ML20069A955

Monthly Operating Repts for Feb 1983

ML20069A955
Person / Time
Site:	Quad Cities
Issue date:	03/02/1983
From:	Buss R COMMONWEALTH EDISON CO.
To:
Shared Package
ML20069A953	List: ML20069A950 ML20069A955
References
NUDOCS 8303160391
Download: ML20069A955 (21)

Text

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! QUAD-CITIES NUCLEAR POWER STATION l UNITS 1 AND 2 PONTHLY PERFORMANCE REPORT FEBRUARY 1983 l COMMONWEALTH EDISON COMPANY AND i

IOWA-ILLINOIS CAS & ELECTRIC COMPANY t

NRC DOCKET NOS, 50-254 AND 50-265 LICENSE NOS, DPR-29 AND DPR-30 i

t t

, 8303160391 830302

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TABLE OF CONTENTS F

I. Introduction II. Summary of Operating Experience A. Unit One B. Unit Two III. Plant or Procedure Changes, Tests, Experiments, and Safety Related Maintenance A. Amendments to Facility License or Technical Specifications B. Facility or Procedure Changes Requiring NRC Approval C. Tests and Experiments Requiring NRC Approval D. Corrective Maintenance of Safety Related Equipment IV. Licensee Event Reports V. Data Tabulations A. Operating Data Report B. Average Daily Unit Power Level C. Unit Shutdowns and Power Reductions 4

VI. Unique Reporting Requirements A. Main Steam Relief Valve Operations B. Control Rod Drive Scram Timing Data VII. Refueling Information VIII. Glossary i

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I. INTRODUCTION Quad-Cities Nuclear Power Station is composed of two Boiling Water Reactors, each with a Maximum Dependable Capacity of 769 MWe net, located in Cordova, Illinois. The Station is jointly owned by Commonwealth Edison Company and Iowa-Illinois Gas & Electric

' Company. The Nuclear Steam Supply Systems are General Electric Company Boiling Water Reactors. The Architect / Engineer was Sargent & Lundy, Incorporated, and the primary construction contractor was United Engineers & Constructors. The condenser cooling method is a closed cycle spray canal, and the Mississippi River is the condenser cooling water source. The plant is subject to license numbers DPR-29 and DPR-30, issued October 1,1971, and March 21, 1972, respectively, pursuant to Docket Numbers 50-254 and 50-265. The date of initial reactor criticalities for Units 1 and 2 respectively were October 18, 1971, and April 26, 1972.

Commercial generation of power began on February 18, 1973 for Unit 1 and March 10, 1973 for Unit 2.

This report was complied by Becky Brown and Randall Buss, telephone number 309-654-2241, extensions 127 and 181, 1

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II.

SUMMARY

OF OPERATING EXPERIENCE A. UNIT ONE February 1-15: The unit began the month holding load at approximately 826 MWe. On February 6 load was reduced to 700 MWe to perform weekly Turbine tests and was increased to approximately 830 MWe that same day. Load was decreased again on February 13 to 700 MWe for Turbine tests then increased to 831 MWe by 1750 hours0.0203 days <br />0.486 hours <br />0.00289 weeks <br />6.65875e-4 months <br />. On February 14, at 2300 hours0.0266 days <br />0.639 hours <br />0.0038 weeks <br />8.7515e-4 months <br />, load was dropped to 700 MWe to backwash and precoat Condensate Demineralizers and to change Reactor Feedwater Pumps. Load began increasing on February 15.

February 16-22: On February 16 the unit scrammed on a Main Steam Line High Flow signal af ter contractor personnel inadvertently Jarred an Instrument rack, resulting in a spurious trip. The Reactor was made critical at 2100 hours0.0243 days <br />0.583 hours <br />0.00347 weeks <br />7.9905e-4 months <br /> and the unit was on line at 0125 hours0.00145 days <br />0.0347 hours <br />2.066799e-4 weeks <br />4.75625e-5 months <br /> on February 17 Load was held at 560 MWe for eight hours before increasing to maximum. On February 19 load was decreased to 700 MWe for weekly Turbine tests, then increased to approximately 811 MWe on February 20.

February 23-28: On February 23 load was dropped to 700 MWe to backwash and precoat a Condensate Demineralizer. Load was increased to 808 MWe by 1500 hours0.0174 days <br />0.417 hours <br />0.00248 weeks <br />5.7075e-4 months <br /> but decreased at 1900 hours0.022 days <br />0.528 hours <br />0.00314 weeks <br />7.2295e-4 months <br /> to 700 MWe for backwashing and precoating Condensate Demineralizers. Load was increased to approximately 807 MWe on February 24. On February 26 load was reduced to perform weekly Turbine tests and to reverse flow through the main condenser. Load was increased to 803 MWe by 2200 hours0.0255 days <br />0.611 hours <br />0.00364 weeks <br />8.371e-4 months <br />.

B. UNIT TWO February 1-11 : The unit began the month shutdown for a Maintenance Outage to repair the casing on the 2C Circulating Water Pump. The Reactor was made critical on February 3 and the unit was on line on February 4 at 0155 hours0.00179 days <br />0.0431 hours <br />2.562831e-4 weeks <br />5.89775e-5 months <br />. On February 6 the unit dropped load from 700 MWe to 435 MWe to repair the 2A Moisture Separator Drain Tank Emergency Drain Valve. Load was increased to 808 MWe by February 8.

February 12-19: On February 12 load was reduced to perform weekly Turbine tests. Load was increasing at 5 MWe/ hour when load was dropped to approximately 650 MWe to backwash Condensate Demineralizers.

Load was then increased to 803 MWe by February 13 On February 14 load was dropped 200 MWe to repair the 2B Reactor Feed Pump Seal water line. The Load Dispatcher requested a further drop to approximately 400 MWe. At 2330 hours0.027 days <br />0.647 hours <br />0.00385 weeks <br />8.86565e-4 months <br /> load was increased at 100 MWe/ hour for three hours then 50 MWe/ hour to 800 MWe to perform a maximum capacity test on the Turbine.

February 20-28: On February 20 load was decreased to 500 MWe for control rod pattern adjustments. Load began increasing at 5 MWe/ hour to 805 MWe on February 22. At 2120 hours0.0245 days <br />0.589 hours <br />0.00351 weeks <br />8.0666e-4 months <br /> on February 22 the 2B Recirculation Pump Motor-Generator Set tripped on low oil pressure and load was decreased further when the 2A Recirc Pump M-G Set was reduced to minimum speed. The 2B Motor-Generator Set was restarted and load was increased to 802 MWe by February 24. On February 27, load was reduced to 600 MWe to perform weekly Turbine tests, reverse r..aln condenser flow and adjust the control rod pattern. At 0300 hours0.00347 days <br />0.0833 hours <br />4.960317e-4 weeks <br />1.1415e-4 months <br />, load began increasing at 5 MWe/ hour to 792 MWe by February 28.

1 III. PLANT'OR PROCEDURE CHANGES, TESTS, EXPERIMENTS,' AND SAFETY RELATED MAINTENANCE A. Amendments to Facility License or Technical- Specifications There were no Amendments to the Facility License or Technical Specifications for the reporting period.

B. Facility or Procedure Changes Requiring NRC Approva_1_

There were no Facility or Procedure changes requiring NRC approval for the reporting period.

C. Tests and Experiments Requiring NRC Approval There were no Test or Experiments requiring NRC approval for the reporting period.

D. Corrective Maintenance of Safety Related Equipment The following represents a tabular summary of the safety related maintenance performed on Unit One and Unit Two

1. during the reporting period. This summary includes the following headings: Work Request Numbers, LER Numbers, Components, Cause of Malfunctions, Results and Effects on Safe Operation, and Action Taken to Prevent Repetition.

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4 .- - , -~n + y . --,.. - - , _ r , . - - - .-, ,--,

1 UNIT OtlE MAINTENANCE

SUMMARY

4 CAUSE RESULTS & EFFECTS W.R. LER OF ON ACTION TAKEN TO NUMBER NUMBER COMPONENT MALFUNCTION SAFE OPERATION PREVENT REPETITION Q23580 82-39/03L 1/2 Diesel A cracked air line to The 1/2 Diesel The cracked air line Gene ra to r the Diesel Gcnerator Generator failed to was replaced.

air start pilot valve, start during testing.

Q23300 Clean-up Inlet The torque switch on The valve would not A new torque switch Isolation Valve the 1-1201-2 valve go closed sufficiently was installed.

1-1201-2 failed. to actuate the closed position switch.

Q24385 Drywell Equip- A loose coupling to The valve had dual Locked coupling to ment Drain the operator .was indication when in the operator stem.

Sump 1-2001-16 found . This prevented closed position.

proper closed position indication.

i Q24408 83-7/03L Torus Purge The valve operator air Valve 1-1601-56 A new solenoid valve Valve 1-1601-56 supply solenoid valve failed to close; was installed.

failed to open. Containment integrity i intact at all times.

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UNIT TWO itAINTENANCE

SUMMARY

CAUSE RESULTS & EFFECTS W.R. LER OF ON ACTION TAKEN TO NUMBER NUMBER COMPONENT HALFUNCT10N SAFE OPERAT10N PREVENT REPETITlON Q24359 TIP fiachine #2 The ball valve TIP #2 would not re t ract Replaced the ball valve.

, position switch completely into its failed to provide shield. Containment an open indication integrity was intact at to the T!P drive, all times.

logic.

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IV . LICENSEE EVENT REPORTS The following is a tabular summary of 'all licensee event reports for Quad-Cities Units one and Two occurring during the reporting period, pursuant to the reportable occurrence reporting requirements as set forth in sections 6.6.B.1. and 6.6.B.2. of the Technical Specifications.

UNIT ONE Licensee Event 4 Report Number Date Title of Occurrence 83-6/03L 2-13-83 Condenser Pit Level Switch 1-4441-25B Failure

.i l 83-7/03L 2-14-83 1-1601-56 Valve Failed to Isolate on Group 11 Signal 83-8/03L 2-10-83 1-1705-16A Fuel Pool Radiation Monitor Failed Source Check 83-9/03L 2-22-83 RCIC Flow Switch Instrument.

Dri f t UNIT TWO There were no Licensee Event Reports for Unit Two for the reporting period.

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V. DATA TABUIATIONS The following data tabulations are presented in this report:

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'A. Operating Data Report -

i B. Average Daily Unit Power Level C. Unit Shutdowns and Power Reductions 4

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4 2

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OPERATING DATA REPORT DOCKET NO. 50-254 UNIT ONE DATEMarch 01 1983 COMPLETED BYRondoll D Boss TELEPHONE 309-654-2241xiBi OPERATING STATUS 0000 020183

1. Reporting pe'riod 2400 022883 Gross' hours in reporting period: 672

2. Currently authorized power level (MWt): 2511 Max. Depend copacity (MWe-Net): 769* Design electrical rating (MWe-Net): 789

3. Power level to which restricted (if any)(MWe-Net): NA

4. Reasons for restriction (if any):

This Month Yr.to Date Cunulative S. Number of hours reactor was~ critical 667 i' 1411.1 76582.3

6. Reactor reserve shutdown hours 0.0 0.0 3421.9

7. Hours generator on line 662.7 1406.7 73493.3

8. Unit reserve shutdown hours ^. 0,0 0.0 909.2'

9. Gross 'thernal energy generated (MWH) 1603134 3420096 149633087

10. Gross electrical energy generated (MWH) 527212 1125668 48247549 ii. Het electrical energy' generated (MWH) 496728 1060102 '44889010

12. Reactor service factor 99.3 99.7 80.9

13. Reactor availability factor 99.3 99.7 84.5

14. Unit service factor 98.6 99.3 77.6

15. Unit ovellobility factor 98.6 99.3 78.6

16. Unit capacity factor (Using MDC) 96.1 97.4 61.6

17. Unit copocity factor-(Using' Des.MWe) 93.7 94.9 60,1

18. Unit forced outage rate 1,4 .7 6.6

19. Shutdowns scheduled over next 6 nonths (Type,Date,ond Duration o f each):

20. If shutdown at end of repo t period, estimated date of startup ___liA_________

• The MDC nay be lower than 769 MWe during periods of high anblent tenperatere due to the thernal performance of the spray canel.

SUN 0FFICIAL COMPANY NUMBERS ARE USED IN THIS REPORT

OPERATING DATA REPORT DOCKET NO. 50-265 UNIT TWO DATEMorch 01 1983 COMPLETED BYRondall D Boss

, TELEPHONE 309-654-2241x181 OPERATING STATUS 0000 020183

1. Reporting period:2400 022883 Gross hours in reporting period: 672

2. Currently authorized power ~ level (MWt): 2511 Max. Depend capacity (MWe-Net): 769* Design electrical rating (MWe-Net): 789

,3. Power level to which restricted (if any)(MWe-Net): NA

4. Reasons for restriction (if,any):

This Month Yr.to Date Cunulative

5. Number of hours reactor was' critical 606.4' 1266.1 73529.5

6. Reactor reserve shutdown hours 0.0 0.0 2985.8

7. Hours generutor on line 598.1 1254.0 70842.1

8. Unit reserve shutdown hours. 0.0 0.0 702.9 i

9. Gross thernal e.nergy generated (MWH) 1368597 2015719 147407213

10. Gross electrical energy generated (HWH) 437466 887702 46925237

11. Net electrical energy generated (MWH) 411081 833622 44017189

12. Reactor service factor 90.2 89.4 78.4

13. Reactor ovollobility factor 90.2 89.4 81.6

14. Unit service factor 89.0 88,6 75.5

15. Unit ovellobility factor 89.0 88.6 76.3

16. Unit copocity factor (Using MDC) 79.5. 76.6 61.0

17. Unit capacity factor (Using Des.MWe) 77.5 74.6 59.5

10. Unit forced outage rate 0.0 6.6 9i

19. Shutdowns scheduled over next 6 months (Type,Date,and Duration of each):

20. If shutdown at end of report period, estimated date of startup NA' 3The MDC nay be lower thcn 769 MWe daring periods of high unbient temperatore due to the thernal performance af the ' pray canel.

• iM0FFICIAL COMPANY NUMBERS ARE USED IN TlilS REPORT

l APPENDIX B

[ AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-254 UNIT ONE DATEMarch 01 1983 .

COMPLETED BYRandall D Buss t

TELEPHONE 309-654-224ix181 NONTH Februarv 1983 1 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL

! (MWe-Net) (MWe-Net)

i. 775.8 17. 490.0

2. 782.5 18. 687.8

3. 780.7 19. 756.5

4. 783.6 20. 734.2

5. 707.1 21. _

754,i L 6. 823.6 *

22. 761.6

7. 782.4 23. 706.5 i

8. 782.3 24. 744.7

9. 779.8 25. 759.1

10. 783.8 26. 760.4

11. 781.8 27, 694.0

12. 784.7 28. 739.7

13. 754.7

14. 761.0

15. 736.8 .

16. 508.0 INSTRUCTIONS On this forn, list the average daily salt power level in MWe-Net for each day in the reperting nonth.Conpite to the nearest whole negawatt.

These figures will be esed to plot a graph for each reperting nonth. Note that when notinen dependable capacity is used for the net electrical rating of the snit there may be occasions when the daily overege power level exceeds the 1983 line (or the restricted pcuer level line),In sich cases,the average daily unit power output sheet sheeld be festnoted to explain the apptrent onencly l

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. APPENDIX B AVERAGE DAILY UNIT POWER LEVEL

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DOCKET.NO.

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50-265 UNIT TWO

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.- __-._.._.__ --_.~~~'DATEMorch'Oi'1983 ~~ ~ ~

. . _ ..2_ .. _ ..__...n COMPLETED BYRondall D' Buss TELEPHONE 309'654-2241xi81 -

-MONTH 1 - Februarv-1983 _

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~

DAY AVERAGE. DAILY POWER. LEVEL- DAY AVERAGE DAILY POWER' LEVEL (MWe-Net)' -- -

"(MWe-Net)'- - ' ~ ~ ~ ~ ~ - ' ~

i. 5.0 17. 756.4 .

_. . . . _ . , . . . _ _ _ _ - ~ . _ . . - -

2. -6.0' 18 . -

747.7

(~

• L 37., _g. 4 ~_ . . - _ = ._.

, _.__ __. _g9 , 73g , 9 _ -

-4. 413.6 20. 530.4

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l S. 571.3' 21.- -638.0

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i 653.5

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721.-4 _._ _ _

! 8. 733.i_ 24, 752.0

" ' " ' ' ~ ~

3. 754;0' ~ - ' ~

'25. " ~ ' ' 749'i0

10. 758.5 26. 743.8-ii. 753.8 '27. 600.3

- - 12 . 656;0 -

28 ~.

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'704.2

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13. 730.1

14. 712.8 .

' ~ ~ 15 '. 714.8

.16. .

751.8 -

INSTRUCTIONS .

- On this fern

,a, interest whole,negewett. list the overage .. .. -

daily enit power level in ille-Net for each day in the reporting nenth.Conpite to the These figures will be vsed to plot a graph for each reporting nonth. Note that when noninen dependable capacity is used for the net electrical rating of the enit

.1001 line (or the restricted power level line)[there In sich cases,theney be occasions overage daily when snitthe power dailyoutputoverage sheetpower shouldlevel be exceeds the y.. _festnoted to explain the apparent anenely l _

M M M n M M M M M M M M M M n r"""1 n ID/5A APPENDIX D QTP 300-S13 UNIT SilUTDOWNS AND POWER REDUCTIONS Revision 6 DOCKET NO. 050-254 August 1982 UNIT NAME Quad-Citles Unit One CotfPI.ETED BY Randal1 Buss DATE March 3, 1983 REPORT tl0NTl! February 1983 TEI.EPl10NE 309-654-2241 m 5 e w 8 $EE N $w

$ $ M l.ICENSEE @ @

u w DURATION M g EVENT $ o NO. DATE (IIOURS) o REPORT NO. CORRECTIVE ACTIONS /CONilENTS a

83-8 830206 s 0.0 B* 5 HA XXXXXX Load reduced to perform weekly Turbine tests 83-9 830213 S 0.0 B 5 HA XXXXXX Load reduced to perform weekly Turbine tests 83-10 830214 F 0.0 B 5 HG DEtil NX Reduced load due to Condensate Demineralizer problems and to change Reactor Feed Pumps 83-11 830216 F 9.3 H 3 ZZ ZZZZZZ Reactor scram from Main steam Line High Flow signal caused by contractors hitting instrument rack resulting in a spurious trip 83-12 830219 s 0.0 B 5 HA XXXXXX Load reduced to perform weekly Turbine tests 83-13 830223 F 0.0 B 5 HG DEMINX Reduced load due to Condensate Demineralizer problems 83-14 830223 F 0.0 B 5 HG DEtilNX Reduced load due to Condensate Demineralizer problems APPROVED 83-15 830227 5 0.0 B 5 HA XXXXXX Load reduced to perform AUG 1 G 1982

__ weekly _Iurh ina tacts (final) _ ygg3g P

n n n n M M M M M M M M M M f*'"1 n n p ID/5A APPENDIX D QTP 300-S13 tlNIT SilHTDOWNS AND POWER REDIICTIONS Revision 6 DOCKET NO. _050-265 August 1982 UNIT NAffE _ Quad-Cities Unit Two Cot!Pl.ETED IlY Ran_daLLBust DATE tia rch_3,_19_83 REPORT HONTil February _1383_ TEl.EPil0NE _

309-654-2241 N $ H w" B $EE "w $w

$ Q $ LICENSEE @ @

w DURATION d EVENT go 0 o

NO. DATE U (Il0URS) o REPORT NO. CORRECTIVE ACTIONS /C0titIENTS o

83-13 830128 S 73.9 B 4 HF PdMPXX Continuation of tiaintenance Outage to repair 2C Circulating Water Pump casing 83-14 830206 F 0.0 B 5 HC VALVEX Reduced load to repair tioisture Separator Drain Tank Emergency Drain Valve 83-15 830212 S 0.0 B 5 HA XXXXXX Reduced load to perform weekly Turbine tests 83-16 830212 F 0.0 B 5 HG DEtil NX Load reduced due to Condensate Demineralizer problems 83-17 830214 F 0.0 B 5 CH PUtiPXX Load reduced to repai r leak in 28 Reactor Feed Pump Seal Water System 83-18 830214 S 0.0 5 EA ZZZZZZ Load reduction requested by Load Dis-patcher due to low system demand 83-19 830219 5 0.0 5 RB CONROD Load reduced to adjust Control Rod Pattern 83-20 830227 S 0.0 B 5 HA XXXXXX Load reduced to perform weekly Turbine tests A P f' ROV E D AUG 1 G 1982 (final) ygObH

4 VI. UNIOUE REPORTING RFI)UIRFMENTS The following items are included in this report based on prior commitments to the commission:

A. MAIN STEAM' RELIEF VALVE OPERATIONS There were no Main Steam Relief Valve Operations for the reporting period.

F B. CONTROL ROD DRIVE SCRAM TIMING DATA FOR UNITS ONE AND TWO There was no Control Rod Drive Scram Timing Data for Units One and Two for the reporting period.

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VII. REFUELINC INFORMATION The following information about future reloads at Quad-Cities Station was requested in a January 26, 1978, licensing nemorandum (78-24) from D. E. O'Brien to C. Reed, et al. , titled "Dresden, Quad-Cities, and Zion Station--NRC Request for Refueling Information",

dated January 18, 1978, i

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QTP 300-S32

[. . ' Revision 1 QUAD-CITIES REFUELING March 1970 i

s INFORMATION REQUEST

r. ,

1. Unit

Q1 Reload: 6 Cycle: 7

2. Scheduled date for next refueling shutdown: 9-6-82 3 Scheduled date' for restart following refueling: 12-18-82 -

F

4. Will refueling or resumption of operation thereaf ter require a technical specification change or other license amendment: Yes R

L

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

. Information: 8-19-82: Tech. Spec. changes submitted to the NRC.

6. Important licensing considerations associated with refueling, e.g., new or

' dif ferent fuel design or supplier, unreviewed design or performance analysis methods, significant changes in fuel design, new operating procedures:

a) All 7x7 fuel assemblies vill be removed from the core.

b) MAPLHGR curves for fuel types in the core are being extended to h0,000 MWD /ST.

s c) MCPR limits will be determined by GE's GDYN computer code.

d) The vessel pressure safety limit is being modified to acco==odate the potential for higher reacter pressures as calculated by ODYN.

I li 7 The number of fuel assemblies.

1

a. Number of assemblies la core: 724

b. Number of assemblies in spent fuel pool: 800

8. The present licensed spent fuel pool storage capacity and the size of any increase in licensed storage capacity that has been requested or is planned in number of fuel assemblies:

1

a. Licensed storage capacity for spent fuel: 3657

b. Planned increase in licensed storage: 0 9 The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity: 2003

[ APPROVED APR 2.01978 Q.c.o.S.R.

5

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QTP 300-S32 Revision 1 I..

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QUAD-CITIES REFUELING H2rch 1978 s INFORMATION REQUEST r ,

, 1. Unit: Q2 Reload: 6 Cycle: 7 m 2. Scheduled date for next refueling shutdown: 9-11-83 3 Scheduled date'for restart following refueling: 11-20-83 -

4. Will refueling or resumption of operation thereaf ter require a technical specification change or other license cmendment:

Depending upon the Licensing analyses, a MCPR limit change may be needed.

L 5 Scheduled d. ate (s) for submitting proposed licensing action and supporting 1 * " "

8-22-83 (if necessary) b j

P

6. Important IIcensing considerations associated with refueling, e.g., new or

• different fuel design or supplier, unreviewed design or performance analysis

, methods, significant changes irt fuel design, new operating procedures:

y NFS intends to apply 10CFR50.59 to the Q2R6CT reload unless MCFB Technical Specification change is required.

~,

7 The number of fuel assemblies.

[

.1

a. Number of assemblies la core:

72h

b. Number of assemblies in spent fuel pool: 1140

8. The present licensed spent fuel pool storage capacity and the size of any increase in licensed storage capacity that has been requested or is planned in number of fuel assemblies:

1 -

a. Licensed storage capacity for spent fuel: 3897

b. Planned increase in licensed storage: 0 9 The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present IIcensed capacity: 2003

.[ WPPROVED APR 2 01978 a

Q.C.O.S.R.

m.

VIII, CLOSSARY 4

The following abbreviations which may have been used in the Monthly Report, are defined below: -

ACAD/ CAM - Atmospheric Containment Atmospheric Dilution / Containment Atmospheric Monitoring ANSI -

American National Standards Institute APRM - Average Power Range Monitor ATWS - Anticipated Transient Without Scram BWR - Bolling Water Reactor CRD - Control Rod Drive EHC - Electro-Hydraulic Control System EOF -

Bnergency Operations Facility CSEP - Generating Stations Emergency Plan HEPA -

High-Ef ficiency Particulate Filter I, HPCI - - High Pressure Coolant Injection System HRSS - High Radiation Sampling System 4

IPCLRT - Integrated Primary Containment Leak Rate Test lIRM - Intermediate Range Monitor ISI -

Inservice Inspection LER - Licensee Event Report l

LLRT -

Local Leak Rate Test LPCI - Low Pressure Coolant Injection Mode of RHRS

. LPRM - Locci Power Range Monitor MAPLHCR - Maximum Average Planar Linear Heat Generation Rate

, MCPR -

Minimun Critical Power Ratio

.MFLCPR - Maximum Fraction Limiting Critical Power Ratio MPC -

Maximum Permissible Concentration MSIV -

Main Steam Isolation Valve NIOSH - National Institute for Occupational Safety and Health

. PCI - Primary Containment Isolation PCIOMR - Precondition 1ng Interim Operating Management Recommendations 1 RBCCW - Reactor Building Closed Cooling Water System RBM. -

Rod Block Monitor RCIC - Reactor Core Isolation Cooling System RHRS - Residual Heat Removal System RPS - Reactor Protection System RWM -

Rod Worth Mininizer SBGTS - Standby Cas Treatment System SBLC - Standby Liquid Control SDC - Shutdown Cooling Mode of RHRS SUV - Scram Discharge Volume SRM - Source Range Monitor TBCCW - Turbine Building . Closed Cooling Water System TIP. - Traveling Incore Probe

' Technical Support Center TSC -

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