing for non outage work (ECN L5370). . The workplan to replace pressure switches (SYS 3) is in the approval cycle (ECN L5823). The preparation of the electrical workplans for valve operator replacement is continuing. Several workplans for valve operator replacement are in the approval cycle (ECN L5824). One
, workplan for valve operator replacement.has begun work. Two of 93 valve operators have been replaced.' The workplan for limit. switch replacement
- " (ECN L5881) is approved and ready.to work. The workplan for the temperature switch replacement on systems 12 and 30 (ECN L5882) is_ approved and ready te work. The solenoid valve replacement (ECN 5457) has begun and.four non outage related valves are being worked as they become available.
-24 ,
w.
A
- - - - +
e --, ,~r -. -a,--- , -y r--- y y # - i- , ,-eir-
Plant Maintenance Summary (Continued)
Modifications Group (Continued)
- 22. NuReg 0588 Items (Continued)
The ' flow transmitter replacement materials are on order from ENDES for delivery.of July 9,1984.and the workplan preparation is in progress
~
(ECN 5884)~. The relays for the revision of system 43 limit switches have
- arrived for unit 1 & 2 (ECN 5898). System 3 and 7 motors are on order for valve operators (ECN 5970). The miscellaneous instrument replacement workplan preparation is complete and is in the review cycle (ECN 5995).
- Also, the mechanical and electrical workplan preparations are in progress for the hydrogen monitor modification (ECN 6032). ,
- 23. Other
'Cavitating venturi ECN 5842 - Prefabrication of venturi is complete.
L-Shape Shielding Wall ECN 6071 - Concrete _ shielding wall installation in auxiliary building elevation 669 has begun.
k 1
A
0FFSITE DOSE CALCULATION MANUAL CHANGES
- APPENDIX A (3
.%) . Change 1 Description of change Correction of a typographical error in definition of terms following equation l.1 on page 3 of the SQN ODCM.. No model changes are reflected in this change; therefore, no evaluations are necessary.
~ . - . __
1
- Change 2 ,
~
t I j Description of change
, y .
Correction of an inaccurate statement on page 13 of the SON ODCM. . No model changes are reflected in this change: .therefore, no evaluations are necessary.
I a Change 3 Description of change.
These changes to the SQN ODCM'and? RAP 1.2 result from the Fall 1983 land use census. Actual ODCM changes appear on pages 12, 15,_15a, 16, and Tables 1.4 and 1.4a.- RAP changes: appear on pages 6 and 7. ,
4 Analysis'or evaluation' justifying change.
Ths Fall 1983-land use census has resulted in changes in the maximum X/O and D/O'8
'g- used in the monthly gaseous ODCM calculations.
U e n
, - ,,g., , y - - - . , - - ---w , -- x ,.-v,e .m - , w,
OFFSITE DOSE CALCULATION MANUAL CHANGES (Continued)
. APPENDIX A Evaluation of - Accuracy of Dose Calculation or Setpoint Determination This change will have no effect on setpoint determinations. Monthly air doses and child bone doses calculated will decrease slightly as indicated 37
^'-) '
l in the attachment. Infant thyroid doses will increase slightly as indicated.
Chango'4 Descr ption of Change h
The 0QCM currently estimates fish ingestion doses to the maximum organ gastrointestinal tract (GIT and bone). Doses to the liver should be added to thfs pathway. Tha actual changes appear on page 21.
The O CH also currently estimates water ingestion doses for the maximum organs (bone and thyroid). . Doses to the GIT should be added to this pathway.
.%J ('] Analysis or Evaluation Justifying Change Review of the 1983 mix data indicate the need for these organs to be added to the calculations.
Evaluation of Accuracy of Dose Calculation or Setooint Determination This change will have no effect on calculated quarterly doses or setpoint determinations. It will allow us a more appropriate monthly dose estimate of the releases from the plant.
, \
\_/
9 %'d .
- _ _ _ _ _ . OFFSITE DOSE CALCULATION MANUAL CHANGES APPENDIX A 9 7 I/2 (1.1)
[
T
, Xg= (2/n) f.k
.I J lQ.P exp (-Ag x/u )
j=1 k=1 zkuJ. (2nx/n) where Xg = air concentration of radionuclide i,p Ci/m3 .
fjk = j int relative frequency of occurrence of winds in windspeed class j, stability class k, blowing toward this exposure point, expressed as a fraction.
Qg = average release rate of radionuclide i, pCi/s.
p = fraction of radionuclide remaining in plume, Figure 1.1.
Izk: vertical dispersion coefficient for stability class k
~
which includes a building wake adjustment, Izk = (ozk2 + cA/n) I! , where o zk is the vertical 9 dispersion coefficient for stability class k (m), c is a building shape factor (c=0.5), and A is the minimum building cross-sectional area (1800 m 2 ), ,,
u)= nidpoint value of wind speed class interval j , m/s.
x= downwind distance, m. -
n = number of sectors, 16.
Ag = radioactive decay coefficient of radionuclide i, s9-1#.
2 nx/n = sector width at point of interest, m.
For determining the total body dose rate D g= XgDFB f (1.2) i where DTB = total body dose rate, mrem /y.
Xg = air concentration of radionuclide i, pCi/m3 .
DFB. * = total body dose factor due to gamma radiation, mrem /y per pCi/m3 (Table 1.5).
,a #
, ;o Revision 9 s
SNP Err 7 JUN M 1984- :;
c =
4
- . OFFSITE DOSE CALCULATION MANUAL CHANGES .
APPENDIX A
- where:
Dy =~ gamma dose to air, mrad.
X/Q = highest annual-average relative concentration, 5.12 x 9 10 6 s/m3 .
0.9 = fraction of total gamma dose expected to be contributed by these nuclides. 3 106 = pCi/Ci conversion factor '
3.15 x 107 = s/yr conversion factor Qg = monthly release of radionuclide i, Ci.
DFy*.' = gamma-to-air dose factor for radionuclide i, mrad /yr per
' pCi/m3 (Table 1.5). -
This equation then reduces to Dy 1.81 x 10'7 Qg DFy g (1.13) 1 5
For detennining the beta dose to air:
i D e (X/Q) 108 Qg DFp g (1,14) 5 O.9 3.15 x 107 where: '
DE = beta dose to air, mrad.
X/Q' = highest 6 annual-average 3
relative concentration, 5.12 x 9 10 s/m .
0.9 = fraction of total beta dose expected to be contributed by these nuclides.
3 106 = pCi/Ci conversion factor 3.15 x 107 = s/yr conversion factor Qg = monthly release of radionuclide i, Ci.
DF 1, = gamma-to-air dose factor for radionuclide i, mrad /yr per pCi/m3 (Table 1.5).
This equation then reduces.to: -
D = 1.81 x 10~7 Qg DF gt (1.15) 5 i
Revision 9
-29.
CE7 IEV /
,){j, , 'S lqR4 3 - - _ _ , .
0FFSITE DOSE CALCULATION MANUAL CHANGES APPENDIX A Step 2 This methodology is to be'used if the calculations in Step 1 yield doses that exceed applicable limits.
Equations and assumptions for calculating doses to air from releases of noble gases are as follows:
Assumptions _
- 1. Doses to be calculated are gamma and beta air doses.
- 2. Dose is to be evaluated at the nearest site boundary point in each sector.
- 3. Historicalonsitemeteorolog[caldatafromtheperiod 1972-1975 will 9 be used.
- 4. All measured radionuclide releases are considered.
- 5. A semi-infinite cloud model is used.
- 6. Radioactive decay is considered.
t
- 7. Build ng wake effects on effluent dispersion are considered.
- 8. Dose factors are calculated using data from TVA's radionuclide libra y. .
Equations,-
Equations for calculating air concentration, X, is the same as in Section 1.1.1, step 1, part A. Air concentrations are calculated for the site boundary in each sector.
For determining the gamma dose to air D, = t, X,g DFy g (1.16) 5 i
where:
D = gamma dose to air for sector n, mrad.
X,g = air concentration of radionuclide i in sector n, pCi/m 3 1
DFYg = gamma-to-air dose factor for radionuclide i, mrad /yr per pCi/m3 (Table 1.5).
t, s time period considered, yr ,
.) !
30-Z .
]' SNPnw 7 Ji@l 261984
-[ - .OFFSITE DOSE' CALCULATION MANUAL CHANGES APPEN 'X A Equations For determining the thyroid dose from milk ingestion of I-131:
5 DTl!131
- 9 131 DF 333 D/Q x los (0.9) 3.15 x 10' (1.18) where:
DTH131 = thyroid dose from I-131, mrem.
Q33, = monthly release of I-131, Ci.
DF,31 = I-131 milk ingestion 2 dose factor to infant, 7.24 x 10' mrem /yr per pCi/m -s (Table 1.7)
D/Q = relative deposition rate, 2.96 x 10 ~9m 2,
, 9 0.9 = fraction of dose expected to be contributed by I-131.
3.15 x 107 = s/yr.
108 = pCi/Ci Equation 1,.18 then reduces to:
DTilg3g = 75.6
- Qg33 9 l
For determining the bone dose,from vegetable ingestion:
Q, DF , D/Q
- 108 g,g DBC s
=
3.15x107 (0.9) where: $
i DBC, = bone dose to child from Sr-90, mrem.
Q, =' monthly release of Sr-90, Ci.
DF, = Sr-90 vegetable ingestion dose factor to child, 1.36x10i a mrem /yr per pCi/m 2 -s. (As per Regulatory Guide 1.109 and NUREG/CR-1004 methodologies).
D/Q = relative deposition rate, 7.10x10- m 2, 9 3.15x107' = s/yr.
108 = pCi/Ci.
0.9 = f raction of total bone dose expected to be contributed .
by Sr-90.
Equation 1.19 then reduces to 9 '
4 obc, = 3406'Q,
- Revision 9 1
1 SNPnu/ / Jijp j 1984
- e
- c. . .-
~
- '0FFSITE DOSE CALCULATION MANUAL CHANCES ~ .
APPENDIX A i
For determining the gastrointestinal (s.i.) tract dose from vegetable ingestion:
10 6 DGI c c D/Q (1.20)
T , (0.9) 3.15 x 10' Where:
DGIT = teen g.i. tract dose from Co-58, mrem Qc = monthly release.of Co-58, ci DFC = Co-58 vegetable ingestion dose factor for the teen g.i.
9 tract, 3.87 x 10 mrem /yr per pCi/m 2 -s. (Regulatory 7 Guide 1.109 and NUREG/CR-1004 methodologies.)
D/Q = relative deposition rate, 7.10 x 10 ~9 m 2 9 3.15 x 107 = s/yr i
108 = pCi/Ci 0.9} = fraction of total g.i. tract dose expected to be contributed f
by Co-58 Equation .20 then reduces o
\
9 DGIT = 0.97 Q c Revision 9 snz z.sy 7 JU. M1984 m _ _ .
_. , ,~, . _.. __ __ _ __ _ __ , . _ _ . _ _ _ _
T ," OFFSITE DOSE CALCULATION MANUAL CHANGES
[ .v APPENDIX A.
~~
[Q, Step 2 O.
- - This methodology is to be used_if the calculations in step 1 yield doses that. exceed applicable limits.
Doses for releases of iodines and particulates shall be calculated
-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.
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. Hoyever, if the annual. doses determined in this manner exceed "
or approach the specification limits, doses calculated for previous
~ quarters 6ith the methodology of section 1.4 will be used instead of the doses estimated by summing monthly results. 8 1.3 Dose Projections
, In accorda)nce with specification 3.11.2.4, dose projections will be -
-(( m .
performed ( This will be done by averaging the calculated dose for the most recent month and the :alculated 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 ?.nd 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 1.4) are considered. In 9 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) describ'edLbelow shall be maintained and operated to keep releases AI. ARA. "
1.5.1 System Description A flow diagram for the CRTS is given in Figure 1.3. The system consists of two waste gas compressor packages, nine gas . decay tanks, Q . and ~ t.he issociated piping, valves, and instrumentation. Gaseous pg Revision 9 4 t
se nzv:7 JUN 261984:
M;r m
- - , - ,- . . - . . . - , . ~ . . _ - . - ,<_.,,-..---,m - . - - - - . -
7__
_g gvmyn= r ~
Loi
^
. 1 TENNESSEE VALLEY AUTHORITY Sequoyah Nuclear Plant P. O. Box 2000 Soddy-Daisy, Tennessee 37379 July 13, 1984-Nuclear Regulatory Commission Office of Management.Information-and Program Control Washington, DC 20555
-Gentlemen:
Enclosed is the June 1984 Monthly Operating Report to the NRC for Sequoyah Nuclear Plant.
Very truly yours, TENNESSEE VALLEY AUTHORITY hh.
P. R. Wallace Plant Manager 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 !!arietta Street Washington, DC 20555 (2 copies)
Suite 3100 Atlanta, GA 30323 (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 P. O. Box 10412 Palo_ Alto, CA 94304 (1 copy)
Mr. R. C. Goodspeed MNC 461
' Westinghouse Electric Corporation e P. O. Box 355 Pittsburgh, PA 15230 (1 copy)
?
Y-An Equal Opportunity Employer k.
, , . . . _ _ _ - . . _ _ . _. __