ML20027A590

Monthly Operating Rept for Feb 1979

ML20027A590
Person / Time
Site:	Davis Besse
Issue date:	02/28/1979
From:	Caba E TOLEDO EDISON CO.
To:
Shared Package
ML19283B748	List: ML19283B747 ML20027A590
References
NUDOCS 7903140323
Download: ML20027A590 (13)

Text

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A OPERATING DATA REPORT DOCKET NO. 50-346 DATE March 8 1979 Erdal G. Caba COSIPLETED BY TELEPHONE 419-259-5000, E:ct.

236 OPERATING STATUS Davis-Besse Unit 1 Notes

1. Unit Name:

February, 1979

2. Reporting Period:

2772

3. Licensed Thermal Power 131Wt p:

925

4. Nameplate Rating IGross 31We):

906

5. Design Electrical Rating INet 31We):

t be determined

6. Maximum Dependable Capacity (Gross 31We): to be determined

7. Maximum Dependable Capacity INet 31We):

8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report. Give Reasons:

906

9. Power Level To Which Restricted,if Any (Net 31We):

10. Reasons For Restrictions. If Any:

This Month Yr.-to.Date Cumulative 1,416 13,181 672

11. Hours in Reporting Period 635 1, m. 3

/, m.1

12. Number Of Hours Reactor Was Critical 37 67.8 856.1

13. Reactor Reserve Shutdown Hours

14. Hours Generator On.Line 6,696.1 616.2 962.9 0

0 0

15. Unit Resene Shutdown Hours 1,447,394 2,276,332 12,463,902

16. Gross Thermal Energy Generated (31WH)

17. Gross Electrical Energy Generated 131WH) 484,573 758,861 4,142,616 456.145 708,968 3,750,428

18. Net Electrical Energy Generated (31WH) 91.7%

68.0%

53.5%

19. Unit Service Factor 91.7%

68.0%

53.5%

20. Unit Availability Factor to be determined

21. Unit Capacity Factor (Using 3!DC Net) 74.9%

55.3%

36.1%

22. Unit Capacity Factor (Using DER Net) 8.1%

24.5%

8.3%

23. Unit Forced Outage Rare

24. Shutdowns Scheduled Oser Nest 6 Stonths IType.Date.and Duration of Eacht:

Approximately April 1979 (9 days) to repair Main Steam Safety Valve SPl7A2.

25. If Shut Down At End Of Report Period. e timated Date of Startup:

s

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

Forecast Achiesed INITIA L CRITICALITY INITIAL ELECTRICITY CO3151ERCIAL OPER ATION 7903140323 gy,)

AVERACE DAILY UNIT POWER LEVEL 50-346 DOCKET NO.

Davis-Besse Unit 1 UNIT March 8,1979 DATE COMPLETED BY, _Erdal C. Caba TELEPHONE 419-259-5000, Ext.

236 February, 1979 MONTH DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe Net)

(MWe Net]

746 778-

,7 775 744 18 2

747 3

746 781 4

20 749 782 5

21 105 741 22 6

239 23 744 757 g

24 751 755 9

25 761 756 26 10 670 f

II 756 683 f

12 28 348 13 29 277 14 30 765 15 31 775 16 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.

I"!773

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50-346

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. DOCKET NO. Davis-Besse Unit 1 UNIT S1101 DOWNS AND POWLit REDUCTIONS UNIT NAME March 8, 1979 DATE COMPLETED 119 Charles N. Alm February, 1979 TELEPilONE 419-259-5000. Ext. 251 REPORT MONTil 1

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.Eh Licensee je,

• L Cause & Corrective No.

Date o.

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.3 s 5 Event sT n3 Action to f

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ggg Report #

A0 yU Prevent Recurrence 6

5 79 02 13 F

23.6 H

3 NP-33-79-29 NA NA The reactor tripped due to the loss of power to Reactor Coolant Pumps (RCP) 1-2 and 2-1.

This event was initiated by relay testing at Beaver Substation (Ohio Edison) which resulted in the s

de-energization of our unit "B" f

Bus that supplies power to the RCP 1-2 e

and 2-1.

Refer to the Operational Summary for further details.

6 79 02 22 F

32.2 A

1 NA HA INSTRU Electrical circuitry in the electro-hydraulic control of the turbine failed which led to a manual trip of the reactor because of increasing RCS pressure. The circuitry was checked out by General Electric and faulty com ponents were replaced. Refer to the Operational Sununary for further detail i.

i 2

3 4

Method:

Exhibit G. Instructions F: Forced Reason:

S: Schedu!cd A.Eignipment Failnic(Explain) 1-Manual for Preparation of D.ita ll-Maintenance or Test 2-Manual Scram.

Entry Sheets for Licensee C Refncling 3 Automatic Scram.

livent Repoit (LElt) File (NUREG-D Regniatony Resisiction 4 Other (Explain) 0161) 1:-Operator Training & License Examination 5

F Adininistsative Exhibit I Same Source G Oper.iiional Enor (IIxplain)

(9/77) li Other (limplain)

v OPERATIONAL

SUMMARY

FOR FEBRUARY, 1979 2/1/79 - 2/10/79 Reactor power was maintained at 87 percent with the generator gross load at 790 ! 10 MWe, The Main Steam Safeties SPl7A2 and SPl7B2 were inoperable, and therefore the unit power level was limited to 92.91 percent. Also, the high pressure feed-water heat exchanger train 1 was still isolated to complete modifications on the heat exchanger 1-4.

l 2/11/79 Reactor power was reduced at 0200 hours0.00231 days <br />0.0556 hours <br />3.306878e-4 weeks <br />7.61e-5 months <br /> to return the high pres-sure feedwater heat exchanger train 1 to service. At 2255 hours0.0261 days <br />0.626 hours <br />0.00373 weeks <br />8.580275e-4 months <br /> reactor power was increased from 76 percent to 88 percent power, and the generator gross load was 820 1 10 MWe, 2/12/79 Reactor power was maintained at 88 percent of full power (2772 MWT at full power).

2/13/79 The reactor tripped at 1130 hours0.0131 days <br />0.314 hours <br />0.00187 weeks <br />4.29965e-4 months <br /> due to the loss of power to two Reactor Coolant Pumps (RCP). This event was initiated by relay testing at Beaver Substation of Ohio Edison which caused our Transfer / Trip Receiving Relay to pickup in the Ohio Edison line panel in the relay house. This caused the "K" Bus to lockout which trips the switchyard breakers 34562 and 34564 and isolates the Startup Transformer 02 from the "B" Bus. With "B" Bus de-energized, the RCP l-2 and RCP 2-1 lost power and tripped.

2/14/79 The reactor was returned to criticality at 0448 hours0.00519 days <br />0.124 hours <br />7.407407e-4 weeks <br />1.70464e-4 months <br />, and at 1107 hours0.0128 days <br />0.308 hours <br />0.00183 weeks <br />4.212135e-4 months <br />, the turbine generator was synchronized on line. A unit power increase to 88 percent was then initiated. During the outage, the lif t setpoint of the Main Steam Safety Valve

' ~

SPl7B2 was reset making this safety operable. The unit power level was still limited at 92.91 percent though since the Main Steam Safety Valve SPl7A2 could not be repaired due to the plant conditions required. This safety is suspected of having a broken spindle.

2/15/79 - 2/21/79 Reactor power was maintained at 87 percent with the generator gross load at 815 ! 10 MWe.

2/22/79 A unit runback to 15 percent occurred at 0401 hours0.00464 days <br />0.111 hours <br />6.630291e-4 weeks <br />1.525805e-4 months <br />. A manual reactor trip occurred at 0440 hours0.00509 days <br />0.122 hours <br />7.275132e-4 weeks <br />1.6742e-4 months <br /> when it was determined that a reactor trip on Reactor Coolant System (RCS) high prescure was inevitable af ter an inadvertent load increase signal. The event was initiated by electrical component failure in the tur-bine electro-hydraulic control system.

OPERATIONAL 3LTfARY FOR FEBRUARY, 1979 PAGE 2 The reactor was returned to criticality at 2326 hours0.0269 days <br />0.646 hours <br />0.00385 weeks <br />8.85043e-4 months <br />.

2/23/79 The turbine generator was synchronized on line at 1250 hours0.0145 days <br />0.347 hours <br />0.00207 weeks <br />4.75625e-4 months <br />.

During the outage, the turbine primary speed control amplifier board was replaced and calibrated. Seven main steam safety valve lift setpoints were checked due to low pressure lif ts during the trip. The unit power level was then increased and attained 84

~ percent full power at 1730 hours0.02 days <br />0.481 hours <br />0.00286 weeks <br />6.58265e-4 months <br />. The Main Steam Safety Valve SP17A2,is still inoperable.

2/24/79 - 2/27/79 The unit power level was maintained at 84 percent with the generator gross load at 810 t 10 MWe.

2/28/79 The RCP l-2 tripped at 0956 hours0.0111 days <br />0.266 hours <br />0.00158 weeks <br />3.63758e-4 months <br /> due to a loss of seal injec-tion flow. The unit power was automatically lowered to 75 per-cent by the Integrated Control System. At 2100 hours0.0243 days <br />0.583 hours <br />0.00347 weeks <br />7.9905e-4 months <br />, the unit power was decreased to 50 percent to restart the RCP l-2 and then at 2330 hours0.027 days <br />0.647 hours <br />0.00385 weeks <br />8.86565e-4 months <br />, unit power was increased to 85 percent.

The seal inj ection flow was lost when the wrong seal injection filter cover was unbolted by maintenance personnel. To reduce the possibility of this same error, signs will be posted to indicate filter numbers.

Also, further investigation of the turbine electro-hydraulic control system has revealed that the backup speed control cir-cuitry may have electrical faults.

The defective backup speed control circuit boards were replaced on March 4, 1979.

T

m REFUELING INFORMATION DATE:

February, 1979 1.

Name of facility:

Davis-Besse Nuclear Power Station Unit 1 2.

Scheduled date for next refueling shutdown:

March, 1980 3.

Scheduled date for restart following refueling:

May, 1980 4.

Will refueling or resumption of operation thereaf ter require a technical specification change or other license amendment? If answer is yes, what, in general, will these be? If answer is no, has the reload fuel design and core configuration been reviewed by your Plant Safety Review Committee to determine whether any unreviewed safety questions are associated with the core reload (Ref. 10 CFR Section 50.59)?

Yes, see attached 5.

Scheduled date(s) for submitting proposed licensing action and supporting information.

December, 1979 6.

Important licensing considerations associated with refueling, e.g., new or different fuel design or supplier, unreviewed design or performance analysis methods, significant changes in fuel design, new operating procedures.

None 7.

The number of fuel assemblies (a) in the core and (b) in the spent fuel storage pool.

(a) 177 (b) 0 (zero) 8.

The present licensed spent fuel pool storage capacity and the size of any increase in licensed storage capacity that has been requested or is planned, in number of fuel assemblies.

475 (735 total)

Present 260 Increase size by 9.

The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity.

March,1980 - May,1980 (assuming ability to unload the ent' ire core into Date the spent fuel pool is maintained.

REFUELING INFORMATION Cont'd February, 1979 Page 2 of 2 4.

The following Technical Specifications (Part A) will require revision:

2.1.1 & 2.1.2 - Reactor Core Safety Limits (and Bases) 2.2.1 - Reactor Protection Systen Instrumentation Setpoints (and Bases) 3.1.3.6 - Regulating Rod Insertion Limits 3.1.3.7 - Rod Program 3.2.1 - Axial Power Imbalance (and Bases)

The following Technical Specifications (Part A) may also require revision:

3.1.2.8 & 3.1.2.9 - Borated Water Sources (and Bases) 3.2.4 - Quadrant Power Tilt (and Bases) 3.2.5 - DNB Parameters (and Bases) 5 e

e 9

0 9

FACILITY CHANGE REQUESTS COMPLETED DURING FEBRUARY 1979 i

FCR NO.77-019 g

SYSTEM: Containment Hydrogen Analyzers COMPONENT: Calibration Gas Vent 3

CHANGE, TEST, OR EXPERIMENT: On January 25, 1979, Facility Change Request (FCR)77-019 was completed. This FCR was to install plugs in the hydrogen analyzer calibration gas vents and to remove themechanicalinterlock on the calibration gas l

valves. This allows the containment gases trapped within the analyzer to be

. pumped back into containment. This change was made under the guidance of the unit architect / engineer, Bechtel Corporation. Bechtel also revised the applicable vendor drawings to reflect this change. Applicable unit procedures have also been revised.

(

REASON FOR THE FCR: The original design of the hydrogen analyzers vented the trapped gases into the auxiliary building ptmosphere, a potential health / safety hazard.

SAFETY EVALUATION: The proposed design change does not involve an unreviewed safe, y t

question or Technical Specification change, and the probability and possibility of an accident related to radiation exposu;e of personnel is greatly reduced.

The proposed design change vill not adversely affect tha operation of the instrumentation j

and will increase safety of the station personnel.

t I

9 FACILITY CHANGE REQUESTS COMPLETED DURING FEBRUARY 1979 FCR NO.77-345 SYSTEM: Reactor Coolant Syctem COMPONENT: Quench Tank CHANGE, TEST, OR EXPERIMENT: On June 2, 1978, the physical work was completed on FCR 77-345. This FCR added a deflector to the Quench Tank rupture dise flange.

This duflector co..sists of a 900 pipe elbow and a short length of pipe which will direct the flow of stesa in a safe direction should the. Quench Tank rupture disc rupture. This change was made under the direction of the unit architect /

engineer, Bechtel Corporation.

]

REASON FOR THE FCR: The former arrangement would allow steam to strike a cooling duct and the insulation on Steam Generator 1-2 as well as damage pressurizer heater cables (see Licensee Event Report NP-32-77-16).

SAFETY EVALUATION: The deflector being added is to change the direction of the steam flow.after the. rupture disc has ruptured. The deflector will not affect the safety related function of the Quench Tank.

1 B

l 4

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• ~ - - -

• '"'~-~e--

Rsvision 1 - 2/9/79 Revision 2 - 3/8/79 OPERATLNG DATA REPORT 50-346 DOCKET NO.

DATE January s, 1979 COMPLETED BY Erdal Ca5a TELEPHONE 419-239-3000, Ext.

236

~

OPERATING STATUS Davis-Besse Unit 1 Notes

1. Unit Name:

December, 1978

2. Reporting Period:

2772

3. Licensed Thermal Power (MWt):

923

4. Nameplate Rating (Gross MWe):

906

5. Design Electrical Rating (Net MWe):

6. Maximum Dependable Capacity (Cross MWe): to be determined to be determined

7. Maximum Dependable Capacity (Net MWe):

8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons:

None

9. Power Level To which Restricted,if Any (Net MWe):

10. Reasons For Restrictions,if Any:

This Month Yr to-Date Cumulative 744 8760 11765

11. Hours In Reporting Period

-328.8 4539.7 6631.s

12. Number Of Hours Reactor Was Critical 2

13. Reactor Reserve Shutdown Hours 367.7 406.6

• 790.3 314.1 4266.2 3/33.4

14. Hours Generator On Line

15. Unit Resene Shutdown Hours 0

0 0

16. Gross Thermal Energy Generated (MWil) 626,864 8,523,538 10,187,570

17. Gross Electrical Energy Generated (MWH) 196,972 2,859,306 3,383,755

18. Net Electrical Energy Generated (MWH) 173,312 2,611,642 3,041,460

19. Unit Service Factor 42.2%

48.7%

51.4%

42.2%

48.7%

51.4%

1

20. Unit Availability Factor to be determined to be determined

21. Unit Capacity Factor (Using MDC Net) 25.7%

32.9%

33.3%

22. Unit Capacity Factor (Using DER Net)

23. Unit Forced Outage Rate 57.8%

25.4%

26.7%

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

None

25. If Shut Down At End Of Report Period. Estimated Date of Startup:

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

Forecast Achiesed INITIA L CRITICA LITY INITIA L ELECTRICITY N/A COMMERCIA L OPERATION (9/77) e

Rev. 1 - 3/8/79 OPERATING DATA REPORT DOCKET NO. 50-346 DATE

• • DE"*'Y 9' 1979 COMPLETED BY Erdal C. Caba TELEPHONE 419-259-5000, Ext.

~

236-OPERATING STATUS Davis-Besse Unit i Notes

!. Unit Name:

January, 1979

2. Reporting Period:

2772

3. Licensed Thermal Power (MWt):

925

4. Nameplate Rating (Gross MWe):

5. Design Electrical Rating (Net MWe):

6. Maximum Dependable Capacity (Gross MWe): to be determined to be determined

7. Maximum Dependable Capacity (Net MWe):

8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report.Give Reasons:

None

9. Power Level To Which Restricted,if Any (Net MWe):

10. Reasons For Restrictions. lf Any:

This Month Yr to.Date Cumulative 744 744 12,509 i1. Hours In Reporting Period

12. Number Of Hours Reactor Was Critical 381.3 381.3 7,013.1 0.5 w.s 1

13. Reactor Reserve Shutdown Hours 821_1 4

14. Hours Generator On-Line 346.7 346.7 6.079.9

15. Unit Reserve Shutdown Hours 0

0 0

16. Gross Thermal Energy Generated (MWH) 828.938 828.938 11.016,508

17. Gross Electrical Energy Generated (MWH) 274.288 274.288 3,658,043 i

18. Net Electrical Energy Generated (MWH) 252.823 252.823 3.294.283

19. Unit Service Factor 46.6%

46.6%

51.1%

l.

46.67.

46.6%

51.1%:

l

20. Unit Availability Factor

21. Unit Capacity Factor (Using MDC Net) to be detemined 37.5%

37.5%

34.7%-

22. Unit Capacity Factor (Using DER Net)

23. Unit Forced Outage Rate 7.7%

7.7%

25.9%

24'. Shutdowns Scheduled Over Next 6 Months (Type.Date,and Duration of Each):

i

25. If Shut Down At End Of Report Period. Estimated Date of Startup:

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

Forecast Achiesed INITIA L CRITICALITY INITIA L ELECTRICITY l

COMMERCIA L OPER ATION 7

I (9/77) 9

_.m,

Rev. 1 - 3/8/79 t

50-346 DOCKET NO.

' UNIT SifUTDOWNS AND POWEll REDUCTIONS UNIT NAME Davis-Besse Unit 1 *.

February 9. 1979 DATE Charles N. Alm COMPLETED BY REPORT MONTil January. 1979 TELEPil0NE 419-259-5000._ Ext. 251 "c.

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C:

O Liccusee Eg Cause & Corrective j

.] g 3 )M l

Action to ss Event gg g.1 No.

Date k

5g

(

U Prevent Recurrence H

f =,,,

5 jdi g Repori#

mo g

6 1l 3

79-01-14 S

.9 B

4 N/A N/A N/A The turbine was tripped from 100 per-cent power to complete the Unit Load Rejection Test, TP 800.13.

1 4

79-01-14 S

367.5 B

4 N/A N/A N/A The-reactor was shutdown twice in this time frame to complete the unit tests TP 800.25, " Shutdown From Out-side the Control Room", and TP 800.26,

,o

" Loss of External Load including Loss of Offsite Power."

. ~.

A unit outage was then continued af ter the shutdown of TP 800.26 to repair many equipment f ailures. The major failure which required the outage was to replace the seals on Reactor doolant Pumps 1-1 and 2-1.

Refer to the Operational Summary for further d e' tails.

3 4

I 2

Method:

Exhibit G Instructions l-Manual for Preparation of Data F: Forced Reason:

, S: Schedu!cd A Equipment Failure (Explain) 2 Manual Scram.

Entry Sheets for Licensee 4

3. Automatic Scram.

Event Report (LERI File (NUREG.

D Maintenance or Test C-Ilefueling 4 Other (Explain) 0161)

D ltegulatory Restrictiim 1: Operatur Training & License Examination 5

'j F Administrative Exhibit 1 Same Source G. Operational Liror (Explaint l'8/11) 110:her (Explain)

_ _ m- - -

Rev. 1 - 3/8/79 4

DOCKET NO.

50-346 UNIT S!!UIDOWNS AND POM.!! REDUCTIONS UNIT NAME Davis-Besse tinit 1,.

DATE February 9. 1979 Charles N. Alm COMPLETED BY January, 1979 TELEPilONE 419-259-5000. Ext. 251 REPORT MONTH u-Cause A Corrective jg 3

$.Ei Licensee gg h"8 Action to l

e.

No.

Date E

E2

.3 s &

Event u '2 Prevent Recurrence iE0 yV

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j;g g Report *

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i-5 32 78-12-16 F

3.7 A

1 N/A IIH PIPEXX The unit was shutdown to repair the extraction steam line bellows. Refer to the Operational Summary of Decem-

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(Cont' d) ber for further details t

i 1

79-01-10 S

0.0 B

4 N/A N/A N/A Power was reduced to 75 percent to perform a Power Imbalance Detector Correlation Test.

i 1

2 79-01-12 F

25.2 H

3 NP-33-79-13 EB ELECON The event was initiated by the acci-dental grounding of the Hydrogen Analyzer AE 5028. The ground caused the 200 amp fuse on the inverter feed-ing Y2 Essential 120 VAC Instrument Bus to blow. The 10 amp fuse on the

-Ilydrogen Analyzer AE 5028 was a standard fuse. The fuse was replaced with a quick acting fuse.

3 4

I 2

Method:

Exhibit G. Instructions F: Forced Reason:

1. Manual for Preparation of Data S: Schedu!cd A Equipment Failure (Explain) 2-Manual Scram.

Entry Sheets for Licensee ll Maintenance of Test

3. Automatic Scram.

Event Repor (LER) File (NUREG.

C Refueling D-Regulatory Restriction 4 Other (Explain) 0161) 1: Operator Training & License Examination S

F. Administrative Exhibit I-Same Source G Operational E:ror (Explain) 19/77) 110 her (Explaini

.