CPSES-200300346, Annual Operating Report for 2002
| ML030650975 | |
| Person / Time | |
|---|---|
| Site: | Comanche Peak  |
| Issue date: | 02/28/2003 |
| From: | Madden F TXU Energy |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| 10250 (RP-85), CPSES-200300346, RG-1.016, TXX-03042 | |
| Download: ML030650975 (22) | |
Text
TXU TXU Energy C. Lance Terry Comanche Peak Steam Senior Vice President &
Electric Station Principal Nuclear Officer PO Box 1002 (EO1)
Glen Rose, TX 76043 Tel. 254 897 8920 Fax 254 897 6652 lance terry@txu corn CPSES-200300346 Log # TXX-03042 File # 10250 (RP-85)
Ref. # 10CFR50.36 February 28, 2003 U. S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555
SUBJECT:
COMANCHE PEAK STEAM ELECTRIC STATION (CPSES)
DOCKET NOS. 50-445 AND 50-446 ANNUAL OPERATING REPORT FOR 2002 Gentlemen:
Attached is the CPSES Annual Operating Report for 2002 prepared and submitted pursuant to guidance provided in C..b of U.S. NRC Regulatory Guide 1.16, Revision
- 4. The attachment also submits the annual Occupational Radiation Exposure Report as required by Technical Specification 5.6.1 contained in Appendix A to the Comanche Peak Steam Electric Station Unit 1 Operating License NPF-87 and Unit 2 Operating License NPF-89.
If you have any questions, please contact Mr. Douglas W. Snow at (254) 897-8448.
gv0 QTXU TXX-03042 PAGE 2 OF 2 This communication contains no new licensing basis commitments regarding CPSES Units 1 and 2.
Sincerely, TXU Generation Company LP By:
TXU Generation Management Company LLC Its General Partner C. L. Terry Senior Vice President and Principal Nuclear Officer By:
.///
P,I ?Y/-M "'/'./
Fred W. Madden Nuclear Licensing Manager DWS/dws Attachment c -
E. W. Merschoff, Region IV W. D. Johnson, Region IV D. H. Jaffe, NRR Resident Inspectors, CPSES Mail Original copy of Personnel Exposure & Monitoring Report to:
Ms. Sheryl Burrows, REIRS Project Manager Office of Nuclear Regulatory Research U.S. Nuclear Regulatory Commission Washington, DC 20555
CPSES-200300346 Attachment to TXX-03042 COMANCHE PEAK STEAM ELECTRIC STATION ANNUAL OPERATING REPORT 2002 TXU Generation Company LP I
CPSES-200300346 Attachment to TXX-03042 TABLE OF CONTENTS 1.0 Summary of Operating Experience 2.0 Outages and Reductions in Power 3.0 Personnel Exposure and Monitoring Report 4.0 Irradiated Fuel Inspection Results 5.0 Outage Related Single Radioactivity Release or Radiation Exposure to an Individual that Accounts for More than 10 Percent of Allowable Annual Values 2
CPSES-200300346 Attachment to TXX-03042 1.0
SUMMARY
OF OPERATING EXPERIENCE The Comanche Peak Steam Electric Station (CPSES) is a dual unit pressurized water reactor power plant, supplied by Westinghouse Electric Corporation. It is located in Somervell County in North Central Texas approximately 65 miles southwest of the Dallas-Fort Worth Metropolitan area. Each generating unit core was originally designed for a warranted power output of 3411 Megawatt thermal (MWt). This output, combined with the reactor coolant pump heat output of 14 MWt, gives a warranted NSSS output of 3425 MWt, which is the license application rating. A 4.5 percent increase in steam flow results in the maximum calculated NSSS output of 3579 MWt, and thus a maximum calculated core output of 3565 MWt. All safety systems, including the containment and engineered safety features, are designed for operation at the maximum calculated power output. Both units rated thermal power was subsequently increased to 3458 MWt, which represents a 1.4 percent increase in core output (from 3411 to 3458 MWt). The reactor coolant pump heat output considered in the safety analysis was increased to approximately 16 MWt for both units.
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 commercial on August 13, 1990. Since being declared commercial, CPSES Unit 1 has generated 99,359,170 net Megawatt-hours (MWH) of electricity as of December 31, 2002, with a net unit capacity factor of 79.6% (using MDC). The unit and reactor availability factors were 86.3% and 89.7%, respectively, for the year 2002.
On September 28, 2002, the unit entered a forced outage due to a steam generator tube leak and began the ninth refueling outage. The unit was scheduled to begin the refueling outage on October 5, 2002.
On November 18, 2002, Unit I implemented Technical Specification Amendment 89, increasing the rating of Unit 1 from 3445 MWt to 3458 MWt output.
During the refueling outage, 88 fresh fuel assemblies were loaded for Cycle 10. The forced outage and the refueling outage lasted 51 days and ended on November 18, 2002. Unit 1 reached 100% power on November 29, 2002.
During the refueling outage, the major work scope completed included:
Identification and disposition of indicated fuel failure during Cycle 9.
High Pressure Turbine Upgrade and Replacement.
Eddy current inspection of Last Stage Blades for both LP Turbines Emergency Diesel Generators 18 month Inspection 100% Eddy Current Testing on all four Steam Generators Sleeving of Steam Generator Tubes.
Figure 1.1-1 provides the generation profile of the average daily net electrical output of Unit 1 for 2002. 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.
3
CPSES-200300346 Attachment to TXX-03042 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 78,931,912 net Megawatt-hours (MWH) of electricity as of December 31, 2002, with a net unit capacity factor of 83.2% (using MDC). The unit and reactor availability factors were 88.5% and 91.9.0%, respectively, for the year 2002.
On March 30, 2002, the unit began the power ramp down for its sixth refueling outage. The unit entered the refueling outage on March 30.
During the refueling outage, 92 fresh fuel assemblies were loaded for Cycle 7. The refueling outage lasted 35 days and ended on May 4, 2002. Unit 2 reached 100% power on May 10, 2002.
During the refueling outage, the major work scope completed included:
Reactor Vessel 10 Year ISI Smart Motor Modification on RCP 2-04 Major Inspection of Main Generator.
Eddy current inspection of Last Stage Blades for both LP Turbines Emergency Diesel Generator replacement of four cylinder liners.
Emergency Diesel Generators 10 Year Inspection 40% Eddy Current Testing on two Steam Generators Refueling machine Modifications for increased reliability Figure 1.2-1 provides the generation profile of the average daily net electrical output of Unit 2 for 2002. 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.
During this reporting period there were no failures or challenges to the Safety Valves.
2.0 OUTAGES AND REDUCTIONS IN POWER 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 Unit 1.
2.2 CPSES UNIT 2 Table 2.2 describes unit-operating experience including unit shutdowns and provides explanations of 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
CPSES-200300346 Attachment to TXX-03042 4.0 IRRADIATED FUEL INSPECTION RESULTS 4.1 CPSES UNIT 1 The reactor coolant fission product activity levels were carefully monitored throughout Unit 1, Cycle 9. Analysis of the activity levels indicated no leaking fuel throughout most of the cycle.
However, in early August 2002, analyses of RCS fission product activity levels indicted the development of a fuel failure. In order to identify the failed assembly, in-mast sipping of Unit 1, Cycle 9 fuel assemblies was conducted during IRFO9 core off-load. To specifically locate the leaking fuel rod within the failed assembly, ultrasonic testing (UT) of the assemblies identified as suspect during in-mast sipping was performed following core off-load. Visual examinations of UIC9 fuel assemblies were also performed by inspection personnel by viewing the assemblies from the edge of Spent Fuel Pool #1 as assemblies were off-loaded from the core.
Randomly selected fuel assemblies were also examined using underwater camera equipment.
All fuel assemblies identified as suspect by in-mast sipping were further visually inspected using the high magnification underwater camera located on the UT inspection rig.
During core off-load, in-mast sipping detected a strong indication of leaking fuel in fuel assembly K-53. The results of the UT inspection of K-53 confirmed a leaking fuel rod near the center of the fuel assembly. Assembly K-53 is a twice-burned Framatome ANP supplied fuel assembly, which was originally scheduled for discharge following U1C9. No U1C1O core design changes were therefore required. There were no indications of leaking fuel in Unit 1 Cycle 10 during 2002.
From the visual inspections discussed in the previous paragraph, all fuel assemblies appeared to be in good condition with no anomalies observed. In general, only light residual crud levels on the assemblies were observed and were consistent with crud patterns observed during previous refueling outage inspection campaigns. Underwater camera inspection of assembly K-53 was not successful in visually identifying the defect because the leaking rod was located near the center of the assembly.
4.2 CPSES UNIT 2 Visual examinations of Unit 2, Cycle 6 fuel assemblies were performed by inspection personnel by viewing the assemblies from the edge of Spent Fuel Pool #2 as assemblies were off-loaded from the core. Randomly selected fuel assemblies were examined using underwater camera equipment, which were performed concurrently with the poolside visual examinations.
From the inspections discussed above, all fuel assemblies appeared to be in good condition with no anomalies observed. In general, only light residual crud levels on the assemblies were observed and were consistent with crud patterns observed during previous refueling outage inspection campaigns.
During refueling outage 2RF06, Westinghouse personnel performed control rod wear measurements through eddy current examination of all 53 Unit 2 control rod clusters. In summary, the results of the exams showed minimum wear (<5% clad volume reduction) on all control rodlets.
5
CPSES-200300346 Attachment to TXX-03042 During 2RF06, eight fuel assemblies were inspected for crud deposition and cladding corrosion. The purpose of this exam was to benchmark crud and corrosion (oxide thickness) performance before implementation of an elevated RCS pH program in Unit 2 beginning in Cycle 7. All assemblies measured were Framatome ANP design. The measured oxide thicknesses were generally as expected with some minor crud deposition observed on most fuel assemblies.
5.0 OUTAGE RELATED SINGLE RADIOACTIVITY 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 reduction in power of over 20% of designed power level during 2002.
During 2002 CPSES I and Unit 2 conducted a refueling outage (see sections 1.1 and 1.2).
During the outage activities, six individuals received radiation exposure exceeding 10% of an allowable dose limit in a single exposure event. Exposure is tabulated in Table 6.0.
6
CPSES-200300346 Attachment to TXX-03042 FIGURE 1.1-1 COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 GENERATION PROFILE AVERAGE DAILY UNIT POWER LEVEL for 2002 1,400 1,200 1,000 800 600 400 200 0
JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC 7
CPSES-200300346 Attachment to TXX-03042 TABLE 1.1-1 (PAGE 1 OF 2)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 MONTHLY ELECTRIC POWER GENERATION DATA (2002)
January February March April May June Hours RX was Critical 744 672 744.0 719.0 744.0 720 RX Reserve Shutdown Hours 0
0 0
0 0
0 Hours Generator On-line 744 672 744.0 719.0 744.0 720 Unit Reserve Shutdown Hours 0
0 0
0 0
0 Gross Thermal Energy Generated (MWH) 2,536,265 2,286,146 2,535,146 2,449,925 2,531,606 2,452,826 Gross Electric Energy Generated (MWH) 861,651 776,600 861,649 831,759 857,423 824,385 Net Electric Energy Generated (MWH) 828,152 747,614 828,429 799,174 823,316 790,891 RX Service Factor (%)
100.0 100.0 100.0 100.0 100.0 100.0 RX Availability Factor (%)
100.0 100.0 100.0 100.0 100.0 100.0 Unit Service Factor (%)
100.0 100.0 100.0 100.0 100.0 100.0 Unit Availability Factor (%)
100.0 100.0 100.0 100.0 100.0 100.0 Unit Capacity Factor(%, using MDC net) 96.8 96.7 96.8 96.7 96.2 95.5 Unit Capacity Factor(%, using DER net) 96.8 96.7 96.8 96.7 96.2 95.5 Unit Forced Outage Rate (%)
0.0 0.0 0.0 0.0 0.0 0.0 Hours in Month 744 672 744 719 744 720 8
CPSES-200300346 Attachment to TXX-03042 TABLE 1.1-1 (PAGE 2 OF 2)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 MONTHLY ELECTRIC POWER GENERATION DATA (2002) uly August September October November December Hours RX was Critical 744 744.0 651.2 0.0 280.3 516.9 RX Reserve Shutdown Hours 0
0.0 0
0.0 0
0 Hours Generator On-line 744 744.0 651.2 0.0 221.8 510.6 Unit Reserve Shutdown Hours 0
0 0
0 0
0 Gross Thermal Energy Generated (MWH) 2,535,590 2,531,416 2,204,280 0
491,755 1,569,091 Gross Electric Energy Generated (MWH) 846,733 844,024 739,521 0
160,058 535,169 Net Electric Energy Generated (MWH) 811,822 808,994 706,331 0
133,829 506,713 RX Service Factor (%)
100.0 100.0 90.4 0
38.9 69.5 RX Availability Factor (%)
100.0 100.0 90.4 0
38.9 69.5 Unit Service Factor (%)
100.0 100.0 90.4 0
30.8 68.6 Unit Availability Factor (%)
100.0 100.0 90.4 0
30.8 68.6 Unit Capacity Factor(%, using MDC net) 94.9 94.6 85.3 0
16.2 59.2 Unit Capacity Factor(%, using DER net) 94.9 94.6 85.3 0
16.2 59.2 Unit Forced Outage Rate (%)
0.0 0.0 9.6 100.0 27.0 31.4 Hours in Month 744 744 720 745 720 744 9
CPSES-200300346 Attachment to TXX-03042 TABLE 1.1-2 COMANCHE PEAK STEAM ELECTRIC STATION - UNIT I ANNUAL ELECTRIC POWER GENERATION DATA (2002)
YEAR CUMULATIVE Hours RX was Critical 7,279.4 94,513 RX Reserve Shutdown Hours 0.0 2,871 Hours Generator On-line 7,214.6 93,663 Unit Reserve Shutdown Hours 0
0 Gross Thermal Energy Generated (MWH) 24,124,048 310,106,179 Gross Electric Energy Generated (MWH) 8,138,972 103,905,593 Net Electric Energy Generated (MWH) 7,785,265 99,359,170 RX Service Factor (%)
83.1 87.1 RX Availability Factor (%)
83.1 89.7 Unit Service Factor (%)
82.4 86.3 Unit Availability Factor (%)
82.4 86.3 Unit Capacity Factor(%, using MDC net) 77.3 79.6 Unit Capacity Factor(%, using DER net) 77.3 79.6 Unit Forced Outage Rate (%)
6.4 3.3 10
CPSES-200300346 Attachment to TXX-03042 FIGURE 1.2-1 COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 GENERATION PROFILE AVERAGE DAILY UNIT POWER LEVEL for 2002 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC 11 M
We 1,400 1,200 1,000 800 600 400 200 0
Main Feedwater Pump Condenser tube leak.
Turbine trip and automatic reactor trip due to generator primary water pump vibration alarm.
2RF06 M
In edae
CPSES-200300346 Attachment to TXX-03042 TABLE 1.2-1 (PAGE 1 OF 2)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 MONTHLY ELECTRIC POWER GENERATION DATA (2002)
January February March Apr__
M June Hours RX was Critical 744 672 707.8 0.0 714.5 694.5 RX Reserve Shutdown Hours 0
0 0
0 0
0 Hours Generator On-line 744 672 707.8 0.0 658.0 690.6 Unit Reserve Shutdown Hours 0
0 0
0 0
0 Gross Thermal Energy Generated (MWH) 2,563,716 2,320,836 2,419,438 0
1,996,301 2,333,719 Gross Electric Energy Generated (MWH) 881,639 797,957 827,902 0
677,213 795,808 Net Electric Energy Generated (MWH) 849,107 768,653 797,643 0
644,577 763,873 RX Service Factor (%)
100.0 100.0 95.1 0.0 88.4 96.5 RX Availability Factor (%)
100.0 100.0 95.1 0.0 88.4 96.5 Unit Service Factor (%)
100.0 100.0 95.1 0.0 96.0 95.9 Unit Availability Factor (%)
100.0 100.0 95.1 0.0 96.0 95.9 Unit Capacity Factor(%, using MDC net) 99.2 99.5 93.2 0.0 75.3 92.3 Unit Capacity Factor(%, using DER net) 99.2 99.5 93.2 0.0 75.3 92.3 Unit Forced Outage Rate (%)
0.0 0.0 0.0 0.0 0.0 4.1 Hours in Month 744 672 744 719 744 720 12
CPSES-200300346 Attachment to TXX-03042 TABLE 1.2-1 (PAGE 2 OF 2)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 MONTHLY ELECTRIC POWER GENERATION DATA (2002)
July Augus September October November December Hours RX was Critical 744.0 744.0 720.0 745 720 744 RX Reserve Shutdown Hours 0
0 0
0 0
0 Hours Generator On-line 744.0 744.0 720.0 745 720 744 Unit Reserve Shutdown Hours 0
0 0
0 0
0 Gross Thermal Energy Generated (MWH) 2,509,555 2,542,003 2,468,448 2,553,420 2,473,948 2,563,145 Gross Electric Energy Generated (MWH) 848,523 861,089 840,784 878,826 853,967 885,175 Net Electric Energy Generated (MWH) 815,409 828,063 808,586 843,342 821,637 852,929 RX Service Factor (%)
100.0 100.0 100.0 100.0 99.9 100.0 RX Availability Factor (%)
100.0 100.0 100.0 100.0 99.9 100.0 Unit Service Factor (%)
100.0 100.0 100.0 100.0 100.0 100.0 Unit Availability Factor (%)
100.0 100.0 100.0 100.0 100.0 100.0 Unit Capacity Factor(%, using MDC net) 95.3 96.8 97.7 98.4 99.2 99.7 Unit Capacity Factor(%, using DER net) 95.3 96.8 97.7 98.4 99.2 99.7 Unit Forced Outage Rate (%)
0.0 0.0 0.0 0.0 0.0 0.0 Hours in Month 744 744 720 745 720 744 13
CPSES-200300346 Attachment to TXX-03042 TABLE 1.2-2 COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 ANNUAL ELECTRIC POWER GENERATION DATA (2001)
YEAR CUMULATIVE Hours RX was Critical RX Reserve Shutdown Hours Hours Generator On-line Unit Reserve Shutdown Hours Gross Thermal Energy Generated (MWH)
Gross Electric Energy Generated (MWH)
Net Electric Energy Generated (MWH)
RX Service Factor (%)
RX Availability Factor (%)
Unit Service Factor (%)
Unit Availability Factor (%)
Unit Capacity Factor(%, using MDC net)
Unit Capacity Factor(%, using DER net)
Unit Forced Outage Rate (%)
7,949.8 0
7,889.4 0
26,744,529 9,148,883 8,793,819 90.8 90.8 90.1 90.1 87.3 87.3 0.4 73,453 2,366 72,978 0
242,335,294 82,297,742 78,931,912 89.0 91.9 88.5 88.5 83.2 83.2 2.8 14
CPSES-200300346 Attachment to TXX-03042 TABLE 2.1 (PAGE 1 OF 2)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT I UNIT OPERATING EXPERIENCE INCLUDING SHUTDOWNS AND POWER REDUCTIONS DURING 2002 TYPE F: FORCED NO DATE S: SCHEDULED DURATION*
(HOURS)
METHOD OF SHUTTING DOWN THE REACTOR OR REASON REDUCING POWER CORRECTIVE ACTION/COMMENTS la 020928 lb 021001 2a 021005 2b 021101 3
021123 4a 021130 I) REASON F
F S
S S
68.80 108.00 637.00 416.27 81.92 F
A 1
A C
C A
4 4
I A
4 On September 28, at 0140 the unit commenced a downpower due to a steam generator tube leak and was taken offline at 0312 and entered Mode 3. The unit was in the end of cycle coastdown prior to the start of IRF09 refueling outage. The SG tube leak exceeded station administrative limits of 40 gpd (Tech Specs limit 150 gpd). The unit ended the month in Mode 5 in a forced outage and mobilizing for entering I RF09 early.
On September 28, at 0140 the unit commenced a downpower due to a steam generator tube leak and was taken offline at 0312 and entered Mode 3. The unit was in a forced outage prior to the start of 1 RF09 refueling outage Officially started IRF09 planned refueling outage on 10/05/02 at 1200 per the original outage schedule.
Started month in Mode 5 lRF09. 1RF09 concluded with synchronization to the grid on November 18, 2002, at 0816 hours0.00944 days <br />0.227 hours <br />0.00135 weeks <br />3.10488e-4 months <br />.
On November 20, 2002, the pressure seal was damaged for I MS-0063, while performing a hot torque on the valve. A decision was made to take the unit off line and down to Mode 5 to perform repairs on the valve. On November 23, 2002, at 1940 hours0.0225 days <br />0.539 hours <br />0.00321 weeks <br />7.3817e-4 months <br />, unit commenced shut down from 80% power and was taken off line at 2127 hours0.0246 days <br />0.591 hours <br />0.00352 weeks <br />8.093235e-4 months <br />. Valve repairs were successful and on November 27, 2002, at 0722 hours0.00836 days <br />0.201 hours <br />0.00119 weeks <br />2.74721e-4 months <br />, unit was synchronized back to the grid. The unit reached full power on November 29, 2002, at 1112 hours0.0129 days <br />0.309 hours <br />0.00184 weeks <br />4.23116e-4 months <br />.
On November 30, at 1412 hours0.0163 days <br />0.392 hours <br />0.00233 weeks <br />5.37266e-4 months <br />, reactor control rod G13 in shutdown bank B, unexpectedly dropped into the core. Unit ended the month investigating cause of failure.
- 2) METHOD A: EQUIPMENT FAILURE (EXPLAIN)
B: MAINT OR TEST C: REFUELING D: REGULATORY RESTRICTION E: OPERATOR TRAINING AND LICENSE EXAMINATION F: ADMINISTRATIVE G-OPERATIONAL ERROR (EXPLAIN)
H" OTHER (EXPLAIN)
I: MANUAL 2: MANUAL SCRAM 3: AUTOMATIC SCRAM 4: OTHER (EXPLAIN)
- INDICATES SHUTDOWN HOURS/OTHERWISE "NA" FOR NOT APPLICABLE 15 I
CPSES-200300346 Attachment to TXX-03042 TABLE 2.1 (PAGE 2 OF 2)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 1 UNIT OPERATING EXPERIENCE INCLUDING SHUTDOWNS AND POWER REDUCTIONS DURING 2002 TYPE F: FORCED NO DATE S: SCHEDULED DURATION*
(HOURS)
METHOD OF SHUTTING DOWN THE REACTOR OR REASON REDUCING POWER CORRECTIVE ACTION/COMMENTS 4b 021204 F
233.40 A
4 On November 30, at 1412 hours0.0163 days <br />0.392 hours <br />0.00233 weeks <br />5.37266e-4 months <br />, reactor control rod G13 in shutdown bank B, unexpectedly dropped into the core. Unit began the month troubleshooting in progress to determine the cause for the dropped control rod. Troubleshooting revealed a CRDM canopy weld leak to be the root cause of the dropped control rod.
The unit entered Mode 5, after a normal shutdown, for repairs on December 04, 2002 at 0021. Repairs were completed and the unit was returned to power on December 13, 2002 at 1745. The unit returned to full power on December 15, 2002 at 1643.
16
Attachment to TXX-03042 TABLE 2.2 (PAGE 1 OF 1)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 UNIT OPERATING EXPERIENCE INCLUDING SHUTDOWNS AND POWER REDUCTIONS DURING 2002 TYPE F: FORCED S: SCHEDULED DURATION*
(HOURS)
REASON METHOD OF SHUTrlNG DOWN THE REACTOR OR REDUCING POWER CORRECTIVE ACTION/COMMENTS Ia 020330 lb 020501 2
020511 3
020606 4a 020729 S
S F
F S
36.20 85.98 29.50 C
C A
A 2
2 4
3 B
Unit began ramp down to begin 2RF06 refueling outage from end of cycle coastdown with power at 95% at 0859 on 03/30/2002. The reactor was tripped at 30% power per procedure and began normal refueling outage, 2RF06, at 1147 on 03/30/2002 and entered Mode
- 3. The unit ended this month in Mode 4 in 2RF06 refueling.
Outage.
Unit began 2RF06 refueling outage on 03/30/2002. 2RF06 refueling outage was sync to the grid on May 4th at 1359 and returned to 100% power on May 9th at 1817.
Smoke was observed coming from Main Feedwater Pump 2-01 insulation. Plant power was reduced to 50% to investigate. The smoke was determined to be residual oil, which was cleaned up and the Unit returned to 100% power on 05/14/2002.
On 06/06/2002 at 1924, Unit turbine trip and reactor trip due to a high vibration alarm on the turbine primary water pump. The alarm was identified as faulty and replaced. The unit returned to power on 06/08/2002 at 2116. (See LER-446 2-001-00)
On July 29, 2002 at 2200 hours0.0255 days <br />0.611 hours <br />0.00364 weeks <br />8.371e-4 months <br />, unit began reducing power due to sodium levels in steam generators, as a result of a leak from a tube in the condenser 2A. On July 30, at 0023 hours2.662037e-4 days <br />0.00639 hours <br />3.80291e-5 weeks <br />8.7515e-6 months <br />, unit at 80% power for condenser repairs. Unit ended the month at 74% power (771 MWe Gross), condenser repairs in progress.
- 2) METHOD A-EQUIPMENT FAILURE (EXPLAIN)
B: MAINT OR TEST C: REFUELING D" REGULATORY RESTRICTION E. OPERATOR TRAINING AND LICENSE EXAMINATION F: ADMINISTRATIVE G: OPERATIONAL ERROR (EXPLAIN)
H: OTHER (EXPLAIN)
I: MANUAL 2: MANUAL SCRAM 3: AUTOMATIC SCRAM 4: OTHER (EXPLAIN)
- INDICATES SHUTDOWN HOURS/OTHERWISE 'NA" FOR NOT APPLICABLE 17 NO DATE I) REASON I
Attachment to TXX-03042 TABLE 2.2 (PAGE 2 OF 2)
COMANCHE PEAK STEAM ELECTRIC STATION - UNIT 2 UNIT OPERATING EXPERIENCE INCLUDING SHUTDOWNS AND POWER REDUCTIONS DURING 2002 NO DATE 4b 020801 5
021106 TYPE F: FORCED S: SCHEDULED F
F DURATION*
(HOURS)
REASON METHOD OF SHUTTING DOWN THE REACTOR OR REDUCING POWER B
A 4
CORRECTIVE ACTION/COMMENTS On July 29, 2002 at 2200 hours0.0255 days <br />0.611 hours <br />0.00364 weeks <br />8.371e-4 months <br />, unit began reducing power due to sodium levels in steam generators, resulting from leaking tubes in the condenser. On July 30, at 0023 hours2.662037e-4 days <br />0.00639 hours <br />3.80291e-5 weeks <br />8.7515e-6 months <br />, unit at 80% power for condenser repairs. Unit ended the month at 74% power, condenser repairs in progress. Condenser repairs were completed and the unit ramped to full power on 08/01/2002.
On November 6, 2002, at 2003 hours0.0232 days <br />0.556 hours <br />0.00331 weeks <br />7.621415e-4 months <br />, the control system for the Turbine Generator malfunctioned resulting in a load rejection.
Operator action stabilized the unit, lowering power to 78% and ultimately to 65% to effect repairs. Repairs were completed and the unit returned to full power on November 7, 2002, at 0930 hours0.0108 days <br />0.258 hours <br />0.00154 weeks <br />3.53865e-4 months <br />.
18 I
Attachment to TXX-03042 TABLE 3.0 COMANCHE PEAK STEAM ELECTRIC STATION - UNITS I AND 2 2002 PERSONNEL EXPOSURE AND MONITORING REPORT
- Personne Total Person -
re Work & Job Function Station UtIEU Contrac Station UtiLItI Contract Reactor Operations & Surveillance Maintenance & Construction 138 0
151 0483
.000 0.525 Operations 327 0
220 2 700
.000 0.349 Health Physics & Lab 50 0
97 1.975
.000 0.636 Supervisory & Office Staff 34 0
7 0 101
.000 0.023 Engineering Staff 173 0
82 0273
.000 0.069 Routine Plant Maintenance Maintenance & Construction 219 0
626 11.042
.000 49.546 Operations 203 0
38 8840
.000 1.178 Health Physics & Lab 46 0
139 3 649
.000 12.784 Supervisory & Office Staff 19 0
3 0275
.000 0 064 Engineering Staff 103 0
210 2.248
.000 53.126 In-service Inspection Maintenance & Construction 34 0
109 0 402
.000 4346 Operations 22 0
6 0.479
.000 0075 Health Ph*'sics & Lab 6
0 19 0.024
.000 0.097 Supervisory & Office Staff 3
0 0
0013
.000 0000 Engineering Staff 24 0
125 0632
.000 20.391
- Special Plant Maintenance Maintenance & Construction 52 0
228 0.738
.000 13.439 Operations 32 0
6 0490
.000 0.079 Health Physics & Lab 15 0
26 0092
.000 0.321 Supervisory & Office Staff 3
0 0
0.025
.000 0.000 Engineering Staff 18 1
43 0.241
.000 5.039 Waste Processing Maintenance & Construction 2
0 2
0.005
.000 0.000 Operations 15 0
5 0.221
.000 0507 Health Physics & Lab 15 0
13 0.069
.000 0.031 Supervisory & Office Staff 0
0 0
0.000
.000 0000 Engineering Staff 3
0 2
0.050
.000 0008 Refueling Maintenance & Construction 89 0
159 0.840 000 4722 Operations 59 0
13 1.635
.000 0202 Health Physics & Lab 41 0
88 2.259
.000 5 833 Supervisory & Office Staff 7
0 0
0078
.000 0000 Engineering Staff 31 1
111 0.751
.000 28 168 Totals Maintenance & Construction 534 0
1275 13.510
.000 72.577 Operations 658 0
288 14365
.000 2391 Health Physics & Lab 173 0
382 8 068
.000 19.702 Supervisory & Office Staff 66 0
10 0493 000 0087 Engineenng Staff 352 2
573 4 195
.000 106800 Grand Totals 1783 2
2528 40631 0000 201.557
- Transfer canal modifications, Installation of permanent lead shielding and Installation of LHRA Barriers.
19
CPSES-200300346 Attachment to TXX-03042 TABLE 6.0 2002 COMANCHE PEAK STEAM ELECTRIC STATION - UNITS 1 AND 2 OUTAGE RELATED RADIATION EXPOSURE TO AN INDIVIDUAL FOR A SINGLE MAINTENANCE ACTIVITY WHICH EXCEEDS 10 PERCENT OF AN ALLOWABLE ANNUAL DOSE LIMIT*
Maintenance Activity Department SIG Nozzle Dam Installation System Engineering SfG Activities Westinghouse SIG Activities Westinghouse SIG Activities Westinghouse SfG Activities Westinghouse SIG Activities Westinghouse Individual's Single Event Exposure (mremr 647 918 815 613 858 980 Total Annual Exposure (mrem) 753 1736 2874 887 918 1207
- Subject annual dose limit is 5000 mrem deep dose equivalent 20