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Annual Operating Report for 1991
	ML20090A434
Person / Time
Site:	Fermi
Issue date:	12/31/1991
From:	Orser W; DETROIT EDISON CO.
To:	; NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
	CON-NRC-92-0008, CON-NRC-92-8 NUDOCS 9203020331
	Download: ML20090A434 (17)
	v • d • e

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, . US$ ?sY w Dettb\t <- i Ec'ison EEf* ta.

i February 28, 1992 NBC-92 0008 U.S. h. clear Regulatory Commission Attnt Document Control Desk

?ashington, D. C. 20555

Reference:

Fermi 2 NRC Docket No. 50-341 NRC 1,1 cense No. NPF-43

Subject:

1991 Annual Operating Report for Fermi 2 In accordance with Fermi 2 Technical Specification 6.9.1.4 and NRC Regulatray Guide 1.16, the Detroit Edison Company is submitting the Annual t". 'reting Report for the Fermi 2 Halear Power Plant for the period of Januar) 1, 1991 through December 31, 1991 (see enclosure 1).

The 1991 Annual Operating Report for r'eral 2 satisfies the rgorting requirements of 10CFR20.407, (Personnel Monitoring Report), Technical Specification 6.9.1.5.a ( Annual Exposure Report by Function), Technical Specification 6.9 1.5.b (Safety /Reller Valve Challenges), Technical Specification 6.915.c (Emergency Core Cooling System Outages), and Technical Specification 6.9 1.5.d (Speciflu Activity Analysis of the Primary Coolant). The 1991 Annual Operating Report also includes a section on service life of the main steam bypass line. This satisfies the commitment stated in Detroit Edison letter VP-86-0154 to the Nuclear Regulatory Commission riated November 7,1986.

I If you have any questions or comments regarding this report, please contact Mr. Joseph Pendergast,, Compliance Engineer, at (313) 586-1682.

Sincerely, O Ell'- J ggg Enclosure cet T. G. Colburn A. B. Davis

, R. W. DeFayette ,

S. Stasek i

9203020331 911231 PDR 7%(N j I i

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FERMI 2 ANNUAL OPERATING HEPORT f JANUARY 1 - DECEMBER 31, 1991 DETROIT EDISON COMPANY NRC DOCKET NO. 50-341 i

FACILITY OPERATING LICENSE NO. NPF-43 l

l 1,

Enclosure to Nite-92-0008 February 28, 1992 Page 2 l

Table of Contents E8E2 1.0 Introduction ........................................ 3 2.0 Summary of Operating ................................ 3 l 2.1 Summary of Oper,. t ina Fetxt J oe .............. 3 ,

2.2 Summary of Outages _cc ; .rced Feductions Greater than 20 Percent of full Poetr . . . . . . . . 4 2 3 Fuel Performance ............................... 7 2.4 Shore Barrier Survey ........................... 7 2.5 Saruty Heller Valve Challenges ................. 8 1

2.6 Personnel Honitoring and Exposure .............. 8 2.7 Service Life of Hain Steam Bypass Line . . . . . . . . . 11 2.8 Specirlo Activity Analysis of the Primary Coolant .............................. 11 2.9 ECCS Outages ................................... 11 J

l l

Enclosure to NRC692-0008 February 28, 1992 Page 3 1.0 Introduction The Fermi 2 Nuclear Power Plant site is located on the western shore of Lake Erie in Frenchtown Township, Honroe County, Michigan. The Nuclear Steam Supply System is a General Electric BWR 4, with a Hark I pressure-suppression containment. The plant is fully owned by the Detroit Edison Company.

2.0 Summary of Operating ;

2.1 Summary of Operating Experience This summary covers the operation of Fermi 2 from January 1,1991 to December 31, 1991. During this period, Feral 2 generated 6,180,932 Hwn (net) and was available 73 8 percent of the time. 1he forced outago rate was 1.1 percent.

The reactor was re-started on January 1, 1991 after an outage to repair the number 3 low pressure turbine. The main generator was synchronized to the grid at 0310 hours0.00359 days 0.0861 hours 5.125661e-4 weeks 1.17955e-4 months , January 2. The plant was administrative 1y limited to as low as 80 percent of rated power because of concerns for main turbine vibration. The plant was on line from January 2, until March 12.

On March 12, the moisture separator reheater re11er valve manifold drain line to the condenser separated. The reactor was manually scrammed due to an impending loss of condenser vacuum. The piping system and supports were repaired and additional supports were added to the piping system to reduce line movement. Following the repairs, the main generator was synchronized to the grid at 1715 hours0.0198 days 0.476 hours 0.00284 weeks 6.525575e-4 months , March

13. The plant remained on line until March 30.

On March 30, the plant was taken off line for the second refueling outage.

There were 1587 work requests performed during the outago.

The major outage work performed includedt o Replacement of 165 Control Rod Blades. Refueling floor activities including control rod blado changeout were completed in 55 days, 41/2 days ahead of schedule.

Also, 13 control rod drive mechanisms were replaced.

o Retubing of the main condenser with titanium condenser

, tubes to improve reactor water chemistry. The main

-condenser retubing project was completed in 63 days, 2 days ahead of schedule.

Enclo:uro to '

NRG-92-0008 February 28, 1992 Page 4 o Replacement of the 4th and 5th stage blades on all 3 low pressure turbines and inspection of the high pressure turbino. Turbine generator maintenance work was completed in 70 days (one day behind schedule).

The outage was scheduled for 72 days. The main generator was synchronized to the grid June 10, resulting in an actual outage lenEth of 72 days 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months .

The plant was removed from the grid on June 14 to perform planned turbine balancing.

On June 27, an overheating of the 2A main unit transformer was detected by Quality Assurance inspectors. The main generator breakers CH and CF were manually opened resulting in a reactor scram due to a turbine control valve fast closure. The overheating was caused by circulating current due to inadequate alcarance between the transformers oil coolant piping and the isophase bus duct housing. Repairs were made and the main Benerator was synchronized to the grid on June 28. ,

The main generator was taken off the grid on September 25, for repair of the Eenerator allp rings. The reactor remained critical. Repairs were made and the main generator was synchronized to the grid on September 29.

On December 10, the main generator was taken off the grid for replacement of the main unit transformer 2A. 1he replacement was successfully completed and the generator was synchronized to the grid on December 20. The main generator remained synchronized to the Brid through the rest of the year.

2.2 Summary of Outages and Forced Reductions Greater than 20 Percent of Full Power February, 1991

- February 2, 1991 - Power Reduction l

Reduced power from approximately 80 percent of rated power to 58 percent of rated power to repair the south reactor feed pump drain line.

- February 22, 1991 - Power Reduction i

Reduced power from approximately 80 percent of rated l power to 60 percent of rated poser for control rod l pattern adjustment.

Enclo:ure to NRC-92-0008 February 28, 1992 Page 5 Harch,1Q21

- Harch 12,1991 - 34.9 Hours Shutdown Holature separator reheater relief valve manifold drain line to the condenser separated. The reactor was manually scrammed from approximately 90 percent of rated power due to an impending loss of condenser vacuum. The piping system and supports were repaired and additional supports were added to the piping system to reduce line movement. 'this was reported by Licensee Event Report (LER)91-004.

- March 16, 1991 Power Reduction Reduced power from approximately 92 percent of ra.ed power to 60 percent of rated power for additional moisture separator reheater repairs.

- March 30,1991 - 1741 Hours Shutdown Shutdown for the second refueling outage.

June, 1991

- June 14, 1991 - 118 3 Hours Shutdown Shutdown for main turbine balancing and feed water heater repairs. During the subsequent startup and prior to generator synchronization to the grid, the plant was _

shutdown on June 17, from approximately 20 percent rated power for additional feedwater system repairs.

- June 23, 1991 - Power Heduction Reduced power from approximately 54 percent of rated power to 33 percent or rated power due to south reheater seal tank repairs.

- June 27, 1991 - 38.7 Hours Shutdo6-Heactor scram from approximately 100 percent of rated power due to manually opening main generator output breakers CH and CF. This action was in response to a main unit transformer 2A overheat condition. This was reported by LER 91-015.

July, 1991

- July 13, 1991 - Power Reduction Reduced power from approximately 100 percent of rated power to 54 percent or rated power for completion of the Maximum Extended Operating Domain test program.

Enclo uro to NR7-92-0008 .

February 28, 1992 '

Page 6 '

September 1991

- September 25, 1991 - Power Reduction i Reduced powcr from approximately 100 percent rated power to 18 percent rated power and removed the main generator from the grid to perform corrective maintenance on the main generator altp rings.

October 1991

- October 19, 1991 - Power Reduction Reduced power from approximately 100 percent of rated power to 79 percent of rated power. The power change i was made for performance of high pressure turbine valve I surveillance, deep and shallow control rod pattern adjustments and main unit transformer 2A testing.

- October 26, 1991 - Power Reduction Reduced power from approximately 100 percent of rated power to 67 percent of rated power. The power reduction was due to the south heater drain pump bearing failure and the resulting reactor recirculation pump run back.

November 1991 '

- November 5, 1991 - Power Reduction Reduced power from approximately 100 percent of rated power to 79 percent of rated power in order to take the center heater drain pump out of service for repair of a steam leak on the discharge line vent valve.

- November 25, 1991 - Power Reduction Reduced power from approximately 100 percent of rated power to 75 percent of rated power in order to take the center heater drain pump out of service for maintenance.

- November 29, 1991 - Power Reduction Reduced power from approximately 100 percent of rated power to 78 percent of rated power, due to the shutdown of the north heater drain pump. Center heater drain pump was placed in service.

A Enclo:ure to NHO-92 0008 February 28, 1992 Page 7 December 1991

- December 10, 1991 - 234.9 Hours Shutdown Shutdown to replace main unit transformer 2A.

23 Fuol Performance The plant completed its second fuel cycle and began its !

third fuel cycle following a 72.5 day refueling outago. The core currently containo 316 cycle one fuoi bundles, 220 cycle two fuel bundles and 228 new fuel bundles, 4 of which are Asea Brown Boveri SVEA-96 Lead Fuel Assemblics.

The reactor was operated in a control cell core modo with only one sequence for both cycle two and three during 1991, so there were no control rod sequence exchanges.

Power reductions were required on three separate occasions for shallow rod pattern adjustments (2-cycle two; 1-cycle three) and six shutdowns after achieving criticality (2-cycle two; 4-cycle three) occurred during the year.

Reactor power was administratively derated to as low as 80 percent at the close of cycle two due to turbine vibration problems. During cycle three, power reductions for rod pattern adjustments were less frequent than in previous fuel cycles following completion of the Maximum Extended Operating Domain test program, when full usage of the extended operating regions was realized.

Cycle two produced 71 effective full power days (EFPD) and cycle three produced 178 EFPD in 1991. There were no indications of fuel pin leakage or other fuel failures during the year.

2.4 Shore Barrier Survey 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 or 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 Specification Table 3 7 3-1. Civil Engincoring Drawings 6C721-44 through 49 were revised to incorporate the survey data. No unusual incidents occurred in 1991 that would have required additional surveillance.

2.5 safety Relief Valve Challenges There were no safety relief valve challenges during 1991.

Enclo:uro to NRC-92-0008 February 28, 1992 Page 8 2.6 Personnel Monitoring and Exposure Pursuant to 10CFH20.407(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.

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). Rt.diation exposures were determined using the direct reading dosimeter (DRD) technique and were adjusted by the total TLD to DRD dose ratio. The number of measured individuals (with radiation exposures >100 aren) reported in Tables 2.6-1 and Table 2.6-2 are different due to the measurement techniques. There was one person which had a dose greater than one REH. The actual dose was 1.075 REM.

EncloCuro to ;

NRO-92-0008 February 28, 1992 Page 9 Table 2.6-1 Statistical Summary Report of the Number of Individuals for Whom Personnel Honitoring was Provided For the Period January 1, 1991, to December 31, 1991 NUMBER OF INDIVIDUALS ESTIMATED Wil0LE DODY EXPOSURE RANGE IN EACll RANGE (REM) 1965 No Measurable Exposure 539 Exposure < 0.100 358 0.100 to 0.249 269 0.250 to 0.499 50 0.500 to 0.749 6 0.750 to 0.999 1 1.000 to 1 999 0 2.000 to 2.999 0 3 000 to 3 999 0 4.000 to 4.999 0 5 000 to 5 999 0 6.000 to 6.999 0 7.000 to 7.999 0 8.000 tu 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 l

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. EnclosurO to I NHC-92-0008 l February 28, 1992 Page 11 i 2.7 Service Life of Hain Steam Hypass Line In accordance with Detroit Edison letter VP-86-0154, dated November 7,1986, Lho 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 l cumulative value of 100 days is not to be exccoded without prior NRC notification. i Evaluations performed by Stone and Webster and by llopper and Associates concluded that the bypass lines are acceptable for safo 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 which will allow it to function for the life of the plant under anticipated operating conditions. The total value for 1991 is 5.53 days and the cumulative value is 30.98 days, well within the constraint of 100 days. The annual average use of the bypass lines is expected to decrease in the future.

2.8 Specific Activity Analysis of the Primary Coolant Exceeding the Limits of Technical Specification 3 4.5 During 1991, the speciffo activity of the primary coolant did not exceed the limits af Technical Specification 3 4.5.

2.9 ECCS Outages Pursuant to Fermi 2 technical specification 6.9.1.5.o, a summary of ECCS system outages which occurred between January 1, 1991 and December 31, 1991 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 spray, high pressure coolant injection (llPCI), and automatic 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 operablo per Technical Specifications.

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Enclosure to a

WRO-92-0008 February 28, 1992 Page 12 ECCS Outagos Table 2.9-1 ECCS Outage llours January 1,1991 to Decettber 31, 1991 ,

ECCS System fporced flours Planned flours ,

LPCI Division ! 0.0 20.16 LPCI Division 11 0.0 14.08 Core Spray Division 1 14.3 16.48 Core Spray Division II 0.0 15.58 HPCI 52.23 52.28 ADS 0.0 0.0

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Enclosuro to WitC-92-0008 February 28, 1992 Page 13 DIVISION I thW PRESSURE COOLANT INJ1X7fl0N ECCS System Outage Division I Low Pressure Coolant Injection Out of Service from 0510 02/05/91 to 01?0 02/06/91 Duration: 20.16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months Planned Outage Outage Summary:

The division ! LPCI system was removed from service to perform variour corrective maintenance (CH) and preventive maintenance (PH) activities. Following completion of the activities and required surveillances, the division 1 LPCI system was returned to service.

DIVISION 11 thW PRESSURE COOLANT INJECTION ECCS System Outage: Div*sion 11 Low Pressure Coolant Injection Out of Service from O WS 02/12/91 to 2010 02/12/91 Duration: 14.08 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Planned Outage Outage Summary The division !! LPCI system was removed from service to perform various CH and l'M activities. Following completion of the activities and required surveillances, the Division !! LPCI system was returned to service.

1 Encloruro to NRC-92-0008 February 28, 1992 Page 14 DIVISION I CORE SPRAY ECCS System Outage: Division I Core Spray Out of Service from 0501 03/05/91 to 2130 03/05/91 Duration: 16.48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months Planned Outage Outage Summary The division I core spray system was removed from service to perform various PH activities. Following complet!on of the activities and required surveillances, the division I core spray system was returned to service.

ECCS System Outage: Division 1 Core Spray Out of Service from 2037 12/22/91 to 1055 12/23/91 Duration: 14.30_ hours Forced Outage Outage Summary:

The division I core spray system was declared inoperable after closing and deenergizing a normally open motor operated valve (HOV) in the discharge path. The action taken was as a result of a slow pressure increase in the system. The valve was returned to service and the normal surveillance completed. The system was declared operable after returning the deenergized HOV to service.

DIVISION II CORE SPHAY ECCS System Outage: Division 11 Core Spray Out of Service from 0600 02/19/91 to 2135 02/19/91 Duration: 15 58 hours6.712963e-4 days 0.0161 hours 9.589947e-5 weeks 2.2069e-5 months Planned outage Outage Summary:

The division 11 core spray system wes removed from service to perform various FM activities. Following et apletion of the activities and required surveillances, the divistor,11 coro spray system was returned l

Lo service.

l 1

EncloOure to l NRC-92-0008 February 28, 1992 Page 15 HIGH PRESSURE 000LANT INJECTION ECCS System Outage: High Pressure Coolant Injection Out of Service from 1420 01/16791 to 2312 01/16/91 i Duration: 8.87 hours0.00101 days 0.0242 hours 1.438492e-4 weeks 3.31035e-5 months Forced Outage i

Outage Summary: -i

)

The HPCI system was removed from service to replace a trip unit that i failed during a surveillance. The trip unit failed due to a degraded !

translator. Following. completion of the replacement and required surveillance, the HPCI system was returned to service. This was i reported in LER 91-001.

ECCS System Outage: High Pressure Coolant Injection f Out of Service from 0145 06/11/91 to 0922 06/11/91 !

-Duration: 7.62 hours7.175926e-4 days 0.0172 hours 1.025132e-4 weeks 2.3591e-5 months Planned Outage f Outane Summary:

The HPCI system was removed from service to purity its hydraulio oil !

system. Following the purification the HPCI system was returned to l service. t ECCS System Outage: High Pressure Coolant Injection Out of Service from _1900 07/18/91 to 0402 07/19/91 i

-Duration: 9 03 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months Porced Outage Outage Summary:

The HPCI system was removed from service to repair / rework the valve position indication of valve E41-F402 which was discovered to not indicate closed during stroking for surveillance testing. -Following rework of E41-F402 position indication and the_ required surveillance, ,

the HPCI system was returned to service.

ECCS System Outages- High Pressure Coolant Injection Out of Service from 0600 09/04/91 to 0550 09/05/91 Duration: 23.83 hours9.606481e-4 days 0.0231 hours 1.372354e-4 weeks 3.15815e-5 months -Planned Outage Outage Summary:

The HPCI system was removed from service to perform various CH and PH E

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

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Enclosure to l NRC-92 0008 February 28, 1992 .

Page 16 l

ECCS System Outage: liiL 41 Pressure coolant Injection Out of Service from I2ES'lD/5h/91 to 0235 10/05/91 Duration: 20.83 hours9.606481e-4 days 0.0231 hours 1.372354e-4 weeks 3.15815e-5 months Planned Outage Outage Summary:

The llPCI system was removed from service to purify its hydraulle oil system. Follo. sing tht purification, the llPCI system was returned to service.

ECCS System Outages liigh Pressure Coolant Injection Out of Service from 1953 11/20/91 to 0613 11/22/91 Duration: 34.33 hours3.819444e-4 days 0.00917 hours 5.456349e-5 weeks 1.25565e-5 months Forced Outage Outago Summaryl The llPCI system was removed from service to replace a failed hydraulio actuator (ECR) that resulted in a llPCI system failure to start.

Following troubleshooting, ECR replacement, and the completion of required surveillances, the ifPCI system was returned to service. This was reported in LER 91-020.

AUlt)MATIC DEPRIESUHIZATION SYSThH ECCS Syatem Outage: Automatic Depressurization Out of Service from 0000 0/00/91 to 0000 0/00/91 Duration: 0.0 hours0 days 0 hours 0 weeks 0 months No Outages There were no ADS outages at a time when ADS was required to be operable por Technical Specifications.

NRC-92-0008, Annual Operating Report for 1991

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