ML20247H938

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Monthly Operating Rept for Apr 1998 for DAEC
ML20247H938
Person / Time
Site: Duane Arnold NextEra Energy icon.png
Issue date: 04/30/1998
From: Woodward R
IES UTILITIES INC., (FORMERLY IOWA ELECTRIC LIGHT
To:
Shared Package
ML20247H928 List:
References
NUDOCS 9805210291
Download: ML20247H938 (6)
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Text

OPERATING DATA REPORT DOCKET NO: 50-0331

. DATE: 05/15/98 Unit: Duane Arnold Enercy Center COMPLETED BY: Richard Woodward TELEPHONE: 0 19)851-7318 OPERATING STATUS Average Daily Power Level

1. Unit Name: Duane Arnold Encrev Center

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2. Reponing Period: April 1998 500

, A00 3.

Licensed Thermal Power (MW th ): 1658 300 o

3: 200 W

4. Nameplate Rating (Gross MW e DER): 565.7(Turbine) 2 E -

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5. Design Electrical Rating (Net MWe DER): 133 8 0l . - , t ,
6. Maximum Dependable Capacity (Gross MWe MDC): 15,Q
7. Maximum Dependable Capacity (Net MW e MDC): j20
8. If Changes Occur in Capacity Ratings (ltems Number 3 through 7) since the last report, Give Reasons: Not Annlicable
9. Power Level to Which Restricted, if Any (Net Mwe ): April 1-3. 93%
10. Reasons for Restrictions, if Any: End of fuel-cycle-15 coast-down April-98 1998 Cumulative
11. Hours in Reporting Period 719.0 2,879.0 203,759.0
12. Number of Hours Reactor Was Critical 53.6 2,213.6 156,980.1
13. Reactor Reserve Shutdown llours 0.0 0.0 192.8
14. Hours Generator On-Line 51.9 2,211.9 153,361.0
15. Unit Reserve Shutdown Hours 0.0 0.0 0.0
16. Gross Thermal Energy Generated (MWH) 68,162.4 3,610,720.8 218,316,763.0
17. Gross Electrical Energy Generated (MWH) 22,554.0 1,230,759.0 73,223,445.6
18. NO Electrical Energy Generated (MWH) 21,132.8 1,161,510.0 68,732,598.2
19. t dit Service Factor 7.2% 76.8 % 75.3 %
20. Unit Availability Factor 7.2% 76.8 % 75.3 %
21. Unit Capacity Factor (Using MDC Net) 5.7% 77.6 % 71.0 %
22. Unit Capacity Factor (Using DER Net) 5.5% 75.0 % 68.0%
23. Unit Forced Outage Rate 0.0% 0.0% 9.7%
24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of each):

Refueline. April 3.1998 03:55. 45 days

25. If Shutdown at End of Repon Period, Estimated Date of Stanup: May 18.1998 9805210291 980515 PDR ADOCK 05000331 R PDR

AVERAGE DAILY UNIT POWER LEVEL

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DOCKET NO: 50-0331 DATE: 05/15/98

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Unit: Duane Arnold Enercy Center

  • l COMPLETED BY: Richard Woodward l TELEPHONE: (3191851-7318 MONTH April 1998 Day Average Daily PowerI. eve!

l (MWe-Net) I 1 493.6 l 2 382.3 3 0.0 4 0.0 5 0.0 6 0.0 7 0.0 8 0.0 9 0.0 l 10 0.0 11 0.0 12 0.0 1 13 0.0 l 14 0.0  !

I 15 0.0 16 0.0 17 0.0 18 0.0

[ 19 0.0 l 20 0.0 21 0.0 22 0.0 23 0.0 24 0.0 25 0.0 26 0.0 27 0.0 I

28 0.0 29 0.0 30 0.0 I 31 #N/A l l

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- _ _ _ _ . _ _ . __ _ _ _ _ _ _ _ _ . _. _____________________________________-__-_s

REFUELING INFORMATION

, DOCKET NO: 50-0331 DATE: 05/15/98 Unit: Duane Amold Energy Center COMPLETED BY: Richard Woodward

'IELEPIIONE: (319) 851-7318 j

1. Name of facility. Duane Arnold Eneruv Center
2. Scheduled date for next refueling shutdown. April 2.1998 (actual: April 3.1998. 03:55)
3. Scheduled date for restart following refueling. May I8.1998
4. Will refueling or resumption of operation thereafter require a technical specification change or other license amendment? ym l

RTS 296 proposes fuel discharge as early as 60 hours6.944444e-4 days <br />0.0167 hours <br />9.920635e-5 weeks <br />2.283e-5 months <br /> after shutdown (versus current 120 hour0.00139 days <br />0.0333 hours <br />1.984127e-4 weeks <br />4.566e-5 months <br /> requirement). l RTS 298 proposes reducing restrictions for Standby Liquid Control System Operability requirements. I RTS 299 proposes allowing performance of Reactor Vessel Hydro without changing reactor mode.

5. Scheduled date(s) for submitting proposed licensing action and supporting information.

RTS 296, " Refueling Operations", approved April 2,1997.

RTS 298, " Standby Liquid Control Operability Requirements", approvedMarch 31,1998.

RTS 299, " Vessel Hydrostatic Pressure and Leak Testing Operability Requirements", approved March 31, 1998.

6. Important licensing considerations associated with refueling, e.g., new or different fuel design or supplier, unreviewed design or performance analysis methods, significant changes in fuel design, new operating procedures. N/A
7. Current and projected fuel assemblies inventory:

Number of Projected date oflast Fuel refueling that can be discharged Assemblies (after allowing margin for maintenance of continuous full-core discharge capability)

Installed in reactor core 368 n/a~

Previously discharged from core to Spent Fuel Storage Pool 1648 _n/a Installed Capacity of Spent Fuel Storage Pool 2411 2001 L.icensed Capacity of Spent Fuel Storage Pool (with reracking) 2829 2006 Licensed Capacity of Spent Fuel Storage Pool and Cask Pool (with 3152 2010 reracking)

DOCKET NO: 50-0331 DATE: 05/15/98 Unit: Duane Arnold Energy Center COMPLETED BY: Richard Woodward TELEPHONE: (319) 851-7318 UNIT SHUTDOWNS AND POWER REDUCTIONS REPORTMONTH: April 1998 No. Date Type Duration Reason Method of Licensee Cause (1) (Hours) (2) Shutting Event Down Reactor Report #

(3) 2 04/03/98 S 667.1 C 2 Refueling Outage 1 - F: Forced 2 - Reason 3 - Method:

S: Scheduled A-Equipment Failure (Explain) 1 Manual B-Maintenance or Test 2-Manual Scram C-Refueling 3-Automatic Scram D-Regulatory Restriction 4-Continued E-Operator Training & License Examination 5-Reduced Load F-Administrative 9-Other (Explain)

G-Operational Error (Explain)

H-Other (Explain)

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d DOCKET NO.: 50-0331 DATE: 05/15/98

., Unit: Duane Arnold Enerny Center COMPLETED BY: Richard Woodward TELEPHONE: (3191 851-7318 Monthly Operational Overview for April 1998 At the beginning of the month, with the DAEC two weeks into its end-of-Fuel-Cycle-15 coast-down, maxin.um available reactor power had decreased to 94%. On April 2 at 14:00, the plant commenced an orderly shutdowa, removing the generator from the grid at 03:55 on April 3, then inserting a planned manual scram at 05:34. Before shutting down, the plant had manufactured the equivalent of 39.9 Full-Power-liours (FPlfy ) of electricity during the first 51.9 hours1.041667e-4 days <br />0.0025 hours <br />1.488095e-5 weeks <br />3.4245e-6 months <br /> of the month.

Coast-down and ramp-down losses accounted for the remaining 12.0 FPII, the plant was on-line. At the end of Cycle 15, the DAEC had continuously operated 201 days, I hour,4 minutes, its sixth longest operational run. Average capacity factor for Cycle 15 from startup (11/16/96) to shutdown was 90.4%.

Allocation of Production & Losses: Electrical Capacity I actor I uti Power Output  % of 565.7 MWe Equivalent MWe (Design Rating) liours (FPil,)

Actual Metered Net Electric Output 29.4 5.2% 37.4 Actual Metered Plant Electric Loads 2.0 0.4% 2.5 Ofr-I ine Capacity Losses: 524.9 92.8 % 667.1 On-Line Unplanned Capacity Losses: 0.0 0.0% 0.0 Normal Capacity Losses (Avg "fullPower" MWth < 1658) 0.0 0.0% 0.0 On-Line Planned Capacity Losses 6.9 1.2% 8.8 (neg.) Weather losses - condenser pressure <2.75 In lig / Circ Water Temp < 74.5 "F 0.0 0.0% 0.0 Unplanned Ei11ciency Losses (Weather-Norm-Full-Power-MWe > 565.7 Design) 0.0 0.0% 0.0 Metering (Avg indicated power MWe - Avg mercred energy MWile) 0.0 0.0% 0.0 Excluded losses (coast-down, lack of grid demand, etc.) 25 04% 3.2 Design Gross Electric Output 1(12 1Q2 3 211g During the refuel outage 120 thrice-burned fuel assemblies have been replaced with fresh-fuel. Outage workscope includes 270 surveillance tests,157 in-service inspections, and 1623 separate maintenance actions, two torus suction strainer /

Emergency Core Cooling System (ECCS) modifications, overhaul of the high pressure turbine, and rewind of the generator stator. Excellent Local Leak Rate Test results during this outage indicate a high quality of on-going valve maintenance.

Outage radiation dose remained below the pre-outage goal. Roughly 5000 tagouts on components have been hung, and over 4300 components have been restored to service thus far during the outage without a tagging e'ror. Refueling performance has also been considered excellent. At the end of the month, DAEC was restoring systems to wvice in preparation for pre-startup testing. Cycle 16 start-up is planned for May 18.

On April 3,1998, while the plant was in flot Shutdown in preparation for Refueling Outage 15, a Primary containment Isolation System Group i isolation signal was generated (as expected) during a Surveillance Test Procedure (STP). This resulted in the unplanned closure of a Recirculation sample isolation valve which had not been verified closed. A second Recirculation sample isolation valve which was also left open failed to close as expected. This isolation valve remained open because of the failure of a relay to drop out. Operations closed the valve, ve-ified closure of all remaining Group 1 isolation vtives, then stopped performance of the STP. De relay was replaced and the STP revised. This event had no effect on the safe operation of the plant. (LER 98-02).

On April 8, three Safety Relief Valves (SRVs) momentarily opened during concurrent Local Leak Rate Testing (LLRT) of the Main Steam Isolation Valves (MSIVs) and functional testing of the Automatic Depressurization System (ADS) Timer Calibration and Logic System. ne event occurred while the plant was in cold shutdown for refueling, the vessel depressurized, the vessel head removed, and the steamline plugs installed. During the ADS test, the ADS timer had timed out and the ADS logic permissive was satisfied to allow the SRVs to open (providing sufficient pressure existed in the main steamlines). Simultaneously, during the LLRT, the main steamlines had been pressurized to about 40 psi between the steamline plugs and the inboard MSIVs. The plant computer recorded the SRV lift and the torus water level perturbation.

LLRT personnel noted a quick drop in test pressure to 6 psi. The potential conflict between the two tests had not been previously recognized.

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l On April 10, a Group Illa Primary Containment Isolation System (PCIS) actuation occurred as a result of a loss of power to a 120 Volt Instrument AC distribution panel. The power loss occurred when an alternate power supply breaker was opened for maintenance..The ca6se has not been determined. Corrective actions, included an extensive troubleshooting effort and investigation of the cause.

On April 13, a Grcrp Illa PCIS actuation occurred unexpectedly when a 125 VDC distribution breaker was opened for maintenance. The cause of this event was procedure deficiencies. Corrective actions include procedure revisions and a review of electrical panel labels and associated operating procedures.

For both above events, the affected PCIS components responded properly. The events occurred during a refueling outage when primary containment was not required, causing no actual or potential impact on public health and safety. (LER 98-03)

Licensine Action Summary:

Plant Availability: 7.2% Unplanned Auto Scrams (while/ critical) this month: 0 Number of reportable events: 0 Unplanned Auto Scrams (while/ critical)last 12 months: 0 Safety Relief Valve Challenges: 0 i

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