ML18152A485

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Monthly Operating Repts for Dec 1989 for Surry Units 1 & 2
ML18152A485
Person / Time
Site: Surry  Dominion icon.png
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)
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  • ATTACHMENT 1 MONTHL V OPERATING REPORT DECEMBER, 1989
  • POW 34-04 VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION MONTHLY OPERATING REPORT REPORT# 89-12 MPM~:~& t n ge

TABLE OF CONTENTS SECTION PAGE Operating Data Report - Unit No. 1 1 Operating Data Report - Unit No. 2 2 Unit Shutdowns and Power Reductions - Unit No. 1 3 Unit Shutdowns and Power Reductions - Unit No. 2 4 Average Daily Unit Power Level - Unit No. 1 5 Average Daily Unit Power Level - Unit No. 2 6 Summary of Operating Experience - Unit No. 1 7 Summary of Operating Experience - Unit No. 2 9 Facility Changes That Did Not Require NRC Approval 12 Procedure or Method of Operation Changes that Did Not Require NRC Approval 15 Tests and Experiments That Did Not Require NRC Approval 16 Chemistry Report 17 Fuel Handling - Unit No. 1 18 Fuel Handling - Unit No. 2 18 Description of Periodic Test Which Were Not Completed Within the Time Limits Specified in Technical Specifications 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: -----------

THIS MONTH YTD CUMULATIVE

11. Hours In Reporting Period 744.0 8760.0 149256.0
12. Number of Hours Reactor Was Critical 719.2 4272.2 92750.8
13. Reactor Reserve Shutdown Hours O O 3774.5
14. Hours Generator On-Line ---=7...,...16=-......,1- ____,4_,,.2., . ,17"'""._, 8,_ 90823.2
15. Unit Reserve Shutdown Hours O O 3736.2
16. Gross Thermal Energy Generated (MWH) -=-=17=3-=35=-=o=o-=.o,. . . -9=-=9:--:-4=55=3=6-=.o,. . . 211116803.0
17. Gross Electrical Energy Generated (MWH) 587650.0 3341730.0 68545403.0
18. Net Electrical Energy Generated (MWH) 560183.0 3170527.0 65010930.0
19. Unit Service Factor 96.3% 48.1% 60.9%
20. Unit Available Factor 96.3% ~~-=4=8""""".1'""'% 63.4%
21. Unit Capacity Factor (Using MDC Net) 96.4% 46.3% 56.3%
22. Unit Capacity Factor (Using DER Net) 95.6% ~~.....,4=5-=,9~% 55.3%
23. Unit Forced Rate 3.8% ---=-51=-."""'9'""'% 21.6%
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. 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

DOCKET NO.: 50-280

--=----.-:--.-,.--,.---

UNIT SHUTDOWN AND POWER REDUCTION UN IT NAME: Surry Un1t 1 DATE: 01/03/90 COMPLETED BY: L.A. Warren REPORT MONTH: DECEMBER 1989 TELEPHONE: 804-357-3184 x355 METHOD OF LICENSEE CAUSE &CORRECTIVE DURATION SHUTTING EVENT SYSTEM COMPONENT ACTION TO PREVENT NO. DATE TYPE(l) (HOURS) REA~ON(2) DOWN REACTOR(3) REPORT# C0DE(4) CODE(5) RECURRENT

  • 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.
  1. 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 tripped reactor.

Additional insulator stacks were added to the high side of a RSS transfonner to support feeder cable.

(1) (2) (3) (4)

F: Forced REASON: METHOD:

S: Scheduled A - Equipment Failure (Explain) 1 - Manual Exhibit G - Instructions for B - Maintenance or Test 2 - Manual Scram. Preparation of Data Entry Sheets C - Refueling 3 - Automatic Scram. for Licensee Event Report (LER)

D - Regulatory Restriction 4 - Other (Explain) File (NUREG 0161)

E - Operator Training & License Examination F - Administrative (5)

G - Operational Error (Explain)

H - Other (Explain) Exhibit 1 - Same Source

DOCKET NO.: 50-281 UNIT SHUTDOWN AND POWER REDUCTION UNIT NAME: --,s=-u-r-ry--..,...Un-.1~t""""'2---

DATE: 01/03/90 COMPLETED BY: L.A. Warren REPORT MONTH: - -DECEMBER

1989

-- TELEPHONE: 804-357-3184 x355 METHOD OF LICENSEE CAUSE &CORRECTIVE DURATION SHUTTING EVENT SYSTEM COMPONENT ACTION TO PREVENT NO. DATE TYPE(l) (HOURS} REASON(2} DOWN REACTOR(3) REPORT# CODE(4} CODE(5} RECURRENT

  • 12/22/89 F 0 A 4 N/A AA FU Control rod D-4 dropped causing turbine runback.

Fuse blew and was re-placed.

12/26/89 S B 4 N/A SG COND Ramped down to perfonn valve freedom test on main turbine and clean water-boxes *

(1) (2) (3) ( 4)

F: Forced REASON: METHOD:

S: Scheduled A - Equipment Failure (Explain) I - Manual Exhibit G - Instructions for B - Maintenance or Test 2 - Manual Scram. Preparation of Data Entry Sheets C - Refueling 3 - Automatic Scram. for Licensee Event Report (LER)

D - Regulatory Restriction 4 - Other (Explain} File (NUREG 0161)

E - Operator Training &License Examination F - Administrative (5)

G - Operational Error (Explain)

H - Other (Explain) 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 DOCKET NO.: --=-:,__,;::_..:,_;:.,..,....-,-.,.--,,--

50-281 UN IT NAME: Surry Unit 2 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) 1 752 17 785 2 747 18 785 3 757 19 784 4 748 20 784 5 770 21 783 6 735 22 724 7 752 23 781 8 782 24 780 9 783 25 781 10 783 26 710 11 783 27 783 12 783 28 783 13 784 29 783 14 783 30 741 15 785 31 781 16 785 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.

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 This reporting period started with the Unit at 100% power, 830 MW.

12/19/89 1217 Started rampdown for PT-29.1, 100% power, 830 MW.

1342 Stopped ramp, 85% power, 700 MW.

1707 Started rampup, PT-29.1, 82.8% power, 700 MW.

1937 Stopped ramp, Unit at 100% power, 830 MW.

12/21/89 2156 Reactor tripped, Unit off line. 1 D1 transfer bus lost 1 A'

reserve station service fault.

12/22/89 1759 Commenced reactor startup.

2112 Tripped rods, 'D bank overlap problems.

1 2157 Commenced pulling rods, reactor startup.

2243 Reactor critical.

2310 Pressurizing main steam, reactor/plant startup. 2% power.

12/23/89 0151 Unit on line and ramping, 15% power, 40 MW.

0259 Stopped ramp up, IRPI adjust, 30% power.

0352 Started ramp up, IRPI adjust, 30% power.

0517 Stopped ramp up, placed secondary systems in service 1-FW-P-lA, recirculation valve problems, 62% power, 490 MW.

0541 Ramped down, 18 feed pump amps high.

1158 Started rampup, 1-FW-P-lA started, 60.4% power, 480 MW.

1234 Stopped rampup for PT-35, 70% power, 560 MW.

1354 Started rampup.

1518 Stopped rampup, polisher differential pressure high, 90.2%

power, 735 MW.

1549 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 Started ramp down, Hi loop 1 C1 differential temperature, 830MW.

0835 Stopped ramp, Hi differential temperature clear, #2 governor valve drifting, 98.5% power, 810 MW.

0959 Started rampup 1050 Stopped ramp, Unit at 100% power, 825MW.

12/31/89 2400 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.

0910 Rampdown, removed 20 polisher, maintain differential pres-sure.

0950 Stopped ramp, polisher differential pressure~ 35 psi, 95%

power, 785MW.

12/02/89 2230 Started rampup, polisher strainers clean.

2310 Stopped ramp, polisher differential pressure~ 42 psi, 97%

power, 800MW.

12/03/89 1130 Started rampdown, polisher differential pressure high, 97.5%

power 805MW.

1135 Stopped ramp, 43 psi polisher differential pressure, 96.5%

power, 800MW.

2300 Ramped down, polisher differential pressure, 95.5% power, 790MW.

12/04/89 2045 Started rampup, polisher differential pressure good.

2225 Stopped ramp, reactor coolant differential temperature A &B high, 98.5% power, 805MW.

12/05/89 1650 Ramped up, differential temperature reset, 99% power, 810MW.

2105 Ramped up, polisher building 43 lbs, 100% power, 815MW.

12/06/89 1229 Started rampdown, clean waterboxes, 100% power, 820MW.

1323 Stopped rampdown, 1 0 1 waterbox out of service, 88% power, 720M~/.

12/07/89 0321 Started rampup, all waterboxes cleaned.

0418 Stopped ramp up, condensate polishing differential pressure 44 psi, 1 C1 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 Ramped up, condensate polishing differential pressure good, 97.5% 800MW.

0105 Stopped rampup, condensate polishing differential pressure 45 psi, 100% power, 825MW.

12/15/89 1443 Started rampdown to 99% power, Instrument tech. to work dif-ferential temperature on channels 2 and 3.

1444 Stopped rampdown/started ramp up, differential temperature satisfactory, 99.5% power, 820MW.

1450 Stopped ramp, unit at 100%, 825MW.

12/22/89 1705 Runback, dropped rod D-4.

1718 Plant stable after runback, rod D-4 blown fuse, 57% power 420MW.

1832 Pulled dropped rod, D-4 at 225 steps.

1851 Started rampup.

1928 Stopped rampup, adjust IRPis, 67% power.

1940 Started rampup, IRPis adjusted.

2130 Stopped ramp, Unit at 100% power, 815MW.

12/24/89 0831 Started rampdown, canal level decreasing, 825MW.

0856 Stopped ramp, ice at low level/canal level stable, 98% pow-er, 800MW.

1006 Started rampup, canal level steady.

llOO Stopped rampup, canal steady, 100% power, 825MW.

12/26/89 0934 Started rampdown, PT-29.1, waterbox cleaning.

1041 Stopped rampdown, 85% power, 705MW.

1258 Started rampdown, unable to remove 1 0 1 waterbox.

1328 Stopped rampdown, 1 0 1 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 Started rampup, PT-29.1 complete, 78% power, 660MW.

2127 Stopped rampup, unit at 100% power, 825MW.

12/30/89 1150 Started rampdown, 1 0 1 waterbox to be cleaned.

1250 Stopped rampdown, 1 01 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 1 0 1 waterbox out of ser-vice.

1720 Stopped ramp, condensate vacuum satisfactory, 83% power, 680MW.

1950 Started rampup, 1 0 1 waterbox returned to service, 700MW.

2333 Stopped ramp, unit at 100% power, 830MW.

12/31/89 2400 This reporting period ended with the unit at 100% power.

11

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 1 611 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.

EWR-89-565 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 11 C" 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 12/12/89 (Safety Evaluation #089-0048)

This modification was to maintain circuit continuity during the replacement of the test switch PC-4570 in accordance with Work Order #086994.

12

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 1 A1 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.

EWR-89-628 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 12/14/89 (Safety Evaluation #089-0049)

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 1 A1 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. 1 A1 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 12/19/89

(.Safety Evaluation #089-0055)

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

PROCEDURE OR METHOD OF OPERATION CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTH/YEAR: DECEMBER 1989 SPS-EOP 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. AVG.

Gross Radioact., µCi/ml 8.46E-1 7.45E-2 6.73E-1 2.75E-1 2.65E-2 2.llE-1 Suspended Solids, ppm 0.0 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 1. 94E-1 Iodine-131, µCi/ml 3.74E-1 2.82E-3 4.05E-2 1. lOE-3 2.79E-4 5.26E-4 Iodine-131/Iodine-133 0.17 0.09 0.12 0.27 0.08 0.12 Hydrogen, cc/kg 32.4 21.1 27.3 32.2 28.0 30.5 Lithium, ppm 2.34 2.06 2.21 2.34 2.06 2.18 Boron - 10, ppm* 146.8 99.8 115. 7 199.7 181.5 189. 3 Oxygen, (DO), ppm 0.005 0.005 0.005 0.005 0.005 0.005 Chloride, ppm 0.010 0.006 0.008 0.010 0.007 0.008 pH@ 25 degree Celsius 6.85 6.60 6. 77 6.50 6.39 6.45

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

UNIT 1&2

  • FUEL HANDLING
  • DATE: DECEMBER 1989 NEW OR DATE NUMBER OF NEW OR SPENT SPENT FUEL SHIPPED ASSEMBLIES ASSEMBLY ANSI INITIAL FUEL SHIPPING SHIPMENT# OR RECEIVED PER SHIPMENT NUMBER NUMBER ENRICHMENT CASK ACTIVITY LEVEL NONE DURING THIS REPORTING PERIOD 18

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

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