ML20034F253

Annual Operating Rept for 1992

ML20034F253
Person / Time
Site:	Fermi
Issue date:	12/31/1992
From:	DETROIT EDISON CO.
To:
Shared Package
ML20034F249	List: ML20034F253 NRC-93-0009, Forwards Fermi 2 Annual Operating Rept for 1992. Rept Satisfies Reporting Requirements of 10CFR20.407 & TS 6.9.1.5.a,b,c & D.Rept Also Include Section on Service Life of Main Steam Bypass Line,Per Commitment in Util
References
NUDOCS 9303020488
Download: ML20034F253 (14)

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FERMI 2 ANNUAL OPERATING REPORT JANUARY 1 - DECEMBER 31, 1992 l

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NRC DOCKET NO. 50-341 l

FACILITY OPERATING LICENSE NO. NPF-43 l

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, Enclosure to NRC-93-0009 February 26, 1993 Page 2 Table of Contents

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D 1.0 Introduction........................................

3 2.0 Summary of Operating................................

3 2.1 Summary of Operating Experience................

3 2.2 Summary of Outages and Forced Reductions

-j Greater than 20 Percent of Full Power........

4 2 3 Fuel Performance................................

6 2.4 Shore Barrier Survey...........................

7 2.5 Safety Relief Yalve Challenges.................

7 2.6 Personnel Monitoring and Exposure..............

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27 Service Life of Main Steam Bypass Line.........

10 2.8 Specific Activity Analysis of the Primary Coolant..............................

10 2.9 ECCS Outages...................................

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Enclosure to NRC-93-0009 February 26, 1993 Page 3 1.0 Introduction The Fermi 2 Nuclear Power Plant site is located on the western shore of Lake Erie in Frenchtown Township, Monroe County, Michigan. The Nuclear Steam Supply System is a General Electric BWR 4, with a Mark I pressure-suppression containment. The plant is fully owned by the Detroit Edison Company, i

2.0 Summary of Operating i

2.1 Summary of Operating Experience l

This summary covers the operation of Fermi 2 from January 1, 1992 to December 31, 1992. During this period, Fermi 2 generated 7,356,765 MWH (net) and was available 79 9 percent of the time. The forced outage rate was 2.7 percent.

The plant was on line from January 1 until March 16.

On March 16, during the performance of a Technical Specification surveillance test on Division 2 Reactor Water Levels 1, 2 and 8, an inadvertent actuation of the Low Pressure Coolant Injection (LPCI) system Loop Select Logic i

(LSL) occurred. The LSL signal caused the Reactor l

Recirculation Pump "B" discharge valve to close. The resulting core flow decrease led to entry into Region A of the power / flow map. No thermal hydraulic instability occurred. By procedure and the Technical Specification j

l Action Statement, the reactor operator then manually tripped l

l the reactor by placing the mode switch in the " Shutdown"

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l position. The plant responded as expected to the resultant i

l manual scram. The LSL actuation signal was caused by a l

short circuit condition 1.n a Digital Multimeter (DMM). The DMM in question, and all DMM's of the same model number and series have been taken out of service at the plant.

Following start up activities the main generator was l

synchronized to the grid on March 18. The plant remained on l

line until April 7.-

l On April 7, during performance of a routine surveillance on drywell and suppression chamber vacuum breaker operability, a vacuum breaker did not close after being opened. The vacuum breaker actuator (utilized during testing only) bound in the open position. The actuator cylinder for the vacuum breaker was replaced. The vacuum breaker was then successfully stroke tested. Following start up activities the main generator was synchronized to the grid on April

11. The plant remained on line until September 12.

On September 12 the main generator was removed from the electrical system for the third refuel Outage.

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Enclosure to l

NRC-93-0009 February 26, 1993 Page 4 The major work included:

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o Refuel.

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Modification and setpoint changes supporting the Power Uprate Project.

o Installation of an Eighth Condensate Filter Demineralizer.

o Installation of a Torus Hardened Vent.

o Replacement of a Main Unit Transformer.

o Repair of a crack discovered during the inspection of the steam dryer.

o Replacement of 160 feet of large bore piping under Erosion / Corrosion program.

There were 1456 work requests performed during the outage.

l Modifications performed during the outage totaled one hundred and four.

l The main generator wts synchronized to the electrical system November 7 The plant remained on line until November 18.

On November 18, the plant was manually scrammed due to the loss of Heater Feed Pumps (HFP). The inadvertent opening of l

a condensate demineralizer inlet valve resulted in the loss of the HFP suction pressure and consequent trip of the HFP.

The root cause of this event was determined to be personnel error by a non-licensed operator. The non-licensed operator inadvertently opened valve N20-F004H due to inattention to detail. The non-licensed operator did not use proper self-checking before opening the valve. An accountability meeting was held with the individual involved and plant management. This event was included in Operations Requalification Training. Followini start up activities the l

main generator was synchronized to the grid on November 21.

The plant remained on line until December 5 On December 5 the plant shutdown to repair the extraction steam line which ruptured inside the main condenser, i

Following start up activities the main generator was synchronized to the grid on December 13 The main generator remained synchronized to the grid through the rest of the year.

2.2 Summary of Outages and Forced Reductions Greater than 20 Percent of Full Power March, 1992 March 16, 1992 - 45.6 Hours Shutdown l

Manual reactor scraz due to operation in region of i

instability (high power to flow) following inadvertent l

actuation of safety systems during surveillance test.

' Enclosure to NRC-93-0009 February 26, 1993 Page 5 The safety system actuation occurred when a digital multimeter shorted internally. This event was reported by LER 92-002.

April, 1992 April 7, 1992 - 92.8 Hours Shutdown During performance of a routine surveillance on drywell and suppression chamber vacuum breaker operability, a vacuum breaker did not close after being opened. The vacuum breaker actuator (utilized during testing only) bound in the open position. This event was reported by LER 92-003 August, 1992 August 29, 1992 - Power Reduction Reduced power to perform flux tilt testing to determine the location of a fuel defect. This was done to minimize the scope of fuel sipping required during the Third Refuel Outage. The fuel defect was the first fuel defect found at Fermi 2.

September, 1992 September 12, 1992 - 1358.5 Hours Shutdown Removed main turbine generator from the electrical system for the scheduled refueling outage. Following outage activities the plant was synchronized to the grid on November 7.

November, 1992 November 18, 1992 - 57.2 Hours Shutdown Scram due to loss of HFP.

Inadvertent opening of condensate demineralizer inlet valve resulted in loss of HFP suction pressure and consequent trip of HFP. This event was reported by LER 92-012.

November 28, 1992 - Power Reduction Repair leaking flange of the high pressure throttle valve of the south reactor feed pump turbine.

December, 1992 December 2, 1992 - Power Reduction Recirculation Pump runback on loss of feedwater heater drains. Heater drains did not actually trip, but heater levels fluctuated.

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Enclosure to NRC-93-0009 February 26, 1993 l

Page 6 December 4,1992 - Power Reduction Power reduction to monitor number 4N heater pressure and extraction steamline. Extraction steamline problem is suspected.

December 5, 1992 - 209.6 Hours Shutdown Repair of extraction steam line rupture.

2 3 Fuel Performance The plant completed its third fuel cycle or. September 12, and began Cycle 4 on November 4.

During the third refuel outage, the remaining 316 bundles of initial-load fuel were discharged. These were replaced with 92 bundles of initial-load fuel, which had been removed at the end of Cycle 1, and 224 bundles of new GE11-type fuel. The amount of thermal energy generated during the year was 247.5 FPD (Full Power Days) in Cycle 3 and 38.0 FPD in Cycle 4.

Indica + dons of a leaking fuel pin were observed near the end of Cycle 3 A Flux Tilting proces was used prior to the outage to locate the leak. This was successful in identifyin; tha control cell (4 bundles) which contained the leaking butedle. Fuel sipping was performed during the outage and successfully identified the leaking bundle. The leaker was a GE6 non-barrier type bundle.

It was one of the 316 bundles discharged during the outsge. No further indications of leaking fuel have been observed since beginning Cycle 4 operation.

Fermi 2 was licensed for Power Uprate of 4.2 percent (thermal) for Cycle 4, 2.1% of which was actually attained before the end of the year. The following additional improvements are expected to improve unit capacity factor by reducing the number and extent of power reductions:

Fuel loading designed to reduce reactivity variation duririg the cycle, resulting in fewer power reductions for control rod pattern adjustments.

Eliminating the use of non-barrier fuel on the interior of the core, which removes the need for fuel preconditioning.

Continuing use of Control Cell Core and Maximum Extended Operating Domain (MEOD), which were introduced in Cycle 2 and Cycle 3, respectively.

Enclosure to NRC-93-0009 February 26, 1993 i

Page 7 i

2.4 Shore Barrier Survey i

A survey of the Fermi 2 shore barrier was completed as per Procedure 43 000 01, " Shore Barrier Surveillance", and as required by Technical Specification 4.7 3 The results of the survey indicated no damage, significant movement, or deterioration of the barrier. All forty-seven survey point elevations were within the tolerance specified in Technical t

Specification Table 3 7 3-1.

Civil Engineering Drawings 6C721-44 through 49 were revised to incorporate the survey data. No unusual incidents occurred in 1992 that would have reqaired additional surveillance.

2.5 Safety Relief Valve Challenges i

There were no safety relief valve challenges during 1992.

2.6 Personnel Monitoring and Exposure I

Pursuant to 10CFR20.407(a)(2), a tabulation of the number of individuals monitored by range of measured exposure is shown in Table 2.6-1.

Whole body exposures were determined using the thermoluminescent dosimeter (TLD) technique.

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Table 2.6-2 provides a breakdown of radiation exposure by work and job function as required by Technical Specification 6.9.1.5(a).

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' nclosure to E

NRC-93-0009 February 26, 1993 Page 8 Table 2.6-1 i

St.atistical Summary Report j

of the Number of Individuals for Whom j

Personnel Monitoring was Provided For the Period January 1, 1992, to December 31, 1992 NUMBER OF INDIVIDUALS ESTIMATED WHOLE BODY EXPOSURE RANGE IN EACH RANGE (REM) 1413 No Measurable Exposure i

545 Exposure < 0.100 325 0.100 to 0.249 239 0.250 to 0.499 85 0.500 to 0.749 16 0.750 to 0.999 3

1.000 to 1.999 0

2.000 to 2.999 0

3.000 to 3 999 i

0 4.000 to 4.999 i

0 5.000 to 5.999 0

6.000 to 6.999 0

7.000 to 7 999 O

8.000 to 8.999 0

9.000 to 9.999 0

10.000 to 10.999 0

11.000 to 11.999 0

12.000 and Over

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Enclosure to NRC-93-0009 February 26, 1993 Page 10 2.7 Service Life of Main Steam Bypass Line In accordance with Detroit Edison letter VP-86-0154, dated November 7, 1986, the cumulative time the main steam bypass lines are operated with the bypass valves between 30 percent and 45 percent opened will be reported annually. A cumulative value of 100 days is not to be exceeded without l

prior NRC notification.

Evaluations performed by Stone and Webster and by Hopper and Associates concluded that the bypass lines are acceptable I

for safe operation when operated within the 100 day constraint. Based on these evaluations, the new main steam bypass piping that was installed in 1985 has a service life l

which will allow it to function for the life of the plant under anticipated operating conditions. The total value for 1992 is 20.3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> and the cumulative value is 31.82 days, l

well within the constraint of 100 days. The annual average

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use of the bypass lines is expected to decrease in the l

future.

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2.8 Specific Activity Analysis of the Primary Coolant Exceeding l

the Limits of Technical Specification 3.4.5 i

During 1992, the specific activity of the primary coolant did not exceed the limits of Technical Specification 3.4.5.

29 ECCS Outages i

Pursuant to Fermi 2 technical specification 6.9.1.5.c, a summary of the ECCS system outages which occurred between January 1, 1992 and December 31, 1992 is provided. The tabulation of ECCS outage hours (Table 2.9-1) includes both forced and planned outages for the Low Pressure Coolant Injection (LPCI), Core Sprav, High Pressure Coolant Injection (HPCI), and Autenatic Depressurization Systems (ADS). An outage was considered to be whenever one of the ECCS systems was out-of-service at a time it was required to be operable per Technical Specifications.

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Enclosure to NRC-93-0009 1

February 26, 1993 Page 11 l

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ECCS Outages l

Table 2.9-1 ECCS Outage Hours January 1, 1992 to December 31, 1992 ECCS System Forced Hours Planned Hours LPCI Division I 0.0 22.91 LPCI Division II 0.0 18.68 Core Spray Division 1 0.0 16.88 Core Spray Division II 0.0 17.42 HPCI 34.90 141.70 ADS 3 52 0.0 A.

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4 Enclosure to NRC-93-0009 February 26, 1993 Page 12 DIVISION I LON PRESSURE COOLANT INJECTION o ECCS System Outage: Division I Low Pressure Coolant Injection Out of Service from 0500 03/31/92 to 0355 04/01/92 Duration:

22.91 hours0.00105 days <br />0.0253 hours <br />1.50463e-4 weeks <br />3.46255e-5 months <br /> Planned Outage Outage Summary:

The division I LPCI system was removed from service to perform various corrective maintenance (CM) and preventive maintenance (PM) activities. Following completion of the activities and required surveillances, the division I LPCI system was returned to service.

DIVISION II LON PRESSURE COOLANT INJECTION i

o ECCS System Outage: Division II Low Pressure Coolant Injection Out of Service from 0355 04/07/92 to 2236 04/07/92 Duration:

18.68 hours7.87037e-4 days <br />0.0189 hours <br />1.124339e-4 weeks <br />2.5874e-5 months <br /> Planned Outage Outage Summary:

The division II LPCI system was removed from service to perform various CM and PM activities. Following completion of the activities and required surveillances, the Division II LPCI system was returned to service.

i DIVISION I CORE SPRAY o ECCS System Outage: Division I Core Spray Out of Service from 0609 03/24/92 to 2302 03/24/92 Duration:

16.88 hours0.00102 days <br />0.0244 hours <br />1.455026e-4 weeks <br />3.3484e-5 months <br /> Planned Outage Outage Summary:

The division I core spray system was removed from service to perform various PM activities. Following completion of the activities and required surveillances, the division I core spray system was returned to service.

Enclosure to NRC-93-0009 February 26, 1993 Page 13 DIVISION II CORE SPRAY o ECCS System Outage: Division II Core Spray Out of Service from 0530 04/14/92 to 2255 04/14/92 Duration:

17.42 hours4.861111e-4 days <br />0.0117 hours <br />6.944444e-5 weeks <br />1.5981e-5 months <br /> Planned Outage Outage Summary:

The division II core spray system was removed from service to perform various PM activities. Following completion of the activities and required surveillances, the division II core spray system was returned to service.

AUTOMATIC DEPRESSURIZATION SYSTEM o ECCS System Outage: Automatic Depressurization Out of Service from 0029 06/28/92 to 0400 06/28/92 Duration:

3.52 hours6.018519e-4 days <br />0.0144 hours <br />8.597884e-5 weeks <br />1.9786e-5 months <br /> Forced Outage Outage Summary:

ADS Logic A was declared inoperable due to RPV water level instrument B21N595A failing its channel check. Following troubleshooting and performance of a partial surveillance, the level instrument was declared operable, along with ADS Logic A.

HIGH PRESSURE COOLANT INJECTION o ECCS System Outage: High Pressure Coolant Injection Out of Service from 0930 02/15/92 to 0925 02/16/92

' Duration:

23.9 hours1.041667e-4 days <br />0.0025 hours <br />1.488095e-5 weeks <br />3.4245e-6 months <br /> Planned Outage Outage Summary:

The HPCI system was removed from service to complete a 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Auxiliary Oil Pump run. This was done to improve the quality of the oil. Following completion of the oil pump run, the HPCI system was returned to service.

o ECCS System Outage: High Pressure Coolant Injection Out of Service from 1516 05/04/92 to 1605 05/04/92 Duration:

0.8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Planned Outage Outage Summary:

The HPCI system was removed from service to clean and sample oil.

i Following the completion of this activity, the HFCI system was returned to service.

b Enclosure to NRC-93-0009 February 26, 1993 Page 14 o ECCS System Outage: High Pressure Coolant Injection f

Out of Service from 0400 05/05/92 to 2052 05/09/92 Duration:

112.9 hours1.041667e-4 days <br />0.0025 hours <br />1.488095e-5 weeks <br />3.4245e-6 months <br /> Planned Outage l

Outage Summary:

The HPCI system was removed from service to perform various CM and PM activities. The cms included replacing the HPCI Turbine Carbon Rings (shaft seals) and replacing the Auxiliary Oil Pump. Following completion of the activities and required surveillances, the HPCI system was returned to service.

j o ECCS System Outage: High Pressure Coolant Injection i

Out of Service from 1900 11/06/92 to 2305 11/06/92 Duration:

4.1 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Planned Outage Outage Summary:

i The HPCI system was not in service during Low and High Pressure testing for start up from the third refuel outage.

i o ECCS Systen Outage: High Pressure Coolant Injection Out of Service from 0245 11/22/92 to 1745 11/22/92 Duration:

15.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> Forced Outage i

Outage Summary:

The HPCI system was removed from service to perform various cms and i

PMs including a recalibration of the loop for HPCI suction pressure. Following completion of these activities and required surveillances, the HPCI system was returned to service.

o ECCS System Outage: High Pressure Coolant Injection Out of Service from 0533 11/29/92 to 0120 11/30/92 Duration:

19.9 hours1.041667e-4 days <br />0.0025 hours <br />1.488095e-5 weeks <br />3.4245e-6 months <br /> Forced Outage Outage Summary:

The HPCI system was removed from service to perform various cms and PMs including replacement of the HPCI suction pressure switch.

Following completion of these activities and required surveillances, the HPCI system was returned to service.

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