Text

Monthly Operating Rept for Jan 1989 for Rancho Seco
	ML20235J579
Person / Time
Site:	Rancho Seco
Issue date:	01/31/1989
From:	Muella M; SACRAMENTO MUNICIPAL UTILITY DISTRICT
To:	;
Shared Package
ML20235J568	List: ML20235J579; ML20235J582; NL-89-202, Forwards Monthly Operating Rept for Jan 1989 & Corrected Dec 1988 Rept for Rancho Seco;
References
	NUDOCS 8902240331
	Download: ML20235J579 (6)
	v • d • e

_ - _ _

JANUARY 1989 SURRY OF PLA.NT OPERATIONS Rancho Seco was in hot shutdown until the reactor was restarted at 0320 hours0.0037 days 0.0889 hours 5.291005e-4 weeks 1.2176e-4 months on January 6; however, due to auxiliary steam reducer vibration the reactor was taken subcritical at 1403 hours0.0162 days 0.39 hours 0.00232 weeks 5.338415e-4 months .

The plant remained in hot standby until January 10 when the reactor was taken critical at 0337 hours0.0039 days 0.0936 hours 5.57209e-4 weeks 1.282285e-4 months .

Power.

production began at 1719 hours0.0199 days 0.478 hours 0.00284 weeks 6.540795e-4 months . A power level of 91 percent was reached on January 17. A power reduction commenced at 2212 hours0.0256 days 0.614 hours 0.00366 weeks 8.41666e-4 months on January 31 for a manual shutdown of the reactor due to the Auxiliary Feedwater System being declared inoperable following testing of the system.

SUMMARY

OF CHANGES IN ACCORDANCE HITH 10 CFR 50.59 The plant staff accepted documentation packages in January 1989 for the

' facility changes and tests described below which required detailed safety analyses.

These changes and tests were reviewed in accordance with the Technical Specifications by the Plant Review Committee (PRC) and the Management Safety Review Committee (MSRC).

There were no documentation packages completed for procedure changes or experiments during January 1989.

1.

DCP R-0143, major, relocated the instrument rack on the second point heater and installed an orifice in the lower connection from the rack to the feedwater heaters. This modification was made to assure that adequate subcooling is achieved in the second point heaters.

The main feedwater heater and controls are located outside of containment isolation valves for main steam and main feedwater. Accidents analyzed in the USAR are bounded by containment isolation valves. This change did not increase the probability of occurrence or the consequences of an accident or malfunction of equipment important to safety previously evaluated, nor did it create the possibility an accident or malfunction of equipment important to safety of a different type than previously evaluated.

2.

PCB oil-filled station service transformers X43C1, X43C2 and X43D1 were replaced with dry-type transformers under ECN A-4697, Revision 1.

The new transformers are of the same KVA, impedance (within tolerance) and winding configuration.

This change did not increase the probability of occurrence or the consequences of an accident or malfunction previously evaluated, nor did it create the possibility of an accident or malfunction of equipment important to safety of a different type than previously evaluated.

3.

Special Test Procedure STP.1196 verified that air ejectors Y-342A and Y-3428 will operate under reduced Auxiliary Steam System pressure.

This test is not described in the USAR; however, the Auxiliary Steam System is not a safety system and is not safety-related.

Moreover, the USAR evaluates losses of secondary systems and the possible malfunction of Auxiliary Steam System plant equipment and auxiliary boilers.

This test did not increase the probability of occurrence or the consequences of an accident or malfunction previously evaluated, nor did it create the possibility of an accident or malfunction of equipment important to safety of a different type than previously evaluated.,

8902240331 890213,,

PDR ADOCK 0500 R

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SUMMARY

OF CHANGES IN ACCORDANCE HITH 10 CFR 50.59 (Continued) 4.

Special Test Procedure STP.1200 tested (1) remote operation of PV-36014A after relocation of the pneumatic controls and (2) satisfactory operation of the replacement Fisher positioner.. This test is not described in the l

USAR.

The test was performed with PV-36014A isolated.

This test did not increase the probability of occurrence or the consequences of an accident or malfunction previously evaluated, nor did it create the possibility of an accident or malfunction of equipment important to safety of a different type than previously evaluated.

MAJOR SAFETY-RELATED MAINTENANCE, TESTS, AND MODIFICATIONS NOT REQUIRING DETAILED SAFETY ANALYSES i

1.

Maintenance was performed on the '28' second point feedwater heater, 'A' and 'B' TDI diesel generators, 'B' high pressure injection pump, 'B' auxiliary feedwater pump, large and small auxiliary boilers, diesel fire pump, borated water storage system, and the Nuclear Services Electrical Building 'A' HVAC system.

Sump pumps in the tank farm were replaced.

The valve controller was relocated and the positioner replaced on the steam reducing station.

2.

ECN R-0893, Revision 1, provided a concrete barrier around the Retention Basins to prevent the influx of erosion material into the basins.

3.

ECN R-3031C, Revision 0, installed flanges on the water side of I

replacement aftercooler E-901C.

4.

ECN R-3131, Revision 1, installed a three-way valve in the Clean Drain System drain header on the turbine deck and added a line to the polishing demineralized sump.

5.

DCP 88-0012, major, provided a local alarm to indicate a high differential pressure drop across the control oil filters for the Lovejoy Main Feedwater Turbine Control System and a local differential pressure indicator for each filter canister at the Turbine Control consoles.

6.

DCP R88-0170 installed a handwheel to allow manual control of PV-36014A on loss of air supply and an approved gagging device on PV-360148 to gag the valve closed.

~

' REFUELING INFORMATION-REQUEST l ~.'

Name of Facility Rancho Seco l

2.

Scheduled date for next refueling' shutdown:

July 1.1989 l

3..

Scheduled date forl restart following refueling:

September 29. 1989 4.

Technical' Specification change or other license amendment required:

l a)

Change to Rod Index vs-Power Level Curve (TS 3.5.2) l b)

Change to Core Imbalance vs Power' Level Curve'(TS 3.5.2) i c)

Tilt Limits (TS 3.5.2) 5.

Scheduled date(s) for submitting proposed licensing action:

Hav 1. 1989_

6.

Important licensing considerations associated with refueling:

N/A l

7.

Number of fuel assemblies:

a)-

In the core:

177 b)

In the Spent Fuel Pool:

316 8.

Present licensed spent fuel capacity:

1080

~

9.

Projected date of the last refueling that.can be discharged to the Spent Fuel Pool:

December 3. 2001 i

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~ AVERAGE DAILY' UNIT POWER LEVEL g

DOCKET NO.

50-312 UNIT Rancho Seco

DATE 1/31/89 COMPLETED BY-Marla Mueller TELEPHONE-(916) 452-3211 MONTH January '1989 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net)

(MHe-Net) 1 0

17-807 2

0 18 835' 3

0 19 843 4

0 20 851 5

0 21 846 6'

'O 22 842 7

0 23 839 8

0 24' 842 ~

9.

0 25 844 10 41 26 844 11 233 27 846 12 243 28 845 13 248 29 845 14 281

.30 843 15 542 31 827 16 596 INSTRUCTIONS j

1 On this format, list the average daily unit power level in MHe-Net for each day in the reporting month. Compute to the nearest whole megawatt.

o

^'

OPERATING. DATA REPORT.

-DOCKET.NO.

50-312 DATE 1/31/89 COMPLETED BY Marla Mueller TELEPHONE (916) 452-3211

' OPERATING STATUS

.1.- Unit Name:.

Rancho Seco-Notes:

.2.

Reporting Period:

January 1989 '

3.. Licensed Thermal Power (MHt):

2.772 14. - Nameplate Rating (Gross MHe):

963 5.

Design l Electrical' Rating (Net MWe):

918'

6. ~ Maximum Dependable. Capacity (Gross MHe):

917

7.. Maximum Dependable-Capacity (Net MHe):-

873

'8.

If' changes Occur in. Capacity Ratings (Items Number 3 Through 7) Since Last Report,.

Give Reasons:.

N/A 9..

Power Level to Which Restricted, If Any (Net MHe):

N/A

10. ' Reasons For Restrictions, If Any:

N/A-This Month Yr-to-DateL Cumulative

'll.

Hours in Reporting Period

'744 744 120.912 12.

Number of Hours Reactor Has Critical 535.1 535.1 60.400.9-

13. " Reactor Reserve Shutdown Hours' O

O 10.300.2 14.

Hours Generator On-Line

-510.7 510.7 56.104.2 11 5. Unit Reserve Shutdown Hours 0-0 1.210.2

16. Gross Thermal Energy Generated (MHH) 1.101.655 1.101.655 138.430.483

17. Gross Electrical Energy Generated (MHH) 375.229 375.229 45.023.454

18. Net Electrical Energy Generated (MHH) 345.874 345.874 41.389.728-

-19.

Unit Service Factor 68.6%

68.6%

46.4%

20. Unit Availability Factor 68.6%

68.6%

47.4%

21. Unit Capacity Factor (Using MDC Net) 53.3%

53.3%

39.2%-

22.

Unit Capacity Factor (Using DER Net) 50.6%

50.6% -

37.3%,.

23. Unit Forced Outage Rate 31.4%

31.4%

42.7%

24.

Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):

25.

If Shut Down At End Of Report Period, Estimated Date of Startup:

26. Units In Test Status (Prior to Commercial Operation):

Forecast Achieved INITIAL CRITICALITY N/A N/A INITIAL ELECTRICITY N/A N/A COMMERCIAL OPERATION N/A N/A

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SUMMARY

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