ML20041G181

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Monthly Operating Repts for Jan 1982
ML20041G181
Person / Time
Site: Surry  Dominion icon.png
Issue date: 02/05/1982
From: Jones V, Saunders B
VIRGINIA POWER (VIRGINIA ELECTRIC & POWER CO.)
To:
Shared Package
ML20041G177 List:
References
NUDOCS 8203190363
Download: ML20041G181 (45)
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Text

i e VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION

. gNTHLY OPERATING REPORT REPORT NO. 82-01 JANUARY, 1982_ _

AreR0vEO Y:

O Ah//~Me STATION MANAGER s

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b 8203190363 820212

> PDR ADOCK 05000280 R PDR I . . . . . _ . .__.;.,_...... . . _

i Section Page, Operating Data Report - Unit #1 1 Operating Data Report - Unit #2 2 Unit Shutdowns and Power Reductions - Unit #1 3 Unit Shutdowns and Power Reductions - Unit #2 4 Load Reductions Due to Environmental Restrictions - Unit #1 8 Load Reductions Due to Environmental Restrictions - Unit #2 9 Average Daily Unit Power Level - Unit #1 10 Average Daily Unit Power Level - Unit #2 11 Summary of Operating Rxperience 12 Amendments to Facility License or Technical Specifications 17 Facility Changes Requiring NRC Approval 18

. Facility Changes That Did Not Require NRC Approval 18 Tests and Experiments Requiring NRC Approval 19 Tests and Experiments That Did Not Require NRC Approval 19 Other Changes, Tests and Experiments 20 Chemistry Report 21 Description of All Instances Where Thermal Discharge Limits Were Exceeded 22 Fuel Bandling 24 Procedure Revisions That Changed the Operating Mode Described in the FSAR 26 Description of Periodic Tests Which Were Not Completed Within the Time Limits Specified in Technical Specifications 27 l

Inservice inspection 28 Reportable Occurrences Pertaining to Any Outage or Power Reductions 29 Maintenance of Safety Related Systems During Outage or Reduced Power Periods - Unit #1 - Mechanical Maintenance 30 Maintenance of Safety Related Systems During Outage or Reduced Power Periods - Unit #2 - Mechanical' Maintenance 32 l

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Section a Page, Maintenance of Safety Related Systems During Outage or Reduced Power Periods - Unit #1 - Electrical Maintenance 34 Maintenance of Safety Related Systems During Outage or Reduced Power Periods - Unit #2 - Electrical Maintenance 36 Maintenance of Safety Related Systens During Outage or Reduced Power Periods - Unit #1 - Instrument Maintenance 38 Maintenance of Safety Related Systems During Outage or Reduced Power Periods - Unit #2 - Instrument Maintenance 40 Health Physics Summary 42 Procedure Deviations reviewed by Station Nuclear Safety and Operating Committee af ter Time Limits Specified in T. S. 43 e

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OPERATING DATA REPORT DOCKET NO. 50-280 DATE 08 FEB 82 COMPLETED BY Vivian H. Jones TELEPHONE 804-357-3184 QPERgTING STATUS

1. UNIT NAME SURRY UNIT 1
2. REPORTING PERIOD 10182 T0 13182:
3. LICENSED THERMAL POWER (MWT) 2441 1
4. NAMEPLATE RATING (GROSS MWE) 847.5 NOTES l
5. DESIGN ELECTRICAL RATING (NET MWE) 788
6. MAXIMUM DEPENDABLE CAPACITY (GROSS MWE)811
7. MAXIMUM DEPENDABLE CAPACITY (NET MWE) 775
8. IF Cl!ANGES OCCUR IN CAPACITY RATINGS N/A (ITEMS 3 THROUGil 7) SINCE LAST REPORT

, GIVE REASONS

9. POWER LEVEL TO WHICil RESTRICTED, IF ANY N/A (NET MWE)
10. REASON FOR RESTRICTIONS, IF ANY N/A TilIS MONTH YR-TO-DATE CUMULATIVE
11. HOURS IN REPORTING PERIOD 744.0 744.0 79872.0
12. NUMBER OF IIOURS REACTOR WAS CRITICAL 688.7 688.7 46723.2 13.. REACTOR RESERVE SHUTDOWN HOURS 0.0 0.0 3731.5
14. HOURS GENERATOP ON-LINE 685.6 685.6 45760.4
15. UNIT RESERVE SHUTDOWN HOURS 0.0 0.0 3736.2
16. GROSS TIIERMAL ENERGY GENERATED (MWil) 1593217.5 1593217.5 105926483.9
17. GROSS ELECTRICAL ENERGY GENERATED (MWH) 493860.0 493860.0 34313073.0 i
18. NET ELECTRICAL ENERGY GENERATED (MWH) 467662.0 467662.0 32544898.0
19. UNIT SERVICE FACTOR 92.2% 92.2% 57.3%
20. UNIT AVAILABILITY FACTOR 92.2% 92.2% 62.0%
21. UNIT CAPACITY FACTOR (USING MDC NET) bl.1% 81.1% 52.6%
22. UNIT CAPACITY FACTOR (USING DER NET) 79.8% 79.8% 51/7%

l 23. UNIT FORCED OUTAGE aATE 7.9% 7.9% 24.6%

l 24. SHUTDOWHS SCIIEDULED OVER NEXT 6 MONTHS SPRING MAINT. 02-82-10 DAYS (TYPE, DATE, AND DURATION OF EACH)

! 25. IF SHUT DOWN AT END OF REPORT PERIOD, j ESTIMATE DATE OF STARTUP i 26. UNITS IN TEST STATUS FORECAST ACllIEVED l (PRIOR TO COMMERCIAL OPERATION)

INITIAL CRITICALITY l INITIAL ELECTRICITY l COMMERCIAL OPERATION l

OPERATING DATA REPORT DOCYFT NO. 50-281 DATF 09 FEP 82 C0YPLFTED BY Vivian H. Jones TELEPHCli! 804-35?-318n CFERATIhG STATUS

1. UliiT 11Ar'E SURRY UNIT 2
2. REPOR'*II.G PERIOD 10182 TC 13182
3. LICENSFD T4FBIAL FCVER (WT) 24~1 l ~~ ~~~~ ~~ ~~ ~ ~ l
n. .b A4FPi,ATF RATING (GROSS WE) 847.5 l NOTES l S. DESIGN ELSCTRICAL RATIt!G (NET NWh) 188
6. FAXiO' DSPFNDABLE CAPACITY (GROSS WF) 811
7. VAXTVUt.' DEPENDABLE CAPACITY (NFT WF) 775
8. IE CHANGES OCCUR IN CAPACITY RATINGS ll/A (IT5v3 3 T4 ROUGH ~1) SINCE LAST EEPORT, GIVE REASONS
9. PC.r?R LEVEL TO VHICH RFSTRICTED, IF ANY N/A (KET WE)
10. LFASat!S FOR RESTRICTI0llS, IF ANY N/A THIS MONTH YR-TO-DATF CU.VULATIVF
11. I! CURS Ih REPORTING PERIOD 744.O 744.0 16752.O
12. buv9FR OF HOURS RFACTOR WAS CRITICAL 740.1 740.1 45600.8 13.1.EA: TOP hESERVF SHU'"DCk'N NCURS O.O O.O O.O in. NCURS GETERATOR 04-LIllE 730.4 736.4 44842.1
15. UhET RESh5VE SHUTDCL7: HOURS 0.0 0.0 0.0
15. GI. CSS THERVAL Fl!ERGY GENERATED (WH) 151?173.8 1517173.8 10sB1n459.7 1?. Gh0SS ELECTRICAi, EllERGY GENERATED (WH) n81855.0 n81855.0 34159034.0
18. NET RLFCTRICAL E!!FRGY gel /FRATED (W4) 451909.0 451909.0 3238062s.O
19. [7.IT 3FRVICE FACTOE 98.2 e/o 98.2 e/o 58.4 e/o
20. Uh!T AVAILABILITY FACICR 98.2 e/o 98.2 */* 5R.4 */o
21. UhTT CATA:ITY FACTOR (USING \lDC NFT) 78.4 */* 18.4 */* Sn.n */*
22. Ct.II CAFACITY FACTOR (USING DER flET) 77.1 */* 77.1 ele 53.5 e/o
23. Uh ET F0hCED OUTAGF RATF 1.9 */o 1.9 */o 20.6 */o 2.e . SliUTDXAS SCHEDULTD OVER NEXT 6 MONTHS SPRING A'AINT-05-07-82-10 DAYS (STFE,DATE, A?ID DURATIOl} OF EACH)
25. IF SHUT COVN AT END OF RFPORT PERIOD, EC'4 ATE DATF CF ETARTUP
26. UNITS IN TEST STATUS FORFCAST ACHIEVFD (EETOR 70 Cavr'FRCIAi, OPERATI0t))

INETIAi, CRITICALITY lliETIAi, FLFCIRICITY C04NERCIAi, CPERATION O

1 . .

DOCKET NO. 50-280 .

UNIT SHUTDOWNS AND POWER REDUCTIONS UNIT N AME Surry One ,

DATE 02-05-82 REPORT MONTH January, 1982 COMPLETED BY Vivian H. Jones TELEPHONE (804) 357-3184 ext. 477 "i

No. Dale

.! E 3g 3

i

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,3 g E Licensee Eveni y E

4 k Cause & Correceive Action to

[ vO U F

fI E j i?3 g Reptw e g Present Recurrence 6

82-1 01-05-62 F 58.4 H I Fire in ground straps on isolated phase bus ductwork caused by induced current. Unit was shutdown and

- ductwork and ground straps were replaced prior to startup.

82-2 01-26-82 F 0.0 H 4 Dropped rod B-6 due to fault in the e power supply cable. This caused a T turbine runback to 70% power. The fault was repaired and the rod was withdrawn and power was returned to 100%.

l 2 3 4 F: Forced Reason: Method: Exhibit G . instructions S: Scheduled A Equipment Failure (Explain) 1-Manual for Preparation of Data B-Maintenance of Test 2-Manual Scram. Entry Sheels for Licensee C Refueling 3 Automatic Scram. Event Repix (LER) File (NUREG-D Fegulatory Restriction 4-Other (Explain) 0161)

E-Cperator Training & License Examination F.AJministrative 5 G. Operational Error (Explain) Exhibii I- Same Source t'8/77 ) Il-Other (Explain)

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UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-281 UNIT NAME Surry Two -

DATE 02-05-82 REPORT MONTil January, 1982 COMPLETED ay Vivian H. Jones .

TELEPHONE (804) 357-3184 ext. 477 -

w E

!E "h j EE Licensee E g*3

., Cause & Corrective No. Date h 3g @ jg5 Event g'ir 5- Action to H

cs E 5 jgg Report # mu

[u Present Recurrence c5 82-1 01--01-82 S 0.0 H 4 Return of Unit following refueling is limited to 3% per hour rate of power Increase.

82-2 01'-02-82 F 4.1 H 3 Unit tripped on "6B" FW Htr. High Level turbine trip signal. No cause for the high level could be determined i The "5B" and "6B" FW Htrs were i isolated and bypassed after unit startup. This required Unit power be limited to 90%.

  • 82-3 01-04-82 F 0.0 H 4 Experier$ced condenser vacuum decrease due to air leakage. Stopped leak and returned Unit to 90% power.

i I

I 2 3 4 F: Forced Reason: Method: Exhibit G . instructions S: Stheduled A-Equipment Failure (Explain) 1-Manual for Preparation of Data B-Maintenance of Test 2-Manual Scram. Entry Sheels for Licensee C Refueling 3 Automatic Scram. Event ReporI(LER) File tNUREG.

D Regulatory Resiriction 4-Other (Explain) 0161)

E-Operator Training & Ucense Examination F Adminisitative 5 G Operational Error (Explain) Eshibit I . Same Source I'l/77) Il Other (Explain)

s UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-281 UNIT NAME Surry Two DATE 02-05-82 REPORT MONT11 January, 1982 COMPLETED 8Y Vivian H. Jones .

TELEPHONE (Bole) M 7-11814 s.xt. 477 e.

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.IE 3 y EIi Licensee Eg k g'8 Cause & Correceive No. Date k 5g @ 23E Event p 6-u Action to F

$5 5 j gg g Report # mO g Preveni Recurrence 6

82-4 01-05-82 F 0.0 H 4 S/G cation conductivity levels exceeded allowable concentrations.

Power was ' reduced to 35% I AW applicable action statements. The condenser tube leaks were plugged and S/G cation conductivity was reduced to an ,

acceptable level prior to power y escalatlon.

82-5 01-07-82 F 9.5 H Lost EHC system pumps causing a .

turbine trip - reactor trip. Repair <

EHC system leak prior to startup.

I 2 3 4 F: Forced Reason: Method: Exhibit G. Instructions -

S: Scheduled A Equipment Failure (Explain) I-Manual . for Preparation of Data B-Maintenance of Test 2-Manual Scram. Entry Shecis for Licensee C Refueling 3. Automatic Scram. Event Repore (LER) File (NUREG-D Regulatory Restriction 4 Other (Explain) 0161)

E-Operator Training & License Examis.ation F Administrative 5 G Operational Ersur (Explain) Exhibis 1 Same Source '

l'8/77) Il-Other (Explain)

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UNITSHUTDOWNS AND POWER REDUCTIONS DOCKET NO.50-28I UNIT NAME Surry Two .

DATE 02-05-82 REPORT MONTH January. 1982 COMPT.ETED BY Vivian H. Jones ,

, TELEPHONE (804) 18;7-118h ext . 477 -

w E

.I E 3 jI} Licensee Eg h4 Cause & Corrective p E- Action in EE f]

Wa- . Date { I .i! E a: Event H

$5 5 j;5g Repor # mO Prevent Recurrence 6

82-7 01-18-82 F 0.0 H 4 Turbine runback on loss of "E" transfer Bus power supply to the 2J.

Bus. An unexplained runback occurred during recovery from the first runback. The loss of "E" transfer Bus was caused by a fault in the ,

cables on the "high side" of the "B"

! i RSS transformer. These cables were

! replaced.

82-8 01-23-82 S 0.0 H 4 Reduced power to return "5B" an["6B" FV Htrs. to service after plugging leaking tubes in the "6B" FW Htr.

r i 2 3 4 F: Forced Reason: Method: Exhibli G . Instructions S: Scheduled A Equiprnent Failure (Explain) I Manual for Preparation of Data B Maintenance of Test 2 Manual Scram. Entry Shecis for Licensee C Refueling 3-Automatic Scram. Eveni Report (LER) File (NUREG-D Regulatory Resiriction 4-Other (Explain) 0161)

E-Operator Training & Ucense Enamination F Adnunistrative 5 G-Operational Error (Explain) Eshibis 1 Same Source i9/77) Il-Oiher (Explain)

DOCKET NO.50-28I -

UNIT SIIUTDOWNS AND POWER REDUCTIONS UNIT NAME Surry Two ,

I DATE 02-05-82 COMPLETED By Vivian H. Jones REPORT MONTig January , 1982 TELEPHONE (804) 157-1184 ext. 477 .

~

~

jE Licensee Eg h Cause & Corrective No. D.ite g k [ Event . 'ie E.4 1 Action to

,  :. 5 a .E 5 cc

" j di { N0 c5 E 8E Rer*4 8 fU Prevent Recurrence 6 .

82-10 01-31-82 S 0.0 H 4 Load followed on Instruction of the system operator.

I 2 3 4 F: Forced Reason: - Method: Exhibit G Instructions S: Scheduled A Equipment Failure (Explain) 1-Manual for Preparation of Data B. Maintenance of Test 2 Manual Scram. Entry Sheets for Licensee C Refueling 3 Automatic Scram. Event ReporI (LER) File (NilREG.

D Regula ory Restriction 4 Other (Explain) 0161)

L E Operator Training & License Examination 5

l F Adnnnistrative G-Operational Error (Explain) Exhibit I Same Source l

j l'8/77) Il-Other (Explain) l l *

. . LOAD REDUCTIONS DUE TO ENVIRONMENTAL RESTRICTIONS UNIT NO.1 MONTH: January, 1982 DATE TIIE HOURS LOAD, MW REDUCTIONS, NW MWH REASON NONE DURING THIS REPORTING PERIOD.

e MONTHLY TOTAL

9 LOAD REDUCTIONS DUE TO ENVIRONMENTAL RESTRICTIONS UNIT NO. 2 MONTH: Jan ua ry , 1982 4

DATE TIME HOURS LOAD, MW REDUCTIONS, MW MWH REASON NONE DURING THIS REPORTING F ERIOD.

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MONTHLY TOTAL

. . DOCKET NC 50-280 UNIT SURRY Z DATE 2-1-82 COvPLETFD BY Vivian H. Jones AVFRACF DAILY UllIT POVFR Ls' VFL Va7"E: JACUARI 82 AVERACT DAILY POUFR LEVEL AVERACF DAILY POVER LRVFL DAY ( WF-NET) DAY (WF-NET) 1 721.5 17 716.4 .

2 723.0 18 7 18 .7 3 722.7 19 718.3

  • 721.0 20 718.1 5 573.0 21 718.6 6 0.0 22 716.6 7 0.0 23 715.0 8 2'3.0 24 721.2 9 702.3 25 -

719.9 10 719.1 26 716.7 11 718.3 27 491.4 12 ?18.7 28 485.9 13 718.1 29 486.2 1* 715.3 30 668.9 15 716.2 31 7 17.8 16 713.5 DAILY UN:T FCAER !EVEL FDP' INSTRUCTIONS C': 5'!'IF 70Lv LIST THF AVFFAGF DAILY Ul:IT POVFR EFVEL I:l WF-NFT FCR FACP DAY IN TVE FFFWICC N0!:TH. THESE FIGURPS k'ILL EF USED TO PLOT A GRAP4 FOR FAC4 RrTORT-I73 VCliT7. NCTF THAT BY USII;G VAXI,L71v DEPENDASLF CAPACITY FOR T9F i;FT FLFCIRICAL RATICG OF, S'EF UNIT, THERE VAY BF CCCASIOUS VHE!! T4F JAILY AVFPAGE POVER EXCFFDS I?F 100 */* LINE (CR THF RKSTRICTED P.TFS LCVEL LINF). IN SUCP CASFS, THE AVFRAGF DA!LY UVIT F0dFR CUTPU" SHEET 5900LD FF FCOTNCTED TC EXPLAIN THE APPARF?lT ANovALY.

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. . DOCKET NC 50-2R1 UNIT SURRY II DATF 2-1-82 COYFLFTFD BY Vivian H. Jones AVERAG=' DAILY IMIT PCm'FR UVFL 42NTE: .1A!!UARY B2 AVFEAGE DAILY POWER LFVFL AVFRACF DAILY POVFR LFVFL DAY (WF-NFT) DAY (WF-NFT) 1 379.6 17 672.3 2 . 306.8 18 60*.7 3 567.5 19 665.3

  • 502.0 20 663.0 5 469.3 21 667.0 6 303.6 22 666.6 7 23*.0 23 649.1 8 632.5 2* 715.7 9 627.1 25 747.9 3C 628.5 26 7*R.1 11 628.0 27 7*5.0 12 627.4 28 70*.3 13 625.4 29 732.2 1* 630.9 30 749.2 15 665.6 31 602.5 16 669.4 i

DAILY UVIT F0e'FP LFVFL FORY I!!STEUCTIC?lS OY,' TIS FCRY. LIST THF AVFRACF DAILY Ul:TT POWER LEVEL IN 'A'F-NFT FOR FACH DAY I?:

T.7517PC.7TI?.C XO?.'TH. T4FSF FICURFS VILL PF-USED TO PLOT A GRAPH FOR FAC'l REPORT-I'l0 '01.T.T. ACTF THAT RY USI'iG A' AXIS'Ur' DFPFCDABLF CAPACITY FOR T4F NFT FLFCTRICAL FATIIC OF THE UNTT. THERF XAY PF OCCASIONS W4Fl! THE DAILY AVFRACF FS*FR FXCFFDS TVS 100 */o lid! (CF THE RESTRICTFD ">?FE LFVFL LI4F). IN SUCP CASES. T!!F AVERACF DA:51 UVIT FCWFR Cl!TPUT S4FFT SHOU s'. PF FOOTNOTFD TO FXPLAIN THE AFPARF?iT .**:D'ALY.

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SUMMARY

OF OPERATING EXPERIENCE January, 1982 4

Listed below in chronological sequence by unit is a summary of operating experiences for this month which required load reductions or resulted in significant non-load related incidents.

UNIT ONE January 1 This reportina period begins with the Unit at 100% power.

January 2 The "A" RSS transformer load exceeded 2000 amperes at 0135 due to a reactor trip on Unit 2. The load on "A" RSS transformer decreased to less than 2000 amperes at 0720 when Unit 2 was transferred to "A" SS transformer.

January 5 At 1650, a fire was reported on the isolated phase bus duct ground straps. The decision was made to allow the -

fire to burn itself out. A power reduction commenced at 1704. The fire was out at 1719 The generator was taken off the line at 2052 to allow work on the isolated phase bus ductwork. At 2058, a safety injection occurred on a header to line AP signal. Investigation of the cause of the Si has concluded that vibration of the header pressure transmitters caused by lifting the turbine crossunder safety valves initiated the spurious 51. The reactor coolant system was borated to the Xenon-free hot shutdown boron concentration at 2345 January 6 Rod J-9 did not move while pulling the "B" shutdown bank at 1825 Reinserted "B" shutdown bank to investigate problem.

January 7 The load on "A" RSS transformer exceeded 2000 amperes at 0140 due to a reactor trip on Unit 2. The electricians found a faulty connector pin on rod J-9 and repaired it.

l Rod J-9 returned to operable status at 0514. The "A" RSS transformer load was <2000a at 1135 when Unit 2 was l transferred to the "2A" SS transformer. The isolated phase bus ductwork repairs were completed at 1800.

January 8 The reactor was critical at 0420 and the generator was placed on the line at 0715 At 1000, decreased the rate of power increase to 3% per hour. Stopped the power increase at 70% power to perform a secondary calorimetric l and a primary leak rate test. At 1820 commenced increasing l power at 3% per hour.

January 9 The Unit reached 100% power at 0625 l

January 26 At 2331, rod B-6'in Control Bank A dropped causing a turbine runback. The plant was stabilized at 70% power and 545 MWe.

  • . 1 33

SUMMARY

OF OPERATING EXPERIENCE January, 1982 (continued)

UNIT ONE January 27 At 0312, all high flux rod stops had been reset from 103%

to 78% and all high flux trip setpoints from 107% to 82%

I AW T.S.-312 to compensate for the 12% tilt caused by dropped rod B-6. At 0353, all attempts to retrieve dropped rod B-6 had been unsucheisful,' and the electric 1ans' were continuing their investigat,lon of the problem.

January 28 The electricians found a broken wire in the power supply cable to rod B-6 at 2303 The break was in the electrical penetration area inside the containment.

January 29 The repairs to the broken lead for rod B-6 was repairsd and retrieval of the rod began at 0037 The retrieval was at a rate of 15 steps per hour to minimize potential flux problems. At 1537, rod B-6 was fully withdrawn f rom the core (228 steps) . An incore detector flux map was completed indicating high flux rod stop and high flux trip setpoints could be increased to 94% and 98%

respectively. The setpoint changes were completed at 2250 and a power increase at 3% per hour was begun at 2300.

January 30 An incore detector flux map was compeleted Indicating the high flux rod stop and high flux reactor trip setpoint could be increased to their normal values (103% and 107%

respectively). The Unit reached 100% power at 1300.

January 31 This reporting period ends with the Unit at 100% power.

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SUMMARY

OF OPERATING EXPERIENCE January, 1982 (continued)

UNIT TWO January 1 This reporting period begins with the Unit at 40% power and increasing at 3% per hour with the incore detector flux maps scheduled at 10% intervals.

January 2 A high water level in the "6B" feedwater heater caused a turbine trip which in turn tripped the reactor at 0140.

The reactor was critical at 0407 and back on the line at 0548.

Stopped increasing power at 1930 with the reactor at 72% power until the problem with the "6B" FW Htr level can be resolved. Decreased power to 69% at 2005 and commenced incore-excore flux detector calibrations.

The incore-excore cal". ations were completed at 2335 January 3 Started increasing psoer at 0333 at 3% per hour after removing the 6B and SB FW Htrs from service and bypassing them.

Stopped power increase at 1220 at 90% power until 5B & 6B FW Htrs are returned to service.

January 4 Experienced condenser vacuum problems and reduced power at 0105 to maintain condenser vacuum. Stopped reducing power at 53% /300 MWe at 0147 The condenser vacuum problem was determined to be leakage through a drain line from a steam trap which a welder had cut to replace a valve.

per hour The beganleakatwas stopped and a power increase at 3%

0200. At 1420, power was decreased from 84 to 80% in anticipation of stopping the "A" Main Feedwater Pump to fix an oil leak on the outboard motor bearing. The leak was determined to be on the bearing oil return drain

lineMFP.

"A" and could be temporarily repaired without stopping l Temporary repairs were completed and a power Increase was began at 1700. Power reached 90% at 2100.

January 5 The chemist reported increasing sodlum concentration in the condensate system at 1100. Investigation of the source of the sodium inleakage pointed to the condenser water boxes as the source. "B" waterbox was removed from service to check for a possible tube leak at 1210. At 1220, started reducing power at 150 MWe per hour due to i

high sodium levels in the system and subsequent break through of the condensate polishing demineralizers. r power decrease was stopped at 1351 at 64%. This powerThe level allowed removal of the depleted demineralizers without the necessity of bypassing any condensate flow around the condensate polishing demineralizers. At 1445, it was determined no leak existed in was returned to service. At 1454 "A" "B" waterbox and it waterbox was I removed from service to check for a possible tube leak.

At 1845, it was determined that steam generator cation conductivity would not decrease to <2.0 micrombos prior to the end of the eight hour period allowed under the Action Level I statement of Abnormal Procedure 33 and a

SUMhARy 0F OPERATING EXPERIENCE January, 1982 (continued)

UNIT TWO January 5 power decrease to 35% at 150 MWe per hour was begun.

The Unit reached 35% power at 2010.

Janaury 6 The leaks in "A" waterbox were located and plugged and the waterbox was returned to service at 0241. The chemistry problems were resolved and a power increascat 150 MWe per hour was begun at 1336. At 1620, the rate of power increase was reduced 3% per hour.

Jarsary 7 The reactor tripped from 87% power at 0140. The trip was a result of the loss of electro hydraulic control fluid through a blown disharge flange on an EHC pump, which caused a turbine trip. The reactor was critical at 0313 and on the line at 1113 The power increase was stopped at 1151 at 35% power to get secondary chemistry in specification. The chemistry was satisfactory and a power increase was begun at 1538.

Janaury 8 The unit reached 90% power at 0115 This is the maximum allowable power level with the "5B" & "6B" FW Htrs isolated and b /passed. The power level was reduced to 85% while the instrement technicians and engineers investigated the reason for the HIGH STEAM LINE FLOW ALARMS being received.

January 14 The engineers and instrument technicians determined the HIGH STEAM LINE FLOW ALARMS were being caused by " noise" The " noise" problem was resolved and a power increase began at 1755 The unit reached 90% power at 1940.

January 18 The Control Room Operator determined the reactor coolant system leak rate was greater than the allowable rate of one gallon per minute at 1345. An immediate Investigation was begun to locate and isolate the source of the increased leakage. At 1401, the "E" Transfer Bus supply breaker opened causing a turbine runback. The runback was a result of a spurious dropped rod signal from the N-41 excore detector. N-41 " sad' the momentary. loss of power on Vital Bus 2-1, during the transfer of the 2J bus from the "E"

' Transfer Bus to No. 2 Emergency Diesel Generator, as a sudden decrease of reactor power indicating a dropped rod.

The unit was stabilized at 1405 and a power increase was begun. At 1435 the turbine ranback to 35% power /200 Mwe.

There were no alarms on this second runback and no cause for it could be found. The decision was made to maintain 35%/200 MWe until the source of the unidentified leakage on the RCS was found. At 1651, the RCS leak rate was

~ I re duced to <1 GPM by isolating the normal letdown header.

The actual leak itself was subsequently found to be a leaking flange on letdown line relief valve RV-2209 At

4

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SUMMARY

OF 0?ERATING EXPERIENCE January, 1982 (continued)

UNIT TWO January 18 1731, a power increase was begun and the unit reached 90%

power at 1918. The reason the "E" Transfer Bus supply breaker opened was later determined to be a multiple fault in the "B" Reserve Station Service Transformer supply cables. -

January 20 Paralleled across 25J8, normal 2J bus supply breaker, and closed it at 1708. Increased the load on the No. 2 EDG to 2.5 MWe and ran it for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> I AW the manufacturers recommendations following extended operation at light load. Opened 25J3, No. 2 EDG output breaker and shutdown No. 2 EDG at 1912. This left the 2J bus being supplied by the 2B Station Service Bus through a backfeed arrangement.

January 23 Started reducing power at 2122 to allow return of "5B" and "6B" FW Htrs to service. Stopped power decrease at 60%

power at 2313 and began return to service of the "5B" and "6B" FW Htrs.

January 24 The "5B" and "6B" FW Htrs were returned to service and a power increase began 0026. The unit reached 100% at 0545 January 28 The discharge flange gasket on the "B" High Pressure Heater Drains Pump blew out at 1450. The pump was stopped and the leak isolated. At 1455 started reducing power to allow closing the condensate polishing system bypass MOV-CP-200 which had opened on a low main feed pump suction pressure signal. Stopped reducing power at 90%/

690 MWe at 1535

( January 29 Repairs were compeleted on the "B" H. P. Heater Drain j Pump discharge falnge and the pump was started at 0130.

l Started increasing power at 0205. The unit was at 100%

l at 0313 ,

. January 31 Started reducing power at 0018 to load follow on orders l of the system operator. Stopped the power decrease at l 0524 at 57%/455 MWe to investigate low turbine bearing l oil pressure alarm. The problem with the low L. O.

pressure alarm was a bellows leak on the turbine protection l block. The leak was repaired and a power increase was begun j at 1110. The unit reached 100% power at 1446. Started reducing power at 2235 to load follow on orders of the i

system operator. This reporting period ends with the unit at 80% power and 680 NWe.

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AMENDMENTS TO FACILITY LICENSE OR TECHNICAL SPECIFICATIONS January, 1982 i NONE DURING THIS REPORTING PERIOD.

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- 20 CCorrcetcd Copy for D1cembsr Report FACILI" CHANGES THAT DID NOT REQUIRE NRC APPROVAL DECEMBER. 1981 (continued)

Unit D/C 81-21 Change Hydraulic Tubing of Six Inch and Twelve Inch Patton Snubbers to SS (continued). 2

SUMMARY

OF SAFETY ANALYSIS This modification provides additional seismic protection for the Reactor Coolant Systan. It does not affect the station operations or the operation of safety related equipment.

D/C 81-54 Relocation of Steam Generator FW Flow Indicators 2 This design change removed the horizontal orientation of the Steam Generator Feedwater Flow Indicators and replaced them in a vertical orientation. The change provides consistency throughout the Steam Generator Section on the vertical board in the control room.

SUMMARY

OF SAFETY ANALYSIS This modification provides the operator with a consistent Steam Generator Indicator Section and does not affect the operation of any safety related equipment.~

D/C 81-58 Prevention of Tripping Trm,sfer Breaker 15F1 *1 & 2 This design change added a B.E. SAM timer in the trip circuit of transfer breaker 15F1 to prevent loss of power on Transfer Bus F for an undervoltage condition on Emergency Bus lH and Emergency Bus 2J.

SUMMARY

OF SAFETY ANALYSIS This modification does not affect the operation of any safety related equipment.

D/C 81-107 Main Steam Line Trip Valve Modification 2 This design change modified the control circuits of the Main Steam Line Trip Valves by adding a new contact deck to each of the trip valve control switches and a new limit switch to each trip valve. A new limit switch contact in series with the new control switch contact was connecttl into the existing train "B" control circuitry to provide a " seal-in" function similar to that existing in the train "A" portion of the circuit.

, . . ,,--,e% -=,

FACILITY CHANGES REQUIRING

~

NRC APPROVAL JANUARY 1982 NONE DURING THIS REPORTING PERIOD.

FACILITY CHANGES THAT

. DID NOT REQUIRE NRC APPROVAL JANUARY 1982

~

Unit D/C 81-14 LHSI & ORS Pump Casing Restraints 1 This design change replaced the teflon plugs used in the LHSI and ORS pump casing restraints. The new material now being used is TORLON. This material meets or exceeds all applicable properties of teflon. Teflon was determined not to be qualified to the calculated total integrated .

radiation dose at the pump location.

Summary Of Safety Analysis This modification will increase the reliability of the safety-related pumps during accident conditions.

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. . TES'RS AND EXPERIMENTS REQUIRING NRC APPROVAL t n January, 1982 '

NONE DURING THIS REPORTING PERIOD.

t TEST AND EXPERIMENTS THAT DID NOT REQUIRE NRC APPROVAL January, 1982 Special Test No. Unit Title Completed ST-52 2 RCS Flow Measurement Data 01-28-82 I

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January, 1982 i

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  • CHDf1STRY REPORT 3mmimrv , 19_,82_

T. S. 6. 6. 3.d PRIMARY COOLANT UNIT NO. 1 UNIT NO. 2 ANALYSIS MAXIMUM MINIMUM AVERAGE MAXIMUM MINIMUM AVERACI (A) (A) (A) E-1 E-1 E-1 Gross Radioact., UCi/mi 2.32 1.06 1.45 2.61 1.09 1.86 Suspended Solids, ppe 0.1 0.1 0.1 0.1 0.1 0.1 E-1 E-1 E-1 E-1 E-Z E-2 Gross Tritium, UCi/ml 2.07 1.46 1.74 1.53 6.57 8.38 Iodine-131, uci/mi (A) E-2 E-1 E-2 E-4 E -3 4.26 8.16 5.76 2.39 6.33 4.37 I-131/I-133 .9640 4682 .7804 1.1645 .4220 .8274 Hydrogen, cc/kg (D)

" 40.0 30.0 35.1 49.5 16.8 33.0 Lithium, ppm (B) 1.60 1.04 .68 2.30 .00 1.54 Boron-10, ppm +

243.04 138.96 .153.82 247.16 172.87 189 71 0xygen-16, ppm .000 .000 .000 .000

.000 .000 Chloride, ppm <.05 <.05 <.05 <.05 <.05 <.05 pH @ 25'C 6.78 6.01 6.53 6.75 5.25 6.24

+ Boron-10 = Total Boron x 0.196
NON-RADI0 ACTIVE CHEMICAL RELEASES, POUNDS T. S . 4 .13 . A . 6 ,-

Phosphate -

Boron 1358 i

Sulfate -

Chromate .34 50% NaOH -

Chlorine n-R: marks: (A) Indicates a possible failed fuel element Unit #1-Rx trip @2056 on 1-5-82-Rod dropped turbine runback to 70% 1-26-82 @ 2335-added 2235 g LiOH to #IRCS on 1-26-82 Unit #2-Rx trip 1-2-82 @ 0134,1-7-820 0115, 0138-Unit on line 1-7-82 @ 1113 (B) Unit #2 startup commenced without 217 Mixed Bed in service (C) The levels of these chemica chould create no adverse environmental impact (D) Reflects a unit #2 escalation in power from l startup-transient condition.

DESCRIPTION OF All INSTANCES WHERE THER!!AL DISCHARGE 1,It!ITS WERE EXCEEDED Janua ry , 1982 The thermal discharge limits were exceeded on the following dates as noted.

January 1, 1982 Exceeded 15*F AT across station

  • January 2, 1982 Exceeded 15 F AT across station
  • January 3, 1982 Exceeded 17 5 F AT across station January 4, 1982 Exceeded 17 5 F AT across station
  • January 5, 1982 Exceeded 17 5 F AT across station
  • 6 January 8, 1982 Exceeded'15 F AT across station
  • January 9, 1982 Exceeded 17 5 F AT across station January 10, 1982 Exceeded 17 5 F AT across station 6

January 11, 1982 Exceeded 23 F AT across station January 12, 1982 Exceeded 17.5 F AT across station January 13, 1982 Exceeded 17 5 F AT across station January 14, 1982 Exceeded 17 5 F AT across station 6

, January 15, 1982 Exceeded 15 F AT across station January 16, 1982 Exceeded 17 5 F AT across station 6

January 17, 1982 Exceeded 15 F AT across station January 18, 1982 Exceeded 17 5 F AT across station *

. January 19, 1982 F AT across station January 20, 1982 Exceeded Exceeded 17.517 5"F AT across station January 21, 1982 Exceeded 17 5 F AT across station 6

January 22, 1982 Exceeded 23 F AT across station January 23, 1982 Exceeded 15 F AT across station

  • January 24, 1982 Exceeded 17 5 F AT across station
  • January 25, 1982 Exceeded 17 5 F AT across station January 26, 1982 Exceeded 17 6 5% AT across station January 27, 1982 Exceeded 15 F AT across station
  • January 28, 1982 Exceeded 15 F AT across station
  • Janua ry 29, 1982 Exceeded 15 F AT across station
  • January 30, 1982 Exceeded 17 5 F AT across station January 31, 1982 Exceeded 17.5 F AT across station *
  • Indicates dates where the AT was less than or equal to 15.0 F across the station for some time during the day.

With the exception of two events these AT excursions were allowable undgr Technical Specification 4.14.B.2. One event (exceeding 23 F AT on January 11,1982) was allowable under T.S.4.14.B.1 due to exceptional power demand caused by a severe winter storm. The other event (exceeding 23 F AT on January 22, 198?.)

was reported to the NRC IAW T.S.4.14.C.I. There were no reported instances of adverse environmental impact.

The temperature change at the station discharge exceeded 3 F per hour on the following dates and for the noted reasons:

On January 2, 1982, due to a Unit 2 reactor trip; On January 5, 1982,'due to a forced shutdown on Unit 1; On January 7,1982, due to a Unit 2 reactor trip; and On January 11, 1982, due to cooling water problems as a result of a severe winter storm.

. . . DESCRIPTION OF ALL INSTANCES WHERE THERMAL DISCHARGE LIMITS WERE EXCEEDED January, 1982 h

(continued)

These events were allowable IAW T.S.4.14.5.1 or 4.14.B.2.

The temperature change at the station discharge exceeded 3 F per hour on January 22, 1982 due to problems experienced with the station intake vacuum priming system. This event was reported to the NRC LAW T.S.4.14.C.I.

There were no reported instances of adverse environmental impact.

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' FUEL HANDLING-l

' - UNIT I January, 1982

, DATE NO. OF ANSI NO. NEW OR SPENT FUEL SHIPPED / RECEIVED ASSEMBLIES PER SHIPMENT INITIAL ENRICHMENT SHIPPING CASK ACTIVITY LEVE:

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NONE DURING THIS REPORTING PERIOD.

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FUEL HANDLING UNIT 2 January, 1982 DATE NO. OF ANSI NO. NEW OR SPEhi FUEL I SHIPPED / RECEIVED ASSEMBLIES PER SHIPMENT INITIAL ENRIClOfENT SHIPPING CASK ACTIVITY LEVEL NONE DURING THIS REPORTING PERIOD.

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PROCEDURE REVISIONS THAT CHANCED THE OPERATING HODE DESCRIBED IN THE FSAR January, 1982 NONE DURING THIS REPORTING PERIOD.

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DESCRIPTION OF PERIODIC TESTS WHICH WERE NOT COMPLETEL WITHIN THE TIME LIMITS SPECIFIED IN TECHNICAL SPECIFICATIONS .

January, 1982 NONE DURING THIS REPORTING PERIOD.

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Janua ry , 1982 No inservice inspections were conducted this month on Unit One or Unit Two.

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. , . REPORTABLE OCCURRENCES PERTAINING TO ANY OUTAGE OR POWER REDUCTIONS Janua ry , 1982 NONE DURING THIS REPORTING PERIOD.

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HEALTH PHYSICS JANUARY 1982 1

There was no single release of radioactivity or radiation exposure specifically associated with an outage that accountad for more than 10%

of the allowable values in 10CFR20.

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  • A 43-PROCEDURE DEVIATIONS REVIEWED BY STATION TUCLEAR SAFETY AND OPERATING COFD!ITTEE AFTER TIME LIMITS -

SPECIFIED IN TECENICAL SPECIFICATIONS JANUARY 1982 Date SNSOC Procedure No. Unit Title Date Deviated Reviewed HMP-C-RC-009.1 2 Reactor Coolant Pump 12-23-81 01-14-82 Seals OP-5.1 2 Fillins and ventins .

12-20-81 01-14-82 the RCS EP-1 1 Reactor Trip 01-05-82 01-21-82 4

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