NOC-AE-03001466, January 2003 Monthly Operating Report for South Texas Project Units 1 & 2

January 2003 Monthly Operating Report for South Texas Project Units 1 & 2

ML030550797
Person / Time
Site:	South Texas
Issue date:	02/13/2003
From:	Mallen F South Texas
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
NOC-AE-03001466, STI:31556984
Download: ML030550797 (14)

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&t' Tas 77433 February 13, 2003 NOC-AE-03001466 File No.: G02 10CFR50.71 STI: 31556984 U. S. Nuclear Regulatory Commission Attention: Document Control Desk One White Flint North 11555 Rockville Pike Rockville, MD 20852 South Texas Project Units 1 and 2 Docket Nos. STN 50-498, STN 50-499 Monthly Operating Reports for January 2003 Pursuant to 10CFR50.71(a) and South Texas Project Electric Generating Station (STPEGS) Technical Specification 6.9.1.5, attached are the Monthly Operating Reports for January 2003. If you should have any questions on this matter, please contact R.L.

Hill at (361) 972-7667.

F.italen Manager, Planning &

Controls Attachments: 1) STPEGS Unit 1 Monthly Operating Report - January 2003

2) STPEGS Unit 2 Monthly Operating Report - January 2003

cc:

(paper copy) (electronic copy)

Ellis W. Merschoff A. H. Gutterman, Esquire Regional Administrator, Region IV Morgan, Lewis & Bockius LLP U.S. Nuclear Regulatory Commission 611 Ryan Plaza Drive, Suite 400 M. T. Hardt/W. C. Gunst Arlington, Texas 76011-8064 City Public Service U. S. Nuclear Regulatory Commission Mohan C. Thadani Attention: Document Control Desk U. S. Nuclear Regulatory Commission One White Flint North 11555 Rockville Pike R. L. Balcom/D. G. Tees Rockville, MD 20852 Texas Genco, LP Richard A. Ratliff A. Ramirez Bureau of Radiation Control City of Austin Texas Department of Health 1100 West 49th Street C. A. Johnson/A. C. Bakken III Austin, TX 78756-3189 AEP - Central Power and Light Company Cornelius F. O'Keefe Jon C. Wood U. S. Nuclear Regulatory Commission Matthews & Branscomb P. 0. Box 289, Mail Code: MN1 16 Wadsworth, TX 77483 C. M. Canady City of Austin Electric Utility Department 721 Barton Springs Road Austin, TX 78704

SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 1 MONTHLY OPERATING REPORT JANUARY 2003 STP NUCLEAR OPERATING COMPANY NRC DOCKET NO. 50-498 LICENSE NO. NPF-76 Approved By://- -. 2X c7 E.D.HAL-IN D te

MONTHLY

SUMMARY

South Texas Project Unit 1 operated during the reporting period at full power with no unit shutdowns or significant power reductions.

OPERATING DATA REPORT DOCKET NO. 50-498 UNIT 1 DATE Feb. 11, 2003 COMPLETED BY R L. Hill TELEPHONE 361.972.7667 OPERATING STATUS

1. REPORTING PERIOD: 1/1/03-1/31/03 GROSS HOURS IN REPORTING PERIOD: 744

2. CURRENTLY AUTHORIZED POWER LEVEL (Mwt): 3853 MAXIMUM DEPENDABLE CAPACITY (MWe-Net)" 1,250 6 DESIGN ELECTRICAL RATING (MWe-Net): 1250.6

3. POWER LEVEL TO WHICH RESTRICTED (IF ANY) (MWe-Net): None 4 REASONS FOR RESTRICTION (IF ANY): N/A THIS MONTH YR TO DATE CUMULATIVE

5. NUMBER OF HOURS REACTOR CRITICAL 744 0 744.0 99=23.

6. REACTOR RESERVE SHUTDOWN HOURS 0 0 0

7. HOURS GENERATOR ON LINE 744 0 744 0 97,637.1

8. UNIT RESERVE SHUTDOWN HOURS 0 0 0

9. GROSS THERMAL ENERGY GENERATED (MWH) 2,839,482 2,839,482 364,789,945

10. NET ELECTRICAL ENERGY GENERATED (MWH) 953,247 953,247 119,169,302

11. REACTOR SERVICE FACTOR (%) 100.0 1000 78.4

12. REACTOR AVAILABILITY FACTOR (%) 100.0 100.0 78.4

13. UNIT SERVICE FACTOR (%) 100.0 100.0 77.2

14. UNIT AVAILABILITY FACTOR (%) 100.0 100.0 77.2

15. UNIT CAPACITY FACTOR - Using MDC (%) 102.5 102.5 75 3

16. UNIT CAPACITY FACTOR - Using DER (%) 102.5 102.5 75 3

17. UNIT FORCED OUTAGE RATE (%) 00 00 133

18. SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE, & DURATION OF EACH):

Scheduled 25-day outage to allow scheduled refueling to begin on March 26, 2003.

19. IF SHUTDOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP: N/A

AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-498 UNIT 1 DATE Feb. 11, 2003 COMPLETED BY R.L. Hill TELEPHONE 361.972.7667 MONTH JANUARY DAY AVERAGE DAILY POWER DAY AVERAGE DAILY POWER LEVEL LEVEL (MWe-Net) (MWe-Net) 1 1286 17 1262 2 1286 18 1261 3 1287 19 1266 4 1287 20 1276 5 1289 21 1275 6 1285 22 1283 7 1286 23 1285 8 1287 24 1283 9 1285 25 1282 10 1287 26 1283 11 1286 27 1284 12 1282 28 1284 13 1282 29 1284 14 1278 30 1284 15 1284 31 1283 16 1266

UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-498 UNIT 1 DATE Feb. 11, 2003 COMPLETED BY R.L. Hill TELEPHONE 361 972.7667 REPORT MONTH JANUARY 1 2 3 4 5 No. Date Type Duration Reason Method of Licensee System Component Cause & Corrective Action to Prevent Recurrence (Hours) Shutting Event Code Code Down Report #

Reactor THERE WERE NO UNIT SHUTDOWNS OR SIGNIFICANT POWER REDUCTIONS DURING THE REPORTING PERIOD I III I III 1 2 3 4 5 F: Forced Reason: Method: IEEE 805-1983 IEEE 803-1983 S: Scheduled A-Equipment Failure (Explain) 1-Manual B-Maintenance or Test 2-Manual Scram C-Refueling 3-Automatic Scram D-Regulatory Restriction 4-Cont. of Existing E-Operator Training & License Exam Outage F-Administrative 5-Reduction G-Operational Error (Explain) 9-Other H-Other (Explain)

PORVS AND SAFETY VALVE

SUMMARY

There were no PORV or Safety Valves challenged during the reporting period.

SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 MONTHLY OPERATING REPORT JANUARY 2003 STP NUCLEAR OPERATING COMPANY NRC DOCKET NO. 50-499 LICENSE NO. NPF-80 Approved By. _. _ _ _ _ _ 02 I/o*

E.D. IALPIN Date

MONTHLY

SUMMARY

South Texas Project Unit 2 began the reporting period shutdown. On December 15, at 1805 the reactor was manually tripped due to a sudden high main turbine vibration. After opening the turbine and condenser, one last row blade on low-pressure (LP) rotor 22 had separated from the rotor causing some collateral damage within LP 22. Numerous last row blade cracks were discovered during visual inspections of the blades on LP 22 and 23. Additional damage was found on stationary blades in 22, the exhaust flow guide and some condenser tubes.

Metallurgical examinations found the cracks as a result of high cycle fatigue.

Following repairs, the unit was returned to service on January 22, at 0422 using a special test procedure for turbine vibration data collection. Full power was achieved on January 23, at 1502.

On January 24, at 2140 the main turbine/generator was removed from service due to excessive vibration.

The unit concluded the reporting period in Mode 5 with the secondary plant secured in order to facilitate continued repairs on the main turbine/generator rotor train.

OPERATING DATA REPORT DOCKETNO. 50-499 UNIT 2 DATE Feb.11,2003 COMPLETED BY R.L. Hill TELEPHONE 361.972.7667 OPERATING STATUS

1. REPORTING PERIOD: 1/1/03-1/31/03 GROSS HOURS IN REPORTING PERIOD. 744

2. CURRENTLY AUTHORIZED POWER LEVEL (MWt): 3,853 MAXIMUM DEPENDABLE CAPACITY (MWe-Net): 1,250.6 DESIGN ELECTRICAL RATING (MWe-Net): 1,250.6

3. POWER LEVEL TO WHICH RESTRICTED (IF ANY) (MWe-Net): None

4. REASONS FOR RESTRICTION (IF ANY): N/A THIS MONTH YR TO DATE CUMULATIVE

5. NUMBER OF HOURS REACTOR CRITICAL 80.3 80.3 94,6380

6. REACTOR RESERVE SHUTDOWN HOURS 0 0 0 65.3 65.3 92=37.

7. HOURS GENERATOR ON LINE

8. UNIT RESERVE SHUTDOWN HOURS 0 0 155,001 344,568,652

9. GROSS THERMAL ENERGY GENERATED (MWH)

10. NET ELECTRICAL ENERGY GENERATED (MWH) 46,377 46,377 112,224,344

11. REACTOR SERVICE FACTOR (%) 108 108 79.3

12. REACTOR AVAILABILITY FACTOR (%) 108 108 793

13. UNIT SERVICE FACTOR (%) 88 8.8 77.4

14. UNIT AVAILABILITY FACTOR (%) 8.8 8.8 77.4

15. UNIT CAPACITY FACTOR - Using MDC (%) 5.0 5.0 75.2

16. UNIT CAPACITY FACTOR - Using DER (%) 5.0 5.0 75.2

17. UNIT FORCED OUTAGE RATE (%) 91.2 91.2 14.0

18. SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE, & DURATION OF EACH): N/A

19. IF SHUTDOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP: 03/13/03

AVERAGE DAILY UNIT POWER LEVEL DOCKETNO. 50-499 UNIT 2 DATE Feb. 11, 2003 COMPLETED BY R L Hill TELEPHONE 361.972.7667 MONTH JANUARY DAY AVERAGE DAILY POWER DAY AVERAGE DAILY POWER LEVEL LEVEL (MWe-Net) (MWe-Net) 1 17 0 2 18 0 3 19 0 4 20 0 5 21 0 6 22 238 7 23 1115 8 24 580 9 25 0 10 26 0 11 27 0 12 28 0 13 29 0 14 30 0 15 0 31 0 16 0

UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-499 UNIT 2 DATE Feb. 11, 2003 COMPLETED BY R.L. Hill TELEPHONE 361.972.7667 REPORT MONTH JANUARY 1 2 3 4 5 No. Date Type Duration Reason Method of Licensee System Component Cause & Corrective Action to Prevent Recurrence (Hours) Shutting Event Code Code Down Report #

Reactor 02-04 021215 F 508.4 A 2 02-02-005 TA TRB Reactor manually tripped due to a sudden high main turbine vibration. After opemng the turbine and condenser, one last row blade on low-pressure (LP) rotor 22 had separated from the rotor causing some collateral damage within LP 22.

Numerous last row blade cracks were discovered during visual inspections of the blades on LP 22 and 23.

Additional damage was found on stationary blades in 22, the exhaust flow guide and some condenser tubes.

Metallurgical examinations found the cracks as a result of high cycle fatigue.

03-01 030124 F 170.3 A I N/A TA TRB Main turbine/generator removed from service due to excessive vibration.

1 2 3 4 5 F: Forced Reason: Method: IEEE 805-1983 IEEE 803-1983 S: Scheduled A-Equipment Failure (Explain) 1-Manual B-Maintenance or Test 2-Manual Scram C-Refueling 3-Automatic Scram D-Regulatory Restriction 4-Cont. of Existing E-Operator Training & License Exam Outage F-Administrative 5-Reduction G-Operational Error (Explain) 9-Other H-Other (Explain)

PORVS AND SAFETY VALVE

SUMMARY

Pressurizer PORV 655A lifted due to high system pressure following the start of Reactor Coolant Pump (RCP) 2A. The PORV immediately reclosed after restoring pressurizer pressure to its normal band.

All RCPs lost power due to switchyard north Bus lockout on January 19, at 1255. RCP 2A was the first RCP restarted following the event. Reactor Coolant System (RCS) pressure was normal at 2235 psig, RCS pressurizer level was normal at 25 percent, but RCS temperature had cooled down to 551 degrees which is 16 degrees cooler than normal no-load temperature. Decay heat was extremely low following the steam generator replacement outage and forced outage turbine outage.

Prior to the pump start, the RCS was 16 degrees cooler than the steam generators due to low decay heat. The steam generator acted as a heat source upon pump start instead of a heat sink. This resulted in an increase in RCS temperature and a 12 percent increase in pressurizer level. The surge in the pressurizer squeezed the steam bubble, which rapidly increased pressure. The pressurizer pressure control system responded automatically with both spray valves. This resulted in the pressurizer spray water from RCP 2A short cycling through the 2D-spray valve and bypassing some of the spray water from the pressurizer common spray supply line.

The pump startup response is different than previous RCP starts following loss of offsite power events due to the low decay heat. In previous blackouts, the decay heat was sufficient to maintain the RCS temperature above the steam generators and the RCS and steam generators stayed thermally coupled through natural circulation flow.