CP-200800244, Transmittal of Annual Operating Report for 2007

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Transmittal of Annual Operating Report for 2007
ML080660335
Person / Time
Site: Comanche Peak  Luminant icon.png
Issue date: 02/28/2008
From: Blevins M
Luminant Generation Co
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
CP-200800244, TXX-08028
Download: ML080660335 (14)
v • d • e


Text

F Luminant Mike Blevins Executive Vice President

& Chief Nuclear Officer Mike.Blevins@Luminant.com Luminant Power P 0 Box 1002 6322 North FM 56 Glen Rose, TX 76043 T 254 897 5209 C 817 559 9085 F 254 897 6652 CP-200800244 Log # TXX-08028 Ref. #

10CFR50.36 February 28, 2008 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555

SUBJECT:

COMANCHE PEAK STEAM ELECTRIC STATION DOCKET NOS. 50-445 AND 50-446 ANNUAL OPERATING REPORT FOR 2007

Dear Sir or Madam:

By means of the Attachment to this letter, Luminant Generation Company LLC (Luminant Power) hereby submits the 2007 Annual Operating Report for the Comanche Peak Steam Electric Station (hereafter referred to as Comanche Peak Nuclear Power Plant (CPNPP)), prepared and submitted pursuant to guidance provided in C.1.b of U.S. NRC Regulatory Guide 1.16, Revision 4.

This communication contains no new licensing basis commitments regarding CPNPP Units 1 and 2.

Should you have any questions, please contact Robert Kidwell at (254) 897-5310.

Sincerely, Luminant Generation Company LLC Mike Blevins By:

  • 1A

/lred W. N~iadden Director, Oversight &

A member of the STARS (Strategic Teaming and Resource Sharing) Alliance Regulatory Affairs AmO~

Callaway : Comanche Peak

  • Diablo Canyon
  • Palo Verde
  • South Texas Project. Wolf Creek

U. S. Nuclear Regulatory Commission TXX-08028 Page 2 02/28/2008.

Attachment c -

E. E. Collins, Region IV B. K. Singal, NRR Resident Inspectors, Comanche Peak

Attachment to TXX-08028 Page 1 02/28/2008 COMANCHE PEAK NUCLEAR POWER PLANT ANNUAL OPERATING REPORT 2007 LUMINANT GENERATION COMPANY LLC I

Attachment to TXX-08028 Page 2 02/28/2008 TABLE OF CONTENTS 1.0 Summary of Operating Experience 2.0 Outages and Reductions in Power 3.0 Deleted (Reference 69 FR 35067 & TSTF-369) 4.0 Irradiated Fuel Inspection Results 5.0 Deleted (Reference 69 FR 35067 & TSTF-369) 2

Attachment to TMX-08028 Page 3 02/28/2008 1.0

SUMMARY

OF OPERATING EXPERIENCE The Comanche Peak Nuclear Power Plant (CPNPP) 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 outpuf of 14 MWt, gives a warranted NSSS output of 3425 MWt, which is the license application rating. 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. All safety systems, including the engineered safety features, are designed for operations at a maximum NSSS output of 3579 MWt and an associated maximum core output of 3565 MWt.

1.1 CPNPP UNIT 1 CPNPP 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, CPNPP Unit 1 has generated 146,115,784 net Megawatt-hours (MWH) of electricity as of December 31, 2007, with a net unit capacity factor of 83.37% (using MDC), The cumulative unit and reactor availability factors were 88.19% and 90.71% respectively, as of December 31, 2007.

On February 24, 2007, the unit began a power ramp down for its twelfth refueling outage. The unit entered the refueling outage on the same day. During the refueling outage, 88 fresh fuel assemblies were loaded for Cycle 13. The refueling outage lasted 55 days 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> and ended on April 20, 2007. Unit 1 reached 100%

power on April 24, 2007.

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

  • Reactor head replacement and head assembly upgrade project
  • GSI-191, Containment sump modification
  • Identification and inspections of leaking fuel rods
  • Alloy 600 inspections (hot leg nozzles, BMI, Other RCS locations)
  • Containment Integrated Leak Rate Testing
  • Large motor replacement for Centrifugal Charging Pump 1-01, Component Cooling Water Pump 1-02, Residual Heat Removal Pump 1-02, Heater Drain Pump 1-02, and Circulating Water Pump 1-04 3

Attachment to TXX-08028 Page 4 02/28/2008 Figure 1.1 provides the generation profile of the average daily net electrical output of Unit 1 for 2007. Table 1.1 is a compilation of the yearly and total summaries of the operating data.

Duringthis reporting period there were no failures or challenges to the Safety Valves.

1.2 CPNPP UNIT 2 CPNPP 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, CPNPP Unit 2 has generated 126,166,721 net Megawatt-hours (MWH) of electricity as of December 31, 2007, with a net unit capacity factor of 86.85% (using MDC). The cumulative unit and reactor availability factors were 90.30% and 92.64% respectively, as of December 31, 2007.

Figure 1.2 provides the generation profile of the average daily net electrical output of Unit 2 for 2007. Table 1.2 is a compilation of 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 CPNPP UNIT 1 Table 2.1 describes unit operating experience including unit shutdowns and provides explanations of significant reductions in average power levels for CPNPP Unit 1.

Unit 1 had one unit shutdown, one reactor shutdown and one unplanned power change greater than 20% of full power.

2.2 CPNPP UNIT 2 Table 2.2 describes unit operating experience including unit shutdowns and provides explanations of significant reductions in average power levels for CPNPP Unit 2.

Unit 2 had no unit shutdowns, reactor shutdowns, and no unplanned power changes greater than 20% of full power.

4

Attachment to TXX-08028 Page 5 02/28/2008 3.0 EXPOSURE AND MONITORING REPORT Deleted (Reference 69 FR 35067 & TSTF-369).

4.0 IRRADIATED FUEL INSPECTION RESULTS 4.1 CPNPP UNIT 1 Core Offload Visual Examination Results Inspection personnel performed visual examination of Unit 1, Cycle 12 fuel assemblies as each assembly was withdrawn from the Fuel Building upender during core off-load operations. The new "Quad-camera" system was used around the Fuel Building upender which simultaneously allows underwater camera inspection of the four faces of an assembly as it is withdrawn from the upender basket. The new system reduces inspection time and provides a much more effective inspection of fuel assemblies relative to previous binocular visual inspections performed from the edge of the spent fuel pool.

All fuel assemblies appeared to be in good condition with no anomalies observed, including the assembly identified as leaking by in-mast sipping. Only very light residual crud levels on the assemblies were observed which is consistent with crud patterns observed during previous refueling outage inspection campaigns.

In-Mast Sipping (IMS) and Ultrasonic Testing (UT) Results During refueling outage 1RF12 core offload, IMS inspections were performed on all assemblies. The results provided clear indication of one second-burned leaking fuel assembly (N75) which was scheduled to be discharged during the refueling outage.

IMS can identify a leaking assembly but does not provide information on the number or location of leaking fuel rods within a leaking assembly. To determine this information, UT is performed on each fuel rod of each assembly identified as leaking by IMS. UT showed distinct indications of a leaking rod in assembly location A-1 (corner rod) of assembly N75. Close-up camera inspection of the leaking rod in A-1 showed significant bowing and possible cracking of the rod. In response to these indications, the decision was made not to extract the rod for further examination due to the increased risk the rod breaking apart during the process. Consequently, the primary defect location was not observed. The indications of bowing and cracking were consistent with secondary hydriding.

5

Attachment to TXX-08028 Page 6 02/28/2008 4.2 CPNPP UNIT 2 Also during 1RF12, leaking Unit 2, Cycle 9 assemblies KK28 and KK32 were also UT examined to determine the number and location of the leaking fuel rods in those assemblies. These assemblies had been previously identified as leaking by IMS during the last Unit 2 refueling outage (2RF09) in October,.2006. UT identified one leaking rod in assembly KK28 (location D-13) and one leaking rod in KK32 (location E-5).

The leaking rod in KK28 was successfully extracted and examined using the reconstitution equipment and replaced with a solid stainless steel rod. A debris wear scar which appeared to penetrate through the clad was observed just above the lower end plug area of the rod. -There were also several areas with indications of secondary hydriding observed axially along the rod.

An attempt was made to extract the leaking rod in assembly KK32, however, the rod severed due to secondary hydriding at approximately 40" from the top of the rod. The primary defect location for this rod was not observed as a result.

Apparent cause analyses were performed on all three leaking rods examined during 1RF12. Debris induced fretting of the clad was determined to be the likely cause of all leaking rods.

5.0 OUTAGE RELATED SINGLE RADIOACTIVITY RELEASE OR RADIATION EXPOSURE TO AN INDIVIDUAL THAT ACCOUNTS FOR MORE THAN 10 PERCENT OF ALLOWABLE ANNUAL VALUES Deleted (Reference 69 FR 35067 & TSTF-369) 6

Attachment to TXX-08028 Page 7 02/28/2008 FIGURE 1.1 COMANCHE PEAK NUCLEAR POWER PLANT - UNIT 1 GENERATION PROFILE AVERAGE DAILY UNIT POWER LEVEL (2007) 1,400 1,200 1,000 800 600 400 200 0

JAN FEB MAR APR M.AY JUN JUL AU (-3 SEPF OCT N_,V 0 EC, 7

Attachment to TXX-08028 Page 8 02/28/2008 TABLE 1.1 COMANCHE PEAK NUCLEAR POWER PLANT - UNIT 1 ANNUAL ELECTRIC POWER GENERATION DATA (2007)

YEAR CUMULATIVE Hours RX was Critical 7,460.13 135,358.88 RX Reserve Shutdown Hours "0

2870.89 Hours Generator On-line 7,437.68 134,397.05 Gross Thermal Energy Generated (MWH) 25,512,038.40 449,557,398.60 Gross Electric Energy Generated (MWH) 8,931,372 152,481,699 Net Electric Energy Generated (MWH) 8,596,749 146,115,784 RX Service Factor (%)

85.16 88.82 RX Availability Factor (%)

85.16 90.71 Unit Service Factor (%)

84.91 88.19 Unit Availability Factor (%)

84.91 88.19 Unit Capacity Factor (%, using MDC net) 85.34 83.37 Unit Capacity Factor (%, using DER net) 85.34 83.37 Unit Forced Outage Rate (%)

0.00 2.31 8

Attachment to TXX-08028 Page 9 02/28/2008 FIGURE 1.2 COMANCHE PEAK NUCLEAR POWER PLANT - UNIT 2 GENERATION PROFILE AVERAGE DAILY UNIT POWER LEVEL (2007) 1,400 1,200 1.000 800 600 400 200 A

OPT-217 OPT-217 CWP 2-01 Motor Failed OPT-217 I

TDAFWP Auto Start 2-HV-2452-1 Failed open OPT-217 2-HV-2958 CEV 2-03 Inlet valve Loss of vacuum 0

JAN FEB M'.IAR APR MAY JUN JUL AULG SEP OCT NOV DEC' 9

Attachment to TXX-08028 Page 10 02/28/2008 TABLE 1.2 COMANCHE PEAK NUCLEAR POWER PLANT - UNIT 2 ANNUAL ELECTRIC POWER GENERATION DATA (2007)

YEAR CUMULATIVE Hours RX was Critical RX Reserve Shutdown Hours Hours Generator On-line 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 (%)

8,760.00 0

8,760.00 30,275,848.22 10,648,722 10,248,998 100.00 100.00 100.00 100.00 101.74 101.74 0.00 114,666.79 2,366.46 114,070.82 383,154,933.02 131,444,280 126,166,721 90.77 92.64 90.30 90.30 86.85

.86.85 2.25 10

Attachment to TXX-08028 Page 11 02/28/2008 TABLE 2.1 COMANCHE PEAK NUCLEAR POWER PLANT - UNIT 1 UNIT OPERATING EXPERIENCE INCLUDING SHUTDOWNS AND SIGNIFICANT POWER REDUCTIONS DURING 2007 TYPE F: FORCED NO DATE S: SCHEDULED METHOD OF SHUTTING DOWN THE REACTOR OR REASON REDUCING POWER DURATION*

(HOURS)

CORRECTIVE ACTION/COMMENTS l

02/24/2007 2

12/13/07 S

F 1323.32 NA C

2 On 2/24/07 at 0954, Unit I commenced power reduction from 94% to 24% reactor power in preparation for unit shutdown to commence refueling outage I RF 12.

Operators manually tripped the reactor per procedure at 1200 hours0.0139 days <br />0.333 hours <br />0.00198 weeks <br />4.566e-4 months <br /> this date to enter MODE 3. Entered MODE 4 at 1702 hours0.0197 days <br />0.473 hours <br />0.00281 weeks <br />6.47611e-4 months <br />. Entered MODE 5 at 2236 hours0.0259 days <br />0.621 hours <br />0.0037 weeks <br />8.50798e-4 months <br />.

Entered MODE 6 on 2/26/07 at 0915 hours0.0106 days <br />0.254 hours <br />0.00151 weeks <br />3.481575e-4 months <br />. On 3/01/07 at 0226, commenced core offload to spent fuel pool. On 3/2/07 at 2250, completed core offload and entered MODE 0. On 4/03/07 at 1123, entered MODE 6 and commenced core reload. On 4/08/07 at 1300, entered MODE 5. On 4/17/07 at 2235, entered MODE 4. On 4/18 at 0754, entered MODE 3. On 4/19/07 at 1512, entered MODE 2. Reactor critical at 1652 hours0.0191 days <br />0.459 hours <br />0.00273 weeks <br />6.28586e-4 months <br />. On 4/20/07 at 0916, entered MODE 1. At 1519 hours0.0176 days <br />0.422 hours <br />0.00251 weeks <br />5.779795e-4 months <br /> Unit I synchronized to the grid ending I RF 12. On 4/24/07 at 0847, attained 100% reactor power.

On 12/13/07 at 0903, during performance of monthly rod repositioning procedure ETP-106, Shutdown Bank B, Rod J 13 dropped from 224 steps to rod bottom, 0 steps indicated. Control room operators reduced reactor power from 100%, as required per procedure to maintain reactor operating parameters. At 1625 hours0.0188 days <br />0.451 hours <br />0.00269 weeks <br />6.183125e-4 months <br /> Rod J 13 was recovered. At 1923 hours0.0223 days <br />0.534 hours <br />0.00318 weeks <br />7.317015e-4 months <br /> reactor power reached a minimum level of 42% during the evolution. This meets the NRC criteria for an unplanned power change greater than 20% of full power. At 2055 hours0.0238 days <br />0.571 hours <br />0.0034 weeks <br />7.819275e-4 months <br />, commenced return to full power operation. On 12/15/07 at 0100, Unit I returned to 100% reactor power.

Investigation determined that inadequate mechanical engagement of the gripper mechanism caused the rod to drop during repositioning.

A I

1) REASON
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 11

Attachment to TXX-08028 Page 12 02/28/2008 TABLE 2.2 COMANCHE PEAK NUCLEAR POWER PLANT - UNIT 2 UNIT OPERATING EXPERIENCE INCLUDING SHUTDOWNS AND SIGNIFICANT POWER REDUCTIONS DURING 2007 TYPE F: FORCED S: SCHEDULED METHOD OF SHUTTING DOWN THE REACTOR OR REDUCING POWER DURATION*

(HOURS)

NO DATE 1

03/12/2007 REASON CORRECTIVE ACTION/COMMENTS F

NA A

I On 03/12/07 at 2027, control room operators initiated a manual turbine runback from 100% to 89% reactor power when the Unit 2 Turbine Driven Auxiliary Feedwater Pump auto started. The auto start was caused by a leaking diaphragm in the steam supply valve 2-HV-2452-1. Unit returned to 100% power at 2358 hours0.0273 days <br />0.655 hours <br />0.0039 weeks <br />8.97219e-4 months <br /> the same day. This event does not meet the NRC criteria for an unplanned power change greater than 20% of full power.

I) REASON

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 12
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