ML19350E271

Monthly Operating Rept for May 1981

ML19350E271
Person / Time
Site:	Sequoyah
Issue date:	06/02/1981
From:	Ballentine J, Dupree D TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML19350E268	List: ML19350E267 ML19350E271
References
NUDOCS 8106170224
Download: ML19350E271 (18)

Text

- -

O s

TENNESSEE VALLEY AUTHORITY t DIVISION OF NUCLEAR POWER SEQUOYAH NUCLEAR PLANT MONTHLY OPERATING REPORT MAY 1, 1981 - MAY 31, 1981 i

DOCKET NUMBER 50-327 .

LICrNSE NUMBER DPR-77 '

Submitted By: 4 io . 11 t ILt 0 f '- Plant gSufferintendent J

e t

, 8106l'l0 N

d J

1 s

TABLE OF CCNTENTS Operations Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2 PORV's and Safety Valves Snanna ry . . . . . . . . . . . . . . . . . . . . 2 Offsite Dose Calculation Manual Changes ....... .. . .. .. . . 2-4 Significant. Operational Events . . . . . . . . . . . .. . ...... . 5-6 Average Daily Unit Power Level . . . . . . . . . . . . . . . . . . . . . 7 Operating Data Report . . . . . . .. . ... ... .. . . .. . ... 8 Unit Shutdown and Power Reduction ... . . . , . , . . ... ..... .9 Plant Maintenance Summary . . . .... ...... . . .. .... . . 10

. Outage Maintenance Summary . . .... . ... ... ... .. ... . . 10-11 Documentation for ODCM Changes . . ... . ..... ... ... .. . . . 12-16 i

- . . . . . , , . _ .m. _ , . - _ . . . .._._..._ , , ,._.,. . ,_,, _ , . __ _ _ _ . . . , _ , , ,. , . _ _ . . _ , , , , , , , . , . , , . ~ . _ _ _ . . . . . . . _ . . _ _ . , _ _ - .

Operations Summary May, 1981 The following summary describes the significant opSrational activities for the month of May. In support of this summary, a chronological log of significant events is included in this report.

There were twelve Licensee Event Reports and 3 Special Reports during May.

There were two scrans during May. .

Unit I was critical for 446.2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, produced 418,430.MWH (gross) with 4.39 percent station use, resulting in an average hourly gross load of 953,505 KW during the month. The net heat rate for the month was 10,730 BTU /KWH.

There are 293.61 full power days estimated remaining until the end of cycle 1 fuel. With a capacity factor of 85 percent the target EOC exposure would be reached May 11, 1982. The capacity factor for the month was 46.8 percent.

Unit 1 May 1 at 0001 brs, the reactor was in mode 3, it was taken critical at 0537 hrs and the unit tied on line at 0735 hrs. The reactor obtained 100%

power producing 1100 MW(e) at 2200 hrs. At 2305 the reactor scramed (Reactor Trip #13) as the result of a manual generator trip required for Start-Up Test 9.4B. The unit experienced a safety injection when the steam driven auxiliary feedwater pump continued feeding cold water to the steam generators after the component cooling water and reactor coolant pumps tripped, creating a steam generator AP safety injection signal. ,,

On May 2 at 1758 hrs., the reactor was again taken critical and the unit tied on line at 2004 hrs. At 1225 hrs. on May 9, preparations were made to bring the unit down to investigate and repair leaks inside containment. At 1600 hrs., began load reduction to bring unit off line. The turbinc was taken off line at 1842 hrs. and the search was started to locate the leak inside containment. On May 10 at 1600 hrs., began cooldown to 300'F to verify the leak is on the #3 steam generator manway's. At 0305 on May 11, the leaks were verified on the #2 and #3 steam generators top manway's. May 11 at 1330 hrs., the reactor was taken to mode 5 to repair the leaks on the steam generators and other maintenance items. On May 14 at 1130 hrs., repairs were completed on the steam generators.

May 17 at 1605 hrs.,.the reactor entered mode 4 and .emperature increased to 300*F and held for steam generators soaks. The reactor was taken critical at 0733 brs. on May 20 and the turbine tied on line at 1030 hrs. At 0430 hrs.

May 21, began increasing load from 30% after holding for chemical parameters to come into specification. On May 28 at 1700 hra., began decreasing load to 30% due to secondary chemistry limits out of specifications. 0957 hrs. on May 30, load was increased to 100% after secondary chemistry was declared acceptable. .

Operations Summary (Continued)

May 31 at 0112 hrs., the reactor tripped (Reactor Trip #14) and experi-enced a safety injection caused by a Lo pressurizer pressure indication and radical fluctuation of the pressurizer level transmitters caused by radio transmission from the incore instrument room.

At 2359 hrs. May 31, the reactor was in mode 3.

PORV's and Safety Valves Summary No PORV's or safety valves were challenged during the month.

Offsite Dose Calculation Manual Changes Changes in the Sequoyah Nuclear Plant ODCM are described in this section in accordance with Sequoyah Technical Specification 6.1.14.

Changes 1 through 6 were officially approved by the RARC on May 20, 1981. -

See Appendix A at the end of this report for the approved ODCM page changes.

Change 1 ,_-

Description of Change Page 22a, equation 2.5 "(b y R-1)" should read "(by Rg -1)"

Analysis or Evaluation Justifying Change Subscript was unintentionally left off.

Evaluation of Accuracy of Dose Calculations or Setpciat Determinations Accuracy of dose calculation or setpoint determination is improved by this change. Equation was incorrect as written.

Change 2 Description of Change ..

Page 25, introduction to equation 2.12 "I is described by..." should t

read "I ik is described by...."

Analysis or Evaluation Justifying Change See Change 1.

Offsite Dose Calculation Manual Changes (Continued)

Evaluation of Accuracy of Dose Calculations or Setpoint Determinations Does not affect calculations.

Change 3 Description of Change ,

Page 25, the equation for relative concentration "r" should be given the number "2.13a".

Analysis r Evaluation Justifying Change Correct equation number unintentionally omitted.

Evaluation of Accuracy of Dose Cal:tiation or Setpoint Determinations Does not affect calculations.

Change 4 Description of Change th Pagegg,section2.3.2.2,line2..."....the4 .... " should read

"....the i Analysis or Evaluation Justifying Change Index letter incorrectly listed. ,

. Evaluation of Accuracy of Dose Calculations or Setpoint Determinations l

l Does not affect calculations.

Change 5 l

Description of Change i

Page 26, the equations for relative concentration and dose from cooling tower blowdown should be numbered "2.15a" and "2.15b", not "2.13a" and "2.13b".

I Analysis or Evaluation Justifying Change l

See Change 3.

{

Offsite Dose Calculation Manual Changes (Continued)

Evaluation of Accuracy of Dose Calculations or Setpoint Determinations See Change 3.

Chante 6 Description of Change .

Page 27, equation 2.18 "I f

should read "I ik '

Analysis or Evaluation Justifying Change See Change 1.

Evaluation of Accuracy of Dose Calculations or Setpoint Determinations See Change 1.

O .

l i

t l

i

Significant Operational Events Unit 1 Date Time Event 05/01/81 0001 Reactor in mode 3.

0537 Reactor taken critical 2200 Reactor obtained 100%.

2305 Reactor Scram (Reactor Trip #13) as the result of a manual generator trip re-quired for Start-Up Test 9.4B. Experi-enced a safety injection with the trip when all three component cooling water pumps and all four reactor coolant pumps tripped.

Cold water was fed to the steam generators with no reactor coolant pump flow creating a steam generator AP safety injection signal.

05/02/81 1758 Reactor taken criti, cal.

2004 Unit 1 tied on line.

05/09/81 1600 Began load reduction to bring the unit off line to locate and repair leaks

< inside containment.

1842 Turbine off line.

! 05/11/81 0305 Leaks were verified on the top manways l

of the #2 and #3 steam generators.

1100 Reactor entered mode 5.

05/17/P1 1605 Reactor entered mode 4 and held at 300*F for steam generator soak.

05/20/81 0733 Reactor taken critical.

1030 Tied on line, increased to 30% power and held for secondary chemistry to come into specification.

05/21/81 0430 Secondary chemistry in specifications, began increasing to 100% power.

l

e Sianificant Operational Events

(Continued)

(

Unit 1 Date Time Event

05/28/81 1700 Began power reduction to 30% - secondary ,

chemistry out of specification.

l 05/30/81 0957 Increased load to 100% - secondary chemistry declared within specifications.

4 05/31/81 0112 Reactor tripped (Reactor Trip #14) and we j experienced a safety injection caused by i a Lo pressurizer pressure indication. The pressurizer level transmitters were observed to be fluctuating radically at this time also. Two-way radio transmissions from the incore instrument room is believed to be the

cause of instrumentation fluctuations.

2359 Reactor was in mode 3.

4 9 .

l e

f 9 -s

,( a 9

e

. - . _ _ _ . _ _ _ . . - ~ . . . . . . . _ . _ . _ _ . _ _ _ . _ - _ - _ . _ . _ . _ _ . . . _ . . . . . _ . _ _ . _ _ _ _ _ - _ . - . _ _ _ _ . _ . _ - _ .

O AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-327 UNIT Secuoyah one DATE 6-2-81 COMPLETED BY David Dupree TELEPHONE (615) 842-0295 ,

MONTH May, 1981 DAY AVERAGE DAILY POWER LEVEL DAY' AVERAGE DAILY POWER LEVEL (fNe-Net) (?Ne-Net) 1 528 17 0 2 439 18 0 3 20 19 0 4 936 20 151 5 1071 21 799 6 1112 22 ., 1097 7 1C86 23 1097 8 1092 24 1098

.9 800 25 1098 10 n 26 logg 11 0 27 1098 12 0 28 966 13 n 29 52 14 _

0 30 572 15 0 31 244 16 0 INSTRUCTIONS Onthishformat, list the average daily unit power level in ?Ne-Net for each day M the repcyting month. Compute to the nearest whole megawatt. -

(9/77) 5

! t

, _ _ --,--n_,-..,,___-- ,, . , ,- .---- . - , - - - . , - , , . - - , - , . - . _ ~ - . - ,

OPERATING DATA REPORT DOCKET NO. 50-327 DATE 6-2-81 COMPLETED BY David Duprei TELEPHONE (615) 842-0295 OPERATING STATUS

1. Unit Name: Sequoyah Notes -

2. Reporting Period: May. 1981

3. Licensed Thermal Power (MWt): 3411

4. Nameplate Rating (Gross MWe): 1220.58

5. Design Electrical Rating (Net MWe): 1148

6. Maximum Dependable Capacity (Gross MWe): 1183

7. Maximum Dependable Capacity (Net MWe): 1148

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. Reasons For Restrictions, If Any:

This Month Yr-to-Date Cumulative

11. Hours in Reporting Period 744 3623 10968

12. Number of Hours Reactor Was Critical 446.2 2050.8 3589.4

13. -Reactor Reserve Shutdown Hours 0 0 0

14. Hours Generator On-Line 436.83 1883.68 2727.67

15. Unit Reserve Shutdown Hours 0 0 0

16. Gross Thermal Energy Generated -(MWH) 1,253,272 5,653,070 7,325,100

17. Gross Electrical Energy Generated (MWH) 418,430 1,926,153 2,483,474

18. Net Electrical Energy Generated '4WH) 400,067 1,836,129 2,354,969

19. Unit Service Factor 58.7 52.0 14.8

20. Unit Availability Factor 58.7 52.0 14.8

21. Unit Capacity Factor (Using MDC Net) 46.8 61.0 18.7

22. Unit Capacity Factor (Using DER Net) 46.8 61.0 18.7

23. Unit Forced Outage Rate 41.3 48.0 85.2

24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Durati9n ot Each):

2 week Outage in September, 1981 for ice weighing and Type C containment penetration 1 2k ene, canHnm

25. If Shut Down At End Of Report Period, Estimated Date of Startup: June 4, 1981

26. Units In Test Status (Prior to Commercial Operation):

Forecast Achieved INITIAL CRITICALITY 7-4-80 ,7-5-80 INITIAL ELECTRICITY 8-21-80 7-22-80 COMMERCIAL OPERATION 5-1-80

^

(9/77)

UNIT Sil0TDOWNS AND POWFH REDUCTIONS DOCKET NO. 50-327 .

UNIT NAME Sequoyah One COMPIETED I L ee REPORT MONTl! May3 1981 TELEPl!ONE (615) 542-0293 i n a es n o e.o 8 Licensee U Cause & Corrective No. Date "k j[$ $ s3 fj % Event @ 't $#b Action to yg y jUy Report # %3 R3 Prevent Recurrence h- M5 & 22 &* 8*

o xm{o u 12 81/05/01 S 7.58 B 4 Start-Up Test 9.4A, Turbine Trip @ 100%

Power, Reactor Trip #12

. 13 81/05/01 S 20.98 B 2 Net Load Trip, Start-Up Test 9.4B, Reactor Trip #13 14 81/05/09 F 2.7 B 5 Peduction Caused by Leaks on the Top Manways 4

, of the #2 and #3 Steam Generators 14 81/05/09 F 255.81 A,B 1 Outage Caused by Leaks Inside Containment on the Top Manways of the #2 and #3 Steam Generators 4

15 81/05/28 F 3.75 F 5 Steam Generators Sodium Concentration out of

. Specification (Deration) ,

15 GI/05/31 F 22.8 G 3 Radio Interference Caused Transmitters to the Pressurizer Level to Oscillate Causing the Reactor to Trip, Reactor Trip #14 J

e 1 , 2 3 4 I

F: Forced Reason: Method: Exhibit G-Instructions S: Scheduled A-Equipment Failure (Explain) 1-Manual for Preparation of Data B-Maintenance or Test 2-Manual Scram. Entry Sheets for Licensee

, C-Refueling 3-Automatic Scram. Event Report (LER) File (NUREG-D-Regulatory Restriction 4- Con t . of Existing 0161)

E-Operator Training & License Examination Outage d

F-Administrative 5-Reduction a G-Operational Error (Explain) 9-Other 5 i (9/77) H-Other (Explain) Exhibit I-Same Source 1

Plant Ifaintenance Summary The following si.. 41 cant maintenance items were completed during the musth of May, 1981:

Mechanical Maintenance ,

1. MFPT IB high pressure governor valve was disassembled to ground out a creak then re-assembled.

2. Began staking the tubes on the C component cooling water heat exchanger.

Electrical Maintenance

1. Completed the ice loading of the Unit 2 ice condenser.

2. Repaired the Limitorque operator on 1-FCV-74-12.

3. Conducted a visual inspection of the vital inverters.

4. Adjusted the level switch and replaced the annunciator card on reactor coolant pump #4.

5. Aligned the trolley rails on the Unit 2 polar crane. The overload relay was calibrated and functionally tested.

l Instrumcat Maintenance 1

j 1. Performed scheduled CSSC instrument calibration and maintenance. No emergency maintenance items performed on CSSC instrumentation during the month.

I Outage Maintenance j Unit 1

1. Work continued to eliminate hanger problems for Unit 1 per IE Bulletin 79-14.

2. Leaks were repaired on the steam generator manways.

3. The eight outlet nozzels on the reactor vessel were inspected to verifv l

there were not any surface indications of cracking.

4. The pressurizer instrument 12 .rs on pressurizer loop 340 were re-routed to original configuration.

l l

1

Outage Maintenance (Continued)

Unit 2

1. Work continued to eliminate hanger problems for Unit 1 per IE Bulletin 79-14.

2. The installation of additional Unit 2 fire sprinklers was completed.

3. Work is in progress to modify the fuel transfer system wafer valve.

Unit 0 or items Affecting Unit I and 2

1. Work was completed to add a water tight enclosure box and a fire damper around the ERCW junction box and associated conduit where train A and B split.

2. Completed the rerouting of t rain B conduit and cable serving the ERCW pumps and fire pumps.

3. Work continued to provide security access screens for the auxiliary building and diesel building exhaust fan housings. Seven of the nineteen screens are cocplete. .

4. Work is in progress to add fire detectors a'b'ove each ERCW pump.

5. Began work to re-locate the nitrogen truckfill piping to allow tr eks

to be located outside the auxiliary building and not violate secondary containment.

1 1

e 1

l f

l

O a

APPENDIX A DOCUMENTATION FOR ODCM CHANGES l

l l

t t

l 9

1 I-

~

l l i

8 Documentation for ODCM Changes th DCF g =

adultyngestion dose commitment factor for the j organ from the i radionuclide rem /pci, see attached as Table 2.1.

t I

ik

= monthly activity ingested of the i radionuclide from the k' release point, pCi.

I is described by ik 365.Ag V I

ik

, C1 (2.12) 12 u d ,

where:

365 = days per year A

ik

=

activgyreleasedofi radionuclide during the month from the k release point, pCi.

V = average rate of water consumption (730 ml/d ICRP 23, p. 358) 12 = months per year u = total cooling tower blowdown during releases, ml.

d = diffuser pipe dilution (5).

The dose equation then becomes 5

W D

jk

= 4.67x108 (DCF)g) x A ik mrem (2.13) u i=1 For continuous releases into the cooling tower blowdown line, additional mixing occurs in the diffuser pond when SQN is operating in Helper or Open cooling mode. The relative concentrat' ion r, is given as a function of total flow into the pond:

r = 1.48x10"I' u (2.13a)

Multiplying equation 2.13 by r, the dose from cooling to er blowdown becomes:

5 D

jk

= 6.906x10 ~0 (DCF)g) x Aik mrem (2.13b) l i=1 i

f i

_ . - - ~ _ . _ _

~

Documentation for ODCM Changes (Continued)

The R4 used in Equation 2.3a must also be scaled by the corresponding scale factot. Equation 2.3 and the corresponding alarm / trip setpoints become 2.4x10-6 (F + fg+f2*I3*I) 4 If 1(DIgR -1) +

f2 (bj R2"I)

• f3 (b3 3 ~I)

• f4 (b4 R4 -1)] 1F (2. 5')

by =b (2.6)

I b

2=b (2.7) 2 b3= (2.8) 3 b (2.9) 4=C 4 2.3.2.2 Fish Ingestion Thedosetoanindividualfromtheconsumptionoffishgsdescribedby t Equation 2.13. In this case the activity ingested of the i radionuclide (I 1) is described by

• t Aik BM pCi I

ik

= g , (2.14) l ud i

l where:

t D

A gp' =

activityrgeasedofi radionuclide during the month l

from the k release point, pCi th radionuclide pCi/gm i B. = fish concentration factor of i pCi/ml, see attached as Table 2.1.

M = amount of fish eaten monthly (1.9x103gm) u = total cooling tower blewdown during releasei, al l

j' d = diffuser pipe dilution (5) l l

9 Documentation for ODCM Changes (Continued)

The dose equation then becomes 5

d k

= 4x105 aikxBg xDCF q mrem (2.15) u i=1 -

For continuous releases into the cooling tcwer blowdown line, additional mixing occurs in the diffuser pond when SQN is operating in Helper or Open cooling mode. The relative concentration r, is given as a function of total flow into the pond:

r = 1.48x10"I' u (2.15a)

Multiplying equation 2.15 by r, the dose from cooling tower blowdown becomes:

5

~9 D

jk

= 5.91x10 A ik xB 1x DCF rem (2.15b) 13

-- i=1 where: ..

= th D dose to the j organ from the i radionuclide from the k ijk release point, rem.

j= the organ of interest (bone, GI tract, thyroid, or total body).

(DCF)IJ

.. = adult ingestion gse commitment factor for the j*

organ from the i radionuclide, res/pCi, see Table 2.1.

th th I = activity ingested of the i radionuclide from the k release ik point, pCi.

I f r water ingested is described by ik A "

I.k I

= ik , pCi (2.18) ud -

and for fish ingestion I is described by f

I = Aik BMg Ci (2.19) ik

,. o Documentation for ODCM Changes (Continued) where:

th Ag =

activityrggeasedofj radionuclide during the release period from the k release point, pC1.

V = average rate of water consumption (730 ml/d).

n = number of days during the release period (d). ,

u = cooling tower blowdown during the release period, ml.

d = credit for diffuser pipe dilution (5).

th Y IIE" B = fish concentration factor of f he i radionculide, pCi/ml f

M = amount of fish eaten monthly (1.9x103 gm)

At the end of the year an annual dose analysis will be performed by calculating the sum of the quarterly doses to the critical receptors.

2.4 Operability of Liquid Radwaste Equipment Specification 3.11.1.3 of the Radiological Effluent Technical Specifications .

re:uires that the liquid radwaste system shall be,used to reduce l

l l

O l

l l

, m.. _ _ __ ____ _ ~ - . . ._.- . . . _ . . . _ . . _ . . . _ _ ._. __ _._ ,_ - , _ . _ - . . - . . , _ . ,