ML18025B036
| ML18025B036 | |
| Person / Time | |
|---|---|
| Site: | Browns Ferry  |
| Issue date: | 08/02/1980 |
| From: | Abercrombie H TENNESSEE VALLEY AUTHORITY |
| To: | |
| Shared Package | |
| ML18025B035 | List: |
| References | |
| NUDOCS 8008180332 | |
| Download: ML18025B036 (76) | |
Text
TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT July 1, 1980 July 31, 1980 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68 Submitted By:
Plant Superintendent go08z 8035&
TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT July 1, 1980 - July 31, 1980 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68 Submitted By:
Plant Superintendent
C 4
TABLE OF CONTENTS Operations Summary . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~
Refueling Information ~ ~ ~ ~ ~ ~
Significant 'Operational Events ~ ~
Average Daily Unit Power Level . ~ ~ ~ ~ ~ ~ ~ ~ 14 Operating Data Reports ~ ~ ~ ~ ~ ~ ~ ~ 17 Unit Shutdowns and Power Reductions. ~ ~ ~ ~ ~ ~ ~ ~ 20 Plant Maintenance ~ ~ ~ ~ ~ t ~ ~ ~ ~
Outage Summary 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 32
I I 0 erations Summar July 1980 The following summary describes the significant operational activities during the reporting period. Tn support of this summary, a chronological log of significant events. is included in this report.
There were sixteen reportable occurrences and three revisions to previous reportable occurrences reported to the NRC duzing the month of July.
Unit 2 There were three scrams on the unit, during the month. On July 22, the reactor scrammed when the main turbine tripped closing the main turbine stop valves. The turbine tripped when water from a fixed spray nozzle (accidently initiated during a surveillance instruction) was sprayed into an open juction box (a modification was in progress and the cover was off) containing turbine trip wires. The reactor was manually scrammed on July 23, in accordance with Special Test 182 which implements the. testing required by NRC I. E. Bulletin 80-17. On July 24, the reactor was scrammed by placing 2 APRMS, one in each trip system in inoperable in accordance with ST 182.
Unit 2 There were four scrams on the unit during the month. On July 17, the reactor scrammed on low water level when the loss of the unit preferred MG set caused a loss on control power and feedpump lock out. The reactor was manually scrammed on July 27, and was scrammed automatically by placing 2 APRMS, one in each trip system in inoperable on July 27, in accordance with ST 182. On July 29, the reactor was manually sczammed to permit maintenance and repair of the short cycle valve in the condensate system.
0 erations Summar (Continued)
July 1980 Un1t 3 There were two scrams on the unit during the month. On July 11, the reactor was manually scrammed in accordance with ST 182. The reactor was scrammed auto-matically on July 12, by placing 2 APRMs, one in each trip system in inoperable in accordance with ST 182.
0 erations Summary .(Continued)
July 1980 Fati ue Usa e Evaluation The cumulative usage factors for the reactor vessel are as follows:
Location Usa e Factor Unit 1 Unit 2 Unit 3 Shell at water line 0.00485 0.00364 '.00308 Feedwater nozzle 0.22993 0.15593 0.11325 Closure studs 0.19498 0.12505 0.09060 Note: This accumulated'onthly information satisfies technical specification section 6.6.A.17.B(3) reporting requirements.
Common S stem Approximately 3.7E+05 gallons of waste liquid were discharged containing approximately 2.74E-01 curies of activity.
Refuelin Information July 1980 Unit 1 Unit 1 is scheduled for its fourth refueling beginning on or about April 15, 1981, with a scheduled restart date of July 25, 1981. This re-fueling will involve loading additional 8 x 8 R (retrofit) fuel assemblies into the core, the final fix on the sparger modification, power supply on LPCI modification, and torus modifications if all approvals are received.
There are 764 fuel assemblies- in the reactor vessel. The spent fuel storage pool presently contains 550 spent 7 x 7 fuel assemblies, five 8 x 8 fuel assemblies,, and one 8 z 8 R fuel assembly. Because of modification work to increase spent fuel pool capacity to 3471 assemblies, present capacity is limited to 1152 assemblies.
Unit 2 Unit 2 is scheduled for its third refueling beginning on or about September 5, 1980, with a scheduled restart. date of October 16, 1980.
Resumption of operation on that date will require a change in technical specifications pertaining to the core thermal limits. Licensing information in support of these changes will be submitted to the NRC before the outage.
This refueling involves replacing some more 7 x 7 fuel assemblies with 8 x 8 R (retrofit) assemblies, and power supply on LPCI modification.
There are 764 fuel assemblies in the reactor vessel. At the end of the month, there were 132 discharged cycle 1 fuel assemblies, 268 discharged cycle 2 fuel assemblies, and 240 new p 8 z 8 R assemblies in the spent fuel storage pool. The present storage capacity of the spent fuel pool is 820 assemblies. With present capacity, the 1979 refueling was the last
Ref uelin Information (Continued)
July 1980 Unit 2 (Continued) refueling that could be discharged to the spent fuel pool without exceeding that capacity and maintaining full core discharge capability in the pool.
However, new high density storage racks are being installed prior to the upcoming third refueling of Unit 2.
Unit 3 Unit -3 is. scheduled for its third refueling beginning on or about October 17, 1980, with a scheduled restart date of November 25, 1980. This EOC-3 refueling, involves loading additional 8 x 8 R (retrofit) assemblies into the core, and power supply on LPCI modification.
There are 764 fuel assemblies presently in the reactor vessel. There
~ are 144 discharged cycle 2 fuel assemblies, 208 discharged cycle 1 fuel assemblies, and 164 new. P 8 x 8 R assemblies in the spent fuel storage pool. The present storage capacity of the spent fuel pool is 1528 assemblies. Qith present capacity, the 1980 refueling would be the last refueling that could be discharged to the spent fuel pool without exceeding that capacity and maintaining full core discharge capability in the pool.
Si nificant 0 erational Events Unit 1 Date Time Event 7/01/80 0001 Reactor thermal power at 99%, maximum flow (Sequence "A")
0700 Reactor thermal power at 98%, EHC vibration limited 7/02/80 0700 Commenced PCIOMR from 98% thermal power 1500 Reactor thermal power at >99% thermal power, steady state 7/05/80 0123 Reduced thermal power from >99% to 80% for turbine C. V.
tests and SI's 0225 Turbine C. V. tests and SI's completed, commenced power ascension.
0335 Reactor thermal power at 90%, holding for problem to be resolved on control rod No. 46>>27 0645 Problems on control rod No. 46-27 cleared, commenced power ascension 0759 Commenced PCIOMR from 96% thermal power 0945 Reactor thermal power at >99%, steady state 7/06/80 1555 Reduced thermal power from >99% to 95% due to high con-denser back pressure 1950 Commenced power ascension from 95% thermal power 0700 Reactor thermal power at >99%, steady state '/07/80 0844 Reduced thermal power from >99X to 98% due to loss of "B" string high pressure heaters (high level) 0855 "B" string high pressure heaters placed in service, com-menced power ascension 0905 Reactor thermal power at >99X, steady state 1105 Reduced thermal power from >99X to 95X due to condenser high back pressure 7/08/80 0203 Reduced thermal power from 95% to 90X for backwash and precoat condensate demineralizers (no spare available) 0440 Condensate demineralizers backwash and precoat completed, commenced power ascension 1530 Reduced thermal power from 97% to 95X due to condenser high back pressure 1810 Reduced thermal power from 95% to 78% for removal of "A" condenser circulating pump from service to keep condenser back pressure belo~ 4.0" of mercury 7/09/80 0430 Commenced power ascension from 78% thermal power 0600 Commenced PCIOMR from 85% thermal power 1539 Reduced thermal power from 92% to 75% due to high river temperature 2050 Commenced power ascension from 75% thermal power
Si nificant 0 erational Events Unit 1 Date Time Event 7/10/80 0230 Commenced PCIOMR from 80% thermal power 1330 Reactor thermal power at 90%, holding to place unit on cooling towers due to river high temperature 1450 Unit on cooling towers resumed PCIOMR 1620 Reduced thermal power from 92% to 82% due to condenser high back pressure 7/11/80 0100 Commenced PCIOMR from 82% thermal power 1328 Reduced thermal power from 90% to 86% due to condenser high back pressure 2247 Reduced thermal power from 86X to 84% due to condenser high back pressure 7/12/80 0240 Reduced thermal power from 84X to 80% for turbine C. V. tests and SI's 0425 Turbine C. V. tests and SI's completed, holding due to condenser high back pressure 7/13/80 1708 Reduced thermal power from 80% to 65% for control rod pattern adjustment 1945 Control rod pattern adjustment completed, commenced power ascension 7/14/80 1930 Reactor thermal power at 82%, holding due to condenser high back pressure 7/15/80 1100 Commenced PCIOMR from 82% thermal power 7/16/80 1500 Reactor thermal power at 96%, holding due to condenser high back pressure.
7/17/80 0515 Commenced power ascension from 96X thermal power 1500 Reactor thermal power at 98%, limited by condenser high back pressure 7/18/80 1520 Commenced reducing thermal power due to river high temperature 1715 Reactor thermal power at 45%, holding due to river high temperature 1848 Commenced control rod exchange from "A" to "B" 2025 Control rod exchange completed, holding at 45% for. river high temperature 7/19/80 1402 Commenced power ascension from 45% thermal power 7/20/80 1630 Commenced PCIOMR from 63% thermal power
Si ificant 0 erational Events Unit 1 Date Time Event 7/22/80 1500 Reactor therm~/ power at 99%, maximum flow 2108 Reactor Scram No. 132 from 99% thermal power (FP water spray into open junction box) 7/23/80 0636 Commenced rod withdrawal 1035 Reactor Critical No. 153 sequence "B" 1443 Reactor Scram No. 133 manual from 5% thermal power to comply with NRC I. E. Bulletin 80-17 2130 Commenced rod withdrawal 2346 Reactor Critical No. 154 sequence "B" 7/24/80 0228 Reactor Scram No. 134 automatic from 5% thermal power to comply with NRC I. E. Bulletin 80-17 0442 Commenced rod vithdraval 0620 Reactor Critical No. 155 sequence "B" 0835 Rolled T/G 0854 Synchronized generator, commenced power ascension 7/25/80 0030 Commenced PCIOMR from 71% thermal power 7/26/80 0100 Reactor thermal power at 95%, maximum flov 7/27/80 2328 Commenced power ascension by withdrawing control rods 7/28/80 0700 Reactor thermal power 98%, maximum flow 7/30/80 1500 Reactor thermal power at 98%, maximum flow 7/31/80 0146 Reduced thermal power from 98% to 85% for removal of Al and A2 water boxes from service for flushing 0550 Flushing both water boxes completed, commenced power ascension 0700 Reactor thermal power at 98%, maximum flov 2400 Reactor: thermal power at 98%, nmcimum flow
Si nificant 0 erational Events Unit 2 Date Time Event 7/01/80 0001 Reactor thermal power at 97%, maximum flow, (sequence "B")
0700 Reactor thermal power at 94%, maximum flow 7/03/80 2125 Reduced thermal power from 94% to 65% for control rod pattern adjustment 7/04/80 0200 Control rod pattern adjustment completed, commenced power ascension from 65% thermal power 1500 Reactor thermal power at 81%, CPR limited 7/05/80 0040 Reduced thermal power from 81% to 75% for turbine C. V."
tests and SI's 0130 Turbine C. V. tests and SI's completed, commenced PCIOMR from 75X thermal power 7/06/80 0150 Reduced thermal power from 97% to 94% for SI 4.3.A-2 (control rod exercise) 0300 SI 4.3.A-Z completed, commenced PCIOMR from 94% thermal power 0700 Reactor thermal power at 98%, maximum flow 7/08/80 1616 Reduced thermal power from 98% to 90% due to condenser high back pressure 7/09/80 0425 Commenced power ascension from 90% thermal power 0600 Commenced PCIOMR from 95% thermal power 2300 Reactor'hermal power at 99%, maximum flow 7/10/80 1633 Reduced thermal power from 99X to 93X for cooling tower operation 7/11/80 0630 Commenced PCIOMR from 93X thermal power 7/12/80 1400 Reduced thermal power from 95X to 90% due to condenser high back pressure 1630 Reduced thermal power from 90% to 80X due to high river temperature 2315 Reduced thermal power from 80% to 70% due to high river temperature 7/13/80 0810 Commenced power ascension from 70% thermal power 1500 Reactor thermal power at 90%, holding due to condenser high back pressure 7/14/80 0330 Commenced PCIOMR from 90% thermal power 1005 Reduced thermal power from 94% to 74% due to condenser high back pressure
10 Si nificant 0 erational Events Unit 2 Date Time Event 7/15/80 1055 Commenced power ascension from 74% thermal power 1445 Commenced PCIOMR from 83% thermal power 7/16/80 0630 Reactor thermal power at 99%, maximum flow 1420 Reduced thermal power from 99% to 93% due to main transformer high temperature 2030 Reduced thermal power from 93% to 84% due to condenser high back pressure 7/17/80 0030 Commenced power ascension from 84% thermal pover 0150 Commenced PCIOMR from 90% thermal power 0700 Reactor the~$ ~power at 96%, maximum flov 0907 Reactor Scram No. 104 from 95% thermal power on low reactor level (loss of unit preferred MG Set) 1202 Commenced rod withdrawal for startup 1420 Reactor Critical No. 115 sequence "B" 1626 Rolled T/G 1645 Synchronized. generator, commenced power ascension 7/18/80 0430 Commenced PCIOMR from 76% thermal pover 2300 Reactor thermal power at 95%, holding due to con>>
denser high back pressure 7/19/80 2300 Reduced thermal power from 95% to 90% due to con-denser high back pressure 7/20/80 0650 Commenced PCIOMR from 90% thermal power 7/21/80 0700 Reactor thermal power at 95X, ~num flow 7/26/80 2130 Commenced reducing thermal power from 95X for a manual scram to comply with NRC I. E. Bulletin 80-17 7/27/80 0201 Reactor. Scram No. 105 from 44X thermal power to comply with NRC I. E. Bulletin 80-17 0635 Commenced, rod withdrawal 1115 Reactor Critical No. 116 sequence,"B" 1358 Reactor Scram No.. 106, automatic, from 5% thermal power to comply with NRC I. E. Bulletin 80-17 2245 Commenced rod withdrawal 7/28/80 0103 Reactor Critical No. 117 sequence "B" 0530 Rolled T/G 0604 Synchronized generator, commenced power ascension
Si nificant 0 erational Events Unit 2 Date Time Event 7/28/80 2200 Reactor thermal power at 37%, holding due to problems
'ith condensate short cycle valves (FCV 2-29 isolation valve would not close) 2339 Reactor Scram No. 107, manual, from 37% thermal power for condensate short cycle valve maintenance 7/29/80 0600 Reactor at cold shutdown for maintenance to short cycle valves 7/30/80 2243 Commenced rod withdrawal for startup 7/31/80 0250 Holding reactor startup due to water quality 0600 Reactor Critical No. 117 sequence "B" 1550 Rolled T/G 1628 Synchronized generator; commenced power ascension 2400 Reactor thermal power at 45%, with power ascension in progress
12 Si nificant Onerational Events Unit 3 Date Time Event 7/01/80 0001 Unit at cold shutdown for maintenance 7/10/80 0325 Commenced rod withdrawal for startup 0435 Reactor Critical No. 95 sequence "B" 1655 Reactor thermal power at 5X, holding at 2 bypass valve capacity 7/11/80 1211 Reactor Scram No. 86, manual, from 5% thermal power to comply with NRC I. E. Bulletin 80-17 2200 Commenced rod withdrawal 2347 Reactor Critical No. 96 sequence "B" 7/12/80 0901 Reactor Scram No. 87, automatic, from 5% thermal power to comply with NRC I. E. Bulletin 80-17 1655 Commenced rod withdrawal 1825 Reactor Critical No. 97 sequence "B" 7/13/80 1855 Rolled T/G 1940 Synchronized generator, commenced power ascension 7/14/80 0930 Reactor thermal power at 47%, holding due to RCIC being inoperable 1405 RCIC made operable, holding for SI's 1855 Reactor thermal power at 47X, holding for "D" RHR pump being inoperable 7/15/80 0030 "D" RHR pump made operable, commenced power ascension from 47X thermal power 1141 Commenced PCIOMR from 68% thermal power 7/16/80 1435 Reduced thermal power from 86% to 76X due to main steam line high temperature alarm 2120 Commenced reducing thermal power to investigate half isolation received on main steam tunnel high temperature (temperature switch 1-54B) 2207 Reactor thermal power at 40%, holding for replac'ement of temperature switch 1-54B 2350 Temperature switch 3.-54B replacement completed, commenced power ascension 7/17/80 0250 Reactor thermal power at 60%, holding due to river high temperature 0818 Commenced power ascension from 60% thermal power 0930 Commenced PCIOMR from 82% thermal power 2100 Commenced reducing thermal power from 88% to 40% for replacement of temperature sensor in moisture separator room
13 Si nificant 0 erational Events Unit 3 Date Event 7/18/80 0100 Commenced power ascension 0500 Commenced PCIOMR from 82% thermal power 1300 Reduced thermal power from 94% to 90%'ue to main steam line low pressure (A-1) 1603 Reduced thermal power from 90% to 46% due to river high
, temperature 2045 Commenced power ascension 7/19/80 0405 . Reactor thermal power at 85%, holding for turbine C. V.
tests and SI's 0500 Turbine C. V. tests and SI's completed, commenced PCIOMR 7/20/80 0500 Reduced thermal power from 96% to 77% for removal of "A" reactor feed pumps from service for maintenance (leak)
. 1751 "A" reactor feedpump maintenance completed and pump placed in service, commenced power ascension 1900 Commenced PCIOMR from 83% thermal power 7/21/80- 1500 Reactor thermal power at 97%, maximum flow 7/26/80 2345 Reduced thermal power from 97% to 85% for turbine C. V.
tests and SI's 7/27./80 0038 Turbine C. V. tests and SI's completed, commenced power ascension 0700 Reactor thermal, power at 95%, maximum flow 7/30/80 1500 Reactor thermal power at 94%, maximum flow 7/31/80 2400 Reactor thermal power at 94%, maximum flow (1) Maintenance error (2) Equipment mal function
>> ~
14 AVERAGE DAlLYUNIT POWER LEVEL DOCKET NO.
ATE 8-2-80 COMPLETED BY Ted Thottt TELEPHONE 205 729 6846 MON'M July 1980 DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAILYPOWER LEVEL (MWe-iVet ) (iMWe.Net) 986'7 1048 827 19 511 20 623 5 1032 843 1002 22 893 1003 23 -13 937 '74 359 772 25 899 10 850 26 955 853 27 962 ~
12 800 28 1018 13 798 29 993 30 994 15 868 31 990 16 989 INSTRUCTIONS On this format.!ist the average daily unit power level in Mme.Net for each day in the reporting iniinth. Ciimp\ite lo the nearest whole megawatt.
(')/771
~ V~
+V
15 AVERAGE DAILYUNIT POWER LEVEL DOCKET NO.
Browns 'Ferry -2 DATE 8-2-80 COMPLETED BY Ted Thorn MONTH July 1980 DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAILYPOWER LEVEL (MWe.Net) (MWe-Net I I 1002 17 492 999 18 3":.. 956 19 945 785 20 929 946 21 973
~ 6- 1005 22 998 1026 990
-8 990 24 991
~
-10
-9:- 989 1015 954 31'30 25 26 1016 907 18 27 12 913 28 218 13 898 29 -10 14 804 30 IS 827, 98 16 971 INSTRUCTIONS On this fortnat,!1st the average daily unit power Ieiel in Mac.Net for <<ach'day in the reporting tnonth. Cotnputl. lu the nearest whole megawatt:
I'>/77 I
16 AVERAGE DAlLYUiVIT POWER LEVEL Browns Ferry 3 DATE 8-'2-80 COMPLETED BY TELEPHONE 205 729 6846 MONTH July 1980 DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAlLYPOWER LEVEL (MWe-Net) (MWe.iVet)
I
-11 l7 711
-10 IS 809
-10 19 949
-10 20 876 21 1037 22 1030 23 1025 1023 25 1042 Ip -10 26 986
~
II 27 1000 28 1003 l3 29 462 30- 986 IS 668 988 31 832 hVSTRUCTIONS On this format.!ist the average daily unit power level in iv(IVe Net for each day in thc reporting tmmth. Ciiinputc to the nearest whole rnegawat t.
(9/77) l r
r ~ ~
17 OPERATING DATA REPORT DOCKET NO.
DATE
.COilIPLETED BY TEI.FpHONE
~~
~Graeu 205 729 6846 OPERA'flNG STATUS Browns Perry Unit 1 Notes
. Reportinu Period:
- 3. Licensed Thermal Power (MWt): 3293'.
iVamepiate Rating (Gross i'>Ve):
- 5. Design Electrical Rating (Net MWe):
- 6. Maximum Dependable Capacity (Gross ilIIVe): 1098.4
- 7. IIaximum De p endable Ca p acit y(Net 4~IWe: 1065
)
- 8. IfChanges Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons:
N A
- 9. Power Level To Which Restricted, If Any (Net MWe): N/A IO. Reasons For Restrictions, If Any This Month Yr.-to Date Cumuhtive I I. Hours In Reporting Period 744 52,609
- 12. Number Of Hours Reactor Was Critical 717.63 2,909.13 31,186.41
- 13. Reactor Reserve Shutdown Hours 12. 39 '356.42 57046.03
- 14. Hours Generator On-Line 708. 23 2780.43 30 393.16
- 15. Unit Reserve Shutdown Hours 0 0 0
- 16. Gross Thermal Energy Generated (MWH) 2,101,344 7,892,806 82,029,299 l7. Gross Electrical Energy Generated (ibIWH) 661 940 2 531 200 27 049 660
- 18. Net Electrical Energy Generated (MWH) 639 591 2,452,337 26,254,305 l9. Unit Service Factor 95.2 54.4 57.8
- 20. Unit Availability Factor 95.2 54.4 57.
- 21. Unit Capacity. Factor (Using MDC Net) 80.7 45.1 46.9
- 22. Unit Capacity Factor (Using DER Net) 80.7 45.1 46.9 23; Unit Forced Outage Rate 4.8 13.7 31.6
- 24. Shutdowns Scheduled Over Next 6 Months (Type. Date. and Duration of Each):
- 25. If Shut Down At End Of Report Period. Estimated Date of Startup:
- 26. Units In Test Status (Prior to Commercial Opemtion): Forecast Achieved INITIALCRITICALITY INITIALELECTRICITY COMM ERCI A L OPERATION
OPERATING DATA REPORT DATE ~K DOCKET YO 50-260 COMPLETED BY 2/cuLZireen TELEPHONE 225 '~846 OPERATliVG STATUS Browns Ferr Unit 2 Notes
- l. Unit 1Vame:
93
- 3. Licensed Thermal Power (MWt):
- 4. 1Vameplate Rating (Gross MWe):
>. Design Electncal Ratmg (iVet MWe).
- 6. Maximum Dependable Capacity (Gross MWe): 1098 4 7 l avimum De endable Ca p acit y(Net a(We )
4
- 8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report. Give Reasons:
N/A
- 9. Power Level To Which Restricted, If Any (Net 5IWe): N/A
- 10. Reasons For Restrictions, If Any This 49(onth Yr.-to-Date Cumulative
- 11. Hours In Reporting Period 744 5 111 47 520
- 12. Number Of Hours Reactor Was Critical 664.12 4,452.10 28,936.58
- 13. Reactor Reserve Shutdown Hours 59.15 63
- 14. Hours Generator Oh Line 643.50 4 322.59 27 986.90
- 15. Unit Reserve Shutdown Hours 0 0 0
- 16. Gross Thermal Energy Generated (MWH) 1 858 754 12 416 629 78 571 629 17; Gross Electrical Energy Generated (MWH) 606 890 4 128 890 26 078 958
- 18. 1Vet Electrical Energy Generated (MWH) 586,379 ',013,311 25,344,780
- 19. Unit Service Factor 86.5 84.6 58.9
- 20. Unit Availability Factor 86.5 84.6 58..9
- 21. Unit Capacity Factor (Using MDC Net) 74.0 73.7 50.1
- 22. Unit Capacity Factor (Using DER Net) 73. 7'4.0 50.1
- 23. Unit Forced Outage Rate 13.5 14.0 34.1
- 24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):
Refuel outage September 1980
- 25. If Shut Down At End Of Report Period, Estimated Date of Startup:
- 26. Units ln Test Status (Prior to Commercial Operation): Forecast Achieved IN ITI A L CR ITICALITY INITIAL ELECTRICITY COMMERCIAL OPERATION (o/7 7)
19 OPERATING DATA REPORT DOCKET NO. 50 296 04T8 ~3-COMPLETED BY AarLZizean TELF.PHONE ~Z29 6846 OPERATIi'4 G STATUS Browns Ferry Unit 3 i lotes
- 3. Licensed Thermal Power (MWt):
- 4. Nameplate Rating (Gross MWe):
- 5. Design Electrical Rating (Net MWe):
- 7. ~Iaxinium De p endable Ca p acit y(Net MWe: ) 1065
- 8. IfChances Occur in Capacity Ratings (Items ilumber 3 Through 7) Since Last Report. Give Reasons:
N/A
- 9. Power Level To Which. Restricted, If Any (Net ilIWe)t N A
- 10. Reasons For Restrictions, If Any:
This illonth Yr..to.Date Cumulative
- 11. Hours In Reporting Period 744 5111 29,975
- 12. 4Vumber Of Hours Reactor Was Critical 502. 42 4356.22 23,263.77
- 13. Reactor Reserve Shutdown Hours 101.63 1 759.94
- 14. Hours Generator On. Line 436.33 4259.13 22696.94
- 15. Unit Reserve Shutdown Hours 0 0 0
- 16. Gross Thermal Energy Generated (MWH) 1,227,122 13,164,883 66,272,749
- 17. Gross Electrical Energy Generated (MWH) 408 950 4 437 980 21,840,560
- 18. Net Electrical Energy Generated (MWH) 391, 806 4 4,319,383 21,207,156
- 19. Unit Service Factor 58.6 83.3 75.7
- 20. Unit Availability Factor 58.6 83.3 75.7
- 21. Unit Capacity Factor (Using 4%IDC Net) 49.4 79.4 66.4
- 22. Unit Capacity Factor (Using DER Net) 49.4 79.4 66.4 41.4 16.7 '10. 6
- 23. Unit Forced Outage Rate
- 24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):
Refuel outage October 1980
- 25. IfShut l)own At End Of Report Period. Estimated Date of Startup:
- 26. Units ln Test Status (Prior to Commercial Operation): Forecast Achieved IN ITIAL CRITICALITY INITIALELECTRICITY COMMERCIAL OPERATION
()OCKET NO. 50-259 UNIT SIIUTI)OWNS AND POWER REI)UCTIONS UNIT NAhlE l)ATE COhIPLETEI) ItY REPORT MON'fll TELEPI !ONE C rr Cl
~c Cause.r<. ('>>rrcclivc
'0 ~ a Lice>>sec o Ihtc l Vl tl g cc Event Action lo V
Report ~
E ~ Prevc>>l Rec>>rrc>>ce d ~ Ch O 135 800705 B Derated for turbine control valve test and SX's.
136 800718 H Derated due to high river AT 137 800722 17.58 EHC system failure (turbine controls) 138 800723 11,75- Rx manual scram to test control rods er NRC Bulletin 80-17.
139 800724 6.44 Rx automatic scram to test control rods per NRC Bulletin 80-17.
I F: Forced Reason: hI ethod: Exhibit G - Instr>>ctions S: Scheduled A.Equipment Failure (Explain) I hlaIIual fi)r Preparation ot Data 8 hlaintenance or Test 2.hlanual Scram. Entry Sheets I'or I.icc>>sce C.Refueling 3-Auto>>latic Scraln. Event Report (I.ER) File (NUREG-I) Regulatory Restriction 4'Other (Explanl) 016I )
L'.Operator Training 8; Liccnsc Exanlilmtion F.Administrative G.Operational Error (Fxplain) Exhlbll I ~
Sal>>c Source I I Other (Explalrl )
UNIT SIIUTDOWNS AND POWER REl)UCTIONS UNIT NAhIE COh(PLETED BY ~~@eau 205 729 6846 TELEPIIONE CI J 4J NII.'ale Vl r)
J Liccnscc Evcnl 0
C tJ Cause &, CI)rrcctivc Acth)n lo Rcporl 4F Prevent Rccufrcncc
~ CA O
145 800703 H Derated for control rod pattern ad) ustment 146 800712 Derated due to high. river i))T 147 800714 Derated due to condenser high back ressure 148 800717 F 7.63 Low reactor water level due to loss of unit preferred MG set (over voltage rela malfunction 149 800727 F ll.95 Reactor manual scram to test control rods er NRC Bulletin 80-17.
150 "800727 F 16,10 D Reactor automatic scram to test con-trol rods er NRC Bulletin 80-17.
151 800728 F 64.82 Failure of condensate short cycle valves.
I F: Forced Reason: h(ethod: Exhibit G - Instructions
, S: Scheduled A.Equiptnent Failure (Explain) I -hlanual for Pr cpa ra ti ) I) ) f Data 8-hlaintcnance or Test 2-Manual Scram. Entry Sheets lor l.icenscc C Rcfucling 3-Auloo)atic Sera)n. Event Rcport (I.I'.lt) File (NUREG.
D Regulatory Restriclion 4-Other (Explain) OI61)
I'.-Operator Training & Liccnsc Exalni>>ation F.Administrative G.Opcrallonal Error (Explain) Fxhiblt I ~
Sa)nc SI)urcc I I Other (Explain)
DOCKET NO. 50-296 UNIT SIIUTDOWNS AND POWER REDUCTIONS UN(i NAhtE DATE COMPLETED IN REPORT INONTII ~>~T TELEPIIONE PP I
rE MI LIccnscc S Cause %. ('orrcctivc 4I 4l Dale vl Event IA Q CI Aclhln I o PE I
o4 ~ ce Rcport Ir IPI G C o Prevent Rccul'fcucc
~ V) Cr 132 800701 5.50 A Maintenance to feedwater PiPing continued. Reactor shutdown in June 133 800701 246;68 D Investigation and testing of control rods and scram discharge volume due t problems inserting rods on Scram No. 85. Reactor was shutdown in Junr 134 800711 20. 84 D Reactor manual scram to test control rods er NRC Bulletin 80-17.-
135 800712 34.65 D Reactor automatic scram to test con-trol rods er NRC Bulletin 80-17.
136 800716 A Derated due to main steam tunnel high tern erature tern erature switch 1-54B 137 800717 Derated to replace temperature senser.
in moisture se erator room.
138 800718 H Derated due to high river AT.
3 4
. F: Forced Reason: hfethod: Exhibit G ~ Instr<<>>tions S: Schctlulcd A.Equiptnent Failure (Explain) I -h(anual I'or Prep'Iralh)n of Data 8 h)alit tcnance or Test 2.h(anual Scram. I:<<try Shc>>ts tor l.i>>c<>>>
C.Rcfuclinti 3 Auto<<1'IIIC Sera<<l. Lv>><<t ltcpor I (I.I!R) I'il>> (NUREG-D Regulatory Restriction I-Ot Itcr ( explain) Ol 6 I )
I'.-Operator Trainhtt; 8; Liccnsc Examination F-Ad<<<<sist rat Ivc G Operational Error ((explain) Exhibit I - Sat<<>> So<>>>
(I)/77) I I.Other (Explain)
BRONNB PERRY NUCLEAR PLANT UNXT 1 MECHANICAL MAINTENANCE SUMIIARY For tl>e Month of JulV 19 8O EFFECT ON SAFE ACTION TAKEN OPERATION OF CAUSE OF RESULTS OF TO PRECLUDE SYS TIKI COMPONENT NATURE OF THE REACTOR MALFUNCTION MALFUNCTION RECURRENCE MAINTENANCE 7/23/8 11igh press Valve 1-26-73B Valve not None Mussel .shells Leaking valve Disassembled, cleaned fire prote- seating off under seat and and replaced tion ilot line lu TR 180537 7/19/8 Reactor FCV-64-139 Valve would None Hole in diaphrag i Stuck valve Replaced diaphragm Building not open TR 137666 Ventilatio 7/8/80 HPCI PCV'73-43 Valve stuck None Stem guide bush- ':alve stuck in closed Replaced diaphrag in closed ing was screwed P s t cleaned inside of position out of place valve. Tightened stem TR 153423 bushing
HEG1ANICAL MALITENANCE
SUMMARY
a9~
CSSC EQUIPHENT For the tfonth of EFFECT ON SAFE ACTlON TX)'EN .
DATE SYSTEH CO<~1PONENT NATURE OF - OPERATION OF CAUSE OF RESULTS OF TO PRECLUDE MAINTENANCE THE REACTOR 11ALFUNCTION MALFUNCTION RECURRENCE 7/14/8 Fuel Pool Pump 213 Seal leaking None Drains stopped rains stopped up and Unstopped drains and Cooling 6 drain clogg d up and packing packing leak ad)usted packing leak TR 170762
MECHANICAL MAINTENANCE SUMifARY EFFECT ON SAFE ACTION TAi'EN DA.TE SYSTEM COMPONENT NATURE OF OPERATION OF CAUSE OF RESULTS OF TO PRECLUDE MAINTENANCE TilE REACTOR MALFUNCTION MALFUNCTION RECURRENCE 7/9/80 CRD FCV-85-37A Bent poppet None Bent stem Bent stem Removed valve and stem and repaired stem TR 103306 7/5/80 EECW P.CV 67-79 Strainer None Strainer stopped Render 3B control bay Cleaned s t ra iner sto ed u u chiller )no erable TR 174755 0
BROWNS FERRY NUCLEAR PLANT UNIT Common CSSC E UIPMENT MECIIANICAL MAINTENANCE SUGARY For the Month of . July 19 80 EFFECT ON SP2'E ACTION TAKEN DATE SYS'lZII COM POHEHT NATURE OF OPERATION OF CAUSE OF RESULTS OF TO PRECLUDE MAINTENANCE THE REACTOR MALFUNCTION MALFUNCTION RECURPZNCE 7/22/80 RHR Pump Al Packing leak None Packing leak Packing leakoff needs Replaced packing leak-replacing off tubing TR l37669
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UPOlPitS PP1U<Y HUCXMA11 PXhUT UliXT ELECTRICAL MAINTENANCE SQ!HARX E ect on a e I Action Taken Date System , Component Nature of Operation of Cause of Results:of To Preclude Haintenance The Reactor Halfunction Halfunction Recurrence 7/7/80 Control 3A shutdown 3A shutdown Hotor burned Bad Bearing ~
Replaced motor and bay board room board room up, bearing overload heater." .
heating exhaust fan exhaust fan worn out, over- Checked rotation in vent and 'otor bad, load heater both speeds. Checked air con- burned out ok. TR8 180699 ditioning 7/14/8 Hain Check limit Check limit NONE Limit switch Broken limit switch Replaced switch steam switches on switches for broken on MSIV 83. Checked all (stop stop valve. proper op- MSIV 83, switches also. All valve) eration. switches presently
- working properly.
- Check ok. TR8174761 I
7/14/80 HPCI Pos. lights Pos lights NONE Switch out of Ad)usted limit 'Ad)usted limit switch on valve on valve in- ad)ustment. switch. to get proper lights, indicating icating valve Check ok TRiI16S610 valve open open when P valve is def-l initely closed.
I nu(SO RCIC FCV-3-71-34 FCV-3-71-34 NONE Torque switch Torque switch 'Cleaned torque tcb
)
vill not contact was prevented valve 'Contact valve now close dirty. closing, operates correctly.
~ X TR8 174766 BFR0-50-.
.256/8026 7/28/80 Neutron Bad APRH Honitoring switch Bad APRH
.switch
.. NONE Bad switch Switch out of ad)ustment
'hanged switch.
witch works properly, heck ok. TRI'/170399
BROlhrHS PEiUVE HUCLHAll PLAHT UNIT E> ECTRICAI HAIHTEHAHCE SlMfARY Por the Honth of ~uly 19 L ecton 'a e Action laken Hature of Operation of Cause of Results of To Preclude Date System Component
~hia 1 func t ion Haintenance The Reactor Malfunction Recurrence 7/31/80 Fire Zone heat Zone sensing HONE Broken heat Heat det'ector was Replaced heat Protection'detector element in detector. Ther operable inspite SI 4.11.C detecto)'erformed 1
cable tray is was no alarm in of being cut.
~
and 5 and SI 4.11 C 3 open. Replace for the detec- and 4. Pire watch element TE 39-101. Col TRI4 tor. Detector broken. into was established making repairs.
~e
~ck I
Elevation 565 makipg two ok. TR8 148256 unit 3 RX bldg detectors.
BROUUB FERRY EUCLR&R PLANT UULT 1 2 & 3 INSTRUMENT MAINTEHANCE StBMRY CSSC E UIPHEHT NATURE EFFECT ON SAFE CAUSE ACTION TAKEN SYSTEM COMPONEHT OF OPERATION OF OF RESULTS OP TO PRECLUDE DATE MAINTENANCE THE REACTOR MALPUNCTION MALFUNCTION RECURRENCE Unit 7-16 Radwaste RM-77-6 Calibrate None In'strument Drift Indicated Plow with None Pump Of f Unit 2 7-15 Primary PdI-64-137 Calibrate None Instrument Drift Disagreement Between None Containment PdI-64-138 Redundant Indicators PdT-64-138 Unit 7-31 Of f-Gas FIS-66-33A Calibrate None Instrument Drift Flow Alarm Mould None FIS-66-33B Replace None Bad Photo Cell Not Reset Hone
I 32 OUTAGE
SUMMARY
July 1980 Major work for the outage group during the month consisted of continuing modifications to the plant. Security modification work is 99 percent com-plete in preparation for the August 15, commitment date. The E- Field checkout and modification is underway after a vendor representative was on-site to review some of the recurring problems.
Emphasis was also placed upon inspections of the CRD water lines and the scram volume discharge tank for Unit 3 reactor after scram problems were encountered. Investigations continue.
The last shipment of fuel for the upcoming outage was received July 20, 1980, and processing completed by July 25.
Meetings were held to shorten duration on some modifications scheduled during the Unit 2 refueling outage. The generator breaker modification was reviewed in depth to schedule the work in 49 days. Several contingency plans for the Unit 2 outage were also issued to reflect jobs that could impact the critical path" schedule and extend the overall refueling outage duration.
Other outage work consisted of: the repair of the condensate short cycle valves which forced Unit 2 to shutdown. The modifications to the hypochlorite building, the condensate storage tanks, the low level rad-waste facilities-,. construction of a new east portal/medical station, construction of the outage fabrication shop and piping and hanger in-spections per the NRC Bulletin 79-02 and 79-14.
I TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT July 1, 1980 July 31, 1980 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68 Submitted By 'f ) dJ ( r(
Plant Superintendent
~ \ ~
0 TABLE OF CONTENTS Operations Summary 0 0 ~ ~ ~ ~ ~ ~ ~
Refueling Xnformation Significant Operational Events Average Daily Unit Power Level . 14 Operating Data Repor ts 17 Unit Shutdowns and Power Reductions. 20 Plant Mintenance 23 Outage Summary 32
0 erations Summar July 1980 The foll'owing summary describes the significant opexational activities during the reporting period. In support of this summary, a chronological log of significant events is included in this report.
There were sixteen reportable occurrences and three revisions to previous reportable occurrences reported to the NRC during the month of July.
Unit 1 There were three scrams on the unit during the month. On July 22, the reactor scrammed when the main turbine tripped closing the main turbine stop valves. The turbine tripped when water from a fixed spray nozzle (accidently initiated during a surveillance instruction) was sprayed into an open guction box (a modification was in progress and the cover was off) containing turbine trip wires. The xeactor was manually scrammed on July 23, in accordance with Special Test 182 which implements the testing required by NRC I. E. Bulletin 80-17. On July 24, the reactor was scrammed by placing 2 APRMS, one in each trip system in inoperable, in accordance with ST 182.
Unit 2 There were four scrams on the unit duxing the month. On July 17, the xeactor scrammed on low watex level when the loss of the unit preferred MG set caused a loss on control power and feedpump lock out. The reactor was manually scrammed on July 27, and was scrammed automatically by placing 2 APRMS, one in each trip system in inoperable on July 27, in accordance with ST 182. On July 29, the reactor was manually scrammed to permit maintenance and repair of the short cycle valve in the condensate system.
0 erations Summar (Continued)
July 1980 Unit 3 There were two scrams on the unit during the month. On July 11, the reactor was manually scrammed in accordance with ST 182. The reactor was scrammed auto-matically on July 12, by placing 2 APRMs, one in each trip system in inoperable in accordance with ST 182.
0 erations Summar (Continued)
July 1980 Fati ue Usa e Evaluation The cumulative usage factors for the reactor vessel are as follows:
Location Usa e Factor Unit 2 Unit 2 Unit 3
'Shell at water line 0.00485 0.00364 0.00308 Feedwater nozzle 0.22993 0.15593 0.11325 Closure studs 0.19498 0.12505 0.09060 Note: This accumulated monthly information satisfies technical specification section 6.6.A.17.B(3) reporting requirements.
Common S stem Approximately 3.7E+05 gallons of waste liquid were discharged containing approximately 2.74E-01 curies of activity.
Refuelin Information July 1980 Unit 1 Unit 1 is scheduled for its fourth refueling beginning on or about April 15, 1981, with a scheduled restart date of July 25, 1981. This re-fueling will involve loading additional 8 x 8 R (retrofit) fuel assemblies into the core, the final fix on the sparger modification, power supply on LPCI modification, and torus modifications if all approvals are received.
There are 764 fuel assemblies in the reactor vessel. The spent fuel storage pool presently contains 550 spent 7 x 7 fuel assemblies, five 8 x 8 fuel assemblies, and one 8 x 8 R fuel assembly. Because of modification work to increase spent fuel pool capacity to 347'1 assemblies, present capacity is limited to 1152 assemblies.
Unit 2 Unit, 2 is scheduled for its third refueling beginning on or about September 5, 1980, with a scheduled restart date of October 16, 1980.,
Resumption of operation on that date will require a change in technical specifications pertaining to the core thermal limits. Licensing information in support of these changes will be submitted to the NRC before the outage..
This refueling involves replacing some more 7 x 7 fuel assemblies with 8 x 8 R (retrofit) assemblies, and power supply on LPCI modification.
There are 764 fuel assemblies in the reactor vessel. At the end of the month, there were 132 discharged cycle 1 fuel assemblies, 268 discharged cycle 2 fuel assemblies, and 240 new p 8 'x 8 R assemblies in the spent fuel storage pool. The present storage capacity of the spent fuel pool is 820 assemblies. With present capacity, the 1979 refueling was the last
Refuelin Information (Continued)
July 1980 Unit 2 (Continued) refueling that could be discharged to the spent fuel pool without exceeding that capacity and maintaining full coze discharge c'apability in the pool.
However, new high density storage racks are being installed prior to the upcoming third refueling of Unit 2.
Unit 3 Unit 3 is scheduled for its third refueling beginning on or about October 17, 1980, with a scheduled restart date of November 25, 1980. This EOC-3 refueling, involves loading additional 8 x 8 R (retrofit) assemblies into the core, and power supply on, LPCI modification.
There are 764 fuel assemblies presently in the reactor vessel. Ther'e are 144 discharged cycle 2 fuel assemblies, 208 discharged cycle 1 fuel assemblies, and 164 new P 8 x 8 R assemblies in the spent fuel storage pool. The present storage capacity of the spent fuel pool is 1528 assemblies. With present capacity,, the 1980 refueling would be the last refueling that could be discharged to the spent fuel pool without exceeding that capacity and maintaining full core discharge capability in the pool.
Si nificant Operational Events Unit 1 Date Time Event 7/01/80 0001 Reactor thermal power at 99%, maximum flow (Sequence "A")
0700 Reactor thermal power at 98%, EHC vibration limited 7/02/80 0700 Commenced PCIOMR from 98% thermal power 1500 Reactor thermal power at >99% thermal power, steady state 7/05/80 0123 Reduced thermal power from >99% to 80% for turbine C. V.
tests and SI's 0225 Turbine C. V. tests and SI's completed, commenced power ascension.
0335 Reactor thermal power at 90%, holding for problem to be resolved on control rod No. 46-27 0645 Problems, on control rod No. 46-27 cleared, commenced power ascension 0759 Commenced PCIOMR from 96% thermal power 0945 Reactor thermal power at >99%, steady state 7/06/80 1555 Reduced thermal power from >99X to 95% due to high con-denser back pressure 1950 Commenced power ascension from 95% thermal power 7/07/80 0700 Reactor thermal power at >99X, steady state 0844 Reduced thermal power from >99% to 98% due to loss of "B" string high pressure heaters (high level) 0855 "B"- string high pressure heaters placed in service, com-menced power ascension 0905 Reactor thermal power at >99%, steady state 1105 Reduced thermal power from >99X to 95% due to condenser high back pressure 7/08/80 0203 Reduced thermal power from 95X to 90X for backwash and precoat condensate demineralizers (no spare available) 0440 Condensate demineralizers backwash and precoat completed, commenced. power ascension 1530 Reduced thermal power from 97X to 95% due to condenser high back pressure 1810 Reduced thermal power from 95% to 78X for removal of "A" condenser circulating pump from service to keep condenser back pressure below 4.0" of mercury 7/09/80 0430 Commenced power ascension from 78% thermal power 0600 Commenced PCIOMR from 85% thermal power 1539 Reduced thermal power from 92X to 75% due to high river temperature 2050 Commenced power ascension from 75% thermal power
Si nificant 0 erational Events Unit 1 Date Time Event 7/10/80 0230 Commenced PCIOMR from 80% thermal power 1330 Reactor thermal power at 90%, holding to place unit on cooling towers due to river high temperature 1450 Unit on cooling towers resumed PCIOMR 1620 Reduced thermal power from 92% to 82% due to condenser high back pressure 7/11/80 0100 Commenced PCIOMR from 82%,thermal power 1328 Reduced thermal power from 90% to 86% due to condenser high back pressure 2247 Reduced thermal power from 86% to 84% due to condenser high back pressure 7/12/80 0240 Reduced thermal power from 84% to 80% for turbine C. V. tests and SI's 0425 Turbine C. V. tests and SI's completed, holding due to condenser high back pressure 7/13/80 1708 Reduced thermal power from 80% to 65% for control rod pattern adjustment 1945 Control rod pattern adjustment completed, commenced power ascension 7/14/80 1930 Reactor thermal power at 82%, holding due to condenser high back pressure 7/15/80 1100 Commenced'CIOMR from 82% thermal power 7/16/80 1500 Reactor thermal power at 96%,, holding due to condenser high back pressure 7/17/80 0515 Commenced power ascension from 96% thermal power 1500 Reactor thermal power at 98%, limited by condenser high back pressure 7/18/80 1520 Commenced reducing thermal power due to river high temperature 1715 Reactor thermal power at 45%, holding due to river high temperature 1848 Commenced control rod exchange from "A" to "B" 2025 Control rod exchange completed, holding at 45% for river high temperature 7/19/80 1402 Commenced power ascension from 45% thermal power 7/20/80 1630 Commenced PCIOMR from 63% thermal power
Si nificant 0 erational Events Unit 1 Date Time Event 7/22/80 1500 Reactor therm/~power at 99%, maximum flow 2108 Reactor Scram No. 132 from 99% thermal power (FP water spray into open )unction box) 7/23/80 0636 Commenced rod withdrawal 1035 Reactor Critical No. 153 sequence "B" 1443 Reactor Scram No. 133 manual from 5% thermal power to comply with NRC I. E. Bulletin 80-17 2130 Commenced rod withdrawal 2346 Reactor Critical No. 154 sequence "B" 7/24/80 0228 Reactor Scram No. 134 automatic from 5% thermal power to comply with NRC I. E. Bulletin 80-17 0442 Commenced rod withdrawal
. 0620 Reactor Critical No. 155 sequence "B" 0835 Rolled T/G 0854 Synchronized generator, commenced power ascension 7/25/80 0030 Commenced PCIOMR from 71% thermal power 7/26/80 0100 Reactor thermal power at 95%, maximum flow 7/27/80 2328 Commenced power ascension by withdrawing control rods 7/28/80 . 0700 Reactor thermal power 98%, maximum flow 7/30/80 1500 Reactor thermal. power at 98%, maximum flow 7/31/80 0146 Reduced thermal power from 98% to 85% for removal of Al and A2 water boxes from service for flushing 0550 Flushing both water- boxes completed, commenced power ascension 0700 Reactor therma1, power at 98%, maxinnun flow 2400 Reactor thermal power at 98%,, ma~urn flow
Si nificant 0 erational Events Unit 2 Date Time Event 7/01/80 0001 Reactor thermal power at 97%, maximum flow, (sequence "B")
0700 Reactor thermal power at 94%, maximum flow 7/03/80 2125 Reduced thermal'power from 94% to 65% for control rod pattern adjustment 7/04/80 0200 Control rod pattern adjustment completed, commenced power ascension from 65X thermal power 1500 Reactor thermal power at 81%, CPR limited 7/05/80 0040 Reduced thermal power from 81% to 75% for turbine C. V.
tests and SI's 0130 Turbine C. V. tests and SI's completed, commenced PCIOMR from -75% thermal power 7/06/80 0150 Reduced thermal power from 97% to 94% for SI 4.3.A-2 (control rod exercise) 0300 SI 4.3.A-2 completed, commenced PCIOMR from 94% thermal power.
0700 Reactor thermal power at 98%, maximum flow 7/08/80 1616 Reduced thermal power from 98% to 90% due to condenser high back pressure 7/09/80 0425 Commenced power ascension from 90% thermal power 0600 Commenced PCIOMR from 95% thermal power 2300 -Reactor thermal power at 99%, maximum flow 7/10/80 1633 Reduced thermal power from 99% to 93% for cooling tower operation 7/11/80 0630 Commenced PCIOMR from 93% thermal power 7/12/80 Reduced thermal power from 95% to 90% due to condenser high 1400'630 back pressure Reduced thermal power from 90X'o 80% due to high. river temperature 2315 Reduced thermal power from 80% to 70% .,due to high river temperature 7/13/80 0810 Commenced power ascension from 70% thermal power 1500 Reactor thermal power at 90%, holding due to condenser high back pressure 7/14/80 0330 Commenced PCIOMR from 90% thermal power 1005 Reduced thermal power from 94% to 74% due to condenser high back pressure
10 Si nificant Operational Events Unit 2 Date Time Event 7/15/80 1055 Commenced power ascension from 74% thermal power 1445 Commenced PCIOMR from 83% thermal power 7/16/80 0630 Reactor thermal power at 99%, maximum flow 1420 Reduced thermal power from 99% to 93% due to main transformer high temperature 2030 Reduced thermal power from 93% to 84% due to condenser high back pressure 7/17/80 0030 Commenced power ascension from 84X thermal power 0150 Commenced PCIOMR from 90% thermal power 0700 Reactor the~[ power at 96%, maximum flow 0907 Reactor Scram No. 104 from 95% thermal power on low reactor level (loss of unit preferred MG Set) 1202 Commenced rod withdrawal for startup 1420. Reactor Critical No. 115 sequence "B" 1626 Rolled T/G 1645 Synchronized generator, commenced power ascension 7/18/80 0430 Commenced PCIOMR from 76% thermal power 2300 Reactor thermal power at 95X, holding due to con-denser high back pressure 7/19/80 2300 Reduced thermal power from 95X to 90% due to con-denser high back pressure 7/20/80 0650 Commenced PCIOMR from 90X thermal power 7/21/80 0700 Reactor thermal power at 95%, maximum flow 7/26/80 2130 Commenced reducing thermal power from 95% for a manual scram to comply with NRC I. E. Bulletin 80-17 7/27/80 0201 Reactor Scram No. 105 from 44% thermal power to comply with NRC I. E. Bulletin 80-17 0635 Commenced rod withdrawal 1115 Reactor Critical No. 116 sequence "B" 1358 Reactor Scram No. 106, automatic, from 5X thermal power to comply with NRC I. E. Bulletin 80-17 2245 Commenced rod withdrawal 7/28/80 0103 Reactor Critical No. 117 sequence "B" 0530 Rolled T/G 0604 Synchronized generator, commenced power ascension
11 Si nificant 0 erational Events Unit 2 Date Time Event 7/28/80 2200 Reactor thermal power at 37%, holding due to problems with condensate short cycle valves (FCV 2-29 isolation valve would not close) 2339 Reactor Scram No. 107, manual, from 37% thermal power for condensate short cycle valve maintenance 7/29/80 0600 Reactor at cold shutdown for maintenance to short cycle valves 7/30/80 2243 Commenced rod withdrawal for startup 7/31/80 0250 Holding reactor startup due to water quality 0600 Reactor Critical No. 117 sequence "B" 1550 Rolled T/G 1628 Synchronized generator, commenced power ascension 2400 Reactor thermal power at 45%, with power ascension in progress
Si nificant 0 erational Events Unit 3 Date Time Event 7/01/80 0001 Unit at cold shutdown for maintenance 7/10/80 0325 Commenced rod withdrawal for startup 0435 Reactor Critical No. 95 sequence "B" 1655 Reactor thermal power at 5%, holding at 2 bypass valve capacity 7/11/80 1211 Reactor Scram No. 86, manual, from 5% thermal power to comply with NRC I. E. Bulletin 80-17 2200 Commenced rod withdrawal 2347 Reactor Critical No. 96 sequence "B" 7/12/80 0901 Reactor Scram No. 87, automatic, from 5% thermal power to comply with NRC I. E. Bulletin 80-17 1655 Commenced rod 1825 Critical withdrawal'eactor No. 97 sequence "B" 7/13/80 1855 Rolled T/G 1940 Synchronized generator, commenced power ascension 7/14/80 0930 Reactor thermal power at 47%, holding due to RCIC being inoperable 1405 RCIC made operable, holding for SI's 1855 Reactor thermal power at 47%, holding for "D" RHR pump being inoperable
~
7/15/80 0030 "D" RHR pump made operable, commenced power ascension from 47% thexmal power 1141 Commenced PCIOMR from 68% thermal power 7/16/80 1435 Reduced thermal power from 86% to 76% due to main steam line high temperature alarm 2120 Commenced. reducing thermal power to investigate half isolation received on main steam tunnel high temperature (temperature switch 1-54B) 2207 Reactox'hermal power at 40%, holding for replacement of temperature switch 1-54B 2350 Temperature switch 1-54B replacement completed, commenced power ascension 7/17/80 0250 Reactor thermal power at 60%, holding due to river high temperature 0818 Commenced power ascension from 60% thermal power 0930 Commenced PCIOMR from 82% thermal power 2100 Commenced reducing thermal power from 88% to 40% fox replacement of temperature sensor in moisture separator room
13 Si nificant 0 erational Events Unit 3 Date Time Event 7/18/80 0100 Commenced power ascension 0500 Commenced PCIOMR from 82% thermal power 1300 Reduced thermal power from 94% to 90% due to main steam
,line low pressure (A-1) 1603 Reduced thermal power from 90% to 46% due to river high temperature 2045 Commenced power ascension 7/19/80 0405 Reactor thermal power at 85%, holding for turbine C. V.
tests and SI's 0500 Turbine C. V. tests and SI's completed, commenced PCTOMR 7/20/80 0500 =
Reduced thermal power from 96% to 77% for removal of "A" reactor feed'umps from service for maintenance (leak) 1751 "A" reactor feedpump maintenance completed and pump placed in service, commenced power ascension 1900 =Commenced PCIOMR from 83% thermal power 7/21/80 1500 Reactor thermal, power at 97%, maximum flow 7/26/80 - 2345 Reduced thermal power from 97% to 85% for turbine C. V.
tests and SI's 7/27/80 0038 Turbine C. V. tests and SI's completed, commenced power ascension 1 0700 Reactor thermal power at 95%, maximum flow 7/30/80 1500 Reactor thermal power at 94%, maximum flow 7/31/80 2400 Reactor thermal power at 94%, maximum flow (1) Maintenance error (2) Equipment malfunction
14 A VERAGE DAlLYUNIT POWER LEVEL DOCKET NO.
DATE 8-2-80 COMPLETED BY ed Thorn TELEPHONE 205 729 6846 ONTH Ju1y 1980 DAY AVERAGE DAlLYPOWER LEVEL DAY AVERAGE DAILYPOWER LEVEL (MWe iVet) (MWe-iVet) 986'7 1048 827 19 511 20 623 1032 843 1002 893 1003 -13 937 359 772 25 899 10 850 26 955 853 27 962 ~
12 800 1018 13 798 29 993 30 994 15 868 31 990 16 989 INSTRUCTIONS On this fortnat.!1st the average daily unit power level in M'tVe.Net for each day in the reporting inonth. Ciimputc to the nearest whole megawatt.
('>/77)
15 AVERAGE DAILYUNIT POWER LEVEL DOCKET NO.
Browns 'Ferry -2 DATE 8-2-80 COMPLETED BY Ted Thorn MONTH July 1980 DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAILYPOWER LEVEL (MWe-iVet) (MWe-Net)
I 1002 17 492 999 IS 830 956 19 945 785 20- 929 946 21 973 1005 22 998 1026 23 990 8 990 991 989 '75 1016
'10 1015 "6 ~ 907 954 27 18 12 913 28 218'10 13 898 29 804 30 15 827 31 98 16 971 INSTRUCTIONS On this format, list the avenge daily unit power level in iWIIVc.Net for,each'day in the reporting inonth. Compute to the nearest whole megawatt.
Ii)/77)
16 A VERAGE DAlLYUi IIT POWER LEVEL Browns Ferry 3 DATE COMPLETED BY TELEPHONE 205 729 6846 gIO q TH Jtsly 1 980 DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAILYPOWER LEVEL IMWe-Net) (MWe.Net)
I
-11 711 '7
-1.0 18 809
-10 19 949
-10 20 876 2] 1037 1030 22'3 1025
-12 24 1023 25 1042 10 -10 26. 986
~
11 27 1000 IZ 28 1003 13 29 14 462 986 30 IS 668 988 31 l6 832 INSTRUCTIONS On this format.!ist the average daily unit power level in MtVe.Net for each day in thc reporting inonth. Ciimputc to the nearest whole megawart.
(<)/77)
I
'r ~ . ~ V(4 NS' hA
OPERATING DATA REPORT DOCKET istO.
DATE COidPLETED BY
~99
~Galen TELEPHONE 205 729 6846 OPERATliVC STATUS Browns Ferry Urd.t 1 Notes,
,t,n, P .d. Jul 1980
- 3. Licensed Thermal Power (MlVt):
3293 1
- 4. Nameplate Rating (Cross ilfWe):
- 5. Design Electrical Rating (Net MWe):
- 6. lfaximum Dependable Capacity (Gross MlVe): 1098.4
- 7. Ifaximum De p endableCa p acit y( Net MlVe:
1065
)
- 8. IfChanges Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons:
N/A
- 9. Power Level To Which Restricted, If Any (Net MlVe): N/A IO. Reasons For Restrictions. If Any:
- 11. Hours In Reporting Period
- 12. Number Of Hours Reactor
'44 Was
- 13. Reactor Reserve Shutdown Hours
- 14. Hours Generator On-Line Critical This ilfonth 717.63 12.39 708. 23 Yr.-to. Date 5111 2,909.13 356.42 2780.43 Cumulative 52,609 31,186.41 5,046.03 30 393.16 IS. Unit Reserve Shutdown Ilours 0 0 0
- 16. Cross Thermal Energy Generated (MlVH) 7,892,806 82,029,299 is. Cross Electrical Energy Generated (MtSH) 2 531 200 27 049 660
- 18. Net Electrical Energy Generated (MWH) 639,591 2,452,337 26,254,305
- 19. Unit Service Factor 95. 2 54 ' 57.8
- 20. Unit Avaihbility Factor 54.4 57.8
- 21. Unit Capacity Factor (Using tlfDC Net) 80. 7 45.1 46.9
- 22. Unit Capacity Factor (Using DER Net). 80. 7 45.1 46.9 D. Unit Forced Outage Rate 4.8 13.7 31.6
- 24. Shutdowns Scheduled Over Next 6 Months (Type, Date. and Duration of Ea chl
- 25. IfShut Down At End.Of Report Period. Estimated Date of Startup:
- 26. Units ln Test Status IPrior to Commercial Operation): .
Forecast Achieved IN ITI A L CRITICALITY INITIALELECTRICITY COMilfERCIAL OPERATION
'9/77)
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18 OPERATING DATA REPORT DOCKET NO.
DATE ~K 50-260 J)~~t COMPLETED BY TELEPHONE ~~846 OPERATING STATUS I Unit Name: Browns Fer - Unit 2 Notes
. Reporting Period:
3 3
- 3. Licensed Thermal Power (MWt):
- 4. Nameplate Rating (Gross MWe):
- 5. Design Electrical Rating (Net MWe):
- 6. Maximum Dependable Capacity (Gross MWe):
- 7. i laxtmum Dependable Cap acit y ( Net MWe: )
- 8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report. Give Reasons:
N/A
- 9. Power Level To Which Restricted, If Any (Net MWe):
- 10. Reasons For Restrictions, ff Any:
This Month Yr..to.Date Cumulative
- 11. Hours In Reporting Period 744 664.12 5 ill 4,452.10 47 520 28,936.58
- 12. Number Of Hours Reactor Was Critical
- 13. Reactor Reserve Shutdown Hours 59.15 4 3.11
- 14. Hours Generator On-Line 643.50 4 322.59 27 986.90 IS. Unit Reserve Shutdown Hours 0 0 0
- 16. Gross Thermal Energy Generated (MWH) 1 858 754 12 416 629 -78 571 629
- 17. Gross Electrical Energy Generated (MWH) 606 890 4 128 890 26 078 958
- 18. Net Electrical Energy Generated (MWH) 586,379 4,013,311 25,344,780
- 19. Unit Service Factor 86.5 84.6 58.9
- 20. Unit Availability Factor 86.5 84.6 , 58.,9
- 21. Unit Capacity Factor (Using ~WIDC Net) 74.0 73.7 50.1
- 22. Unit Capacity Factor (Using DER Net) 74.0 73.7 50.1
- 23. Unit Forced Outage Rate 13.5 14.0 34.1
- 24. Shutdowns Scheduled Over Next 6 L~Ionths (Type, Date.and Dumtion of Each):
Refuel outage September 1980
- 25. If Shut Down At End Of Report Period, Estimated Date of Startup:
- 26. Units ln Test Status (Prior to Commercial Operation): Forecast Achieved INITIALCRITICALITY INITIALELECTRICITY COMMERCIAL OPERATION (9I77)
19 OPERATliVG DATA REPORT DOCKET NQ. 50-296 04T8 ~9-COMPLETED 8Y ~2raen6846 TELF.PHONE ~229 OPERAT14VG STATUS Browns Ferry - Unit 3 Notes
- 3. Licensed Thermal Power (MWt):
rneplate Rating (Gross S. Dcsian Electrical Rating (Net MWe):
- r. hiaximum De p endable Ca p acit y(Net MWe:) 1065
- 8. If Changes Occur in Capacity Ratings (Items iVumber 3 Through 7) Since Last Report, Give Reasons:
N/A
- 9. Power Level To Which Restricted, If Any (Net MWe):
- 10. Reasons For Restrictions, If Any:
This Month Yr.-to-Date Cumulative I I. Hours ln Reporting Period 744 5111 29 975 IZ. Number Of Hours Reactor Was Critical 502.42 4356.22 23,263.77
- 13. Reactor Reserve Shutdown Hours 101.63 1 759.94
- 14. Hours Generator On-Line 436.33 4259.13 22696.94
- 15. Unit Reserve Shutdown Hours 0 0 0
- 16. Gross Thermal Ener y Generated (MWH) 1,227,122 -
13,164,883 66,272,749
- 17. Gross Electrical Energy Generated (MWH) 408 950 4 437 980 21,840,560
- 18. Net Eiectricai Energy Generated (MWH) 391,806 4,319,383 "
21,207,156
- 19. Unit Service Factor 58.6 - 83.3 75.7
- 20. Unit Availability Factor 58.6 83.3 75.7 Zl. Unit Capacity Factor (Using MDC Net) 49.4 79.4 66.4
- 22. Unit Capacity Factor (Using DER Net) 79. 4'9.4 66.4
- 23. Unit Forced Outage Rate 41.4 "
16.7 '10. 6
- 24. Shutdowns Scheduled Over Next 6 Months (Type. Date. and Duration of Each):
Refuel outage October 1980
- 25. If Shut Down At End Of Report Period. Estimated Date of Startup:
- 26. Units ln Test Status (Prior to Commercial Operation): Forecast Achieved INITIALCRITICALITY INITIALELECTRICITY COMM ERCIA L OPERATION (9/77)
DOCKET NO. 50-259 UNIT SIIUTDOWNS AND POWER REDUCTIONS UNIT NAhlE DATE 1
COhlPLETED BY REPORT MON'fll TELEI'IlONE C
l 1 CJ~
~ A Ln:cnscc C Cause A ('orrcclivc No. l)alc fl Vl rJ Event Action Io Q r Report > 0 Prevent Recurrence 135 800705 B Derated for turbine control valve test and SI's.
136 800718 Derated due to high river AT 137 800722 17.58 EHC system failure (turbine controls) 13& 800723 11.75 Rx manual scram to test control rods er NRC Bulletin 80-17.
139 800724 6.44 3 Rx automatic scram to test control rods per NRC Bulletin 80-17.
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I I 3 4 F: Forced Reason: hlethod: Exhibit G - Instruct ious I",-: S: Scheduled A.Equipment Failure (Explain) I -hlanual Ior Preparation of Data 1" B.hlaintenance oi Test 2.hlanual Scram. Entry Sheets tor I.iccusce C-Refueling 3-Aulonwlic Scranl. f vent Rep 111 (I.I'.It) Fil 'NUREG.
D.Regulatory Restriction 4.Other (Lxplaul) OI 6 I )
l Ir L.Operator Training 8; Llccnsc Exanlhlalion F.Administrative I 1. G.Operational Error (Explain) Fxhibil I ~ Salnc Source
(')/77) I I.Ol hcr (Ex plain)
Iii
UNIT SIIUTDO1VNS AND PO)VER REDUCTIONS DOCKET NO.
UNIT N Ah(E DATE COhIPLETED IN TELEPIIONE 205 729 6846 I
C CJ~
III n Ln:cnscc Cause &, Corrcelivc h o No: Ihtc tS m 5 rx.' Event Aclloll to I
E ~
d M Rcport 4f O Prevent Rl aurrcllcc 145 800703 H Derated for control rod pattern adjustment 146 800712 H Derated due-.to high. river AT 147 800714 Derated due to condenser high back ressure 148 800717 7.63 A 3 Low reactor water level due to loss of unit preferred MG set (over voltage rela malfunction 149 800727- ll.95 Reactor manual scram to test control rods er NRC Bulletin 80-17.
150 800727 16.10 D 3 Reactor automatic scram to test con-trol rods er NRC Bulletin 80-17.
151 800728 64.82 A Failure of condehsate short cycle valves.
F: Forced Reason: 'hlethod: Exhibit G - Instructions S: Scheduled A.Equipment Failure (Explain) I hlanual for Prcpafallou ot Data B.hlaintcnance or Test 8 2.hlanual Scram. Entry Shccls I'or Liecnsec C-Refueling 3.Automatic Scranl. Event Rcport (I.I!I<) Fil>> (NURI.G.
D Regulatory Rcslrietion 4.0tlrcr (Explain) OI6I )
li Opcralor Training &, License Exalni>>ation F.Administrative G.Opcralional Error (Explain) Exhibit I - Salne Source I I.Other (Explain)
l)OCKET NO. 50-296 UNIT SIIUTI)OWNS ANI) POWER REI)UCTIONS UNll NAhlE I)ATE Gre fli ~Jul COhIPLETEI) BY IIEPORT hhON TELEPIIONE rr, I
Ltccnscc Cl C ~ ~
Ca<<sc & ChIrrcctrvc Ch o ~
I)atc 2 oCt Event AltIhln III I l(eport rr C
o ~ Prevent Rclllrfcllce
~ CR 132 800701 5.50 Haintenance to feedwater piping continued. Reactor shutdown in June 133 800701 F 246. 68 Investigation and testing of control rods and scram discharge volume due t problems inserting rods on Scram No. 85. Reactor was shutdown in Jun 134 800711 F 20.84 Reactor manual scram to test control rods er NRC Bulletin 80-17.
135 800712 34I65 Reactor automatic scram to test con-trol rods er NRC Bulletin 80-17.
Ih h
136 800716 Derated due to main steam tunnel high tern erature tern erature switch 1-54B 137 800717 Derated to replace temperature senser.
in moisture se erator room.
138 800718 Derated due to high river hT.
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3 F: Forced Reason: Method: Exhibit G - Instr<<ctioos S: Scheduled A-Equipment Failure (Explain) I -hlanual Il)r Prep'lr'l ill)Il ol 0'lla B.hlaintenance oi Test 2I.h( annal Sera<<I. Fntry Sh<<cts tor l.iccllscc C.Refueling 3 Auto<<i:Itic Sera<<i. Event Report (I.lilt)I'il<<(NIIRFG-I) R<<gulalory Restriction A.Other (Explain) 016I )
Ii Operator Training & Uccnsc Fxantination F.Adntinist rat ivc G-Operational Lrn>r (lixplain) Exhibit I ~ S:IInc Sh<<trc<<
I I Other (Explain)
BROGANS PERRY NUCLEAR PLANT UNIT 1 MECHANICAL MAINTENANCE SUtkfARY Por the Month of ~ulJ 19 8O EFFECT ON SAFE ACTION TAKEN OPERATION OP CAUSE OP RESULTS OP TO PRECLUDE DATE SYSTEM COMPONENT NATURE OP MAINTENANCE THE REACTOR MALPUNCTION MALFUNCTION RECURRENCE 7/23/8( 1(igh press Valve 1-26-73B Valve not None Mussel .shells Leaking valve Disassembled, cleaned fire prote seating off seat 'nder and replaced line lu and'lot tion TR 180537 7/19/8( Reactor FCV-64-139 Valve would None Hole in diaphrag Stuck valve Replaced diaphragm Building not open TR 137666 Ventilatio 7/8/80 HPCI PCV 73-43 Valve stuck None Stem guide bush- Valve stuck in closed Replaced diaphra(, &
in closed ing was screwed position cleaned inside of position out of place valve. Tightened stem TR 153423
CSSC EOOIPHSrIT 1fEClfANICAL MAINTENANCE SUMf fARY For the 1fonth of 19~
EFFECT ON SAFE ACTION 'LIKEN DATE SYSTE1f COIIfPONENT NATURE OF OPERATION OF CISE OF RESULTS OF TO PRECLUDE MAINTENANCE TfIE REACTOR MALFUNCTION MALFUNCTION RECURRENCE 7/14/8( Fuel Pool Pump 28 Seal leaking Hone Drains stopped rains stopped up and Unstopped drains and Cooling & drain clogg d up and packing packing leak ad)usted packing leak TR 170762
~ )lECIIANICAL MAINTENANCE
SUMMARY
EFFECT ON SAFE ACTION TAl;EN DATE SYS TEN COMPONENT NATURE OF .OPERATION OF CAUSE OF RESULTS OF TO PRECLUDE f
MAINTENANCE TllE REACTOR MALFUNCTION MALFUNCTION RECURRENCE 7/9/80 CRD FCV-85-37A Bent poppet None Bent stem Bent stem Removed valve and stem and repaired stem TR 103306 7/5/8g EECM- PCV 67-79 Strainer None Strainer stopped Render 3B control bay Cleaned strainer sto ed u u chiller ino arable TR 174755
BROMHS FERRY NUCLEAR PLANT UNIT Common CSSC E UIPlKNT FEQIAHICAL MAINTENANCE SVMtfARY For the Month of - July 19 80 EFFECT ON SIZE ACTION TAKEN SYS'lw11 COMPONENT NATURE OF OPERATION OF CAUSE OF RESULTS OF TO PRECLUDE MAINTENANCE THE REACTOR MALFUNCTION MALFUNCTION RECURPENCE 7/22180 RHR Pump Al Packing leak None Packing leak Packing leakoff needs Replaced packing leak-replacing off tubing TR 137669
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LPOUUU PEUlH UUCLUAII PLIIIIT OUGHT ELECTRICAL HAINTENANCE StMfARY ect on 'a e I Action Taken D.".te System , Component Nature of Operation of Cause of Results:of To,Preclude Haintenance The Reactor Halfunction Halfunction Recurrence 7/7/80 Control 3A shutdown 3A shutdovn NONE Hotor burned Bad Bearing ~
Replaced motor and bay board room,. board room up, bearing 'I overload heater," ,
heating exhaust fan exhaust fan worn out, over- Checked rotation in vent and 'otor bad. load heater both speeds. Checkei air con- burned out ok. TR8 180699 ditioning 7/14/8 Hain steam Check limit switches on Check limit svitches for NONE Limit switch broken on,
'roken limit switch Replaced switch on MSIV 83. Checked al:
(stop stop valve. proper op- MSIU P3. .svitches also. All valve) eration. switches presently
- working properly.
- Check ok. TRII'174761 I
7/14/80 HPCI Pos. lights Pos lights NONE Switch out of Adjusted limit Adjusted limit switch on valve on valve in- adjustment, switch, to get proper lights, indicating icating valve :Check ok. TR8165610 valve open open when valve is def-initely closed.
7/14/80 RCIC FCV-3-71-34 FCV-3-71-34 NONE Torque svitch Torque svitch 'Cleaned torque switcl will not . contact was prevented valve I
'Contact valve now close dirty. closing, operates correctly.
'TR8 174766 BFRO-50~
256/8026 I
7/28/80 Neutron Bad APRH Bad AP1Qf NONE Bad switch Switch out of Changed switch.
Honitoring switch .switch adjustment witch works properly heck ok. TR8170399
BROliNS PEIUiY NUCLEAO PLANT UNIT ELI?CTRICAL IQINTENANCE SU>BhRY Por the Ihonth of ~uly 19 80 E ecton 'a e Action Taken Nature of Opera tion o f Cause of Results of To Preclude Unte System Component llaintenance The Reactor Nalfunction i~lal func tion Recurrence t
7/31/80 Fire Zone heat Zone sensing NONE Broken heat Heat detector was Replaced heat Protection'detector element in detector. Ther operable inspite SX 4,11.C 1 detecto)'erformed cable tray is 4.11.C 3',
~
was no alarm in of being cut. and 5 and SX open. Replace for the detec- and 4. Pire watch element TE 39- tor. Detector was established wh~e 101. Col TRI4 Elevation 565 broken. into making two making ok.
repairs.
TRf/ 148256 k
unit 3 RX bldg detectors,
BRCURE BERRY NUCLEAR PLAUT UEXT 1 2 & 3 INSTRUMENT MAINTENANCE StMQNY CSSC E UIPMENT a NATURE EFFECT ON SAFE CAUSE ACTION TAKEN COMPONENT OF OPERATION OF OF RESULTS OF TO PRECLUDE DATE SYSTEM MAINTENANCE THE REACTOR MALFUNCTION 5$ LFUNCTION RECURRENCE Unit 1 7-16 Radwaste RM-77-6 Calibrate None Instrument Drift Indicated Flow with None Pump Off Unit 2 7-15 Primary PdI-64-137 Calibrate None Instrument Drift Disagreement Between None Containment PdI-64-138 Redundant Indicators PdT-64-138 Unit 7-31 Off-Gas . FIS-66-33A Calibrate None Instrument Drift Flow Alarm Would None FIS-66-33B Replace None Bad Photo Cell Not Reset None
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+I I
32 OUTAGE
SUMMARY
July 1980 Major work for the outage group during the month consisted of continuing modifications to the plant. Security modification work is 99 percent com-plete in preparation for the August 15, commitment date. The E- Field checkout and modification is underway after a vendor representative was on-site to review some of the recurring problems.
Emphasis was also placed upon inspections of the CRD water lines and the scram volume discharge tank for Unit 3 reactor after scram problems were encountered. Investigations continue.
The last shipment of fuel for the upcoming outage was received July 20, 1980, and processing completed by July 25.
Meetings were held to shorten duration on some modifications scheduled during the Unit 2 refueling outage. The generator breaker modification was reviewed in depth to schedule the work in 49 days. Several contingency plans for the Unit 2 outage were also issued to reflect jobs that could impact the critical path schedule and extend the overall refueling outage duration.
Other outage work consisted of: the repair of the condensate short cycle valves which forced Unit 2 to shutdown. The modifications to the hypochlorite building, the condensate storage tanks, the low level rad-waste facilities, construction of a new east portal/medical station, construction of the outage fabrication shop and piping and hanger in-spections per the NRC Bulletin 79-02 and 79-14.
1