ML18152A485
| ML18152A485 | |
| Person / Time | |
|---|---|
| Site: | Surry  |
| Issue date: | 12/31/1989 |
| From: | Warren L VIRGINIA POWER (VIRGINIA ELECTRIC & POWER CO.) |
| To: | |
| Shared Package | |
| ML18152A486 | List: |
| References | |
| NUDOCS 9001230019 | |
| Download: ML18152A485 (23) | |
Text
ATTACHMENT 1 MONTHL V OPERATING REPORT DECEMBER, 1989
VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION MONTHLY OPERATING REPORT REPORT#
89-12 POW 34-04 MPM~:~&
t n
ge
TABLE OF CONTENTS SECTION Operating Data Report - Unit No. 1 Operating Data Report - Unit No. 2 Unit Shutdowns and Power Reductions - Unit No. 1 Unit Shutdowns and Power Reductions - Unit No. 2 Average Daily Unit Power Level
- Unit No. 1 Average Daily Unit Power Level
- Unit No. 2 Summary of Operating Experience - Unit No. 1 Summary of Operating Experience - Unit No. 2 Facility Changes That Did Not Require NRC Approval Procedure or Method of Operation Changes that Did Not Require NRC Approval Tests and Experiments That Did Not Require NRC Approval Chemistry Report Fuel Handling - Unit No. 1 Fuel Handling - Unit No. 2 Description of Periodic Test Which Were Not Completed Within the Time Limits Specified in Technical Specifications PAGE 1
2 3
4 5
6 7
9 12 15 16 17 18 18 19
OPERATING DATA REPORT DOCKET NO.:
50-280 DATE:
01/03/90 COMPLETED BY:
L.A. Warren TELEPHONE:
(804)357-3184 x355 OPERATING STATUS NOTES
- 1. Unit Name:
Surry Unit 1
- 2. Reporting Period: Dec 01-31, 1989
- 3. Licensed Thermal Power (MWt):2441
- 4. Nameplate Rating (Gross MWe):847.5
- 5. Design Electrical Rating (Net MWe):
788
- 6. Maximum Dependable Capacity (Gross MWe):
820
- 7. Maximum Dependable Capacity (Net MWe):
781
- 8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons: -----------------------
- 9. Power Level To Which Restricted, If Any (Net MWe): -----------
- 10. Reason For Restrictions, If Any:
- 11.
- 12.
- 13.
- 14.
- 15.
- 16.
- 17.
- 18.
- 19.
- 20.
- 21.
- 22.
- 23.
- 24.
THIS MONTH YTD CUMULATIVE Hours In Reporting Period 744.0 8760.0 149256.0 Number of Hours Reactor Was Critical 719.2 4272.2 92750.8 Reactor Reserve Shutdown Hours O
O 3774.5 Hours Generator On-Line
---=7...,...16=-......,1- __ __,4_,,.2.,,..,17"'""._,,8,_
90823.2 Unit Reserve Shutdown Hours O
O 3736.2 Gross Thermal Energy Generated (MWH)
-=-=17=3-=35=-=o=o-=.o,......
-9=-=9:--:-4=55=3=6-=.o,......
211116803.0 Gross Electrical Energy Generated (MWH) 587650.0 3341730.0 68545403.0 Net Electrical Energy Generated (MWH) 560183.0 3170527.0 65010930.0 Unit Service Factor 96.3%
48.1%
60.9%
Unit Available Factor 96.3%
~~-=4=8""""".1'""'%
63.4%
Unit Capacity Factor (Using MDC Net) 96.4%
46.3%
56.3%
Unit Capacity Factor (Using DER Net) 95.6%
~~.....,4=5-=,9~%
55.3%
Unit Forced Rate 3.8%
---=-51=-."""'9'""'%
21.6%
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. Unit In Test Status (Prior to Commercial Operation):
FORECAST.-~A"""CH'""'"'I=E=v=ED,,.--
INITIAL CRITICALITY INITIAL ELECTRICITY COMMERCIAL OPERATION 1
OPERATING DATA REPORT DOCKET NO.:
50-281 DATE: ~Ol.....,/=o.,...3;=9=0-----
COMPLETED BY:
L.A. Warren TELEPHONE: ~(8=oc-:-4.,-,)3==5=7_--:;3=1=-84-=--x=35-5,-.-
OPERATING STATUS NOTES
- 1. Unit Name:
Surry Unit 2
- 2. Reporting Period: Dec 01-31, 1989
- 3. Licensed Thermal Power (MWt):2441
- 4. Nameplate Rating (Gross MWe):847.5
- 5. Design Electrical Rating (Net MWe):
788
- 6. Maximum Dependable Capacity (Gross MWe):
820
- 7. Maximum Dependable Capacity (Net MWe):
781
- 8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons: -----------------------
- 9. Power Level To Which Restricted, If Any (Net MWe): -----------
- 10. Reason For Restrictions, If Any: -------------------
THIS MONTH YTD CUMULATIVE
- 11. Hours In Reporting Period 744.0 8760.0 146136.0
- 12. Number of Hours Reactor Was Critical 744.0 1504.3 91198. 6
- 13. Reactor Reserve Shutdown Hours 0
0 328.1
- 14. Hours Generator On-Line 744.0 1355.9 89648. 9
- 15. Unit Reserve Shutdown Hours 0
0 0
- 16. Gross Thermal Energy Generated (MWH) 1789591. 0 2869898.7 209610334. 8
- 17. Gross Electrical Energy Generated (MWH) 602620.0 944355.0 68080599.0
- 18. Net Electrical Energy Generated (MWH) 573084.0 893581.0 64540959.0
- 19. Unit Service Factor 100%
15.5%
- 61. 3%
- 20. Unit Available Factor 100%
15.5%
61.3%
- 21. Unit Capacity Factor (Using MDC Net) 98.6 13.1%
56.7%
- 22. Unit Capacity Factor (Using DER Net) 97.8%
12.9%
56%
- 23. Unit Forced Rate 0
45.7%
15.7%
- 24. Shutdowns Scheduled Over Next 6 Months ( Type, Date, and Dura ti on of Each):
- 25. If Shut Down at End of Report Period Estimated Date of Startup:_---,,....,,.,..,.,~==--
- 26. Unit In Test Status (Prior to Commercial Operation}:
FORECAST ACHIEVED INITIAL CRITICALITY INITIAL ELECTRICITY COMMERCIAL OPERATION 2
NO.
DATE UNIT SHUTDOWN AND POWER REDUCTION REPORT MONTH:
DECEMBER 1989 METHOD OF LICENSEE DOCKET NO.:
50-280
--=----.-:--.-,.--,.---
UN IT NAME:
Surry Un1t 1 DATE:
01/03/90 COMPLETED BY:
L.A. Warren TELEPHONE:
804-357-3184 x355 DURATION SHUTTING EVENT SYSTEM COMPONENT CAUSE & CORRECTIVE ACTION TO PREVENT RECURRENT TYPE(l)
(HOURS)
REA~ON(2) DOWN REACTOR(3) REPORT# C0DE(4)
CODE(5)
- 10-5 12/21/89 F 27.9 A
2 89-044 EB XFMR Insulation blew off of the turbine building room and struck the high side lead of a
reserve station service (RSS) transformer actuating pilot wire trip.
- 3 EDG started and loaded on lJ 4160 emergency bus.
Ensuing transient caused IRPI rod bottom runback with questionable rod position indication.
Reactor operator manually (1)
F:
Forced S: Scheduled (2)
REASON:
A - Equipment Failure (Explain)
B - Maintenance or Test C - Refueling D - Regulatory Restriction E - Operator Training & License Examination F - Administrative G - Operational Error (Explain)
H - Other (Explain)
(3)
METHOD:
1 - Manual 2 - Manual Scram.
3 - Automatic Scram.
4 - Other (Explain) tripped reactor.
Additional insulator stacks were added to the high side of a
RSS transfonner to support feeder cable.
(4)
Exhibit G - Instructions for Preparation of Data Entry Sheets for Licensee Event Report (LER)
File (NUREG 0161)
(5)
Exhibit 1 - Same Source
UNIT SHUTDOWN AND POWER REDUCTION REPORT MONTH:
DECEMBER 1989 METHOD OF LICENSEE DOCKET NO.:
50-281 UNIT NAME: --,s=-u-r-ry--..,...Un-.1~t""""'2---
DATE:
01/03/90 COMPLETED BY:
L.A. Warren TELEPHONE:
804-357-3184 x355 DURATION SHUTTING EVENT SYSTEM COMPONENT CAUSE & CORRECTIVE ACTION TO PREVENT RECURRENT NO.
DATE TYPE(l)
(HOURS}
REASON(2} DOWN REACTOR(3) REPORT#
CODE(4}
CODE(5}
12/22/89 F 0
A 4
12/26/89 S B
4 (1)
F:
Forced S: Scheduled (2)
REASON:
A - Equipment Failure (Explain)
B - Maintenance or Test C - Refueling D - Regulatory Restriction E - Operator Training & License Examination F - Administrative G - Operational Error (Explain)
H - Other (Explain)
N/A N/A (3)
METHOD:
I - Manual AA SG 2 - Manual Scram.
3 - Automatic Scram.
4 - Other (Explain}
FU COND Control rod D-4 dropped causing turbine runback.
Fuse blew and was re-placed.
Ramped down to perfonn valve freedom test on main turbine and clean water-boxes *
( 4)
Exhibit G - Instructions for Preparation of Data Entry Sheets for Licensee Event Report (LER)
File (NUREG 0161)
(5)
Exhibit 1 - Same Source
AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.:
50-280 UNIT NAME:
Surry Unit 1 DATE:
01/03/90 COMPLETED BY:
L.A. Warren TELEPHONE:(804)357-3184 x355 MONTH:
DECEMBER 1989 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net)
(MWe-Net) 1 791 17 793 2
792 18 793 3
791 19 766 4
790 20 793 5
792 21 725 6
792 22 0
7 791 23 558 8
790 24 786 9
789 25 790 10 791 26 790 11 791 27 786 12 792 28 785 13 791 29 787 14 791 30 789 15 791 31 786 16 792 INSTRUCTIONS On this format, list the average daily unit power level in MWe-Net for each day in the reporting month.
Compute to the nearest whole megawatt.
5
AVERAGE DAILY UNIT POWER LEVEL MONTH:
DECEMBER 1989 DAY AVERAGE DAILY POWER LEVEL (MWe-Net) 1 752 2
747 3
757 4
748 5
770 6
735 7
752 8
782 9
783 10 783 11 783 12 783 13 784 14 783 15 785 16 785 INSTRUCTIONS DAY 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 DOCKET NO.:
50-281
--=-:,__,;::_..:,_;:.,..,....-,-.,.--,,--
UN IT NAME:
Surry Unit 2 DATE:
01/03/90 COMPLETED BY:
L.A. Warren TELEPHONE:(804)357-3184 x355 AVERAGE DAILY POWER LEVEL (MWe-Net) 785 785 784 784 783 724 781 780 781 710 783 783 783 741 781 On this format, list the average daily unit power level in MWe-Net for each day in the reporting month.
Compute to the nearest whole megawatt.
6
SUMMARY
OF OPERATING EXPERIENCE MONTH/YEAR: ~-D_EC_E_MB_E_R_1_98_9~-*
Listed below in chronological sequence by unit is a summary of operating expe-riences for this month which required load reductions or resulted in signifi-cant non-load related incidents.
UNIT ONE 12/01/89 0000 12/19/89 1217 1342 1707 1937 12/21/89 2156 12/22/89 1759 2112 2157 2243 2310 12/23/89 0151 0259 0352 0517 0541 1158 1234 1354 1518 1549 This reporting period started with the Unit at 100% power, 830 MW.
Started rampdown for PT-29.1, 100% power, 830 MW.
Stopped ramp, 85% power, 700 MW.
Started rampup, PT-29.1, 82.8% power, 700 MW.
Stopped ramp, Unit at 100% power, 830 MW.
Reactor tripped, Unit off line.
1D 1 transfer bus lost 1A' reserve station service fault.
Commenced reactor startup.
Tripped rods, 'D 1 bank overlap problems.
Commenced pulling rods, reactor startup.
Reactor critical.
Pressurizing main steam, reactor/plant startup. 2% power.
Unit on line and ramping, 15% power, 40 MW.
Stopped ramp up, IRPI adjust, 30% power.
Started ramp up, IRPI adjust, 30% power.
Stopped ramp up, placed secondary systems in service 1-FW-P-lA, recirculation valve problems, 62% power, 490 MW.
Ramped down, 18 feed pump amps high.
Started rampup, 1-FW-P-lA started, 60.4% power, 480 MW.
Stopped rampup for PT-35, 70% power, 560 MW.
Started rampup.
Stopped rampup, polisher differential pressure high, 90.2%
power, 735 MW.
Started rampup, polisher AOV bypass opened, 90.2% power, 735 MW.
7
SUMMARY
OF OPERATING EXPERIENCE MONTH/YEAR:
DECEMBER 1989 Listed below in chronological sequence by unit is a summary of operating expe-riences for this month which required load reductions or resulted in signifi-cant non-load related incidents.
UNIT ONE 12/23/89 1602 Stopped ramp, Hi differential pressure polisher, 93%
- power, 770 MW.
1816 Started rampup, differential pressure satisfied polisher, 93% power, 770 MW.
1918 Stopped rampup, Unit at 100% power, 820MW.
12/24/89 0824 0835 0959 1050 12/31/89 2400 Started ramp down, Hi loop 1C1 differential temperature, 830MW.
Stopped ramp, Hi differential temperature clear, #2 governor valve drifting, 98.5% power, 810 MW.
Started rampup Stopped ramp, Unit at 100% power, 825MW.
This reporting period ended with the Unit at 100%.
8
SUftttARY OF OPERATING EXPERIENCE MONTH/YEAR: ---------
DECEMBER 1989 Listed below in chronological sequence by unit is a summary of operating expe-riences for this month which required load reductions or resulted in signifi-cant non-load related incidents.
UNIT TWO 12/01/89 0000 This reporting period begins with the unit at 98%
- power, 805MW.
Power reduced due to limitations on condensate pol-isher differential pressure.
12/02/89 12/03/89 12/04/89 12/05/89 12/06/89 12/07/89 0910 0950 2230 2310 1130 1135 2300 2045 2225 1650 2105 1229 1323 0321 0418 Rampdown, removed 20 polisher, maintain differential pres-sure.
Stopped ramp, polisher differential pressure~ 35 psi, 95%
power, 785MW.
Started rampup, polisher strainers clean.
Stopped ramp, polisher differential pressure~ 42 psi, 97%
power, 800MW.
Started rampdown, polisher differential pressure high, 97.5%
power 805MW.
Stopped ramp, 43 psi polisher differential
- pressure, 96.5%
power, 800MW.
Ramped
- down, polisher differential pressure, 95.5% power, 790MW.
Started rampup, polisher differential pressure good.
Stopped ramp, reactor coolant differential temperature A & B high, 98.5% power, 805MW.
Ramped up, differential temperature reset, 99% power, 810MW.
Ramped up, polisher building 43 lbs, 100% power, 815MW.
Started rampdown, clean waterboxes, 100% power, 820MW.
Stopped rampdown, 1 01 waterbox out of service, 88% power, 720M~/.
Started rampup, all waterboxes cleaned.
Stopped ramp up, condensate polishing differential pressure 44 psi, 1C 1
loop differential temperature 102, 99% power, 820MW.
0630 Ramped down, condensate polishing differential pressure 43 psi, 97.5% power, 810MW.
9
SUMMARY
OF OPERATING EXPERIENCE MONTH/YEAR:
DECEMBER 1989 Listed below in chronological sequence by unit is a summary of operating expe-riences for this month which required load reductions or resulted in signifi-cant non-load related incidents.
UNIT TWO 12/08/89 0031 0105 12/15/89 1443 1444 1450 12/22/89 1705 1718 1832 1851 1928 1940 2130 12/24/89 0831 0856 1006 llOO 12/26/89 0934 1041 1258 1328 Ramped up, condensate polishing differential pressure good, 97.5% 800MW.
Stopped rampup, condensate polishing differential pressure 45 psi, 100% power, 825MW.
Started rampdown to 99% power, Instrument tech. to work dif-ferential temperature on channels 2 and 3.
Stopped rampdown/started ramp up, differential temperature satisfactory, 99.5% power, 820MW.
Stopped ramp, unit at 100%, 825MW.
Runback, dropped rod D-4.
Plant stable after runback, rod D-4 blown fuse, 57% power 420MW.
Pulled dropped rod, D-4 at 225 steps.
Started rampup.
Stopped rampup, adjust IRPis, 67% power.
Started rampup, IRPis adjusted.
Stopped ramp, Unit at 100% power, 815MW.
Started rampdown, canal level decreasing, 825MW.
Stopped ramp, ice at low level/canal level stable, 98%
pow-er, 800MW.
Started rampup, canal level steady.
Stopped rampup, canal steady, 100% power, 825MW.
Started rampdown, PT-29.1, waterbox cleaning.
Stopped rampdown, 85% power, 705MW.
Started rampdown, unable to remove 101 waterbox.
Stopped rampdown, 101 waterbox out of service.
10
SUMMARY
OF OPERATING EXPERIENCE MONTH/YEAR:
DECEMBER 1989 Listed below in chronological sequence by unit is a summary of operating expe-riences for this month which required load reductions or resulted in signifi-cant non-load related incidents.
UNIT TWO 12/26/89 1950 2127 12/30/89 1150 Started rampup, PT-29.1 complete, 78% power, 660MW.
Stopped rampup, unit at 100% power, 825MW.
Started rampdown, 10 1 waterbox to be cleaned.
1250 Stopped
- rampdown, 10 1
waterbox out of service, 93% power, 755MW.
1600 Ramping to maintain vacuum, 90% power, 740MW.
1622 Started rampdown, instrument air loss at low level intake canal decreasing.
1634 Stopped ramp, intake canal level high, 87% power, 710MW.
1659 Started rampdown, maintain vacuum 10 1 waterbox out of ser-vice.
1720 Stopped ramp, condensate vacuum satisfactory, 83%
- power, 680MW.
1950 2333 12/31/89 2400 Started rampup, 10 1 waterbox returned to service, 700MW.
Stopped ramp, unit at 100% power, 830MW.
This reporting period ended with the unit at 100% power.
11
EWR-89-565 FACILITY CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTH/YEAR:
DECEMBER 1989 SCAFFOLD REQUEST UNIT 2 12/05/89 (Safety Evaluation #089-0047)
This request will erect a temporary scaffold located in Unit 2 turbine building at elevation 9 16 11 between column T-58 and valve 2-SD-LCV-2000.
The 6 1 x 6 1 (max) scaffold will be erected *from the floor about 15 1 high and will be laterally supported from structural steel.
The temporary scaffold is required for safe working.
The installation of scaffold constructed per SUADM-ADM-07 has a high confidence level against failure and was reviewed for effects on accident analyses and equipment operability function.
It is concluded that assumptions, bases and probabilities of accident analyses and equipment malfunctions are not affected.
ENGINEERING WORK REQUEST UNIT 1 12/05/89 This EWR was written to eliminate periodic testing and calibra-tion of 1-SW-RM-107 until the monitor was replaced.
Technical Specification required surveillance via grab sample is being performed.
Since the monitor is not presently in service, and will be replaced by one of a different design, cessation of testing and calibration of the monitor did not create an unreviewed safety question.
S2-AC-89-1210 ADMINISTRATIVE CONTROL 12/10/89 (Safety Evaluation #D89-0047A)
Administrative control was placed to document that the 11 C" main feed regulating valve will be jacked open and MOV-FW-254C will be throttled to control 11C" S/G level.
An operator will be stationed at the "C" main feed regulating valve to shut the valve should feedwater isolation be required by an automatic signal.
The operator will be in contact with the control room by way of 2 radios and will close the valve if required.
Therefore, an unreviewed safety question is not created.
TM-Sl-89-172 TEMPORARY MODIFICATION (Safety Evaluation #089-0048) 12/12/89 This modification was to maintain circuit continuity during the replacement of the test switch PC-4570 in accordance with Work Order #086994.
12
EWR-89-628 FACILITY CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTH/YEAR:
DECEMBER 1989 Failure of this temporary modification would result in loss of continuity to the safety injection (SI) master relay from the pressurizer low pressure Train 1A 1 function and result in loss of this function.
Redundant low pressure SI actuation will be pro-vided by Train 1 8 1 low pressure SI and backup protection for a loss of cooling accident is provided by the hi consequence limit-ing safeguard and manual SI actuations.
The jumpers will be installed to limit the possibility of an inadvertent safety injection, including precautions to prevent jumper slippage.
The affected pressurizer pressure channel will be in tripped position during jumper installation. Since the affected channel is in trip and the remaining safety injection actuation logics and com-ponent actuations are unaffected by this change and remain opera-ble, no unreviewed safety question is created.
ENGINEERING WORK REQUEST UNIT 2 12/14/89 This EWR was required to document the change in reference value and maximum limiting stroke time of power operated valves in the inservice testing program as required by NRC recommendation.
This EWR provides a change to the reference values and maximum limiting stroke times to the Unit 2 power operated valves in the inservice testing program in accordance with the requirements of NRC Generic Letter 89-04.
The maximum stroke times listed in the EWR have been reviewed and do not affect the results of the safety analysis, therefore an unreviewed safety question was not created.
TM-Sl-89-176 TEMPORARY MODIFICATION (Safety Evaluation #089-0049) 12/14/89 Relay 33XB1590 is energized and the normal state for present operating condition is de-energized.
With an energized relay signal, contacts are made up to the high differential pressure safety injection signal A loop defeat (
1 8 1
Train) and steam generator low low level reactor trip 1A1 loop defeat (
1 8 1 Train) because the signal implies that A loop hot leg stop valve is closed.
By lifting the lead to 33XB1590, the relay will be de-energized (normal state) and hi steam line differential pressure safety injection defeat and low low steam generator level reactor trip defeat signals will not be functional.
However, the safety injection and reactor protection signals will not be affected.
The hot leg loop stop valve interlock with the reactor coolant pump will also not be functional (i.e.
1A1 reactor coolant pump would not trip if the logic required a 1590 close signal).
How-ever, technical specifications do not allow loop isolation for present operating conditions.
Therefore, an unreviewed safety question was not created.
13
FACILITY CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTH/YEAR:
DECEMBER 1989 JC0-89-3-012 JUSTIFICATION OF CONTINUED OPERATION UNITS 1 & 2
(.Safety Evaluation #089-0055) 12/19/89 This JCO was written to temporarily resolve the station deviation documenting that the backflow preventors are not installed in the emergency switchgear room (ESGR) floor drains as described in UFSAR Appendix 9C.
A JCO is required to provide continqency actions -until permanent repairs are made.
An unreviewed safety question is not created by this JCO as the contingency actions perform the same function as the backflow preventers which should be installed in the emergency switchgear room floor drains. This function is to prevent flooding of the ESGR from water entering the room through the floor drain system from the turbine building.
14
SPS-EOP PROCEDURE OR METHOD OF OPERATION CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTH/YEAR:
DECEMBER 1989 SURRY EMERGENCY OPERATING PROCEDURES REV IA - UNITS 1&2 12/29/89 (Safety Evaluation #D89-0065)
Changes to the EOPs is to conform to Rev. IA of the Westinghouse Owners Group Emergency Response Guidelines and miscellaneous plant specific items.
The effectiveness of the EOPs have been demonstrated through the EOP validation program in accordance with VPAP-0506 11 EOP Develop-ment, Revision and Maintenance 11 Therefore, the revision lA to the EOPs do not constitute an unreviewed safety question.
15
TESTS AND EXPERIMENTS THAT DID NOT REQUIRE NRC APPROVAL MONTH/YEAR:
DECEMBER 1989 NONE DURING THIS REPORTING PERIOD 16
VIRGINIA POWER SURRY POWER STATION.
CHEMISTRY REPORT MONTH/YEAR: DECEMBER 1989 PRIMARY COOLANT UNIT NO. 1 UNIT NO. 2 ANALYSIS MAX.
MIN.
AVG.
MAX.
MIN.
Gross Radioact., µCi/ml 8.46E-1 7.45E-2 6.73E-1 2.75E-1 2.65E-2 Suspended Solids, ppm 0.0 0.0 0.0 0.0 0.0 Gross Tritium, ~Ci/ml 2.87E-1
- 1. 78E-1 2.51E-1 2.42E-1 1.18E-1 Iodine-131, µCi/ml 3.74E-1 2.82E-3 4.05E-2
- 1. lOE-3 2.79E-4 Iodine-131/Iodine-133 0.17 0.09 0.12 0.27 0.08 Hydrogen, cc/kg 32.4 21.1 27.3 32.2 28.0 Lithium, ppm 2.34 2.06 2.21 2.34 2.06 Boron - 10, ppm*
146.8 99.8 115. 7 199.7 181.5 Oxygen, (DO), ppm 0.005 0.005 0.005 0.005 0.005 Chloride, ppm 0.010 0.006 0.008 0.010 0.007 pH@ 25 degree Celsius 6.85 6.60
- 6. 77 6.50 6.39
UNIT ONE:
The month began with the. unit at 100% with B Mixed Bed in service.
On 12/19/89, the unit was ramped back to 83% for a valve freedom
- test.
The reactor was tripped on 12/21 at 2156 due to rod bottom runback.
The unit was returned to criticality on 12/22 at 2243.
The unit reached 100% on 12/23 at 1918.
The following Lithium additions were made to the RCS:
350g on 12/03, 368g on 12/12, 340g on 12/18, 325g on 12/21, 470g on 12/23, 420g on 12/24, and 430g on 12/28.
UNIT TWO:
The month began with the unit at 98% with B Mixed Bed in service.
The power level was maintained at approximately 98% for the first half of the month due to problems with condensate polishing DP.
On 12/06, the unit was ramped back to 88% to clean waterboxes.
On 12/22, the unit automatically ramped down to approximately 60% from a turbine runback caused by a rod drop.
On 12/26, the unit ramped down to 85% to clean waterboxes.
The unit again ramped back to 93% for waterbox cleaning on 12/30.
The power was reduced further to 83% to maintain condenser vacuum.
The CAT Bed was placed in service for Lithium removal on 12/01, 12/06, 12/10, 12/15 and 12/21.
17 AVG.
2.llE-1 0.0
- 1. 94E-1 5.26E-4 0.12 30.5 2.18 189. 3 0.005 0.008 6.45
UNIT 1&2 NEW OR SPENT FUEL SHIPMENT#
DATE SHIPPED OR RECEIVED FUEL HANDLING NUMBER OF ASSEMBLIES ASSEMBLY ANSI PER SHIPMENT NUMBER NUMBER NONE DURING THIS REPORTING PERIOD 18 INITIAL ENRICHMENT DATE:
DECEMBER 1989 NEW OR SPENT FUEL SHIPPING CASK ACTIVITY LEVEL
DESCRIPTION OF PERIODIC TEST WHICH WERE NOT COMPLETED WITHIN THE TIME LIMITS SPECIFIED IN TECHNICAL SPECIFICATIONS MONTH/YEAR:
DECEMBER 1989 NONE DURING THIS REPORTING PERIOD 19
ATTACHMENT 2 CORRECTED PAGES SEPTEMBER, OCTOBER,
& NOVEMBER, 1989