TXX-9501, CPSES Annual Operating Rept for 1994

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CPSES Annual Operating Rept for 1994
ML20080P429
Person / Time
Site: Comanche Peak  Luminant icon.png
Issue date: 12/31/1994
From: Terry C
TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC)
To:
NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
TXX-95011, NUDOCS 9503070366
Download: ML20080P429 (28)
v • d • e


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M Log # TXX 95011

-- Fila # 10250 l 1 4  : Ref. # 10CFR50.36 -

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3 1UELECTRIC  :

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ii U. S. Nuclear RegulatoryCommission ,

' Attention: Document Control Desk Washington, DC 20555 ,  :

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SUBJECT:

COMANCHE PEAK S1EAM ELECTRIC STATION (CPSES)-

UNITS 1 AND 2 . ,

DOCKET NOS 50 445 AND 50 446

. ANNUAL OPERATING REPORT FOR 1994 ,

Gentlemen: ,

Attached is the CPSES Annual Operating Report for 1994 prepared and submitted j

. pursuant to Technical Specification 6.9.1.2 contained in Appendix A to the ,

Comanche Peak Steam Electric Station Unit 1 Operating License NPF 87 and ,

Unit 2 Operating License NPF-89. This attachment also corolies with the ,-

annual . operating report guidance provided in position C.1.] of U.S. NRC '

Regulatory Guide 1.16 Revision 4.  ;

If you have any' questions, please contact Mr. J. M. Kulangara at  ;

(214) 812-8818.

Sincerely, i a

C. L. Terry By: ,

M. S. Marshall  :

Generic Licensing Manager  !

JMK/jmk-Attachment j c- Mr. L. J. Callan, Region IV Resident Inspector, CPSES Mr. T. J. Polich, NRR  ;

Mr. D. D. Chamberlain, Region IV p\ 1 n rw . . .

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.dttachment to TXX-95011'-

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COMANCHE PEAK STEAM ELECTRIC-STATION r

ANNUAL OPERATING REPORT 1994 TEXAS UTILITIES ELECTRIC COMPANY

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TABLE'0F CONTENTS ,

1.0 Summary of Operating Experience-

1. .. '

2.0 ' Outages and Reductions in Power 3.0 Personnel Exposure and Monitoring Report 4.0 Report of Results of Specific Activity Analysis in which the Primary Coolant Exceeded the Limits of Technical Specification 3.4.7 5.0 Irradiated Fuel Inspection Results 6.0- Outage Related Single Radioactivity Release or Radiation Exposure to an Individual that Accounts for More than 10 Percent of Allowable Annual Values r

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F 1,0L SUHRY OF OPERATING EXPERIENCE '

The Comanche Peak: Steam Electric Station (CPSES) is' a dual unit pre'ssurized

water reactor power plant, each unit licensed at 3411 Megawatt thermal (MWt).

1VLM ilt is located in Somervell County in North Central Texas approximately65 miles -

southwest of the Dallas-Fort Worth Metropolitan area. ' The nuclear steam supply.

system was purchased from Westinghouse Electric Corporation and is rated for a '

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t3425 MWt output. ,

1.11 l CPSES UNIT 1 ,

F .CPSES Unit 1 achieved initial criticality on April 3,1990. Initial power -

4 generation occurred on Aaril 24.'1990, and the plant was declared commercial'on:

sw August 13; 1990. Since 3eing declared commercial. CPSES Unit i has generated

- 31,363,447 net Megawatt-hours (MWH) of electricity as of December 31,1994,-

. with a net unit capacity factor of 70.9% (using MDC). The unit and reactor

availability factors were 98.8% and 100% respectively, for the year 1994.

On December 16J 1993; the unit was returned to service following its third 0 . refueling outage and a refueling outage was neither required nor executed for the unit in the calendar year 1994.

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Figure 1.1-1 provides the generation profile of the average daily net electrical output of Unit 1 for 1994. Table 1.1-1 is a compilation of the monthly summaries of the operating data and Table 1,1-2 contains the yearly and  !

total summaries of the operating data.

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'1.2 CPSES UNIT 2-

. CPSES Unit 2 achieved initial criticality on' March 24,1993. Initial power .

. generation occurred on April 9,1993, and the plant was declared commercial on ,

August 3,1993. Since being declared commercial. CPSES Unit-2 has generated _ J 8,694,956 net Megawatt-hours (MWH)of electricity as of December 31,1994, with- 1

- a net unit capacity factor of 61.1% (using MDC) The unit and reactor availability factors were 65.0% and 87.4%, respectively, for the year 1994, t i

Mid-cycle Outace: 0n'Aaril 21., 1994,- a power reduction was-initiated at 0215 '

central standard time (CST) to perform a mid-cycle outage; the main turbine was . l manually tripped at approximately 1335 CST. This mid-cycle outage allowed the 1

unit to conserve fuel and to be available to support the system peak electric:

demands in the summer of 1994. This planned outage also allowed the unit to =  ;

complete material condition improvements to enhance performance. The original ,

scope of the mid-cycle outage activities ended on May 22,1994: however, the ,

unit remained shutdown under a forced outage due to repair of both trains of the containment spray system. After completion of this work, operators a restarted the unit and synchronized the main generator to the grid at 1607 CST t on June 19. 1994, resulting in a combined outage duration of 59 days. ,

The major work scope completed for the scheduled portion of the mid-cycle '  ;

outage included:

e Iso-phase Bus Duct Maintenance and Testing  :

e Main Turbine Control Valve Repairs o Train "A" Sequencer Upgrade and Cleaning l e Emergency Diesel Generator "A" Load Test and 24 Hour Run l e Train "A Integrated Test Sequence (ITS) Testing j e Repair to Leaking Valves in the Auxiliary Feedwater System o Circulating Water Intake Expansion Joint Replacement e Removal of Main Feedwater Pump Strainers e Repair of Steam Generator Blowdown Heat Exchanger Leaks j 4

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'te l Repairs of. l.eaks to Decrease Contamination. Increase Megawatt..

y Output and Improve Plant Material Conditions '

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L 1e Required. Surveillance'and Preventive Maintenance 1.

e .. Emergency Diesel. Generator A Teardown and Inspection Refuelina Outaae: Ori OcEober 6,1994, power reduction was initiated for the

.. unit's > first-... refuel ing outage:.t.h e unit main turbine generator was tr ippedon : ~

October 7.1994.- The outage was successful in its implementationwith at a J duration of.48 days, Eighty-eight new fuel assemblies were loaded for. Cycle 2.-

The unit was returned to service on November 24;.1994.

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During the refueling outage. the major work scope completed included:

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e ' Apaendix J Local Leak Rate Testing -

e e ES /RPS Time Response Testing '

e Diesel Generator Train "B" Maintenance Inspections and Testing >

e Train "B" Integrated Test Sequence Testing

e. - All Pressurizer Safety Valves Setpoint Tests-e All Main Steam Safety Valves Setpoint Tests e Eddy Current' Testing and Sludge Lancing on. Steam Generators e Replacement of a Last Stage Blade on LP2 Turbine .i e Mid-Loop Level Instrumentation Addition to Improve Level Measurement of the RCS . .

l e Installation of New Impellers on Containment Spray Pumps'01. 02, 03 and'04 e Turning Gear Replacement for Main Feedwater Pump Turbines 2-01

.and 2-02 e RHR Pump 2-02 Modification from Uncoupled to Coupled Design with . A Cartridge Mechanical Seal e Rebuilding of Station Service Water Pump 2-01 -

e Snubber Functional Testing e Circulating Water Expansion Joint Re' placement .

-e Containment Recirculationsumps Screen Structure 2-01 and 2-02 Weld Repairs Figure 1,2-1 provides the' generation profile of the average daily net '

electrical output .of Unit 2.for 1994- Table 1.2-1 is a compilation of the monthly summaries of the' operating data and Table 1.2-2 contains the yearly.

and the total summaries of the operating data.

2.0 OUTAGES AND REDUCTIONS IN POWER 3 2.1 . CPSES UNIT 1 Table 2.1 describes unit operating experience including unit shutdowns and provides explanations of significant dips in average power levels for CPSES Jnit 1.

2.2 CPSES UNIT 2 Table 2.2 describes unit operating experience including unit shutdowns and i arovides explanations of significant dips in average power levels.for CPSES Jnit 2.  ;

.3.0 EXPOSURE AND MONITORING REPORT  !

The personnel exposure and monitoring report for CPSES is provided in Table 3.0.

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  • Attachmsnt J tolTXX-95011-Page 5,of 27_

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REP)RT OF tESUl.TS OF- SPIECIFIC ACTIVITY ANALYSIS IN WHICH THE PRIMARY C00LAKf' '

- 4 EXC EEDED Ti! L:: HITS OF "ECHNICAL SPECIFICATION 3.4.7.

, activity analyses in which the primary coolant exceeded the limits of

Technical Specification 3.4.7.'  ;

CPSES Units 1 and 2 primary coolant did not exceed the limits of-Technical.

Specification 3.4.7 for the calendar year 1994. ,

L5.0- IBB8DIATED FUEL INSPECTION RESULTS 5.1 CPSES UNIT 1 .

CPSES Unit 1 did not enter a refueling outage in 1994 and therefore irradiated '

? . fuel examinations were not performed for the unit in calendar year 1994, p 5.2 CPSES UNIT 2 ,

The reactor coolant fission product' activity levels were carefully monitored throughout Cycle 1 operation. There were no indications of leaking fuel during

. steady-state operation or during reactor power changes. Nonetheless, visual-inspectionswere performed to assess the external condition of the fuel  :

assemblies.

Visual inspections (using binoculars) were performed on all the Unit 2- fuel-assemblies as the fuel was off-loaded from the reactor into the spent fuel pool. All four faces of each fuel assembly were examined for anomalies, _ .

including grid strap damage. The visual inspections revealed no anomalies and :

no indications of grid strap damage. All fuel assemblies appeared to be in excellent condition.

6.0 OUTAGE R ELA"ED SINCLIE RADI#CTIVITY R8. EASE OR RADIATION EXPOSURE "O AN IN)IVl )UAL TFA" ACC0JhTS FOR H01E THAN 10 PERCENT OF A_LOWABLE MNUAL VALUE3 CPSES Units 1 and 2 did not experience any single release of radioactivityor -

single radiation exposure event to an individual greater than 10% of an allowable dose limit during an outage or forced reduction in power of over,20%

of designed power level during 1994.

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Attachment to TXX-95011 Page 6 of 27 < -

FIGURE 1.1-1 ^

  • COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 GENERATION PROFILE ~

AVERAGE DAILY UNIT POWER LEVEL 1,200 -

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TABLE 1.1-1.(PAGE 1 0F'2) -

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- COMMCHE PEAK STEAM ELECTRIC STATION - UNIT 1 - . _la m n MONTHLY ELECTRIC POWER GENERATION DATA (1994) < **'

. January: - February March April ~ &ltJ - Jggg - ' <

Hours RX was Critical 744 625 744.0 719.0 s744.0 720 RX Reserve Shutdown Hours 0 47 0.0-. 0.0 - - 0.0 0 -

Hours Generator On-Line 744 621 744.0 L719.0 ~744.0' ?720' Unit Reserve Shutdown Hours 0.0 0.0 0.0 0.0 0.0 - 10.0E -

Gross Thermal Energy Generated (MWH)-- 2.536.090' '2.062.130~ -2.490.775 2.445.370 2.459.700' '2.449;733-Gross Electric Energy Generated (MWH) 854.089- 692.763- 836.539 820.540- 824.769 817~316L.

Net Electric Energy Generated (MWH) 821.112 663.514: - 804.328 789.247- 791.188 1784.547-

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f RX Service Factor (2) 100.0 93.0 100'0

. - 100.0 -100.0 100.0- i RX Availability Factor (%) 100.0. 100.0 100.0 100.0 100.0- 1100.0.

Unit Service Factor (%) 100.0 . 92.~4 : 100.0 100'0-

. 100.0 ~100.0 Unit Availability Factor (%) 100.0 92.4 100.0 100.0; '

.~100.0 1100'0 .

Unit Capacity Factor (%.using MDC aet) 96.0 85.9 94.0' ~ 95.5- ~ 92.5? 94;8:

Unit Capacity Factor (%.using DER net)  : 96.0 85.9- 94.0 - 95.5 - z92.5 ;94.8 Unit Forced Outage Rate'(%) - 0.0 7.6 - 0.0' O.0' 10'0 . ~ 0.0:

- Hours in Month 744.0. -672.0 744.0 J719.0 '744.0: 720.0j .AED Net MDC (MWe) Estimated 1150.0 1150.0 -1150.0- .1150.0 1150.0: .1150.01 1 ,-- m

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COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 MONTHLY. ELECTRIC POWER GENERATION DATA (1994)- i

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du!I Auoust SeDteter October  : November Deceeer

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Hours RX was Critical . 744.0 744.0. 720.0 745.0 - 2693.0 '732.0;

  • A RX Reserve Shutdown Hours 0.0 0.0 0.0 0.0 ~ 127.0 .12.0

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Hours Generator On-Line 744.0 744.0 720.0 745.0 693.0 715.0 Unit Reserve Shutdown Hours - 0.0 0.0 0.0 0.0 0.0 0.0i N< A

' Gross Thermal Energy Generated (MWH) 2.531.710 2.506.709 2.449.997 2.532.295' 2.362.373 :2.3'58.420:  ;

Gross Electric Energy Generated (MWH) 838.252- - 829.392 813.716 849.788 794.949~ .789.257:

Net Electric Energy Generated (MWH) 804.503- 795.611 781.363. 815.066 761.4171 -755.700 ~

RX Service Factor (%). ' 100.0 100.0

'100- 0 . - 100.0 96. 3 -: L98.3 ' '

RX Availability Factor (%) 100.0- 100.0 100.0 100.0 . 100.0: - (100.0- ,

Unit Service Factor-(%) 100.0 '100.0- 100.0 100.0 96.3" 96.0 Unit Availability Factor (%)- 100.0 ~100.0 100.0 100.0 -96$ 96.0 Unit Capacity Factor (%.using MDC net)

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.94.0 93.0 94.4. 95.1 92.0 88.3

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Unit Capacity Factor' (%.using DER. net) 94.0 93.0 94.4 . 95.1: _92.0:

' 88.~3. - ,

Unit forced Outage Rate'(%)' O.0 0:0- 0.0  : 0.0 - i3.7 m 4. 0 -' 2 Hours in Month --744.0 744.01 720.01 -

745.0 720.0, .744.0: ,

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Net MDC (Mwe) Estimated . 1150.0 J1150.0' 1150.0. 1150.01 1150.0' :1150.0- -

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ttachment to TXX-95011 Page 9.of 27 TABLE 1.1-2 C0HANCHE PEAK STEAM ELECTRIC STATION UNIT 1 ANNUAL ELECTRIC POWER GENERATION DATA (1994) yfAR CUMULATIVE Hours RX was Critical 8.674 31.213 RX Reserve Shutdown Hours 86 2.440 Hours Generator On-Line 8,653 30.745 Unit Reserve Shutdown Hours 0.0 0.0 Gross Thermal Energy Generated (MWH) 29.185,301 98.935.106 Gross Electric Energy Generated (MWH) 9,761.370 32,896.627 Net Electric Energy Generated (MWH) 9,367.596 31.363,447 RX Service Factor (%) 99.0 81.2 RX Availability Factor (%) 100.0 87.5 Unit Service Factor (%) 98.8 80.0 Unit Availability Factor (%) 98.8 80.0 Unit Capacity Factor (%,using MDC net) 93.0 70.9 Unit Capacity Factor (%.using DER net) 93.0 70.9 Unit Forced Outage Rate (%) 1.2 4.8 Hours in Reporting Period 8,760 38,441

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Attachment to TXX-95011 '

Page 10 of 27 ' -

1 FIGURE 1.2-1 COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2-GENERATION PROFILE ~

-AVERAGE DAILY UNIT POWER LEVEL Actual i 1,200 -

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. .I MONTHLY: ELECTRIC POWER GENERATION DATA-(1994)' .

4 January- . February March iADril 'Mn Jungi E

-Hours RX was Critical 744.0 '

'672.0 - 541.0 495.0- 0.0 ?226' 0::

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RX Reserve Shutdown Hours 0.0 0.0: 203.0 .. 224.0~ ~744- 1494.0- .

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Hours Generator On-Line 744.0 672.0 490.0 493.0 0.01 "214 0'

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Unit Reserve Shutdown Hours 0.0- 0.0 0.0 0.0 0.0 10.0 Gross Thermal Energy Generated (MWH)_ 2.471.383 1.545.139 . 1;165.937. 1.225.908: 0 608.844:

Gross Electric Energy Generated (MWH) 840.410 509.180 375.130' .403.7001 .0' T199.730?

Net Electric Energy Generated (MWH)- 808.488- - 481.799 -'343 870

. 378.444 0;

171.227-
- ,

RX Service Factor (%) < 100.0 100.0' 72. 7. . 68.8 10.0' > 31.4 ,

P Availability Factor (%) 100.0 100.0~ 100.0: -100.0 1100.0' '100.0~ -

s Unit a rvice Factor (%) .100.0 - 100.0 - 65'9. - 68.5' O.0- :29;7 e Unit Availability Factor-(%)- 100.0 100.0 -~

65.9: 68.5- 0.0' !29.7 Unit Capacity Factor-(%.using MDC net) 94.5 62.31 L40.2  :

45.8 0.0- >20.72 l%it Capacity Factor (%.using DER net) 94.5 : '62.3 - 40.2T 45.8L 00- ^20.7. ,

Unit Forced Outage. Rate (%)

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' 0.0. -: 0.0, _ . 34.1 - - 0.0 100.0. 170.3-Hours in Month 1744.0! 672:0L 744.0 - 719.0 .744.0- t720.0; Net MDC (MWe) Estimated .

1150.0 - 1150.0: 1150.0 '

1150.0 1150.0: 11150.0 l m .- -

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TABLE ~1.2-1:(PAGE!2 0F-2) Y 4 COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2

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MONTHLY ELECTRIC POWER GENERATION DATA (1994)- -

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~ Jg.ly Aucust - Seotember ' October: November'  : Decent)er '

Hours RX was Critical 728'0 . 599.0- '720.0- 161.0 198.0' '744.0-

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RX Reserve Shutdown Hours. :16.0 145.0- 0.0 .0.0 :1.0: 2 0.' 0 <

p Hours Generator On-Line 724.0 573.0 720.0 161.0 162.0

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- Unit Reserve Shutdow1' Hours 0.0 ~ 0.0 0.0 0.0 -0.0- -0;0; .

Gross Thermal Energy Generated (MWH) .2.417.832 1.728.622- 2.323.594 342.494. -317.364-- '2.53418511

' Gross Electric Energy. Generated (MWH) 808.280 573.540 781.520 112.870 100.050: '864.418 9 - j Net Electric Energy Generated (MWH) .773.340- 539.381 748.167 102.640! 82.961 ;832.833..

RX Service Factor (%)' 97 . - 80.6 100.0 21.7: -

27. 5 -c :100;01 '

RX Availability Factor (%) . 100.0 100.0- 100.0. ' 21;7 -- 27.7' L100.0! . _

Unit Service Factor (%) '97.3- - 77.0 100.0 21.6- 22.5f 100.0.

Unit Availability Factor (%)- .97.3 -77.0 - -100.0 :21-6 . ~22.5 ;100.0:

Unit Capacity Factor (%.using MDC~ net)- -90.4= 63.0 90.4- 112.0- 10.0 '97.3-Unit Capacity Factor (% using DER net) :90.4 -63.0' 190.4 -12.0 ? .10.0 J97.3-Unit Forced Outage Rate.(%)' 0.0 23.0 0.0 0.0 .0.8 20.0- J Hours in Month N4.0. 744'.0 7

720.0. 7410. '72020 744.0" _ .

a Net MDC (Mwe) Estimated 1150.0 - 1150.0- 1150.0 -1150.0 1150.0L 1150.0~ *,,

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TABLE'1.2-2~ m+-

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, 'ANNUALELECTRICPOWERGENERATIONDATAl(1994);

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h rM LyfA8L CUMULATIVE' a

[~ . Hours RX was ' Critical-' 5.829' 9.118 '

  • ' RX Reserve Shutdown Hours: 1.8261 2.154 1 z- ;

l5.696 Hours Generator. On-Line - 8.941-Unit Reserve Shutdown' Hours. 0.0 0.0 L

- Gross Thermal Energy Generated (MWH) 16.681.968 27.299[9261 lGrossElectricEnergyGenerated(MWH)- 5.568.828 9.156.055 ,

nh Net Electric Energy Generated..(MWH) '8.694,956 1 5.263.150 l

RX Service Factor (%)' '66.5- 73.7) W RX Availability Factor (%) 87.4 91.1 H

Unit' Service' Factor- (%) 65.0' 72.2

' Unit Availability Factor (%)

.65.0- -72.2!

-Unit Capacity Factor (%.using MDC net) 52.2 '61.1 Unit Capacity Factor (%.using DER net) 52.2 61.11 ...

' Unit Forced Outage Rate (%) 17.1 12.1.

Hours in Reporting Period 8.760 12.376 .

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CONANCHE PEAK STEAM ELECTRIC STATION:- UNIT.11 , .

UNIT OPERATING EXPERIENCE INCLUDING SHUTDOWNS AND, POWER-REDUCTIONS - -

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.c ' ~ ~

F: FORCED DURATION * 'THE REACTOR OR . .

fB QAIE S SCHEDULED (HOURS) REASON REDUCING POWER ' CORRECTIVE ACTIONS /CDPMENTS'- - - '5C 1 940201- F 50.93 A. ~3- Turbine /reactorEtrippedat21i382 dues  :

to spurious indications;of 1ow; main:) 23 '.g

. generator. stator. primary cooling water ', ^L flow; Unit was returned to MODEc1Tandi .

generator synchronized to the grid ata J 00:05 and 00:34.respectively'onJ

~

i February -4.11994 following1 . 1. -

troubleshooting activities which? #' ' "

~

indicated the'cause.of the problem.to: E

. be ;an sintennittant ground in thel power.

supply to the primary 1 water flof 7 -

_M;.. .

indication circuit "i.ER 445/94-0011., E

. dated February 28.;.1994- *

,i ,_ . , , .

2 940318 F" 20.00 A- . 4. :At approximately 23:15.zfeedwateri

~

1 heater valve 1C0-0122 lifted 'and. failed: g to reseat.1 Reduced powerilevelito 87%' '. e: '

until; heater relief-valve repairs.. a

~'

1

. comp 1eted.- M "

3 940320- F 0.001 -A. 4 Heater [drairi pumpL1-01 dripped at w _ . ,

21;28.)as maintenance personnel;were.

y' , troubleshooting high~ stator temperature-.

indication on the pimp. .:The;1oss of' - "

~

heaterdrainptmp"1-01: caused.a.untt! ~

0 . - ; turbine l runback) to1 approximately;70%

- power.' E Altered ventilation around thef ' ' e4 s -

pu.mp and cleaned u.p the filters:asi 4 4

1 ,-

~ e.

precautionary measure;to-reduce motorf

~

yrunning}emperature.LAn'.exactcausefofj

^^ '

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. Page 15 of 27:

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. TABLE:2.1'(PAGE-2 0F 4)' '

COMANCHE-PEAK STEAM ELECTRIC STATION -~ UNIT 1' -

UNIT 0PERATING EXPERIENCE INCLUDING SHUTDOWNS AND POWER REDUCTIONS. JJ .  ? [w METHOD OF a,  ;

TYPE F: FORCED . DURATION *-

SHUTTING DOWN-THE REACTOR OR-s

[" -

@ DATE S: SCHEDULED (HOURS)' REASON REDUCING POWER. CORRECT _lyf ACTIONS /CO MENTS-

" ~ "

the problem was~not determined.

4 940322 F 0.00' A :4 Reduced power to approximately 55k'to a.' ,

perform troubleshooting'on main : .

feedwater. pump:18 due.to acti,ve thrust bearing wear detector alarm in they control room at approximately 19:24.-

Replaced a failed annunciator card ; . -

-associated with the pump andfinitiated .a power increase.

    • 940510 NA NA -NA. NA On May-10. 1994 at 07-20. : control room missile shield door could not be closed due--to broken latching'  :
mechanismi Unit entered technical! ..

specification 3.0.3. -Closed

/ lockedi ,

'the control room missile shield door at4 approximately 07i37-upon comple' tion'of; _ <

repairs. .LER 445/94-002 dstedJune3.

< ;1994.;No power change occurred.-

5 940514 ~F

. 0.00 ~ ~A. 4 Noticed main feedwater pump-1A solenoid valve tubing oili. leak.'As a precautionary measure ' reduced power.to :

approximately 56% to troubleshoot and ,

, repais Replaced solenoid _valvel

~

~

' tubing and four solenoid. valves.due toe

~

'the' oil fouling from the leak?

xz =:v ~

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s _

Page'16 of. 27 - '

; 3 TA' ' l'(PAGE 3 0F 4).-

COMANCHE PEr .W ELECTRIC' STATION - UNIT 1 UNIT OPERATING EXPEF 4LUDING SHUTDOWNS AND POWER REDUCTIONS -

NETH00 0F -.

TYPE . SHUTTING DOWN

^ -

"N F: FORCED - DURATION * .THE REACTOR OR. o I '

19 .QA_TE .S: SCHEDULED (HOURS)- . REASON ' REDUCING POWER -CORRECTIVE' ACTIONS / COMMENTS -

6 940822 F 0.00 Al '4 Sheared fittiing during' maintenance'on : ' -

pressurized side.of isolation" valve;1- "

PIL2111-72 which resulted in oil. leak.:

leading to. loss of oil pressure and tripping of mainifeedwater. pump 1A. , 2:::

Replaced the sheared fitting and returned the pump to service.~. .

Subsequent. investigation ' revealed a :

' material defect as the most likely? ~_

m cause of the failure.

Turbine / reactor tripped at 21:20 due tok

~ ^

7 941129 F 27.00. A- 3-generator primary water stator low flow 1 .

signal. 1The low flow indication was' .

' result of gas coming from s'olution in, the primary water differential pressure. ~

. sensing lines causing erroneous-

~ indications. Re-sloped :linstriment

~

tubing to aid in venting'and maintained, '

de-energized state.for the heat trace? ,

with the turbine in operation to i minimize gas coming out of solution..

'8 941201' F 19.00 .AT 3 Continued outage due.to turbine /reactorJ

~

I trip.with testing of:the generator-y .. -

. primary water system in progress. ; Unit:

. entered MODE:1 at.18:07 Land generator.-

synchronized toLthe grid at 18:503 _

respectively;cn-Decembe61.1994.TLER"

. 445/94-006 dated December 29.?1994.

t I

s ,

. .. - ~ . ~ . . . . . . .

Attachment to TXX-95011 ~f Page 17 of 27 .

TABLE 2.1 (PAGE 4 0F 4)

COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 UNIT OPERATING EXPERIENCING INCLUDING SHUTDOWNS AND POWER REDUCTIONS- . z.

METHOD OF TYPE SHUTTING DOWN F: FORCED DURATION

  • THE REACTOR OR N_Q DAJE 5: SCHEDULED (HOURS) REASQN REDUCING POWER CORRECTIVE ACTIONS / COMMENTS' 9 941202 F 10.00 A 4 Turbine tripped at 02:03 as a result of' generator lockout actuation. A misaligned auxiliary switch contact from the generator output disconnect.

switch caused the lockout actuation.

Repaired the disconnect switch. The rj generator was synchronized to the grid at.approximately 12:41.

1) REASON 2) METHOD -

A: EQUIPMENT FAILURE (EXPLAIN) E: OPERATOR TRAINING AND LICENSE EXAMINATION. 1: MANUAL B: MAINT OR TEST F: ADMINISTRATIVE- 2: MANUAL SCRAM C: REFUELING G: OPERATIONAL ERROR (EXPLAIN) 3: AUTOMATIC SCRAM D: REGULATORY RESTRICTION H: OTHER (EXPLAIN) 4: OTHER (EXPLAIN).

  • INDICATES SHUTDOWN HOURS
    • AN EVENT WHICH DID NOT REQUIRE UNIT SHUTDOWN /SIGNIFICANT POWER CHANGES FOR CORRECTIVE ACTIONS (NA-~MEANS-NOT APPLICABLE)

= -

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. ^ , ei" - V W} QPb w '7Wwi ggi y J

1 ._

m.-y MTABLE 2.2 (PAGE 1 0F 9) <1 *

  • COMANCHE PEAK STEAM ELECTRIC STATION . UNIT 2-

~

N.i D ' _M"f 42 UNIT OPERATING EXPERIENCE INCLUDING SHUTDOWNS AND POWER REDUCTIONS:' 4

< - ~.. .

+ ,

A ,. 4 METHOD OF _

~

TYPE . SHUTTING DOWN' * '

~

F: FORCED ~ DURATION

  • s -THE REACTOR OR T . . . .. i- ,

. .s ,

@. - MTf . -5: SCHEDULED (HDURS)  : REASON REDUCING POWER CORRECTIVE ' ACTIONS /COPMENTS1 4

_3

electric. governor,igovernor. booster.' servos y motori motor. operated potentiometer:and3 . ~ f2

' normal ~voltageregulator;iSpecial) reports; 5 2-SR-93-004 dated January 2N 1994~and'2-D '

SR--94-001l dated January,21.n1994J -

4

    • : 940119 NA NA ' NA ' NA ~ Reduced' power to;981 with electro-hydraulicy , _

< control-(EHC).at 98%.and mechanical..

hydraulic control (MHC) at'100% due:to' ~

+

. minor turbine. load swings caused by i ~

intermittent problems; associated.with; '

turbine speed input'to EHC.!With the PNC atz --

  1. 1002.' upward load swing was;1imited by MiC_ ~ '

A

. control system.

1 940129 S- 0.00; H 4  ! Commenced operation 'at 8K nower for: fuel:- , q..

. Cycle' optimization. , ,

M

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Attachment to TXX-95011 -

Page 19 of 27 ,

TABLE 2.2 (PAGE 2 0F 9)

COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 UNIT OPERATING EXPERIENCE INCLUDING SHUTDOWNS AND POWER REDUCTIONS .

METHOD OF TYPE SHUTTING DOWN F: FORCED DURATION * .THE REACTOR OR fiQ E S: SCHEDULED (HOURS) REASON REDUCING POWER CORRECTIVE ACTIONS / COMMENTS.

2 940204 S 0.00 H~ 4 Further reduced power to 55%.' On February

10. increased power to.100% to support TU-Electric system demand. . Reduced power to 80% on February 11. 1994, followed by reduction in power to 55% on February 14.-

1994 and increased power to 73% on February

25. 1994, for. fuel cycle optimization purposes. On February 13. 1994 moisture separator reheaters (MSRs) were taken out of service for miscellaneous balance of

~

plant maintenance and on February 27.L 1994 feedwater heater was taken out of service' for preventive maintenance inspections and repaired the associated heater drain valves. Unit ended the month ~with reactor-power at 75%.

3 940305 F 189.82 A 2 Manually tripped the reactor at 14:29 upon experiencing load swings of 100 MWe on the main turbine. Commenced troubleshooting on EHC system. On March.6. 1994 feedwater-heaters 1B and 2B returned to service and-feedwater heaters IA and 2A removed from service.for preventive maintenance "

~ inspections and put back in service on March 11. 1994. Unit entered MODE 1 at 10:55 and generator synchronized to the grid at 12:18 on March 13. 1994. LER' 446/94-003 dated March 31. 1994.

m i

Attachment to TXX-95011 '

Page 20 of 27 .

j

' ~-

TABLE 2.2 (PAGE 3 0F 9)

COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 >

1 UNIT OPERATING EXPERIENCE INCLUDING SHUTDOWNS AND PCMER REDUCTIONS .

METHOD OF TYPE SHUTTING 00WH F: FORCED DURATION

  • THE REACTOR OR

_N_Q DAIE S: SCHEDULED (HOURS) REASON REDUCING POWER CORRECTIVE ACTIONS / COMMENTS

~

4 940313 F 29.00 A 1 During restart of unit. turbine.

control valves- abruptly closed.

Operators manually tripped the turbine ganerator at 16:47 (a reactor trip was not required). The cause of the load swings was considered as intermittent shorting followed by failure of the feedback (Collins) coil in the EHC system.

On March 14. 1994 at 21:47 generator synchronized to the grid following replacement of the failed coil and the unit maintained at 72% '

power on March 16. 1994 for fuel-cycle optimization.

5 940319 F 35.25 A 1 Unit taken off line at 23:49 to allow troubleshooting of high temperature alarm on reactor coolant ptznp (RCP) 2-04 lower radial bearing. Oil from a leaking bushing fouled a temperature detector '

causing. false' indication of high temperature. Replaced the RTD and its holder and cleaned the wiring connection at the tenninal block.

Unit entered MODE 1 at'10:27 and synchronized the generator to the grid at 11:04 on March 21. 1994.

-Unit maintained at 73% reactor power.

for uel cycle optimization.

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' ~~_w Page 21 of 27 -

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4

' TABLE 2.2-(PAGE 4 0F 9)

~

COMANCHE PEAK STEAM ELECTRIC STATION -' UNIT 2 - '

UNIT OPERATING EXPERIENCE' INCLUDING SHUTDOWNS AND POWER REDUCTIONS' .

^

a ^

' METHOD OF

~

TYPE- SHUTTING DOWN .. . 1,.

F: FORCED DURATION *- THE REACTOR OR

.N_Q M[E S: SCHEDULED (HOURS) REASON  : REDUCING POWER ' CORRECTIVE ACTIONS /C0mENTS1 6 940421 S- 226.42 B 1 Commenced dow" power at 02:15.to begin mid cycle outage. At 13:35, while unitrati >

approximately 15% power and while the, main T -

turbine was being transferred from loadi controltospeedcontrol.3theunitig .

experienced turbine 11oad swings ~of x about ;

50 to 60 W e due to a personnel error.-

lduring shutdown and the turbine was>

. manually tripped. 'Also on April;22.11994 .?

.while performing scheduled: testing on the solid state. protection. system (SSPS); Train -

8 and shutdown rods'still withdrawn 7 a reactor. trip signal was: generated due toi spike on a nuclear instrumentation sourcel range channel. Shutdown rods-were- .

automatically inserted on the reactor. trip -

signal. LER 446/94-004 dated May;23.11994.

7 '940501 S 504.00 B 1 Mid-cycle outage continued. >

8 940522 F ~240.00 A 4 Ended planned mid-cycle outage: ' began; forced outage at-00:00 due to repairsLto

~

! system;- f Pump vibration caused ~ welds in -

small bore piping' branch ? connections to; experience fatigue cracking.' ~

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Page 22 of 27 ,

TABLE 2.2 (PAGE 5 0F 9)-

COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 UNIT OPERATING EXPERIENCE INCLUDING SHUTL%HS AND.PCWER REDUCTIONS ..

METHOD OF TYPE SHUTTING DOWN F: FORCED DURATION

  • THE REACTOR OR. e N_Q ME' S: SCHEDULED (HOURS) REASQN REDUCING POWER CORRECTIVE ACTIONS /COME!ES 9 940601 F 448.00 A 4 Forced outage continv A due to the containment spray system cracked welds in piping connections. Upon completing weld / pipe-support repairs. perfomed-extensive vibration tests. Unit entered MODE I at 15:05 and generator synchronized to the grid at 16:07 on June 19.1994. LER 446/94-005 dated June 17. 1994 10 940627 F 58.00 A 3 Turbine / reactor tripped at *. 9 due to' damaged cable to the phase B generator differential relay current transformer.

Replaced cables to all current' transfomers: performed inspections and tests on current transformer for evidence of damage'or degradation as well as tested.

all relays in generator protection . .

circuitry. Unit entered MODE 1 at 01:42 and generator synchronized to the grid at 02:43 on June 30.~ 1994. LER 446/94-010

' dated July 22.1994.

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, Page 23 of.27 _

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. TABLE 2.2 (PAGE 6 0F 9) -

1 COMANCHE PEAK STEAM ELECTRIC STATION '- UNIT 2 - . i UNIT OPERATING EXPERIENCE INCLUDING ~ SHUTDOWNS AND POWER REDUCTIOht .

  • -M

- METHOD OF ~

TYPE SHUTTING DOWN 4 F: FORCED DURATION

  • THE REACTOR OR NQ QAE S: SCHEDULED (HOURS) ' REASON REDUCING POWER CORRECTIVE ACTIONS /COPNENTS:

11 940708 5 20.00 A; 1 At 20i30 commenced power reduction for main :

generator current::transfonner repairs.

Thennography' indicated that' conduits and =

cables'to current transformers were-overheatingduetoelectromagneticfield0 inducing heating in ferromagnetic conduit.

1 Tripped main turbine. generator:at'06:01:on? T

. July 9.1994. _ Replaced cables with high:

temperature design and conduits:with non-: _

ferromagnetic material following MODE 3 '

entry at 07i07. Unit entered MODE 1~at 00:54 and: generator synchronized to theb grid at' 01:50 on July 10.' 1994.'

12 940815 F- -124.00 .A 2 Reactor tripped manually at 10:45 from 75%~

reactor thermal power c(RTP) due to oil:

11eak to the'C-phase bushing of main:

transfonner 2MT2. Drained' oil ~from the :

transformer and replaced the;1eaking..

bushing. : Transformer; filled with oil and -

. satisfact'orily tested < Unit. entered .MODEll-at 14:32 and' generator synchronized to the?

grid at 14:45 on August 20 J1994.- : LER :

446/94-012 dated September 13. 1994.

'N-e.

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Page 24 of 271 .

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-TABLE 2.2 (PAGE-7 0F.9)  : * ~

CONANCHE. PEAK STEAM ELECTRIC STATION - UNIT 2.? s W <

UNIT OPERATING EXPERIENCE' INCLUDING SHUTDOWNS'AND POWER REDUCTIONS 1 ~, ,  ?;ji METHOD OF. w ,

TYPE . SHUTTING DOWN'  ; - ' ' --

F: FORCED DURATION *- THE REACTOR OR -

1

~

EQ DA_TI T  : S: SCHEDULED (HOURS) REASON REDUCING POWER CORRECTIVE ACTIONS / COP 91ENTS ,

13 940824 F 0.00 A1 4  : Rise in' auxiliary condenserilevel indicated!  ::

~

I

~

Lpossible tube rupture; The" unit.was h

~

~

rapidly down powered to approximately 50tj reactor thermal powerL(RTP) to securel <

condenser and main feed pump r.Later; determined the cause to be-air lin-leakage';

around' conductivity'cellinterferingwithi condenser drains;= On August 31? 1994.lthei ' -

leak was isolated and the auxiliary - ,

' condenser. water level was returned;to :

nonnal -

14 940827 F 35.73- :A 1  : Turbine tripped manually at 08i16 for unit 1 - -

shutdown ~due to axial flux out of limits asJ .gf a result.of rapid ; down. power late--in' core -

life;(from auxiliary condenser problem).

. Unit entersd MODE 1:atL18:49 and generators synchronized to,the grfd'at 20iOO on August?

.28."1994. ,

,s ,

15 940829 F 11.67 LAl 4- - - Turbine trippdd manually t 00:15 while' transferring non IE busesion startup.:Ar misadjustedcamswjtch.Onmaingenerator

~ fdisconnect 8022 caused the trip. 1

Readjusted _the switch. Lunit entered.. MODE'l~ g.

..'at11:00-and1.synchronizedthegeneratorftol

the grid ~at 11:55  ?

u.

~

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- ~

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m TM N N Page 25 of 27 ' -

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~

~

a-yp TABLE 2.2 (PAGE 8 0F 9)! _

~ ~ , :S COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 .N UNIT. OPERATING EXPERIENCE INCLUDING SHLrTDOWNS AND POWER REDUCTIONS 1 N+

METHOD OF.  ; ..,

TYPE . SHUTTING DOWN2 F: FORCED DURATION * .

THE' REACTOR OR .

T L. ^'

.NQ .

DA_. 5: SCHEDULED (HOURS)~ REASON REDUCING POWER  : CORRECTIVE ACTIONS /COPMENTS.. -

16 940928 .F 0.00 A- -4 Main ~feedwaterpump28takenoutofservice; ,

'due.to failed bearing; 2 Unit. ended'the?

month at 26% reactor power with the mainf H

~

ffeedwater pump 28 out of; service.

~

~-

17 941001 F 0.00 LA- 4 iUnitcontinuedoper$tionat26%' reactor:

power with the main feedwater pump' out 'of. -

. service.:Powerheldat26%toallowxenonj _

- oscillationLto ' dampen. : On October:2,;1994E

-at 20:00' xenon stabilized and raised the: '

reactor power level tc 53%; --On October 4, 1994 at 0030;; increased to 100% reactor {

~

power-:upon completing' replacement of the.

failed . bearing (pump- 1_nboard bearing): and -

. the damaged pump shaft ~as well;as the'

, winspection the lube. oil' system.to' remove-anyfdebris from' theifailed bearing Jor-anyi debris ? potentially caused. ther' bearing; failure.

18 941006 5 584.00 C 1- .' Commenced power reduction for first?

refueling outage.: Tripped the turbine Lgeneratorandthe'reactorrespectively:at.

116:34'and 17:20 on October 7,11994.and- ~

core. offloaded at-08:08: on October 10. -

1994.' -

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Page 26 of 27 - .

TABLE 2.2 (PAGE 9 0F 9)

COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 UNIi 'ERATING EXPERIENCE INCLUDING SHUTDOWNS AND POWER REDUCTIONS .

METHOD OF TYPE SHUTTING DOWN F: FORCED DURATION * .THE REACTOR OR HQ DAIE S: SCHEDULED (HOURS) RMSDM REDUCING POWER CORRECTIVE ACTIONS / COMMENTS 19 341101 5 557.00 C 1 First refueling outage continued. Following the refueling outage,. reactor entered f criticality at 18:01 on November 22. 1994.

l Unit entered MODE 1 at 03:39 and generator.

l synchronized to the grid at 04:56 on November 24, 1994.

l 20 941124 F 1.00 G 4 Turbine tripped at 09:25 due to high generator primary water temperature.

Operator failed to adjust cooling water while controlling in manual with increasing turbine load. Synchronized the generator to the grid at 10:48. Unit ended the month with 90% reactor thermal power and increased to 1001 reactor power on December

1. 1994.
1) REASON 2) METHOD A: EQUIPMENT FAILURE (EXPLAIN) E: OPERATOR TRAINING AND LICENSE EXAMINATION 1: MANUAL B: MAINT OR TEST F: . ADMINISTRATIVE 2: MANUAL SCRAM C: REFUELING G: OPERATIONAL ERROR (EXPLAIN) 3: AUTOMATIC SCRAM D: REGULATORY RESTRICTION H: OTHER (EXPLAIN) 4: OTHER (EXPLAIN) f '* INDICATES SHUTDOWN HOURS
    • AN EVENT WHICH DID NOT REQUIRE UNIT SHUTDOWN /SIGNIFICANT POWER CHANGES FOR CORRECTIVE ACTIONS (NA- MEANS NOT APPLICABLE)
u. - _ _ _ _ - - _ - _ .

&y w p 'wQ; !:M ,

f? ,

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1 '

  • Atiachmentito;TXX295011  ;

'%- ;Pagel.7ot27f q '

' TABLE 3.0

+ .

' ~

'. COMANCHE PEAK STEAM ELECTRIC STATIONf- UNITS 1 AND 2. d PERSONNEL EXPOSURE'AND-MONITORING REPORT.

/

^ ' ]'

.  :# Personnel U100 mrem)' Total Person . Rem ,

" Work & Job function Station, . Utility._ Contract . Station 1 Utility Contract .  ;

[ Reactor' Operations'& Surveillance, ,

'"~F

' Hafntenance & Construction- 0' 0' 15 . .041' .000 S.601

u Operations- '7 0~ 3 4.405 14.405i 11.366
s. ' Health Physics & Lab: 5' O. 22 ' 1.773 1.773. 7.059~

[ Supervisory & Office Staff 'O O '0 J25 .125 .086- .,

-Engineering Staff 0 0 4 .481- ,481- 895g ,

Routine Plant Maintenance

, Maintenance & Construction .14 0 ' 76 :4.490- .000 25.743' 'i Operations 1 0' 0 .440= .000 .383 *

' Health Physics & Lab .

0- 0 .4- .161 .000 ._1.373

,  ; Supervisory & Office Staff 0 0 0 .079 .055 .006' ,

Engineering Staff 0 0 0 . 0% .000 .731 :i

[InserviceInspection

. Maintenance & Construction- 0 0 37 .037 .000 9.460 10perations .

2 0 3 .302 .000 .4% ..

, Health Physics & Lab 1 -0 6- .182 .000 . 1,406 : -

. Supervisory & office Staff 0 0 0 .000 000 .000-Engineering Staff 'O O 0 .000 .000~ .128 Special Plant Maintenance . .

Hair.tenance & Construction . 0 0 19 .083 .000. '7.294 i Operations 0 0 2 .052 ,000 .392- r  !

Health Physics & Lab 1 0- 0 0 .003 .000 .044 Supervisory & Office Staff 0 0 0 .002 .000. .030 Engineering Staff 0 0 0 .000 .000 .190  %

l LWaste Processing ..

5{

Hatntenance & Construction 0 0 0 4168 .000- .493 Operations 1 0 1 .703 .000 , 1.862' I

, Health Physics & Lab 0 0 0 .338 .000 1.032 =;

Supervisory & Office Staff 0 0 0 .000 .000 .000 Engineering Staff 0 0 0 .022 .000 011

b

' Refueling ' .

^f Haintenance & Construction 0- .0 27 .084 .000 8.330 Operations 0 0 0 .164- .000' .141 -1 Health Physics & Lab

' Supervisory & Office Staff 0

0 0 0 2 0

047.

.145

.000

.000 1.071

.000 j r Engineering Staff- 0 0 0 .066 ' .000

.147 i 4 .

[

Totals " ,

Halntenance & Construct 1ui 16 0 192 4.903 .000 56.921 '

. Operations' 0 8 6.066 .018 4.641

, ~ Health Physics & Lab - 8 0 41 2.504 .000 11.986

. Supervisory & Office Staff . 0 0 0 .351 .073 .122 i

'Eng1reering Staff 1 0 4 .665 .016 2.101  !

.i Grand Totals 38 0 245 14.489 ,107 75.771 '!

.i .

'f ,

. . _ _ . _ _ _ _ ___.____.__m

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