TXX-9401, Annual Operating Rept 1993
| ML20064C728 | |
| Person / Time | |
|---|---|
| Site: | Comanche Peak  |
| Issue date: | 12/31/1993 |
| From: | William Cahill, Woodlan D TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC) |
| To: | NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM) |
| References | |
| TXX-94012, NUDOCS 9403100188 | |
| Download: ML20064C728 (24) | |
Text
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_=== tllllllllll Log # TXX-94012
, 7 File # 10250
,_, c Ref. # 10CFR50.36
TUELECTRIC February 28, 1994 M liliam J. Cahill, Jr.
Group Vwe hesiderrt U. S. Nuclear Regulatory Commission Attention: Document Control Desk Washington, DC 20555
SUBJECT:
COMANCHE PEAK STEAM ELECTRIC STATION (CPSES) - UNITS 1 AND 2 DOCKET N05. 50-445 AND 50-446 ANNUAL OPERATING REPORT FOR 1993 Gentlemen:
Attached is the CPSES Annual Operating Report for 1993 prepared and i submitted 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 complies with the annual operating report guidance provided in position j C.1.b of U.S. NRC Regulatory Guide 1.16 Revision 4. I If you have any questions, please contact Mr. Jacob M. Kulangara at (214) 812-8818. 1 l
I Sincerely, l l
l William J. Cahill, Jr.
By:
D. R. Woodlan Docket Licensing Manager JMK/jmk Attachment
- -Mr. L. J. Callan, Region IV Resident Inspectors. CPSES (2)
Mr. T. A. Bergman, NRR Mr. A. B. Beach, Region IV
%-3:3 pT 9403100188 931231 5 I I PDR ADOCK 0500 R 4to N. Olive Street LB. 81 Dallas, Texas 75201
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COMANCHE PEAK STEAM ELECTRIC STATION l 4
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l ANNUAL OPERATING REPORT 1993 i
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TABLE OF CONTENTS l
1.0 Summary of Operating Experience 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 i
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1.0 SUIMARY OF OPERATING EXPERIENCE The Comanche Peak Steam Electric Station (CPSES) is a dual unit pressurized water reactor power plant, each unit licensed at 3411 Megawatt thermal (MWt). It is located in Somervell County in North Central Texas approximately 65 miles southwest of the Dallas-Fort Worth Metropolitan ,
The nuclear steam supply system was purchased from Westinghouse l
area.
Electric Corporation and is rated for a 3425 MWt output.
1.1 CPSES UNIT 1 CPSES Unit 1 achieved initial criticality on April 3,1990. Initial power
! generation occurred on April 24, 1990, and the plant was declared l commercial on August 13, 1990. Since being declared commercial, CPSES Unit 1 has generated 21,995,851 net Megawatt-hours (MWH) of electricity as of December 31, 1993, with a net unit capacity factor of 64.4% (using MDC). The unit and reactor availability factors were 79.2% and 81.2% l l respectively for the year 1993.
On October 5, 1993, power reduction was initiated for the unit for its l third refueling outage and the main turbine was tripped on October 6,1993, l for the outage. Overall, the outage was successful in its implementation .
l with a duration of 70 days. Eighty-eight fresh fuel assemblies were loaded !
for Cycle 4. The unit was returned to service on December 16, 1993.
During the refueling outage the major work scope included:
- Snubber Functional Testing
- Steam Generators 1-01 and 1-04 Eddy Current Testing i
- Motor Operated Valve Testing I
- Containment Integrated Leak Rate Testing
- Reactor Vessel Nozzle Inspections
- Repair of Shrouded Blades on LP1 and LP2 Turbines
- Changeout of Main Transformer 1MT1 for Refurbishment
- Diesel Generator Train A and Train B Maintenance, Inspections and Testing
- ECCS Forward Flow Testing
- Replacement of Plant Computer
- Train A and Train B Integrated Test Sequence (ESFAS)
- Fuel Assembly Inspections including Identification of Leaking Fuel l Figure 1.1-1 provides the generation profile of the average daily net electrical output of Unit 1 for 1993. 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.
Attachment TXX-94012 l
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i 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 4
commercial on August 3, 1993. Since being declared commercial, CPSES Unit 2 has generated 3,441,806 net Megawatt-hours (MWH) of electricity as i of December 31, 1993, with a net unit capacity factor of 82.5% (using MDC). )
i The unit and reactor availability factors were 89.8% and 100.0%
respectively.
Figure 1.2-1 provides the generation profile of the average daily net
. electrical output of Unit 1 for 1993. 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 2.1 CPSES UNIT 1 Table 2.1 describes plant shutdowns and provides explanations of significant dips in average power levels for CPSES Unit 1.
2.2 CPSES UNIT 2 l
Table 2.2 describes plant shutdowns and provides explanations of I significant dips in average power levels for CPSES Unit 2.
3.0 EXPOSURE AND MONITORING REPORT The personnel exposure and monitoring report for CPSES is provided in Table 3.0.
4.0 REPORT OF RESULTS OF SPECIFIC ACTIVITY ANALYSIS IN WHICH THE PRIMARY COOLANT EXCEEDED THE LIMITS OF TECHNICAL SPECIFICATION 3.4.7 l Technical Specification 6.9.1.2.b requires the reportability of results of specific activity analyses in which the primary coolant exceeded the limits of Technical Specification 3.4.7.
CPSES Units 1 and 2 have not exceeded the limits of Technical Specification 4
3.4.7 for the calendar year of 1993.
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5.0 IRRADIATED FUEL INSPECTION RESULTS 5.1 CPSES UNIT 1 TU Electric currently utilizes a system termed "in-mast sipping", which was installed and qualified by Westinghouse, for fuel assembly leak detection. "In-mast sipping" is performed from the refueling machine mast during core off-load and the system relies on the detection of fission product gases from leaking fuel assemblies.
During the third refueling outage in October 1993, in-mast sipping and underwater camera visual inspections were performed on the Cycle 3 fuel during the core off-load process. The results of in-mast sipping indicated leaking fuel in assemblies C28 and C07. Ultrasonic Testing was subsequently performed on the two assemblies and revealed one leaking rod in assembly C28 (rod location M3) and one leaking rod in assembly C07 (rod location C15). The in-mast data was reviewed to conservatively assure that all possible suspect assemblies were selected for Ultrasonic Testing.
l Visual examination of leaking fuel assembly C28 revealed that the fuel rod in location M3 had grown approximately one-half inch taller than the l remainder of the rods in the assembly. Occasionally, fuel rod defects l will result in accelerated rod growth. Visual inspection of leaking assembly C07 showed no unusual indications. Since both leaking rods were located in the interior of their respective assembly, visual identification of the cause of the leaking rods could not be performed. Both fuel assemblies C28 and C07 were originally scheduled for discharge during the third refueling outage.
During visual examinations, the Cycle 3 fuel appeared to be in excellent condition, overall. In general, there was an unexpectedly light amount of " crud" observed on the rods; particularly on the higher burnup fuel.
On most assemblies, the normally expected amount of " crud" was observed only at the top portion of the fuel rods, if at all. There was also no grid strap damage observed on any fuel assemblies.
Also, during the visual examinations, an anomaly was observed on face number 2 of the top nozzle of assembly E55. Face 2 of the assembly was located against the core baffle. The anomaly appeared as a dark circular indication of approximately two inches in diameter. No significant depth to the anomaly was observed. A video tape copy of the inspection was sent to Westinghouse where it was concluded that the anomaly should not affect I the future performance of the assembly, which is scheduled for use in Cycle
- 4. The precise cause of the anomaly has not yet been determined. No other l significant anomalies were observed on the remainder of the fuel assemblies.
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5.2 CPSES UNIT 2 CPSES Unit 2 has not entered a refueling outage since achieving initial criticality on March 1993, and irradiated fuel examinations have not been performed for the Unit.
i 6.0 OUTAGE RELATED SINGLE RADI0 ACTIVITY RELEASE OR RADIATION EXPOSURE TO AN INDIVIDUAL THAT ACCOUNTS FOR MORE THAN 10 PERCENT OF ALLOWABLE ANNUAL VALUES CPSES Units 1 and 2 did not experience any single release of radioactivity greater than 10% of an allowable dose limit during an outage or forced 1 reduction in power of over 20 percent of designed power level during 1993.
While CPSES Unit 1 was in the scheduled third refueling outage, CPSES experienced radiation exposures to an individual of greater than 500 mrem which exceeds 10% of the allowable annual dose limit of 5000 mrem. Table 6.0 provides a synopsis of the dose received during this period (the outage) which contributed to greater than 500 mrem for a single individual.
The dose values were derived from reviewing the Thermoluminescent Dosimeter (TLD) data corresponding to the individual's TLD processed for the fourth quarter of 1993, even though the refueling outage was during October 6 through December 16, 1993. Although the TLD monitoring period was longer than the outage duration, a significant contribution of the dose was received during the outage for each individual.
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FIGURE 1.1-1 l COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 GENERATION PROFILE AVERAGE DA!LY UNIT POWER LEVEL 1,200 Actual Power w Cm pm# ~VWW ~
1,000 .
\ 1 800 E
5 e
600 400 200 ,
1RFO3 0
JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC
Attachment to TXX-94012 Page 8 of 23 -
TABLE 1.1-1 (PAGE 1 OF 2)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 ,
MONTHLY ELECTRIC POWER GENERATION DATA (1993)
January February March April May June Hours RX was Critical 704.4 672.0 744.0 719.0 744.0 694.4 RX Reserve Shutdown Hours 39.6 0.0 0.0 0.0 0.0 25.6 Hours Generator On-Line 688.8 672.0 744.0 719.0 744.0 686.2 Unit Reserve Shutdown Hours 0.0 0.0 0.0 0.0 0.0 0.0 Gross Thermal Energy Generated (MWH) 1,950,103 2,269,738 2,434,910 2,326,877 2,493,823 2,240,426 Gross Electric Energy Generated (MWH) 667,267 766,531 816,313 766,050 838,023 746,685 Net Electric Energy Generated (MWH) 633,961 735,925 782,208 733,348 802,475 712,442 RX Service Factor (%) 94.7 100.0 100.0 100.0 100.0 96.5 RX Availability Factor (%) 100.0 100.0 100.0 100.0 100.0 100.0 Unit Service Factor (%) 92.6 100.0 100.0 100.0 100.0 95.3 Unit Availability Factor (%) 92.6 100.0 100.0 100.0 100.0 95.3 Unit Capacity Factor (%,using MDC net) 74.1 95.2 91.4 88.7 93.8 86.0 Unit Capacity Factor (%,using DER net) 74.1 95.2 91.4 88.7 93.8 86.0 Unit Forced Outage Rate (%) 7.4 0.0 0.0 0.0 0.0 4.7 Hours in Month 744.0 672.0 744.0 719.0 744.0 720.0 Net MDC (MWe) Estimated 1150.0 1150.0 1150.0 1150.0 1150.0 1150.0
Attachment to TXX-94012 Page 9 of 23 .
TABLE 1.1-1 (PAGE 2 0F 2)
CDMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 MONTHLY ELECTRIC POWER GENERATION DATA (1993)
July Aucust September October November December Hours RX was Critical 744.0 744.0 720.0 141.0 0.0 394.0 RX Reserve Shutdown Hours 0.0 0.0 0.0 0.0 0.0 30.0 Hours Generator On-Line 744.0 744.0 720.0 139.0 0.0 333.0 Unit Reserve Shutdown Hours 0.0 0.0 0.0 0.0 0.0 0.0 Gross Thermal Energy Generated (MWH) 2,534,069 2,522,482 2,443,056 444,324 0.0 794,170 Gross Electric Energy Generated (MWH) 846,814 833,587 810,579 148,735 0.0 259,508 Net Electric Energy Generated (MWH) 810,578 797,753 776,316 136,414 0.0 232,055 RX Service Factor (%) 100.0 100.0 100.0 18.9 0.0 52.9 RX Availability Factor (%) 100.0 100.0 100.0 18.9 0.0 57.0 Unit Service Factor (%) 100.0 100.0 100.0 18.7 0.0 44.7 Unit Availability Factor (%) 100.0 100.0 100.0 18.7 0.0 44.7 Unit Capacity Factor (%,using MDC net) 94.7 93.2 93.8 15.9 0.0 27.1 Unit Capacity Factor (%,using DER net) 94.7 93.2 93.8 15.9 0.0 27.1 Unit Forced Outage Rate (%) 0.0 0.0 0.0 0.0 0.0 12.2 Hours in Month 744.0 744.0 720.0 745.0 720.0 744.0 Net MDC (Mwe) Estimated 1150.0 1150.0 1150.0 1150.0 1150.0 1150.0
Attachment.to TXX-94012 Page 10 of 23 TABLE 1.1-2
. COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 ANNUAL ELECTRIC POWER GENERATION DATA (1993)
YEAR CUMULATIVE Hours RX was Critical 7,020 22,539
, RX Reserve Shutdown Hours 95 2,354 Hours Generator On-Line 6,934 22,093 )
Unit Reserve Shutdown Hours 0.0 0.0 Gross Thermal Energy Generated (MWH) 22,453,978 69,749,805 Gross Electric Energy Generated (MWH) 7,500,092 23,135,257 Net Electric Energy Generated (MWH) 7,153,475 21,995,851 RX Service Factor (%) 80.1 75.9 1
. RX Availability Factor (%) 81.2 83.9 4
Unit Service Factor (%) 79.2 74.4 Unit Availability Factor (%) 79.2 74.4 I Unit Capacity Factor (%,using MDC net) 71.0 64.4
! Unit Capacity Factor (%,using DER net) 71.0 64.4 Unit Forced Outage Rate (%) 1.9 6.1 Hours in Reporting Period 8,760 29,681 l
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Attachment to TXX-94012 Page 11 of 23 FIGURE 1.2-1 COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 GENERATION PROFILE AVERAGE DAILY UNIT POWER LEVEL 1,200 Actual Pow - r_-_.-- , yl p-i 1,000 4
800 [
t s:
600 400
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200 0
JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC 4
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TABLE 1.2-1 (PAGE 1 0F 2)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 MONTHLY ELECTRIC POWER GENERATION DATA (1993)
January February March April May June Hours RX was Critical NA 3.0 171.2 508.0* 326.0 0.0 RX Reserve Shutdown Hours NA 0.0 0.0 0.0 418.0 720.0 Hours Generator On-Line NA 0.0 0.0 508.0 279.0 0.0 Unit Reserve Shutdown Hours NA 0.0 0.0 0.0 0.0 0.0 Gross Thermal Energy Generated (MWH) NA 0 0 665,234 499,853 0 Gross Electric Energy Generated (MWH) NA 0 0 168,070 152,610 0 Net Electric Energy Generated (MWH) NA 0 0 139,519 129,268 0 RX Service Factor (%) NA NA NA NA NA NA RX Availability Factor (%) NA NA NA NA NA NA Unit Service Factor (%) NA NA NA NA NA NA Unit Availability Factor (%) NA NA NA NA NA NA Unit Capacity Factor (%,using MDC net) NA NA NA NA NA NA Unit Capacity Factor (%,using DER net) NA NA NA NA NA NA Unit Forced Outage Rate (%) NA NA NA NA NA NA Hours in Month 744.0 672.0 744.0 508.0* 744.0 720.0 Net MDC (MWe) Estimated 1150.0 1150.0 1150.0 1150.0 1150.0 1150.0 0 Denotes hours following initial generator synchronization (note reactor was critical for 211 hours0.00244 days <br />0.0586 hours <br />3.488757e-4 weeks <br />8.02855e-5 months <br /> in April prior to ,
initial synchronization)
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TABLE 1.2-1 (PAGE 2 JF 2)
COMANCHE PEAX STEAM ELECTRIC STATION - UNIT 2 MONTHLY ELECTRIC POWER GENERATION DATA (1993)
July Auaust September October November December Hours RX was Critical 628.0 744.0* 430.0 745.0 682.5 744.0 RX Reserve Shutdown Hours 116.0 0.0 290.0 0.0 37.5 0.0 Hours Generator On-Line 519.0 744.0* 406.0 745.0 663.0 744.0 Unit Reserve Shutdown Hours 0.0 0.0 0.0 0.0 0.0 0.0 Gross Thermal Energy Generated (MWH) 1,398,238 2,506,311 1,317,156 2,397,394 2,063,460 2,512,502 Gross Electric Energy Generated (MWH) 454,120 842,230 441,350 809,500 698,030 855,730 Net Electric Energy Generated (MWH) 421.120 808,757 417,205 774.195 666,354 822,318 RX Service Factor (%) NA 100.0 59.8 100.0 94.8 100.0 RX Availability Factor (%) NA 100.0 100.0 100.0 100.0 100.0 Unit Service Factor (%) NA 100.0 56.4 100.0 92.1 100.0 Unit Availability Factor (%) NA 100.0 56.4 100.0 92.1 100.0 Unit Capacity Factor (%,using MDC net) NA 95.2 50.4 90.4 80.5 96.1 Unit Capacity Factor (%,using DER net) NA 95.2 50.4 90.4 80.5 96.1 Unit Forced Outage Rate (%) NA 0.0 0.0 0.0 7.9 0.0 Hours in Month 744.0 744.0* 720.0 745.0 720.0 744.0 Net MDC (Mwe) Estimated 1150.0 1150.0 1150.0 1150.0 1150.0 1150.0
- Includes 57 hours6.597222e-4 days <br />0.0158 hours <br />9.424603e-5 weeks <br />2.16885e-5 months <br /> in August prior to commercial operation of the unit
l Attachment to TXX-94012 Page 14 of 23 TABLE 1.2-2 j COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 ANNUAL ELECTRIC POWER GENERATION DATA (1993) l i YEAR YEAR CUMULATIVE (Pre-Commercial) (Commercial)
Hours RX was Critical 1,519* 3,289 4,808 l l
RX Reserve Shutdown Hours 1,254* 327 1,581 )
Hours Generator On-Line 1,363 3,245 4,608 l
l Unit Reserve Shutdown Hours 0.0 0.0 0.0 l Gross Thermal Energy Generated (MWH) 2,742,190 10,617,958 13,364,756 i Gross Electric Energy Generated (MWH) 834,413 3,587,227 4,421,640 Net Electric Energy Generated (MWH) 746,930 3,431,806 4,178,736 !
t 1 i RX Service Factor (%) NA 91.0 91.0** I
( RX Availability Factor (%) NA 100.0 100.0**
Unit Service Factor (%) NA 89.8 89.8**
i Unit Availability Factor (%) NA 89.8 89.8** '
Unit Capacity Factor (%,using MDC net) NA 82.5 82.5**
Unit Capacity Factor (%,using DER net) NA 82.5 82.5**
Unit Forced Outage Rate (%) NA 1.7 1.7**
Hours in Reporting Period 2,773* 3,616 6,389 Hours reflect duration between the initial generator synchronization to the grid l on April 9, 1993, at 2003 and commercial operation on August 3, 1993 at 0905.
- Based on post commercial operation data of the unit l
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TABLE 2.1 (PAGE 1 0F 3)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 UNIT SHUTDOWNS AND POWER REDUCTIONS METHOL' 0F TYPE SHUTTING DOWN F: FORCED DURATION
- THE REACTOR OR EL DATE S: SCHEDULED (HOURS) REASON REDUCING POWER CORRECTIVE ACTIONS / COMMENTS 1 930118 F 25.6 G 3 At 100% RTP, Reactor tripped due to Intermediate Rangc (ID)
High Flux inadvertently unblocked while performing surveillance test. Unit entered MODE 3. ILER 93-001-00 was submitted.
2 930124 F 29.7 A 3 Reactor tripped due to pressurizer pressure transmitter spiked low causing one overtemperature N16 channel to trip while another channel was in trip for surveillance testing.
Unit entered MODE 3. ILER 93-002-00 was submitted.
3 930313 F 0.0 A 4 Experienced oscillations on MFP 1A. While at reduced power due to the MFP oscillations, Incore/Excore calibration of nuclear instruments were performed on March 17, 1993.
On March 18, 1993, secured MFP 1A for troubleshooting and repair. MFP 1A speed controller had intermittent failures causing speed oscillations. The problem was isolated to two components, an electronic controller card and an operation feed back transducer. On March 19, 1993, both were replaced and MFPT 1A was returned to service with the speed oscillation problem resolved.
4 930416 F 0.0 B 4 On April 1, 1993, the unit started in Mode 1 with turbine load reduced approximately 15 Megawatts due to a failure of MSR drain tank level control valve (1-LV-2704A). Trouble shooting showed that the problem was internal to the valve.
On April 16, 1993 the MSR was removed from service to perform maintenance on MSR drain tank normal level control valve. Failed valve internals were replaced.
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TABLE 2.1 (PAGE 2 0F 3)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 UNIT SHUTDOWNS AND POWER REDUCTIONS METHOD OF TYPE SHUTTING DOWN F: FORCED DURATION
- THE REACTOR OR NO. DATE S: SCHEDULED (HOURS) REASON REDUCING POWER CORRECTIVE ACTIONS / COMMENTS 5 930418 F 0.0 B 4 On April 17, 1993, Feedwater Pump (FWP) 1A lube oil pressure regulator failed to maintain the required pressure for turbine bearing lube oil. The following day, Unit load was reduced to 630 MWe to remove FWPT 1A from service to perform corrective maintenance.
The lube oil pressure regulator was repaired.
6 930418 F 0.0 A 4 Reduced power to 530 MWe to allow Axial Flux Difference penalty to clear as required by Unit Technical Specifications.
/ 930420 F 0.0 A 4 A failed weld in an extraction steam drip pot required both strings of high pressure heaters to be taken out of service and repaired, during power ascension.
8 930605 S 0.0 H 4 Reduced power to install modification to turbine valve indication and to perform turbine valve cycling.
9 930606 F 0.0 A 4 Circulating Pump 1-02 discharge expansion joint failed. Replaced with new expansion joint.
10 930626 F 33.8 A 1 High Stator Temperature indicated on RCP 1-04 and the reactor was manually tripped. The high temperature indication was due to failed RTD. 1LER 93-007-00 was submitted.
Attachment to TXX-94012 i Page 17 of 23 .
l l TABLE 2.1 (PAGE 3 0F 3)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 UNIT SHUTDOWNS AND POWER REDUCTIONS METHOD OF TYPE SHUTTING DOWN F: FORCED DURATION
- THE REACTOR OR NO. DATE S: SCHEDULED (HOURS) REASON REDUCING POWER CORRECTIVE ACTIONS / COMMENTS 11 930807 F 0.0 A 4 Valve 1-LV-2509, Extraction Steam Drip Pot Valve was not controlling properly. The valve was taken out of service, reworked and restored to service.
12 931006 S 605.6 C 1 Third Refueling Outage. Commenced power reduction on October 5, 1993, at 2330.
13 931101 S 720.0 C 1 Third Refueling Outage.
14 931201 S 365.0 C 1 Third Refueling Outage.
15 931224 F 46.3 G 3 Technician in the process of troubleshooting the turbine speed sensor, inadvertently grounded the functional sensor resulting in 0 speed indication.
The turning gear oil supply valve opened as designed causing drop in bearing oil pressure resulting in turbine trip and reactor trip. ILER 93-011-00 was submitted.
- Indicates shutdown hours.
- 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: OPERATION ERROR (EXPLAIN) 3: AUTOMATIC SCRAM D: REGULATORY RESTRICTION H: OTHER (EXPLAIN) 4: OTHER (EXPLAIN)
Attachment to TXX-94012 Page 18 of 23 ,
TABLE 2.2 (PAGE 1 0F 4)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 UNIT SHUTDOWNS AND POWER REDUCTIONS METHOD OF TYPE SHUTTING DOWN F: FORCED DURATION
- THE REACTOR OR
& DATE S: SCHEDULED (HOURS) REASON REDUCING POWER CORRECTIVE ACTIONS / COMMENTS A 930201 S 672.0 H 4 Unit in startup phase prior to initial criticality.
(Note that the unit received low power operating license on February 2,1993, began initial fuel load on February 4,1993 and completed the initial fuel load on February 11, 1993, at 0130).
B 930301 S 744.0 H 4 Unit in startup phase prior to initial electrical power generation (Note that the reactor achieved initial criticality on March 24,1993, at 2400 - unit entered MODE 2).
1 930418 F 0.0 B 4 Observed high temperature on condensate pump motor thrust bearing. Performed troubleshooting on the condensate pump motor (Note that unit was issued full power operating license on April 6, 1993; the unit achieved the initial entry to MODE 1 on April 6,1993, at 1934 and the initial generator synchronization to the grid on April 9, 1993, at 2003).
2 930426 S 0.0 8 4 Performed steam dump testing in accordance with the initial startup test sequence.
3 930430 S 0.0 8 4 Conducted additional steam dump testing.
4 930504 F 47.7 A 1 Manually tripped the reactor due to loss of feedwater flow to steam generator no. 1.
Attachment to TXX-94012 Page 19 of 23 . .
TABLE 2.2 (PAGE 2 0F 4)
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COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 UNIT SHUTDOWNS AND POWER REDUCTIONS METHOD OF TYPE SHUTTING DOWN F: FORCED DURATION
- THE REACTOR OR
& DATE S: SCHEDULED (HOURS) REASON REDUCING POWER CORRECTIVE ACTIONS / COMMENTS 5 930506 S 27.5 8 1 Manually tripped the reactor for remote shutdown test.
6 930508 S 109.1 B 1 Manually tripped the reactor for loss of offsite power test.
7 930520 F 97.9 A 3 Reactor automatically tripped due to loss of coolant flow to generator stator.
8 930524 S 183.0 A 4 Observed slow closure of feedwater isolation valve while the unit was already in MODE 5. Started post ISU.
9 930601 S 720.0 B 1 Entered outage to perform major surveillance testing.
10 930701 S 160.68 B 1 Upon return from outage, major surveillance testing was performed. On July 15, 1993, calorimetric and recommended Initial Startup Testing were performed.
11 930718 F 0.0 A 4 Excessive pressure drop occurred across heater drain pump suction strainer as a result of startup debris. Strainer was cleaned and heater drains were returned to service.
12 930726 S 0.0 B 4 Performed 50% load rejection test from 100% rated thermal power plateau. Restored to 100% power on July 27, 1993.
13 930727 5 64.8 B 1 Performed 100% load rejection test from 100% power plateau.
Unit entered MODE 3 following manual reactor trip.
14 930801 S 0.0 B 4 Month began with the unit in MODE 1 and ramping up for full power following load rejection test (Note that the unit was placed into commercial operation on August 3,1993, at 0905.)
Attachment to TXX-94012 Page 20 of 23 . .
TABLE 2.2 (PAGE 3 0F 4)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 UNIT SHUTDOWNS AND POWER REDUCTIONS .
METHOD OF TYPE SHUTTING DOWN F: FORCED DURATION
- THE REACTOR OR NO. DATE S: SCHEDULED (HOURS) REASON REDUCING POWER CORRECTIVE ACTIONS / COMMENTS 15 930917 5 313.68 B 1 Commenced power reduction for maintenance outage to repair valve leaks at Steam Generator 2-03 feedwater split flow bypass valve in containment and feedwater full flow recirculation valve in the turbine building on September 16, 1993. The valve leaks were repaired on September 17, 1993.
On September 29, 1993, the reactor entered criticality and Main Feedwater Pump 2B discharge check valve stuck open following resetting of the pump, allowing backflow into the pump and causing reverse rotation of the turbine which damaged the turning gear. Main Feedwater Pump 2B was placed out of service.
16 931001 F 0.0 A 4 Following completion of the maintenance outage power was held at 50 percent to perform repair and inspections on Main Feedwater Pump (MFP) 2B turbine. Damage to the turning gear occurred when discharge check valve of opposite MFP failed open and caused reverse rotation (occurred during startup on September 28,1993). MFP 2B was repaired on October 3, 1993. 2LER 93-008-00 was submitted.
17 931113 S 0.0 B 4 Feedwater Heater 2-5B Water Box Relief Valve 2C0-0109 leaked by seat. The valve was replaced with new model during regularly scheduled down power for turbine valve cycling surveillance.
18 931117 F 57.0 A 3 MSR Separator Drain Tank 2A Normal Level Control Valve 2-LV-2708 failed open due to feedback linkage arm problem.
The resulting heating drain flow transient caused the Main Feed Pump to trip which resulted in turbine runback and subsequent plant trip. 2LER 93-011-00 was submitted.
Attachment to TXX-94012 Page 21 of 23 ,
TABLE 2.2 (PAGE 4 0F 4) .
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 UNIT SHUTDOWNS AND POWER REDUCTIONS METHOD OF TYPE SHUTTING DOWN F: FORCED DURATION
- THE REACTOR OR
_N O DATE S: SCHEDULED (HOURS) REASON REDUCING POWER CORRECTIVE ACTIONS / COMMENTS 19 931121 S 0.0 B 4 Power held at 57% to troubleshoot and repair Main Feed Pump 2B vibration. Repaired the main feed pump vibration.
20 931214 F 0.0 A 4 Condensate Cooling Supply valve to blowdown heat exchanger (2-PV-5223) failed open causing secondary transient resulting in loss of Main Feed Pump 2B which caused an automatic runback. 2-PV-5223 ( part of Steam Generator Blowdown System) failed open due to failure of the valve pneumatic controller (2-PC-5223) as a result of wear of controller internal components caused by high frequency vibration. The unit was maintained below 80% of the design power level for approximately 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> when the applicable equipment were repaired / replaced. Corrective actions to prevent recurrence include (1) moving 2-PC-5223 to a proper location to minimize the vibration and (2) inspecting controller internals for wear while performing controller calibration.
OIndicates shutdown hours.
- 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: OPERATION ERROR (EXPLAIN) 3: AUTOMATIC SCRAM D: REGULATORY RESTRICTION H: OTHER (EXPLAIN) 4: OTHER (EXPLAIN)
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Attachment to T,XX-94012 Page 22 of 23 ,
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l TABLE 3.0 L
COMANCHE PEAK STEAM ELECTRIC STATION - UNITS 1 AND 2 PERSONNEL EXPOSURE AND MONITORING REPORT
- Personnel (> 100 mRom) Tceal Person-Rom
! Work & Job Function Sier.aon Utibry Com: rect Stadon UtiDry Contract Reactor Operations & Surveillance l Mamtmance & Construction 0 0 32 0.238 0 000 9 347 operanons 2 0 2 4 71) 0.037 1.420 Hea th Physics & Lab 7 0 24 1.578 0.033 6.811 Supemsory & Office Staff 0 0 0 0.154 0.033 0.028 Engmeermg Staff 0 0 1 0.303 0.000 0.537 Reutine Plant Maintenance Maintenance & Constructic.n 17 0 74 5.745 0.000 16.757 Operauons 0 0 1 0.129 0.000 0.515 !
Health Physics & Lab 0 0 2 0.088 0 000 1.808 l Supervisory & Office Staff 0 0 0 0.028 0.061 0.013 Engmeermg Staff 0 0 0 0 000 0.000 0.101 Innervice Inspection l Mamtenance & Construcuon 1 0 24 0.329 0.000 7.532 Operations 0 0 2 0.190 0.000 0.896 Health Physics & Lab 0 0 2 0.106 0.000 1.780 Supervisory & Office Staff 0 0 0 0.000 0.000 0 021 Engineerms Staff 0 0 0 0.000 0 000 0.453 l Special Plant Maintenance Mamtenance & Construction 0 0 39 0.480 0.000 11.719 I Operations 0 0 1 0.032 0.000 0.823 Health Physics & Lao 0 0 3 0.051 0 000 1.766 f Supervisory & Office Staff 0 0 0 0.000 0 000 0 011 Enginecrmg Staff 0 0 0 0.000 0 000 0.478 l
Waste Processmg Mamtenance & Construction 0 0 48 0.G45 0.000 14.719 Operations 0 0 3 0.265 0.000 0.823 Health Physics & Lab 1 0 2 0.552 0.000 1.766 Supemsory & Office Staff 0 0 0 0.000 0.000 0.011 Engmeerms Staff 0 0 0 0.017 0 000 0 478 Refuelmg l Maintenance & Construction 2 0 21 0.602 0 000 8 582 Operatwns 1 0 1 0 467 0.000 0 851 Health Physics & Lab 0 0 6 0 001 0.000 2.054 Supemsory & Office Staff 1 0 0 0.220 0.000 0.029 Engmeermg Staff I O O 0.233 0.000 0.519 Totals Maintenance & Consruction 21 0 210 7.007 0 000 67.971 Operations 5 0 17 5.795 0.037 5.999 Health Physics & Lab 14 0 49 2 375 0.033 16.035 Supemsory & Office Staff 1 0 0 0 402 0.094 0.113 Engmeerms Staff 1 0 7 0553 0.000 2.617 Grand Totals 42 0 283 16.132 0.164 92.7M mm'
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, Attachment to TXX-94012 i Page 23 of 23 TABLE 6.0 COMANCHE PEAK STEAM ELECIRIC STATION - UNITS 1 AND 2 l l
I OUTAGE RELATED RADIATION EXPOSURE TO AN INDIVIDUAL THAT ACCOUNTS FOR MORE THAN 10 PERCENT OF ALLOWABLE ANNUAL VALUES Individual's Repartment_ p_qse (mreml l
RP 563 W 1320 ,
l W 515 W 522 W 565 i l
W 831 W 501 W 1140 l W 693 '
W 735 W 873 1 W 583 W 1006 I W 707 l W 720 ,
W 702 l W 534 )
W 504 i W 1081 l
l RP - Radiation Protection W - Westinghouse l
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